,· I THISFILINGIS Item 1: 00 An Initial (Original) OR D Form 1Approved OMB No.1902-0021 Resubmission No. (Expires 11/30/2016) Submission Form 1-F Approved OMS No.1902-0029 (Expires 11/30/2016) Form 3-Q Approved OMB No.1902-0205 (Expires 11/30/2016) FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of ~ajor Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Reporti 0 ~~ <' ---;.- . ·>c; poz ~------------------------------------------~ ~·10 These reports are mandatory under the Federal Power Act, Sections 3, 4{a), 304 and 309, and :; ..,., 18 CFR 141 .1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature Exact Legal Name of Respondent (Company) -r -r "" - c:::) C 7' :X l> -< I N ~ ~ c.n N r c: ;:.· ("")6 o>::t I!" "'Ct'T'' stcr =--rorr r->r:;c ~nrr o(./)c...t~r ~ < ("') ...... Year/Period of Report INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q GENERAL INFORMATION I. Purpose FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q)is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms. II. Who Must Submit Each Major electric utility, licensee, or other, as classified in the Commission's Uniform System of Accounts Prescribed for Public Utilities and Licensees Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101 ), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400). Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following: (1) one million megawatt hours of total annual sales, (2) 100 megawatt hours of annual sales for resale, (3) 500 megawatt hours of annual power exchanges delivered, or (4) 500 megawatt hours of annual wheeling for others (deliveries plus losses). Ill. What and Where to Submit (a) Submit FERC Forms 1 and 3-Q electronically through the forms submission software. Retain one copy of each report for your files. Any electronic submission must be created by using the forms submission software provided free by the Commission at its web site: http://www.ferc.gov/docs-filinq/eforms/form-1/elec-subm-soft.asR. The software is used to submit the electronic filing to the Commission via the Internet. (b) The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings. (c) Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at: Secretary Federal Energy Regulatory Commission 888 First Street, NE Washington, DC 20426 {d) For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class Cor Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above. FERC FORM 1 & 3-Q (ED. 03-07) The CPA Certification Statement should: a) Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and b) Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.) Reference Schedules Comparative Balance Sheet Statement of Income Statement of Retained Earnings Statement of Cash Flows Notes to Financial Statements e) 110-113 114-117 118-119 120-121 122-123 The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported. "In connection with our regular examination of the financial statements of _ _ for the year ended on which we have reported separately under date of , we have also reviewed schedules ---~---___,.of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances. Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases." The letter or report must state which, if any, of the pages above do not conform to the Commission's requirements. Describe the discrepancies that exist. (f) Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. To further that effort, new selections, "Annual Report to Stockholders," and "CPA Certification Statement" have been added to the dropdown "pick list" from which companies must choose when eFiling. Further instructions are found on the Commission's website at http://www.ferc.gov/help/how-to.asp. (g) Federal, State and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from http://www.ferc.gov/docs-filing/eforms/form-1/form-1.pdf and http://www. ferc.gov/docs-filing/eforms. asp#3Q-gas . IV. When to Submit: FERC Forms 1 and 3-Q must be filed by the following schedule: FERC FORM 1 & 3-Q (ED. 03-07) II a) FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1 ), and b) FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400). V. Where to Send Comments on Public Reporting Burden. The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,144 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 150 hours per response. Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S. C.§ 3512 (a)). FERC FORM 1 & 3-Q (ED. 03-07) iii GENERAL INSTRUCTIONS I. Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA. 11. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts. Ill Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact. IV. For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3. V. Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below). VI. Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses. VII For any resubmissions, submit the electronic filing using the form submission software only. Please explain the reason for the resubmission in a footnote to the data field. VIII. Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized. IX. Wherever (schedule} pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used. Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows: FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self' means the respondent. FNO- Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. LFP- for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and" firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the FERC FORM 1 & 3-Q (ED. 03-07) iv termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract. OLF- Other Long-Term Firm Transmission Service. Report service provided under contraCts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract. SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year. NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry. AD -Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. EFINITIONS Commission Authorization (Comm. Auth.) --The authorization of the Federal Energy Regulatory Commission, or any ther Commission. Name the commission whose authorization was obtained and give date of the authorization. II. Respondent-- The person, corporation, licensee, agency, authOrity, or other Legal entity or instrumentality in whose behalf the report is made. ··-····--·-.....,.. FERC FORM 1 & 3-Q (ED. 03-07) v _____ EXCERPTS FROM THE LAW Federal Power Act, 16 U.S.C. § 791a-825r Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with: {3) 'Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined; (4) 'Person' means an individual or a corporation; {5) 'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof; (7) 'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ...... {11) "project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit; "Sec. 4. The Commission is hereby authorized and empowered (a) To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development -costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act." "Sec. 304. (a) Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may be rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the -proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports salt be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.1 0 FERC FORM 1 & 3-Q (ED. 03-07) vi "Sec. 309. The Commission shalf have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field ... " General Penalties The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a). FERC FORM 1 & 3-Q (ED. 03-07) vii FERC FORM NO. 1/3-Q: REPORT OF MAJOR ELECTRIC UTILITIES LICENSEES AND OTHER IDENTIFICATION 02 Year/Period of Report 01 Exact Legal Name of Respondent · Florida Power & Light Company End of 2015/Q4 03 Previous Name and Date of Change (if name changed during year) I I of 04 Address Principal Office at End of Period (Street, City, State, Zip Code) 700 Universe Boulevard, P.O. Box 14000, Juno Beach, Florida 33408 05 Name of Contact Person Kim Ousdahl 06 Title of Contact Person VP, Controller & CAO 07 Address of Contact Person (Street, City, State, Zip Code) 700 Universe Boulevard, P.O. Box 14000, Juno Beach, Florida 33408 08 Telephone of Contact PersonJncJud/ng 09 This Report Is Area Cqde (1) IX) An Original (561) 694-6231 (2) 0 A Resubmission 10 Date of Report (Mo, Da, Yr) I I ANNUAL CORPORATE OFFICER CERTIFICATION The undersigned officer certifies that I have examined !his report and to the best of my knowledge, information, and belief all statements of fact contained In this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts. 01 Name Kim Ousdahl 03 Signature 04 Date Signed ~ Ott~ (Mo, Da, Yr) 0211tle . Vice President Controller & CAO 04/15/2016 Title 18, U.S.C, 1001 makes It a crime for any person to knowingly and wunngly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction. FERC FORM No.1/3-Q (REV. 02~04) Page 1· Name of Respondent This ~ort Is: (1) An Original (2) flA Resubmission Florida Power & Light Company Date of Report (Mo, Da, Yr) II Year/Period of Report 2015/Q4 End of LIST OF SCHEDULES (Electric Utility) Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA". Line No. Title of Schedule Reference Page No. (b) (a) 1 General Information (c) 101 2 Control Over Respondent 102 3 Corporations Controlled by Respondent 103 4 Officers 104 5 Directors 105 6 Information on Formula Rates 106(a)(b) 7 Important Changes During the Year 108-109 8 Comparative Balance Sheet 110-113 9 Statement of Income for the Year 114-117 10 Statement of Retained Earnings for the Year 118-119 11 Statement of Cash Flows 120-121 12 Notes to Financial Statements 122-123 13 Statement of Accum Comp Income, Comp Income, and Hedging Activities 122(a)(b) 14 Summary of Utility Plant & Accumulated Provisions for Oep, Amort & Dep 200-201 15 Nuclear Fuel Materials 202-203 16 Electric Plant in Service 204-207 17 Electric Plant Leased to Others 213 18 Electric Plant Held for Future Use 214 19 Construction Work in Progress-Electric 216 20 Accumulated Provision for Depreciation of Electric Utility Plant 21 Remarks Not Applicable 219 Investment of Subsidiary Companies 224-225 22 Materials and Supplies 227 23 Allowances 228(ab)-229(ab) 24 Extraordinary Property Losses 230 Not Applicable 25 Unrecovered Plant and Regulatory Study Costs 230 Not Applicable 26 Transmission Service and Generation Interconnection Study Costs 231 27 Other Regulatory Assets 232 28 Miscellaneous Deferred Debits 233 29 Accumulated Deferred Income Taxes 234 30 Capital Stock 250-251 31 Other Paid-in Capital 253 32 Capital Stock Expense 254 33 Long-Term Debt 256-257 34 Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax 261 35 Taxes Accrued, Prepaid and Charged During the Year 262-263 36 Accumulated Deferred Investment Tax Credits 266-267 FERC FORM NO. 1 (ED. 12-96) Page 2 This I!Jort Is: (1) An Original (2) [jA Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/04 End of U T OF SCHEDULES (Electric Utility) (continued) Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA". Reference Page No. (b) Title of Schedule Line No. (a) (c) 269 37 Other Deferred Credits 38 Accumulated Deferred Income Taxes-Accelerated Amortization Property 272-273 39 Accumulated Deferred Income Taxes-Other Property 274-275 40 Accumulated Deferred Income Taxes-Other 276-277 41 Remarks Not Applicable 278 Other Regulatory Liabilities 300-301 42 Electric Operating Revenues 302 43 Regional Transmission Service Revenues (Account 457. 1) Not Applicable 304 44 Sales of Electricity by Rate Schedules 45 Sales for Resale 310-311 48 Electric Operation and Maintenance Expenses 320-323 47 Purchased Power 326-327 48 Transmission of Electricity for Others 328-330 49 Transmission of Electricity by ISO/RTOs 331 50 Transmission of Electricity by Others 332 51 Miscellaneous General Expenses-Electric 335 52 Depreciation and Amortization of Electric Plant 336-337 53 Regulatory Commission Expenses 350-351 54 Research, Development and Demonstration Activities 352-353 55 Distribution of Salaries and Wages 354-355 Not Applicable 56 Common Utility Plant and Expenses 356 Not Applicable 57 Amounts included in ISO/RTO Settlement Statements 397 Not Applicable 58 Purchase and Sale of Ancillary Services 398 59 Monthly Transmission System Peak Load 400 60 Monthly ISOIRTO Transmission System Peak Load 400a 61 401 Electric Energy Account 62 Monthly Peaks and Output Not Applicable 401 63 Steam Electric Generating Plant Statistics 402-403 64 Hydroelectric Generating Plant Statistics 406-407 Not Applicable 65 Pumped Storage Generating Plant Statistics 408-409 Not Applicable 66 Generating Plant Statistics Pages 410-411 Not Applicable FERC FORM NO.1 (ED. 12-96) Page 3 This ~ort Is: (1) An Original (2) []A Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/Q4 End of LIST OF SCHEDULES (Electric Utility) (continued) Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA". Title of Schedule Line No. Reference Page No. {b) (a) 67 Transmission Line Statistics Pages 422-423 68 Transmission Lines Added During the Year 424-425 69 Substations 426-427 70 Transactions with Associated (Affiliated) Companies 71 429 450 Footnote Data Stockholders' Reports Check appropriate box: D Two copies will be submitted 0 No annual report to stockholders is prepared FERC FORM NO. 1 (ED. 12-96) Page 4 Remarks (c) Name of Respondent This Report Is: (1) (2) Florida Power & Light Company 00 0 An Original A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I End of 2015/04 GENERAL INFORMATION 1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept. Kim Ousdah~, Vice President, Contro~~e:r and Chief Accounting Office:r 700 Unive:rse Boulevard Juno Beach, ~lorida 33408 2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized. ~1orida - December 2B, 1925 3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased. Not App~i.cable 4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated. E~ectric Utility Service is provided in Florida. The respondent owns 76.36% of Scherer Unit No. 4, a generating unit ~ocated in centr~ Georgia. coa~-fi:red 5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements? (1) (2) D Yes ... Enter the date when such independent accountant was initially engaged: !X] No FERC FORM No.1 (ED. 12-87) PAGE 101 Name of Respondent This Report Is: Florida Power & Light Company ( 1) (2) 00 0 An Original A Resubmission Date of Report (Mo, Da, Yr) I I Year/Period of Report End of CONTROL OVER RESPONDENT 1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the repondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiearies for whom trust was maintained, and purpose of the trust. NextEra Energy, Inc. a holding company, is the sole holder ofthe common stock of the respondent. FERC FORM N0.1 (ED. 12-96} Page 102 2015/04 Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote . . If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved. 3. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests. Definitions 1. See the Uniform System of Accounts for a definition of control. 2. Direct control is that which is exercised without interposition of an intermediary. 3. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party. Line No. Name of Company Controlled Kind of Business {a) (b) Business Development Percent Voting Stock Owned (c) 100 100 12.5 100 4 FPL Services, LLC 100 Generating 100 Gas Production 100 26 27 FERC FORM NO. 1 (ED. 12-96) Page 103 This Report is: {1) ~An Original (2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) 2015/04 I I FOOTNOTE DATA !Schedule Page: 103 Line No.: 1 Cglumn: tj__-------.-----.-------,--,.-------.-----.,--.---;-;------;o----=------.--:---__j l§chedule Page: 103 Line No.: 2 Column: d___ _ FPL Enersys, Inc., a Florida corporation, is a wholly-owned subsidiary of Respondent formed to investigate and pursue opportunities for the development and acquisition of energy systems. KPB Financial Corp., a Delaware corporation, is a wholly-owned subsidiary of Respondent formed to manage and maintain intangible assets related to Respondent's Storm Restoration and Non-Qualified Decommissioning Funds. [Schedule Page: 103 Line No.: 3- Columii:-d--=------------------------- Private Fuel Storage, LLC, is a Delaware limited liability company (the "Company") formed by eight (8) utility companies to obtain a license to site an Independent Spent Fuel Storage facility on land owned by the Bank of Goshute Indians in the State of Utah. Members include: Respondent, Energy Nuclear PFS Company, Genoa Fueltech, Inc., GPU Nuclear, Indiana Michigan Power Company, Northern States Power Company, Southern California Edison and Southern Nuclear Operating Company. Each member has a 12.5% ownership interest in the Company. This company is considered a non-operating entity as it does not actively transact business. Further, Florida Power & Light Company has no recorded investment in this entity (Account 123/Account 123.1). [Schedule Page: 103 Line No.: 4 Column: d ______ _______ ------------- FPL Services, LLC, a Florida limited liability company and wholly-owned subsidiary of FPL Enersys, Inc. (Line 1 above), was formed to provide marketing, development, design, installation, construction, financing and servicing of energy conservation projects. Respondent owns 100% of the voting stock of the parent company of FPL Services, LLC, FPL Enersys, Inc. (Line 1 above). !Schedule Page: 103 Line No.: s -·--coiumn·:c:r·- RGs Realty Holdings, LLC, a Delaware limited liability company is a wholly-owned subsidiary of Respondent and owns all o£ the membership interests in RGS Realty, LLC (line 6 below) and Gray Sky Investments, LLC (Line 7 below) . ~ch-eiiiii8fiii9"i):-i03-- 'Lirie-No~:-·if Column: d - . . --- -- - --- -- - ---- . -···-· m • ---~ RGS Realty, LLC, a Delaware limited liability and wholly-owned subsidiary o£ RGS Realty Holdings, LLC (Line 5 above), and is a indirect subsidiary of the Respondent formed to acquire real estate · ~chedule P~~ 1o3 Line No.:i ___ coiumn:qii------------------ Gray Investments, LLC, a Delaware limited liability company and wholly-owned subsidiary of RGS Realty Holdings, LLC (Line 5 above), and is an indirect subsidiary of Respondent formed to acquire real estat_e~~---------------------------------- [SChedu/e Page: 103 LTne-Na:·:-8 Column: d -----·--------·- ·· - --- - FPL Recovery Funding, LLC, a Delaware limited liability company and wholly-owned subsidiary of the Respondent, formed authorize, issue, sell and deliver storm recovery bonds [Schedu--=-le----=-Pa-g-e: ·;;o3 -- -"Line No.: 9 Column: d APOG, LLC, a Delaware limited liability company, was--formed to provide technical, engineering and procurement support services to and for the benefit of member-owned or member-operated nuclear facilities. Members include: Respondent, Duke Energy Carolinas, LLC, Duke Energy Progress,Inc., Duke Energy Florida, Inc., South Carolina Electric & Gas Company and Georgia Power Company. ~E_f!.~!!_!l!_!!.!!11!!.:..1Q3 une No.: 10 -cc)ifiliiil:-"ir··-- ---------------- cedar Bay Holdings, LLC, a Delaware limited liability company and wholly-owned subsidiary of Respondent, holds the general and limited partnership interests in Cedar Bay Generating Company, Limited Partnership (Line 13 below) \§_chedule Page: 103 Lin_~_r!._(!:.:_!_J._ Column: d ---------- Cedar Bay Cogeneration, LLC, a Delaware limited liability compa-ny-an:cr-wl:loiiY--owned subsidiary of Cedar Bay Holdings, LLC (Line 10 above), is an indirect subsidiary of Respondent holding a 2% general partnership interest and a 78% limited partnership interest in Cedar Bay Generating Company 1 Limited Partnership (Line -13 below) ~f?hec!_~le Page: 103 ___ L~I}e tyo.:._12 IFERC FORM NO. 1 (ED. 12-87) Columli:-iF __ _ Page450.1 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original I{2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 FOOTNOTE DATA Cedar II Power, LLC, a Delaware limited liability company and wholly-owned subsidiary of Cedar Bay Holdings, LLC (Line 10 above), is an indirect subsidiary of Respondent holding a 20% general partnership interest in Cedar Bay Generating Company, Limited Partnership (Line 13 below) ~chedu/e Page: 103 Line No.: 13 Column: d ·----,-.....-------:~,.-----;;-;-----.-:----,,.----,.------;-;----;---~ Cedar Bay Generating Company, Limited Partnership, a Delaware limited partnership, is an indirect subsidiary of Respondent owned by Cedar Bay Cogeneration, LLC (Line 11 above} and Cedar II Power, LLC (Line 12 above) and holds ~~~.Cedar Bay generating assets f§_~hedU'-f! Pf!g~~-103 Line No.: 14 Column: d GR Woodford Properties, LLC, a Delaware limited liability company and wholly-owned --subsidiary of Respondent, was formed to operate production in gas reserves properties IFERC FORM NO. 1 (ED. 12-87) Page 450.2 BLANK PAGE (Next Page is 104) Name of Respondent This wort Is: (1) An Original (2) EJA Resubmlssion Florida Power & Light Company Date of R~ort (Mo, Da, r) I I Year/Period of Report 2015/04 End of OFFICERS 1. Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer'' of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions. 2. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made. .Line No. Title Name of Officer {a) {b) 1 Chairman James L. Robo Sala~ for Ye r (c) 774,788 2 President & CEO Eric E. Silagy 723,700 3 EVP, Finance and Chief Financial Officer Moray P. Dewhurst 457,613 4 Treasurer Paul I. Cutler 275,506 5 VP Compliance & Corporate Secretary W. Scott Seeley 207,640 6 EVP, Power Generation Division Miguel Arechabala 199,694 7 President, Nuc:lear Division and Chief Nuclear Officer Manoochehr K. Nazar 420,300 8 SVP Power Delivery Manuel B. Miranda 353,430 9 10 11 12 13 14 15 16 17 .. 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 FERC FORM NO. 1 (ED. 12-96) Page 104 Name of Respondent Florida Power & Light Company This wort Is: (1) An Original (2) [JA Resubmlsslon DIRECTORS Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/04 End of 1. Report below the Information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), abbreviated titles of the directors who are officers of the respondent. 2. Designate members of the Executive Commitiee by a triple asterisk and the Chaimnan of the Executive Committee by a double asterisk. Name (and :ntle) of Director Princ1pal Business Address L~g {a) (b) 1 James L. Robo P.O. Box 14000 2 Juno Beach, FL 33408 Chairman of the Board 3 4 5 Eric E. Silagy 6 President and Chief Executive Officer 7 8 9 Moray P. Dewhurst 10 Executive Vice President, Finance and Chief Financial 11 Officer 12 13 14 15 P.O. Box 14000 Juno Beach, FL 33408 P.O. Box 14000 Juno Beach, FL 33408 16 17 18 Note: There was no FPL Executive Committee in 2015 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 FERC FORM NO. 1 (ED. 12-95) Page 105 Name of Respondent Florida Power & Light Company This ~ort Is: {1) An Original (2) E] A Resubmission Date of Report {Mo, Da, Yr) I I Year/Period of Report End of 2015/04 INFORMATION ON FORMULA RA ES FERC Rate Schedule/Tariff Number FERC Proceeding Does the respondent have formula rates? Qg Yes O No 1. Please list the Commission accepted formula rates Including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate. Line No. FERC Rate Schedule or Tariff Number FERC Proceeding 1 FERC Rate Schedule No. 317 Docket No. ER11-3742-000 2 FERC Rate Schedule No. 322 Docket No. ER11-3740-000 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 FERC FORM NO. 1 (NEW. 12-08) Page 106 Name of Respondent This {!]ort Is: An Original (1) (2) A Resubmission EJ Florida Power & Light Company Date of Report (Mo, Da, Yr) I I Year/Period of Report End of 2015/04 INFORMATION ON FORMULA RATES FERC Rate Schedule/Tariff Number FERC Proceeding 0 Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)? [XI Yes No 2. If yes, provide a listing of such filings as contained on the Commission's elibrary website Une No. Accession No. Document Date \Filed Date Docket No. Description 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 FERC FORM N0.1 {NEW. 12-08) Page 106a Formula Rate FERC Rate Schedule Number or Tariff Number Name of Respondent Florida Power & Light Company This wort Is: (1} An Original (2) [] A Resubmission Date of Report (Mo, Da, Yr} I I Year/Period of Report End of 2015/Q4 INFORMATION ON FORMULA RATES Formula Rate Variances 1. If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate Inputs differ from amounts reported in the Form 1. 2. The footnote should provide a narrative description explaining how the "rate" (or billing} was derived if different from the reported amount in the Form 1. 3. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts. 4. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote. line No. Page No{s}. 1 110-111 2 112-113 3 200 4 204-207 5 204-207 6 214-214.3 7 232 8 278 Column Schedule Comparative Balance Sheet {Assets and Other Debit) Comparative Balance Sheet (Liabilities and Other} Line No c 45,48-52, 54, 57, 82 c 3, 16,24,63,64 Summary of Utility Plant and Accumulated Provision B 12 Electric Plant In Service Other Regulatory A.ssets G 5, 15, 24,44, 46, 57,58 G 74, 75, 86-95, 97-99, 101 D 46 F 21,35,41 Other Regulatory Liabilities F 36 Electric Plant in Service Electric Plant Held for Future Use 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 FERC FORM NO. 1 (NEW. 12-08) Page 106b Name of Respondent Florida Power & Light Company This Report Is: {1) [29 An Original (2) A Resubmission 0 Date of Report I I Year/Period of Report End of 2015/04 IM ORTANT CHANGES DURING THE QUARTER/YEAR Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears. 1. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact. 2. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization. 3. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission. · 4. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization. 5. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each dass of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc. 6. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees induding issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee. 7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments. 8. State the estimated annual effect and nature of any important wage scale changes during the year. 9. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year. 10. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Page 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest. 11. (Reserved.) 12. If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page. 13. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have .occurred during the reporting period. 14. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio. PAGE 108 INTENTIONALLY LEFT BLANK SEE PAGE 109 FOR REQUIRED INFORMATION. FERC FORM NO. 1 (ED. 12-96) Page 108 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original i (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 IMPORTANT CHANGES DURING THE QUARTERNEAR (Continued) 1. Renewed franchise agreements for 30 years in the State of Florida, all with consideration of fees equaling 4.5%, 5.9% or 6.0% of specified revenues; 6.0% 6.0% 6.0% 4.5% 5.9% 6.0% 6.0% 6.0% City of Lake City City of Belle Glade City of Macclenny * Village of Estero Town of Haverhill City of Waldo * Martin County - Unincorporated Town of Sewall's Point * These are new franchise agreements. 2. On September 18, 2015, FPL purchased the equity interest in Cedar Bay Holdings, LLC (formerly CBAS Power, Inc.) which is the upstream owner of a 250 MW coal-fired topping cycle cogeneration facility located in Jacksonville, Florida. As part of this transaction, the long-term power purchase agreement in which FPL bought all the capacity and electric power from the facility was terminated. The transaction was approved by the Commission in Docket No. EC15-102-000 on July 2, 2015. Per the order authorizing the transaction, the final accounting entries are to be filed with the Commission within six months of consummating the transaction, which FPL completed as of March 16, 2016, Docket No. AC 16-60-000. 3. On February 18, 2014, Florida Power & Light filed a Section 203 application with FERC (Docket No. EC14-58-000) requesting authorization to acquire certain transmission assets and substation facilities from Lee County Electric Cooperative, Inc. The Commission authorized the transaction on April 3,2014. The transaction closed on December 30, 2014 and notice of consummation was filed on January 8, 2015. On June 4, 2015, FPL submitted final accounting entries to clear the assets from FERC account 102, Docket No. AC 15-143-000. On March 9, 2015, Florida Power & Light filed a Section 203 application with FERC requesting authorization to acquire a 138kV load break gang switch breaker and other related equipment included within the Belle Meade substation from Lee County Electric Cooperative. The purchase was recorded to FERC account 102. Commission authorization for acquisition of the assets, Docket No. EC15-89-000, was issued on May 5, 2015. On November 16, 2015, FPL submitted final accounting entries to clear the assets from FERC account 102, Docket No. AC 16-22-000. 4. None. 5. None. 6. For information on Long-Term Debt, see Note 12 - Debt to the December 31, 2015 Consolidated Financial Statements. At December 31, 2015, FPL had $3,000 million of bank revolving line of credit facilities which provide for the funding of loans up to $3,000 million and the issuance of letters of credit of up to $1,070 million. At December 31, 2015, approximately $6 million in letters of credit were outstanding under FPL's bank revolving line of credit facilities. The entire amount of the bank revolving line of credit facilities is available for general corporate purposes and to provide additional liquidity in the event of a loss to the company's or its subsidiaries' operating facilities (including a transmission and distribution property loss). FPL's bank revolving line of credit facilities are also available to support the purchase of $718 million of pollution control, solid waste disposal and industrial development revenue bonds in the event they are tendered by individual bond holders and not remarketed prior to maturity. FPL also has a $200 million revolving IFERC FORM NO. 1 (ED. 12-96) Page 109.1 Name of Respondent Florida Power & Light Company This Report is: (1) 6 An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 IMPORTANT CHANGES DURING THE QUARTER/YEAR (Continued) credit facility. At December 31, 2015, no borrowings were outstanding under this revolving credit facility. In order for FPL to borrow or to have letters of credit issued under the terms of its revolving credit facilities, FPL is required, among other things, to maintain a ratio of funded debt to total capitalization that does not exceed a stated ratio. The FPL revolving credit facilities also contain default and related acceleration provisions relating to, among other things, failure of FPL to maintain the ratio of funded debt to total capitalization at or below the specified ratio. At December 31, 2015, FPL was in compliance with its required ratio. At December 31, 2015, FPL had standby letters of credit of approximately $6 million, all of which were issued under FPL's bank revolving line of credit facilities, and approximately $15 million of surety bonds. During 2015, FPL had issued commercial paper from time to time, with the maximum outstanding at any one time of approximately $1,152 million. At December 31, 2015, FPL had commercial paper outstanding of approximately $56 million and current notes payable of $100 million. The incurring of these obligations was authorized under FPSC Order No. PSC-14-0656-FOF-EI. 7. None. 8. None. 9. See Notes to the December 31, 2015 Consolidated Financial Statements - Note 14 Commitments and Contingencies - Legal Proceedings and Note 1 - Rate Regulation for a discussion of an appeal related to the Cedar Bay settlement and Revenues and Rates for a discussion of FPL's notification to the FPSC indicating its intent to initiate a base rate proceeding. Also, during 2015, the State of Florida Office of Public Counsel and the Florida Industrial Power Users Group each filed notices of appeal to the Florida Supreme Court challenging the FPSC's approval of FPL's initial investment in the Woodford Shale natural gas production wells and challenging the FPSC's approval of the guidelines, which appeals are pending. 10. None. 12. Not Applicable. 13. 01/02/2015 Paul W. Hamilton resigned as Vice President - Transition 01/10/2015 Joseph N. Jensen's title was changed from Vice President, St. Lucie Nuclear Power Plant to Vice President, Fleet Support Services 01/26/2015 Christopher R. Costanzo was appointed as Vice President, St. Lucie Nuclear Power Plant 04/13/2015 Ashok S. Bhatnagar resigned as Vice President, Nuclear Fleet Support 05/29/2015 Mark E. Hickson's title changed from Vice President, Corporate Development and Strategic Initiatives to Senior Vice President, Corporate Development and Strategic Initiatives 05/29/2015 John J. Coneys was appointed as Vice President and Chief Tax Officer IFERC FORM NO.1 (ED. 12~96) Page 109.2 Name of Respondent Florida Power & Light Company This Report is: (1) X An Original ! (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/Q4 IMPORTANT CHANGES DURING THE QUARTER/YEAR (Continued) 14. 05/29/2015 Michael W. Kiley's title changed from Vice President, Turkey Point Nuclear Power Plant to Vice President, Fleet Support 05/29/2015 Bryan Olnick was appointed as Vice President, Distribution Operations 05/29/2015 Thomas Summers was appointed Vice President, Turkey Point Nuclear Power Plant 05/29/2015 Manuel B. Miranda's title changed from Vice President, Power Delivery to Senior Vice President, Power Delivery 12/03/2015 Peter P. Sena resigned as Senior Vice President & Nuclear Chief Operating Officer Not Applicable. jFERC FORM N0.1 (ED. 12-96) Page 109.3 BLANK PAGE (Next Page is 110) Name of Respondent This Report Is: (1) [ZJ An Original A Resubmission Florida Power & Light Company Date of Report (Mo, Da, Yr) Year/Period of Report End of I I 2015104 COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS) Line No. PriorYear End Balance Ref. Page No. Title of Account 12/31 (b) (d) ~ -~r~~ 'C -•-~-~~--- - ~~----.,---~ -- ~~~-~-------- - - - -- ....,. _,.., - FERC FORM NO.1 (REV. 12-03) Page 110 . --- - -~ -~ - - ~ ~ --.,.,..,......~~~ - -- ,.,.--..-~"""'~- . ------ - - - - - - - ---~ Name of Respondent This Report Is: (1) ~ An Original (2) D A Resubmission Florida Power & Light Company Date of Report (Mo, Da, Yr) Year/Period of Report .End of I I 20151Q4 COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITSlcontlnued) Line No. Title of Account (a) (Less) Noncurrent Portion of Allowances 54 Stores Expense Undistnbuted (163) 55 Gas Stored Underground- Current (164.1) 56 Liquefied Natural Gas Stored and Held for Processing (164.2-164.3) 57 Prepayments (165) Advances for Gas (166-167) 59 Interest and Dividends Receivable (171) Prior Year End Balance 12/31 (d) 0 53 58 Current Year End of QuarterNear Balance (c) Ref. Page No. (b) 0 227 157,955 0 0 114,662,774 0 0 25,630,154 60 Rents Receivable (172) 61 Accrued Utility Revenues (173) 62 Miscellaneous Current and Accrued Assets (174) 8,961,639 63 Derivative Instrument Assets (175) 6,427,535 223,157,891 64 (Less) Long-Term Portion of Derivative Instrument Assets (175) 65 Derivative Instrument Assets- Hedges (176) 66 (Less) Long-Term Portion of Derivative Instrument Assets- Hedges (176 67 Total Current and Accrued Assets (Lines 34 through 66) 932,284 0 0 - DEFERRED DEBITS 68 1,872,855,136 ~ ~ --~-- " .. ~ ----- 69 Unamortized Debt Expenses (181) 78,081,655 83,657,242 70 Extraordinary Property Losses (182.1) 230a 0 0 71 Unrecovered Plant and Regulatory Study Costs (182.2) 230b 0 0 72 Other Regulatory Assets (182.3) 232 2,407,333,477 1,945,694,640 73 Prelim. Survey and Investigation Charges (Electric) (183) 32,905,076 13,160,480 74 Preliminary Natural Gas Survey and Investigation Charges 183.1) 0 0 75 Other Preliminary Survey and Investigation Charges (183.2) 0 0 76 Clearing Accounts (184) 24,031 8,414 77 Temporary Facilities (185) 78 Miscellaneous Deferred Debits (186) 79 Def. Losses from Disposition of UtiHty Pit. (187) 80 Research, Devel. and Demonstration Expend. (188) 81 Unamortized Loss on Reaquired Debt (189) 82 Accumulated Deferred Income Taxes (190) 83 Unrecovered Purchased Gas Costs (191) B4 Total Deferred Debits (lines 69 through 83) 85 TOTAL ASSETS (lines 14-16,32,67, and 84} FERC FORM NO.1 (REV. 12~03) 233 0 0 1,372, 778,384 1,577,604,968 300,809 0 0 352-353 104,720,41 234 ~i!t;ii~:@~j\~i?~~~~j 0 15,260,715 994,267,497 0 4,965,997,73 41,980,559,606 Page 111 4,629,653,956 38,678,263,906 Name of Respondent Florida Power & Light Company This Report is: {1) ~An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 20151Q4 FOOTNOTE DATA fSCiiiidule Page:.J10 Line No.: 45 Column: c Schedule No. 317 formula rate utilizes the simple average balances (averages of beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances (averages of beginning and ending balances) for all ra!_r:'. bas_e_i_n_,p~u_t-'--s-'-._ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - , i§Chedule Page: 110 Line N9.:: 48 Column: c Schedule No. 317 formula rate utilizes the simple average balances (averages of beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances (averages of beginning and ending bala~~e~2 for all rate base inputs. ~chedufe Page: 110 Line No.: 49 . Column: c Schedule No. 317 formula rate utiirzes··-the simple average baTances (averages of beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes and ending balances) for all rate base f§__chedule Pt!_gf!;.. !}O Line No.: 50 Column: c Schedule No. 317 formula rate utilizes and ending balances) for all rate base the simple average balances (averages of beginning inputs. Schedule No. 322 formula rate utilizes and ending balances) for all rate base ~cheduie Pag_e: 110 LineN!!:~·. 51 Column: c Schedule No. 317 formula rate utilizes and ending balances) for all rate base the simple average balances (averages of beginning inputs. Schedule No. 322 formula rate utilizes and ending balan.<;:~:>..L.~or all rate base ~'!.~f!.!:_if!g_e: 110 Line No.: 52 Column: c Schedule No. 317 formula rate utiiiZ'e's and ending balances) for all rate base the simple average balances (averages of beginning inputs. the simple average s·alances inputs. Schedule No. 322 formula rate utilizes and ending balances) for all rate base rsC.Iiedule Page: 110 Line No.: 54-- -Column: c Schedule No. 317 formula rate utilizes and ending balances) for all rate base the simple average balances (averages of beginning inputs. ----·- -· ·-·d•""'"_'_] the simple. average balances '(averages of beginning inputs. the simple average balan.ces (averages of beginning inputs. the simple average balances (averages of beginning inputs. (averages of beginning Schedule No. 322 formula rate utilizes the simple average balances (averages of beginning and ending balances) for all rate base inputs. !Schedule P'i:ige:11o Line No.: 57 Column:c·-·-·- - - - - - - - - ·schedule No. 317 formula rate-· utilizes the simple average--,-b-a'l_a_n_c_e_s_(:-a_v_e_r-age-s of beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes and ending balances) for all rate base :Schedule Page: 110 Line No.: 82 Column: c Schedule No. 317 ·:rorlliula rate utilizes and ending balances) for all rate base the simple average balances (averages of beginning inputs. the simple average balanc-es (averages of beginning inputs. Schedule No. 322 formula rate utilizes the simple average balances (averages of beginning and ending balances) for all rate base inputs. jFERC FORM N0.1 (ED. 12-87} Page450.1 BLANK PAGE (Next Page is 112) Name of Respondent This Report is: Florida Power & Light Company (1) ~ An Original A Resubmission Date of Report {mo, da, yr) I I Year/Period of Report end of 2015/04 ILITIES AND OTHER CREDITS) Line No. Title of Account Ref. Page No. (a) (b) FERC FORM NO. 1 (rev. 12-03) Page 112 Current Year End of QuarterNear Balance (c) Prior Year End Balance 12131 (d) Name of Respondent This Report is: Florida Power & Light Company (1) lXI An Original A Resubmission Date of Report (mo, da, yr) I I Year/Period of Report end of 2015/04 COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDIT(Sc)ntinued) Line No. Ref. Page No. (b) Title of Account (a) FERC FORM NO. 1 (rev. 12-03) Page 113 Current Year End of Quarter/Year Balance (c) Prior Year End Balance 12/31 (d) Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/Q4 FOOTNOTE DATA ~Ciuie Page: 112 Line No.: 3 Column: c Schedule No. 317 formula rate utilizes--the simple average-- balances (averages of beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes and ending balances) for all rate base fjiiiieiiiiTe Page: 112 !-lne No.: 16 Column: c Schedule No. 317 formula rate utilizes and ending balances) for all rate base the simple average balances (averages of beginning inputs. Schedule No. 322 formula rate utilizes and ending balances) for all rate base ~Schedule _~?_age: 11i- Line No.: 24 Column: c Schedule No. 317 formula rate utilizes and ending balances) for all rate base the simple average balances (averages of beginning the___slmple average balances (averages orbeginning inputs. ~-~J~Uts. the simple average balances (averages of beginning inputs. Schedule No. 322 formula rate utilizes the simple average balances (averages of beginning and ending balances L for all rate base inr:u~_s. )Schedule Pag_~;__ 112 Line No.: 63 Column:c Schedule No. 317 formula rate utilizes the simple average balances (averages of beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes and ending balances) for all rate base ~chedule Pag_e: 112 Line No.: 64 Column: c Schedule No. 317 formula rate utilizes and ending balances) for all rate base the simple average balances (averages of beginning inputs. -----] the simple average bai"ances (averages "(if- beginning inputs. Schedule No. 322 formula rate utilizes the simple average balances (averages of beginning and ending balances) for all rate base inputs. )FERC FORM NO.1 (ED.12-87l Page 450.1 BLANK PAGE (Next Page is 114) Date of Report (Mo, Da, Yr) of Respondent Florida Power & Light Company I I Yea End of 2015104 Quarterly 1. Report In column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the in column (k). Report In column {d) similar data for the previous year. This information is reported In the annual filing only. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. Report in column (g) the quarter to date amounts for electric utUity function; in column (i) the quarter to date amounts for gas utility, and in column (k) quarter to date amounts for other utility function for the current year quarter. Report In column (h) the quarter to date amounts for electric utility function; in column Q) the quarter to date amounts for gas utility, and in column (I) quarter to date amounts for other utility function for the prior year quarter. 5. If additional columns are needed, place them in a footnote. or Quarterly if applicable Do not report fourth quarter data In columns (e) and (f) 6. Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to others, In another utility columnin a similar manner to utility department. Spread the amount(s) over lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals. 7. Report amounts in account 414, Other Utility Operating Income, in the s;;~me manner as accounts 412 and 413 above. Total CurrentYearto Date Balance for Line No. FERC FORM NO. 1/3-Q (REV. 02-04) Page 114 I PriorYearto Date Balance for Current 3 Months Ended Quarterly Only No 4th Quarter (e) Florida Power & Light Company 9. Use page 122 for important notes regarding the statement of income for any account thereof. 10. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases. 11 Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas porches, and a summary of the adjustments made to balance sheet, income, and expense accounts. 12. If any notes appearing in the report to stokholders are applicable to the Statement of Income, such notes may be included at page 122. 13. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, Including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes. 14. Explain in a footnote if the previous year's/quarter's figures are different from that reported In prior reports. 15. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to schedule. FERC FORM NO.1 (ED. 12-96) Page 115 Name of Respondent This ~ort Is: (1) ~An Original (2) A Resubmission Florida Power & Light Company Date of Report (Mo, Da, Yr) I I Year/Period of Report End of 2015/04 STATEMENT OF INCOME FOR THE YEAR (continued) Llne TOTAL No. Title of Account (a) 27 28 29 30 (Ref.) Page No. Current Year (b) (c) Net Utility Operating Income (Carried forward from page 114) Other Income and Deductions Other lnoome Nonutllly Operating Income Previous Year d 2,032,n5, 123 Current 3 Months Ended Quarterly Only No 4th Quarter (e) Prior 3 Months Ended Quarterly Only No 4th Quarter (Q 1,918,360,048 ·--~--------- - ~ ~ - ~ . - . - - - . ,__ " - 31 Revenues From Merchandising, Jobbing and Contract Wori< (415) 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 (Less Costs and Exp. of Merchandising, Job. &eontractWor1<(416) Revenues From Nonutility Operations (417) (Less) Expenses of Nonutiftly Operations (417 .1) Nonoperating Rental income (418) Equity in Earnings of Subsidiary Companies (418.1) Interest and Dividend Income (419) Allowance for Other Funds Used During Construction (419.1) Miscellaneous Nonoperating Income (421) Gain on Disposition of Property (421.1) TOTAL Other Income (Enter Total of lines 31 thru 40) Other Income· Deductions Loss on Disposition of Property {421.2) Miscellaneous Amortization (425) Donations (426.1) Life Insurance (426.2 Penalties (426.3) Exp. for Certain Civic, Political & Related Activities (426.4) Other Deductions (426.5) TOTAL Other income Deductions (Total of lines 43 thru 49) Taxes Appllc. to Other Income and Deductions Taxes Other Than Income Taxes (408.2) Income Taxes-Federal (409.2) Income Taxes-Other (409.2) Provision for Deferred Inc. Taxes (410.2) (Less) Provision for Deferred Income Taxes-Cr. (411.2) Investment Tax Credit Adj.-Net (411.5) (Less) Investment Tax Credits (420) TOTAL Taxes on Other Income and Deductions (Total oflfnes 52-58) Net Other Income and Deductions (Total oflines 41, 50, 59) Interest Charges Interest on Long-Tenn Debt (427) Amort. of Debt Disc. and Expense (428) Amortization of Loss on Reaqulred Debt (428.1) (Less) Amort. of Premium on Debt-Credit (429) {Less) Amortization of Gain on Reaquired Debt-Credit (429.1) Interest on Debt to Assoc. Companies (430) Other Interest Expense (431) (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432) Net Interest Charges (Total of lines 62 thru 69) Income Before Extraordinary Items (Total of lines 27, 60 and 70) Extraordinary Items Extraordinary Income (434) (Less) Extraordinary Deductions (435) Net Extraordinary Items (Total of line 73Jess line 74) Income Taxes-Federal and Other (409.3) Extraordinary Items AIter Taxes (line 75 less line 76 Net Income (Total of line 71 and 77) FERC FORM NO. 1/3-Q (REV. 02-04) 119 72,529 29,028,613 62,470 22,587,401 67,807,740 17,172 693,352 74,703,514 35,770,043 -124,222 6,232 33,265,473 . - .. -·- r-·--~---····-~- L 262-263 262-263 262-263 234, 272-277 234, 272-277 ~ -- -- -~-~---~-~­ - 4,575,571 2,945,901 54,455 22,962,262 23,879,631 51,471,919 40,000 18,696,783 11,242,718 32,925,402 ~ - ~ - ~ ~- ~ - -~ --.----·~-.. ---~-· -~ 1,201,453 -7,834,542 -1,326,202 1,716,467 12,574,991 589,394 -3,998,893 -700,242 1,640,312 13,533,005 -18,817,815 42,049,410 -16,002,434 16,342,505 417,462,378 6,086,064 3,422,903 402,748,171 5,539,837 2,247,688 208,035 208,035 20,748,5n 20,598,152 426,913,735 1,647,910,798 21,675,934 14,370,114 417,633,481 1,517,069,072 .::::__~- -~~- -- - ~ 262-263 1,647,910,798 Page 117 "' --------._.-~-. ~--~------·----~ L __ -- 1,517,069,072 ""'--·- __ --~-~-. ~ ._...=.:--~~ ~-- - Name of Respondent Florida Power & Light Company This Report is: ( 1) XAn Original ·(2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/Q4 FOOTNOTE DATA [Schedule Page: 114 Line No.: 37____Column: c __ This account contains offsetting entries related to interest and divi-d~e-n-d,-l''n __ c_o_m_e__f~r-o-m----~ FPL's nuclear decommissioning and storm special use funds which are held at an FPL subsidiary (KPB) . These earnings which are recognized at the FPL subsidiary and reflected in Account 418.1 Equity in Earnings of Subsidiary Companies are offset in account 419, resulting in no net income impact to FPL. ~ule P_~!J!!: 114 Line No.: 37 Column: d ----------~ This account contains offsetting entries related to interest & dividend income from FPL's nuclear decommissioning and storm special use funds which are held at an FPL subsidiary (KPB) . These earnings which are recognized at the FPL subsidiary and reflected in Account 418.1 Equity in Earnings of Subsidiary Companies are offset in Account 419, resulting in no net income impact to FPL. IFERC FORM NO. 1 (ED. 12-87) Page 450.1 This ~art Is: (1) ~An Original (2) A Resubmlssion Name of Respondent Florida Power & Light Company Date of Report (Mo, Oa, Yr) Year/Period of Report End of 2015/04 I I STATEMENT OF RETAINED EAR INGS 1. Do not report Lines 49-53 on the quarterly version. 2. Report all changes in appropriated retained earnings, unappropriated retained earnings, year to date, and unappropriated undistributed subsidiary earnings for the year. 3. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436 - 439 inclusive). Show the contra primary account affected in column (b) 4. State the purpose and amount of each reservation or appropriation of retained earnings. 5. List first account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items in that order. 6. Show dividends for each class and series of capital stock. 7. Show separately the State and Federal income tax effect of items shown in account 439, Adjustments to Retained Earnings. 8. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. 9. If any notes appearing in the report to stockholders are applicable to this statement, include them on pages 122-123. Item Line No. (a) Contra Primary ccount Affected Current Quarter/Year Year to Date Balance Previous Quarter/Year Year to Date Balance (b) (c) (d) ---------~~-~--_~-~- UNAPPROPRIATED RETAINED EARNINGS (Account 216) Balance-Beginning of Period ----- 2 Changes -~- __ -_-- ------r------~ 3 Adjustments to Retained Earnings (Account 439) 4 5 6 7 8 9 TOTAL Credits to Retained Earnings (Acct. 439} 10 11 12 13 14 15 TOTAL Debits to Retained Earnings (Acct. 439) 16 Balance Transferred from Income (Account 433 less Account 418.1) 1,618,882,185 1,494,481,671 -700,000,000 ( 1,55{),000,000) -700,000,000 ( 1,550,000,000) 17 Appropriations of Retained Earnings (Acct. 436) 18 19 20 21 22 TOTAL Appropriations of Retained Earnings (Acct. 436) 23 Dividends Declared-Preferred Stock (Account 437) 24 25 26 27 28 29 TOTAL Dividends Declared-Preferred Stock {Acct. 437) 30 Dividends Declared-Common Stock (Account 438) 31 32 33 34 35 36 TOTAL Dividends Declared-Common Stock (Acct. 438} 37 Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings 38 Balance. End of Period (Total1 ,9, 15, 16,22,29,36,37) APPROPRIATE[) RETAI NED EARNINGS (Account 215) FERC FORM NO. 1/3-Q (REV. 02-04) Page 118 29,028,613 22,587.401 6,447,361,050 5,499,450,252 ~ort ~An Date of Report (Mo. Da, Yr) I I STATEMENT OF RETAINED EARNINGS This (1) (2) Name of Respondent Florida Power & Light Company Is: Original A Resubmission Year/Period of Report End of 2015/04 1. Do not report Lines 49-53 on the quarterly version. 2. Report all changes in appropriated retained earnings, unappropriated retained earnings, year to date, and unappropriated undistributed subsidiary earnings for the year. 3. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436 - 439 inclusive). Show the contra primary account affected in column (b) 4. State the purpose and amount of each reservation or appropriation of retained earnings. 5. List first account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items in that order. 6. Show dividends for each class and series of capital stock. 7. Show separately the State and Federal income tax effect of items shown in account 439, Adjustments to Retained Earnings. 8. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. 9. If any notes appearing in the report to stockholders are applicable to this statement, include them on pages 122-123. Line No. Contra Primary Account Affected (b) Item (a} Current QuarterNear Year to Date Balance (c) Previous QuarterNear Year to Date Balance (d) 39 40 41 42 43 44 45 TOTAL Appropriated Retained Earnings (Account 215) APPROP. RETAINED EARNINGS -AMORT. Reserve, Federal (Account 215.1) 46 TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1) 47 TOTAL Approp. Retained Earnings (Acct. 215, 215.1} (Total45,46) 48 TOTAL Retained Earnings (Acct. 215, 215.1, 216}(Total 38, 47) (216.1) UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly 49 Balance-Beginning of Year (Debit or Credit) 50 Equity in Earnings for Year (Credit) (Account418.1) 51 (Less} DMdends Received (Debit) 52 53 Balance-End of Year (Total lines 49 thru 52) FERC FORM NO. 1/3-Q (REV. 02-04) Page 119 - r--- ---- ---- --- . ---6,447,361,050 5,499,450,252 29,028,613 29,028,613 22,587,401 22,587,401 Florida Power & Light Company (1) Codes to be used:(a) Net Proceeds or Paymenls;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, Intangibles, etc. (2) Information about noncash Investing and financing activities must be provided In the Notes to the Financial statements. Also provide a reconciliation between "Cash aJid cash Equivalents at End of Period" with related amounts on the Balance Sheet (3) Operating Activities- Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to Investing and financing activities should be reported In those activttles. Show in the Noles to the Ananclais the amounts of interest paid (net of amount capitalized) and income taxes paid. (4} Investing Activities: Include at 01her Oine 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed In the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; Instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost. Line Description (See Instruction No. 1 for Explanation of Codes) No. FERC FORM NO. 1 (EO. 12-96) Page 120 Date of Report (Mo, Da, Yr) Florida Power & Light Company Year/Period of Report 2015104 End of I I (1) Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt (c) Include commercial paper; and (d) IdentifY separately such Items as investments, fixed assets, intangibles, etc. (2) Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet. (3) Operating Activities- Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to lnvestlng and financing activities should be reported In those activities. Show in the Notes to the Finandals the amounts of interest paid (net of amount capitalized} and income taxes paid. (4) Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed In the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; Instead provide a reconciliation of the dollar amount of leases capitall2:ed with the plant cost. Line No. Description (See Instruction No. 1 for Explanation of Codes) Quarter/Year -491 ,673,615 FERC FORM NO. 1 (ED. 1 Z-96) Page 121 QuarterlYear -300,000,000 This Report is: (1) ~An Original [(2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 FOOTNOTE DATA Schedule Page: 120 Line No.: 21 Column: b --------------------=---~--=--=·--:~~::~:-=-c··::::c:-'"] $ (Increase) Decrease in Other Current Assets Increase (Decrease) in Customers' Deposits (Increase) Decrease in Deferred Pension Cost Derivatives Activity Storm Related Costs and Amortization Nuclear Fuel Amortization Equity in Earnings of Subsidiary Companies Gain on sale of Non-utility property Disposition of analog meters Other Total (8,450,876) 11,578,017 (54,094,083) (145,912,263) 34,941,835 192,862,050 (29,028,613) (693,352) 94,338,017 (19,618,249) $ 75, 922,483 ~chedule Page: 12fJ____ ____b!I!~!!.C?.::.."_~~-----g_()IUmn: b -- -·--------supplemental Disclosure of Cash Flow Information: Cash Paid (Received) During the Period For: $ 443,125,146 $ 365,247,822 $ 73,811,203 Interest Federal Income Taxes State Income Taxes !§Cileiiiiie-f:iage:-120 Line No.: 36 Column: b s:-:-==-::-:::~=--=,-'?-Ol..:::.::__:_::;:.:::----,:~=.-:~'-'-=='=-~==-=-7'-'-=-=--- . ···-····-····--·····--·--Contributions to Special Ose Funds Spent Fuel Settlement Total $ (52, 671, 572) 1,742,935 $ (50,928,637) r::rs,-c-=-h-ed--=u-1=-e--:P=-a-g_e_:--=1:-::2-=-o--=-L-=-in_e_N=-=o-.-..--=3-=7,----=c,-o--=-lu_m ____-~_-:__-=-~!__-_-__-__ - - - - · · - ---·-· ····-·--· · - - - - - - - - - - - - - - - - - , Sale of Real Estate Reimbursement from Special Ose Funds Total $ $ ~chedule Page: 12_Q__I::![I~_!!C!~:_~_3_____c:;__o.Jumn: b Sale of Assets ..::..:::.:=-...::....:.::.____ _ _ _ _ _ _ _ _ _ _ _ ~ediiiePage: 120 Line No.: 90 ----···---------·- 34,678,945 2,104,618 36,783,563 $·-- ia;·789, 558 Column: b Reconciliation between "Cash and Cash-Equ1valents at End of Period" with related amounts on the Balance Sheet: $ 53,945,659 TOTAL BALANCE SHEET ACCOONTS $ 53,945,659 Accrued Property Additions $ 475,705,608 BALANCE SHEET ACCOUNTS: Cash (131) Special Deposits (132-134) Working Fund (135) IFERC FORM N0.1 (ED.12-87) $ 52,200,549 1,741,810 3,300 Page 450.1 Name of Respondent Florida Power & Light Company This Report Is: (1) ~ An Original (2) A Resubmission 0 Date of Report I I Year/Period of Report End of 2015/04 NOTES TO FINANCIAL STATEMENTS 1. Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement. 2. Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock. 3. For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Corm mission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof. 4. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts. 5. Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions. 6. If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein. 7. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted. 8. For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred. 9. Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein. PAGE 122 INTENTIONALLY LEFT BLANK SEE PAGE 123 FOR REQUIRED INFORMATION. FERC FORM NO. 1 (ED. 12-96) Page 122 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original I(2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) Introduction The accompanying financial statements were prepared in accordance with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases, which is a comprehensive basis of accounting that varies from generally accepted accounting principles in the United States of America (GAAP). These requirements differ from GAAP related to (1) the presentation of long-term debt, (2) the presentation of deferred income taxes, (3) the presentation of transactions as operating or non-operating income, (4) the presentation of long term portions of deferred fuel, (5) the presentation of current portions of regulatory assets and nabirlties, (6) the presentaflon of accruals assoc"rated with cost of removal included within accumulated depreciation reserve, (7) the presentation of storm costs including storm and property insurance reserve and corresponding regulatory asset, (8) the presentation of short-term and long-term derivatives included in the Form 10-Q, and (9) the presentation of activities at wholly-owned subsidiaries using the equity method of accounting. The Notes to the Financial Statements included herein are from the NextEra Energy, Inc. and subsidiaries Form 10-K for the yearly period ended December31, 2015, as filed with the Securities and Exchange Commission (SEC), and are prepared in conformity with GAAP. For SEC reporting, FPL's operations are presented on a consolidated basis, which includes the operation of FPL's subsidiaries, and differs from the financials presented herein, which have been prepared on a stand-alone basis. Due to the differences between FERC and SEC reporting requirements as mentioned above, certain footnotes may differ from FPL's Financial Statements contained herein. FPL's Form 10-K disclosures did not reference or disclose two additional items. The first was a change in accounting policy related to the Federal Energy Regulatory Commission's approval of Docket No. AC14-39-000, which allowed the Company to reflect a prospective change in its accounting method for the pre-capitalization of transformers. Based on this approval, FPL will treat distribution line transformers as inventory items and capitalize them at the time of installation rather than the time of purchase. FPL made this change during the twelve months ended December 31, 2014, which resulted in a one time pre-tax increase of approximately $14 million in operations & maintenance expenses to remove the capitalized installation costs associated with the transformers that were held in inventory at the time of the accounting change. The second item is that FPL has been authorized by the Florida Public Service Commission (FPSC) in Docket No. 15001-EI to enter into a joint venture agreement with PetroQuest, a publicly traded oil and natural gas company, to invest in natural gas production in Oklahoma's Woodford Shale region. In March 2015, FPL began this investment through a wholly owned subsidiary, GR Woodford Properties, LLC. These investments are reflected in the Investment in and Advances to Assoc. and Subsidiary Companies line on the Statement of Cash Flows for the year ended December 31, 2015, the Equity in Earnings of Subsidiary Companies line on the Statement of Income for the three months and year ended December 31, 2015, and the Investment in Subsidiary Companies line and Notes Receivable from Associated Companies line on the Comparative Balance Sheet as of December 31, 2015. Management has evaluated the impact of events occurring after December 31, 2015, up to February 19, 2016, the date Florida Power & Light Company's U.S. GMP financial statements were issued. These financial statements include all necessary adjustments and disclosures resulting from such evaluation. NEXTERA ENERGY, INC. AND FLORIDA POWER & LIGHT COMPANY NOTES TO CONSOLIDATED FINANCIAL STATEMENTS Years Ended December 31,2015, 2014 and 2013 1. Summary of Significant Accounting and Reporting Policies Basis of Presentation- The operations of NextEra Energy, Inc. (NEE) are conducted primarily through its wholly owned subsidiary Florida Power & Light Company (FPL) and its wholly owned indirect subsidiary NextEra Energy Resources, LLC (NEER). FPL, a rate-regulated electric utility, supplies electric service to approximately 4.8 million customer accounts throughout most of the east and lower west coasts of Florida. NEER invests in independent power projects through both controlled and consolidated entities and noncontrolling ownership interests in joint ventures essentially all of which are accounted for under the equity method. NEER also participates in natural gas, natural gas liquids and oil production through non-operating ownership interests and in pipeline infrastructure through either wholly owned subsidiaries or noncontrolling or joint venture interests. See Note 15 for a discussion of the movement of the natural gas pipeline projects to the NEER segment from Corporate and Other. The consolidated financial statements of NEE and FPL include the accounts of their respective majority-owned and controlled subsidiaries. Intercompany balances and transactions have been eliminated in consolidation. Amounts included in the consolidated financial statements and the accompanying Notes have been adjusted to reflect the retrospective application of a Financial Accounting Standards Board (FASB) accounting standard update related to the presentation of debt issuance costs in the financial statements. See Debt Issuance Costs below. In addition, certain amounts inCluded in prior years' consolidated financial statements have been reclassified to conform to the current year's presentation. The preparation of financial statements requires the use of estimates and IFERC FORM N0.1 {ED.12~88) Page 123.1 ~ Name of Respondent Florida Power & Ugh! Company This Report is: ( 1) ~An Original (2) A Resubmission Date of Report (Mo, Da, Yr) Year/Period of Report I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued} assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ from those estimates. NextEra Energy Partners, LP - NEE, through NEER, formed NextEra Energy Partners, LP (NEP) to acquire, manage and own contracted clean energy projects with stable, long-term cash flows through a limited partner interest in NextEra Energy Operating Partners, LP (NEP OpCo). On July 1, 2014, NEP closed its initial public offering (IPO) by .Issuing 18,687,500 common units representing limited partner interests. The proceeds from the sale of the common units, net of underwriting discounts, commissions and structuring fees, were approximately $438 million. NEP used such proceeds to purchase 18,687,500 common units of NEP OpCo, of which approximately $288 million was used to purchase common units from an indirect wholly owned subsidiary of NEE and $150 million was used to purchase common units from NEP OpCo. Through an indirect wholly owned subsidiary, NEE retained 74,440,000 units of NEP OpCo representing a 79.9% interest in NEP's operating projects. Additionally, NEE owns a controlling general partner interest In NEP and consolidates this entity for financial reporting purposes and presents NEP's limited partner interest as a noncontrolling interest in NEE's consolidated financial statements. Certain equity and asset transactions between NEP, NEER and NEP OpCo involve the exchange of cash, energy projects and ownership interests in NEP OpCo. These exchanges are accounted for under the profit sharing method and resulted in a profit sharing liability of approximately $447 million and $299 million at December 31, 2015 and 2014, respectively, which is reflected in noncurrent other liabilities on NEE's consolidated balance sheets. The profit sharing liability will be amortized into income on a straight-line basis over the estimated useful lives of the underlying energy projects held by NEP OpCo. During the purchase price adjustment period associated with the IPO, which is expected to extend into the fourth quarter of 2016, approximately $288 million of the profit sharing liability is subject to potential adjustment and will not be amortized. During 2015, NEP sold an additianal11,857,925common units and purchased an additional11,857,925 NEP OpCa common units. Also, in 2015, a subsidiary of NEE purchased 27,000,000 of NEP OpCo's common units. After giving effect to these transactions, NEE's interest in NEP's operating projects is approximately 76.8% as of December 31, 2015. As of December 31, 2015, NEP, through NEER's contribution of energy projects to NEP OpCo, owns a portfolio of 19 wind and solar projecls with generating capacity totaling approximately 2,210 megawatts (MW), as well as a portfolio of seven long-term contracted natural gas pipeline assets located in Texas. Rate Regulation - FPL is subject to rate regulation by the Florida Public Service Commission (FPSC) and the Federal Energy Regulatory Commission (FERC). Its rates are designed to recover the cost of providing electric service to its customers including a reasonable rate of return on invested capital. As a result of this cost-based regulation, FPL follows the accounting guidance that allows regulators to create assets and impose liabilities that would not be recorded by non-rate regulated entities. Regulatory assets and liabilities represent probable future revenues that will be recovered from or refunded to customers through the ratemaking process. Cost recovery clauses, which are designed to permit full recovery of certain costs and provide a return on certain assets allowed to be recovered through various dauses, include substantially all fuel, purchased power and interchange expense, certain construction-related costs for FPL's planned additional nuclear units at Turkey Point and FPL's solar generation facilities, and conservation and certain environmental-related costs. Revenues from cost recovery clauses are recorded when billed; FPL achieves matching of costs and related revenues by deferring the net underrecovery or overrecovery. Any underrecovered costs or overrecovered revenues are collected from or returned to customers in subsequent periods. In September 2015, FPL assumed ownership of a 250 MW coal-fired generation facility located in Jacksonville, Florida (Cedar Bay) and terminated its long-term purchased power agreement for substantially all of the facility's capacity and energy for a purchase price of approximately $521 million. The FPSC approved a stipulation and settlement between the State of Florida Office of Public Counsel and FPL regarding issues relating to the ratemaking treatment for Cedar Bay. Key elements of the settlement included, among other things, the following: • FPL will recover the purchase price and associated income tax gross-up as a regulatory asset which will be amortized over approximately nine years. Approximately $709 million will be recovered through the capacity clause with a return an the portion of the unamortized balance associated with the purchase price and $138 million will be recovered through base rates until FPL's next test year for a general base rate proceeding, at which time the unamortized balance will be transferred to the capacity clause for continued recovery until fully amortized. At December 31, 2015, the regulatory assets, net of amortization, totaled approximately $817 million and are included in purchased power agreement termination and current other regulatory assets on NEE's and FPL's consolidated balance sheets. The reserve amount that is available for amortization under the 2012 rate agreement, which is effective through December 2016, was reduced by $30 million to $370 million, unless FPL needs the entire $400 million reserve to maintain a minimum regulatory ROE of 9.50%. See Revenues and Rates - FPL Rates Effective January 2013 through December 2016 below. In October 2015, the Florida Industrial Power Users Group tiled a notice of appeal challenging the FPSC's approval of this settlement, which is pending before the Florida Supreme Court. IFERC FORM NO. 1 (ED. 12-88) Page 123.2 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original I (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) J I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) If FPL were no longer subject to cost-based rate regulation, the existing regulatory assets and liabilities would be written off unless regulators specify an alternative means of recovery or refund. In addition, the FPSC has the authority to disallow recovery of costs that it considers excessive or imprudently incurred. The continued applicability of regulatory accounting is assessed at each reporting period. Revenues and Rates- FPL's retail and wholesale utility rate schedules are approved by the FPSC and the FERC, respectively. FPL records unbilled base revenues for the estimated amount of energy delivered to customers but not yet billed. FPL's unbilled base revenues are included in customer receivables on NEE's and FPL's consolidated balance sheets and amounted to approximately $246 million and $223 million at December 31, 2015 and 2014, respectively. FPL's operating revenues also include amounts resulting from cost recovery clauses (see Rate Regulation above), franchise fees, gross receipts taxes and surcharges related to storm-recovery bonds (see Note 9 - FPL). Franchise fees and gross receipts taxes are imposed on FPL; however, the FPSC allows FPL to include in the amounts charged to customers the amount of the gross receipts tax for all customers and the franchise amount for those customers located in the jurisdiction that imposes the fee. Accordingly, franchise fees and gross receipts taxes are reported gross in operating revenues and taxes other than income taxes and other in NEE's and FPL's consolidated statements of income and were approximately $722 million, $716 million and $680 million in 2015, 2014 and 2013, respectively. The revenues from the surcharges related to storm-recovery bonds included in operating revenues in NEE's and FPL's consolidated statements of income were approximately $115 million, $109 million and $108 million in 2015, 2014 and 2013, respectively. FPL also collects municipal utility taxes which are reported gross in customer receivables and accounts payable on NEE's and FPL's consolidated balance sheets. FPL Rates Effective January 2013 through December 2016- In January 2013, the FPSC issued a final order approving a stipulation and settlement between FPL and several intervenors in FPL's base rate proceeding (2012 rate agreement). Key elements of the 2012 rate agreement, which is effective from January 2013 through December 2016, include, among other things, the following: • • • • • • New retail base rates and charges were established in January 2013 resulting in an increase in retail base revenues of $350 million on an annualized basis. FPL's allowed regulatory return on common equity (ROE) is 10.50%, with a range of plus or minus 100 basis points. If FPL's earned regulatory ROE falls below 9.50%, FPL may seek retail base rate relief. If the earned regulatory ROE rises above 11.50%, any party to the 2012 rate agreement other than FPL may seek a review of FPL's retail base rates. Retail base rates will be increased by the annualized base revenue requirements for FPL's three modernization projects (Cape Canaveral, Riviera Beach and Port Everglades) as each of the modernized power plants becomes operational. (Cape Canaveral and Riviera Beach became operational in April 2013 and April 2014, respectively, and Port Everglades is expected to be operational by April2016.) Cost recovery of FPL's West County Energy Center (WCEC) Unit No.3 will continue to occur through the capacity cost recovery clause (capacity clause) (reported as retail base revenues). Subject to certain conditions, FPL may amortize, over the term of the 2012 rate agreement, a depreciation reserve surplus remaining at the end of 2012 under a previous rate agreement (approximately $224 million) and may amortize a portion of FPL's fossil dismantlement reserve up to a maximum of $176 million (collectively, the reserve), provided that in any year of the 2012 rate agreement, FPL must amortize at least enough reserve to maintain a 9.50% earned regulatory ROE but may not amortize any reserve that would result in an earned regulatory ROE in excess of 11.50%. See Rate Regulation above regarding a subsequent reduction in the reserve amount. Future storm restoration costs would be recoverable on an interim basis beginning 60 days from the filing of a cost recovery petition, but capped at an amount that could produce a surcharge of no more than $4 for every 1,000 kilowatt~hours (kWh) of usage on residential bills during the first 12 months of cost recovery. Any additional costs would be eligible for recovery in subsequent years. If storm restoration costs exceed $800 million in any given calendar year, FPL may request an increase to the $4 surcharge to recover the amount above $800 million. An incentive mechanism whereby customers will receive 100% of certain gains, including but not limited to, gains from the purchase and sale of electricity and natural gas (including transportation and storage), up to a specified threshold. The gains exceeding that specified threshold will be shared by FPL and its customers. 2016 Base Rate Proceeding- In January 2016, FPL filed a formal notification with the FPSC indicating its intent to initiate a base rate proceeding, consisting of a four-year rate plan that would begin in January 2017 following the expiration of the 2012 rate agreement at the end of 2016. The notification stated that, based on preliminary estimates, FPL expects to request an increase to base annual revenue requirements of (i) approximately $860 million effective January 2017, (ii) approximately $265 million effective January 2018, and (iii) approximately $200 million effective when the proposed natural gas-fired combined-cycle unit in Okeechobee County, Florida becomes operational, which is expected to occur in mid-2019 assuming it receives approval by the Siting Board (comprised of the governor and cabinet) under the Florida Electrical Power Plant Siting Acl Under the proposed rate plan, FPL commits that if its requested adjustments to base annual revenue requirements are approved, it will not request further adjustments for 2020. In addition, FPL expects to propose an allowed regulatory return on common equity midpoint of 11.50%, which includes a 50 basis point performance adder. FPL expects to file its formal request to initiate a base rate proceeding in March 2016. IFERC FORM NO. 1 (ED. 12-88) Page 123.3 Name of Respondent Florida Power & Light Company This Report is: {1) ~An Original !{2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/Q4 NOTES TO FINANCIAL STATEMENTS (Continued) NEER's revenue is recorded on the basis of commodities delivered, contracts settled or services rendered and includes estimated amounts yet to be billed to customers. Certain commodity contracts for the purchase and sale of power that meet the definition of a derivative are recorded at fair value with subsequent changes in fair value recognized as revenue. See Energy Trading below and Note 3. In May 2014, the FASB issued a new accounting standard which provides guidance on the recognition of revenue from contracts with customers and requires additional disclosures about the nature, amount, timing and uncertainty of revenue and cash flows from an entity's contracts with customers. The standard will be effective for NEE and FPL beginning January 1, 2018 and may be applied retrospectively to each prior period presented or retrospectively with the cumulative effect recognized as of the date of initial application. NEE and FPL are currently evaluating the effect the adoption of this standard will have, if any, on their consolidated financial statements. Electric Plant, Depreciation and Amortization- The cost of additions to units of property of FPL and NEER is added to electric plant in service. In accordance with regulatory accounting, the cost of FPL's units of utility property retired, less estimated net salvage value, is charged to accumulated depreciation. Maintenance and repairs of property as well as replacements and renewals of items determined to be less than units of utility property are charged to other operations and maintenance (O&M} expenses. At December 31, 2015, the electric generation, transmission, distribution and general facilities of FPL represented approximately 50%, 11%, 33% and 6%, respectively, of FPL's gross investment in electric utility plant in service and other property. Substantially all of FPL's properties are subject to the lien of FPL's mortgage, which secures most debt securities issued by FPL. A number of NEER's generation and pipeline facilities are encumbered by liens securing various financings. The net book value of NEER's assets serving as collateral was approximately $13.9 billion at December 31, 2015. The American Recovery and Reinvestment Act of 2009, as amended (Recovery Act), provided for an option to elect a cash grant (convertible investment tax credits (ITCs)) for certain renewable energy property (renewable property). Convertible ITCs are recorded as a reduction in property, plant and equipment on NEE's and FPL's consolidated balance sheets and are amortized as a reduction to depreciation and amortization expense over the estimated life of the related property. At December 31, 2015 and 2014, convertible ITCs, net of amortization, were approximately $1.8 billion ($153 million at FPL) and $1.6 billion ($159 million at FPL). At December31, 2015 and 2014, approximately $207 million and $1 million, respectively, of such convertible ITCs are included in other receivables on NEE's consolidated balance sheets. Depreciation of FPL's electric property is primarily provided on a straight-line average remaining life basis. FPL includes in depreciation expense a provision for fossil and solar plant dismantlement, interim asset removal costs, accretion related to asset retirement obligations (see Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs below), stonm recovery amortization and amortization of pre-construction costs associated with planned nuclear units recovered through a cost recovery dause. For substantially all of FPL's property, depreciation studies are typically performed and filed with the FPSC at least every four years. As part of a previous rate agreement, the FPSC approved new depreciation rates whidl became effective January 1, 2010. In accordance with the 2012 rate agreement, FPL is not required to file depreciation studies during the effective period of the agreement and the previously approved depreciation rates remain in effect. As discussed in Revenues and Rates above, the use of reserve amortization is permitted under the 2012 rate agreement. FPL files a twelve-month forecast with the FPSC each year which cpntains a regulatory ROE intended to be earned based on the best information FPL has at that time assuming normal weather. This forecast establishes a fixed targeted regulatory ROE. In order to earn the targeted regulatory ROE in each reporting period under the 2012 rate agreement, reserve amortization is calculated using a trailing thirteen-month ;;~verage of retail rate base and capital structure in conjunction with the trailing twelve months regulatory retail base net operating income, which primarily includes the retail base portion of base and other revenues net of O&M, depreciation and amortization, interest and tax expenses. In general, the net impact of these income statement line items is adjusted, in part, by reserve amortization or its reversal to earn the targeted regulatory ROE. In accordance with the 2012 rate agreement, FPL recorded approximately $(15} million, $(33) million and $155 million of reserve (reversal) amortization in 2015, 2014 and 2013, respectively. The reserve is amortized as a reduction of (or reversed as an increase to) regulatory liabilities - accrued asset removal costs on NEE's and FPL's consolidated balance sheets. The weighted annual composite depreciation and amortization rate for FPL's electric utility plant in service, including capitalized software, but excluding the effects of decommissioning, dismantlement and the depreciation adjustments discussed above, was approximately 3.3%, 3.3% and 3.4% for 2015,2014 and 2013, respectively. NEER's electric plant in service less salvage value, if any, are depreciated primarily using the straight-line method over their estimated useful lives. At December 31, 2015 and 2014, wind, nuclear, natural gas and solar plants represented approximately 62% and 63%, 11% and 12%, 3% and 8%, and 9% and 7%, respectively, of NEER's depreciable electric plant in service and other property. The estimated useful lives of NEER's plants range primarily from 25 to 30 years for wind, natural gas and solar plants and from 25 to 47 years for nuclear plants. NEER reviews the estimated useful lives of its fixed assets on an ongoing basis. NEER's oil and gas production assets, representing approximately 7% and 6%, respectively, of NEER's depreciable electric plant in service and other property at December 31, 2015 and 2014, are accounted for under the successful efforts method. Depletion expenses for the acquisition of reserve rights and development costs are recognized using the unit of production method. Nuclear Fuel- FPL and NEER have several contracts for the supply of uranium, conversion, enrichment and fabrication of nuclear fuel. jFERC FORM N0.1 {ED. 12-88) Page 123.4 I Name of Respondent Florida Power & Light Company This Report is: (1} X An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 NOTES TO FINANCIAL STATEMENTS {Continued) See Note 14 - Contracts. FPL's and NEER's nuclear fuel costs are charged to fuel expense on a unit of production method. Construction Activity- Allowance for funds used during construction (AFUDC) is a non-cash item which represents the allowed cost of capital, including an ROE, used to finance FPL construction projects. The portion of AFUDC attributable to borrowed funds is recorded as a reduction of interest expense and the remainder is recorded as other income. FPSC rules limit the recording of AFUDC to projects that have an estimated cost in excess of 0.5% of a utility's plant in service balance and require more than one year to complete. FPSC rules allow construction projects below the 0.5% threshold as a component of rate base. During 2015, 2014 and 2013, FPL capitalized AFUDC at a rate of 6.34%, 6.34% and 6.52%, respectively, which amounted to approximately $88 million, $50 million and $81 million, respectively. See Note 14- Commitments. FPL's construction work in progress includes construction materials, progress payments on major equipment contracts, engineering costs, AFUDC and other costs directly associated with the construction of various projects. Upon completion of the projects, these costs are transferred to electric utility plant in service and other property. Capitalized costs associated with construction activities are charged to O&M expenses when recoverability is no longer probable. See Rate Regulation above for information on recovery of costs associated with new nuclear capacity and solar generation facilities. NEER capitalizes project development costs once it is probable that such costs will be realized through the ultimate construction of a power plant or sale of development rights. At December 31, 2015 and 2014, NEER's capitalized development costs totaled approximately $133 million and $122 million, respectively, which are included in noncurrent other assets on NEE's consolidated balance sheets. These costs include land rights and other third-party costs directly associated with the development of a new project. Upon commencement of construction, these costs either are transferred to construction work in progress or remain in other assets, depending upon the nature of the cost. Capitalized development costs are charged to O&M expenses when it is no longer probable that these costs will be realized. NEER's construction work in progress includes construction materials, progress payments on major equipment contracts, third-party engineering costs, capitalized interest and other costs directly associated with the construction and development of various projects. Interest capitalized on construction projects amounted to approximately $100 million, $104 million and $109 million during 2015, 2014 and 2013, respectively. Interest expense allocated from NextEra Energy Capital Holdings, Inc. (NEECH) to NEER is based on a deemed capital structure of 70% debt. Upon commencement of plant operation, costs associated with construction work in progress are transferred to electric plant in service and other property. Asset Retirement Obligations - NEE and FPL each account for asset retirement obligations and conditional asset retirement obligations (collectively, AROs) under accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated, with the offsetting associated asset retirement costs capitalized as part of the carrying amount of the long-lived assets. The asset retirement cost is subsequently allocated to expense, for NEE's non-rate regulated operations, and regulatory liability, for FPL, using a systematic and rational method over the asset's estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense, which is included in depreciation and amortization expense in the consolidated statements of income for NEE's non-rate regulated operations, and ARO and regulatory liability, in the case of FPL. Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost, or income when asset retirement cost is depleted, in the case of NEE's non-rate regulated operations, and ARO and regulatory liability; in the case of FPL. See Decommissioning of Nuclear Plants, Dismantlement of Plants and· Other Accrued Asset Removal Costs below and Note 13. Decommissioning of Nuclear Plants, Dismantlement of Plants and Other Accrued Asset Removal Costs - For ratemaking purposes, FPL accrues for the cost of end of life retirement and disposal of its nuclear, fossil and solar plants over the expected service life of each unit based on nuclear decommissioning and fossil and solar dismantlement studies periodically filed with the FPSC. In addition, FPL accrues for interim removal costs over the life of the related assets based on depreciation studies approved by the FPSC. As approved by the FPSC, FPL previously suspended its annual decommissioning accrual. For financial reporting purposes, FPL recognizes decommissioning and dismantlement liabilities in accordance with accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred. Any differences between expense recognized for financial reporting purposes and the amount recovered through rates are reported as a regulatory liability in accordance with regulatory accounting. See Revenues and Rates, Electric Plant, Depreciation and Amortization, Asset Retirement Obligations above and Note 13. Nuclear decommissioning studies are performed at least every five years and are submitted to the FPSC for approval. FPL filed updated nuclear decommissioning studies with the FPSC in December 2015. These studies reflect FPL's current plans, under the operating licenses, for prompt dismantlement of Turkey Point Units Nos. 3 and 4 following the end of plant operation with decommissioning activities commencing in 2032 and 2033, respectively, and provide for St. Lucie Unit No. 1 to be mothballed beginning in 2036 with decommissioning activities to be integrated with the prompt dismantlement of St. Lucie Unit No. 2 in 2043. IFERC FORM NO. 1 {ED. 12-88) Page 123.5 Name of Respondent Florida Power & Light Company This Report is: (1) 2S, An Original (2) A Resubmission Date of Report Year/Period of Report {Mo, Da, Yr) I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) These studies also assume that FPL will be storing spent fuel on site pending removal to a United States (U.S.) government facility. The studies indicate FPL's portion of the ultimate costs of decommissioning its four nuclear units, including costs associated wlth spent fuel storage above what is expected to be refunded by the U.S. Department of Energy (DOE) under a spent fuel settlement agreement, to be approximately $7.5 billion, or $2.9 billion expressed in 2015 dollars. Restricted funds for the payment of future expenditures to decommission FPL's nuclear units are included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's and FPL's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily classified as available for sale and carried at fair value. See Note 4. FPL does not currently make contributions to the decommissioning funds, other than the reinvestment of dividends and interest. Fund earnings, consisting of dividends, interest and realized gains and losses, as well as any changes in unrealized gains and losses are not recognized in income and are reflected as a corresponding offset in the related regulatory liability accounts. During 2015, 2014 and 2013 fund earnings on decommissioning funds were approximately $96 million, $91 million and $167 million, respectively. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. Fossil and solar plant dismantlement studies are typically performed at least every four years and are submitted to the FPSC for approval. FPL's latest fossil and solar plant dismantlement studies became effective January 1, 2010 and resulted in an annual expense of $18 million which is recorded in depreciation and amortization expense in NEE's and FPL's consolidated statements of income. At December 31 , 2015, FPL's portion of the ultimate cost to dismantle its fossil and solar units is approximately $752 million, or $411 million expressed in 2015 dollars. In accordance with the 2012 rate agreement, FPL is not required to file fossil and solar dismantlement studies during the effective period of the agreement. NEER records nuclear decommissioning liabilities for Seabrook Station (Seabrook), Duane Arnold Energy Center (Duane Arnold) and Point Beach Nudear Power Plant (Point Beach} in accordance with accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred. The liability is being accreted using the interest method through the date decommissioning activities are expected to be complete. See Note 13. At December 31, 2015 and 2014, NEER's ARO related to nuclear decommissioning was approximately $423 million and $462 million, respectively, and was detenmined using various internal and external data and applying a probability percentage to a variety of scenarios regarding the life of the plant and timing of decommissioning. NEER's portion of the ultimate cost of decommissioning its nuclear plants, including costs associated with spent fuel storage above what is expected to be refunded by the DOE under a spent fuel settlement agreement, is estimated to be approximately $11.8 billion, or $1.9 billion expressed in 2015 dollars. Seabrook files a comprehensive nuclear decommissioning study with the New Hampshire Nuclear Decommissioning Financing Committee (NDFC) every four years; the most recent study was filed in 2015. Seabrook's decommissioning funding plan is also subject to annual review by the NDFC. Currently, there are no ongoing decommissioning funding requirements for Seabrook, Duane Arnold and Point Beach, however, the U.S. Nuclear Regulatory Commission (NRC), and in the case of Seabrook, the NDFC, has the authority to require additional funding in the future. NEER's portion of Seabrook's, Duane Arnold's and Point Beach's restricted funds for the payment of future expenditures to decommission these plants is included in nuclear decommissioning reserve funds, which are included in special use funds on NEE's consolidated balance sheets. Marketable securities held in the decommissioning funds are primarily classified as available for sale and carried at fair value. Market adjustments result in a corresponding adjustment to other comprehensive income (OCI), except for unrealized losses associated with marketable securities considered to be other than temporary, including any credit losses, which are recognized as other than temporary impairment losses on securities held in nuclear decommissioning funds in NEE's consolidated statements of income. Fund earnings are recognized in income and are reinvested in the funds. See Note 4. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. Major Maintenance Costs - FPL recognizes costs associated with planned major nuclear maintenance in accordance with regulatory treatment and records the related accrual as a regulatory liability. FPL expenses costs associated with planned fossil maintenance as incurred. FPL's estimated nuclear maintenance costs for each nuclear unit's next planned outage are accrued over the period from the end of the last outage to the end of the next planned outage. Any difference between the estimated and actual costs is included in O&M expenses when known. The accrued liability for nuclear maintenance costs at December 31, 2015 and 2014 totaled approximately $48 million and $50 million, respectively, and is included in regulatory liabilities- other on NEE's and FPL's consolidated balance sheets. For the years ended December 31, 2015, 2014 and 2013, FPL recognized approximately $90 million, $76 million and $92 million, respectively, in nuclear maintenance costs which are primarily included in O&M expenses in NEE's and FPL's consolidated statements of income. NEER uses the deferral method to account for certain planned major maintenance costs. NEER's major maintenance costs for its nuclear generation units and combustion turbines are capitalized and amortized on a unit of production method over the period from the end of the last outage to the beginning of the next planned outage. NEER's capitalized major maintenance costs, net of accumulated amortization, totaled approximately $97 million and $141 million at December 31, 2015 and 2014, respectively, and are included in noncurrent other assets on NEE's consolidated balance sheets. For the years ended December 31, 2015, 2014 and 2013, NEER amortized approximately $79 million, $81 million and $93 million in major maintenance costs which are included in O&M lFERC FORM N0.1 {EO. 12-88) Page 123.6 This Report is: {1) ~An Original (2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued expenses in NEE's consolidated statements of income. Cash Equivalents- Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less. Restricted Cash- At December 31, 2015 and 2014, NEE had approximately $244 million ($75 million for FPL) and $228 million ($38 million for FPL), respectively, of restricted cash included in other current assets on NEE's and FPL's consolidated balance sheets, which was primarily related to margin cash collateral requirements, debt service payments and bond proceeds held for construction at FPL. Where offsetting positions exist, restricted cash related to margin cash collateral is netted against derivative instruments. See Note 3. Allowance for Doubtful Accounts - FPL maintains an accumulated provision for uncollectible customer accounts receivable that is estimated using a percentage, derived from historical revenue and write-off trends, of the previous five months of revenue. Additional amounts are included in the provision to address specific items that are not considered in the calculation described above. NEER regularly reviews collectibility of its receivables and establishes a provision for losses estimated as a percentage of accounts receivable based on the historical bad debt write-off trends for its retail electricity provider operations and, when necessary, using the specific identification method for all other receivables. Inventory- FPL values materials, supplies and fossil fuel inventory using a weighted-average cost method. NEER's materials, supplies and fossil fuel inventories are carried at the lower of weighted-average cost or market, unless evidence indicates that the weighted-average cost (even if in excess of market) will be recovered with a normal profit upon sale in the ordinary course of business. Energy Trading - NEE provides full energy and capacity requirements services primarily to distribution utilities, which include load-following services and various ancillary services, in certain markets and engages in power and gas marketing and trading activities to optimize the value of electricity and fuel contracts, generation facilities and gas infrastructure assets, as well as to take advantage of projected favorable commodity price movements. Trading contracts that meet the definition of a derivative are accounted for at fair value and realized gains and losses from all trading contracts, including those where physical delivery is required, are recorded net for all periods presented. See Note 3. Securitized Storm-Recovery Costs, Storm Fund and Storm Reserve - In connection with the 2007 storm-recovery bond financing (see Note 9 - FPL), the net proceeds to FPL from the sale of the storm-recovery property were used primarily to reimburse FPL for its estimated net of tax deficiency in its storm and property insurance reserve (storm reserve) and provide for a storm and property insurance reserve fund (storm fund). Upon the issuance of the storm-recovery bonds, the storm reserve deficiency was reclassified to securitized storm-recovery costs and is recorded as a regulatory asset on NEE's and FPL's consolidated balance sheets. As storm-recovery charges are billed to customers, the securitized storm-recovery costs are amortized and included in depreciation and amortization expense in NEE's and FPL's consolidated statements of income. Marketable securities held in the storm fund are classified as available for sale and are carried at fair value with market adjustments, including any other than temporary impairment losses, resulting in a corresponding adjustment to the storm reserve. Fund earnings, net of taxes, are reinvested in the fund. The tax effects of amounts not yet recognized for tax purposes are included in deferred income taxes. The storm fund is included in special use funds on NEE's and FPL's consolidated balance sheets and was approximately $74 million and $75 million at December 31, 2015 and 2014, respectively. See Note 4. The storm reserve that was reestablished in an FPSC financing order related to the issuance of the storm-recovery bonds was not initially reflected on NEE's and FPL's consolidated balance sheets because the associated regulatory asset did not meet the specific recognition criteria under the accounting guidance for certain regulated entities. As a result, the storm reserve will be recognized as a regulatory liability as the storm-recovery charges are billed to customers and charged to depreciation and amortization expense in NEE's and FPL's consolidated statements of income. Furthermore, the storm reserve will be reduced as storm costs are reimbursed. As of December 31, 2015, FPL had the capacity to absorb up to approximately $119 million in future prudently incurred storm restoration costs without seeking recovery through a rate adjustment from the FPSC or filing a petition with the FPSC. Impairment of Long-Uved Assets- NEE evaluates long-lived assets for impairment when events or changes in circumstances Indicate that the carrying amount may not be recoverable. An impairment loss is required to be recognized if the carrying value of the asset exceeds the undiscounted future net cash flows associated with that asset. The impairment loss to be recognized is the amount by which the carrying value of the long-lived asset exceeds the asset's fair value. In most instances, the fair value is determined by discounting estimated future cash flows using an appropriate interest rate. See Note 4 - Nonrecurring Fair Value Measurements. IFERC FORM N0.1 (ED. 12-88) Page 123.7 Name of Respondent Florida Power & Light Company This Report is: (1) X An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr} 2015/04 I I NOTES TO FINANCIAL STATEMENTS (Continued) Goodwill and Other Intangible Assets - NEE's goodwill and other intangible assets are as follows: WeightedAverage UsefUl Lives December 31, 2015 2014 NEE's goodwill relates to various acquisitions which were accounted for using the purchase method of accounting. Other intangible assets subject to amortization are amortized, primarily on a straight-line basis, over their estimated useful lives. For the years ended December 31, 2015, 2014 and 2013, amortization expense was approximately $17 million, $15 million and $13 million, respectively, and is expected to be approximately $38 million, $37 million, $36 million, $35 million and $35 million for 2016, 2017, 2018, 2019 and 2020, respectively. Goodwill and other intangible assets are included in noncurrent other assets on NEE's consolidated balance sheets. Goodwill and other intangible assets not subject to amortization are assessed for impairment at least annually by applying a fair value-based analysis. Other intangible assets subject to amortization are periodically reviewed when impairment indicators are present to assess recoverability from future operations using undiscounted future cash flows. Debt Issuance Costs - Effective December 31, 2015, NEE and FPL retrospectively adopted an accounting standard update which changed the presentation of debt issuance costs in the consolidated financial statements. This standard update requires that debt issuance costs be presented on the balance sheet as a direct deduction from the carrying amount of the related debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs was not affected by this standard update. Upon adoption, NEE reclassified debt issuance costs of $324 million ($85 million for FPL) as of December 31, 2014 from noncurrent other assets to long-term debt Pension Plan - NEE allocates net periodic pension income to its subsidiaries based on the pensionable earnings of the subsidiaries' employees. Accounting guidance requires recognition of the funded status of the pension plan in the balance sheet, with changes in the funded status recognized in other comprehensive income within shareholders' equity in the year in which the changes occur. Since NEE is the plan sponsor, and its subsidiaries do not have separate rights to the plan assets or direct obligations to their employees, this accounting guidance is reflected at NEE and not allocated to the subsidiaries. The portion of previously unrecognized actuarial gains and losses and prior service costs or credits that are estimated to be allocable to FPL as net periodic (income) cost in future periods and that otherwise would be recorded in accumulated other comprehensive income {AOCI) are classified as regulatory assets and liabilities at NEE in accordance with regulatory treatment. lFERC FORM NO.1 (ED. 12-88) Page 123.8 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original I(2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) Stock-Based Compensation - NEE accounts for stock-based payment transactions based on grant-date fair value. Compensation costs for awards with graded vesting are recognized on a straight-line basis over the requisite service period for the entire award. See Note 11 - Stock-Based Compensation. Income Taxes- Deferred income taxes are recognized on all significant temporary differences between the financial statement and tax bases of assets and liabilities. In connection with the tax sharing agreement between NEE and its subsidiaries, the income tax provision at each subsidiary reflects the use of the "separate return method," except that tax benefits that could not be used on a separate return basis, but are used on the consolidated tax return, are recorded by the subsidiary that generated the tax benefits. Any remaining consolidated income tax benefits or expenses are recorded at the corporate level. Included in other regulatory assets and other regulatory liabilities on NEE's and FPL's consolidated balance sheets is the revenue equivalent of the difference in deferred income taxes computed under accounting rules, as compared to regulatory accounting rules. The net regulatory asset totaled $283 million ($268 million for FPL) and $250 million ($236 million for FPL) at December 31, 2015 and 2014, respectively, and is being amortized in accordance with the regulatory treatment over the estimated fives of the assets or liabilities for which the deferred tax amount was initially recognized. NEER recognizes ITCs as a reduction to income tax expense when the related energy property is placed into service. Production tax credits {PTCs) are recognized as wind energy Is generated and sold based on a per kWh rate prescribed in applicable federal and state statutes and are recorded as a reduction of current income taxes payable, unless limited by tax law in which instance they are recorded as deferred tax assets. NEE and FPL record a deferred income tax benefit created by the convertible ITCs on the difference between the financial statement and tax bases of renewable property. For NEER, this deferred income tax benefit is recorded in income tax expense in the year that the renewable property is placed in service. For FPL, this deferred income tax benefit is offset by a regulatory liability, which is amortized as a reduction of depreciation expense over the approximate lives of the related renewable property in accordance with the regulatory treatment. At December 31, 2015 and 2014, the net deferred income tax benefits associated with FPL's convertible ITCs were approximately $48 million and $50 million, respectively, and are included in other regulatory assets and regulatory liabilities on NEE's and FPL's consolidated balance sheets. A valuation allowance is recorded to reduce the carrying amounts of deferred tax assets when it is more likely than not that such assets will not be realized. NEE recognizes interest income (expense) related to unrecognized tax benefits (liabilities) in interest income and interest expense, respectively, net of the amount deferred at FPL At FPl,., the offset to accrued interest receivable (payable) on income taxes is classified as a regulatory liability (regulatory asset) which will be amortized to income (expense) over a five-year period upon settlement in accordance with regulatory treatment. All tax positions taken by NEE in its income tax returns that are recognized in the financial statements must satisfy a more-likely-than-not threshold. See Note 5. In November 2015, the FASB issued an accounting standard update which simplifies the classification of deferred taxes by eliminating the requirement to separate deferred tax assets and liabilities between current and noncurrent amounts, and instead requires deferred taxes to be presented as noncurrent on the balance sheet. NEE and FPL decided to early adopt this standard update effective for the year ended December 31, 2015, and to apply it prospectively. Sale of Differential Membership Interests - Certain subsidiaries of NEER sold their Class B membership interest in entities that have ownership interests in wind facilities, with generating capacity totaling approximately 5,272 MW at December 31, 2015, to third-party investors. In exchange for the cash received, the holders of the Class B membership interests will receive a portion of the economic attributes of the facilities, including income tax attributes, for variable periods. The transactions are not treated as a sale under the accounting rules and the proceeds received are deferred and recorded as a liability in deferral related to differential membership ·Interests - VIEs on NEE's consolidated balance sheets. The deferred amount is being recognized in benefits associated with differential membership interests - net in NEE's consolidated statements of income as the Class B members receive their portion ofthe economic attributes. NEE continues to operate and manage the wind facilities, and consolidates the entities that own the wind facilities. Variable Interest Entities (VIEs) -An entity is considered to be a VIE when its total equity investment at risk is not sufficient to permit the entity to finance its activities without additional subordinated financial support, or its equity investors, as a group, lack the characteristics of liaving a controlling financial interest. A reporting company is required to consolidate a VIE as its primary beneficiary when it has both the power to direct the activities of the VIE that most significantly impact the VIE's economic performance, and the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. NEE and FPL evaluate whether an entity is a VIE whenever reconsideration events as defined by the accounting guidance occur. See Note 9. IFERC FORM N0.1 (ED. 12-88) Page 123.9 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original •(2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 NOTES TO FINANCIAL STATEMENTS {Continued) In February 2015, the FASB issued an accounting standard update that will modify current consolidation guidance. The standard makes changes to both the variable interest entity model and the voting interest entity model, including modifying the evaluation of whether limited partnerships or similar legal entities are VIEs or voting interest entities and amending the guidance for assessing how relationships of related parties affect the consolidation analysis of VIEs. The standard is effective for NEE and FPL beginning January 1, 2016. NEE and FPL continue to evaluate the effect the adoption of this standard will have on their consolidated financial statements. Proposed Merger- In 2014, NEE and Hawaiian Electric Industries, Inc. (HEI) entered into an Agreement and Plan of Merger (the merger agreement) pursuant to which Hawaiian Electric Company, Inc., HEI's wholly owned electric utility subsidiary, will become a wholly owned subsidiary of NEE and each outstanding share of HEI common stock will be converted into the right to receive 0.2413 shares of NEE common stock. Completion of the merger and the actual closing date remain subject to the satisfaction of certain conditions, including Hawaii Public Utilities Commission approval. The merger agreement contains certain termination rights and provides that, upon termination of the merger agreement under specified circumstances, HE! or NEE, as the case may be, would be required to pay to the other party a termination fee of $90 million and reimburse the other party for up to $5 million of its documented out-of-pocket expenses incurred in connection with the merger agreement. Assets and Uabilities Associated with Assets Held for Sale - In November 2015, a subsidiary of NEER entered into an agreement to sell its ownership interest in its merchant natural gas generation facilities located in Texas, which have a total generating capacity of 2,884 MW at December 31, 2015. The transaction is expected to close in the first quarter of 2016, pending the receipt of necessary regulatory approvals and satisfaction of other customary closing conditions. The carrying amounts of the major classes of assets and liabilities related to the facilities that were classified as held for sale on NEE's consolidated balance sheets primarily represent property, plant and equipment and the related long-term debt. 2. Employee Retirement Benefits Employee Pension Plan and Other Benefits Plans - NEE sponsors a qualified noncontributory defined benefit pension plan for substantially all employees of NEE and its subsidiaries. NEE also has a supplemental executive retirement plan (SERP), which includes a non-qualified supplemental defined benefit pension component that provides benefits to a select group of management and highly compensated employees, and sponsors a contributory postretirement plan for other benefits for retirees of NEE and its subsidiaries meeting certain eligibility requirements. The total accrued benefit cost of the SERP and postretirement plans is approximately $321 million ($230 million for FPL) and $355 million ($237 million for FPL) at December 31, 2015 and 2014, respectively. IFERC FORM N0.1 (ED. 12-88) Page123.10 - Name of Respondent This Report is: ( 1) ~ An Original (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) II 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) Plan Assets, Benefit Obligations and Funded Status- The changes in assets, benefit obligations and the funded status of the pension plan are as follows: 2015 2014 Plan amendments (9) Benefit payments ,-8~}lk~t~K~r8~b~mQ~"A1W:~t-~-•-:''_-:L ~- · · · _·: · - -··· ;;·,,··::·:···. ··-·····.··.··· Funded status: iE.~k~~~)~&._~69~,~t_H~~~_e_~~fi¥£jj_->LL':. _- _. _~•~-;~---"~-------' ___ :c,i:,_·: c-----·-=-- -• _ ---•••-•- ·:·. -._·._.:• · Prepaid benefit costs at FPL at December 31 (a) i · _-, ..••,,.~-~· ·$:··;;:_-: ·•·''Ji¥44: ___ 1,243 $ $ 1..;___ '189 NEE's accumulated pension benefit obligation, Which includes no assumption about future salal)' levels, at December 31, 2015 and 2014 was approximately $2,366 million and $2,400 million, respectively. NEE's unrecognized amounts included in accumulated other comprehensive income (loss) yet to be recognized as components of prepaid pension cost are as follows: 2015 . 2014 ··.··· · ..·· .. Unrecognized prior service cost (net of $1 and $1 tax benefit, ~espectively) ;" :-.:t:f.~~~:9P9":!~~~.-~P-~.se~~ ~ry_:t ·~r.~~-~~/~~ --~-~ 9~~~--p¢n·~r~~~}~~~~~~~~,,;>·r:··.,-. 7 ..... -~ ~ ~ ~: -::.~:~-~.:~~ _-,-~;~~--~;~::~.~-~~~-.'·:·:·· ..._.. , ... .... .... Total .. -- · ·. -. $ --~- -~ :.~ .. (2) $ ..:: . .. .. .-.:·.·...... ___ (2) /~:·:<<~or~·'-'. .:__;_,._;_:_,·::...:.=~:..::.:..:~::·--~--_-_..:.:;J1_.. ,~""'=·.): $ (62) $ __;......;. (18) NEE's unrecognized amounts included in regulatory assets yet to be recognized as components of net prepaid pension cost are as follows: 2015 2014 (millions) i llnrec~g~lz~~ prj~~-~&iC? co!)t Unrecognized losses IFERC FORM NO.1 (ED. 12-88) Page 123.11 Name of Respondent This Report is: {1) ~An Original I(2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report {Mo, Da, Yr) I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) The following table provides the assumptions used to determine the benefit obligation for the pension plan. These rates are used in determining net periodic income in the following year. 2014 2015 4.10% 4.10% Salary increase NEE's investment policy for the pension plan recognizes the benefit of protecting the plan's funded status, thereby avoiding the necessity of future employer contributions. Its broad objectives are to achieve a high rate of total return with a prudent level of risk taking while maintaining sufficient liquidity and diversification to avoid large losses and preserve capital over the long term. The NEE pension plan fund's current target asset allocation, which is expected to be reached over time, is 45% equity investments, 32% fixed income investments, 13% alternative investments and 10% convertible securities. The pension fund's investment strategy emphasizes traditional investments, broadly diversified across the global equity and f!xed income markets, using a combination of different investment styles and vehicles. The pension fund's equity and fixed income holdings consist of both directly held securities as well as commingled investment arrangements such as common and collective trusts, pooled separate accounts, registered investment companies and limited partnerships. The pension fund's convertible security assets are principally direct holdings of convertible securities and includes a convertible security oriented limited partnership. The pension fund's alternative investment holdings consist of absolute return oriented limited partnerships that use a broad range of investment strategies on a global basis as well as other alternative investments, such as private equity, income and real estate oriented investments in limited partnerships. The fair value measurements of NEE's pension plan assets by fair value hierarchy level are as follows: December 31, 2015(•1 Quoted Prices in Active Markets for Identical Assets or liabilities (Level1) · Equity commingled vehlcles(c) - ., .. .•....... - -·-···· .. -·· ... ·- ····- ------. -------- ,..........------····.. Significant Other Observable Inputs Significant Unobservable Inputs (Level3) (Level2) Total . ............. . .u.~;'i;;o~~rl'lm~i¥~i1~0J~h~IP#i h;()od{( · · <:. _, ·,-:"::iS · • •· ··. '.. · ._. . ··-·· · ·. ·.• '-hci.. ._ ~ Corporate debt securities( d) 2 277 280 21 21 '),i~~backed .,,.,,,-,.It;.~<:. Debt security commingled vehicles , ............. · Ccinv~:rtible .secl.tritie~(e> .; : · : • ·. ·?74:; Total investments in the fair value hierarchy \•Total liw~tm~ts'n1-dast'~·~tri~tiis~etvalu~... ,. . ·:.; :;: ~.--. ;-::-· ·-; . ···-.· .... ·.·· ···: .... 1,038 $ $ ----•• ·-~·--:-:- ... 2,589 2 .. -. -..'"".-... --..c-..-.""".:,...·...'..."".,...,._-... - - --~~ --· . : ;::iii' ··:.:: ... . :.:.:•.. ·_______ ····-----···------·· $ Total fair value of plan assets (a) (b) (c) (d) (e) (f) 1 ,549 $ 3,563 See Note 4 for discussion of fair value measurement techniques and Inputs. Includes foreign Investments of $384 million. Includes foreign Investments of $24S million. Includes foreign investments of $68 million. Includes foreign Investments of $23 million. Includes foreign Investments of $283 million. Reflects the adoption of an accounting standard update in 2015 whereby certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient are excluded from the fair value hierarchy. IFERC FORM NO. 1 (ED. 12-88} Page 123.12 Date of Report Year/Period of Report (Mo, Da, Yr) This Report is: (1) X An Original I (2) A Resubmission Name of Respondent Florida Power & Light Company I I 2015104 NOTES TO FINANCIAL STATEMENTS (Continued) December 31, 2014Ca) Quoted Prices inActive Markets for Identical Assets or liabilities (Level1) Significant Other Observable Inputs (Level2) Significant Unobservable Inputs (Level3) Total (millions) Debt security commingled vehicles . ··:.:,:··:.:;'.'.:~·::.: . :: ·..': ~-:·:.:.,:;=-~ .···: .··· .. ·:.: ··::::·: :·. · Cqove.i:tlbJe ~JeC\intJ~s :.: .. . . ·. _. :; ·:. --~:·· :...,·- ~ -::.::~-;. ---:·.-:. ·: _: .:~~- ~- ·~-~--:~~ ~-~-:.-~ c: -:c: =-:- ·-, -•- • , : Totalinvestments in the fair value hierarchy ~~\- -- - 21 ·.. .· .. . ·.: :::: ·• ::::: ......_. -~-. :_:'.-' -:·-~:. ::--· ... - \,i{. • .. ··<:45.: $ 1,173 $ <.:~~--'?iiL·X 21 :::::: . . _._._.,..c,•• -· - ···- 'z7~( _..;.."""'-------~ 1,646 $ 2,819 -:t~t~C~~¥4_t,;~~t~ ;£.~;~~ ~t ~~{~~~t'v~I~T-)/ .: ___ ~- _': _: -_ ·_- · · · --::· . < ·•- ' <-> :~:~. -:> ·_-""':"'":-.:·~. . -._.__-_-.-._ .-.-·:._"':\-_. ~"':'·-• ~-.-_.- . -· • ., _. --•{i}-~?i~ $ Total fair value of plan assets (a) (b) (c) {d) {e) 3,698 See Note 4 for discussion of fair value measurement techniques and inputs. Includes foreign investments of $321 million. · Includes foreign investments of $306 million. Includes foreign Investments of $88 million. Includes foreign investments of $200 million. Reflects the retrospective application of an accounting standard update in 2015 whereby certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient are excluded from the fair value hierarchy. Expected Cash Flows- The following table provides information about benefit payments expected to be paid by the pension plan for each of the following calendar years (in millions): 2017 $ 150 2019 $ 160 2021-2025 $ 865 lFERC FORM N0.1 (ED.12-88) Page 123.13 Name of Respondent Date of Report Year/Period of Report (Mo, Da, Yr) 2015104 I I This Report is: (1) ~An Original (2) A Resubmission Florida Power & Ugh! Company NOTES TO FINANCIAL STATEMENTS (Continued) Net Periodic (Income) Cost- The components of net periodic (income) cost for the plans is as follows: Pension Benefits 2015 2014 Special termination benefits -:~~fp~~i~i,~Jlll'~~)-~i~'~m~:1·cc_·_:,•·-•··-•' Netperiodic(income)costatFPL -·· $""_ ._.~_.,.._,_,.,.,.,._••-""ca"'"s~J$ 2014 2015 2013 101 97 Interest cost Postretirement Benefits 16 13 94 2013 14 46 ._.t7...4;;.Y_f,.; :<.{17r __$.....:' .......__.__.-...14_-'$ ·_. _, -As- ... $_--......._1_7_! $_·_••. _ _ (55)$ (47)$ ---- 11$ (7)$ 11$ 13 Other Comprehensive Income- The components of net periodic income (cost) recognized in OCI for the pension plan is as follows: 2014 2015 2013 Net gains (losses) (net of $27 and $29 tax benefit and $58 tax expense, resoe<:tlv,alvl ,.. ,.. , .. ,.... · .. o.--c:•:~-c •;• ,,...,_ .._--:• _ ... -.-c·:----c·:·•·,--"c:·•; ;_ArnoitiZ*tlon_of £r~o~,sir:yice lienefil Total $ ---93 (40) $ (44) $ Regulatory Assets (Liabilities) - The components of net periodic (income) cost recognized during the year in regulatory assets (liabilities) for the pension plan is as follows: 2015 2014 {millions) -----:~::----$--\: ;:,,··::l~!i 127 132 Foreign currency swaps $ Commodity contracts - $ - ~-...,........,....,. . . . . . ·.' . :_ ":\". ~: :·:::.-.-~ ,."'... ·....... :. : . 7 $ $ - ... . 225$ :.::·:........ :... -~...:. ·:::.~. ___·. ~~. -~_:_ ::~ __ 4$ ~~-----~,~-...,.....~_"""'··.,_ . ...• .·-:-·.;: .. ··--· ::.· 882 $ ass&ciatt:id_~,~~~~c~!:~~-~r~~~~ _ _, _____ :_______ ::: Noncurrent derivative liabilities( d) ·.. : . -~· ....: -~'-·· .. _ -.~:... ... 1~[ 530 ·---...:...-----··--------------------- _ :/ :;'_$_--·_------_.:.·.-_1_.9_71_- -_::. -.. --· $•.·--. :.':_{42a! :. : · Noncurtentiitherasseis_. $ Current derivative liabilities (a) (b) (c) (d) Reflects the Reflects the Reflects the Reflects the netting of approximately $279 million in margin cash collateral received from counterpartles. netting of approximately $151 million in margin cash collateral received from counterparties. netting of approximately $46 million in margin cash collateral paid to counterparties. netting of approximately $13 miiUon in margin cash collateral paid to counterparties. IFERC FORM NO.1 (ED. 12-88) : .. ............ - ·..... :· .... :.· :... :~.::.:.:.. 1 Current derivative liabilities(c) : Net fair vatue by FPS ~~lao~ She~l~e itellt: . Current other assets 222 ·:.··.'. 67 Assets held for sale i ~.-i:iab!fiti!!s 982 Page 123.16 222 Florida Power Date of Report Year/Period of Report (Mo, Da, Yr) This Report is: (1)~An Original (2) A Resubmission Name of Respondent & Light Company I f 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued} December 31 , 2014 Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis Assets Liabilities Fair Values of Derivatives Not Designated as Hedging Instrumenls for Accounting Purposes - Gross Basis Assets liabilities Total Derivatives Combined Net Basis Liabilities Assets 1,009 Noncurrent derivative assets(b) Noncurrent deriVative liabilities( d) 466 Current derivative liabilities {a) {b) (c) (d) Reflects the Reflects the Reflects the Reflects the $ 370 netting of approximately $197 million In margin cash collateral received from counterpartles. netting of approximately $97 million in margin cash collateral received from counterparties. netting of approximately $20 million in margin cash collateral paid to counterparties. netting of approximately $10 million in margin cash collateral paid to counterparties. At December 31, 2015 and 2014, NEE had approximately $27 million and $60 million (none at FPL), respectively, in margin cash collateral received from counterparties that was not offset against derivative assets in the above presentation. These amounts are included in current other liabilities on NEE's consolidated balance sheets. Additionally, at December 31, 2015 and 2014, NEE had approximately $116 million and $122 million (none at FPL), respectively, in margin cash collateral paid to counterparties that was not offset against derivative assets or liabilities in the above presentation. These amounts are included in current other assets on NEE's consolidated balance sheets. IFERC FORM N0.1 {ED.12-88) Page 123.17 Name of Respondent Date of Report Year/Period of Report (Mo, Da, Yr) This Report is: (1) ~An Original (2) A Resubmission Florida Power & Light Company I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) Income Statement Impact of Derivative Instruments - Gains {losses) related to NEE's cash flow hedges are recorded in NEE's consolidated financial statements (none at FPL) as follows: Year Ended December 31, 2015 Interest Rate Contracts Year Ended December31, 2014 Foreign currency Total Swaps Interest Rate Contracts Year Ended December31, 2013 Foreign Currency SWaps Total Interest Rate Contracts Foreign Currency Swaps Total (millions) '9~~-<~e~).~rJZ:~~-~?:<>~uc .-... :,~:·.: :~.'- :·: ·.:··:·:!'.. , ·:· . :' :• (b) .., ..... '. ·.·' ... ·'.' "· . ·.· ... . - --- ·- ..,. ... ·-·· -··· ·--····~.-~:·:.~-- ·- .. . . . . . . . . . . . . -- _ _ ):• ·i·JH~> :_'$ i't.::H~} )C$.:H~i$ _ -.,p~i!J--i· s··- >Li~RH-i f'-l~H-i Losses reclassified from AOC Ito net Income (a) . $ (73) 1•1 $ $ (15) {bl (88) $ (78) (77) 1•1 $ (b) :··:.·:· ··.:::·::: •·,15o:'i (61) $ (155) $ ·- . t•r: {?1J.,C, ,~-··- 12~' (44) {a)$ (b) $ (1 05) Included In Interest expense. For 2015, 2014 and 2013, losses of approximately $11 million, $8 million and $4 million, respectively, are included in Interest expense and the balances are Included in other- net. For the years ended December 31, 2015, 2014 and 2013, NEE recorded gains (losses) of approximately ${4) million, $20 million and $(65) million, respectively, on fair value hedges which resulted in corresponding increases (decreases) in the related debt. Gains (losses) related to NEE's derivatives not designated as hedging instruments are recorded in NEE's consolidated statements of income as follows: Years Ended December 31, 2015 2014 (1) Foreign currency swap - other- net ·-··~. ·--_::--:-·:-:~:-·--:·-:---:-:·::.:·::-·.-.:··:· ...-·· ... ,,, •I Mere$( rtlt~'~(?ntr~#~C: ~~~ire~f~~.P~~}-~:c:_:~ --·;-:;_·--···-·-··- .. ·-··-··- .. _:_ •· · · :.. :--._, __ :______ .... ' . -,: . '<~ _·' ",, ·\ ·'·•--'· ".:': $ Total (a) 2013 '::~:~~··.:~ :jt_ . ·.•····... -948 $ ___ (72) •. : (64)...__........_ 356 I . ···:-3! ._. $ 7 ----- For the years ended December 31, 2015, 2014 and 2013, FPL recorded gains (losses) of approximately $(326) million, $(289) million and $81 million, respectively, related to commodity contracts as regulatory llabllitles (assets) on its consolidated balance sheets. Notional Volumes of Derivative Instruments - The following table represents net notional volumes associated with derivative instruments that are required to be reported at fair value in NEE's and FPL's consolidated financial statements. The table includes significant volumes of transactions that have minimal exposure to commodity pr"1ce changes because they are variably priced agreements. These volumes are only an indication of the commodity exposure that is managed through the use of derivatives_ They do not represent net physical asset positions or non-derivative positions and their hedges, nor do they represent NEE's and FPL's net economic exposure, but only the net notional derivative positions that fully or partially hedge the related asset positions. NEE and FPL had derivative commodity contracts for the following net notional volumes: IFERC FORM NO. 1 (ED. 12-88) Page 123.18 This Report is: (1) 2S, An Original (2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 NOTES TO FINANCIAL STATEMENTS (Continued) December 31,2015 NEE Commodity Type (a) Megawatt-hours (b) One million Br~ish thermal December31, 2014 FPL NEE FPL un~s At December 31, 2015 and 2014, NEE had interest rate contracts with notional amounts totaling approximately $8.3 billion and $7.4 billion, respectively, and foreign cunrency swaps with notional amounts totaling $715 million and $661 million, respectively. Credit-Risk-Related Contingent Features - Certain derivative instruments contain credit-risk-related contingent features including, among other things, the requirement to maintain an investment grade credit rating from specified credit rating agencies and certain financial ratios, as well as credit-related cross-default and material adverse change triggers. At December 31, 2015 and 2014, the aggregate fair value of NEE's derivative instruments with credit-risk-related contingent features that were in a liability position was approximately $2.2 billion ($224 million for FPL} and $2.7 billion ($369 million for FPL), respectively. If the credit-risk-related contingent features underlying these agreements and other commodity-related contracts were triggered, certain subsidiaries of NEE, including FPL, could be required to post collateral or settle contracts according to contractual terms which generally allow netting of contracts in offsetting positions. Certain contracts contain multiple types of credit-related triggers. To the extent these contracts contain a credit ratings downgrade trigger, the maximum exposure is included in the following credit ratings collateral posting requirements. If FPL's and NEECH's credit ratings were downgraded to BBB/Baa2 (a two level downgrade for FPL and a one level downgrade for NEECH from the current lowest applicable rating), applicable NEE subsidiaries would be required to post collateral such that the total posted collateral would be approximately $250 million ($20 million at FPL) as of December 31, 2015 and $700 million ($130 million at FPL) as of December 31, 2014. If FPL's and NEECH's credit ratings were downgraded to below investment grade, applicable NEE subsidiaries would be required to post additional collateral such that the total posted collateral would be approxima~ely $2.5 billion ($0.6 billion at FPL) and $2.8 billion ($0.7 billion at FPL) as of December31, 2015 and 2014, respectively. Some contracts do not contain credit ratings downgrade triggers, but do contain provisions that require certain financial measures be maintained and/or have credit-related cross-default triggers. In the event these provisions were triggered, applicable NEE subsidiaries could be required to post additional collateral of up to approximately $660 million ($120 million at FPL) and $850 million ($200 million at FPL) as of December 31, 2015 and 2014, respectively. Collateral related to derivatives may be posted in the form of cash or credit support in the normal course of business. At December 31, 2015, applicable NEE subsidiaries have posted approximately $123 million ($3 million at FPL) in the form of letters of credit which could be applied toward the collateral requirements described above. At December 31, 2014, applicable NEE subsidiaries have posted approximately $20 million (none at FPL) in cash and $236 million (none at FPL}, respectively, in the form of letters of credit which could be applied toward the collateral requirements described above. FPL and NEECH have credit facilities generally in excess of the collateral requirements described above that would be available to support, among other things, derivative activities. Under the terms of the credit facilities, maintenance of a specific credit rating is not a condition to drawing on these credit facilities, although there are other conditions to drawing on these credit facilities. Additionally, some contracts contain certain adequate assurance provisions where a counterparty may demand additional collateral based on subjective events and/or conditions. Due to the subjective nature of these provisions, NEE and FPL are unable to determine an exact value for these items and they are not included in any of the quantitative disclosures above. 4. Fair Value Measurements The fair value of assets and liabilities are determined using either unadjusted quoted prices in active markets (level1) or pricing inputs that are observable (level 2} whenever that information is available and using unobservable inputs (Level 3) to estimate fair value only when relevant observable inputs are not available. NEE and FPL use several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those assets and liabilities that are measured at fair value on a recurring basis. NEE's and FPL's assessment of the significance of any particular input to the fair value measurement requires judgment and may affect their placement within the fair value hierarchy levels. Non-performance risk, including the consideration of a credit valuation adjustment, is also IFERC FORM N0.1 (ED, 12-88) Page 123.19 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original I(2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) considered in the determination of fair value for all assets and liabilities measured at fair value. Cash Equivalents and Restricted Cash - NEE primarily holds investments in money market funds. The fair value of these funds is calculated using current market prices. Special Use Funds and Other Investments- NEE and FPL hold primarily debt and equity securities directly, as well as indirectly through commingled funds. Substantially all directly held equity securities are valued at their quoted market prices. For directly held debt securities, multiple prices and price types are obtained from pricing vendors whenever possible, which enables cross-provider validations. A primary price source is identified based on asset type, class or issue of each security. Commingled funds, which are similar to mutual funds, are maintained by banks or investment companies and hold certain investments in accordance with a stated set of objectives. The fair value of commingled funds is primarily derived from the quoted prices in active markets of the underlying securities. Because the fund shares are offered to a limited group of investors, they are not considered to be traded in an active market. Derivative Instruments - NEE and FPL measure the fair value of commodity contracts using prices observed on commodities exchanges and in the OTC markets, or through the use of industry-standard valuation techniques, such as option modeling or discounted cash flows techniques, incorporating both observable and unobservable valuation inputs. The resulting measurements are the best estimate of fair value as represented by the transfer of the asset or liability through an orderly transaction in the marketplace at the measurement date. Most exchange-traded derivative assets and liabilities are valued directly using unadjusted quoted prices. For exchange-traded derivative assets and liabilities where the principal market is deemed to be inactive based on average daily volumes and open interest, the measurement is established using settlement prices from the exchanges, and therefore considered to be valued using other observable inputs. NEE, through its subsidiaries, including FPL, also enters into OTC commodity contract derivatives. The majority of these contracts are transacted at liquid trading points, and the prices for these contracts are verified using quoted prices in active markets from exchanges, brokers or pricing services for similar contracts. NEE, through NEER, also enters into full requirements contracts, which, in most cases, meet the definition of derivatives and are measured at fair value. These contracts typically have one or more inputs that are not observable and are significant to the valuation of the contract. In addition, certain exchange and non-exchange traded derivative options at NEE have one or more significant inputs that are not observable, and are valued using industry-standard option models. In all cases where NEE and FPL use significant unobservable inputs for the valuation of a commodity contract, consideration is given to the assumptions that market participants would use in valuing the asset or liability. The primary input to the valuation models for commodity contracts is the forward commodity curve for the respective instruments. Other inputs include, but are not limited to, assumptions about market liquidity, volatility, correlation and contract duration as more fully described below in Significant Unobservable Inputs Used in Recurring Fair Value Measurements. In instances where the reference markets are deemed to be inactive or do not have transactions for a similar contract, the derivative assets and liabilities may be valued using significant other obseNable inputs and potentially significant unobservable inputs. In such instances, the valuation for these contracts is established using techniques including extrapolation from or interpolation between actively traded contracts, or estimated basis adjustments from liquid trading points. NEE and FPL regularly evaluate and validate the inputs used to determine fair value by a number of methods, consisting of various market price verification procedures, including the use of pricing services and multiple broker quotes to support the market price of the various commodities. In all cases where there are assumptions and models used to generate inputs for valuing derivative assets and liabilities, the review and verification of the assumptions, models and changes to the models are undertaken by individuals that are independent of those responsible for estimating fair value. NEE uses interest rate contracts and foreign currency swaps to mitigate and adjust interest rate and foreign currency exchange exposure related primarily to certain outstanding and forecasted debt issuances and borrowings when deemed appropriate based on market conditions or when required by financing agreements. NEE estimates the fair value of these derivatives using a discounted cash flows valuation technique based on the net amount of estimated future cash inflows and outflows related to the agreements. Recurring Fair Value Measurements - NEE's and FPL's financial assets and liabilities and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows: IFERC FORM N0.1 (ED, 12-88) Page 123.20 This Report is: (1) ~An Original (2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I f 2015/Q4 NOTES TO FINANCIAL STATEMENTS (Continued) December 31,2016 Level2 Level 1 Netting(al Level3 Total (millions) Cash equivalents and restricted cash:(b) NEE: U.S. Government and municipal bonds $ 446 $ 166 $ $ 612 · ·> ;- £~~bfate_d~bt s;cli~~e~s :., Mortgage-backed securities :-~~,:·:,:···:·:·._:-··: ·.:-·;··,~··· .. :·:· ·.·:·;:·.~~-. ·:···:;·'.' •:: $ - $ 412 $ $ 412 $ 30 $ 10 $ $ 40 $ 2,187 $ 2,540 $ :~- ••. -._•:- ·-•· ••o.th~rd~btSec;iiiiti¢s' : . : ,._-FPL: -·· -·- -i~---eBJ&_~q~-~·~~~ -\ · U.S. Government and municipal bonds Other investments: Equity securities -· ------ ---·--·------ ··· -: :; Debt sec:it;uities Derivatives: ·:-:·: ··•-...'-NEE:'<'·•·-,-Commodity contracts -· '.""' ----'··:' 1,179 $ :·!'".. · ··:~-~$_< -$ FPL - commodity contracts - $ 1 $ 1,937 . 6 $ Liabilitle!i: -_ '. - ····------- (e) (el., (3} $ 4 (el -··· Derivatives: :·. NEE:'' 1,887 $ 540 $ ······----------·· -~-~----- ~--=---.,.·-:-·~·-:···· .. - - _21{<; $ ·····-·· Foreign currency swaps -' 'Ff>~ J ~~in~ity' eorrtra~s $ :.· .... ··. ... $ $ 132 $ 219 ·-> 982 (el '1o1·l $ <>s< > ·- {a) lndudos the effect of the co.otradual o~~bliHy t-o settle (Xlnlrael:s under master netl:i11g arrangemen1s and the netting of margin cash cal lateral payments and recefpts. NEE and FPL also h!iilve cor~lracl seltlemenl recolvab!a and payable bcllances 1tlal are subject to the master neiOng arrangements but are not ol'fi;~;~t witnln the consolidated bala11ce sheets am:f are recorcled In customer ll!tcefvable~- net and accaUJJls payable, respectfvely. (b) (c) Includes res1Ftcted cash of approximately $B, mlllloo ($36 mHI!on for FPL) in olher Cli'Tent assets on tna ronsolldated balance sheets. Excludes lnveslmenLs accounted ror urader tM equity m~lhod sod leans not mea~i:uretl at fatr value on a recurrhlg basi!i. See Fair Value of Financial ln!itrt.JIT18l11S Recorded .at the canyln~ Amount bel mY. Pr1mArlly lnve.steCS: In commingled fundswho.se undertyklg securl.las wou1d be Lev~ 11fthnse securftfes were held Cli.-ectly by NEE or FPL See Note 3- Fair Value of Derivative Instruments for a reconcif1allon or net derivatives to NEE's and FPL's oonsolldaled balance sheets. (d) (e) \FERC FORM NO.1 (ED. 12-88) Page 123.21 Name of Respondent Florida Power & Light Company I This Report is: (1) ~An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I1 2015/Q4 NOTES TO FINANCIAL STATEMENTS (Continued) December 31, 2014 Level2 Level 1 Netting{ a) Level3 Total Special use funds:(b) Corporate debt securities $ _, :_;}~~~~~~~~~~{~~~~~~!_e~ ·· 704 $ $ 704 $ $ 57 :•·$·. : Other debt securities $ 25 $ 32 Equity securities $ 324 $ 1,237 ._ _ _ (c) $ $ --~~i--:··-Ty~~~--<3~vini§~~i-~d-;~~-~~~~:~~;~~]_2::1P-i:;_;-••-: ._~:~3~ ·~.c. . '.$,':_•_·.·...· 1,561 .... -c·.··:-:··::•1 ·••·•·sao.;-:; ."•.:-•: . . . . . . $ NEE: Debt securities ·· beriv~ti\(e:s: > $ 5 $ 170 $ $ $ 35 $ $ 175 •>·· . ·. .· ·.·. . . . . . .-. .·. NEE: :_·. •-· ._,_ ··.·_coinni.~dltY.tc,nifa~s··•.:· Interest rate contracts $ . pf?l.; co~m?dl_ty .d()~t~acis .· •·• 15 r(1) 50 (d) .. :···.:">-:: 7 {d) Liabilities: NEE: .··... c()rri~()dity t:bntr~t:!S' ' - Interest rate contracts .-·. ·: - ·..-:::: .. -.···-:':':-.-·-:-··--: (a) (b) (c) (d) 3,150 126 $ ;~::-- ··:··-~-.---:----. j:: ·.·:.420'$ ••. (3,932)j> . $ 125 $ $ 1 $ 15 $ 266 (d) 370 (d) ·;·-:--: ·· · Foreign c~rrel'lcy swaps · ··•$: FPL - commodity contracts $ • - $ 13_1 370 Includes 1tJe effed. Df the contractual abiH1y ID settllil' contraas under master r~eftinG &rrengemen1s and lhe n~Hing of margin cash collateral pa~rnents atlCI rece-lpls. NEE and FPL also have contract sanlemenl recaivable. and payable batances thai are subject to the maSiar netting ammgamenls but aTB not ctrsel within the oo!"ISOIIda\ed balance sheets and are recorded '"customer recelvables- nel :md accounts payable, respactively. Exdudes investments accounted for under the equity method and loans nOI maasurect at fllir value on a recl)rring basts. See Fair Value of Finatlc:~t ln:sl.nnntsnls. Recordl!d :alltle Carrying Arnount. below. Primarily lnve.sled In commlnglad funds whose unoeriylng securilles woUld be Le\lel1 rr lhDse secur'ltie& wl:h.: hek! directly~ NEE -or F?L See Note 3 • Fliir Value Of OertvPtlve lnS1rvmenls ror a reconcillalion of net deriva11ves lo NEE's anc:l FPL's consolidated balanoe sheets, Significant UnobseNab/e Inputs Used in Recurring Fair Value Measurements - The valuation of certain commodity contracts requires the use of significant unobservable inputs. All forward price, implied volatility, implied correlation and interest rate inputs used in the IFERC FORM N0.1 {ED.12-88) Page 123.22 This Report is: (1) ~An Original .{2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I f 2015104 NOTES TO FINANCIAL STATEMENTS (Continued) valuation of such contracts are directly based on third-party market data, such as broker quotes and exchange settlements, when that data is available. If third-party market data is not available, then industry standard methodologies are used to develop inputs that maximize the use of relevant observable inputs and minimize the use of unobservable inputs. Observable inputs, inducting some forward prices, implied volatilities and interest rates used for determining fair value are updated daily to reflect the best available market information. Unobservable inputs which are related to observable inputs, such as illiquid portions of forward price or volatility curves, are updated daily as well, using industry standard techniques such as interpolation and extrapolation, combining observable forward inputs supplemented by historical market and other relevant data. Other unobservable inputs, such as implied correlations, customer migration rates from full requirements contracts and some implied volatility curves, are modeled using proprietary models · based on historical data and industry standard techniques. All price, volatility, correlation and customer migration inputs used in valuation are subject to validation by the Trading Risk Management group. The Trading Risk Management group performs a risk management function responsible for assessing credit, market and operational risk impact, reviewing valuation methodology and modeling, confirming transactions, monitoring approval processes and developing and monitoring trading limits. The Trading Risk Management group is separate from the transacting group. For markets where independent third-party data is readily available, validation is conducted daily by directly reviewing this market data against iryputs utilized by the transacting group, and indirectly by critically reviewing daily risk reports. For markets where independent third-party data is not readily available, additional analytical reviews are performed on at least a quarterly basis. These analytical reviews are designed to ensure that all price and volatility curves used for fair valuing transactions are adequately validated each quarter, and are reviewed and approved by the Trading Risk Management group. In addition, other valuation assumptions such as implied correlations and customer migration rates are reviewed and approved by the Trading Risk Management group on a periodic basis. Newly created models used in the valuation process are also subject to testing and approval by the Trading Risk Management group prior to use and established models are reviewed annually, or more often as needed, by the Trading Risk Management group. On a monthly basis, the Exposure Management Committee (EMC), which is comprised of certain members of senior management, meets with representatives from the Trading Risk Management group and the transacting group to discuss NEE's and FPL's energy risk profile and operations, to review risk reports and to discuss fair value issues as necessary. The EMC develops guidelines required for an appropriate risk management control infrastructure, which includes implementation and monitoring of compliance with Trading Risk Management policy. The EMC executes its risk management responsibilities through direct oversight and delegation of its responsibllities to the Trading Risk Management group, as well as to other corporate and business unit personnel. The significant unobservable inputs used in the valuation of NEE's commodity contracts categorized as Level 3 of the fair value hierarchy at December 31, 2015 are as follows: Fair Value at December 31, 2015 Transaction Type Asseb . k~-~;rd contr~-~~~ ~p'o-;~i .. -···- ,. Valuation Technlque(s) Significant Unobservable Inputs Liabilities (millions) ·--·- .. _:::·-.: ...... ."$, .. . . &3& $., '·•· ·:.: .2_s2 . ·,oi~-~~u.~~~:~~;h· n~;r:;:.·~~iVF~fi'P~e~ o;;r)t~W!l/ : ::~ :: $~-;--,~ :· · Forward contracts - gas .'f_ciili¥_~6"0'~-~~~th,~--~rn~~djty r~lat~cl....• .:·• ·.••.:. Options - power 24 ·, : 25 ... . .. .. . . Discounted cash flow -· .. ··-- Forward price (per MMBtu) Full requirements and unit contingent contracts 68 58 Option models 330 35 Discounted cash flow Applies only to full requirements contracts. IFERC FORM NO.1 (ED.12-88) $t13 ': :-.. -.::~.:.. ·.,:...: ..:.... -~:-·; ... -~. -·---· .. .: ..~ $1 $6 ~~- ..•. · ••. ~.~-: . .. :~·"J:pjs~~".)t~:~~~rJ()~ O:•ro~lltd.,Pri~· (v;irlou~) . ···_-.,.'$.(1~)·-._-,~-:·--·~~~ ·.l (5)% 99% 1% 308% Forward price (per MWh) $(20) $239 Customer migration rate(a) -% 20% Implied correlations Implied volatilities (a) Range Page 123.23 Name of Respondent This Report is: (1) X An Original L{_~ A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) 2015/04 I I NOTES TO FINANCIAL STATEMENTS (Continued) The sensitivity of NEE's fair value measurements to increases (decreases) in the significant unobservable inputs is as follows: Significant Unobservable Input Position Implied correlations :·····::---~--'--.:..::-:·-:-:=-:-t":"; -,~·.-..·-:~"- Purchase option Decrease (Increase) Sell option Increase (decrease} '::'';"'"'.,..,'":--;·"·:; -:-·.-::":"''":":7'--7------~-- .·-:·;:-....-·--:·. ": ~=~-:··:··--;··:·7: tfitp.lie~)i.~>,J~tilitt~~--\ :. -.. _,, Impact on Fair Value Measurement ......,.• _., ·; ··:--; :·-.-·.--·- ;• ~ ;_p!J'rc_h~~~ptic)l1/ . , ::!®.~~~~~~ll~r~a$MC. ··· .· _,·{ :•·.-.-·.·· . . . .:;· .....;. :. \:::;~llpp~Q.r~<<: ··5: •:_;:-.~~(:r~~~~~ry~~~~~~-:-· 'C: Sell power(a) Customer migration rate (a) Decrease (increase) Assumes the contract Is In a gain position. In addition, the fair value measurement of interest rate swap liabilities related to the solar projects in Spain of approximately $101 million at December 31, 2015 includes a significant credit valuation adjustment. The credit valuation adjustment, considered an unobservable input, reflects management's assessment of non-performance risk of the subsidiaries related to the solar projects in Spain that are party to the swap agreements. The reconciliation of changes in the fair value of derivatives that are based on significant unobservable inputs is as follows: Years Ended December 31, 2015 2014 NEE NEE FPL FPL (millions) -- ...... --------··· -----·····-·-·-·-· ......, ,__ ... ::-::-:: ... NEE FPL .:f~~~;r:~·~ri:f£r~~~--~~~~~~-~-~q~.ti~~~b~~~ri~~·~t·•>·.· <$< ·.·,~ ,:·$ ..·•··· .$· f ·· 6~£ ....... 2013 ~ ~ ·- .·:- .. ·.;; ... ··:·;·:.··· . ··:.·_,:~:..~ _._.,,. -- $. · .. ?'. Z:$;-··< ~6:·$ .iO: ..' -2 Realized and unrealized gains Oosses): . -·- - .. -- ·--- ···.· .. : .. -- ····;,';:·:. :~·_>lri_c.ili~ed_ifl~~~r~ingf;(a). -... ·· 180 Purchases ~- ;...... · =---·-·· '"··=- ... _,_: ---·--·-·····-·-- -------~--~-· •· •... '. ;. __ ._ - ~- ·-· The amount of gains {losses) for the period included in eamings attributable to the change In unrealized gains (losses) relating to derivaijves still held at the reporting dale( c) (a) (b) (c) 101 __ Transfers out(b) : Fe~ir value ofnet deilva~$ basecl.on sign\ficant unob~rva_b)e l~pu!S.at > ' ~becember3.1 ·-··.- ·· ·• · ··· ·· · ·· .... -.:.····· · 55 $ .538 $ $ 277 $ ........ ~ - $ 246 $ - $ 329 $ --- For the year ended December 31, 2015, $462 mllllon of realized and unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance is primarily reflected in interest expense. For the year December 31, 2014, $79 million of realized and unrealized losses are reflected In the consolidated statements of income in interest expense and the balance is primarily reflected in operating revenues. For the year ended December 31, 2013, $302 million of realized and unrealized gains are reflected in the consolidated statements of income in operating revenues and the balance Is primarily reftected In Interest expense. Transfers into Level 3 were a result of decreased observabillty of market data and, in 2013, a significant credit valuation adjustment Transfers from Level 3 to Level 2 were a result of Increased observab!lity of market data. NEE's and FPL's policy is to recognize all transfers at the beginning of the reporting period. For the years ended December 31, 2015, 2014, and 2013, $289 million, $328 million, and $330 million of unrealized gains are reflected In the consolidated statements of income in operating revenues and the balance is reflected in inlerest expense. IFERC FORM N0.1 (ED.12-88) Page 123.24 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original I (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 NOTES TO FINANCIAL STATEMENTS (Continued) Contingent Consideration - NEE recorded a liability related to a contingent holdback as part of the acquisition of seven long-term contracted natural gas pipeline assets located in Texas. See Note 8. Nonrecurring Fair Value Measurements- NEE tests long-lived assets for recoverability whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. In February 2013, the Spanish government enacted a new law that made further changes to the economic framework of renewable energy projects including, among other things, changes that negatively affect the projected economics of the 99.8 MW of solar thermal facilities that affiliates of NEER were constructing in Spain (Spain solar projects) (see Note 14- Spain Solar Projects). Due to the February 2013 change in law, NEER performed a recoverability analysis, considering, among other things, working with lenders to restructure the financing agreements, abandoning the projects or selling the projects, and concluded that the undiscounted cash flows of the Spain solar projects were less than the carrying value of the projects. Accordingly, NEER performed a fair value analysis based on the income approach to determine the amount of the impairment. Based on the fair value analysis, property, plant and equipment with a carrying amount of approximately $800 million were written down to their estimated fair value of $500 million as of March 31, 2013, resulting in an impairment of $300 million (which is recorded as a separate line item in NEE's consolidated statements of income for the year ended December 31, 2013) and other related charges ($342 million after-tax, see Note 5). The estimate of the fair value was based on the discounted cash flows which were determined using a market participant view of the Spain solar projects upon completion and final commissioning of the projects. As part of the valuation, NEER used observable inputs where available, including the revised renewable energy pricing under the February 2013 change in law. Significant unobservable inputs (Level 3), including forecasts of generation, estimates of tariff escalation rates and estimated costs of debt and equity capital, were also used in the estimation of fair value. In addition, NEER made certain assumptions regarding the projected capital and maintenance expenditures based on the estimated costs to complete the Spain solar projects and ongoing capital and maintenance expenditures. An increase in the revenue and generation forecasts, a decrease in the projected capital and maintenance expenditures or a decrease in the weighted-average cost of capital each would result in an increased fair market value. Changes in the opposite direction of those unobservable inputs would result in a decreased fair market value. See Note 14- Spain Solar Projects for a discussion of additional developments that could potentially impact the Spain solar projects. In 2013, NEER initiated a plan and received internal authorization to pursue the sale of its ownership interests in oil-fired generation plants located in Maine (Maine fossil) with a total generating capacity of 796 MW. In connection with the decision to sell Maine fossil, a loss of approximately $67 million ($43 million after-tax) was originally reflected in net gain from discontinued operations, net of income taxes in NEE's consolidated statements of income for the year ended December 31, 2013. The fair value measurement (Level 3) was based on the estimated sales price less the estimated costs to sell. The estimated sales price was estimated using an income approach based primarily on capacity revenue forecasts. In 2014, NEER decided not to pursue the sale of Maine fossil due to the divergence between the achievable sales price and management's view of the assets' value, which increased as a result of significant market changes. Accordingly, the Maine fossil assets were written-up to management's current estimate of fair value resulting in a gain of approximately $21 million ($12 million after-tax). The fair value measurement (Level 3) was estimated using an income approach based primarily on the updated capacity revenue forecasts. Based on NEER's decision to retain Maine fossil, the $67 million loss recorded during the year ended December 31, 2013 was reclassified from discontinued operations to income from continuing operations and together with the $21 million gain recorded during the year ended December 31, 2014 are included as a separate line item in NEE's consolidated statements of income. IFERC FORM N0.1 (ED. 12-88) Page 123.25 Name of Respondent This Report is: (1) ~An Original {2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 NOTES TO FINANCIAL STATEMENTS (Continued) Fair Value of Financial Instruments Recorded at the Carrying Amount- The carrying amounts of cash equivalents, commercial paper and notes payable approximate their fair values. The carrying amounts and estimated fair values of other financial instruments, excluding those recorded at fair value and disclosed above in Recurring Fair Value Measurements, are as follows: December 31, 2015 . , ...... -:.-:··:····.. Carrying Estimated Carrying Estimated Amount Fair Value Amount Fair Value $ Special use funds(•) :-··:;;-:-··~.···;--·-.-:-7:-::'":'~·-.--- •. December 31, 2014 675 :···---~-'0""'7""":-·-:···· _qfu~iW~~ful~l\t~Fe~i-r!o/i.i¥~~;~~~,f(I¥Jyab!B-:\~_._-·-__,,~> _:\/ $ 675 ... ~'li,. - \;$ - - - - - - •. ,- $ $ 567 $ 27,552 ---------"~'----, $ :-I;~~-~~~i~~d~tit;Jrid~~~~~"~G~~~-1_iri~~rlt\a$ (a) (b) (c) (d) .· :';~.:r~~- 528 $ :" _ "1q,o.21i\ 1 .. '· _122 (ll;.$>2-'' --------•;,~is '$:-}:\:::c •- - - 679 ·M; $ Special use funds!•> 567 ·-------·-·--· ...... ,...... ,., ~--·-----·--·-·.-.-· 528 $ 395 30,013 ... ,_ .._,,- ..,.. , $ (d) 395 .... ·_-~ •. h.q~~·l~>$ ._. ____ ->;~,3~-:'Y¥J-~-~·~-, 11;b'2o ~¥J Primarily represents Investments accounted for under the equity method and loans not measured at fair value on a recurring basis_ Primarily classified as held to maturity. Fair values are primarily estimated using a discounted cash flow valuation technique based on certain observable yield curves and indices considering the credit profile of the borrower (Level 3). Notes receivable bear interest primarily at fl)(e(j rates and mature by 2029. Notes receivable are considered Impaired and placed in non"accrual status when it becomes probable that all amounts due cannot be collected In accordance with the contractual terms of the agreement. The assessment to place notes receivable in non--accrual status considers various credit indicators, such as credit ratings and market;elated Information. As of December 31, 2015 and 2014, NEE had no notes receivable reported in non-accrual status. Excludes debt totaling $938 million reflected In liabilities associated with assets held for sale on NEE's consolidated balance sheet for which the carrying amount approximates fair value. See Note 1 -Assets and Uabllities Associated with Assets Held for Sale. As of December 31, 2015 and 2014, for NEE, approximately $16,031 mil»on and $19,973 million, respectively, is estimated using quoted market prices for the same or similar issues (Level2); the balance Is estima1ed using a discounted cash flow valuation technique, considering the current credit spread of the debtor (level 3). For FPL, primarily estimated using QIJOted market prices for the same or similar issues (Level2). Special Use Funds - The special use funds noted above and those carried at fair value (see Recurring Fair Value Measurements above) consist of FPL's storm fund assets of approximately $74 million and $75 million at December 31, 2015 and 2014, respectively and NEE's and FPL's nuclear decommissioning fund assets of $5,064 million and $5,091 million at December 31, 2015 and 2014 ($3,430 million and $3,449 million, respectively, for FPL). The investments held in the special use funds consist of equity and debt securities which are primarily classified as available for sale and carried at estimated fair value_ The amortized cost of debt and equity securities is approximately $1,823 million and $1,505 million, respectively, at December31, 2015 and $1,906 million and $1,366 million, respectively, at December 31, 2014 ($1,409 million and $732 million, respectively, at December 31, 2015 and $1,519 million and $664 million, respectively, at December 31, 2014 for FPL). For FPL's special use funds, consistent with regulatory treatment, changes in fair value, including any other than temporary impairment losses, result in a corresponding adjustment to the related regulatory liability accounts. For NEE's non-rate regulated operations, changes in fair value result in a corresponding adjustment to OCI, except for unrealized losses associated with marketable securities considered to be other than temporary, including any credit losses, which are recognized as other than temporary impairment losses on securities held in nuclear decommissioning funds in NEE's consolidated statements of income. Debt securities included in the nuclear decommissioning funds have a weighted-average maturity at December 31, 2015 of approximately eight years at both NEE and FPL. FPL's storm fund primarily consists of debt securities with a weighted-average maturity at December 31, 2015 of approximately three years. The cost of securities sold is determined using the specific identification method. · Realized gains and losses and proceeds from the sale or maturity of available for sale securities are as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2014 2015 2015 2013 2014 2013 (millions) :·· .. ·.·.···. . 194 $• Realized losses ..... _, .. ·.·. ·:·-_, $ : Prba;!~d~,i'r~rn sale 6~ maturtty of!recurities $ ' .·. 87 $ 211······$ 115 $ --· "" .·· 1.20. 4 43 $ 94 $ 88 $ ,· <(64:l j • ---:: ··:::··-- :A,\9Q: $ :, :. 3,724 Page 123.26 ···.·.·····182!, 59 -·-, :$ ' :-::3,34~:: $ •- : ·. 3,342: Name of Respondent Florida Power & Light Company 1 Date of Report Year/Period of Report (Mo, Da, Yr) This Report is: (1) 6 An Original (2) A Resubmission 2015/Q4 II NOTES TO FINANCIAL STATEMENTS (Continued) The unrealized gains on available for sale securities are as follows: NEE FPL December 31, December 31, 2014 2015 Debt securities 17 $ $ 2014 2015 66 $ 14 $ 54 The unrealized losses on available for sale debt securities and the fair value of available for sale debt securities in an unrealized loss position are as follows: · NEE FPL December 31, December 31, 2014 2015 2014 2015 (millions) Fair value (a) $ 1,129 $ 542 $ 861 $ 434 Unrealized losses on available for sale debt securities in an unrealized loss position for greater than twelve months at December 31, 2015 and 2014 were not material to NEE or FPL. Regulations issued by the FERC and the NRC provide general risk management guidelines to protect nuclear decommissioning funds and to allow such funds to earn a reasonable return. The FERC regulations prohibit, among other investments, investments in any securities of NEE or its subsidiaries, affiliates or associates, excluding investments tied to market indices or mutual funds. Similar restrictions applicable to the decommissioning funds for NEER's nuclear plants are included in the NRC operating licenses for those facilities or in NRC regulations applicable to NRC licensees not in cost-of-service environments. With respect to the decommissioning fund for Seabrook, decommissioning fund contributions and withdrawals are also regulated by the NDFC pursuant to New Hampshire law. The nuclear decommissioning reserve funds are managed by investment managers who must comply with the guidelines of NEE and FPL and the rules of the applicable regulatory authorities. The funds' assets are invested giving consideration to taxes, liquidity, risk, diversification and other prudent investment objectives. Financial Instruments Accounting Standard Update- In January 2016, the FASB issued an accounting standard update which modifies current guidance for financial instruments. The standard requires that equity investments (except investments accounted for under the equity method and investments that are consolidated) be measured at fair value with changes In fair value recognized in net income and provides an option for those equity investments that do not have readily determinable fair values to be measured at cost minus impairment (plus or minus changes resulting from observable price changes). The standard also makes certain changes to presentation and disclosure requirements of financial instruments. The standard is effective for NEE and FPL beginning January 1, 2018 and will be applied retrospectively with the cumulative effect recognized as of the date of initial application. NEE and FPL are currently evaluating the effect the adoption of this standard will have, if any, on their consolidated financial statements. JFERC FORM N0.1 (ED. 12-88) Page 123.27 Name of Respondent This Report is: (1) ~An Original (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/Q4 NOTES TO FINANCIAL STATEMENTS (Continued) 5. Income Taxes The components of income taxes are as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2015 Current .,-pefer~¥ -----·-··-·------------------------~- ·: >• \_•/: Total state ........ ··············--···· : <. · 2013 ~0 $ - $ •?.._.1,;_;,,1.._9.:...( .... Y-.•..- ...••_·•·••-_::_1.._.o_i:~7-... .> :.·.·""'··-~··•...-_·.·-.•_:... i·_._. . ._.· ·_·•. . 24 ,.... 'T:ct.~dr.Ccii:l~ 1~x~$-<'. ::< · •- 2014 2015 (145) $ 423 $ 240 $ 174 135 128 121 ·...:..·l3_s3.;.;.;.< 99 69 ~: ·__ .•.•. ._· -·. A reconciliation between the effective income tax rates and the applicable statutory rate is as follows: NEE FPL Years Ended December 31, Years Ended December 31, 2015 2014 }>!~~.~~~i~~t:aJ ~~so~~ t~--i · -· Increases (reductions) resulting from: :·~_i_f:~n5f~~-~6~tbfred;ti.Jtnfcim~ : .. ;. ·::. ·. :_~::... ·. . :.. : -·. -. "' . : 0.7 ·. :· ..·-'··.. ·. . ··:···>,.··."· \·.·... _:>;.~···- . . i~~.4 ~; .•· -· :" -·; . ·.··-.:-.··.· ~.6.'.··.· 5.2 ~i,~-~~~~~fiated'Ni~ dli~~~n~~¥f~--- -- --0.3 other- net :'M••"• Effective Incom-e •"••••.. •••:..••••••••••-: (a) ··--·--·---·-···- .. Valuation allowance associated with Spain solar projects(aJ •· --- :. ..:·.:_:;.:-_.::: ·.:·:.·: 0.7 (1.7) (0.9) tax rate~ · Reflects a full valuation allowance on deferred IFERC FORM N0.1 (ED. 12-88) tax assets associated with the Spain solar projects. See Note 4- Nonrecurring Fair Value Measurements. Page 123.28 (0.4) Date of Report Year/Period of Report (Mo, Da, Yr) This Report is: (1) ~An Original (2) A Resubmission Name of Respondent Florida Power & Light Company 2015104 I I NOTES TO FINANCIAL STATEMENTS (Continued} The income tax effects of temporary differences giving rise to consolidated deferred income tax liabilities and assets are as follows: FPL NEE December 31, December 31 , 2014 2015 Investments in partnerships and joint ventures -·- ·-- ...... .,_.•.. ------:. ... -·-·- ..... --·- ----------··;---- -----.--- -----~-- --~ lOther;<.< .... c,;:'; \:i> ----.------ · -- Total deferred tax liabilities ;oeteire0:-_-_;{_~~;~·-: 403 - __ \<\ -'~:- ·.;···:·-~ :;·::··: ·.· :·.;··.:;··: ;: =:::> ·.-::. ·· : •.\N~~daferrec:t.tax:as5'ets·--··.··········.· 15,005 ·. :-: ::::·;>.:.:.~:~;· .... -·---~- ----";":-:-;· .-·:·:-·..-;·:-.··.·:-··; 13,897 ··-- __.,________ ::.:~~~:-~: ~-.:~~-----·-··· . .,.~-.--. ..... ·--· --------· - - ''- .- · · ;435A 9,215 8,351 ..._,..,,,.,_ •._-- - -' - , · • "7"_""'--"""'-----, ~. :·. :_: :-.-~ ··- . .... '-. ~ _:,:~·.: -.:·~:~.~.-:.":~ ~-:_: ::<. _·:~ ..... -. .. 386 427 438 ,_-.' __,..,.---___......;..(2;.._23,:.) - "- •. ·.~.471 c-·· $ Amount relates to a valuation allowance related 291 ~ ·:--;~·---~-~---·=-~~~--= -< - - -. ,""_-_••._."_" """-_,-_,~--~-_.____,. ,.,..__ :....___,._=.____ ""--•···""'••••-'.,.._'_,_,.....,.,.,....,.,..,_,~<-;,'-.-;--_,--""'.._. ,"",_ ._-,..., •. '""'•·::"""..:-·-...,_:.... __ ,_,:.,....,....,.,.,.,...,..,....,__ Net deferred income taxes (a) ... •1019_a - - _ ,_- ,.-.. ,._- :r.~~-<:···•···-·--·-·•· -·.·. ··:- ~95 <·<~• Decommissioning reserves Valuation allowance(a) 258 219 Nuclear decommissioning trusts 2014 2015 (323) 374 -~~-- ......,....,..,.....,.,.,.,...,.,.......,...., - >' : 1.48~ :_ . . : •: 1.477-.i - - ·· .5,e~i'_.: 8,270 $ 9,534 $ 7,730 $ ----6,874 to the Spain solar projects, deferred state tax credits and state operating loss canyforwards. Deferred tax assets and liabilities are included on the consolidated balance sheets as follows: FPL NEE December 31, 2015 December 31, 2015 2014 {millions) ; DeferreQ inco~~fu.~~~;~~(;¢rit-~~s~t;~---:--~":: ~' '_[a)$' : , ... 293 Noncurrent other assets Deferred income taxes - noncurrent liabilities 'Net deterreii inbbmet~xes (a) • · Effective December 31, 2015, all deferred taxes are classified as noncurrent See Note 1 - Income Taxes. IFERC FORM N0.1 (ED. 12~88) Page 123.29 264 2014 Name of Respondent Florida Power & Light Company This Report is: (1) X An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 20151Q4 NOTES TO FINANCIAL STATEMENTS (Continued) The components of NEE's deferred tax assets relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2015 are as follows: Amount Expiration Oates Tax credit carryforwards: (a) (b) Includes $89 million of net operating loss canyforwards with an Indefinite expiration period. Includes $158 ml!lion of lTC carryforwards with an indefinite expiration period. 6. Discontinued Operations In 2013, a subsidiary of NEER completed the sale of its ownership interest in a portfolio of hydropower generation plants and related assets with a total generating capacity of 351 MW located in Maine and New Hampshire. The sales price primarily included the assumption by the buyer of $700 million in related debt. In connection with the sale, a gain of approximately $372 million ($231 million after-tax) is reflected in gain from discontinued operations, net of income taxes in NEE's consolidated statements of income for the year ended December 31, 2013. The operations of the hydropower generation plants, exclusive of the gain, were not material to NEE's consolidated statements of income for the year ended December 31, 2013. See Note 4 - Nonrecurring Fair Value Measurements for a discussion of the decision not to pursue the sale of Maine fossil and the related financial statement impacts. 7. Jointly-Owned Electric Plants Certain NEE subsidiaries own undivided interests in the jointly-owned facilities described below, and are entitled to a proportionate share of the output from those facilities. The subsidiaries are responsible for their share of the operating costs, as well as providing their own financing. Accordingly, each subsidiary includes its proportionate share of the facilities and related revenues and expenses in the appropriate balance sheet and statement of income captions. NEE's and FPL's respective shares of direct expenses for these facilities are included in fuel, purchased power and interchange expense, O&M expenses, depreciation and amortization expense and taxes other than income taxes and other in NEE's and FPL's consolidated statements of income. lFERC FORM N0.1 (ED. 12-88) Page 123.30 Date of Report Year/Period of Report (Mo, Da, Yr) This Report is: (1) ~An Original l{2) A Resubmission Name of Respondent Florida Power & Light Company 2015/Q4 I I NOTES TO FINANCIAL STATEMENTS (Continued) NEE's and FPL's proportionate ownership interest in jointly-owned facilities is as follows: December 31, 2015 Ownership Interest Duane Arnold Transmission substation assets located in Seabrook, New Hampshire (a} Gross Investment(•) Accumulated Depreciation(a) Construction Work In Progress 70% $ 435 $ 126 $ 24 88.23"/. $ 73 $ 19 $ 3 Excludes nuclear fuel. 8. Texas Pipeline Business Acquisition On October 1, 2015, a subsidiary of NEP acquired 100% of the membership interests in NET Holdings Management, LLC (Texas pipeline business), a developer, owner and operator of a portfolio of seven long-term contracted natural gas pipeline assets located in Texas (Texas pipelines). One of the acquired pipelines is subject to a 10% noncontrolling interest. The aggregate purchase price of approximately $2 billion included approximately $934 million in cash consideration and the assumption of approximately $706 million in existing debt of the Texas pipeline business and its subsidiaries at closing and excluded post-closing working capital adjustments of approximately $2 million. The purchase price is subject to (i) a $200 million holdback payable, in whole or in part, upon satisfaction of financial performance and capital expenditure thresholds relating to planned expansion projects (contingent holdback) and (ii) a $200 million holdback retained to satisfy any indemnification obligations of the sellers through April 2017. The $200 million indemnity holdback may be reduced by up to $10 million depending on certain post-closing employee retention thresholds. If successful, NEP may spend up to an additional $100 million of capital expenditures for the planned expansion projects, bringing the total transaction size of the acquisition to approximately $2.1 billion. NEP incurred approximately $13 million in acquisition-related costs.during the year ended December 31, 2015, which are reflected in O&M expenses in NEE's consolidated statements of income. Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed on October 1, 2015 based on their estimated fair value. All fair value measurements of assets acquired and liabilities assumed, including the noncontrolling interest, were based on significant estimates and assumptions, including Level 3 inputs, which require judgment. Estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in future cash flows and future market prices. The excess of the purchase price over the estimated fair value of assets acquired and liabilities assumed was recognized as goodwill at the acquisition date. The goodwill arising from the acquisition consists largely of growth opportunities from the Texas pipeline business. Upon full settlement of the contingent holdback, all of the goodwill is expected to be deductible for income tax purposes over a 15 year period. A liability of approximately $186 million was recognized as of the acquisition date for each of the contingent holdback: and the indemnity holdback, reflecting the fair value of the expected future payments. NEP determined this fair value measurement based on management's probability assessment. The significant inputs and assumptions used in the fair value measurement included the estimated probability of executing contracts related to financial performance and capital expenditure thresholds as well as the appropriate discount rate. The valuation of the acquired net assets is subject to change as additional information related to the estimates is obtained during the measurement period. The primary areas of the purchase price allocation that are not yet finalized relate to identifiable intangible assets and residual goodwill. IFERC FORM NO. 1 (ED. 12--88) Page 123.31 Name of Respondent This Report is: (1) ~An Original (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/Q4 NOTES TO FINANCIAL STATEMENTS (Continued) ~e ~ollowin_g table summarizes the estimated fair value of assets acquired and liabilities assumed for the acquisition of the Texas p1pelme bus1ness: Amounts Recognized as of October 1, 2015 Other receivables and current other assets 21 '~~~~~;~·pth~T~~~.~~i~~~(i"!~~~~a$~~;-~~-~-~~ 1 -'.Y_~W.U!-_·arid·_.Qth~Jh,~ngibi~Jl.s~ei~J .••.-•.-••_ Noncurrent other assets !i·-· _: ·~:·•-· .-_-._·<••--~ -----~-------:_- :·:t~#\ see Note 1 -Goodwill and Other Intangible Assets) Long-term debt, including current portion $ Less non controlling interest at fair value 706 69 9. Variable Interest Entities (VIEs) As of December 31, 2015, NEE has twenty-four VIEs which it consolidates and has interests in certain other VIEs which it does not consolidate. FPL - FPL is considered the primary beneficiary of, and therefore consolidates, a VIE that is a wholly owned bankruptcy remote special purpose subsidiary that it formed in 2007 for the sole purpose of issuing storm-recovery bonds pursuant to the securitization provisions of the Florida Statutes and a financing order of the FPSC. FPL is considered the primary beneficiary because FPL has the power to direct the significant activities of the VIE, and its equity investment, which is subordinate to the bondholder's interest in the VIE, is at risk. Storm restoration costs incurred by FPL during 2005 and 2004 exceeded the amount in FPL's funded storm and property insurance reserve, resulting in a storm reserve deficiency. In 2007, the VIE issued $652 million aggregate principal amount of senior secured bonds (storm-recovery bonds), primarily for the after-tax equivalent of the total of FPL's unrecovered balance of the 2004 storm restoration costs, the 2005 storm restoration costs and to reestablish FPL's storm and property insurance reserve_ In connection with this financing, net proceeds, after debt issuance costs, to the VIE (approximately $644 million) were used to acquire the storm-recovery property, which includes the right to impose, collect and receive a storm-recovery charge from all customers receiving electric transmission or distribution service from FPL under rate schedules approved by the FPSC or under special contracts, certain other rights and interests that arise under the financing order issued by the FPSC and certain other collateral pledged by the VIE that issued the bonds. The storm-recovery bonds are payable only from and are secured by the storm-recovery property. The bondholders have no recourse to the general credit of FPL. The assets of the VIE were approximately $230 million and $279 million at December31, 2015 and 2014, respectively, and consisted primarily of storm-recovery property, which are included in securitized storm-recovery costs on NEE's and FPL's consolidated balance sheets. The liabilities of the VIE were approximately $278 million and $338 million at December 31, 2015 and 2014, respectively, and consisted primarily of storm-recovery bonds, which are included in long-term debt on NEE's and FPL's consolidated balance sheets. FPL entered into a purchased power agreement effective in 1995 with a 330 MW coal-fired facility to purchase substantially all of the facility's capacity and electrical output over a substantial portion of its estimated useful life. The facility is considered a VIE because FPL absorbs a portion of the facility's variability related to changes in the market price of coal through the price it pays per MWh IFERC FORM NO.1 {ED. 12~88) Page 123.32 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original I{2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) 2015104 I I NOTES TO FINANCIAL STATEMENTS {Continued) (energy payment). Since FPL does not control the most significant activities of the facility, incl~ding operati~ns and maintenance, ~PL is not the primary beneficiary and does not consolidate this VIE. The energy payme:nts paid by FPL fluctuate as coal pnces change. This fluctuation does not expose FPL to losses since the energy payments pa1d by FPL to the fac1hty are recovered through the fuel clause as approved by the FPSC. W'!'. NEER - NEE consolidates twenty-three NEER VIEs. NEER is considered the primary beneficiary of these _YIEs since NEER; cont~ls the most significant activities of these VIEs, including operations and maintenance, as well as construction, and through 1ts eqUity ownership has the obligation to absorb expected losses of these VIEs. A NEER VIE consolidates two entities which own and. operate natural gas/oil electric generation facilities with the capability of producing 110 MW. This VIE sells its electric output under power sales contracts to a third party, with expiration dates in 2018 and 2020. The power sales contracts provide the offtaker the ability to dispatch the facilities and require the offtaker to absorb the cost of fuel. This VIE uses third-party debt and equity to finance its operations. The debt is secured by liens against the generation facilities and the other assets of these entities. The debt holders have no recourse to the general credit of NEER for the repayment of debt. The assets and liabilities of the VIE were approximately $84 million and $47 million, respectively, at December 31, 2015 and $85 million and $55 million, respectively, at December 31, 2014, and consisted primarily of property, plant and equipment and long-term debt. Two indirect subsidiaries of NEER each contributed, to a NEP subsidiary, an approximately 50% ownership interest in three entities which own solar PV facilities that, upon completion of construction, are expected to have a total generating capacity of 277 MW, of which approximately 153 MW have been placed in service as of December 31, 2015. Each of the two indirect subsidiaries of NEER is considered a VIE since it has insufficient equity at risk, and is consolidated by NEER. The VIEs use third-party debt and equity to finance a portion of development and construction activities and require subordinated financing from NEER to complete the facility under construction. These VIEs will sell their electric output to third parties under power sales contracts with expiration dates in 2035 and 2036. The debt balances are secured by liens against the assets of the entities. The debt holders have no recourse to the general credit of NEER. The assets and liabilities of these VIEs were approximately $657 million and $626 million, respectively, at December 31, 2015, and consisted primarily of property, plant and equipment and long-term debt. The other twenty NEER VIEs consolidate several entities which own and operate wind electric generation facilities with the capability of producing a total of 5,272 MW. These VIEs sell their electric output either under power sales contracts to third parties with expiration dates ranging from 2018 through 2041 or in the spot market. The VIEs use third-party debt and/or equity to finance their operations. Certain investors that hold no equity interest in the VIEs hold differential membership interests, which give them the right to receive a portion of the economic attributes of the generation facilities, including certain tax attributes. The debt is secured by liens against the generation facilities and the other assets of these entities or by pledges of NEER's ownership interest in these entities. The debt holders have no recourse to the general credit of NEER for the repayment of debt. The assets' and liabilities of these VIEs totaled approximately $7.6 billion and $5.0 billion, respectively, at December 31,2015. Sixteen of the twenty were VIEs at December 31, 2014 and were consolidated; the assets and liabilities of those VIEs totaled approximately $6.6 billion and $4.1 billion, respectively, at December 31, 2014. At December 31, 2015 and 2014, the assets and liabilities of the VIEs consisted primarily of property, plant and equipment, deferral related to differential membership interests and long-term debt. Other- As of December 31, 2015 and 2014, several NEE subsidiaries have investments totaling approximately $602 million ($476 million at FPL) and $716 million ($606 million at FPL), respectively, in certain special purpose entities, which consisted primarily of investments in mortgage-backed securities. These investments are included in special use funds and other investments on NEE's consolidated balance sheets and in special use funds on FPL's consolidated balance sheets. As of December31, 2015, NEE subsidiaries, induding FPL, are not the primary beneficiary and therefore do not consolidate any of these entities because they do not control any of the ongoing activities of these entities, were not involved in the initial design of these entities and do not have a controlling financial interest in these entities. 10. Investments in Partnerships and Joint Ventures Certain subsidiaries of NEE, primarily NEER, have noncontrolling non-majority owned interests in various partnerships and joint ventures, essentially all of which own electric generation. facilities. At December 31, 2015 and 2014, NEE's investments in partnerships and joint ventures totaled approximately $1,063 million and $663 million, respectively, which are included in other investments on NEE's consolidated balance sheets. NEER's interest in these partnerships and joint ventures range from approximately 29% to 50%. At December 31, 2015 and 2014, the principal entities included in NEER's investments in partnerships and joint ventures were Desert Sunlight Investment Holdings, LLC, and Northeast Energy, LP, and in 2015 also included Sabal Trail Transmission, LLC and Cedar Point II Wind, LP. lFERC FORM NO.1 (ED. 12-88) Page 123.33 Name of Respondent This Report is: (1) 6; An Original I(2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 NOTES TO FINANCIAL STATEMENTS (Continued) Summarized combined information for these principal entities is as follows: 2015 2014 Partners'/members' equity "··.·::·. -:~ · :.·: -. :·' " · ···:· ~:.--:-:-:··•.,-·,·:7·:-:-•·:c:··,.,..,..-,.~':-7-:-:·:-,· ····· ~-~····-:-:·~·-:·:-.···.~·-·:::·.· ·· · :·.t:JFr;~:~~a~:.~r;~d¥;rl~~-~9~-~-~-~h~p.~r@~~-~!lt~s:·•: · Difference between investment carrying amount and underlying equity In net assets(aJ N~ER's r~v~s!~;~tc~r~g ~m~unt forth~pri~cl~~i entities (a) : ~ /::. ··• : The majori1y or the difference between the investment carrying amount and the under1ying equi1y in net assets is being amortized over the remaining life of the investee's assets. In 2004, a trust created by NEE sold $300 million of 5 7/8% preferred trust securities to the public and $9 million of common trust securities to NEE. The trust is an unconsolidated 100%-owned finance subsidiary. The proceeds from the sale of the preferred and common trust securities were used to buy 5 7/8% junior subordinated debentures maturing in March 2044 from NEECH. NEE has fully and unconditionally guaranteed the preferred trust securities and the junior subordinated debentures. 11. Common Shareholders' Equity Earnings Per Share- The reconciliation of NEE's basic and diluted earnings per share attributable to NEE from continuing operations is as follows: Years Ended December 31, 2015 2014 2013 (millions, except per share amounts) ·-~~~r~tQr/\flfd~~tfb~~6~rit\ri~;~:-~,;;~tl~n~.-~~~b~!~~~t~-N~-(a))·:~·-··. .·• .· .• · .~.;;$~::·-:~~;···2,75~ '••.$;>_•·;·::•(. ;·2.465._-·$···:~_--o?''0-1:sn-j Denominator: ···••·Yf~I~I)~d_-avera!ie~ ~urnber.ot·c9mrnori; ~~~es__~~!~~~d-~hg_i}:ia~ic ·•-· • . .4242) • Equity units, performance share awards, options, forward sale agreements and restricted stock(b) •·· ·•. 3.5 5.7 IJ!.!eig!'~~~~!r~~~- r\~hl~~r ot.c:O_mmo_nshaf~s .outstarydi'ri~ _i_i,~~~~-~~-~!l)~~ri•··.-· .• -.. ____ 2.8 -·.:.:.-)~~QJ_:·:·: ;..._ -- .......... . ...;_....__. .:.:~-427-.Cf~ Earnings per share attributable to NEE from continuing operations: ............... .... - ····-····· ~ • ).~~!<_: :cc_:-___ :. :·-·...--···· ···-····-·····-··-··-·-···-·······-··· . . - -- .... ----- ·--~-·: ______ ~$ __ Assuming dilution (a) (b) $ ~.95;· 6,06 $ 5.60 $ 3.93 Calculated as income from continuing operations less net income attributable to noncomrolling interests from NEE's consolidated statements or income. Calculated using the treasury stock method. Performance share awards are included In diluted weighted-average number of common shares outstanding based upon what would be Issued If the end of the reporting period was the end of the term or the award. Common shares issuable pursuant to equity units, the forward sale agreement described below, stock options and performance share awards and restricted stock which were not included in the denominator above due to their antidilutive effect were approximately 3.5 million, 2.6 million and 7.1 milfion for the years ended December 31, 2015, 2014 and 2013, respectively. Issuance of Common Stock and Forward Sale Agreement- In November 2013, NEE sold 4.5 million shares of its common stock at a price of $88.03 per share, and a forward counterparty borrowed and sold 6.6 million shares of NEE's common stock in connection with a forward sale agreement. In December 2014, NEE physically settled the forward sale agreement by delivering 6.6 million shares of its common stock to the forward counterparty in exchange for cash proceeds of approximately $552 million. The forward sale price used IFERC FORM NO. 1 (ED. 12-88) Page 123.34 Name of Respondent Florida Power & light Company This Report is: ( 1) 25: An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 NOTES TO FINANCIAL STATEMENTS (Continued) to determine the cash proceeds received by NEE was calculated based on the initial forward sale price of $88.03 per shar~ l~ss certain adjustments as specified in the forward sale agreement. .Prior to the settleme~t date, the forward sale agreement.had a d1lutive effect on NEE's earnings per share when the average market pnce per share of NEE s common stock was above the adjusted forward sale price per share. Common stock Dividend Restrictions - NEE's charter does not limit the dividends that may be paid on its common stock. FPL's mortgage securing FPL's first mortgage bonds cQntains provisions which, under certain conditions, restrict the payment of dividends and other distributions to NEE. These restrictions do not currently limit FPL's ability to pay dividends to NEE. Employee Stock Ownership Plan - The employee retirement savings plans of NEE include a leveraged ESOP feature. Shares of common stock held by the trust for the employee retirement savings plans (Trust) are used to provide all or a portion of the employers' matching contributions. Dividends received on all shares, along with cash contributions from the employers, are used to pay principal and interest on an ESOP loan held by a subsidiary of NEECH. Dividends on shares allocated to employee accounts and used by the Trust for debt service are replaced with shares of common stock, at prevailing market prices, in an equivalent amount. For purposes of computing basic and fully diluted earnings per share, ESOP shares that have been committed to be released are considered outstanding. ESOP-related compensation expense was approximately $63 million, $59 million and $46 million in 2015, 2014 and 2013, respectively. The related share release was based on the fair value of shares allocated to employee accounts during the period. Interest income on the ESOP loan is eliminated in consolidation. ESOP-related unearned compensation included as a reduction of common shareholders' equity at December 31, 2015 was approximately $1 million, representing unallocated shares at the original issue price. The fair value of the ESOP-related unearned compensation account using the closing price of NEE common stock at December 31, 2015 was approximately $11 million. Stock-Based Compensation- Net income for the years ended December 31, 2015, 2014 and 2013 includes approximately $60 million, $60 million and $67 million, respectively, of compensation costs and $23 million, $23 million and $26 million, respectively, of income tax benefits related to stock-based compensation arrangements. Compensation cost capitalized for the years ended December 31, 2015, 2014 and 2013 was not material. As of December31, 2015, there were approximately $70 million of unrecognized compensation costs related to nonvestedfnonexercisable stock-based compensation arrangements. These costs are expected to be recognized over a weighted-average period of 1.8 years. At December 31, 2015, approximately 17 million shares of common stock were authorized for awards to officers, employees and non-employee directors of NEE and its subsidiaries under NEE's: (a) Amended and Restated 2011 Long Term Incentive Plan, (b) 2007 Non-Employee Directors Stock Plan and (c) earlier equity compensation plans under which shares are reserved for issuance under existing grants, but no additional shares are available for grant under the earlier plans. NEE satisfies restricted stock and performance share awards by issuing new shares of its common stock or by purchasing shares of its common stock in the open market. NEE satisfies stock option exercises by issuing new shares of its common stock. NEE generally grants most of its stock-based compensation awards in the first quarter of each year. Restricted Stock and Performance Share Awards- Restricted stock typically vests within three years after the date of grant and is subject ~o, among ot~er things, restrictions on transferability prior to vesting. The fair value of restricted stock is measured based upon the closmg market pnce of NEE common stock as of the date of grant. Performance share awards are typically payable at the end of a three-year performance period if the specified performance criteria are met. The fair value of performance share awards is estimated primarily based upon the closing market price of NEE common stock as of the date of grant less the present value of expected dividends, multiplied by an estimated performance multiple which is subsequently trued up based on actual performance. IFERC FORM N0.1 (ED. 12-88) Page 123.35 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original I(2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr} II 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) The activity in restricted stock and performance share awards for the year ended December 31, 2015 was as follows: WeightedAverage Grant Date Fair Value Per Share Nonvested balance, January 1, 2015 Nonvested balance, December 31, 2015 996,227 $ 67.19 915,199 $ 81.90 The weighted-average grant date fair value per share of restricted stock granted tor the years ended December 31, 2014 and 2013 was $93.46 and $74.02 respectively. The weighted-average grant date fair value per share of performance share awards granted for the years ended December 31, 2014 and 2013 was $71.52 and $58.53, respectively. The total fair value of restricted stock and performance share awards vested was $108 million, $85 million and $82 million for the years ended December 31, 2015, 2014 and 2013, respectively. Options - Options typically vest within three years after the date of grant and have a maximum term of ten years. The exercise price of each option granted equals the closing market price of NEE common stock on the date of grant. The fair value of the options is estimated on the date of the grant using the Black-Scholes option-pricing model and based on the following assumptions: 2015 2014 2013 3.11% 3.11% 3.28-3.64% 1.84% 2.17% 1.15-1.40% L~:~!Eld.:Y!).f:uiity(_..i· Expected dividends ..... ,........ _... . •. expe~~~,~~rm· Other oomprehenslve Income (loss) before reclassifications .....,,...... -_._o_· __ o_· ~.ore_ s__.s__>_._be __·... ..___ :: -. _.. - .. ;'-:_.· ·AI~~~~;:z~h;r~~r~tm~~O$$): Less other comprehensive Joss attributable to nonoontrolllng Interests ~:~~~~;~~~~ ~-1/2Q1~~:.::~>::=?-::--~->:(a) (b) h15) . :.•·-.:•....• 97 •········ '\••197~' •. • ·.. : i• 218 ..... 7 (45) ········< (45) . 7 .,.,....,.,.,..,_,_,.,_,,_,..,.._,.,., 23 . . .....•..·····(~3)'-< "' · ..· : ··-:.~_-,. ....,_._...,-.,.... 311 -.ct~) _·>·. 5e· (44} (25) (8} (156) (20) (58) (24) (40) <··~ · . .:-··. .···'{~}). · · ·· . ··· ···' .•.:·::: . . _,·.·.· · <:._:- ·. '· _,_..... ·:.. :· ·· · .· . ·· -. :: (.zi). __ ..,.... •>{1~) .:·::.,.. ___________ 37 · .<:.:.: ;.:_~(a)·=· '·='•=· · =· =·===·-=~44==; ~,_~,.-_.-.,.....,...~.- ~-~- - ~4.2_,..r·.> ,., (11) --- ~--~---<17~; :_< -_s:.=~- 259 .- ··:.-;-·-·:-~~--=--: ''""!'~-,--·-:-.··.- ··:·· ;; ._._•._.•_-.·-•.· -• -.•'·.·•.·.• ·_._·._·.'·_·. _·._:_·_·_..· ·_-.'•. ..·.• ····. ·· • '··::••''"··· · . ·.:. .... (7) > ·. 88'I - •_._·•·.···--·····c··_: •..•._•._{•·.-· .....;_:...:-c--'--·-.... ~.--~<;·::s· ~~:::-> .. -.; ..... - Total ·······;·2:c.':: ., .·., Y : ..... ,_. \':::· '.s.::< .>52 101 . (156) -~li:oa. ·~ ~~2~0Tisl 0sve illeClm.~.. -~--:-------~:·-~·-:-:-.-:-·:·:·: HiJ·j~Ji·····.•. (141) Balances, December 31, 2014 - \ . . . .. .. ..... ·. Translation 95 118 ·.. :·-.: :. '· ._.jArnov~ilj,$~i!s_s~r~m·A.qc!:<<·· ··· ,.·.· · .· . ·.·······.···· <'i Other Comprehensive Income (Loss) Related to Equity Method lnvestee Net Unrealized Gains (Losses) on Foreign Currency Defined Benefit Pension and Other Benefits Plans , ···· 'i<.2n _ . :. :... ...:· ~"'-Cl·---:(..,._1·"'::..,i (11) :::_ ...:·..... --. --:'174- ____ .-.-_ ......:. _;>; . . (6.-ij . ~.-~ ------ ; . --- <~(85)_~;~--:_>.":::-:· . _. . . . -. .· . -~--~ .;:(:Z4,.,:i(eJ : Other long-tenm debt- primarily varlable{c)(o) . 20 24 2017-2038 2,203 5.88 '¥. 2,273 . '·. '201~ ~ 203S· 6.02% ..... --: .•. 3.12% 2015-2035 3.71% 2.~3~ ca.r;.~dia:n (BvOt~in.~ i;(e?it flle;nue$ ;·viiabia(•> · · Unamortized debt issuance costs and discoun.t · ': Jo.tai JOniJ:.!.;t;n !iE.biOr ~fi:eR·: : · 1,4119 Less current maturities of long-tenm debt(h) 1,668 ·... -..5-~:;~~ cif~effi,.exci~Jng c~~ ~~tu;ltie~ .... Total long-term debt (a) (b) (c) (d) (e) (f) (g) (h) $ 26,681 $ 24,044 Principal en the storm-recovery bonds is due on the final maturity dale (the date by which the principal must be repaid to prevent a default) for each tranche, however, it is being paid semiannually and sequentially. Tax exempt bonds that pennit individual bond holders to tender the bonds for purchase at any time prior to maturity. In the event bonds are tendered for purchase, they would be remarketed by a designated ramarl'(1) Accretion expense ··.·: (1) . ·.:.····. .... ·... , .'":·.:·~:.:- ·... :·.: . ··- ..·:_::><. :)·~·~.:·. (1~1 1,355 631 1,986 73 43 116 : ••Liabilities ~etUed ·•. < •Revision in estimated cash flows- net (a) (b) Primarily reflects the effect of revised cost estimates for decommissioning FPL's nuclear units consistent with the updated nuclear decommissioning studies filed with the FPSC in December2015. Primarily reflects the effect of revised cost estimates for decommissioning NEER"s nuclear units and a change in assumptions relating to spent fuel costs, partly offset by increased escalation rates_ IFERC FORM N0.1 (ED. 12-88) Page 123.41 Name of Respondent This Report is: (1) ~An Original .(2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) Restricted funds for the payment of future expenditures to decommission NEE's and FPL's nuclear units included in special use funds on NEE's and FPL's consolidated balance sheets are as follows (see Note 4- Special Use Funds): FPL NEE NEER (millions) Balances, December 31, 2014 3,449 $ $ 1,642 $ 5,091 NEE and FPL have identified but not recognized ARO liabilities related to electric transmission and distribution and telecommunications assets resulting from easements over property not owned by NEE or FPL These easements are generally perpetual and only require retirement action upon abandonment or cessation of use of the property or facility for its specified purpose. The ARO liability is not estimable for such easements as NEE and FPL intend to use these properties indefinitely. In the event NEE and FPL decide to abandon or cease the use of a particular easement, an ARO liability would be recorded at that time. 14. Commitments and Contingencies Commitments - NEE and its subsidiaries have made commitments in connection with a portion of their projected capital expenditures. Capital expenditures at FPL include, among other things, the cost for construction or acquisition of additional facilities and equipment to meet customer demand, as well as capital improvements to and maintenance of existing facilities and the procurement of nuclear fuel. At NEER, capital expenditures include, among other things, the cost, including capitalized interest, for construction and development of wind and solar projects and the procurement of nuclear fuel, as well as the investment in the development and construction of its natural gas pipeline assets. Capital expenditures for Corporate and Other primarily include the cost to meet customer-specific requirements and maintain the fiber-optic network for the fiber-optic telecommunications business (FPL FiberNet) and the cost to maintain existing transmission facilities at NextEra Energy Transm"tssion, LLC. At December 31, 2015, estimated capital expenditures for 2016 through 2020 for which applicable internal approvals (and also FPSC approvals for FPL, if required) have been received were as follows: 2016 2017 2019 2018 2020 Total Generation: (a) 620 Existing Nuclear fuel : ·;;~~j~~~~:it;;~;:;-- .. . ' .. . :. ' 170 ~ ·.: ~ .. . . . ... .: ·. :·-. $ Total ,-~~~~~~~-~~ptl'!ltn~\1) 496 ·.. •,$ Corporate and Other (a) (b) (c) (d) (e) (f) s 170 ~·2..0.<: '3,095 240 .. ,:;··:...:,40 ·' Other : 75 $ 840 $ $ 160 $ 115 $ $ $ :.10;72~ 865 >1:i2o 17,170 1,385 745 65 .-42ll •$ 140 .>: .-··. 265 50 1,125 ' <1lls· 3,280 310 '-·s,oss ·..• $_ 215 210 -, -. <.' >•·c~B~ . $ 270 60 3,330 550 ' 2,335 .• • 190 .•....•.·,, 265,: $ 300 Nuclear, including nuclear filet , 4,050 .. - '· .1,9~5 125 -·•:·,illlsT:········ 520 680 960 ···1,\lllO..'. 370 $, 7,eso: 135 $ 765 Includes AFUDC of approximately $76 million, $14 million and $11 million for 2016 through 2018, respectively. Includes land. generation stNct..-es, transmission interconnection and integration and licensing. Excludes capital expendiltres of approximately $1.0 billion for the natural gas-flred combined-cycle un~ in Of . $ 1t~{$ ~;4# . i <3s{') tf;4s$ . . $_11~~2\);~\K19~ ;$ :404 $:1i,p2i $ 'lb,;qs ._$ 4,3s3 .if a.s~ .i-15.1;,63 Operating expenses(b) •..'·1·n·_•t,'e·_•_-_•_·._.·_·$·.·_. t._.·.......··..,..'·.·.'.'._. n. ._s·.·~. -.·.'<.> , . -.; ' . '" """~ "' "' • ; ·. FPL NEERC•> -~---11_~67_4__$___ ~8.~.~ $ 315 $ 12,854 ~-- ~~~~~---~-. 3,727 $ 317 ~ }~~6-~!-, $ 7,~06 $ 3,730 $ ~-~9 ~ _]~·895 '$·. ·.::'.i·,.:•:··.-:::..• :$_,,,:•'>'c·6·.·.2:•:5:·.•:: $..... ·_:_:.·.1'....:4·1·.•_;_ ;.;,; : ·.·.·_,.-,_··.1·5 ..._.:_:,•_:_;:_• •.·.:: '5·•.·.28.·. •·•· :._$· ':.· 1.7.8__ ;__:_·$·.·. :.·,·:.'_·1: ,1..2.__1., .. •o:c~.S.:.: :::::"' , . · -. .. _.'1·_'_,·2·.-...1·_1····...•·. $·.·. -'.• .:_·-~.-~9·.··.· ..~ .•.··._.a,,· ,._ _.:_·: "~.·_.6:•7·.· .··'_.•$,··. •.·.:·_:1_.: 5·5·.· .:-:..."',•.:•::1 .• •~'!.':.:-.._ . _,__...... "· ·_.·$· ... : Interest income 7 $ $ 28 $ '.$·_...• _:. .:.·••. $ 51 86 $ 3 o~l'~i:J~vtiri.1~~-~~~rk~11~ii\. .- 1,576), .1,1~~-~~-· .:'ii i · "t831 $ \;~~ $ Equity in eamlngs (losses) of equity method lnvestees $ $ 103 $ _ $ 4 $ 26 $ $ 107 $ 51 t;q~j__ ).· 80 $ $ 6 $ .68 95 $ 19 $ 53 $ 26 $ {1) $ 25 (12) $ 1,677 78 :~(-'~5~1' $.~1:1s~ i -'~49 ) cos:~ _z.,_ea: . - .. --c.·· ..,~-: :-:• ·~·· :.· ···" . ·. (2) $ 93 $ ·· ..·.. ·. •:. $ . ··~~~·~·~~~<~~~~ij(~J(~--:·-;··\--~;?$. ~C.:iag·· s .-:{,8>,'$ .>1·;·~--;,.·:. $jri":~·; Y£sa·-· ~i: d~;~--~.~-;~-I; ·-~; $. . .. ·.. • ... ·: ;::w~f-~•-t1~~•---~·}~·;z;:; Income (loss) from continuing $ operatlons(d) 'c:;~lliri;rt;'cii~~iiPJed~~ik)iiL.•:·· netQfJncornet~~{e)' >:; ..... 1,~~~ _! · .· · · · · . . ~~-102 $ :'$. ::·:-:;.:{ 2,762 $ _1,~17_ ..S.. 12 $ ·· · .. ._;:'$.· :;:..;.. $ :c •. C \_:i •993, (41) $ $ 2,469 $ 1,349 $ ····<· ( . . ~ . -" . . . . . ,. . $... •;,_:.;; $.•. ·••··.··,·...:.;;._• .$.' (-•;·.$ · .· .:•:,;.;,. $ ·•··········· . .. . ·.. Net income (loss) attributable to 340 $ .·: . . . ~;' ... ·$._'··••-• 21.6 . . : -~; ·.: .: : . :- :·:: :. ::.: :.::i $> •1s::~ :'•:j31· 989 $ NEE(d) $ _1,~411 $ 1,09~-- ~-----12 __ ~---- ~,7~2 $ 1,517 $ (41) $ 2,465 $ 1,349 $ 556 $ 3 $ 1,908 · c~italllxp~ndlt~~;1~~p~d;;~L}'.' :·•• .·-:··~-~~~-, 1 0 ·, ':.'·_._Pa._._!lW91:n_n.·.._'.d,· .•.. .·_...rl_.p_._,_ ur . _ves_...... _··.,·_ .. en_e-,·_·s·_· l$:·_· .• ·.·.·.,··_.·$·_.·.·..··.•.·,·.•3··,·6·.·;1·:3:·_·.·_·$.·. ·_.•·.•·.•_..,_·.·'•s'_·6'·_1· _.: $··_: _ -.·.·. ·.•.·,83... · $., '8 377:·:· '·$-' ·3···2•4•-1 ,::_. 7.. 5.. ·c :··r·· ;·.$: - ;,;•a··a·2· · """"' '"" ~'1"> . .., '. :... _,_.· ... :•· "'.i .. .,_;··:_._,.<.:<>•:.:,.y·., ... •.·• .. ,·.,..,,.:·.. o. . . •.:·· •. :•,.,""'!,:....:-",,•··•.,·:· ...,·, ...:.·:.'Lc.:.:·~·!;,.... ,. . , ·_.u•,_:. ._·_.rid_-.·,~· r_.· .~·.·.·.e.· c·· .:.... ·.· t·.~m.~ . . .. ,, Property, plant and equi~~:~...... ~--~.~8~- $ 33,34?. $}~~D7 $ : · ·· ~-:•$·.:, ~7·:-·o~<'$·:· ~~,178 8D,330 $ 41,938, $ $ ..-. ... · : ·:.: :: ' . ,-, . . ·. .....•,-, --. ·.--.··:--.. _, .. ··.·. 'o'·1.:7·····.·····$·.~:·;~.;.,~· ~-$· _3;·:6:·~3··:::-:$···.-·,·:.··1···6·.··•6 1,5~~--~_!~.~~9 $ 39,896 $ 28,081 $ 1,471___ $_~~.~~ ·"1~~;~~~~~~~~~~~0!" ~:;;.-\ 1:1,s~~: i$··,.~2-~x:f~~-i.i-~1~.~- · ·~ ,{~~ $•:.as.3.$c: $2,535 $ 69,007 ·o-· >: <. · · ,:;.$:.<·?as:·$ s•L:$.::42_2_ '•: .. , ·· Interest expense allocated from NEECH Is based on a deemed capital structure of70% debt. For this purpose, the deferred credit associated wfih differential membership interests sold by NEER subsidiaries is Included with debt Residual NEECH corporate interest expense is included in Corporate and Other. NEER includes an impairment charge of $300 million in 2013 related to the Spain solar projects. See Note 4 - Nonrecurring Fair Value Measurements. NEER Includes PTCs that were recognized based on Its tax sharing agreement with NEE. See Note 1 -Income Taxes. NEER Includes after-tax charges of $342 million in 2013 associated with the impairment of the Spain solar projects. See Note 4- Nonrecurring Fair Value Measurements. See Note 6. Reflects reclassificatiOil of debt Issuance costs of $324 million ($85 million for FPL) in 2014 and $298 million ($68 million for FPL) In 2013. See Note 1 -Debt Issuance Costs. 16. Summarized Financial Information of NEECH NEECH, a 100% owned subsidiary of NEE, provides funding for, and holds ownership interests in, NEE's operating subsidiaries other than FPL. NEECH's debentures and junior subordinated debentures including those that were registered pursuant to the Securities Act of 1933, as amended, are fully and unconditionally guaranteed by NEE. Condensed consolidating financial information is as follows: \FERC FORM N0.1 (ED. 12~88) Page 123.46 Name of Respondent This Report fs: ( 1) .2\; An Original (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) Condensed Consolidating Statements of Income Year Ended Year Ended Year Ended December 31, 2015 December31, 2014 December 31,2013 NEE NEE NEE (Guarantor) NEE Consoli· dated (Guaran- NEE Consolidated NEE (Guaran- Consoli- NEECH .,-.. ,-.,.,,. :· .. ,... ". ·:··-·.· ··.• ~ -~~i!OO""li~Je$_:,- _,_-·$ Equity in earnings of subsidiaries . . .. . . .. (2,754) ;_;_,_;.;..;.;__. 2,734 .·· .·· _·~~-~ftt>_G7" _f"~; -·---0 Net income (loss) attributableloNEE (a} $ ·- -· 1,441 (185) -(1~J-i- ,. :.·:··· 2,494 -·::· " .. -::-::.-:·-:-·.-:-:-~;~:-:···---:-;-.--.-.--.--~-. ~-.,...,--; ~~"':":-·-,..··--:-.·:··:·-·:-·-: .. ·:':-.:···. : > (2,494) -~ .•. 3,990 2,470 ... -..-. •:•:•·:·· .. 1,243 -•-:--co- 1,915 (1,915) --:8;:·_._:_ ____ ~;( r:;;-;~i~-: · .· · :o2~-- ----··-·... .. -~-:-----·----::-~:---.:---,., dated NEECH $ ··-··•<<•)i:~;6~4\•~•:1i;.4or•J;J?.._4_.79~--~.}~~<~·1_s.,1~.J · -· . <. 1..----·----·· ··4~~~-"-----,.~~:-:-·:; ~~9<\ -·--· Income from continuing operations before income taxes - . tax'. ----:--~"':" .--;--~~··:,- tor) Other(a) (millions) ... 2,754 ;-?:~ti~~-~ti~~l>-:-~, I NEECH Other( a) ;;..._.··•·¥- ~~&<~~---·- f_11,637Li~i.48&•· .---·· tor) ··· (68) . 3,645 ----,--.""·-.~.::·-··· ---·-·-· 1,891 . :~:~:'._'{ :·;i~:/--:-··· ~i4·· .,. __ ·-·--· ' 296 267 ·· ·· · · ···· · zga·•---~.--. · .1.228•:_•·_.-:______s..;,.;'::-_::_••-•.:_~~_6_~, _, rio9 ::,~:1.17&'·\-> < (~'\··(55}'_:_ 2,752 $ 1,132 $ (1,132) $ 2,752 $ 2,465 $ 977 $ (977) $ 2,465 $ 1,908 $ 567 $ 2,454 :-:-:.:·•;:::.):' - ~ ;· . ~1fi: (567) $ 1,908 Represents FPL and consolidaUng adjustments. Condensed Consolidating Statements of Comprehensive Income Year Ended Year Ended Year Ended December 31, 2015 December 31,2014 December 31, 2013 NEE NEE Consoli- (Guarantor) NEE NEE (Guaran- Con sol~ tor) NEECH Other<•l dated dated NEECH ;c~mp~tie~~~v~ : _. •. .................. :- ;_tn:~~jr;-.- ~<~_;_,;.;:;;~ · ' . .(12) _ ·_;_:·{~.64"_~0-·> --~-~-t_ij_•:;_r_-~-~:-::--·0;-·;;~)-:..,_..;........;:..;...:. '---'.;;;.. ·;;.;'-'-;....._.;. .;;.;......;.....:.....:. ·;;:..;.o..;;;.c_.:.;:.,.;;..;. ••. •··•· ··.- .., ;·.-·---· 546 25 571 4 2,443 1,512 3,959 823 7,790 5,685 14,298 23,472 $ 40,143 . ::: :_:.:.::. ~ : '.: .. . 562 15 577 19 2,512 1,677 4,208 736 5,827 5,393 11,956 20,555 $ 35,313 i' • •·_·.;_· . ·.· Other OTHER ASSETS Other }_ :-_ ".:r~J.qjl\~~-~--:_ . ······ $ TOTAL ASSETS ' CAP.lTALlZATION - .. : . ... :.,· --.: :;: '_: ·: ·..:··. ~-. -~-.·.. ;_:~_: ..·-. ·~. ·:· ~ __·_ _;__ ._.• .. .....: _,, · ·· --_, TotalCe.pitallzaHc;>ri: · ···'· 18,864 $ 82,479 $ 18,737 $ $ 74,605 .. . . '· :-..: .. .., ;.-::·,. :. .. ·.:. .. . ·. ·.:·_."_.\.··-: Long-term debt ·:::"·"" $ 16,725 9,956 26,681 1,919 606 2,529 647 1,822 2,469 5,139 4,659 10,283 14,715 9,329 24,044 739 586 1,354 631 1,355 1,986 ... ·.··· ~~.:~:~- ~; _ CURRENT LIABILITtES 4 Accounts payable . ·-· . ;·:~ ._:_:;:- .... . ,:·.:,::: · Other:> · · · 29 _:.::::··. . . . . . . ..... Total current liabilities ·-:!··, .... :..;··. ·. .:..· .•. ·. .OTHE~-~IJ>,~Ilt~!~S-~~~ I)EFER~O CREDITS. · Asset retirement obligations - ----··-·-· ......... ,.. other 485 308 4,317 ................ 4,858 .... .,.....,..,...,.,.9,483 ........ ,....,..~ , : ~·-Totelo!herfl~ilitiesanC! defer~ed~dltS 13,75_5 COMMITMENTS AND CONTINGENCIES (a) Represents FPL and consolidating adjus\ments. \FERC FORM N0.1 (ED. 12-88) Page 123.48 -' 'n,s79 : _ 4.:>7. :_ : :7,656 . 12,1t1 .. ~ •2o,73o Date of Report Year/Period of Report (Mo, Oa, Yr) This Report is: (1) 2S. An Original A Resubmission (2) Name of Respondent Florida Power & Light Company I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) Condensed Consolidating Statements of Cash Flows Year Ended Year Ended Year Ended December 31, 2015 December 31,2014 December 31, 2013 NEE {Guar- NEE Consolidated antor) . :··· :··· . . •.·.-_'·...· ·. _.·, ·•. o···p_._E_· ".·.·_·._·n· .._·_·N__. G,_..,·AC-._._·._T· ·. •..·"..-'ITI._.·E·_··s··_._·.••·, ·,_._.-~.·_,.,· _.•. :. _· ..._··.'.'.·. •-_.•. _·,._·.·_:_c_'1",·'~.'s··ft_·:··._,·_:·s· "" •• Consoli- anlor) dated NEE (Guarantor) NEE Consolidated - - - - - - ---------------- ------- ---- --(millions) Othe,ia) NEECH NEiCASH.PRovroeo.SY.~>-,··. NEE NEE (Guar- • ....... ··· · · .•.'.:,:__._..2.·_··:4.:_-·a._'a,•·• Otheri•J NEECH NEECH Other(•) ·· ··.·- - -._.-. . .-;-.~-:-.:·-------------------:-.:--:-:~:;··.-:::::.:·:::.-.-~--~:-:-:·_::·~·::. . -.·.: ,_._ ··:::<::.'::.:.:::.:··.. ":·"'7 ••...•. · · .-- ········.·.:,·· :-:.·--.:.: $ :· ..:.·.·...·11~··~·:~--~:$''5.500•_$_::1,147;~::1."'-'6 · ·.: ·.... ··•··· '· · ._,._ . . · · ':•:::• · ····... ,... , :- · ,._.,. ,.,.,_,.._, . ,., .._,,, ... ·" '· ·' · ·. ·.·.·.-~ · · .,, ..· :··$· . . . . "ae' -$ ··.'··s'· .:·,··,~:, ' .~.·9_·.·.:.• .. ·~~ _·...._.. ·.·.·.·_•_·:_'·.·.·_•_,:9· . ... ... CASH FLOWS FROM INVESTING ACTIVITIES Sale of independent power and other investments of NEER 52 52 307 307 165 165 Proceeds from the sale of a nonoontroliing interest in subsidiaries 345 Net cash used 1n investing {1,480) acfivities ...._.... ,... ············-.---.· • CASH FlOWS fflOM FINANCING . . · .,o,cnvr:nes · · _ (2,766) {903) (8,005) ..... ~-- .:.:._ ..:;.:< (777) (6,361) (813) '• -~·.- - .. -,···-:·:-:""-;-~.:--- :_-3_1_8_····.· •.•. ,_. 997 5,054 {4,395) · · ..:7(~5$}:: 761 •.. ·..-...- - :~f ••·•: ::-{1sr . . (3,181) .... -.. ·=:-::: --:-.:~>~-~--~- . <.:...._:..:._=_:_:: __=__._ -_::. 4,057 >- · .-.:. ··- : (~.421) ·.. >>:paper:···: :. :_· . (2.692) -.• ·.· ·=·· 4,689 Retirements of notes payable ...... . .. -. _, .. -.................... -.. ,. t-le!t:hanilel.ri~Tfl;ef:clal :_ ..... - ...''... {329) ,;.;::·.(~2J·.•·, (2,165) ~-----_.--_.-.-.. :·~--~-~;··:::, . . {· Proceeds from differential membership investors , (2,222) (4,303) ;'>''(73): - · ·· · Issuances of long-term debt ··· '· •: il.~tinirnentst>fl<;n_g-ter.rn deli! 438 438 1o · ·-·' .'_>_t:._/_IJ_ar - -- i24l. · ·• 761 978 (813) (500) -::· ····-··-·-··-·······-· ·!·~.-~_8_6_·.,· •._.~. ·:{;6_.8)·:_' .·...... . '(~}$)): 3,874 ...... . ... - .. ·.. (1,943) 978 (500) ... ·c·::·:::·<::·:~: ... ' . . . ·--~~~-~-- ...... :~1< >0•~ •• <41i7l -·· ·- 1: (6,123) _ ...-..:_-..>.. ·,. _···./.::! ~-~-~--Y·::·-·. . .·-.-:~:=:·:... ~ 497 4,371 ·~-· ~. -,453) •.•.• \2.396): 448 448 (200) (200) -··- -·-~·-- .-~··--:~--~-i;~-~-~T~::~:::~~--- ~ {619) ·:~~ .. ··.·.; (5?0)! Issuances of common stock: - 1,298 net ··-··----····---·- .. -·-··-···· --·--·--· --·. 1,298 ,c ::·:_~· ·~·.-o~~~c• iin'C!i>T"'~ •!~_:':, -~1~3il~)···· .··• Dividends to NEE . -. i1,l85). (698) ' - •. •.other•net _·,·.· _ ~~-- --:-.·~-Net cash provided by (used in)llnancing activities :f'l~.:.,~~=\'r~-~~~d. 698 •;::-(~zr•:.:'(i&i} ,------·~19 (179) 1,799 633 633 812 ---,.,,12$> · 263 842 1,883 (812) '•s77•$· ·c~;E!t~i1t~r :·.-.-:-·-·-· -· ---·-·-· -·---- _____ ..............,__________ 562 16 677 -~----·.-. (a) (502) 'bos1 ·:~ :'· {~ii-~-.-.,,-ii16i~o:-·•:c:z;~ 1,846 (344) ·..· ·i29aJ) 1,130 -~;_.~- "~,is!_:. __ .-1\l·---;~-,-144- :_•t~:·-1a~-····· <2>:: ·•1a~ __-..•_._-.• _-.••-J-.~----·····•-1~; Cash and cash equivalents at beginning of year .. 842 <_{1i2$1). -· --· ':26-_$··.·~1-,-~ '•~i·'ss2 Represents FPL and consolidating aqustments, IFERC FORM NO, 1 (ED.12-88) 438 418 .. Page 123.49 .. .. .. 2 . . ..·-··:- ..-.--·~: 287 40 329 ··~-~-~ -- _:....,,$.>41e.·s::-.·~.s·::~i Date of Report Year/Period of Report (Mo, Da, Yr) This Report is: ( 1) ~ An Original (2) A Resubmisslon Name of Respondent Florida Power & Light Company I I 2015/04 NOTES TO FINANCIAL STATEMENTS (Continued) 17. Quarterly Data (Unaudited) Condensed consolidated quarterly financial information is as follows: June 30(a) March 31(8 ) December 31(a) September 3Q(a) (millions, except per share amounts) NEE: 2015 ..,., ... ,.,, . .,.....,.,~~..,..,-.-.~ ...~ .. ,-,,,-..,.. ,-, . .~,.,-....., •..7···c··-··c··••···.·· ....,.,_,~~-,_...,.,.,...,,....,.,..,...,.,~ :~f"~tiriJiJ~v~@~s~l{ i <.·<. :'· . .... ·•. > ,, '$ < Net Income attributable to NEE(b) ·.:··.·.·,:..:·:: . •.·.·•···. ·MD4- ·--·-·- . - ·i;a't~i~s:p~r~Mie aWJ1)~~1e_ti?_NE§ •/b~~i~:~c~ .. ···--- .... ·•.· · $: >· ······<·1:47 --···-··---· ·. : . . < · · ·; · · .·,. $ · ·· .... High-low common stock sales prices ~------....- ~~ -~---~... Operating income(b) Net income attributable to NEE(b) '•••,-•,·-;:-•,-,, .. ,.w;:"",oO' ' ••", ..•" '~ .. :·•,',', :.Eatfilr~s, p~Jj~~r~ ~r~~~~lf:)o)~ee=;,.\J~Ip:l~),.. . ......... ..... , -~·:·:.-~ ::._-:-~:-.; :-~---=--:·:--·--:· · ~hlid.eri.ds·p~r.s~#~e •- ':"""""'"":-",'";'"'':': < ~ _> ~ :.;:~''" : ... . . '· .. ·:- . $109.98-$93.74 ·-o.77o.: $105.85-$95.84 ... . ..... .. , 738 $ 951 $ 1,163 $ $ 430$ 492$ 660 $ --·: . . ·.·. .:1:$2 .•1,1.3 . •$ 1 12 $ 0.98 $ ·. ;_·: 1.10 .. _, __ _.......... _ ......... .. 'M74 ;$ . . . _, .- . 4.029) • -·. 'A.ii'S4 $>' __ ,._. ' .· "·........ . '1.11); : .. ··.·. ·_ ...~: 1.93 $ $ . .. ----· -----------·- ----- 507 . -~--------········--·-·····-·-·:··.····,·-''···· $106.63-$97.23 $·''· ' \ i:J.'99 $ >·-.:~ .. <1.~1:$•·······. 879 $ :~:- :~~1_~:~ :-,~~:·$_.:}-_:_:. 1.59 $ ...... < ,. Earnings per share attributable to NEE • assuming dilution:(c) $ -·-·:-·.---,,-_ .. _...... ,. ··--- ·., ·. ·······o;rto )/_ . _·_._· . . . (),7JQ,$•· •· ·••· . ·:.oJfr4.~~ 1,532 884 ... '· ~~Q3~ $ 1.50 $ 2.00 . .... ·. •< :- _$ .. · '• ·: • 0.725 ~i. High-low common stock sales prices $96.13-$83.97 $102.51-$93.28 $102.46-$91.79 $110.84-$90.33 FPL: 2015 ..,.,, . .......... ' ...... . ··::·$': ·. · 2,s41 i$ .. - :'': •.2.9~:_) ---·"::"·,,...~ . ..,.,.,..,-,-."'C""' .. ~·---··"'·'""'·.,.,,,...=""~~..,...,.~..,...,..,.,...,.___,..___,..,.,.,., ~. ·o~~r~th;~}~~~-n~e$tw· ·• :_ • · .·. · .....· · ····· Operating income(b) ' Net.)ribalT1~·."'' ,- -·. r- - - I ~ -~ " --- - - -- ~ - - -· - - - r - - --'- ----- - - • - - --~~-< .. ----- - - - - ---- . "~-- - co•• - -----=---~~- . - - - •••• , - - ---- -~- --- -- -:;. . ;:,. - 750 _,.,....--------' e_ - ·- --.,..-~,. - ---~--~-~·--' ~ FERC FORM NO.1 (REV.12-05) '-" <> - -·-~-- <'r-r----- - -~~-~-.--- - - - ~~ c Page ---~-'"' > ~ • 206 -" -- ------- --- .. I ~-,.-.~,.....,.---~--------~--.-- • - • ---~• -·~ Name Florida Power & Light Company [ FERC FORM NO. 1 (REV. 12-05) 2015/04 End of Page 206 - -- - -·- " -- "" - -__ - - --- -- --- - -- - YearlPeriod of Report End of 2015104 dent Re ort ls: Date of . of espon . [?lm Original (Mo, Da. r) Flonda Power Company A Resubmission 457 195 475.773 541 325 409 997 470 905 997 470 905 FERC FORM N0. 1 (REV. 12-05} ELECTRIC PLANT 1N SERVICE Page 101 1 207 103 and 1 at End Year 417 765 181 138 91.266 829 1 700,009 1 695 1 4 602,016 086 066 Name of Respondent This Report is: (1) ~An Original (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/Q4 FOOTNOTE DATA f§chedule-Page: 2o4 uneNc;::s-coiiiiiiii:·-g-...···· Schedule No. 317 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. [Schedule-Page: 204 Line No.: {5--coliimil:·g·----------------------------, Schedule No. 317 formula rate utilizes the simple average ending balances) for all rate base inputs. balances (average beginning and Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. ~--::"'-o--=-----::--=:-:---::-o----:----:--,---:--:,--=.._--=.--=-:=---------·-·--·-···-········-··-- r::[ s:S-=c~h-=-ed""u::.:l;,::::e..c.P-::a,..gc::e.:....:~20:;;-4';:;----=L""'i.:..:n-=-e-'-:N:=o.:~~ ColumiJ.;_jJ ___ ··---.-,.------;---;-----.-----,-----.---,-----c-' Schedule No. 317 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. r - - - - " - - . , . . - - - - - ' - - ' - - - - - - - - ' - - - - - ' - - ' . - - - - " - - ' - " - - - - - - - - - - - - - · - · - - ·--------······---····--- ISchedufe Page: 204 Line No.: 44 Column: g .. ·-·---·--- -----=---=------,-------,---,----:------:--' Schedule No. 317 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all ~Cite b~~-E:!---~-I1P1lt:s..c.._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ fSchedule Page:_ 204 Line No.: 46 Column: g Schedule No. 317 formula rate utilizes the simple average :balances'"(average beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances ending balances) for all rate base inputs. !Schedule Page: 204 Line No.: 57 J (average beginning and Colu_f!J._f!_;JL __ . Schedule No. 317 formula rate utilizes the simple average balances ending balances) for all rate base inputs. (average beginning and Schedule No. 322 formula rate utilizes the simple average balances (average beginning and end~ balances) for all rate base inputs. [SCireduie. Page: 20.4 Line No.: 58 ·-··caii.miii:-g - - - - - - - - - - - - - - - - - - - - - - - - ·-·--····· ------------··- Schedule No . 31--o7o:--f""o_r_m_u""'l_a_r_a-:t-e_u_t:-l.,-,l"'"i-z"'"'e...s--:-t'h_e_s-.im-p""'l_e_a_v_e_r_a_g_e_ EaTances (average beg inning and ending balances) for all rate base inputs. Schedule No. 322 ending balances) ~.£heduJ'! Page: 204 Schedule No. 317 ending balances) formula rate utilizes the simple average balances (average beginning and for all rate base inputs: .... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - · - - - - , Line No· 74 Co/umn·_g_ formuTa~···rafe .. utilries the simple average balances -(aver-age.. 'f)eginning and for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. ~-·.- -----·······- -··-·----------· ..... ····-··---·-- --·--·· --:::---,-----'~------------...........--··-····---·-·-·····---------, ;Schedule Page: 204 Line No.: 75 -,-c;-----.-----.--.--.---~ Column: g Schedule No. 317 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. [$chedu/e Page: 204 Line No.: 86~!E!E!!.:..9.. .....cc---.--~-----,---=------:-- ·---·--··---------·----] Schedule No. 317 formula rate utilizes the simple average balances (average beginning and IFERC FORM N0.1 (ED. 12-87) Page450.1 Name of Respondent Florida Power & Light Company This Report is: {1) ~An Original I (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) 2015/Q4 I I FOOTNOTE DATA ending balances) for all rate base inputs. Schedule No. 322 formula rate ending balances) for all rate ~chedule Pafl_e: 204 -··· Line No.: 87 Schedule No. 317 formula rate ending balances) for all rate utilizes the simple average balances (average beginning and base inputs. Column: g utilizes the simple average balances (average beginning and base inputs. formula rate for all rate Line No.: 88 formula rate for all rate utilizes the simple average balances (average beginning and base inputs. Column: g utilizes the simple average balances (average beginning and base inputs. Schedule No. 322 ending balances) ~chedu/e Pag_e: 2£!1 Schedule No. 317 ending balances} Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances} for all rate base inputs. !Schedule Page: 204-- :.:N:.:::o:.__.:-=B-=9-=-=--c==-o=-I=-u=-m_:n::..::c:fg::....=..:=-:______________ Line Schedule No. 317 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. ~che~~ P~e: _2._D_4____ Lin:..::e=-;.N-=o:..::.:...::9-=0,---=C-=o.:.:;lu:,:.m:.;:n:..::::...;g;z__:-;-_-,----=-_ _ _ _- - . - - . . , - - - - - - , - - - - - ; - - - , - - - - . - - - - , - J Schedule No. 317 formula rate utilizes the simple average balances (average beginning and ending balances} for all rate base inputs. Schedule No. 322 ending balances) ~chedu/e Page: 204 Schedule No. 317 ending balances) formula rate utilizes the simple average balances (average beginning and for ~-~. :J. ..E~.t:.E?. ~Cl:~~- in_E_!1ts. _____ ___ _____ __ _______ __ __ ····-··--·-···-----··- __ . ···-] Line No.: 91 Column: g formula rate utilizes the simple average balances (average beginning and for all rate base inputs. Schedule No. 322 ending balances) !Schedule Page: 204 Schedule No. 317 ending balances} formula rate for all rate Line No.: 92 formula rate for all rate utilizes the simple average balances (average beginning and base inputs. _________ _______ ______ CoiU!fln:_fl.__ _ utilizes the simple average balances (average beginning and base inputs. Schedule No. 322 ending balances) i§Ci!Jedule Pa~: 204 Schedule No. 317 ending balances) formula rate for all rate Line No.: 93 formula rate for all rate utilizes the simple average balances (average beginning and base inputs. Column: g utilizes the simple average balances (average beginning and base inputs. Schedule No. 322 ending balances) Wctiedute Page: 204 Schedule No. 317 ending balances} formula rate utilizes the simple average balances (average beginning and for all rate base inputs. L~tJ_e}'!C!~:_~~--s;._~tumn: g .... ______________________ ...... . .. formula rate utilizes the simple average balances ·Taverage beginning arid for all rate base inputs. Schedule No. 322 ending balances) [§chedule Page: 204 Schedule No. 317 ending balances) formula rate utilizes the simple average balances (average beginning and for a~~--~!:-~--~~-s-~___i_!l:P\l.~_s_:___________________________ _ Line No.: 95 Column: g formula rate utilizes the simple average balances (average beginning and for all rate base inputs. , ,,.,, __ , -~ J Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. IFERC FORM N0.1 (ED. 12-87) Page 450.2 Name of Respondent Florida Power & Light Company This Report is: (1) X An Original (2J A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) II 2015/Q4 FOOTNOTE DATA ~ r-~--~~=---~·~~~~~~~~~~~--------------------------------------------------- chedule Page: 204 Line No.: 97 __ Column:_g_ ___________________-;---~----:------o----.--.---~ Schedule No. 317 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate ending balances) for all rate ~chedulePage:204 Line No.: 98 Schedule No. 317 formula rate ending balances) for all rate utilizes the simple average balances (average beginning and base inputs. Column: g utilizes the base inputs. Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. '$chedu/e Page: 204 Line No.: 99 Column: g ~~~~~~--;=-~=:.:...~~~~;;z____,.-,------,-----c;---------,---,;------;-·-------·---·······-----····-·· ------···-] Schedule No. 317 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. '$chedule Page: 204 Line No.: ! 01 _Coll!_P._t!_L~------- _ .. -·..... --------·---·------ --·---- ) The balance in account 102-of:$~975,445.78 at December 2014 related to certain transmission lines and substation facilities and associated land/easements acquired from Lee County Electric Cooperative. Account 102 was cleared in June 2015 and November 2015, recording the assets in account 101. The associated journal entries were approved through Docket No. AC15-143-000 and AC16-22-000, respectively . .. . ·----···--------------------------------------------, Schedule No. 317 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. IFERC FORM N0.1 (ED. 12-87) Page 450.3 Year/Period of Report Date of Report (Mo, Da, Yr) Florida Power & Light Company 2015/04 End of I I 1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. 2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give In column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105. [~~-~----------- -~----~~---~ !_ - 47 Total FERC FORM NO.1 (ED. 12-96) Page 214 -- - - - --- -- - - - ' c - -- Report Da, Yr) Florida Power & Light Company 2015104 End of I I 1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. 2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give In column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105. [----- 47 Total FERC FORM NO. 1 (ED. 12-96) Page 214.1 -- --~---- -· -_-_ -~- ----~_ -~ - -- - - -- -- of Report Da, Yr) Florida Power & Light Company End of I I 2015/Q4 1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. 2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105. 1"""":"'""'-------------~~~------~-------- -~------ 1 I • - - -- 47 Total FERC FORM NO. 1 (ED. 12-96} Page 214.2 - - - -~ -- - -- - ----- Florida Power & Light Company 1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. 2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105. 47 Total FERC FORM NO. 1 (ED. 12-96) 236,294,654 Page 214.3 Name of Respondent Florida Power & Light Company 1 This Report is: (1) ~An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA /Schedule Page: 214.3 Line No.: 46 Colum_n: d:-:-:-------.~----------,------..---.,---------;:-;----.---.-------' Schedule No. 317 formula rate utilizes the simple average balances (averages of beginning and ending balances) for all rate base inputs. In addition, adjustments are made to exclude all non-production plant held for future use. Schedule No. 322 formula rate utilizes the simple average balances (averages of beginning and ending balances) for all rate base inputs. In addition, adjustments are made to exclude all non-production plant held for future use. IFERC FORM N0.1 (ED. 12-87) Page450.1 BLANK PAGE (Next Page is 216) This wort Is: An Original (1) (2) EJA Resubmission Name of Respondent Florida Power & Light Company Year/Period of Report 2015/04 End of Date of Report (Mo, Da, Yr) JJ CONSTRUCTION WORK IN PROGRESS-- ELEI TRIC (Account 107) . 1. Report below descriptions and balances at end of year of projects in process of construction (1 07) 2. Show items relating to "research, development. and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts) 3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever Is less) may be grouped. Construction work in progress Electric (Account 107) (b) Description of Project Line No. (a) 1 INTANGIBLE AND GENERAL 2 Turkey Point Common National Fire Protection Association (NFPA)-805 Probability Risk Assess 3 St. Lucie Common National Fire Protection Association (NFPA)-805 Probability Risk Assessmen 4 17,649,855 12,553,701 6401 Next Gen Contact Center 9,809,644 5 New FPL.com Digital Customer Expansion 6 22,554,722 8,760,935 Sentient Grid Analytics Software 7 Riviera Plant- Manatee Viewing Center 6,209,720 8 Automated Meter Infrastructure - 2015 Software 6,075,177 9 5,921,290 EMS Stepped Upgrade Phase 1 5,741,360 10 Video Wall J Map Board Upgrade Hardware 11 4,583,153 6109- BCA opal replacement 12 Distribution Management System (DMS) Software & Implementation Phase I 4,468,740 13 Reengineer Enterprise Budgeting 4,423,317 14 Cloud Computing Services 4,033,806 15 6401 next gen contact center- hardware purchase 3,741,701 16 St. Lucie Common 1 Generic Safety Issue (GSI)-191 Probability Risk Assessment Software 3,371,881 17 7150 ECC Phase 4 - Software Development 3,359,827 18 Turkey Point Common 4 Generic Safety Issue (GSI)-191 Probability Risk Assessment Software 3,134,035 19 Digital Control System Expansion 3,120,979 20 Voice Infrastructure Upgrade- Hardware 3,011,362 21 Turkey Point Common 3 Generic Safety Issue (GSI-191) Probability Risk Assessment Software 2,998,340 22 Hadoop analytics platform hardware 2,975,453 23 St. Lucie Common 2 Generic Safety Issue (GSI) -191 Probability Risk Assessment Software 2,885,172 24 Streetlight Vision Software PH2 2,837,500 25 Streetlight nics phase 2 2,643,938 26 Cylance EndPoint Protection - Software Development 2,627,373 27 6208A-RR-eRRD(Eiectronic Carr) 2,061,741 28 Legacy Equipment and Fiber Lifecycle 1,976,724 29 Network Capacity Upgrade 1,920,728 30 Mobile Workforce Management - Software Development 1,890,279 31 7612 Silver Spring Netks Util (UIQ) 1,861,669 32 General Office Optimization 33 1,775,897 Indiantown Martin Warehouse Canopy and Pavement 1,759,098 1,686,825 34 PGAsite 35 ·1,622,824 lnfrastr Integra & Standard - SW Dev 36 Crew laptop (gd6000) Replace 1,528,631 37 WMS and ARM Scheduler Upgrades 1,481,404 38 STI Dashboard Development SNV 1,479,050 39 Automated Meter Infrastructure and Marketing Data Warehouse 1,400,756 40 Distribution Management System Hardware & Implementation 1,400,452 41 Source Range Monitor (SRM) Upgrade 1,385,502 1,365,749 42 PM-301-902 Org Consolidation S/W 43 TOTAL FERC FORM NO.1 (ED.12-87) 3,071,553,096 Page 216 Name of Respondent This ~ort ls: (1) ~An Original (2) []A Resubmission Florida Power & Light Company D t tR cJo~ &a, $~ort Year/Period of Report End of 2015/Q4 11 CONSTRUCTION WORK lN PROGRESS • • ELECTRIC (Account 107) 1. Report below descriptions and balances at end of year of projects in process of construction (1 07) 2. Show!1ite07ms relatln~ to "research, development, and demonstration" projects last, under a caption Research, Development and Demonstrating (see A ccoun of the Uniform System of Accounts} ' 3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped. Line No. Description of Project Construction work in progress Electric (Account 107) (b) (a} 1 SAP HANA - SW Dev 1,354,885 2 Data Diode 1,302,999 3 Smart Lights IM Dev- Phase 2 1,300,529 4 Increase Budget Billing Enrollments 5 1,194,412 Knowledge Sharing Project 6 Utilities International Planner Gas Reserves and CDR lnt 7 NAMS & documentum major upgrade sw 1,183,742 1' 171,046 1, 163,134 8 VSP-Billing Systems 1'134,689 9 Systems Management Software Jifecycle 1,125,000 10 SAP infrastructure· java stack spl 11 1,078,439 7602 Smart Meter Smart Grid Network 1,071,694 12 Smart Lights PH2- UIQ S/W 1,057,300 13 14 STEAM PRODUCTION 15 Martin Plant 1&2 200 Gallons Per Minute Demineralizer System Installation 1,890,434 16 Martin Plant-Gas Blending Station & Controls Upgrade 1,221,633 17 18 NUCLEAR PRODUCTION 19 Turkey Point Common Common U6&7 Pre-Construction 234,606,708 20 Turkey Point Common U4 Low Pressure Turbine Replacement 29,471,100 21 Turkey Point Common U3 Low Pressure Turbine Replacement 29,360,004 22 St. Lucie Common 1 License Renewal Inspections 6,850,522 23 Turkey Point Common U6&7 Site Selection Cost 6,214,310 24 Turkey Point Common 4 Inc Fukushima Reactor Coolant Pump Seal Replacement 25 St Lucie Unit 162 Reactor Coolant Pump Rotating Assembly Replacement 5,475,373 5,059,093 26 Turkey Point Common New Water Treatment Plant 4,238,091 27 St. Lucie Ocean Intake Velocity Caps Turtle Excluders 3,896,306 28 St. Lucie 2A2 Reactor Coolant Pump Refurbishment (2A2 to 182) 3,218,152 29 Turkey Point Common U3C28 Turbine Valves Refurbishment 2,842,470 30 Turkey Point Common Inc Common Fukushima Wells 2,823,109 31 2,779,170 Turkey Point Common UC S74-A Chiller Replacement 2,724,812 32 Turkey Polnt Common Security Computer Replacement 33 Turkey Point Common U3 Replacement Phase V NUS Modules 2,703,185 34 Turkey Point Common U3 License Renewal Reactor Vessellnternals Inspection 2,567,130 35 St. Lucie Common U2 National Fire Protection Association (NFPA)-805 Elec Mods SL2-22 2, 147,143 36 Turkey Point Common U6&7 Non-Incremental Payroll 2,502,325 37 St. Lucie ComJru)n U2 Emergency Diesel Generator Voltage Regulator/Exciter Train B 2,096,204 38 St. Lucie Common 2 License Renewal Inspections 2,060,804 39 St. Lucie Common Security Intelligent Video Monitoring System Upgrade 2,237,593 40 Turkey Point Common Force on Force Security Upgrade Install Bullet/Blast Resistant Enclosur 2,400,407 41 St. Lucie Common U1 Permanent Platform Additions 2,332,094 42 St. Lucie Common Unit 1 Intake Trash Rake 2,328,841 43 TOTAL FERC FORM NO.1 (EO. 12·87) 3,071,553,096 Page 216.1 This ~ort Is: (1) An Original (2) fiA Resubmission Name of Respondent Florida Power & Light Company Year/Period of Report 2015/Q4 End of Date of Report (Mo, Da, Yr) I I CONSTRUCTION WORK IN PROGRESS-- ELECTRIC (Account 107) 1. Report below descriptions and balances at end of year of projects in process of construction (1 07) . 2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts) 3. Minor projects (5% of the Balance End of the Year for Account 107 or $1 ,000,000, whichever is less) may be grouped. Construction work in progress Electric (Account 107) Description of Project Line No. (b) (a) 1 Turkey Point Common U4 Replacement Phase V NUS Modules 2 Turkey Point Common U4 Motor Control Center 4C Replacement 3 Turkey Point Common Force on Force Security Upgrade Install Bullet/Blast Resistant Enclosur 2,165,895 1,964,174 4 St. Lucie Common Unit 2 Intake Trash Rake 5 Turkey Point Reactor Coolant Pump Motor Refurbishment from 3A 6 2,247,309 2,187,508 1,943,178 1,910,735 Turkey Point Common Force On Force Turbine Grate Delay 7 Turkey Point Common Refurbishment Reactor Coolant Pump Rotating Element 1,848,420 8 Turkey Point Common Inc Fukushima Port FLEX Eqmt 1,648,854 9 1,431,752 St. Lucie Common Water Treatment System 10 St. Lucie Common- South Service Building Air Conditioner Replacement 11 12 Turkey Point Common U4 Motor Control Center 4B Replacement 1,457,679 St. Lucie 182 Reactor Coolant Pump Refurbishment (182 to Spare) 1,214,316 13 Turkey Point Common U4 Motor Control Center 4A Replacement 14 1,349,764 St. Lucie 182 Reactor Coolant Pump Sea I & Flex Hoses SL1-27 1,302,187 1,274,580 1,164,837 15 Turkey Point Common Freshening Well F1-lncremental 16 17 OTHER PRODUCTION 18 1,029,625,291 Port Everglades Modernization 220,656,420 19 Plant Ft. Lauderdale Peaker Upgrade 20 Plant Ft. Myers Peaker Upgrade 85,301,976 21 Plant Ft. Myers 3A & 3B Upgrades 31,727,512 22 Martin Plant 4A Dry Low Nox (DLN)2.6+ & .04 Major Upgrade 21,146,350 23 Martin Plant 38 Dry Low Nox (DLN)2.6+ & .04 Hot Gas Path (HGP) Upgrade 21,144,230 24 Martin Plant 3B Dry Low Nox {DLN)2.6+ & .04 Hot Gas Path (HGP) Upgrade 21,144,230 25 Martin Plant 3A Dry Low Nox {DLN)2.6 & .04 Major Upgrade 21,144,071 26 20,123,929 Riviera Plant- Martin Gas Blending Yard 27 Plant Ft. Myers 2A 2015 Dry Low Nox (DLN)2.6+ & .04 Major Outage 16,421,098 Plant Ft. Myers-2A OCT 15 Major .05 15,006,951 29 Martin Plant-BC Jan-16 Major .05 Upgrade 14,334,236 30 Martin Plant-SO Jan-16 Major .05 Upgrade 14,311,266 28 31 Martin Plant-BB June-17 Major .05 14,290,730 32 Martin Plant-SA Oct-2016 Major .05 Upgrade 14,286,730 14,284,646 33 Sanford Plant-4A Jul-16 Major .05 34 Sanford Plant-48- May 2016 Major .05 14,284,471 35 Sanford Plant-58 Sept 2016 Major .05 14,283,969 Sanford Plant-SA Apr-17 Major .05 14,283,969 36 37 Sanford Plant-4C Mar-2016 Major .05 38 14,283,912 Sanford Plant 4D- May 2016 Major .05 14,283,912 39 Sanford Plant-5C Sept-16 Major .05 14,283,912 40 Sanford Plant-50 April 2017 Major .05 14,283,605 Turkey Point-SA May-17 Major .05 14,283,062 41 42 Turkey Point-58 June 2017 Major .05 43 14,283,062 TOTAL FERC FORM NO. 1 (ED. 12-87} 3,071,553,096 Page 216.2 Name of Respondent This ~ort Is: (1) An Original (2) f]A Resubmisslon Florida Power & Light Company Date of Report (Mo. Da, Yr) Year/Period of Report 2015/04 End of I I CONSTRUCTION WORK IN PROGRESS-- ELECTRIC (Account 107) 1. Repo~ below descriptions and balances at end of year of projects in process of construction (1 07) 2. Show Items relatln~ to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Umform System of Accounts) 3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped. line No. Description of Project Construction work in progress Electric (Account 107) (b) (a) 1 Turkey Polnt-SC July-17 Major .05 14,283,062 2 Turkey Point-50 .05 Aug 2017 Major .05 14,283,062 3 Manatee Plant-3A Jan-17 Major .05 4 14,283,062 Manatee Plant-3B- Mar 2017 Major .05 14,283,062 5 Manatee Plant-3C Dec-16 Major .05 14,283,062 6 Manatee Plant-3D Dec 2016 Major .05 14,283,062 7 Citrus Solar Energy Center 13,917,325 a Babcock Solar Energy Center 13,265,055 9 Manatee Solar Energy Center 11,757,965 10 Commercial and Industrial Solar Partnership Program- Daytona International Speedway 5,515,253 11 Cape Canaveral Plant-32 Turbine Rotor Refurbishment 3,983,562 12 Cape Canaveral Plant-32 Compressor Rotor Refurbishment 2,865,4n 13 Plant Ft. Lauderdale Blackstart Upgrades 2,683,102 14 Sanford Plant U4 Condenser Tube Replace 2,656,444 15 Commercial and Industrial Solar Partnership Program - Florida International University 1,638,380 16 West County Energy Center U2 Controls Upgrade North American Electric Reliability Corporal 1 ,445,144 17 Cape Canaveral Plant-32 R-4 Turbine Blades Refurbishment 1,439,339 18 West County Energy Center Purchase & Install Ultra Filtration System 1,401' 161 19 West County Energy Center U1 Controls Upgrade North American Electric Reliability Corporatl 1,385,286 20 Cape Canaveral Energy Center New Circulating Water Pump Capital Spare Part 1,374,156 21 West County Energy Center U3 Controls Upgrade North American Electric Reliability Corporati 22 Cape Canaveral Energy Center-32 R-3 Turbine Blades Refurbishment 23 Plant Ft. Lauderdale High Pressure/Intermediate Pressure Rotor Refurbishment 24 Cape Canaveral Plant-32 Compressor Blades Refurbishment 1\343,897 1,334,022 1,234,644 1,213,078 25 Plant Ft. Myers 2A low Pressure Evaporator Module Replacement 1,134,316 26 Cape Canaveral Plant-32 R-1 Turbine Blades Refurbishment 1,123,387 27 Cape Canaveral Plant-32 R-2 Turbine Blades Refurbishment 1'123,387 28 29 TRANSMISSION Plant 30 St. lucie #4 Transmission line 51,324,739 31 Port Everglades Energy Center Switchyard Modernization 13,022,079 32 Ampacity Upgrade from Sanford Plant to Progress Tie 9,982,252 33 Ampacity Upgrade on the Hollywood Port Everglades 138kV line 6,233,768 34 Turkey Point1 SYNC Condenser Conversion 5,037,036 35 Finish Construction of 230kV yard 4,914,311 36 Port Everglades Energy Center Modernization: Rebuild Generator Bays 4,558,880 37 Ampacity Upgrade: Hollywood-Port Everglades 138kV: Dania-Port Tap1 Section 4,116,174 38 Manatee COR-MAR 500KV Replace Suspension Insulator 3,416,582 39 Hardening of Flamingo to Driftwood line Section 3,353,793 40 Structure Relocation of DADLIT2 138kV: lndustriai-Fronton Section due to MDC PWD Project a 3,346,660 41 St lucie#4 line Bay 6 addition 3,080,714 42 Purchase Right of Way easement to Festival Substation on FGT Gas Compressor Station Site 2,988,655 43 TOTAL FERC FORM NO.1 (ED. 12-87) 3,071,553,096 Page 216.3 This wort Is: (1) An Original (2) []A Resubmission Name of Respondent Florida Power & Light Company Year/Period of Report 2015/04 End of Date of Report (Mo, Da. Yr) I I CONSTRUCTION WORK IN PROGRESS-- ELECTRIC (Account 107) 1. Report below descriptions and balances at end of year of projects In process of construction (1 07) . . 2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts) 3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped. Construction woi'K in jJrogress Electric (Account 107) (b) Description of Project Line No. {a) 2,861,060 1 Bobwhite-Manatee 230kv Trans Lines Installation 2 St. Lucie Common#4: Line Terminal: Construct One 3 New Transmission substation S&E 4 Buckingham Injection Phase 1: Buck 5 NEW HER-TUC Build new 230kV line 6 Ampacity Upgrade: Korona-Ormand 115kV Line Phase 1 7 Hardening - Replacement of 44 Wood Structures w'rt.h Concrete Structures on Cutler· Galloway 8 AMP LAN-RIV 138 kV Upgrade Ampaclty 9 Andytown bypass 500kv 2,817,154 2,735,982 2,634,673 2,632,325 2,324,174 2,318,933 2,174,612 1,903,129 10 Buckingham 230kV Injection Phase 2B 1,882,847 11 Site Prep for new Hercules Transmission/Distribution Substation 1,837,561 12 Installation of Security Walls and Gates for Corbett Transmission Substation 1,825,081 13 Relocation of Poles on Satsuma Tap-Putnam Tap line section due to FDOT Project 1,824,839 14 Maintenance of ALV-COR 230kV line 1,821,760 15 Installation of Security system at Roberts Transmission Substation 1,729,119 1,710,141 16 Ampacity Upgrade: Altamonte-Sanford 1,611,054 17 Construction of new Brickell distribution substation 18 Construction of new Hercules distribution substation 1,545,278 19 Replacement of 30 Structures of Putnam - Tocoi 230kV Line 1,520,663 20 Replacement of 32 Structures of Putnam - Tocoi 230kV Line 1,492,038 21 Site Preparation at Roberts Station 1,488,028 22 2015 Rebuilt LV Section and Increase 1,366,443 23 NEW CHA-FTP#2_Build new 230kV lines 1,357,665 24 Replace Cap banks 1,357,521 25 TLSA study for new Duval-Raven 230kV line 1,308,105 26 Replacement of 6 SOOkV Transformers at Levee Substation 1,302,113 27 Babcock Ranch 1,283,614 28 Pole relocation along ARC~LAU 138kV line 1,277,136 29 Reinsulate Swyd-Hardening Trinn RG 1,255,425 30 Addition of 4 breaker ring bus and line termianl to Sunshine Transmission Substation 1,181,582 31 Hardening of Flagami-South Miami 138kV line: Flagami Dis! (TAP)-62ND AVE section 1'164,071 32 Port Everglades Modernization: Site Prep and Relay Vault 1,161,392 33 Purchase of Capital Spare Parts for Port Everglades Energy Center Substations 1,118,802 34 North American Electric Reliability Corporation/FERC 1,105,680 35 Maintenance of POl-ROB 500kV line Storm/Tangent Structures 1,088,335 36 Install new 230-138kV, 560MVA Auto transformer at Miami transmission sub 1,030,366 37 Site Prep for new Brickell Distribution Substation 1,017,905 38 40th Street substation - 2015 underground maintenance 1,010,390 39 40 DISTRIBUTION Plant 41 Install of AFS switch-Palm Beach Co. 3,685,507 42 Install of AFS switch-Broward Co. 2,813,326 43 TOTAL FERC FORM NO.1 (ED. 12-87) 3,071,553,096 Page 216.4 Name of Respondent This ~ort Is: (1) ~An Original (2) EJA Resubmission Florida Power & Light Company Date of Report (Mo, Da, Yr) 11 Year/Period of Report 2015/04 End of CONSTRUCTION WORK IN PROGRESS ·- ELE<..TRIC (Account 107) 1. Report below descriptions and balances at end of year of projects in process of construction (1 07) 2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts) 3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped. Une No. Description of Project Construction work in progress Electric (Account 107) {b) (a) 1 Phase 2 Smart Street Lights-Broward Co. 2,002,431 2 Palma Solar Hardening 1,605,857 3 Capri Hardening 1,565,738 4 AMI Residential Meter Purchase-Dade 1,494,484 5 Matanzas Hardening 6 1,370,125 Edgewater Hardening 1,319,656 7 MSTU vanderbuiH beach - Phase 2 8 Hardening 2015 Top CIF 9 Koger Hardening 1,238,291 1,233,968 1,213,175 10 Community based hardening 11 1,136,506 Stirling Hardening 1'120,035 12 Highlands Hardening 1,115,203 1.3 Chronic FOR Orangedale 1,081 '138 14 Stirling Hardening 1,063,897 15 Hiatus Hardening 1,062,185 16 Madison Hardening 1,039,953 17 Smart lighting MC-Dade Co 1,028,884 18 Edgewater Hardening 1,026,498 19 Lewis Hardening 1,020,573 20 Deltona Feeder Hardening 1,020,312 21 Brevard County: Da Communication Equipment 1,000,873 22 23 Total Other Projects 416,419,172 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 TOTAL FERC FORM NO.1 (ED.12-87) 3,071,553,096 Page 216.5 Name 2015/Q4 Florida Power & Light Company 1. Explain in a footnote any important adjustments during year. 2. Explain in a footnote any difference between the amount for book cost of plant retired, Line 11, column (c), and that reported for electric plant in service, pages 204-207, column 9d), excluding retirements of non-depreciable property. 3. The provisions of Account 108 in the Uniform System of accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. . Show separately interest credits under a sinking fund or similar method of depreciation accounting. FERC FORM NO.1 (REV. 12..05) Page 219 Name of Respondent Florida Power & Light Company This Report is: (1) X An Original I(2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA '$chedule Page: 219 Une No.: 8 Column: c Decommissioning Earnings (A/C 108) Decommissioning Fund SFAS 115 A/C's Mark to Market Reclassify ARO related Decomm Earnings & SFAS 115 to ARO Acccount 108 Total 'i§chedu/e Page: 219 Line No.: 12 Column: c Plant Retired - Page 219 Line 12, Column c Book Cost Asset Retirement Cost - Page 219 Line 18, Column c Book Cost of Amortizable.Plant Retired Total Electric Plant In Service Retirements (Page 207, Line 104, Column d) r=~c-c-:-h-e-:d-ul-::-e-P=-a---'g-e: 219 . Line No.: 16 Column: c ·-····-----·----·--Reserve on LCEC Acquired Assets Transfer from Depreciable to Amortizable Regulatory Asset - Extended Power Uprate (EPU) SJRPP Coal Car Adjustment ARO - Prior year true-up Clearing Account Total ........................................ ,__ ........................... ,............ . e_chedule Page: 219 Line No.: 28 Column: c Asset Retirement Cost by Function ( included in column b) ~----··-···-- ____ Steam Production Nuclear Production Other Production Transmission Production Distribution Production Total Electric Plant Asset Retirement Cost IFERC FORM N0.1 (ED. 12-87) Page 450.1 $107,809,899 (107, 845,868) 5,792,433 $ 5,756,464 __j $(874,101,013) (11, 642, 840) (111,727,052) $(997,470,905) ··-----------····--·-········-····---·--~ $20,041,931 (455, 191) 683,291 (53, 435) 11,642,840 $31,859,436 . . ·--···-···-··-··----------.....! $2,750,786 1,636,939 666,105 81,136 867,739 $6,002,705 Name of Respondent This mort Is: (1) An Original (2) [)A Resubmission Florida Power & Light Company Year/Period of Report Date of Report (Mo, Da, Yr) End of I I 2015/04 INVESTMENTS IN SUBSIDIARY COMPANIES Account 123.1) 1. Report below investments in Accounts 123.1, investments in Subsidiary Companies. 2. Provide a subheading for each company and List there under the information called for below. Sub- TOTAL by company and give a TOTAL In columns (e),(f),(g) and {h) (a) Investment in Securities. List and describe each security owned. For bonds give also principal amount, date of issue, maturity and Interest rate. (b) Investment Advances- Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance Is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. 3. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1. Description of Investment ILI08 No. Date Acquired (b) (a) Date Of MaWJritY Amount. ot .lnve~t)Tient at Begmmng of Year (d) 11/17/93 1 KPB Financial Corporation 10 2 Common Stock 3 Paid in Capital 365,220,479 4 Retained Earnings 303,364,861 5 Subtotal KPB Financial Corporation 668,585,350 6 7 8 5/22/2007 9 FPL Recovery Funding LLC 10 Common Stock 3,260,000 11 Paid in Capital 12 Retained Earnings 3,260,000 13 Subtotal FPL Recovery Funding LLC 14 15 11/4/1987 16 FPL Enersys, Inc 17 Common Stock -14,455,686 18 Paid in Capital 18,354,861 19 Retained Earnings 3,899,175 20 Subtotal FPL Enersys, Inc 21 3/1/15 22 GR Woodford Properties, LLC 23 Common Stock 24 Paid in Capital 25 Retained Earnings 26 Subtotal GR Woodford Properties, LLC 27 28 CBAS Power, LLC 29 Common Stock 9/18/15 30 Paid in Capital 31 Retained Earnings 32 Subtotal CBAS Power, LLC 33 34 RGS Realty Holdings, LLC 1113/15 35 Common Stock 36 Paid In Capital 37 Retained Earnings 38 Subtotal RGS Realty Holdings, LLC 39 40 41 42 Total Cost of Account 123.1 $ FERC FORM N0.1 (ED.12-89) 805,826,8741 Page 224 TOTAL 675,744,525 Name of Respondent Florida Power & Light Company This ~ort Is: An Original flA Resubmission (1) (2) Dale of Re~ort (Mo, Da, Yr) I I INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1) (Continued) Year/Period of Report End of 2015fQ4 4. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts In a footnote, and state the name of pledgee and purpose of the pledge. 5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. 6. Report column (f) Interest and dMdend revenues form investments, including such revenues form securities disposed of during the year. 7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if difference from cost) and the selling price thereof, not including interest adjustment includible in column (f). B. Report on Line 42, column (a) the TOTAL cost of Account 123.1 Equity 1n Subs1d1ary Eamin~~)of Year Revenues ror Year Amount of Investment at End r&rar (f) Ga1n or Loss from Investment Disp?h)ed of Line No. 1 10 2 360,473,789 3 24,167,751 327,532,612 4 24,167,751 688,006,411 5 6 7 8 9 10 3,260,000 11 12 3,260,000 13 14 15 16 17 18 4,454,499 22,809,361 19 4,454,499 3,821,905 20 21 22 100 23 93,287,404 24 4,805,390 4,805,390 25 4,805,390 98,092,894 26 27 28 29 16,446,262 30 -4,399,027 -4,399,027 31 -4,399,027 12,047,235 32 33 34 35 1,476 . 36 37 1,476 38 39 40 41 805,826,874 29,028,613 FERC FORM NO. 1 (ED. 12-89) Page 225 42 This ~ort Is: (1) An Original (2) EJA Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) Year/Period of Report End of I I 2015/04 INVESTM NTS IN SUBSIDIARY COMPANIES Account 123.1) 1. Report below investments in Accounts 123.1, investments in Subsidiary Companies. 2. Provide a subheading for each company and Ust there under the information called for below. Sub- TOTAL by company and give a TOTAL in columns (e),(f),(g) and (h) (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity and interest rate. (b) Investment Advances~ Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance Is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. 3. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1. Description of Investment [line No. Date Acquired {b) (a) Date Of Ma(gftY Amount. ot Jnve~t!J:lent at Begtnnmg of Year (d) 1/13/15 1 RGS Realty, LLC 2 Common Stock 3 Paid in Capital 4 Retained Earnings 5 Subtotal RGS Realty, LLC 6 7 Gray Sky Investments, LLC 1/13/15 6 Common Stock 9 Paid in Capital 10 Retained Earnings 11 Subtotal Gray Sky Investments, LLC 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 Total Cost of Account 123.1 $ FERC FORM NO. 1 (ED. 12-89) 805,826,8741 Page 224.1 TOTAL 675,744,525 Name of Respondent This~rtls: (1) An Original (2) tJA Resubmission Florida Power & Light Company Date of~ort (Mo, Da, r) Year/Period of Report End of I I 2015/Q4 INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1) (Continued) 4. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts In a footnote, and state the name of pledgee and purpose of the pledge. 5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. 6. Report column (f) interest and dividend revenues form investments, including such revenues form securities disposed of during the year. 7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if difference from cost) and the selling price thereof, not including Interest adjustment includible in column (f). 8. Report on Line 42, column (a) the TOTAL cost of Account 123.1 Equrty rn ::;u~s1a1ary Eamin~~)of Year Kevenues tor Year Amou':!_t of Investment at End rJ,vear (f) Gain or L_oss rrom Investment Dispf~rd of Line No. 1 2 445,477 3 445,477 5 4 6 7 8 151,476 9 10 151,476 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 29,028,613 FERC FORM NO. 1 (ED. 12-89) 805,826,874 Page 225.1 42 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original I(2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I FOOTNOTE DATA !Schedule Page: 224 Line No.;,7 1=-;=B,____--=C""o'""iu"'-'-incc: ___::-:.n-'-:a..9__,.-;--:--;------;----.----;--;---------There are no cash transactions performed at the subsidiary. IFERC FORM N0.1 (ED. 12-87) Page450.1 2015/04 BLANK PAGE (Next Page is 227) Florida Power & Light Company 1. For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. 2. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable. Une No. Account Balance Beginning ofYear Balance End of Year Department or Departments which Use Material (d) 20 TOTAL Materials and Supplies (Per Balance Sheet) FERC FORM NO. 1 (REV. 12-05) 848,053,981 Page 227 820,259,859 Name of Respondent This Report is: (1) XAn Original ! (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report {Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA ~hedule Page: 227 Line No.: 5 Column: b . During July 2014 FPL prospectively implemented a change ~i-n~i~t~s--a__ c_c_o_u_n~t~i_n_g__m_e_t-.h~od for the pre-capitalization of distribution line transformers. This change was made per the Federal Energy Regulatory Commission's approval of Docket No. AC14-39-000. Based on this approval, FPL will treat distribution line transformers as inventory items and capitalize them at the time of installation rather than the time of purchase. This change resulted in a one-time shift of approximately $26 million from plant in-service to inventory held for construction. '~Schedule Page: 227 ---Line No.: 12 Column: b - ------- ______ _ During 2014 FPL modified its allocation of inventory in Account 154 to more accurately align with the underlying use and purpose of its inventory, in conjunction with its available inventory forecasting models. This change was applied retrospectively to the beginning of year balance for comparison purposes. jFERC FORM N0.1 (ED.12..S7) Page 450.1 Date of (Mo, Da, Florida Power & Light Company End of I I 1. Report below the particulars (details) called for concerning allowances. 2. Report all acquisitions of allowances at cost. 3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. 4. Report the allowances transactions by the period they are first eligible for use: the current year's allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns 0)-(k). 5. Report on line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Line No. S02 Allowances Inventory {Account 158.1) [~ 1_ :-_ --~-~ -~-- ~- , - r- . - - J .. ~ • - - - -- _-- - - .. " _..___ ~.-~-~~- -__ ~ -~- - ""-· 46 Losses Page 228a _..,..,,..,.. , ~ -~ -'-- ---- ------~- 1,1 ~~~~-,-~-,~ """-~ .;.;..:.....:..-~-"'""'- FERC FORM NO.1 {ED.12-95) ~- "---~ ............ - - • - ·-----_--~ ~-- --~- - _. _______ ..,.....,.______ ~ -- ._." • ..,_.__-,....,.._. ---~---~ - -- - ~ - - ___ .----·- - - : _· ~---~---,.,..-- ..... - ~ ~ ~----- -- '"-- --- -----· - ~ - ~ - ...... ......... -- --- ~ ---. ~ - ~ -~ Florida Power & Light Company End of 6. Report on Lines 5 allowances returned by the EPA. Report on Line 39 the EPA's sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA's sale or auction of the withheld allowances. 7. Report on Lines 8-14 the names of vendors/transferors of allowances acquire and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). 8. Report on Lines 22-27 the name of purchasers/ transferees of allowances disposed of an identify associated companies. 9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. 10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales. FERC FORM NO. 1 (ED. 12-95} Page 229a Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original .(2) A Resubmission Date of Report Year!Period of Report (Mo, Da, Yr) I I 2015/Q4 FOOTNOTE DATA !Schedule Page: 228 Line No.: 1 Column: b CSAPR started in 2015. ARP and CSAPR 802 GR 2 combined on 228a - 229a. & CSAPR GR 2 S02 Allowances ARP S02 Allowances ARP Ending Balance VY 2014 from FERC Form 1 RY 2014 1,050,647 + 79(Correction to Emissions Deduction for Manatee Plant) + 66l(Correction to Emissions Deduction for Martin Plant) + 13(Correction- Twice Deducted Emissions- Fort Myers) + 14(Correction- Twice Deducted Emissions- Lauderdale) + 13(Correction- Twice Deducted Emissions- Port Everglades) -!(Correction to Emissions Deduction for Cape) - 2(Correction to Emissions Deduction for Lauderdale) - 2(Correction to Emissions Deduction for Port Everglades) - 2(Correction to Emissions Deduction for Sanford) - 2(Correction to Emissions Deduction for Putnam) -!(Correction to Emissions Deduction for West County)= 1,051,417 Total Banked VY 2014 S02 ARP Allowances as of 1/1/2015 1,051,417 + 139,022 (Previously Allocated VY 2015 Allowances)= 1,190,439 VY 2015 and Earlier Banked Allowances CSAPR GR2 S02 No Allowances held 1/1/2015 ~edule Pagi:m ___Une-No~:-18 · · Column: b ARP FPL S02 Emissions from Electronic Data Reports 2015 FPL Share of Southern S02 Emissions = (10) FPL Share of Scherer Unit .4 Emissions = (571) Total= 2,019 ---···-----··--·-·······_·····_····-·_·····_-····_·-···_·····_·····_·····_··--·_···-=-~___,--! (1,438) CSAPR GR2 S02 FPL Share of Southern S02 Emissions = (4) FPL Share of Scherer Unit 4 Emissions = (571) Total = 575 Grand Total S02 Emission Responsibility= 2,594 [§.c!!_~d_LI_~~-~~91:!=.~?8.____ Line No.: 44 Coliimil:.. Gains on Disposition of Allowances: c.. -------- Vintage Year 2015 allowances sold in 2015 Adjustment from 2014- SJRPP Saleback Vintage Year 2021 correction noted in 2014 Net Sales Proceeds (including adjustments) IFERC FORM N0.1 (ED. 12-87) J 216 {49) (90) 77 Page450.1 BLANK PAGE (Next Page is 228b) Florida Power & Light Company 1. Report below the particulars (details) called for concerning allowances. 2. Report all acquisitions of allowances at cost. 3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. 4. Report the allowances transactions by the period they are first eligible for use: the current year's allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(0, starting with the following year, and allowances for the remaining succeeding years in columns 0)-(k). 5. Report on line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Line NOxAIIowances Inventory No. (Account 158.1) --.,. lr·- - - -.,._........_--~-------,....._..,...'""""~~~· ~~:.: L --. [;--"-_ 1 ~ - -- :. -- -- - ~- . ~ ~ ... _ _ . ~~-~~-~~- ~~--~..,..,--~...,. - - ~ _ - ~ -- ~ -- ~~~-~~ ~~-- -c- - - - F~ - ~-- -•- • -- • - _.. - -- - -~ - - ~ ~ -"'- ~ - - --- - • -- - -- -- -~-- - -~ ------------------.-~--~-----~---~-~ ~-- -- " - ~ --=-:=~=---- ~-=-~-~--_.---- ----:--.--=~--~-~~:- ~~-~~--~---- ~ ~ I -- -- . - [ -~ -"" - -- - :.. -;:- .:..-::'" ~--: - --::----. ~-'~ ~ --- ~-~--~- --= -- ~__ -- ~ "-~ -~----~-- - ------- ~~- ~~- ~ "--'-"- ~~-~-------------~···----~-· (~ -~.-=-~-:-~~-~-~~~:_'-~~~.=-=--· ~~--~--~~,- -~- -~--~~=-~ ~:~-- ~~-, ---~~ FERC FORM NO.1 (ED. 12-95) Page 228b Date Report (Mo, Da, Yr) Florida Power & Light Company I I End of 2015/Q4 6. Report on Lines 5 allowances returned by the EPA. Report on Line 39 the EPA's sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA's sale or auction of the withheld allowances. 7. Report on Lines 8-14 the names of vendors/transferors of allowances acquire and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts}. 8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of an identify associated companies. 9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. 10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales. FERC FORM NO.1 (ED. 12-95) Page 229b Name of Respondent This Report is: Date of Report Year/Period of Report (1) )5 An Original (Mo, Da,.Yr) Florida Power a. Light Company (2) A Resubmission I I 2015l04 FOOTNOTE DATA [ghedule Page: 229 Line No.: 1 Column: CAIR NOX Program ended 12/31/2014. CAIR Annual Allowances were retired. CSAPR (Transport Rule) initiated in 2015. Florida is only subject to the CSAPR Ozone Season Program. CSAPR Annual Program. FPL Held (0) Annual Allowances on 1/1/2015 CSAPR Ozone Season Program Beginning Balance Vintage Year 2015? 7,464 (Distributed Revintaged Allowances)+ 213 (Initial Allocation) 7,677 (Schedule Page: 229 Line No.: 18 Column: ., CSAPR Annual NOX FPL Not Subject to Annual NOX (0) FPL Share of Southern Annual Emissions (0)(Had sufficient allowances) FPL Share of Scherer Unit 4 NOX Annual Emissions (2,968) Total 2,968 CSAPR OS NOX FPL Ozone Season Emissions from electronic Data Reports (4,304) FPL Share of Southern OS Emissions (0)(Had sufficient allowances) FPL Share of Scherer Unit 4 OS Emissions (675) FPL Share of OS Emissions (2,549) Total 7,528 Grad Total 802 Emission Responsibility 2 10,496 FFERC FORM NO. 1 (ED. 12.37} Page 450.1 Name of Respondent Florida Power & Light Company This ~rt Is: (1) ~ An Original (2) A Resubmission Date of Report (Mo. Da, Yr) I I Year/Period of Report End of 2015104 Transmission Service and Generation Interconnection Study Costs 1. Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. 2. List each study separately. 3. In column (a) provide the name of the study. 4. In column (b) report the cost incurred to perform the study at the end of period. 5. In column (c) report the account charged with the cost of the study. 6. In column (d) report the amounts received for reimbursement of the study costs at end of period. 7. In column (e) report the account credited with the reimbursement received for performing the study. e1mbursements ine Costs Incurred During Account Credited Received During No. Account Charged Description Period With Reimbursement the Period (b) (d) (e) (a) (c) Transmission Studies r------·---·- -------------- Generation Studies 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 ;-----------------------------------------------------------500 242.600 22 2G Energy, Inc Fast Track Study 1,000 242.600 23 Florida Solar Energy Center 100,000 242.600 24 US EcoGen Okeechobee Facilities Sy 25 OCEC System Impact Study 26 Hendry Solar Feasibility Analysis 27 Hendry Solar Feasibility Analysis 11,761 242.600 1,019 174.100 1,019 174.100 28 Okeechobee Solar Feasibility Anal 1,417 242.600 29 DeSoto Phase Ill System Imp Study 2,591 242.600 30 Hendry CTY Solar Fee Analysis 2019 1,019 242.600 31 Hendry CTY Solar Fee Analysis 2020 1,019 242.600 32 Manatee Impact Study 4,318 242.600 33 PFM Peaker-5ystem Impact Study 1,909 242.600 34 PFL Peaker-System Impact Study 9,894 242.600 35 36 37 38 39 40 FERC FORM N0.1/1-Ff3-Q~NEW. 03-07) Page 231 I Name of Date o~~~~ort (Mo, Da, I I ms~~~Js:Original N t ' V ·~- Florida Power & Light Company (2) Resubmission Yca11 -,.,.uJ ~6~;~: End of OTHER REGULATORYASSETS (Account 1 B2-:3) 1. Report below the particulars (details) called for conc~rning other regulatory assets, including rate order docket number, if applicable. j2. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped Iby classes. 13. For R"'""'"'+')ty Assets being amortized, show period of amortization. Description and Purpose of Other Regulatory Assets Line No. (a) 1 Ur.u"""""'""'.,J Fuel Clause Costs -FERC 2 3 I I Fuel Clause Costs- FPSC fSalance afl3egiriiil~ of Current QuarterlYear (b) 384,769 {.;KED ITS Debits Written off During lhe Quarter NeEI Acoounl Cha'lled (d) (c) 1557 121 ,360,667 ~· 256,571,851 Written offDUririQ the Period Amount (e) 384,769 Balance at end of CurrentQuarterlYear (f) 340,681,525 37,050,993 4 12,976,120 1456 1Short-tenn § _.4sset_ 12,976,120 6 TaxAudit 7 (5 year"' "u"~~u• 1-various periods) , M>i Adjustrhoots 8 9 (Energy Relat~d n 6,419,815 12.247 1431.5 364,212,199 .~~~.__input=-=s=-·c___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _----, ~hedule Page: 232 ___ T.ine No_:-2if. Column: d . ·-· .-..·-···----·--···---$ -987,873 Account 254 1,628 Account 524 989,501 Total $ - - - - -.. -· Account 101 Account 403 Account 407.3 Total , ______ _ _ .. $ $ ~hedule Page: 232 .. 360,027 13,086 4,395,631 4, 768,-74 4 Line No.: 35 CC?_If!mn;_a...... --···--;-;c---;----,----.--,----------,---~~ The company recorded amortization of net theoretical depreciation reserve surplus amounts as of December 31, 2015 functionalized into the following plant categories in accordance with the Florida Public Service Commission (FPSC) order approving a settlement agreement of the Company's 2009 Retail Rate Case on February 1, 2011 and an order approving a settlement agreement of the Company's 2012 Retail Rate Case on January 14, 2013. \FERC FORM NO. 1 (EO. 12-87) Page 450.1 This Report is: (1) ~An Original (2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA YTD Activity 2015 $ (5,162,104) 690,577 (2, 002,825) (202, 230) (7,609,834) (693,573) $ (14, 979, 989) Steam Nuclear Other Production Transmission Distribution General Plant Total Balance as of December 31, 2015 $ 267,881,290 (35,851,883) 103,899, 919 10,488,333 395,005,360 35,949,859 $ 777,372,878 Steam Nuclear Other Production Transmission Distribution General Plant Total [CiieriiiiePiig.e:i32 r Line No.: 35 Column: Schedule No. 317 formuia-·rat·e··u:tiTizes the simple average balances (average beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate ending balances) for all rate ~~!Jedu/e Pag_f!;_232 Line No.: 41 Schedule No. 317 formula rate ending balances) for all rate utilizes the simple average balances (average beginning and base inputs. ...... -.............................._. -----·----.-.---····--.... . .......... - ...... ·-·- ..... Column: f utilizes the simple average balances (average beginning and base inputs. ·---~ Schedule No. 322 formula rate uti.J.izes the simple average balances (average beginning and ending balances) for all rate base inputs. IFERC FORM NO.1 (ED. 12-87) Page450.2 BLANK PAGE (Next Page is 233) wis~~~ls: Original Name of Respondent Florida Power & Light Company (2) Date of Report (Mo, Da, Yr) , '"'"" ..., '"'" of Report 20151Q4 End of I I n11" ut:::r-r- t:::t(t:u DE Bin. {Account 186) jA Resubmission M SCEL 4 1. Report below the particulars (details) called for conc~ming miscellaneous deferred debits. 2. For any deferred debit being amortized, show period of amortization in column (a) 3. Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes. Line No. Description of Miscellaneous Deferred Debits (a) 1 Deferred Pension Costs 2 3 St. Johnf\~!_Eower Park4 Banking 5 6 7 Scherer4 8 9 FIN 48-Long Term Interest 10 """" 11 12 Mise Deferred Debits 13 14 General Office Gain 15 ·GPIF 16 Balance at Beginning of Year Debits (b) 1,189,172,556 CREDITS e~~a (c) ~;~nt 54094084 9,497,483 ~ 33,Z32,507 777,011 9,928J ••• 52.190,234 ~·.···· 45,143 Balance at End of Year (f) 1 ?.11<1 ?AA Mn 9,497,483 33,732,507 10,471,288 233,723 52,235,378 -1 981,106 981,106 11n RR"i 338,119,997 _798,212 ·· ........ ···~ ARn "i::ln,479 1,0~13_ 210,776 11,806,416 68,_2?_4.._59,? 23,303,114 456 11.806,416 23,303,114 782,717 92~ 171,973 610,744 17,517,838 167,314 17 18 Rate Case 2016 19 20 Minor items 21 ·= 17,535, 7 "' 149,369 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 Misc. Work in Progress pages 49 TOTAL FERC FORM NO.1 (ED. 12-94) 218,401 60,151 48 ~.ererrea {;~~~·~·, 1,;~~ m. 0 I) - 351 1 QA? 928 1,577 981,250 981,250 1,372, 778,384 Page 233 Name of Respondent This Report is: (1) X An Original I (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/Q4 FOOTNOTE DATA !Schedule Page: 233 Account 143 Account 232 Account 242 Total Line No._,_,_.:--"3'------"Co::..=:::.:lu::.:m~n_,_:d""---------- $ $ [Cfieiiute Page: 233 Line No.: 5 Column:d $ Account 107 Account 143 Account 232 Account 242 Account 920 Account 256 Total $ ~~hec!_l!!~--f'_~g_~: _2_~;!_ Line No.: 7 Column: d Account 143 Account 107 Account 154 Account 186 Account 242 Account 431 Account 501 Total ~E!l'!c:!l!!'! PE!g~: ............... ________________ $ 15,884,229 24,273,998 485,259 4,146,702 5,659,054 457 1, 785, 679 52,235,378 =:_=--=_-_-___-__-_-_- - - ] Line llia:·;·12---=c-o-=-lu_m_n_:_d__________________________________-_-___ Account 143 Account 956 Account 107 Total i,§~hedy_!!!. _f'_~_g__e_; ~3_3_ Account 920 Account 228 Account 242 Account 154 Account 232 Account 562 Account 566 Account 593 Account 908 Account 916 Total 360,500 3,481,830 34,027 342,166 24,922 6,227,843 10,471,288 ---·- __________________________:=] $ 233 5,034,230 2,180,187 2,283,066 9,497,483 $ $ Line No.: 20 jFERC FORM N0.1 {ED. 12-87) Column: d ...... ------------$-·· $ Page 450.1 595,122,000 8, 303 385, 400, 176 980,530,479 50,423 6,125,963 11,206,038 40 18,479 4,305 26,017 2,691 761 83,121 17,517,838 of Report (Mo, Da, Yr) I I Florida Power & Light Company 1. Report the information called for below concerning the respondent's accounting for deferred income taxes. 2. At Other (Specify), include deferrals relating to other income and deductions. FERC FORM NO. 1 (ED. 12-88) Page 234 End of 2015/04 Name of Respondent Florida Power & Light Company This Report is: ( 1) ~ An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I f 2015104 FOOTNOTE DATA Page: !Schedule 234 _ Line No.: 7 Column: b Advanced Capacity Payment Bonus/Wages Environmental Liability Injuries and Damages Nuclear Last Core Expenses Nuclear Maintenance Reserve Regulatory Liabilities SJRPP Decommissioning SJRPP Deferred Interest Storm Fund Storm - Regulatory Asset Unbilled Revenues Miscellaneous - Other Total [c_IJ__edule Page:-234 Line No.: 7 _C_o-'--'lu.:.:.m:.:cn:.:c.'-c'-----. Advanced Capacity Payment Bonus/Wages Environmental Liability Injuries and Damages Nuclear Last Core Expenses Nuclear Maintenance Reserve Regulatory Liabilities SJRPP Decommissioning SJRPP Deferred Interest Storm Fund Storm - Regulatory Asset Unbilled Revenues Miscellaneous - Other Total IFERC FORM NO. 1 (ED. 12-87) Page 450.1 $ ------20,803,087 I $ 42,130,833 9,046,705 9,449,543 29,757,445 18,620,353 11,465,396 13,839,216 8,597,688 13,595,749 33,217,812 62,251,901 43,037,795 315,813,523 $ $ 201 25-:3·,-226 49,494,719 9,247,332 6,709,949 34,291,433 18,281,415 10,432,422 14,342,383 7,323,957 13,978,148 31,682,409 21,133,019 47,970,138 285,140,550 Name of "'a" -,.,;u... of Report Date of Report (Mo, Da, Yr) This 'i!Jort Is: (1) An Original (2) -~ Resubmission Ill Florida Power & Light Company End of I I 2015/04 CP.PITAL ;:,svvM> (Account 201 and 2J4) 1. Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 1O-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 1O-K report and this report are compatible. 2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. Line No. 1 2 3 4 5 Class and Series or Stock and Name of Stock Series Number of shares Authorized by Charter Par or Stated Value per share Call Price at End of Year (a) (b) (c) (d) ,.,,.,,,.J Stock, $100 Par Value 10,414,100 100.00 s,ooo,ooo! '"''"'"''"' ~· No Par Value 6 SUL.v,~n•u•~u "'""'' "''u Slc:JC:~· No Par Value 5.000.000- 7 .' ·:·.>:/.: ·,:· 8 TOTAL t'KI::t •nn~J STOCK 9 10 I Common Stock 11 STOCK 12 !TOTAL 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 1,0001 .... 40 41 42 FERC FORM NO.1 (ED. 12-91) Page 250 " . . ·~ ;, ,. . " - This ~rtls: (1) An Original (2) [jA Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/04 End of CAPITAL STOCKS (Account 201 and 204) (Continued) 3. Give particulars (details) concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. 4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or non-cumulative. 5. State in a footnote if any capital stock which has been nominally issued is nominally outstanding at end of year. Give particulars {details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purposes of pledge. OUTSTANDING PER BALANCE SHEET (Total amount outstanding without reduction for amounts held by respondent) Shares Amount (e) (f) HELD BY RESPONDENT AS REACQUIRED STOCK (Account 217) ~pst S~ares (g) (h) IN SINKING AND OTHER FUNDS Sh:ues (i) Line No. Amount 0) 1 2 3 4 5 6 7 8 9 1,000 10 1,373,068,515 11 1,000 12 1,373,068,515 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 FERC FORM NO. 1 (ED. 12-88) Page 251 Name of Respondent Date of Report Year/Period of Report (Mo, Da, Yr) This Report is: (1) ~An Original I(~l A Resubmission Florida Power & Light Company I I 2015/Q4 FOOTNOTE DATA l§chedule Page: 250 No Par Value. !Schedule Page: 250 No Par Value. Line No.: 4 Column: c Line No.: 6 Column: c -~--------- ~~u/e Page: ____________=:=J i5o Line No.: 8 Co!ullJn: _::::_b _ _ _ _ _ _ __ None of these shares are outstanding. ---------------------- - - - - - - - . ~hedule Page: 250 Line No.: 10 --Co_l_u_m~n"---:-c_ _ _ _ _ __ No Par Value. --------- - - - - - - [Chedule Page: 250 _____ Line No.: 12 Column: b All shares are held by NextEra Energy, Inc. 1FERC FORM NO. 1 (ED. 12-87) Page 450.1 _ _ _ _ _ _ _ _ _ _ _ _ _ __ j BLANK PAGE (Next Page is 253) Name of Respondent This wort Is; (1) An Original (2) []A Resubmlssion Florida Power & Light Company Date of Report (Mo. Da, Yr) I I Year/Period of Report 2015104 End of OTHER PAID-IN CAPITAL (Accounts 208-211, inc.) Report below the balance at the end of the year and the infonnation specified below for the respective other paid-In capital accounts. Provide a subheading for each account and show a total for the account, as well as total of all accounts for reconciliation with balance sheet, Page 112. Add more columns for any account if deemed necessary. Explain changes made in any account during the year and give the accounting entries effecting such change. (a} Donations Received from Stockholders (Account 208)-State amount and give brief explanation of the origin and purpose of each donation. (b) Reduction in Par or Stated value of Capital Stock (Account 209): State amount and give brief explanation of the capital change which gave rise to amounts reported under this caption including Identification with the class and series of stock to which related. (c) Gain on Resale or Cancellation of Reacquired Capital Stock (Account 21 0): Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. (d) Miscellaneous Paid-in Capital (Account 211 )-Classify amounts Included in this account according to captions which, together with brief explanations, disclose the general nature of the transactions which gave rise to the reported amounts. '~if' .u~~. A'W>unt 1 Donations Received from Stockholders (Account 208) 2 3 4 Reduction in Par or Stated Value of Capital Stock (Account 209) 5 6 7 Gain on Resale or Cancellation of Reacquired 8 Capital Stock (Account 21 0) 9 10 11 Miscellaneous Paid-In Capital (Account 211} -As of December 31, 2014 6,281,993,846 12 Capital Contribution from Parent Company (NextEra Energy, Inc.) 1,454,006,154 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 TOTAL FERC FORM NO.1 {ED.12-87) 7,736,000,000 Page 253 Name of Respondent Florida Power & Light Company This wort Is: (1) An Original (2) _fJ_A Resubmission Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/Q4 End of CAPITAL STOCK EXPENSE (Account 214) 1. Report the balance at end of the year of discount on capital stock for each class and series of capital stock. 2. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged. [Una No. 1 Class and Series of Stock. (a} Balance at__t:;nd of Year (b) 2 3 Common Stock 3,741,472 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 3,741,472 22 TOTAL FERC FORM N0.1 (ED. 12-87) Page 254b Florida Power & Light Company L :>NG-TERM DEBl ~- =~~wrt This Report Is: (1) -~An Original (2) A Resubmisslon 1Name of, w~t-V ·~~"' v End of I I -~of Report 2015/04 1221, 222, 223 and 224) 1. Report by balance sheet account the particulars (details) concerning long-tenn debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other long-Term Debt. 2. In column (a), for new issues, give Commission authorization numbers and dates. 3. For bonds assumed by the respondent, include in column (a} the name of the Issuing company as well as a description of the bonds. 4. For advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received. 5. For receivers, certificates, show in column (a) the name of the court -and date of court order under which such certificates were issued. 6. In column (b) show the principal amount of bonds or other long-term debt originally issued. 7. In column (c) show the expense, premium or discount with respect to the amount of bonds or other long-term debt originally issued. 8. For column (c) the total expenses should be listed first for each issuance, then the amount of premium (in parentheses) or discount. Indicate the premium or discount with a notation, such as (P) or (D). The expenses, premium or discount should not be netted. 9. Furnish in a footnote particulars (details) regarding the treatment of unamortized debt expense, premium or discount associated with issues redeemed during the year. Also, give in a footnote the date of the Commission's authorization of treatment other than as 1"~-'"'"l"""u by the Uniform System of Accounts. ILine Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) No. (a) Principal Amount Of Debt issued (b) Total expense, Premium or Discount (c) 1 AC:C:OUNT 221 21 FIRST MORTGAGE BONDS: .2oo,ooo,ooo 315.850% DUE 2033 909,936 2,212,000 D 4 5!5.625% DUE 2034 ~ 2,200,402 nnn D ~;"-An 6 ">nn nnnnnn 7!5.950% DUE 2033 8 1,527,334 ono D !'i.Rn7 9!5.650% DUE 2035 240,000,00" 1,264,598 2,762,400 D 10 11 14.950% DUE 2035 'l.nn nnnnon 12 13 15.400% DUE 2035 'l.nn nnnnnn 1,603,257 .ll.n?r:; non D 15 !5.650% DUE 2037 16 ~ 1,993,136 !>.348.000 D 17 16.200% DUE 2036 -:tnnnnnnilri 1,634,975 A.RQ"'OM 14 D 1,733,917 2, 700.QCJ!l D 18 -.,--nnn nnn 19 J5.850% DUE 2037 20 21 J5.550% DUE 2017 22 .ll. m:;~; ,:;~;':\ 600,000 D '>1'11'1 nnnnnn 3,53~·~!4 84,000 D I 23 5.950% DUE 2038 24 .c:tnn nnn nnn 25 J5.960% DUE 2039 ~ flfi34395 27 I 5.690% DUE 2040 28 .:nn nnn nnn 6,907,060 29 !5.250% DUE 2041 30 Ann nnn nnn 670,000 D 5.220.828 31 15.125% DUE 2041 32 ~ 3,487,500 225,000 D 10,208,270,00C 153,012,581 26 365,000 D 992,000 D 33 TOTAL FERC FORM NO. 1 (ED. 12-96) 7,820,521 "~ ?F;.Il. non D Page 256 Date of Report (Mo, Da, Yr) Florida Power & Light Company I I End of 2015/Q4 10. Identify separate undisposed amounts applicable to issues which were. redeemed in prior years. 11. Explain any debits and credits other than debited to Account 428, Amortization and Expense, or credited to Account 429, Premium on Debt - Credit. 12. In a footnote, give explanatory (details) for Accounts 223 and 224 of net changes during the year. Wlth respect to long-term advances, show for each company: (a) principal advanced during year, (b) interest added to principal amount, and (c) principle repaid during year. Give Commission authorization numbers and dates. 13. If the respondent has pledged any of its long-term debt securities give particulars (details) in a footnote including name of pledgee and purpose of the pledge. 14. If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. 15. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (1). Explain in a footnote any difference between the total of column (i) and the total of Account 427, interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. 16. Give particulars (details) concerning any long-term debt authorized by a regulatory commission but not yet issued. Nominal Date of Issue Interest for Year Amount 9,808,271,000 FERC FORM NO. 1 (ED. 12-96) Page 257 417,392,137 Line No. 33 This ~ort Is: An Original (1) (2) flA Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/04 End of LONG-TERM DEBT (Account 221, 222, 223 and 224) 1. Report by balance sheet account the particulars (details) concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other long-Term Debt. 2. In column (a), for new issues, give Commission authorization numbers and dates. 3. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds. 4. For advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received. 5. For receivers, certificates, show in column (a) the name of the court -and date of court order under which such certificates were issued. 6. In column (b) show the principal amount of bonds or other long-term debt originally issued. 7. In column (c) show the expense, premium or discount with respect to the amount of bonds or other long-term debt originally issued. 8. For column (c) the total expenses should be listed first for each Issuance, then the amount of premium (in parentheses) or discount. Indicate the premium or discount with a notation, such as (P) or (D). The expenses, premium or discount should not be netted. 9. Furnish in a footnote particulars (details) regarding the treatment of unamortized debt expense, premium or discount associated with issues redeemed during the year. Also, give in a footnote the date of the Commission's authorization of treatment other than as specified by the Uniform System of Accounts. Une No. Class and Series of Obligation, Coupon Rate (For new Issue, give commission Authorization numbers and dates} Principal Amount Of Debt issued (b) (a) Total expense, Premium or Discount (c) 1 4.125% DUE 2042 600,000,000 8,250,000 2 3 4.055% DUE 2042 600,000,000 8,150,000 400,000,000 5,700,000 D 500,000,000 5,650,000 500,000,000 5,650,000 500,000,000 6,775,000 ~~n~L,~s1tii:I~J9Jl.~:P®. 6,600,000 1,482,000 D 4 840,000 D 5 3.800% DUE 2042 6 1,984,000 D 7 2.75% Due 2023 8 1,905,000 D 9 3.25% Due 2024 10 645,000 D 11 4.05% Due 2044 12 1,650,000 D 13 3.125% Due 2025 14 978,000 D 15 POLLUTION CONTROL, INDUSTRIAL DEVELOPMENT & 16 SOLID WASTE DISPOSAL REFUNDING BONDS: 17 18 CITY OF JACKSONVILLE POLLUTION CONTROL REVENUE 28,300,000 377,136 45,750,000 706,067 45,960,000 396,859 16,510,000 132,450 4,480,000 81,599 19 REFUNDING BONDS, VARIABLE RATE, SERIES 1992 DUE 2027 20 21 DADE COUNTY INDUSTRIAL DEVELOPMENT AUTHORITY REVENUE 22 REFUNDING BONDS, VARIABLE RATE, SERIES 1993 DUE 2021 23 24 CITY OF JACKSONVILLE POLLUTION CONTROL REVENUE 25 REFUNDING BONDS, VARIABLE RATE, SERIES 1994 DUE 2024 26 27 MANATEE COUNTY POLLUTION CONTROL REVENUE 28 REFUNDING BONDS, VARIABLE RATE, SERIES 1994 DUE 2024 29 30 PUTNAM COUNTY DEVELOPMENT AUTHORITY POLLUTION CONTROL 31 REV REFUNDING BONDS, VARIABLE RATE, SERIES 1994 DUE 2024 32 33 TOTAL FERC FORM N0.1 (ED. 12-96) 10,208,270,000 Page 256.1 153,012,581 INam-eorRespondent This (1) (2) Florida Power & Light Company ~c;!rt Is: ~An Original [= A Resubmission p~~~ g~~~~ort I LONG-TERM DEBT rAr.r.oun~ 221 222, 22 i and 224) (Continued) , .... ,,.. ..,,...u End of of Report 2015/04 10. Identify separate undisposed amounts applicable to issues which were redeemed in prior years. 11. Explain any debits and credits other than debited to Account 428, Amortization and Expense, or credited to Account 429, Premium Ion Debt- Credit. 12. In a footnote, give explanatory {details) for Accounts 223 and 224 of net changes during the year. With respect to long-term li::ld\ri:il show for each company: (a) principal advanced during year, (b) interest added to principal amount, and (c) principle repaid !during year. Give Commission authorization numbers and dates. 13. If the respondent has pledged any of its long-term debt securities give particulars (details) in a footnote including name of pledgee and purpose of the pledge. 14. If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. 15. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest .,..... .., ... """in column (i). Explain in a footnote any difference between the total of column (i) and the total of Account 427, interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. 16. Give particulars (details) concerning any long-term debt authorized by a regulatory commission but not yet issued. Nominal Date of ~~jue !12113/2011 Dale of Maturity (e) Io21o112o42 AMORTIZATION PERIOD (;rom 12/0112011 To (Total redu (g) 1o2to1/2042 Interest tor Year Amount 1-io'ruu • .._...._.~· '"';>'"''(hro ILine No. _@_ 600,000,00C 24,783,814 1 2 1o5/15/2012 1ooto1J2o42 I o51o112o12 I o61o112o42 . 600,000,00C 24,333,814 3 4 1o2t2o12o12 112115/2042 112101/2011 112/1512042 400,0D_0,00( 1<; ???-i:;.d• 5 Anvv,<-v13 IOS/0112023 1os1o1 12o13 1os1o 112o23 ~00~0 13,na.180 7 lo5/15/2014 106101/2024 1o61o1 12o14 1os1o112o24 500,000,00( 1"' ??o:t n'>.• Ei 8 9 10 1V<,.UL ""~" (k) .·Line No. Other · • (I) 1 2 16~80$3,624 3~~06,466 3 4 5 6 66,479,445 ':'<{;;:;;:,~'1 ...•. 416,755,744 7 8 ~582 9 10 11 12 ~ .d.~? ~4!=1312 4,096,762 y '~iii :,;:,m 13 00 ' 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 181 '144,261 FERC FORM NO.1 (ED. 12-96) 17,684,252 1,696,953,701 Page 28,768,701 263.1 41 This Report is: (1) ~An Original I(2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA ~chedu/e Page: 262 Une No.: 3 --~C~o~/u~m=n~:'~-----------­ Amount related to IRS Settlement and FIN48 \Schedule Page: 262 J.:-ine No.: 3 Column: I Account 409.2 )Schedule Page: 26?___ Une No.: 7 Column: I Account 107 & 108 Account 146 Total JSchedu{~f!~!le: 262 Line No.: 11 $ $ Line-No.: 16 Wch-edu/e Page: 262 __pne No.: Account 107 & 108 Account 146 Total 19 Line No.: 27 [Schedule Page: 262.1 ._ ... Line No.":i Account 254 Account 182 Account 904 Total ~~~!~- Pa__g_e:-262.1 --$ $ WCfeei:iiiTe-Page: 262 LineN..~~= 16 Column: Amount related to IRS Settlement !Schedule Page: 262 Account 588--... ·-······ $ Line No.: 14 r (7,834,542) 21,354,370 642,119 21,996,489 154,476 17,621 172, 097 -·-·-··~-·- Column: 1 .:....:___ _ _ _ _ __ $ 3, 946,321 $ ( 1, 326, 202) $ $ 318,506 47,399 365,905 $ 1,081,645 Column: 1 Column: I :.:....:__ _ _ _ __ Column: 1 --$ $ 5,246,737 5,599,615 (346,081) 10,500,271 Column: I Account 408 Acco~nt 143 Account 256 Total lFERC FORM NO.1 (ED. 12-87) ... Col:_.::u~m.::.n:.:.:...:.l _ _ _ _ __ Account 107 & 108 Account 146 Total !Schedule Page:_~~? Account 4 0 9. 2 ··--·-] 2 3 , ~~_?J_l.~ $ $ $ Page450.1 99C617 2,859,189 (37,768) 3,813,038 BLANK PAGE (Next Page is 266) Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and operations. Explain by footnote any correction adjustments to the account balance shown in column (g) .Include in column (i) ~...~r~·~~ period over which the tax credits are amortized. ~-- ---- ·- --------- - -- ~- - - - ----- ___,__, ~---- ...... _~~---.=-·-::··---- --~-----~-- 1 - ' l FERC FORM NO. 1 (ED. 12-89) - -- ~ ~ -"----'..- • Page 266 -- - ~ ~ -- J ~ ~ = ' - . -'"- ~ ~ ~ -~ _........,._ -~~- - - . -~- -- ~--- ,_ IName of ~"''"f'UIIut:m 1'his ~ort Is: (1) (2) Florida Power & Light Company 4 740,055 N 'lUI II '\'TEO ·[X An Original L A Resubmission [)ate pf Report (Mo, Da, Yr) OfRePort I ""II !"'"toi!OIJ End of 2015/04 t ~l'iJ:?I=r 1 INVt:l:> fliiiENT TAX GKt::UII s (ACCOUnt 255} (continu,~d) 33 years 4 33years 2,227,095 5 years 30years 7 8 9 12 13 16 20 21 25 26 30 31 32 33 36 38 40 42 43 44 47 48 FERC FORM N0.1 (ED. 12-89) Page 267 Name of Respondent Florida Power & Light Company ~r ~~~~ ~~~~~"~:ssion ~~gort • <>au End of I I <>IIUY ofReport 2015104 O'fHER Ut::.l-r-t:Kt:.U CREDITS {Accoun • 253) 1. Report below the particulars (details) called for concerning <;~ther deferred credits. 2. For any deferred credit being amortized, show the period of amortization. 3. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes. uescnpuu11 and Other Deferred Credits lune No. 2 ; o.re,l,~ at ~~~ (b) ?2 ?R8?.40 5s5 ~Power Costs Accrued 73,032,25' 555 Er,viru"' lental Claims 23,295,274 Amount {d) 5 6 9 To Other Deferred Credits Mise .... ·· .. ·~ 59,3~102 (e} (f) ,··. 1,304,388 65,252,759 ••..·. .!11 547,403 '1-:D67.499 23,815,370 II· 192,7s8,810 198,362,484 64~6 .;··: 6,006,224 18,986,278 '"'"~~lin 7 8 Balance End of Year 3,301,962 3 4 Credits DEBITS Balance at Beginning of Year Q -444 602,645 ... 539,373 ~ 8,611,219 206,834,073 200,957,857 189,012,981 7,403,579 11 12 Minor Items 6,927,106 . ···: ,., . 13 -14 15 16 17 -,8 19 2o 21 22 23 24 25 26 27 2a 29 30 31 32 33 34 35 3s 37 38 39 4o 41 42 43 44 45 4s 47 TOTAL FERC FORM NO. 1 (ED. 12-94) 194,889,197 Page 269 Name of Respondent This Report is: {1) 6An Original {2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 FOOTNOTE DATA f$chediile--Page: 269 Line_ No.: 1 Column: a St. Johns River - The deferred interest payments are --'being amortized over the original life of the St. Johns River Power Park bonds (1987-2020) 'f$chedule Account Account Account [chedule Account Account Account Account Account Account Account Account Account Account Account Page: 269 232 920 930 Total Line No.: 6 Page: 269 182 131 232 920 107 426 4xx 143 408 404 242 Total Line No.: 8 Column: c -~~~~~---------------- 494,512 37,103 15,788 547,403 $ $ - ----·· ------------------------------, Column: c -~~~~------------- $ $ ,-----,------,---...,-----,----=-=--~--~---:-c::---::-:--·------- Line No.: 12 IFERC FORM NO. 1 (ED. 12-87) 127,056 864,937 20,430,414 8,208 153,431,342 700,000 10,389,274 6,177,356 10,293 42,541 577,390 192,758,810 ...... [Schedule Page: 269 Line No.:_tf! __C=..o::::l:.=u.=.!m~n~:-=a:________,--______"'"7"_ __ Premium lighting projects are amortized over a twenty year period. amortized began in the years ranging from 2002 to 2012. )Schedule Page: 269 Account 409 Account 232 Account 421 Total .~=:J Projects being Column: c $ Page450.1 -------~ 244,058 281,868 13,447 539,373 Date of Report (Mo, Da, Yr} This ~ort Is: (1) ~An Original (2) A Resubmission Name of Respondent Florida Power & Light Company Year/Period of Report End of 2015/04 I I ACCUMUlATED DEFFERED INCOME TAXES- 0 ER PROPERTY (Account 282) 1 . Report the information called for below concerning the respondent's accounting for deferred income taxes rating to property not subject to accelerated amortization 2. For other (Specify), include deferrals relating to other income and deductions. CHANGES DURING Line No. Account Balance at Beginning of Year (a) (b) YEAR Amounts Debited to Account 41 0.1 Amounts Credited to Account 411.1 (c) (d) 1 Account 282 2 Electric 6,572,756,582 1,997,324,046 1,483,698,439 6,572,756,582 1,997,324,046 1 ,483,698,439 6,572,701,138 1,997,324,046 1 ,483,698,439 5,856,755,121 1,660,503,097 1,234,971,352 715,946,017 336,820,949 248,727,087 3 Gas 4 5 TOTAL (Enter Total of lines 2 thru 4) -55,444 6 Non Operating 7 8 9 TOTAL Account 282 (Enter Total of lines 5 thru 10 Classification ofTOTAL 11 Federal Income Tax 12 State Income Tax 13 Local Income Tax NOTES FERC FORM NO. 1 (ED. 12-96) Page 274 End of 2015/04 3. Use footnotes as required. Balance at End of Year NOTES (Continued) FERC FORM NO. 1 (ED. 12-96} Page 275 Une No. This Report is: (1) ~An Original (2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA !Schedule Page:··274 Line No.: 2 Column: i ""A-'-c"'"c-=-ou=-n=t:-='--':1:;-';8'=":2~.~3-c=--'-----=~'--'-'-~-=---'=-=-=-'-'-'-"-------- Account 254.1 Total IFERC FORM NO.1 (ED. 12-87) --- · -- ·······-------------,$:;:-----;;1,.-;8;;-,-;:0:-;;8""7-,..,.8..,.8~0 $ Page 450.1 1, 836,894 19,924,774 BLANK PAGE (Next Page is 276) Name Florida Power & Light Company 1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283. 2. For other (Specify),include deferrals relating to other income and deductions. Account 1,295,971,116 90,553, 1 '111 ,192,343 184,nB,773 23 Local Income Tax NOTES FERC FORM NO.1 (ED. 12-96) Page 276 23,233,967 ndent Florida Power & Light Company Provide in the space below explanations for Page 276 and 277. Include amounts relating to insignificant items listed under Other. Use footnotes as required. Line No. NOTES (Continued) FERC FORM NO.1 (ED.12-96) Page 277 This ~ort Is: Date g~~~~ort (Mo, {1) -~An Original I I iA Resubmission (2) a· "HER RFI Ill A,TORYLIABILITIES \Acicount 254) Name of "'"""'v"u"'"' Florida Power & Light Company YeadP~nvdofReport End of 2015/Q4 1. Report below the particulars (details} called for cone€lrning other regulatory liabilities, including rate order docket number, if applicable. 2. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. 3. For Regulatory Liabilities being amortized show period of amortization. Description and Purpose of Other Regulatory Liabilities Line No. Balance at B"ll"""\l of Current QuarterlY ear ~~~~~ (b) (a) Balance at End of Current Quarter/Year DEBITS Amount Credits (d) (e) (f) I 1 Deferred Interest Income - Tax Refunds 21 (5 year a> UU> u..ii~vo >·various periods) 6,016,350 1,937,46! 4,078,fl_84 419 3 41 Deferred Gains on Sale of Land -·• ,,,_,_,II 6,606,~52 29,098,176 5,246,738 14,172,19) 8,925,455 vao•"~l 896,268 2,674,546 2,656,860 year ciiiiVI ULlli 11,302,463 5,025,843 5 (5 year vuu"' "'"""Cost Recovery I 20 Clause Revenues 21 I 22 Deferred r Assessment Fee In, 23 '"'"J Fuel Clause~even~e~ ·FERC M 24 Interest on Uncertain Tax Issues 25 I (5year ',.ft.. r· -~• 981,106 981.10f 26 I 27 Nuclear Cost Recovery 28 1year all lliiLI<.CHIVIl· VarioUS periOdS ~;H't' 389,712,873 210,642,614 212,B52,t oo< noonoo ' 29 30 I Solar vonveroo~e ,,.,,,,.,1.,,1 Tax Credit 31 ! {30 year"" ovn1"'""'1 -various periods) 99,809,813 407.4 3,896,532 95,913.281 1,434,662 407.4 1,229,710 204,952 32 I I 33 Deferred Gain Aviation Group 34 (5 year u" >V> "='""'I 35 26,947,238 F 36 I Deferred Income Taxes '"':" 3,191,129 321, .. · . ' ;·' :~i#;·~;; 37 38 Solid w, ..t .. A11thnrity Power Contract- ECCR 39 -Deferred Revenues (19 year ">La'"'"· 53,928,936 456 1.425,431 52,503,501 40 41 TOTAL FERC FORM NO. 1/3-Q (REV 02-04) 2,877,757,733 Page 27B 712,791,207 629,161 ,424 2,794,127,950 Name of Respondent This Report is: (1) 2S; An Original (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA ISchedule Page: 278 -=L=in=e~N=o,_,_.:~5-~c=o~lu~m~n!:._:~c:.______ ··-----"J ·--------------.,.$------:9::-:2o-' 10,872 6,595,788 $ 6,606,752 Account 186.5 Account 107 Account 407.4 Total [Schedule Pag_e: 278 Line No.: 7 Account 182.3 Account 254 Account 408 Account 904 Total ~!JfJdUie Page: 278 Account 175 Account 182.3 Total ~eiiuie Page: 278 Column: c ------------------ $ Line No.: 9 ··--· Column: c $ $ Line No.: 13 [Sc--:-h-ed--=-u-=-le-__P-=_a__ J-l.~--:._-2=-=7=-=8=---=L-=in-e--=-N-=-o~: iii 49 241,668 Column: c $ 344,896, Account 108 Account 230 Account 407.4. Total Account 101 Account 106 Account 107 Account 182 Account 254 Account 407.3 Account 407.4 Account 407.7 Account 419 Account 432 Total 896,268 1,778,278 2,674.,54.6 ----------,:---------.,·___ =-::J $ 241,619 Column: c $ Line No.: 15 543,466 454,588 13,168, 411 5,732 14,172,197 ·····-·---·--··-··--------- ~~-------------------- Account 411 Account 555 Total jScheduii; Page": 278 $ {22. I 1,021,323 79,777, 911 $ 425,695,856 - ca-=1:---um_n_:_c_ _ _ _ _ _ _ _ _ _ _ _ _ __ ·-·· ---------- -------------------------;o$ ·154··;'h 9, 8 91 448,021 1,200,610 986,245 24,936,085 5,914,683 14,517,032 812 7,632,825 226,410 $ 210,642,614 /Sch-e._d--c__ u___!,-e--=P,...a_g_e_:-=-27=8=----=L-:i-n-e-=-N:-cl.:--3if - Co---,lu_m_n_;_c__._-___-__-__-_- - - - - - - - - - - Account 190 Account 282 Total $ $ 1,354,234 1,836,895 3,191,129 [Sch~c!'!te.. Page: 278 Line No.: 3tf --Column: f _______ _ _ j Schedule No. 317 formula rate utilize-s--the sirriple average balances (average beginning and ending balances) for all rate base inputs. Schedule No. 322 formula rate utilizes the simple average balances (average beginning and ending balances) for all rate base inputs. IFERC FORM N0.1 (ED. 12-87) Page450.1 Date (Mo, Florida Power & Light Company I I End of 2015104 1. The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (1), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required In the annual version of these pages. 2. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. 3. Report number of customers, columns (l) and (g), on the basis of meters, In addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The -average number of customers means the average of twelve figures at the close of each month. 4. If Increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. 5. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Title of Account 27 TOTAL Electric Operating Revenues FERC FORM NO. 113-Q (REV. 12-05) Page 300 Florida Power & Light Company 6. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Unlfonn System of Accounts. Explain basis of classification in a footnote.) 7. See pages 108-109, Important Changes During Period, for important new territory added and important rate increase or decreases. 8. For Unes 2,4,5,and 6, see Page 304 for amounts relating to unbllled re~enue by accounts. 9. Include unmetered sales. Provide details of such Sales in a footnote. 4,775,381 Line 12, column {b) includes$ 0 of unbilled revenues. Line 12, column (d) includes 0 MWH relating to unbilled revenues FERC FORM N0.1/3-Q (REV.12-05) Page 301 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original (2) A Resubmission I Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA l§_chedu/e Page: 300 Une No.: 14 Column: d Does not include the increase in energy delivered to customers but not billed of 626,752 MWH for the twelve months ended December 31, 2015. The unbil1ed revenue is included in other electric revenues (account 456). [~chedule Page: 300 une No.: --------------·--·-··---------~----·-----------Check Service Charges $ 5,763,568 Investigation Cost- Current Diversion 1,068,505 Initial Charges 780,605 Reconnect Charges 13,625,766 Service Charges 17,391,862 Marketing Services 1,047,482 Reimbursable Projects Overhead Recoveries 2,027,945 Temporary Services Of Less 'I'han One Year (2, 314, 820) Amounts of $250,000 and under (55,114) Total $ 39,335,799 ·rr--Ccifiimn:ii -----------.. _______) WCiCedliiePage":-3oo- Line No.: 21 Column: b Corporate Recycling Service --------------------· ------·------------Performance Contracting Use Charges Unbilled Revenues Deferred Clause Revenue Bill Statement Advertising Revenue Biodiesel Fuel Third Party Sales Amounts of $250,000 and under Total IFERC FORM NO. 1 (ED. 12-87) Page 450.1 $ $ 1,887,341 2,775,167 1,799,915 23,073,093 33,395,982 395,838 2,396,736 718,906 66,442,978 Name of Respondent This ~ort Is: (1) An Original (2) lJA Resubmission Florida Power & Light Company Date of R~ort (Mo, Da, r) I I Year/Period of Report 2015/04 End of SALES OF ELECTRICITY BY RATE SCHEDULES 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues, • Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries In column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule haVing a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. !Line No. NUmDer ana IItie or Kate scneaule Kevenue IVIVVII .:>010 (a) (b) Aver~~~fumDer ofC somers (c) ~~?~s~oa::r ~6~okter (f) 1 Residential: 2 011-012 3 044, 047, 048 4 045, 145 5 043 6 Subtotal 7 Commercial: 32,27C 58,810,81E 7,366,618 6,278,283,164 3,095 4,224,216 10,426 13,922 3,254 319,585 114 28,544 0.2283 0.1068 0.0982 58,846,342 6,285,969,367 4,227,425 13,920 0.1068 2,390 262 28,133 0.1658 0.0636 0.0841 8 011-012 67,239 11,145,764 9 054-056 10 062 2,205,82~ 140,284,873 300,378,901 3,572,58~ 11 063 12 064 13 065 440,53:0 34,312,815 316,918,014 4,406,19~ 1,193 32 1,045 60 407,326 493 3,957 889,535 6,094,918 18,451 2,312, 12'1 60,351,123 652,483,995 1,847,659 H 072 21,838,50~ 48,886 1,957,442,01 3,859,757 95,759 19 073 2C 074 1,717,701 4 2 6 14 067-068 15 069 16 070 180,401,821 8,419,176 2,994,621 13,766,625 4,216,455 14,825,583 14,963 37,426 584,312 0.0779 0.0719 0.0678 0.1071 0.1001 0.0780 17 071 24,468 36,481 14,268 21 075 2;, 085 2:1 086 24 087 25 104,804 20,962 59,874 1,369,291 878,178 2,606,21 1,567,125 2,258 33,524,052 1,622,811 7,234,694 25 2E 21 28 29 090 168 164 165 170 30 31 32 33 34 35 36 37 38 264,354 265, 365 270,370 851-853 1,076,491 937,972 123,051 813,313 4,56{ Subtotal 47,358,529 99,652,40 60,725,916 79,239,221 85,374,781 8,346,688 77,412,58c 647,695 4, 119,100,88 347 717,016 1,245,315 24,003 63,642 55,477 45,367,771 67,749,829 1,731,023 5,714,272 ( 0 9 5,963 1 10,869 274 32 829 399 10 1,794 5 532,727 228,057 3,760,462 6,117,000 18,240,500 2,378,000 2,778 17,576 0.0896 0.0790 0.0702 0.0714 0.1098 0.0903 20,962,000 6,429 0.3199 0.0774 0.1035 4,997,412 27,443,063 1,298,542 2,350,807 12,305,100 453,352 0.0728 0.0691 0.0736 0.0910 0.0678 0.0952 912,000 88,917 0.1420 0.0870 43,375 10,544,353 77,832,188 2,000,250 2,545,680 0.1599 0.0633 0.0544 0.0721 0.0898 ( 0.000 0.000 0.000[ Industrial: 011 054 055 39 056 40 062 41 42 43 13 TOTAL Billed Total Unbilled Rev.(See lnstr. 6) TOTAL FERC FORM NO.1 (ED. 12-95) ~~;i~,£ii:t;~o.tp; 8 58 16 1< 25 cC·t''•!oo''iC1 ( c 0 Page 304 [ ( Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) This ~ort Is: (1) An Original {2) [)A Resubmission Year/Period of Report End of 2015/Q4 I I SALES OF ELECTRICITY BY RATE SCHEDULES 1 .. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-311. 2. Provide a subheading and total for each prescribed operating revenue account In the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more them one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading. ~wn_or~es Average_ Numoer Kevenue ~Wh;:>OKl rune Number and JJIJe or ~are schedule Per ~~stomer of c(~)omers (c) No. (b) (a) ~~~0~er (f) 1 063 45,715 3,360,938 3 15,238,333 0.0735 2 064 3 065 158,089 11,807,675 31 5,099,645 0.0747 58,030 4,325,918 6 9,671,667 0.0745 70,661 9,785 7,221 0.1133 0.1032 5 069 483 8,005,975 49,857 27 17,889 6 070 21,931 2,028,210 85 258,012 0.0925 7 071 24,228 1,711,501 1 24,228,000 0.0706 8072 9 073 197,178 19,628,498 1,143 172,509 0.0995 14,464 1,446,757 6 2,410,667 0.1000 10 074 11 075 12 082 14,688 1 ,083,133 4 3,672,000 0.0737 9,837 26,012 789,874 1 9,837,000 2,000,386 1 26,012,000 0.0803 0.0769 11,789,125 0.0792 32,157,250 0.0667 4 067-068 94,313 7,472,373 128,629 8,576,076 8 4 16 164 26,706 1,829,109 2 13,353,000 0.0685 17 165 23,075 1,601,524 2 11,537,500 0.0694 0.0755 13 085 1~ 090 15 168 6,959 525,062 15 463,933 19 264, 364 20 265, 365 18,483 1,537,550 5 3,696,600 0.0832 33,738 3 11,246,000 0.0802 18 170 21 270, 370 13,285 2,705,562 1,191,746 0.0897 5,401 588,662 56 1 237,232 22 852-853 5,401,000 0.1090 23 Subtotal 3,042,228 202,8B4,75a 11,318 268,796 0.0667 0.0890 24 Public Street & Highway Lighting: 25 086 31,121 2,769,824 865 35,978 26 087 417,016 74,975,128 2,818 147,983 0.1798 27 Subtotal 28 Other Sales to Public Authorities 29 019 448,131 77,744,952 3,683 121,677 0.1735 11,296 12,084 1,589,029 820,433 184 61,391 23,380 2,409,462 12,084,000 126,378 0.1407 0.0679 31 Subtotal 32 Railroads and Railways: 1 185 33 080 91,781 8,181,365 27 91,781 8,181,365 27 3,399,296 3,399,296 0.0891 109,820,397 '22!:!\i'tq;!;,®.~.ElP~Z~ 4,775,365 22,997 0.0974 0 0 0 c c O.OOOQ 0.0000 0 q c o.oood 30 090 34 Subtotal 35 36 37 Total 0.1031 0.0891 38 39 40 41 42 43 TOTAL Billed Total Unbilled Rev.(See lnstr. 6) TOTAL FERC FORM NO. 1 (ED. 12-95) 0 '~?.i'if'.c~'x:: ''"'"';:!!;'~:;' q Page 304.1 Name of Respondent Florida Power & Light Company This Report is: {1) X An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA f$chedule Page: 304.1 Line No.: 37 Column: c Fuel Adjustment included in revenues: $3,510,475,167 ~.f!_dule Page: 304 Line No.: 42--·--:;;c=-'o7 1u=-m-=-n-=-_;-=-b~_:...._'-'_c_.: ....:....:_~~--..:::.__,_.::c...:....:....__ _ _ _ _ _ _ _ _ _ _ __ (a) Total Revenue does not include unbilled revenues. r5chedule PE!_g_e: 304 Line No.: 42 -cofiim-n=::.::.:c:...:::..::...:::.::..:::_.::.::....::...:...=.:._-=-_:.... _____ Includes $0 of unbilled revenues. =__:.____.:-_-___-_ - - - - - - - - - - - - - !FERC FORM NO.1 (ED.12-87) Page 450.1 Date Report (Mo, Da, Yr) Florida Power & Light Company I I End of 2015/04 1. Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ- for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF -for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF -for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than frve years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service·, aside from transmission constraints, must match the availability and reliability of designated unit. IU -for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Name of Company or Public Authority (Footnote Affiliations) FERC Rate Subtotal RQ Subtotal non-RQ 0 Total 0 FERC FORM NO. 1 (ED. 12-90) Page 310 Date of (Mo, Da, Florida Power & Light Company I I OS -for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ safes, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotai-Non-RQ" in column (a) after this Listing. Enter "Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. S. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns {d), (e) and (f). Monthly NCP demand is the maximum metered hourly (SO-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (SO-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. B. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column 0). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ!Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal- RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 ,line 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours Sold 2,974,841 0 88,205,561 0 88,205,561 9,584,865 207,599,348 88,205,561 204,254,132 500,059,041 FERC FORM N0.1 (ED. 12-90) Page 311 Name Respondent Florida Power & Light Company 1. Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ- for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF -for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF -for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU -for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Name of Company or Public Authority (Footnote Affiliations) FERC Rate Subtotal non-RQ Total FERC FORM NO.1 (ED. 12-90) Page 310.1 Average Monthly Billing Demand (MW) Name of Respondent Florida Power & Ugh! Company This ~art Is: Date of Report (1) X An Original (Mo, Da, Yr) I I (2) CJA Resubmlssion SALES FOR RESALE (Account 447) (Continued) Year/Period of Report 2015/Q4 End of OS -for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out..of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotai-Non-RQ" in column (a) after this Listing. Enter "Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak {CP) demand in column {f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column G). Explain in a footnote all components of the amount shown in column (j). Report in column {k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal- Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours Sold REVENUE Energy Charges Demand Charges ($) (h) (g) ($) ($) Total($) (h+i+j) (i) Jj)_ (k) Other Charges Line No. 472,582 15,091,269 15,091,269 1 5,821 189,183 189,183 2 34,326 1 '141 ,982 1,141,982 3 337,188 10,713,199 10,713,199 4 285,893 11,637,878 11,637,878 5 344,573 2,371,654 2,371,654 6 2,750 92,300 92,300 7 102 32,086 32,086 a 94,783 3,919,705 3,919,705 9 104,269 3,717,291 3,717,291 10 1,279 39,150 39,150 11 7,383 132,278 132,278 12 155,722 5,651,230 5,651,230 13 25,978 829,460 829,460 14 6,610,024 207,599,348 0 204,254,132 411 ,853,480 2,974,841 0 88,205,561 0 88,205,561 9,584,865 207,599,348 88,205,561 204,254,132 500,059,041 FERC FORM NO. 1 (ED. 12-90) Page 311.1 Name Respondent Date (Mo, Florida Power & Light Company I I Year/Period of Report 2015/04 End of 1. Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF -for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU -for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. Line No. Name of Company or Public Authority (Footnote Affiliations) Statistical Classification (b) FERC Rate Schedule or Tariff Number Average Monthly Billing Demand (MW) 0 Subtotal non-RQ 0 Total D FERC FORM NO.1 (ED.12-90) Page 310.2 Name of Respondent Florida Power & Light Company This ort Is: Date of Report (1) X An Original (Mo. Da, Yr) I I (2) [j_A Resubmission SALES FOR RESALE (Account 447) (Continued) Year/Period of Report 2015/04 End of 00 OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" In column (a). The remaining sales may then be listed in any order. Enter "Subtotai-Non-RQ" in column (a) after this Listing. Enter "Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (50-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column 0). Explain in a footnote all components of the amount shown in column 0). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal- RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401 ,iine 24. 10. Footnote entries as required and provide explanations following all required data. MegaWatt Hours Sold REVENUE Energy Charges ($) Demand Charges ($) (h) (g) ($) 0) ~) Line No. Total($) (h+i+j) Other Charges (k) 4,603 150,695 150,695 1 238,277 1,615,294 1,615,294 2 6,515 252,080 252,080 3 169,122 5,566,095 5,566,095 4 35,688 1,148,579 1,148,579 5 88,070 2,606,345 2,606,345 6 165,263 4,729.759 4,729,759 7 106,089 5,318,347 5,318,347 8 188,784 6,269,076 6,269,076 9 97,933 4,936,535 4,936,535 10 1,600 51,200 51,200 11 12 13 14 6,610,024 207,599,348 0 204,254,132 411,853,480 2,974,841 0 88,205,561 0 88,205,561 9,584,865 207,599,348 88,205,561 204,254,132 500,059,041 FERC FORM N0.1 (ED. 12-90) Page 311.2 Name of Respondent This Report is: (1) 0 An Original (2) A Resubmission Florida Power & Ught Company Date of Report Year/Period of Report (Mo, Da, Yr) 2015/04 I I FOOTNOTE DATA [sCiJecTU/e Page: 310 Line No.: 1 Co/Uf11!l.U_.___ ----------·····-·-·-··--·-·----·····-·------·---···"Other Charges" - customer charge, fuel adjustment and fuel adjustment true-up, as applicable, relating to current year_'_.? __!ran_l';;_~ctio._n_s_._ __ [Schedule Pag_~; 310 Line No.: 2 Column: j "Other Charges" - customer charge, fuel adjustment and fuel adjustment___true=u:J?:·--as applicable, relating to current year's transactions. l§.£ttecfule f'age: 310 Line No.: 3 i - - - - -__-_-_-.-------_-_-_-_-__-_-_-__-___-.--------------, "Other Charges" -customer charge, fuel adjustment and fuel adjustment-true-up, as --coiiimn: ~h~~~fe~~=~e:r;:;~~Zi~et.,.: Nc:.0o-=-: .: ·~-~=-r-r,e-=~-=~c:./u=-~:.:e: .: :.:.: r~j'- ,-s.--t_r_a,n;-s-a...,c,-t_l_·-o.,..n_s_._;---,;o--~---;--;---:---..,.---·--·--:-------------. -_._--_-_-_-____. _____] "Other Charges" - customer charge, fuel adjustment and fuel adjustment true-up, as applicable, relating to current year's transactions. ~~~uJe PaJLe: 310 Line No.: 5 Column: j ____._.....................____________................--------------·--- .... ________ ...................~ "Other Charges" - customer charge, fuel adjustment and fuel adjustment true-up, as to current year's transactions. f§Chedule Page: 310 Line _fi'!~~~----(;_CJ]':!.'!'!J: a____ ·~.--,--,------=,------.--,-----------------_J Complete Name: City of New Smyrna Beach Utilities Commission [~chedule Page: 310 Lineli0.:6__ .... --.---------=-~-----. "Other Charges" - customer charge, fuel adjustment and fuel adjustment true-up, as applicable, relating to current year's transactions. /!lchedule Page:31o--- -Line No.: 7 Column!..L "Other Charges" - customer charge and fuel ad]u-stl:i1enF-as-appT[cab1e~ relating to current year's transactions. . ...........- - - - · - - - - - - - - - - - , f&!J.edl!_!!!__f.t;~_gt3_: 310 Line No.: 8 Column: j "Other Charges" - customer charge and fuel adjustment, as applicable, .relating to current year's transactions. ~~hedule Page: 310 Line No.: 9-·---coll.iiiin: h ·----------··---------· _ __ _ __ j Opportunity Sales - Sale. of power ':lE~rl:_(J_en~ECl.:t_~_<:?I]:__c;gst~--~!:.~~~~:r: than ·pr::Lces: ~£fJ~_c!.'!!!!.f!.age: 310 Line No.: 10 Column: b ... __ ] Opportunity Sales - Sale of power when generation costs are lower than market prices. applicabl~I---~elating coiiirrinT----·-------------.---------._-..-. . -.. -. marke-t :=J [Schedule Page: 310 iiileiio::"fi-·-coiiilnn:b. . ___ Opportunity Sales - sa~~-:?.-! __ p_(l~~~--->:!:1?:~!!..9~-~E!E~!1-.9.!l__ costs are lower than--market prices. [Schedule Page: 310 Line No.: 12 Column: b ______ _] Opportunity Sales- Sale of power when generation costs are lower than marketpri~~j-~ [Schedule Pag£!:}_12 ____ Line No.: 13 Column: b --- ----} Opportunity Sales - Sale of power when generation costs are lower than market prices. [S~hedule Page: 310 Line No.: 14 Column_:_b_~-- Opportunity Sales - Sale of power when ~chedule Pag_~: ~..!.O:L Line No.: 1 Column: b Opportunity Sales - Sale of power when [Schedule Pag_~:-~1P~_L __ Line No.: 2 Column: b Opportunity Sales - Sale of power when [Schedule Pari9:-317f1 ...__i..ine No.: 3 Column: b Opportunity Sales - Sale of power when [c__l)_f}t!._'!_!~.f'age: 310.1 Line No.: 4 Column: b .............. -.........----- ............................................................... generation costs are lower than market prices. - ---· ·1 generation costs are lower than market prices. --] generation costs are lower than market prices. generatic)n--costs ar.eiower-tha_n.. ----- ----- ·· marke-t"-pr:Lc-es-~- =---:J - ------- --- · - - - - - ............................ ________ . ··· - ------~ Opportunity Sales - Sale of power when generation costs are lower than market prices. 2£_1)__edule f.~~: 310.1 Line No.: 5 Column: b ---------·-----··--------··--·-·-·····--·--] Opportunity Sales - Sale of power when generation costs are lower than market prices. ~iiiiiiiPiige: 310.1 Line No.: 6 Column: a THE FOLLOWING PORTION OF--THI"S'"- FOOTNOTE--APPLIES TO- ALL OCCURRENCES-O"F "FLORIDA MUNICIPAL POWER AGENCY" ON PAGES 310-311: lfERC FORM NO.1 (ED.12-87) Page 450.1 Name of Respondent This Report is: (1) ~An Original (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of-Report (Mo. Da, Yr) I I 2015/Q4 FOOTNOTE DATA St. Lucie Unit 2 is jointly owned by Florida Power and Light Company (85.10449%), Florida Municipal Power Agency {8.806%) and Orlando Utilities Commission (6.08951%) '$chedule Page: 310.1 Line No.: 6 Coiuliii1:b.. ·--------··--~ Opportunity Sales - Sale ..:?J~ .. .E~wer when generation costs are-lOwer than market prices. ~hedule Page: 310.1 Line No.: 7 Column: b Op ortunity Sales - Sale of power when generation costs are lower than market prices. checiiiie Pa e: 310.1 Line No.: 8 Column: b Opportunity Sales - Sale of power-when·-·generation costs are lower than market--~s-.---·--·-!Schedule Page: 310.1 Line No.: 9 Column: b .... Opportunity Sales - Sale_§_f~~E~Y"er when generation costs are lower than.rriarket prices. ~chedul~_f!5J.e: 310.1 Line No.: 10 Column: b Opportunity Sales - Sale of power when generation costs are lower than market prices. f§Ciiediiie-Page: 310.1 Line No.: 11 Column: b ________.... · Opportunity Sales - Sale of power when gei:l'e.rat-lc-.o-n--c-o_s_t_s_a_r_e_l~o-w_e_r_t_h_a_n_m_a_r~ket.pr.ic-es·:---·rgcheduie Page: 310.1 Line No.: 12 Column: a _ _-_---_-·_ ....._....._._____. _ _ _ _ _ __ Complete Name: Midcontential Independent·"~System Operator --···--~-------~····-------~-----jSchedu/e Page: 310.1 __Y.!!~-!!.~-= 12 /J · ----~....::..::c=---=-LC:.---=--=-=-==---_. .--------.. --.. -....-.. --:,-_-_-_-_-_-_. . . . ._....-,-...._. . ._.__--.-___~~~~~~__j Opportunity Sales - Sale of power when generation costs are lower than market prices. l$chedule Pagf!.:_~J~L- Line No.: 13 Opportunity Sales - Sale of power when generation costs a:r:~~:J~:~r than market prices. [Schedule Pagei.31ii1--Line No.: 14 Column: b _............ · · - - - - - - - - = - - - - c - : - - - - - = Ql?.portU!l:~!:.Y... !?.~:!:.~s - Sale of power when generation costs are lower than marke't--pricE;s:--· · ~chedule Page: 310.2 Line No.: 1 Column: b Opportunity Sales - Sale of power wf:~!l:..jEir;:~ration costs are lower than ma:~E~t'--pr~ce-s-.----. ___ 1 'tSchedule Page: 310.2 ___f::.!r'e_f!'!·: 2 Column: a THE FOLLOWING PORTION OF =TH=I-=s-=Fo-=-o=T""'N:-o-O""T""'E=--A=P=-P=L=-r=E=s=-=ro-=--A::-cL"'Lo--O.,..C-=-c=URRENCES--OF "ORLANDO UTILITIES COMMISSION" ON PAGES 310-311: column: "iioliiiiiii:-b---· St. Lucie Unit 2 is jointly owned by Florida Power and Light Company (85.10449%), Florida Municipal Power Agency (8.806%) and Orlando Utilities Commission (6.08951%) l§chedule Page-:31ii.2 Line No.: 2 Column: b ............... Opportunity Sales - Sale of power w_t:~ri-i~'rieration costs are lower than market prices. . 'tSchedu/e Page: 310.2 ... !:.!!!.f!_!{C?-= 3 --=C=o::..:lu::::m:.:;n~:~b=--------:-.,------,--opportunity Sales - Sale of _pow~.:r... !"~~~--9_eneration costs are lower than market prices. l$chedule Page: 310.2 ....b!ne No.: ,4..:._..::.C..::.ol:c::u:::..:m..:.cn..:.::..c::b:___ _-,-,.-----,-----..-............. _ - - - - , - ; , - - - - - - ; - - - c - - - . , . - - - - opportuni ty Sales - Sale of power when generation costs -~E<=:_-!<::J.!".er than market prices. "&_l!~ule Page: 310.2-- Line No.: 5 Column: b Opportunity Sales - Sale of power when gen~~~tj_~n_ costs are lower than marke-F···price··s--.--·-···-· f[Jiidule Page: 310.2 Line No.: 6 Colum:;..:n:.:..::::.b_ _ _--:-;----,----.--opportunity Sales - Sale o'f-·i)ower....when gen'::J::C1.t::.~C?-~. costs are lower 'i§Ciiedu/e Page: 310.2 Line No.!~] ....9.'!.!'!mn,.:..:-=b'------.------~­ Opportunity Sales - Sale of power when generation costs are lower than market prices. 'tSchedule Pag_f!:._lJ._(J..~?.... Line No:?8 -- coiiiinn: b Opportunity Sales - Sale of power when generation costs are lower than market prices. l$chedule Pag_f!:__31!!_":..?... Line No.:·9··---coiiiinn: b Opportunity Sales - Sale of power when generation costs are lower than market prices. --- ... -"] !Schedule Paiie:-310.2" Line No.: 10 Column: b ____ __ ---------=-------c'7"'opportunity Sales - Sale of power when generation costs are lower than niaiket prices. --------, /§chedule Page: 310.2 Lin~J'!C!:.:._'!_'!_ __ Column: b -~---~--­ Opportunity Sales - Sale of power when generation costs are Towe·r--than market prices. ==:J . . . . . . . . . . . . . . ----"1 lFERC FORM NO.1 (ED. 12-87) Page450.2 of Report Name of 20151Q4 Florida Power & Light Company I - 1 ,- - _-' ------~---- ' - r·----,---~__, " ~"--· f~ ~...__;'-'-~=..:...-..~" Page 320 - --- : . - ~ - - =----- " . - f""""'- - - - - r,-;:,;.-:;, ~-~-- -~ FERC FORM NO.1 (ED. 12-93) - ~- - -~ ~ - • ~ - - : --- -----" - ·---..--~--·~-~ - '~- '. ~ - ·: - ,-:------~~- -- . ---------~--~---~- - '"'~ ~ ~ • .'--:._ ~- "'-=-- --~ • r ~ -• "f ~--- ~ - ••• __ .:;_"'::_ --~"-..._. .':.- Name of Respondent of Report Florida Power & Light Company 2015/04 I- _-- -_--,-- - -- --- ---------- - . -------- l~~---- i' : FERC FORM NO. 1 (ED. 12-93) Page 321 c . -__ -- -_ - --- - . ----- ' - -- - -- ~------- - - Name of Florida Power & Light Company of Report This ~ort Is: {1) ~An Original (2) A Resubmlssion 2015/04 r''" ' ~ ~ • - ~-::--;_--- .. -~-~~- o••o -. ... ~~~~ Page 322 ,..,..,,~ ----~--~ ., ,,- - "' -~ - --· H~- ----~ - ~---'"'-""'' "~--~---- ~ " I---= FERC FORM NO. 1 (ED. 12-93) -· - ~ • --- " ~~-- ' l- • " = - - - • -- - - - -·-> o - -~---- ·--~--·-----~----- - " -- - ~ -- r·· -· --··-·--··--·""- - - . I - . r---· - .- - r·· - .. - .. - ... - -- ·- .. ·- FERC FORM NO. 1 (ED. 12·93) Page 323 -· . - -- - - .- - - ····- .. . - ·-- -- -·- - Florida Power & Light Company End of 2015/Q4 1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF- for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the suppfier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF -for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Name of Company or Public Authority (Footnote Affiliations) (a) Statistical Classification (b) FERC Rate Schedule or Tariff Number {c) Total FERC FORM NO. 1 (ED. 12-90) Page 326 Average Monthly Billing Demand {MW) {d) Name of Respondent Florida Power & Light Company Year/Period of Report 2015/Q4 End of Date of Report This ooort ls: (Mo, Da, Yr) (1) X An Original I I (2) [j A Resubmission PURt.:HA~~g~~~!,v.t:.~Fu~t 55~, (Continued) Inc udmg po er exc ariili ) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly {60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (Q the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (1). Explain in a footnote all components of the amount shown in column (1). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount forth~ net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or {2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401, line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. POWER EXCHANGES MegaWatt Hours MegaWatt Hours MegaWatt Hours Purchased Received Delivered (g) (h) (I) 19,22( Demand Charges m ~l 30,54E \'I 365,85 ~ 52,552 COST/SETTLEMENT OF POWER Energy Charges Other Charges 171 2,890,890 1,266,720 54,135 Line Total (j+k+l) No. of Settlement ($) (m) 1 365,853 2 178 942,56! 3,833,456 3 2• 24 4 522,73C 1,789,450 5 a 8 6 923,59:3 923,593 7 8 520 520 463,038 95,749,931 16,332,826 112,082,757 9 1:< 559,473 70,903 630,376 10 8,767 8,767 11 12 40' l 1H 115 317,59< 2,164,445 2,164,449 13 -7,25::1 ·7,252 14 s 7,948,125 FERC FORM NO. 1 (ED. 12·90) 307,499,014 Page 327 275,331 '152 108,091 '570 690,921 ,73€ Florida Power & Light Company 1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF -for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the suppller must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate--term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF- for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate--term" means longer than one year but less than five years. EX- For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Name of Company or Public Authority (Footnote Affiliations) Statistical Classification FERC Rate Schedule or Tariff Number (c) Total FERC FORM NO. 1 (ED. 12-90) Page 326.1 Average Monthly Billing Demand {MW) (d) Florida Power & Light Company Pv Year/Period of Report 2015/04 End of Date of Report (Mo, Da, Yr) I I Thls R~ort Is: (1) X An Original (2) flA Resubmission· Name of Respondent '(lnCiuding"powef~gR~~g~~) (L;ontmueo) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column (j), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (1). Explain in a footnote all components of the amount shown in column (1). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401, line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. POWER EXCHANGES MegaWatt Hours MegaWatt Hours Received Delivered (i) (h) MegaWatt Hours Purchased (g) Demand Charges ($) Ul ($1 (k 65,68t 4,131 ! 680,20.< COST/SETTLEMENT OF POWER Energy Charges Other Charges 138,822,747 w Line Total G+k+l) No. of Settlement($) (m) 1 65,685 m 17~ 39,676,32! 178,499, 07:i 3 9,001 4 2 45( 9,001 1 2f 28 5 69,582,73< 123,316,646 6 1,777,181 53,733,912 6,76~ -144,033 7 95,15~ 1,660,551 1,660,557 8 1,42€ 30,55. 30,552 9 -150,79ll 5,64~ 5,644 10 E 125 129 11 85,00S 1,444,03€ 1,444,03S 12 3 85~ 852 13 219,621 1 ,534,30E 1,534,306 14 27~ 7,948,125 FERC FORM NO.1 (ED. 12-90) 307,499,014 Page 327.1 275,331,152 108,091,570 690,921,73f Date of (Mo, Da, Florida Power & Light Company I I 1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ- for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF -for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF -for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means fiVe years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX- For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS -for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of less than one year. Describe the nature of the service in a footnote for each adjustment. Name of Company or Public Authority (Footnote Affiliations) Statistical Classification (b) FERC Rate Schedule or Tariff Number (c) Total FERC FORM N0.1 (ED. 12-90) Page 326.2 Name of Respondent Florida Power & Ught Company ort Is: This (1) X An Original {2) i:]A Resubmission 00 Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/04 End of PURCHA~~c31JdPn~~~AccouRt nc u n o er exc an~~~) (~.,;ont~nuea) AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column {b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly {or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column {f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column {g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column(!). Explain in a footnote all components of the amount shown in column (1). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401 , line 1D. The total amount in column (h) must be reported as Exchange Received on Page 401 , line 12. The total amount in column (l) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. POWER EXCHANGES MegaWatt Hours MegaWatt Hours Received Delivered (i) (h) MegaWatt Hours Purchased {g) Demand Charges ~? ($) ($? (I (k) 6 142,06:.! COST/SETTLEMENT OF POWER Other Charges Energy Charges 6,478,800 -37E -375 1 2,538,70~ 9,017,505 2 32,812 3 32,81~ 1,623 75,09C line No. Total (j+k+l) of Settlement ($) (m) 1,524,53 1,524,533 4 140,02!3 6,650,137 2,299,421: 8,949,562 5 242,7~ 1,497,202 8,855,46~ 10,352,667 6 5,02.- 92,36C 92,360 7 1C 22S 228 8 40,805 713,891 713,897 9 21 ,09S 372,93~ 372,934 10 1 65C 650 11 35,467,214 12 20,871,908 bj;j'J:/;i,{;;'j?i~:~5;~~.~~ 644,55~ 6 13 '~::'i~t)jf~~ii\~~9i~if.1.f~® 111,953,872 14 108,091,570 690,921,73€ E 1 ,722,51C 7,948,125 FERC FORM NO. 1 (ED. 12-90) 307,499,014 Page 327.2 61 ,612,37~ 275,331 '152 Date (Mo, Florida Power & Light Company I I Year/Period of Report End of 2015/04 1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF- for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU -for long-term service from a designated generating unit. "long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU -for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX- For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS- for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. Average Monthly Billing Demand (MW) (d) Total FERC FORM N0.1 (ED. 12·90) Page 326.3 Name of Respondent Florida Power & Ught Company This ortls: (1) X An Original A Resubmission (2) 000 I Date of Report (Mo, Da, Yr) I I I PU ~CHA~~g, nc udtng'powerccouR~~~~~) exc ange ) (L;onllnued) Year/Period of Report 2015/Q4 End of AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (1). Explain in a footnote all components of the amount shown in column (I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. lf the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401, line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours Purchased (g) POWER EXCHANGES MegaWatt Hours MegaWatt Hours Received Delivered (h) (i) Demand Charges COST/SETTLEMENT OF POWER Energy Charges Other Charges ~t~ ~~ ($) (I) 61 ,21C 61,210 19,672,00f ;;)t~.)}~~ft;jft!~i~~i;~ 587,72~ Total O+k+l) of Settlement ($) (m) 62,826,770 Line No. 1 2 3 61,37~ 2,294,72€ 2,294,726 4 42,31t 1,718,03( 1,718,030 5 82,25f 3,460,741 3,460,741 6 182,17!: 7,513,53~ 7,513,538 7 4,21!; 164,611 164,611 8 2,811, 14C 2,811,140 9 17,327 10 75,42 1,64, 17,32 7,17 421,59( 421,590 11 65C 29,25( 29,250 12 8,52S 396,76E 396,765 13 2,26~ 73,60 73,602 14 7,948,125 FERC FORM NO. 1 (ED. 12-90) 307,499,014 Page 327.3 275,331,152 108,091 ,570 690,921,736 mls 'Xl~~ Is: 'nal Name of Respondent Florida Power & Light Company (2) ~b: g~~~~ort =iA Resubmlssion PU~ ·~~~~goro~:~~c~~~~~yt 555) , ca• I -..,uu End of of Report 2015/04 1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. 2. Enter the name of the seller or other party in an exchange transaction in column {a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. 3. In coluinn (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ- for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis O.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF- for long-term firm service. "Long-term" means five years or longer and "firmn means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date ofthe contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX- For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. ILine No. Name of Company or Public Authority (Footnote Affiliations) (a) Statistical Classification (b) 1 •Southern Company SeNices, ,as 2 i Tampa Electric CompMiss/1~6~u~fn~r~~~a~a~~~sT r~~~~ ~~i~~tre~~~~ 4ooJ(t;ontlnueo) 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and 0) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) Point of Receipt (Subsatation or Other Designation} (f) Point of Delivery (Substation or Other Designation) {g) Billing Demand TRANSFER OF ENERGY MegaWatt Hours Received (MW) (h) Line No. Megawatt Hours Delivered . (i) (j} 310 System System 36 8,703 8,324 1 310 System System 35 8,763 8,381 2 310 System System 23 11,663 11,1~ 3 16 8,405 8,03f 5 310 N/A N/A 310 System System NIA N/A N/A 164 System System 1,102 1,100 1,07~ 7 182 System System 182 4,127 4,049 8 4 6 164 System System 4,570 4,565 4,48~ 9 182 System System 46 1,104 1,083 10 182 System System 1,728 22,915 22,69S 11 182 System System 1,737 19,808 19,441 12 1,900 1,86-4 14 4,565 4,48~ 15 182 System System 115 164 System System 2,203 13 System System NIA NIA System System 182 System System 164 System System 4,975 2,700 2,651 19 182 System System 4,400 2,959 2,904 20 30 System lucy Substation 15 7,084 6,9& 21 30 System Lucy Substation 104 38,646 37,91E 22 30 Lucy Substation System 15 230 22E 23 244 System Lucy Substation 80 25,898 25,412 24 40 12,949 12,70E 25 182 164 244 Lucy Substation System N/A NIA N/A NIA 4,570 16 1,107 17 18 26 27 30 System Lucy Substation 13 13 p 30 System Lucy Substation 110 110 11C 29 30 System Lucy Substation 10 10 1C 30 244 System Lucy Substation 83 23,135 22,71C 244 System Lucy Substation 30 System Lucy Substation 30 N/A N/A 31 32 11 224 22C 33 34 748,966 FERC FORM NO. 1 (ED. 12-90) 28 Page 329 13,656,658 13,317,346 Name of Respondent Florida Power & Light Company 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column {n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i) and 0) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. Demand Charges ($) (k) 55,702,558 FERC FORM NO. 1 (ED. 12-90) 1,026,599 Page 330 1,399,111 58,128,268 This~rt Is: Name of Respondent (1) {2) Florida Power & Light Company I X An Original (]A Resubmission Date of Report (Mo, Da, Yr) I I N,<2.'=-~l:S~J:RIC_ITY ~9R U.l11.t:K.;;>_g~ccount 4oti.l) I Year/Period of Report 2015/04 End of (including transactions referred to as 'wheeling') 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO- Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP- "Long-Term Firm Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF- non-firm transmission service, OS- Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitfons of codes. Payment By (Company of Public Authority) (Footnote Affiliation) (a) Line No. Energy Received From (Company of Public Authority) {Footnote Affiliation) (b) Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Statistical Classification (d) 1 City of Homestead Utilities Progress Energy Florida City of Homestead Utilities LFP 2 City of Homestead Utilities Florida Power & Light Company City of Homestead Utilities NF 3 City of Homestead Utilities Florida Power & Light Company City of Homestead Utifrties SFP 4 City of Homestead Utilities Seminole Electric Cooperative City of Homestead Utilities SFP 5 City of Homestead Utilities N/A N/A OS 6 City of Homestead Utilities Progress Energy Florida City of Homestead Utilities LFP 7 City of Homestead Utilities Florida Power & Light Company City of Homestead Utilities NF 8 City of Homestead Utilities Progress Energy Florida Southern Company Services, Inc. NF Florida Power & light Company Florida Municipal Power Pool FNO 10 City of Lake Worth City of Lake Worth Orlando Utilities Commission NF 11 City of Lake Worth NIA N/A OS 12 City of Lake Worth Florida Power & Light Company Florida Municipal Power Pool FNO 13 City of Lake Worth City of Lake Worth Orlando Utilities Commission NF 14 City of Lake Worth N/A N/A OS 15 City of Lake Worth Florida Power & Light Company Florida Municipal Power Pool FNO NF 9 City of Lake Worth 16 City of Lake Worth City of Lake Worth Or1ando Utilities Commission 17 City of Lake Worth N/A N/A OS 18 City of Lake Worth Florida Power & Light Company Florida Municipal Power Pool FNO 19 City of Lakeland NIA N/A OS 20 City of New Smyrna Beach Florida Power & Light Company City of New Smyrna Beach NF 21 City of New Smyrna Beach Florida Power & Light Company City of New Smyrna Beach FNO 22 City of New Smyrna Beach Florida Power & Light Company City of New Smyrna Beach FNO 23 City of New Smyrna Beach N/A N/A OS 24 City of New Smyrna Beach Florida Power & Light Company City of New Smyrna Beach FNO 25 City of New Smyrna Beach Florida Power & Light Company Florida Power & Light Company NF 26 City of New Smyrna Beach NIA N/A OS 27 City of New Smyrna Beach Florida Power & Light Company City of New Smyrna Beach NF 28 City of New Smyrna Beach Florida Power & Light Company City of New Smyrna Beach FNO 29 City of New Smyrna Beach N/A NJA OS 30 City of Vero Beach Florida Power & Light Company Florida Municipal Power Pool FNO 31 City of Vera Beach Florida Power & Light Company Florida Municipal Power Pool FNO 32 City of Vero Beach NJA N/A OS 33 City of Vero Beach Florida Power & Light Company Florida Municipal Power Pool FNO 34 City of Vera Beach N/A N/A OS TOTAL FERC FORM N0.1 (ED.12-90) Page 328.1 Name of Respondent Florida Power & Light Company This ort Is: Date of Report (Mo, Da, Yr) (1) X An Original I I (2) A Resubmission TRANSMISSbO ~ qf EI,..ECTR!PITY FQR !..! ! Ht:K.:> (ACCOU[lt 1 456)(Continued) Including transactions naffered to as 'wlieelin9 .l 00 D i Year/Period of Report 2015104 End of 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and (j) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) Point of Receipt (Subsatation or Other Designation) (f) Point of Delivery (Substation or other Designation) (g) Billing Demand TRANSFER OF ENERGY (MW) (~ (h) Line No. MegaWatt Hours Delivered l'VfegSVVatt Hours Received 0) 244 System Lucy Substation 120 33,315 244 System Lucy Substation 7 7 30 System Lucy Substation 518 15,729 45 32,70~ 1 2 15,43 3 4 30 System Lucy Substation 30 N/A NIA 244 System Lucy Substation 120 33,315 244 System Lucy Substation 11 11 11 7 244 System System 27 24 2 8 5 266 System System 235 119,501 299 System System 314 250 32,70 117,29( 24 6 9 10 11 N/A N/A 266 System System 169 94,666 92,91~ 266 System System 1,761 1,653 1,62( 12 13 14 NIA N/A 266 System System 236 120,072 117,851 15 266 System System 353 308 301 16 NIA N/A System System 265 143,540 140,88< 18 32,056 31 ,46; 20 266 17 19 266 NIA NIA 84 System Smyrna Substation 311 System Smyrna Substation 66 61,381 60,24! 21 311 System Smyrna Substation 193 102,298 100,40~ 22 263 131,435 129,00• 12 7 NIA N/A 311 System Smyrna Substation 311 System System 23 24 25 26 N/A NIA 84 System Smyrna Substation 5 311 System Smyma Substation 220 NIA N/A 27 97,571 95,76 28 29 264 System System 347 171,045 167,88( 30 264 System System 382 198,533 194,86( 31 N/A N/A 264 System System N/A N/A 32 460 219,06. 33 34 748,966 FERC FORM NO. 1 (ED. 12-90) 223,190 Page 329.1 13,656,658 13,317,34! Name of Respondent Date of Report (Mo. Da, Yr) Florida Power & Light Company I I 9. In column (k) through (n), report the revenue amounts as shown on bllls or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provlde revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n} the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i) and 0) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. Charges ($} Total Revenues($) {k+l+m) (n) (k} 55,702,558 FERC FORM NO.1 (ED. 12-90) 58,128,268 Page 330.1 Name of Respondent This wort Is: (1) X An Original (2) DA Resubmission Florida Power & light Company TR· {Including Date of Report {Mo, Da, Yr} I I Year/Period of Report End of 2015/Q4 tg~~~~JsR~~~?oRa~~~tTn~~ccount 456.1} 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other publlc authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain In a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions ofthe service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF- non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Payment By {Company of Public Authority) (Footnote Affiliation) (a) Line No. Energy Received From (Company of Public Authority) (Footnote Affiliation) Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) (b) Statistical Classification (d) 1 City of Wauchula Florida Power & Light Company Progress Energy Florida FNO 2 City of Wauchula 3 City of Wauchula Florida Power & Light Company Progress Energy Florida FNO N/A N/A OS 4 City of Wauchula Florida Power & Light Company Progress Energy Florida FNO 5 City of Wauchula N/A N/A OS SFP 6 City of Winter Park 7 8 9 10 Florida Power & Light Company Progress Energy Florida City of Winter Park Florida Power & Light Company Progress Energy Florida SFP City of Winter Park N/A N/A OS City of Winter Park Florida Power & Light Company Progress Energy Florida FNO City of Winter Park OS N/A N/A 11 Exelon Generation, LLC Southern Company Services, Inc. Q~~t1[~~9Jrt:~~]t;0j~~~~il~;~~~~ NF 12 Exelon Generation, LLC 13 Exelon Generation, LLC Southern Company Services, Inc. City of New Smyrna Beach NF N/A NIA OS 14 Exelon Generation, LLC JEA City of New Smyma Beach NF 15 Exelon Generation, LLC Southern Company Services, Inc. Florida Municipal Power Pool NF 16 Florida Keys Electric Cooperative, Inc. Florida Power & Light Company Florida Keys Electric Cooperative FNO 17 Florida Keys Electric Cooperative. Inc. Florida Power & Light Company Florida Keys Electric Cooperative FNO 18 Florida Keys Electric Cooperative, Inc. N/A NIA OS 19 20 21 22 23 24 25 26 27 28 29 30 Florida Keys Electric Cooperative, Inc. Florida Power & Light Company Florida Keys Electric Cooperative mRit~:tTfl~~: Florida Keys Electric Cooperative, Inc. N/A N/A OS Florida Keys Electric Cooperative, Inc. Florida Power & Light Company Florida Keys Electric Cooperative FNO Florida Municipal Power Agency Florida Power & Light Company Florida Municipal Power Pool OLF Florida Municipal Power Agency Florida Power & Light Company Florida Municipal Power Pool FNO Florida Municipal Power Agency Florida Municipal Power Pool Florida Municipal Power Pool SFP Florida Municipal Power Agency Florida Municipal Power Pool Florida Municipal Power Pool NF Florida Municipal Power Agency Orlando Utilities Commission City of Homestead Utilities OLF OS Florida Municipal Power Agency NIA N/A Florida Municipal Power Agency Progress Energy Florida Progress Energy Florida SFP Florida Municipal Power Agency N/A N/A OS Florida Municipal Power Agency Florida Municipal Power Pool Florida Municipal Power Pool FNO 31 Florida Municipal Power Agency Florida Power & Light Company Florida Municipal Power Pool FNO 32 Florida Municipal Power Agency 33 Florida Municipal Power Agency 34 Florida Municipal Power Agency Florida Municipal Power Pool Florida Municipal Power Pool NF Florida Municipal Power Pool Orlando Utilities Commission NF Florida Municipal Power Pool Florida Municipal Power Pool FNO TOTAL FERC FORM N0.1 (ED. 12-90) Page 328.2 ort Is: This Date of Report (1) X An Original (Mo, Da, Yr) (2) OA Resubmlssion I I qF E\-ECTR[piTY F9R L/ 1!1~!<~ iJ! CCOUtJI 456)(Continued) (Including transactions reffered to as 'wtieeling•)' 00 Name of Respondent Florida Power & Light Company T Year/Period of Report 2015/Q4 End of 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column {f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and 0) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) Point of Receipt (Subsatation or Other Designation) (f) Point of Delivery (Substation or Other Designation) Billing Demand (MW) (h) (g) TRANSFER OF ENERGY Megawatt Hours Received {i) Line No. Megawatt Hours Delivered G) 299 System System 29 13,742 13,28f 1 299 System System 31 16,518 15,97 2 N/A N/A 37 18,377 17,77( 299 3 System System N/A N/A 325 System System 67 41,551 40,783 6 325 System System 102 52,856 51,879 7 N/A N/A 325 System System 159 68,435 67,169 N/A N/A 186 System Smyrna Substation 28 9 9 11 186 System Smyrna Substation 82 63 6~ 12 114 114 11~ 14 N/A N/A System Smyrna Substation 4 5 8 9 10 13 182 System System 293 System System 326 171,361 168,191 16 293 System System 405 209,113 205,245 17 N/A N/A System System 441 250,592 245,956 N/A N/A 293 15 18 19 20 293 System System 392 197,797 194,138 80 System System 48 30,007 29,45{ 22 80 System System 1,138 576,123 565,4~ 23 72 System System 1,240 170 16 72 System System 6,718 5,397 5,29 25 92, 93,2 System Lucy Substation 63 32,209 31 ,57( 26 93 N/A N/A 72 System System 100 29,009 28.47 93 N/A N/A 80 System System 816 9,894 80 System System 1,024 553,367 542,91( 31 72 N/A N/A 10,101 8,788 8,62S 32 72 N/A N/A 339 92,93,2 System System FERC FORM N0.1 (ED.12-90} 21 24 27 28 29 Page 329.2 7,61 30 274 27C 33 24 20,543 19,22~ 34 748,966 13,656,658 13,317,34E Date of Report (Mo, Da, Yr) Respondent Florida Power & Light Company I I Year/Period of Report 2015/04 End of 9. In column (k) through {n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns {i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11 . Footnote entries and provide explanations following all required data. Total Revenues($) (k+l+m) (n) 58,128,268 55,702,558 FERC FORM NO. 1 (ED. 12-90) Page 330.2 Name of Respondent Florida Power & Light Cempany Dale of Report This ®art Is: (Mo, Da, Yr) (1) X An Original I I (2) [jA Resubmission TRAN~~ ~~!PN OF ELI;CTRIC_lTY F:QR o:ri-:IER§n~~ccount 456.1) Including transactions referred to as 'wheelin ' I Year/Period of Report 2015/04 End of 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO- Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF- non-tinm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Payment By (Company of Public Authority} (Footnote Affiliation) (a) Line No. Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Statistical Classification (d) LFP 1 Florida Municipal Power Agency Florida Municipal Power Pool City of Homestead Utilities 2 Florida Municipal Power Agency Florida Municipal Power Pool City of Homestead Utilities LFP 3 Florida Municipal Power Agency NIA N/A OS 4 Florida Municipal Power Agency Florida Power & Light Company Florida Municipal Power Pool SFP 5 Florida Municipal Power Agency Florida Municipal Power Pool Florida Municipal Power Pool NF 6 Florida Municipal Power Agency Rorida Power & Light Company Florida Municipal Power Pool FNO 7 Florida Municipal Power Agency 8 Florida Municipal Power Agency Florida Municipal Power Pool Orlando Utilities Commission NF Florida Municipal Power Pool City of Homestead Utilities LFP 9 Florida Municipal Power Agency NIA NIA OS OS 10 Florida Municipal Power Agency NIA NIA 11 Florida Municipal Power Agency Florida Power & Light Company Gainesville Regional Utilities LFP 12 Florida Municipal Power Agency Florida Power & Light Company Southern Company Services, Inc. FNO 13 Florida Municipal Power Agency N/A NIA LFP 14 Florida Municipal Power Agency NIA NIA OS 15 Florida Municipal Power Agency NIA N/A OS 16 Florida Municipal Power Agency N/A N/A OS 17 Georgia Pacific Corporation N/A NIA OS 18 Georgia Pacific Corporation N/A NIA OS 19 Georgia Pacific Corporation NIA N/A OS 20 Georgia Pacific Pulp N/A N/A OS 21 Georgia Pacific Pulp 22 Georgia Pacific Pulp 23 Georgia Pacific Pulp NIA N/A OS NIA NIA OS N/A N/A OS 24 Georgia Pacific Pulp N/A N/A OS 25 Georgia Transmission Corporation Florida Power & Light Company Southern Company Services, Inc. LFP 26 Georgia Transmission Corporation N/A N/A OS 27 Georgia Transmission Corporation 28 Georgia Transmission Corporation Florida Power & Light Company Southern Company Services, Inc. LFP Florida Power & Light Company Southern Company Services, Inc. LFP 29 Georgia Transmission Corporation NIA NIA OS 30 Georgia Transmission Corporation N/A N/A OS 31 32 33 34 Georgia Transmission Corporation Florida Power & Light Company Southern Company Services, Inc. LFP Georgia Transmission Corporation N/A NIA OS Georgia Transmission Corporation N/A N/A OS Georgia Transmission Corporation N/A NIA OS TOTAL FERC FORM NO. 1 (ED. 12-90) Page 328.3 Name of Respondent Date of Report {Mo, Da, Yr) I I This wort Is: (1) X An Original (2) CJA Resubmission Florida Power & Light Company Year/Period of Report 2015/04 End of I 'KANSMI:;;::;~~~~u~rnitr~~~a~~)0·~ 5T ~Jfe~ l~i;·~fie~rr~~~t 456)(Continueo) 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column {d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (t), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and Q) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number {e) Point of Receipt {Subsatation or Other Designation) Point of Delivery {Substation or other Designation) Billing Demand (f) (g) {h) TRANSFER OF ENERGY (MW) Line No. MegaW.att Hours Delivered Megawatt Hours Received {i) (j) 16,82~ 1 2 System Lucy Substation 24 17,173 2 System Lucy Substation 15 6,848 6,40E 313 N/A N/A 80 System System 4,794 39,168 38,44B 4 72 System System 2,935 2,715 2,665 5 72 System System 1,179 621,334 609,839 6 7 8 93 3 92,93,2 System System 22 10 1G 93 System Lucy Substation 63 33,836 33,168 N/A N/A 9 313 N/A N/A 10 93 System Deerhaven Substation 34,628 33,98 11 727,267 713,81;, 12 63 40,236 39,44 13 72 System 93 N/A N/A N/A N/A 14 313 N/A N/A 15 80 N/A N/A 16 N/A N/A 17 N/A N/A 18 N/A N/A 19 N/A N/A 20 "j";:;:~;;-;:;;r,~:~,;,:':Ci'::~''' System 48 1,380 N/A N/A 21 269 N/A N/A 22 80 N/A N/A 23 80 N/A N/A 269 System System 24 24 10,449 10,25~ 25 26 N/A N/A 269 System System 102 13,848 13,591 27 269 System System 75 12,895 12,651 28 N/A N/A N/A N/A 29 30 17,506 System System N/A N/A 32 N/A N/A 33 N/A N/A 34 40 748,966 FERC FORM N0.1 (ED. 12-90) Page 329.3 17,836 13,656,658 13,317,345 31 !Name of Florida Power & Light Company This ~ort 1s:. . (1} ~ An 0 ngma1 A Resubmlssion (2) Date of Report (Mo, Da, Yr) I I End of of Report 2015/04 9. In column (I<) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column {1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11 011) in column {n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i) and U) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. REVENUE FROM TR/'., ...... ,~~ 1 n"' OF ELECTRICifYFOR.()THffiS Demand Charges ($) (k) Energy Charges ($) (I} 1,836 41,836 1 26,315 2 3,600 3 199,02:l 199,023 4 7,886 5 7,886 2,230,725 6 2,62E 2,626 7 107,632 107,632 8 3,600 3,600 9 2,809 10 -557 ~ 80,413 2,326,475 -3,898 107,874 ;',C;;et' - :,'''' F+:~ 161,860 - No. 26,315 2,231,282 "" IUne Total Revenues ($) (k+l+m) (n) (Otherfrges) 80,413 11 2,322,577 12 107,874 13 3,600 14 150,172 15 132,816 17 95,069 18 16 I 3,600 19 161,860 20 36,62~ 36,624 21 ,,,,;"';,jf;':;>>;:;; 181,192 22 36,62~ 36,624 23 24,416 24,416 24 41,~ 25 41,353 115 50,667 41,464 1,614 2,400 71,909 500 36,624 3,600 55,702,558 FERC FORM N0.1 {ED.12-90) - 1,026,599 Page 330.3 ~ 1,399,111 3,599 26 54,301 27 43,078 26 2,400 29 -20 30 72,401 31 36,624 32 3,219 33 3,600 34 58,128,268 Name of Respondent Florida Power & Light Company Date of Report This wort Is: (1) X An Original (Mo, Da, Yr) I I (2) [)A Resubmission .0!_ ElsC]:RICJ):V !;OR O'f'1_~'3.S (Account 4bti.1) T'"'' (Including transactions referred to as 'wheeling') I Year/Period of Report 2015104 End of 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or {c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO- Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP- "Long-Term Finn Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF- non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Payment By (Company of Public Authority) (Footnote Affiliation) (a) Line No. Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Energy Delivered To {Company of Public Authority) (Footnote Affiliation) (c) Statistical Classification (d) 1 JEA NIA NIA OS 2 J P Morgan Florida Power & Light Company Southern Company Services, Inc. NF 3 Lee County Electric Cooperative 4 Lee County Electric Cooperative 5 Lee County Electric Cooperative Florida Power & Light Company Florida Power & Light Company ~8ii~~~~~t: N/A NIA OS Florida Power & Light Company Florida Power & light Company FNO 6 Lee County Electric Cooperative Florida Power & Light Company Florida Power & Light Company FNO 7 Lee County Electric Cooperative NIA NIA OS 8 Lee County Electric Cooperative Florida Power & Light Company Florida Power & Light Company FNO 9 Lee County Electric Cooperative Florida Power & Light Company Florida Power & Light Company FNO 10 Miami Dade County N/A N/A OS 11 Miami Dade County NIA N/A OS 12 Miami Dade County NIA N/A OS 13 New Hope Power Partnership Florida Power & Light Company Gainesville Regional Utilities NF 14 New Hope Power Partnership Florida Power & Light Company JEA NF 15 New Hope Power Partnership Florida Power & Light Company City of New Smyrna Beach NF 16 New Hope Power Partnership Florida Power & Light Company Progress Energy Florida NF 17 New Hope Power Partnership Florida Power & Light Company Southern Company Services, Inc. NF 18 New Hope Power Partnership Florida Power & Light Company Tampa Electric Company NF 19 New Hope Power Partnership Florida Power & Light Company Gainesville Regional Utilities SFP 20 21 22 23 24 25 Florida Power & Light Company JEA SFP SFP New Hope Power Partnership New Hope Power Partnership Florida Power & Light Company Southern Company Services, Inc. New Hope Power Partnership Florida Power & Light Company Progress Energy Florida SFP New Hope Power Partnership N/A NIA OS New Hope Power Partnership N/A N/A OS New Hope Power Partnership NIA NIA OS 26 New Hope Power Partnership N/A N/A OS 27 28 29 30 31 32 33 34 New Hope Power Partnership NIA N/A AD New Hope Power Partnership N/A N/A OS New Hope Power Partnership NIA N/A OS New Hope Power Partnership Florida Power & Light Company Gainesville Regional Utilities NF New Hope Power Partnership Florida Power & Light Company JEA NF New Hope Power Partnership Florida Power & Light Company City of New Smyrna Beach NF New Hope Power Partnership Florida Power & Light Company Progress Energy Florida NF New Hope Power Partnership Florida Power & Light Company Southern Company Services, Inc. NF TOTAL FERC FORM NO. 1 (ED. 12-90) Page 328.4 This ort Is: (1} X An Original (2} OA Resubmisslon Date of Report (Mo, Da, Yr) I I 00 Name of Respondent Florida Power & Light Company Year/Period of Report 2015/04 End of TRANSMis::W~clu~ln~tr~~~a~U~~~s\~~~ea' l~~~·~Ke~IT~~·~t -456J{Confinuec) 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the finn transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and 0) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number Point of Receipt (Subsatation or Other Designation) (e) 266 266 (f) Point of Delivel)' (Substation or other Designation) (g) Billing Demand (MW} (h) TRANSFER OF ENERGY MegaWatt Hours Received (i) N/A N/A System System 195 System System 2,147 Line No. Megawatt Hours Delivered 0> 1 2 978,761 960,652 3 N/A NIA 266 System System 1,877 869,605 853,515 5 266 System System 2,126 1,029,729 1,010,67€ 6 N/A N/A System Lucy Substation 2,435 1 '142,191 1 '121 ,059 8 System System 229 4 7 9 N/A N/A N/A N/A 11 N/A N/A 12 229 System Deerhaven Substation 3,900 3,945 3,90C 13 229 System System 1,661 1,720 1,704 14 229 System Smyrna Substation 4 4 4 15 229 System System 2,636 3,748 3.68~ 16 229 System System 1,599 1,685 17 230 System System 305 305 1,67i. 30( 228 System Deerhaven Substation 493 2,776 2,72~ 19 228 System System 40 40 4( 20 228 System System 60 60 6( 21 228 System System 58 570 56( 22 N/A N/A N/A N/A 969 939 92• 24 228 N/A N/A 95 228 N/A N/A 331 331 32~ 229 N/A N/A 27 N/A N/A 28 10 18 23 25 26 228 N/A N/A 232 222 22. 29 229 System Deerhaven Substation 849 1,175 30 229 System System 324 238 1 '15t 23E 229 System Smyrna Substation 18 9 ~ 32 229 System System 876 2,377 2,33E 33 229 System System 4,008 4,475 4,421 34 748,966 13,656,658 13,317,34E FERC FORM NO. 1 (ED. 12-90) Page 329.4 31 Florida Power & Light Company 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column {a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. Total Revenues (k+l+m} Demand Charges ($) (n) (k) 55,702,558 FERC FORM NO.1 (ED. 12-90} 1,026,599 Page 1,399,111 330.4 58,128,268 Name of Respondent Florida Power & Light Company This ort Is: (1) X An Original (2) [jA Resubmission 00 I~N(~br~d~~ t~:Ost::a~~~s Date of Report (Mo, Da, Yr) I I 1 ref~ rie~~oKa~ ~~~IYn~~ccount 456·1) Year/Period of Report 2015/04 End of 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO- Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP- "Long-Term Firm Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF - non-f1rm transmission serv'1ce, OS -Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Payment By (Company of Public Authority) (Footnote Affiliation) (a) Line No. Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Statistical Classification (d) SFP 1 New Hope Power Partnership Florida Power & Light Company Gainesville Regional Utilities 2 New Hope Power Partnership Florida Power & Light Company JEA SFP 3 New Hope Power Partnership Florida Power & Light Company Progress Energy Florida NF 4 New Hope Power Partnership Florida Power & Light Company Progress Energy Florida SFP 5 New Hope Power Partnership Florida Power & Light Company Tampa Electric Company NF 6 New Hope Power Partnership Florida Power & Light Company JEA NF 7 New Hope Power Partnership Florida Power & Light Company JEA NF 8 New Hope Power Partnership Florida Power & Light Company JEA SFP 9 New Hope Power Partnership Florida Power & Light Company City of New Smyrna Beach NF 10 New Hope Power Partnership Florida Power & Light Company Progress Energy Florida NF 11 New Hope Power Partnership Florida Power & Light Company Progress Energy Florida SFP 12 New Hope Power Partnership N/A NIA OS NF 13 New Hope Power Partnership Florida Power & Light Company Southern Company Services, Inc. 14 New Hope Power Partnership Florida Power & Light Company Gainesville Regional Utilities SFP 15 New Hope Power Partnership Florida Power & Light Company Gainesville Regional Utilities NF 16 New Hope Power Partnership Florida Power & Light Company City of Homestead Utilities NF 17 New Hope Power Partnership Florida Power & Light Company Orlando Utilities Commission SFP 18 New Hope Power Partnership N/A N/A OS 19 New Hope Power Partnership Florida Power & Light Company JEA NF 20 New Hope Power Partnership N/A N/A OS 21 New Hope Power Partnership Florida Power & Light Company Progress Energy Florida SFP 22 New Hope Power Partnership Florida Power & Light Company Southern Company Services, Inc. NF 23 New Hope Power Partnership Florida Power & Light Company JEA SFP 24 New Hope Power Partnership Florida Power & Light Company Orlando Utilities Commission NF 25 New Hope Power Partnership N/A N/A OS 26 New Hope Power Partnership Florida Power & Light Company Progress Energy Florida NF 27 New Hope Power Partnership Florida Power & Light Company City of New Smyrna Beach SFP 28 New Hope Power Partnership Florida Power & Light Company Southern Company Services, Inc. NF 29 New Hope Power Partnership NIA NIA OS 30 New Hope Power Partnership NIA N/A OS 31 Oleander Power Project, LP N/A NIA OS 32 Oleander Power Project, LP N/A N/A OS 33 Oleander Power Project, LP N/A NIA OS 34 Oleander Power Project, LP N/A N/A OS TOTAL FERC FORM NO.1 (ED.12-90) Page 328.5 ort Is: This Date of Report {1) X An Original (Mo, Da, Yr) I I {2} OA Resubmission _(~[ E!-EC 1 K.\\-'11 r Fp~_ ~ l!l~~~j.ll ccount 456)(Cont•nued) -(Including transactions reffered to as 'wfieelin!{f 00 Name of Respondent Florida Power & Light Company T Year/Period of Report 2015/04 End of I 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (l) and (j) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) 228 228 Point of Receipt (Subsatation or Other Designation) (f) Point of Delivery (Substation or Other Designation) Billing Demand (MW) (h) (g) System Deerhaven Substation System System TRANSFER OF ENERGY MegaWatt Hours Received (i) Line MegaV\(att Hours No. Delivered 0} 2,95( 1 221 3,005 37 382 3n 3 2 228 System System 375 7,358 7,22( 228 System System 271 4,934 4,84( 4 5 229 System Deerhaven Substation 25 25 2~ 229 System System 2,166 1,757 1,72~ 6 228 System System 133 45 45 7 26 611 600 8 6 6 6 9 10 229 System System 229 System Smyrna Substation 229 System System 2,867 3,934 3,863 229 System System 683 13,123 12,880 11 229 N/A N/A 208 204 200 12 229 System System 851 788 78.< 13 228 System Deerhaven Substation 19 245 24C 14 228 System Deerhaven Substation 146 145 145 15 228 System Lucy Substation 62 61 60 16 228 System System 52 535 525 17 N/A N/A 228 18 229 System System . 20 20 20 19 228 N/A NIA 925 885 87C 20 205 924 90t 22 21 229 System System 229 N/A N/A 229 System System 1,622 229 System System 208 4,641 4,556 24 229 N/A N/A 12,547 9,234 9,06 25 23 99( 1,174 996 764 9,634 9,45 2,884 2,432 2,387 26 229 System System 228 System Deerhaven Substation 228 System System 229 N/A N/A N/A N/A 30 178 N/A N/A 31 178 228 27 28 29 19 N/A N/A 32 N/A N/A 33 NIA N/A 34 748,966 FERC FORM NO.1 (ED. 12-90) Page 329.5 13,656,658 13,317,345 This~ort Name of """fiV"U""' Florida Power & Light Company (1) (2) I lX An Is:Original F A Resubmission Date of Report (Mo, Da, Yr) I I I -ifnc\,~~n~\-,~~J~~~ r~~~e~ ~~i~~!';~~9ll: 45ij} (Continued) l End of ..... vJ of Report 2015/04 19. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues from energy charges related to the 1 amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column {m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11 011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i) and U) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. OF ELECTRICITY FOR u 1Ht:.K::i (Other t,;nargesJ REVENUE FROM TRANS Energy Charges Demand Charges ($) (k) ($) ($) (I) (m) Une Total Revenues($) (k+l+m) (n) No. 12,672 12,672 1 2,122 2,122 2 20,759 3 13,934 13,934 4 222 222 5 3,9n 3,973 6 3,704 3,704 7 180 180 8 20,70C 59 29 29 9 9,845 9,845 10 24,431 24,431 11 12 2,625 2,625 13 156 156 14 526 526 15 304 304 16 3,007 17 2,982 25 3,671 18 98 98 19 1,696 1,696 20 3,/ 11,75~ 21 11,753 22 2,78l 2,784 23 11,927 11,927 24 12,651 12,651 25 4,567 4,567 26 43,78~ 43,783 27 2,87€ 2,878 28 1 ,08~ 1,089 29 9,459 30 r'c.'::·::•.•,c·: ~ . . ·-~ 8,~()_8 ''"rci:>.Hi'l 55,702,558 FERC FORM NO. 1 (ED. 12-90) . 65,362 1,399,111 1,026,599 Page 330.5 7,200 31 7,176 32 10,882 33 72,562 34 58,128,268 Name of Respondent This Wort Is: (1) X An Original (2) CJA Resubmission Florida Power & Light Company I " (including Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/04 End of t~Jn;a'aj~~:~~~~;'~?oRa~ ~~~lfn~~ccount 456 ' 1) 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or {c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO- Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP- "Long-Term Firm Point to Point· Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF- non-firm transmission service, OS- Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Payment By (Company of Public Authority) (Footnote Affiliation) (a) Line No. Energy Received From {Company of Public Authority) (Footnote Affiliation) (b) Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Statistical Classlfication (d) N/A OS Florida Power & Light Company 2 ~$:f@~Uutu~~~~~~nfr1·H~l~'t~r~J~];l1q~TI>~t·~~ ····-··· ···-··-- ... ···-·- ·. ············-.. ··. Southern Company Services, Inc. 3 Orlando Utilities Commission Florida Municipal Power Pool NF Florida Municipal Power Pool NF 4 Orlando Utilities Commission Florida Power & Light Company Florida Municipal Power Pool LFP 5 Orlando Utilities Commission Orlando Utilities Commission City of Homestead Utilities NF 6 Orlando Utilities Commission JEA Orlando Utilities Commission NF 7 Orlando Utilities Commission Orlando Utilities Commission Southern Company Services, Inc. NF 8 Orlando Utilities Commission Southern Company Services, Inc. Orlando Utilities Commission NF 9 Orlando Utilities Commission N/A N/A NF 10 Orlando Utilities Commission N/A NIA OS 11 Orlando Utilities Commission JEA Oriando Utilities Commission NF 12 Ortando Utilities Commission Florida Power & Light Company Orlando Utilities Commission FNO 13 Oriando Utilities Commission Florida Power & Light Company Orlando Utilities Commission LFP 14 Orlando Utilities Commission N/A N/A OS 1 Oleander Power Project, LP N/A 15 Orlando Utilities Commission N/A N/A OS 16 Orlando Utilities Commission Florida Power & Light Company Sarasota County Landfill NF 17 Orlando Utilities Commission Seminole Electric Cooperative Southern Company Services, Inc. NF 18 Orlando Utilities Commission Seminole Electric Cooperative Gainesville Regional Utilities NF 19 Orlando Utilities Commission Seminole Electric Cooperative . JEA NF 20 Orlando Utilities Commission Florida Power & Light Company Florida Municipal Power Pool NF NF 21 Orlando Utilities Commission Southern Company Services, Inc. Florida Municipal Power Pool 22 Orlando Utilities Commission Florida Power & Light Company Florida Municipal Power Pool LFP 23 Orlando Utilities Commission N/A N/A OS 24 Orlando Utilities Commission Florida Power & Light Company Florida Municipal Power Pool OLF 25 Progress Energy Florida Florida Power & Light Company Progress Energy Florida NF 26 Progress Energy Florida Florida Power & Light Company Progress Energy Florida NF 27 Progress Energy Florida Progress Energy Florida Southern Company Services, Inc:. NF 28 Progress Energy Florida Progress Energy Florida City of New Smyrna Beach SFP 29 Progress Energy Florida Progress Energy Florida Southern Company Services, Inc. SFP 30 Progress Energy Florida Florida Power & Light Company Progress Energy Florida NF NF 31 Progress Energy Florida Southern Company Services, Inc. Progress Energy Florida 32 Progress Energy Florida N/A N/A OS 33 Progress Energy Florida Florida Power & Light Company JEA NF 34 Progress Energy Florida Florida Power & Light Company Progress Energy Florida FNO TOTAL FERC FORM NO~ 1 (ED. 12-90} Page 328.6 This ort Is: (1) X An Original (2) OA Resubmlssion 00 Name of Respondent Florida Power & light Company T Date of Report (Mo, Da, Yr) Year/Period of Report 2015/04 End of I I J~ tgE. E\-EGT_~l~l_!!_ F£~- ~..t [_!1t:K.~-~ ccount 456)(Gontmued) -(Including transactions reffered to as 'wlieeling') 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and (j) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) Point of Receipt (Subsatatlon or Other Designation) (f) Billing Demand (MW) (h) Point of Delivery (S ubstatlon or Other Designation) {g) TRANSFER OF ENERGY MegaWatt Hours Received Line No. MegaV1fatt Hours Delivered (~ G) 178 N/A NfA 40 System System 1,086 122,190 40 System System 450 150 14 3 69 System System 12 3,898 5,85 4 40 System Lucy Substation 312 222 221 5 40 System System 306 306 30C 6 40 System System 357 357 35C 7 40 System System 1,715 1,545 1,511 8 1 119,92f 2 40 N/A N/A 228 N/A N/A 40 System System 1,760 1,760 1,72r 11 266 System System 186 101,322 99,448 12 266 System System 12 3,968 6,44~ 13 229 N/A N/A 415 415 40S 14 178 N/A NfA 3,288 3,240 3,180 15 40 System System 51 51 50 40 System System 40 System System 12 4,050 6,228 18 40 System System 186 132,260 129,813 19 40 System System 265 265 261 20 40 System System 240 240 23-" 21 69 System System 12 3,713 3,944 70 N/A N/A 9 10 16 17 22 23 System System 186 114,608 112,488 24 24 System System 302 302 29r 25 24 System System 100 100 98 26 24 System System 2,610 2,610 2,562 27 23 System Smyrna Substation 210 1,152 1,131 28 23 System System 31 31 3( 29 13€ 30 24 System System 364 139 24 System System 5,074 4,498 24 N/A N/A 225 228 System System 125 125 12~ 33 266 System System 51 52 sc 34 748,966 13,656,658 13,317,345 FERC FORM NO. 1 (ED. 12-90) Page 329.6 4,41 31 32 misf [f~rt 1~:. An Onginal (2) F= A Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) I I Year/Period of Report End of 2015/04 I IV'\1'->IVII,j:;)!l-'f i U,t;~t::l,.t:v ~~.~~ Y r~ffe~e~ \i;~~~~~ng~~t 456) (Cvt lUI ou"UJ 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column {1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i} and G) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. REVENUE FBOM T Energy Charges Demand Charges • MISS\YI ! O.f EI,.El.' t Kt,yll T FQR q rHER~ ~ ccou!j{ ..f56}1Conttnued) I Year/Period of Report 2015/Q4 End of (Including transactions reffered to as 'w eeliiia;) 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column {n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11 011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i) and Q) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11 . Footnote entries and provide explanations following all required data. REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS Energy Charges (Other Charges) ($) ($) {I) (m) Demand Charges ($) (k) - 2,195 ~ Line No. Total Revenues ($) (k+l+m) (n) 1,704 1 2,195 2 20 3 15,360 4 6,757 6,757 5 956 956 6 1,017 1,017 7 2,580 2,580 8 20 15,360 573 573 9 1,434 1,434 10 165,05~ 154,396 11 11,040 11,040 12 173,216 173,216 13 226 226 14 7,986 7,986 15 8,859 8,859 16 6,526 6,526 17 48,464 48,464 18 466 466 19 18,207 18,207 20 14,794 14,794 21 50 50 22 573 573 23 24 131,841 131,847 25 3,05• 3,054 26 1,810 1,810 27 1,147 1,147 28 77,104 77,104 29 -5,279 30 ~ -5,174 5,110 5,110 31 4,702 4,702 32 2,223 2,223 33 3,908 3,908 34 55,702,558 FERC FORM NO. 1 (ED. 12-90) 1,026,599 Page 330.7 1,399,111 58,128,268 Name of Respondent Florida Power & Light Company I Date of Report This wort Is: (1) X An Original (Mo, Da, Yr) I I (2) OA Resubmlsslon S!9N.Uf ELsCIKII.i)l Y f;"(,JR U,lt:n:;K.~ ~ccount 456.1) (Including transactions referred to as 'wheelin ' Year/Period of Report 2015/04 End of 1 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities fisted in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO- Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP- "Long-Term Firm Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Payment By (Company of Public Authority) (Footnote Affiliation) (a) Line No. Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Florida Power & Light Company Tampa Electric Company Statistical Classification (d) SFP 1 Rainbow Energy Marketing Corporation 2 Rainbow Energy Marketing Corporation Gainesville Regional Utilities Tampa Electric Company NF 3 Rainbow Energy Marketing Corporation JEA Tampa Electric Company NF 4 Rainbow Energy Marketing Corporation 5 Rainbow Energy Marketing Corporation Tampa Electric Company JEA NF Florida Power & Light Company Southern Company Services, Inc. NF 6 Rainbow Energy Marketing Corporation Tampa Electric Company Gainesville Regional Utilities SFP 7 Rainbow Energy Marketing Corporation Tampa Electric Company City of New Smyrna Beach NF 8 Rainbow Energy Marketing Corporation Florida Power & Light Company Southern Company Services, Inc. SFP JEA Florida Power & Light Company SFP NF 9 Rainbow Energy Marketing Corporation 10 Rainbow Energy Marketing Corporation 11 Rainbow Energy Marketing Corporation Florida Power & Light Company City of Homestead Utilities Florida Power & Light Company City of New Smyrna Beach NF 12 Rainbow Energy Marketing Corporation Florida Power & Light Company Progress Energy Florida NF 13 14 15 16 Rainbow Energy Marketing Corporation Florida Power & Light Company Southern Company Services, Inc. NF Rainbow Energy Marketing Corporation Florida Power & Light Company Gainesville Regional Utilities NF Rainbow Energy Marketing Corporation Florida Power & Light Company JEA NF Rainbow Energy Marketing Corporation Florida Power & Light Company Gainesville Regional Utilities SFP 17 Rainbow Energy Marketing Corporation Florida Powe·r & light Company City of New Smyrna Beach SFP 18 Rainbow Energy Marketing Corporation Florida Power & Light Company JEA SFP 19 Rainbow Energy Marketing Corporation Florida Power & Light Company City of Homestead Utilities SFP Rainbow Energy Marketing Corporation Florida Power & Light Company Progress Energy Florida SFP Rainbow Energy Marketing Corporation Southern Company Services, Inc. Tampa Electric Company NF Rainbow Energy Marketing Corporation Florida Power & Light Company Southern Company Services, Inc. SFP 20 21 22 23 24 25 26 27 28 29 30 31 32 Rainbow Energy Marketing Corporation Southern Company Services. Inc. City of New Smyrna Beach NF Rainbow Energy Marketing Corporation JEA Tampa Electric Company NF OS Rainbow Energy Marketing Corporation NIA NIA Reedy Creek Improvement District Florida Power & Light Company Progress Energy Florida NF Progress Energy Florida NF Reedy Creek Improvement District Florida Power & light Company Reedy Creek Improvement District Florida Power & Light Company Progress Energy Florida NF Reedy Creek Improvement District N/A N/A OS Reedy Creek Improvement District Tampa Electric Company Southern Company Services, Inc. NF Reedy Creek Improvement District Southern Company Services, Inc. Tampa Electric Company SFP Sarasota County Landfill Florida Power & Light Company Sarasota County Landfill FNO 33 Sarasota County Landfill N/A NIA AD 34 Sarasota County Landfill Florida Power & Light Company Sarasota County Landfill FNO TOTAL FERC FORM N0.1 {ED. 12-90) Page 328.8 Name of Respondent Florida Power & Light Company I "' Date of Report This~rtls: (Mo, Da, Yr} (1) X An Original I I (2) rlA Resubmlssion !qf ELEC·i~KJ\-'11 '( FQR "-?! Ht::K~ (Account 1 456)(ContlnUed) -(Including transactions reffered to as 'wtieelln!i Year/Period of Report 2015/04 End of I i 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and 0) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) Point of Receipt (Subsatation or Other Designation) (f) Point of Delivery (Substation or Other Designation) (g) Billing Demand (MW) (h) TRANSFER OF ENERGY line No. MegaWatt Hours Delivered MegaWatt Hours Received (I) Ul 8 System System 12,281 18,529 18,191 1 8 System System 978 1,601 1,57f 2 8 System System 25 600 58~ 3 8 System System 215 740 721 4 8 System System 390 4,561 4,48.< 5 237 System Deerhaven Substation 1,384 26,259 25,774 6 237 System Smyrna Substation 36 36 3E 7 237 System System 616 6,920 6,793 8 237 System System 8 System Lucy Substation 300 300 294 10 8 System Smyrna Substation 498 550 540 11 8 System System 20,106 35,471 34,826 12 8 System System 830 2,040 2,002 13 8 System Deerhaven Substation 5,774 6,774 6,654 14 8 System System 1,800 1,787 1,755 15 237 System Deerhaven Substation 765 10,398 10,212 16 237 System Smyrna Substation 155 2,404 2,361 17 237 System System 30 220 21E 18 238 System Lucy Substation 70 3,456 3,39~ 19 237 System System 3,341 59,711 58,59! 20 8 System System 1,30~ 430 42< 21 6( 120 1H 22 ~ 9 ! 23 2ac 280 27! 24 9 237 System System 8 System Smyrna Substation 9 System System N/A N/A 32 System System 40 40 4( 26 32 System System 200 200 20( 27 191 19( 32 System System 32 N/A N/A 8 System System 237 System System System System N/A N/A System System FERC FORM NO.1 {ED.12-90) 25 191 28 29 40 40 4< 30 3 3,067 2,961 32 13 7,734 7,57 748,966 13,656,658 31 33 Page 329.8 13,317,34! 34 ms m~~~~: I Name of ~""'~~"''""'" Florida Power & Light Company (2) =;A •wo~u' I "'ooov< Date of Report (Mo, Da, Yr) I J TRANSMISs~g~~ln~ ,Et T~~lg ~We~e~ ~~i~t~~~Tingw 4~oJ ,~u ...... w..!OJ ~~" ~ .. u. of Report I End of 2015/Q4 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column {k), provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers _rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero {11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. REVENUE FROM TRANSI\IIISSION OF ELECTRICITY FOR OTHERS Ene r Charges . (Other ~arges) Demand Charges ($) (k) ·~~? Line No. Total tevenuef; ($) Jr2l 41,022 $1,023 1 5,28:i 5,282 2 1 ,43~ 1,433 3 2,88E 2,889 4 22,36:; 22,362 5 192,711 192,711 6 162 162 7 83,23E 83,23S 8 ~ 20,827 9 98S 10 2,63( 2,630 11 115,96S 115,969 12 5,61€ 5,618 13 27,69~ 27,695 14 2,717 2,717 15 43,872 16 8,456 17 1,720 18 98E 43,872 m:; 8,471 1,720 10,095 10,095 19 209,292 209,292 20 6,395 6,395 21 3,440 3,440 22 44 44 23 1,372 1,372 24 l.;rp,'~'''tEc:R"*: : 196 :::,.m:;:\: 980 25 26 979 27 939 939 28 5C 49 29 19E 196 30 1,183 31 22,214 32 15,332 26,057 55,702,558 FERC FORM NO. 1 (ED. 12-90) -33 196 1:.:- 1,026,599 Page 1,399,111 330.8 -2,268 33 50,145 34 58,128,268 00 ort Is: This (1) X An Original (2) tjA Resubmission Name of Respondent Florida Power & Light Company I (lncludh1g Date of Report (Mo, Da, Yr) I J Year/Period of Report End of 2015/04 t?!n~~~risK~~'rie~?aRa's' ~~~l~n~~ccount 456 ·1) 1 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP -"Long-Term Firm Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or ''true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Payment By (Company of Public Authority} (Footnote Affillatlon) (a) Line No. Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Statistical Class iffcation (d) AD 1 Sarasota County Landfill N/A NIA 2 Sarasota County Landfill Florida Power & Light Company Sarasota County Landfill FNO 3 Sarasota County Landfill Florida Power & Light Company Sarasota County Landfill FNO 4 Sarasota County Landfill Florida Power & Light Company Sarasota County Landfill FNO 5 Sarasota County Landfill N/A N/A OS 6 tt~~:~J~9lti.~P~~-il~'qf;,'if~i1~~;L~2 Seminole Electric Cooperative Seminole Electric Cooperative 7 Seminole Electric Cooperative, Inc. Florida Power & Light Company 8 Seminole Electric Cooperative, Inc. Gainesville Regional Utilities NF JEA NF Progress Energy Florida NF 9 Seminole Electric Cooperative, Inc. Florida Power & Light Company Southern Company Services, Inc. NF 10 Seminole Electric Cooperative, Inc. Seminole Electric Cooperative Southern Company Services, Inc. NF 11 Seminole Electric Cooperative, Inc. Florida Power & Light Company Seminole Electric Cooperative FNO 12 13 14 15 16 17 18 19 20 21 22 23 Seminole Electric Cooperative, Inc. Florida Power & Light Company Progress Energy Florida SFP Seminole Electric Cooperative, Inc. Florida Power & Light Company Progress Energy Florida AD Seminole Electric Cooperative, Inc. Seminole Electric Cooperative Florida Power & Light Company NF Seminole Electric Cooperative, Inc. Florida Power & Light Company Seminole Electric Cooperative LTF Seminole Electric Cooperative, Inc. Southam Company Services, Inc. Seminole Electric Cooperative NF Seminole Electric Cooperative, Inc. Southam Company Services, Inc. Seminole Electric Cooperative NF Seminole Electric Cooperative, Inc. Seminole Electric Cooperative Gainesville Regional Utilities NF Seminole Electric Cooperative, Inc. Seminole Electric Cooperative JEA NF Seminole Electric Cooperative, Inc. NJA N/A OS Progress Energy Florida NF Seminole Electric Cooperative, Inc. Florida Power & Light Company Seminole Electric Cooperative, Inc. NJA NIA OS Seminole Electric Cooperative, Inc. Southam Company Services, Inc. Progress Energy Florida NF 24 Seminole Electric Cooperative, Inc. JEA Southam Company Services, Inc. NF 25 26 27 28 29 30 31 32 33 34 JEA City of New Smyma Beach NF Seminole Electric Cooperative, Inc. Seminole Electric Cooperative, Inc. Florida Power & Light Company Seminole Electric Cooperative FNO Seminole Electric Cooperative, Inc. Florida Power & Light Company Progress Energy Florida SFP Seminole Electric Cooperative, Inc. Southern Company Services, Inc. Progress Energy Florida NF Seminole Electric Cooperative, Inc. N/A NJA OS Seminole Electric Cooperative, Inc. JEA Seminole Electric Cooperative LTF Seminole Electric Cooperative, Inc. JEA Seminole Electric Cooperative NF Seminole Electric Cooperative, Inc. N/A N/A OS Seminole Electric Cooperative, Inc. Florida Power & Light Company Seminole Electric Cooperative FNO Seminole Electric Cooperative, Inc. N/A N/A AD TOTAL FERC FORM NO.1 (ED. 12-90) Page 328.9 Name of Respondent Florida Power & Light Company Date of Report This wort Is: (1) X An Original (Mo, Da, Yr) I I (2) OA Resubmission TRANSMISSJO ! t:!E_~~t:v I K!~II_Y _!"2_R_(?1!-I~_R,l) ~~ ccount 456){Contrnued) -(Including transactions reffered to as 'wtieeling') 1 Year/Period of Report 2015/Q4 End of 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column 0) and (j) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) Point of Receipt (Subsatation or Other Designation) (f) Point of Delivery (Substation or Other Designation) (g) N/A N/A System System System System System NIA N/A 38 System Deerhaven Substation 38 System System 38 System System TRANSFER OF ENERGY MegaWatt Hours Received (i) Line No. MegaWatt Hours Delivered 0) 1 System 32 Billing Demand (MW) (h) 15 7,734 7,701 15 8,438 8,061 2 3 4 5 50 50 2,595 583 2,925 2,675 5( 6 57 7 2,62E 8 38 System System 10 10 1C 9 38 System System 122 122 12L 10 162 System System 1,009 528,728 498,763 11 234 System System 110 2,640 2,59~ 12 System System 13 System System 150 14 System System 300 15 65 System System 600 600 58~ 16 38 System System 292 600 58~ 17 38 System Deerhaven Substation 20 20 2( 18 38 System System 1,008 148 14f 19 38 N/A N/A 3,010 1,530 1,50. 20 38 System System 38 N/A N/A 38 System System 4,390 1,872 1,83f 23 38 System System 430 3,650 3,58f 24 38 System Smyma Substation 3 30 2~ 25 566,279 534,77f 26 5,657 5,551 5,805 2,995 2,941 21 56,332 10,062 9,88 22 162 System System 1,130 234 System System 250 38 System System 3,740 NIA NIA 27 28 29 234 System System 450 65 System System 105 105 10 31 32 N/A N/A 398 398 39 32 System System 350 350 34t 33 N/A N/A 1,278 692 68( 34 748,966 13,656,658 13,317,34f FERC FORM NO.1 (ED. 12-90) Page 329.9 30 Date of Report {Mo, Da, Yr) I I Florida Power & Light Company 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column {m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column {a). If no monetary settlement was made, enter zero (11 011) in column {n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (Q and G) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. Demand Charges Total Revenues($) {k+l+m) (n) ($) (k) 55,702,558 FERC FORM N0.1 (ED. 12·90) 1,026,599 Page 330.9 1,399,111 58,128,268 Name of Respondent Florida Power & Ught Company This '[K]ort Is: (1) X An Original (2) (]A Resubmission Date of Report (Mo, Da, Yr) I I TRAN~!Vil t;il:ij~N .c:?.~ EL~CTR~C~L~ !;I!_K_~! HE~~- (Account (Including transactions referred to as 'wheelinii'f Year/Period of Report End of 2015/Q4 456.1) 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column·(a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO- Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP- "Long-Term Firm Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF- non-firm transmission service, OS -Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Payment By (Company of Public Authority) (Footnote Affiliation) (a) Line No. 1 Seminole Electric Cooperative, Inc. 2 Seminole Electric Cooperative, Inc. 3 Seminole Electric Cooperative, Inc. Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Statistical Classffication (d) Florida Power & Light Company Southern Company Services, Inc. NF Gainesville Regional Utilities City of Homestead Utilities NF Gainesville Regional Utilities JEA NF 4 Seminole Electric Cooperative, Inc. Florida Power & Light Company Southern Company Services, Inc. FNO 5 Seminole Electric Cooperative, Inc. Gainesville Regional Utilities City of New Smyrna Beach NF 6 Seminole Electric Cooperative, Inc. Florida Power & Light Company Tampa Electric Company NF 7 Seminole Electric Cooperative, Inc. Florida Power & Light Company Seminole Electric Cooperative FNO 8 Seminole Electric Cooperative, Inc. Seminole Electric Cooperative Gainesville Regional Utilities NF JEA NF Seminole Electric Cooperative, Inc. Florida Power & light Company Progress Energy Florida NF Seminole Electric Cooperative, Inc. Florida Power & Light Company Southern Company Services, Inc. NF Seminole Electric Cooperative, Inc. Seminole Electric Cooperative Southern Company Services, Inc. NF Seminole Electric Cooperative, Inc. Florida Power & Light Company Seminole Electric Cooperative FNO Seminole Electric Cooperative, Inc. NIA N/A AD 15 Seminole Electric Cooperative, Inc. Southern Company Services, Inc. Progress Energy Florida NF 16 Seminole Electric Cooperative, Inc. Florida Power & Light Company Seminole Electric Cooperative LFP 17 Seminole Electric Cooperative, Inc. N/A N/A OS 18 Seminole Electric Cooperative, Inc. Southern Company Services, Inc. City of New Smyrna Beach NF 19 Seminole Electric Cooperative, Inc. 20 Seminole Electric Cooperative, Inc. Florida Power & Light Company City of New Smyrna Beach NF N/A NIA OS 9 Seminole Electric Cooperative, Inc. 10 11 12 13 14 Seminole Electric Cooperative 21 Tampa Electric Company Florida Power & Light Company Tampa Electric Company NF 22 Tampa Electric Company 23 Tampa Electric Company Southern Company Services, Inc. Tampa Electric Company NF Southern Company Services, Inc. City of New Smyrna Beach NF 24 Tampa Electric Company Tampa Electric Company JEA NF 25 Tampa Electric Company Tampa Electric Company City of New Smyrna Beach NF 26 Tampa Electric Company Tampa Electric Company Florida Power & Light Company NF NF 27 Tampa Electric Company Tampa Electric Company Southern Company Services, Inc. 28 29 30 31 32 33 Tampa Electric Company Southern Company Services, Inc. Tampa Electric Company SFP Tampa Electric Company Florida Power & Light Company Tampa Electric Company NF Tampa Electric Company Gainesville Regional Utilities Tampa Electric Company NF Tampa Electric Company JEA Tampa Electric Company NF Tampa Electric Company Southern Company Services, Inc. City of New Smyrna Beach NF Tampa Electric Company Tampa Electric Company JEA NF Southern Company Services, Inc. NF 34 Tampa Electric Company Tampa Electric Company TOTAL FERC FORM NO.1 (ED.12-90) Page 328.10 Name of Respondent Florida Power & Light Company T Year/Period of Report 2015/04 End of Date of Report This [i]ort Is: {Mo, Da, Yr) (1) X An Original I I (2) [1A Resubmission qf E\-ECI K!~ll T F9R qTHER,s.~Account 456)(Contlnued) (Including transactions reffered to as 'wlieelin!l} I 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified In the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and 0) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) Point of Receipt (Subsatation or Other Designation) (f) Point of Delivery (Substation or Other Designation) (g) Billing Demand TRANSFER OF ENERGY {MW) (h) Line No. Megawatt Hours Delivered MegaWatt Hours Received (i) a> 38 System System 38 Deerhaven Substation Lucy Substation 38 System System 106 106 1~ 3 38 Deerhaven Substation System 1,476 693,726 653,311 4 38 Deerhaven Substation Smyrna Substation 38 System System 6 162 System System 7 27 89;102 1 13,213 12,96~ 450 2 5 38 System Deerhaven Substation 95 95 9~ 38 System System 6,226 3,836 3,7se 9 38 System System 17,434 10,348 10,161 10 38 System System 865 865 84~ 11 38 System System 1,406 733 72:< 12 162 System System 1,117 560,015 529,882 13 N/A N/A System System 1,350 1,200 1 '178 15 System System 450 65 N/A N/A 53,256 4,216 4,139 17 65 System Smyrna Substation 61 61 60 18 System Smyrna Substation 11 11 11 N/A N/A 38 66 8 14 16 19 20 65 System System 1,222 1,953 1, 14E 21 65 System System 7,997 8,936 8,57E 22 65 System Smyrna Substation 65 System System 65 System 65 System 65 System 5 15 1~ 23 479 469 58( 24 Smyrna Substation 11 18 1E 25 System 25 System 31 30 21 27 26 234 System System 840 160 65 System System 21,614 21,918 65 Deerhaven Substation System 20 65 System System 151 65 System Smyrna Substation 175 175 65 System System 1,459 65 System System 2,448 748,966 13,656,658 13,317,345 FERC FORM N0.1 (ED. 12-90) Page 329.10 28 21,510 29 20 2C 30 151 14B 31 175 32 1,457 1,431 33 2,391 2,34r 34 mis ~~~ ~~iginal I Name of ,-~~"u' ,. ....,,,. Florida Power & Light Company (2) T Date of Report (Mo, Da, Yr) t=" A Resubmission I I -(fnch~in~lrr~~J!'J~~; ~We~e~-~~~~~~~~~St 456) {l,;ontmuea) Yea~PenodofReport I End of 2015/04 9. In column (k) through (n}, report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i) and G) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. REVENUE FROM 1_ _.._ Energy Charges Demand.~harges ~!~ :~InN OF ELECTRIC Ill'£'()!={ v (Other Charges) 1m:.r~;:, (I) Line Total Revenues ($) (l<+l+m) (~) ($) No. (n) 132 132 1 1,304 1,304 2 339 ? 4.?Fi Fi4.~ 176,795 ![ElkT£t\S~, 716,324 2,; ~ 339 3 ~ 2,665,030 4 716,324 5 ~ 146,522 6 600,000 7 8 221 221 23,695 23,695 9 75,280 75,280 10 270 270 11 3,102 3,102 12 1,941,663 13 -1,624 -1,624 14 3,362 3,362 15 766,581 16 1,836,740 45,011. !2 766,593 17 299 299 18 54 54 19 -60 20 1,639 1,639 21 31,432 31,432 22 25 23 2!: :;;c~;,;::cc:;;;;~ 1,444 5~ ~ 1,394 24 54 25 12~ 123 26 103 103 27 817,159 806,119 28 1,851 1,851 29 125 125 31 2E 25 fi40 30 32 33 34 55,702,558 FERC FORM N0.1 (ED. 12-90) 1,026,599 Page 1,399,111 330.10 58,128,268 00tJ Name of Respondent Florida Power & Light Company T This ort Is: Date of Report {Mo, Da, Yr) (1) X An Original I I (2) A Resubmission lN,OF EL~G-1 Klv) IT ~9R OJt:tER~J.Account 456.1) -{including transactions referred to as 'wheeling') Year/Period of Report 2015/Q4 End of 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report In column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP- "Long-Term Firm Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Payment By (Company of Public Authority) {Footnote Affiliation) {a) line No. Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Statistics I Classification (d) NF 1 Tampa Electric Company Tampa Electric Company Gainesville Regional Utilities 2 3 4 5 6 Tampa Electric Company Tampa Electric Company City of Homestead Utilities NF Tampa Electric Company Tampa Electric Company City bf New Smyrna Beach NF Tampa Electric Company N/A N/A OS Tampa Electric Company JEA Tampa Electric Company NF Tampa Electric Company Southern Company Services, Inc. Tampa Electric Company LFP 7 Tampa Electric Company Southern Company Services, Inc. Tampa Electric Company SFP 8 Tampa Electric Company South em Company Services, Inc. Tampa Electric Company NF 9 Tampa Electric Company Southern Company Services, Inc. Gainesville Regional Utilities LFP 10 Tampa Electric Company N/A N/A OS 11 12 13 14 15 16 Tampa Electric Company N/A N/A OS Tampa Electric Company Southern Company Services, Inc. JEA NF Tampa Electric Company Southern Company Services, Inc. Orlando Utilities Commission NF Tampa Electric Company JEA Oriando Utilities Commission NF Tampa Electric Company City of Homestead Utilities NF Tampa Electric Company JEA JEA Gainesville Regional Utilities NF 17 Tampa Electric Company JEA City of New Smyrna Beach NF 18 Tampa Electric Company 19 Tampa Electric Company Seminole Electric Cooperative Gainesville Regional Utilities NF N/A N/A OS 20 Tampa Electric Company Southern Company Services, Inc. Gainesville Regional Utilities NF 21 Tampa Electric Company Florida Power & Light Company Tampa Electric Company NF 22 Tampa Electric Company Southern Company Services, Inc. Tampa Electric Company LFP 23 Tampa Electric Company Southern Company Services, Inc. Tampa Electric Company NF 24 Tampa Electric Company JEA Tampa Electric Company NF 25 Tampa Electric Company Tampa Electric Company Southern Company Services, Inc. NF 26 Tampa Electric Company Florida Municipal Power Pool Tampa Electric Company NF 27 Tampa Electric Company Gainesville Regional Utilities Tampa Electric Company OS 28 29 30 31 32 33 34 Tampa Electric Company Tampa Electric Company Florida Power & Light Company OS Tampa Electric Company Tampa Electric Company Gainesville Regional Utilities OS Tampa Electric Company Tampa Electric Company JEA OS Tampa Electric Company Tampa Electric Company City of New Smyrna Beach OS The Energy Authority Florida Municipal Power Pool Gainesville Regional Utilities NF The Energy Authority Florida Municipal Power Pool JEA NF The Energy Authority Florida Power & Light Company Gainesville Regional Utilities NF TOTAL FERC FORM NO.1 (ED. 12-90) Page 328.11 ort Is: This (1) X An Original (2) [JA Resubmission Name of Respondent 00 Florida Power & Light Company I Date of Report (Mo, Da, Yr) Year/Period of Report 2015/Q4 End of I I TRANSMISSIO ~_qf 1:~_1§~_!-~!~l_:r_Y_j=.Q_~_l;'! Ht:K,S (Account 4oo)tt;ontlnued) -(Including transactions reffered to as 'wlieeling;} 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and (j) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) 65 Point of Receipt (Subsatation or Other Designation) {f) System Point of Delivery (Substation or Other Designation) (g) Billing Demand (MW) (h) Deerhaven Substation 65 System Lucy Substation 65 System Smyrna Substation TRANSFER OF ENERGY MegaWatt Hours Received {i) 1,642 Line No. MegaWatt Hours Delivered {j) 1,639 1,61C 1 10 10 1G 2 821 786 78J 3 5 65 N/A NIA 65 System System 2,571 4,671 4,585 234 System System 48C 19,010 18,65:.! 234 System System 360 234 System System 21,411 24,084 23,631 234 System Deerhaven Substation 21,391 19,006 18,641 9 N/A N/A 50 50 49 10 7,583 7,253 7, 11a 11 178 178 175 12 36C 4 6 7 8 N/A N/A 65 System System 65 System System 56 6 6 13 65 System System 56 56 55 14 65 System Lucy Substation 174 150 15( 65 System Deerhaven Substation 65 System Smyrna Substation 65 System Deerhaven Substation 944 919 90£ 65 N/A NIA 480 28,515 27,97~ 19 65 System Deerhaven Substation 16,58:.! 13,602 13,351 20 15 16 618 17 18 65 System System 18,065 18,025 17,68.: 21 65 System System 3,545 31,486 30,89€ 22 65 System System 7,084 6,946 6,817 23 65 System System 12,597 9,929 9,746 24 65 System System 5,783 5,729 5,62~ 25 65 System System 90 90 BE 26 65 System System 45 45 4~ 27 65 System System 10 65 System Deerhaven Substation 2,804 2,802 2,75€ 29 65 System System 652 652 63f 30 66 System Smyrna Substation 198 198 19 31 112 System Deerhaven Substation 120 120 12( 32 112 System System 112 System Deerhaven Substation FERC FORM N0.1 (ED.12-90) Page 329.11 28 250 250 24~ 33 4,287 4,277 4,241 34 748,966 13,656,658 13,317,345 1Name of .... Date o~~~~ort (Mo, Da, I I mislrort Is: An Original (2) A Resubmission Florida Power & Light Company I•~• .,. ~ .. ~J of Rep_ort End of 2015104 !U.ftTr'i~J:J~~ ~w:r~1~~~~ (JI~OU~! 456) (CuiiUIIUCUJ um;iUOinQ 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column {k.), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column {n). Provide a footnote explaining the nature of the non-monetary settlement, Including the amount and type of energy or service rendered. 10. The total amounts in columns {i) and 0) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following ali required data. REVENUE FROM TRAN~MI!':Sinl\\ OF ELECTRICITY FOR OTHERS (Other Charges) Energy Charges Demand Charges {$) ($) (k) (I) ($) (m) Line Total Revenues ($) (k+l+m) No. (n} 1 49 49 2 79 3 -6,874 4 21,891 21,891 5 801,571 801,571 6 40,533 40,533 8 2,265 2,265 9 33,961 33,961 79 -6, '7o II 7 10 11 12 13 14 15 i•:,c.•::•.•,':; o'i<'l6't 18,167 16 3,02S 3,028 17 817,69f 817,699 19 31,07€ 31,076 20 p.• 18 2,392 2,392 21 817,69E 817,699 22 23 28,061 28,061 52,716 52,716 24 594 594 25 441 441 26 27 28 29 30 l:f']'{ -66 31 588 588 32 1,225 1,225 33 14,008 14,008 34 55,702,558 FERC FORM NO. 1 (ED. 12-90) 1 ,399,111 1,026,599 Page 330.11 58,128,268 Name of Respondent This §ort Is: ·(1) X An Original (2) A Resubmission Florida Power & Light Company Date of Report (Mo, Da, Yr) JI KAN~rr:~~~J~~ 1~;a~~g~s~;~~lr~~'fo"a~~~~Wn~~ccount 4:>6.1) I Year/Period of Report 2015104 End of 1 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column {c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the "respondent has with the entities listed in columns (a), (b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO- Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP- "Long-Term Firm Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF- non-firm transmission service, OS- Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Payment By (Company of Public Authority) (Footnote Affiliation) (a) Line No. Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Statistical Classification (d) NF 1 The Energy Authority Florida Power & Light Company JEA 2 The Energy Authority Florida Power & Light Company Southern Company Services, Inc. NF 3 The Energy Authority Gainesville Regional Utilities City of Homestead Utilities NF 4 The Energy Authority Gainesville Regional Utilities JEA NF 5 The Energy Authority Gainesville Regional Utilities Southern Company Services, Inc. NF 6 The Energy Authority Gainesville Regional Utilities Tampa Electric Company NF 7 The Energy Authority JEA City of Homestead Utilities NF 8 The Energy Authority JEA City of New Smyma Beach NF 9 The Energy Authority Seminole Electric Cooperative Gainesville Regional Utilities NF 10 The Energy Authority Seminole Electric Cooperative JEA NF 11 The Energy Authority Southern Company Services, Inc. Florida Power & Light Company NF 12 The Energy Authority Southam Company Services, Inc. Florida Municipal Power Pool NF 13 The Energy Authority Southern Company Services, Inc. Gainesville Regional Utilities NF 14 The Energy Authority Southern Company Services, Inc. City of Homestead Utilities NF 15 The Energy Authority Southern Company Services, Inc. City of New Smyma Beach NF 16 The Energy Authority Gainesville Regional Utilities Southern Company Services, Inc. SFP 17 The Energy Authority Florida Municipal Power Pool Gainesville Regional Utilities NF 18 The Energy Authority Florida Municipal Power Pool JEA NF 19 The Energy Authority Florida Power & Light Company Gainesville Regional Utilities NF 20 The Energy Authority Florida Power & Light Company JEA NF 21 The Energy Authority Florida Power & Light Company Southern Company Services, Inc. NF 22 The Energy Authority Gainesville Regional Utilities City of Homestead Utilities NF 23 The Energy Authority Gainesville Regional Utilities JEA NF 24 The Energy Authority Gainesville Regional Utilities Southern Company Services, Inc. NF 25 The Energy Authority Gainesville Regional Utilities City of New Smyrna Beach NF 26 The Energy Authority Gainesville Regional Utilities City of New Smyrna Beach SFP 27 The Energy Authority Gainesville Regional Utilities Tampa Electric Company NF 28 The Energy Authority JEA City of New Smyrna Beach NF 29 The Energy Authority Southern Company Services, Inc. Gainesville Regional Utilities NF 30 The Energy Authority Southern Company Services, Inc. City of Homestead Utilities NF 31 The Energy Authority Seminole Electric Cooperative Gainesville Regional Utilities NF 32 The Energy Authority Seminole Electric Cooperative City of Homestead Utilities NF 33 The Energy Authority Southern Company Services, Inc. City of New Smyrna Beach NF 34 The Energy Authority Southern Company Services, Inc. Tampa Electric Company NF TOTAL FERC FORM NO.1 (ED. 12-90) Page 328.12 ort Is: This (1) X An Original (2) OA Resubmission 00 Name of Respondent ~ Florida Power & Light Company I• Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/Q4 End of I ~· •v•mv..;l~~u~tn~~~ia~~~IJsYr~~~e~ l~i~·~k'e~~~·~t 456)(ConffnueaJ 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column {f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the finn transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and (J) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) Point of Receipt (Subsatation or Other Designation) (f) Billing Demand (MW) (h) Point of Delivery (Substation or other Designation) {g) TRANSFER OF ENERGY MegaWatt Hours Received (i) Line No. Megawatt Hours Delivered 0} 112 System System 3,352 3,277 3,22f 1 112 System System 52C 490 48f 2 112 Deerhaven Substation Lucy Substation ~ 9 ~ 3 112 Deerhaven Substation System 4C 35 3~ 4 28. 4( 6 112 Deerhaven Substation System 290 285 112 Deerhaven Substation System 40 40 5 112 System Lucy Substation 6 6 f 7 112 System Smyrna Substation 19 19 19 8 112 System Deerhaven Substation 10 10 10 9 112 System System 70 70 69 10 112 System System 5 112 System System 204 204 200 112 System Deerhaven Substation 2,836 2,745 2,721 13 112 System Lucy Substation 133 133 133 14 112 System Smyrna Substation 139 139 139 15 16 11 12 12.9 Deerhaven Substation System so 7,225 7,068 112 System Deerhaven Substation 52 52 51 17 112 System System 250 250 24~ 18 112 System Deerhaven Substation 525 504 50< 19 112 System System 873 787 78E 20 112 System System 95 95 9! 21 112 Deerhaven Substation Lucy Substation 144 210 20E 22 112 112 Deerhaven Substation System 3,888 3,191 23 Deerhaven Substation System 1,139 3,243 1,058 1,041 24 112 Deerhaven Substation Smyrna Substation 71 71 71 25 234 Deerhaven Substation Smyrna Substation 75 1,031 1,om 26 112 Deerhaven Substation System 20 4 ' 27 112 System Smyrna Substation 81 60 6( 112 System Deerhaven Substation 1,996 1,582 1,561 29 112 System Lucy Substation 579 553 54f 30 20 2( 32 28 112 System Deerhaven Substation 25 112 System Lucy Substation 20 112 System Smyrna Substation 372 398 391 33 112 System System 482 482 47 34 748,966 13,656,658 FERC FORM N0.1 (ED.12-90) Page 329.12 31 13,317,34f Date of Report This ~~rrt Is: (1) X An Original (Mo, Da, Yr) I I (2) EJA Resubmlsslon TRAN::>MISSIO O.f El,.tC 1 Klyll Y FQR q~HER;> (Accou~t 456} {Continued} (Including transactions raftered to as 'wlieelingif Name of Respondent Florida Power & Light Company Year/Period of Report 2015104 End of 9. In column (k) through (n}, report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (Q and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS Energy Charges (Other Charges) Demand Charges ($) (k) ($) ($) (I) (m) Line No. Total Revenues($) (k+l+m) (n) . 11,046 11,046 1 1,890 1,890 2 44 44 3 100 100 4 1,264 1,264 5 196 196 6 29 29 7 93 93 8 25 25 9 343 343 10 12 12 11 1,000 1,000 12 9,098 9,041 13 536 536 14 647 647 15 85,177 85,177 16 255 255 17 1,225 1,225 18 1,891 1,891 19 3,447 3,447 20 333 333 21 788 788 22 12,906 12,906 23 4,995 4,995 24 280 280 25 4,301 4,301 26 20 20 27 28 301 301 7,799 7,799 29 2,474 2,474 30 123 123 31 98 98 32 1,771 1,771 33 1,200 1,200 34 55,702,558 FERC FORM NO. 1 (ED. 12·90) 1,026,599 Page 1,399,111 330.12 58,128,268 Name of Respondent Florida Power & Light Company This (1) (2) ort Is: An Original CJA Resubmission 00X Date of R~ort (Mo, Da, r) I I Year/Period of Report 2015/04 End of I KAN~~c~j>J~~ ~Jn;~~~ri:~~~Je~~ta~·t...~~l~nt>ccount 456.1) 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public awthority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO- Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP- "Long-Term Finm Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF- non-firm transmission service, OS- Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Payment By (Company of Public Authority) (Footnote Affiliation) (a) Une No. Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Energy Dellvered To (Company of Public Authority) (Footnote Affiliation) (c) Statistical Classifi-cation (d) 1 The Energy Authority Southern Company Services, Inc. Orlando Utilities Commission NF 2 The Energy Authority JEA Tampa Electric Company NF 3 The Energy Authority JEA City of Homestead Utilities NF 4 The Energy Authority 5 The Energy Authority JEA Gainesville Regional Utilities NF JEA City of New Smyrna Beach NF 6 The Energy Authority JEA City of New Smyma Beach SFP 7 The Energy Authority JEA Gainesville Regional Utilities SFP 8 The Energy Authority JEA Gainesville Regional Utilities NF NF 9 The Energy Authority JEA City of Homestead Utilities 10 The Energy Authority JEA Tampa Electric Company NF 11 The Energy Authority 12 The Energy Authority 13 The Energy Authority N!A N/A OS N/A N/A OS Seminole Electric Cooperative JEA NF 14 The Energy Authority JEA Tampa Electric Company NF 15 The Energy Authority Southern Company Services, Inc. City of New Smyrna Beach LFP 16 The Energy Authority Southern Company Services, Inc. Tampa Electric Company NF 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 The Energy Authority Florida Power & Light Company Gainesville Regional Utilities NF The Energy Authority Florida Power & Light Company Florida Power & Light Company NF The Energy Authority Florida Power & Light Company Gainesville Regional Utilities NF The Energy Authority Florida Power & Light Company Florida Power & Light Company NF The Energy Authority Florida Power & Light Company Florida Power & Light Company NF The Energy Authority Gainesville Regional Utilities City of Homestead Utilities NF The Energy Authority Gainesville Regional Utilities JEA NF The Energy Authority Gainesville Regional Utilities Southern Company Services, Inc. NF The Energy Authority Gainesville Regional Utilities City of New Smyrna Beach NF The Energy Authority Florida Power & Light Company Tampa Electric Company NF The Energy Authority Florida Power & Light Company City of New Smyma Beach NF The Energy Authority Southern Company Servlces, Inc. Gainesville Regional Utilities SFP The Energy Authority Southern Company Services, Inc. City of Homestead Utilities NF The Energy Authority Florida Power & Light Company Gainesville Regional Utilities NF The Energy Authority Southern Company Services, Inc. JEA NF The Energy Authority Southern Company Services, Inc. Orlando Utilities Commission NF The Energy Authority JEA Orlando Utilities Commission NF 34 The Energy Authority JEA City of Homestead Utilities NF TOTAL FERC FORM NO. 1 (ED. 12-90) Page 328.13 Name of Respondent Florida Power & Ught Company ort Is: This Date of Report (Mo, Da, Yr) (1) X An Original I I A Resubmission (2) TRANSMISSJ_Q ~. qf E!-ECTR!CITY FQR QTHER,S (Accoul)t 456){Continued) (Including transactions reffered to as 'wlieelinit') 00 0 YeariPeriod of Report 2015104 End of In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the 5. contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. Report in column (i) and G) the total megawatthours received and delivered. 8. FERC Rate Schedule of Tariff Number (e) Point of Receipt (Subsatation or Other Designation) {f) Point of Delivery (Substation or Other Designation) Billing Demand (g) (h) TRANSFER OF ENERGY (MW) Line No. Megawatt Hours Delivered MegaWatt Hours Received (i} 0) 112 System System 1,204 729 7H 1 112 System System 600 600 58! 2 112 System Lucy Substation 36 36 3E 3 112 System Deerhaven Substation 35 25 2~ 4 112 System Smyrna Substation 36 36 3E 5 112 System Smyrna Substation 15 321 31t 6 234 System Deerhaven Substation 47 752 73! 7 112 System Deerhaven Substation 10 10 1C 8 112 System Lucy Substation 5 5 E 9 112 System System 8,400 7,352 N/A NIA 7,21 10 11 12 NIA NIA 112 System System 44 65 System System 130 130 129 14 234 System Smyrna Substation 97 97 96 15 234 System System 6,159 5,594 5,522 16 13 112 System Deerhaven Substation 147 122 12 17 112 System System 177 177 17 18 112 System Deerhaven Substation 30 30 3( 19 112 System System 689 669 65 20 112 System System 915 868 86• 21 112 Deerhaven Substation Lucy Substation 56 55 5! 22 112 Deerhaven Substation System 20 20 2( 23 24 112 Deerhaven Substation System 10 10 1( 112 Deerhaven Substation Smyrna Substation 887 11,699 11 ,487 25 112 System System 477 460 45~ 26 778 778 772 112 System Smyrna Substation 234 System Deerhaven Substation 112 System Lucy Substation 27 28 10 991 91 as 29 30 112 System Deerhaven Substation 5,837 3,313 112 System System 19 19 1! 31 112 System System 136 2,176 2,13E 32 112 System System 81 81 81 33 112 System Lucy Substation 75 1,200 1,17! 34 748,966 13,656,658 13,317,3M FERC FORM NO.1 (ED. 12-90) Page 329.13 3,25 Name of Respondent Florida Power & Light Company This wort Is: Date of Report {1) X An Original (Mo, Da, Yr) {2) Resubmission I I ~ ~~P..'!Y~o~~ccou~t ~g~:) (Continued) ' '"~nCludmg po er exc ang OA ··PI 1 I Year/Period of Report 2015/04 End of AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column {g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column Q), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (1). Explain in a footnote all components of the amount shown in column {I). Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain ctedits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must be reported as Purchases on Page 401, line 10. The total amount in column {h) must be reported a!s Exchange Received on Page 401, line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data. MegaWatt Hours Purchased (g) POWER EXCHANGES MegaWatt Hours MegaWatt Hours Received Delivered (h) (i) Demand Charges ($~ (k ($) (j) 46,241 5,500 COST/SETTlEMENt OF POWER Energy Charges Other Charges ($/ {I 4,090 line No. 1,930,243 1 239,511 239,511 2 269,867 269,867 1,930,24 " Total (j+k+l) of Settlement ($) (m} 3 4 5 6 7 8 9 10 11 12 13 14 7,948,125 FERC FORM NO.1 (ED. 12-90} 307,499,014 Page 327.4 275,331,152 108,091,570 690,921,73€ Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA -----::--c:-----:-:--:-----::::-:-----------------·---·-··---·-·""•"----------, ~edu/e Page: 326 Line No.: 1 Column: a complete Name: Broward County Resource Recove~_¥.=:...:_=:-!:'!.?.E!.!i.~-~------ - - · · - - - - - - - - - - - - - - , \Schedule ·Page: 326 L~I)_~.Ji~o·:.:..:-=2~~C:.:::o~/u~m=n.:...:~a-=-----~-..,.-.--:;-:;;--------- ................................._ ...__ _ Complete Name: Broward County Resource Recovery - North AA ...- ..........--- ........................... - - - - - - - - - - , lschedule Page: 326 Line No.:.,_3____ ~C~o~lu=m~n.:...:= - a - ; ; : : - - - - - : : ; - : - - : - = - - - - - - - - - -..- - - -..---·... Complete Name: Broward County Res.~o~u~r~c~e~R~e~c~o~v~e~r~y~-~N~o~r~t~h~-------------------, ~ule Page: 326 Line No.: ;,_--..-Column: a ........... ____________ ......-----· Complete Name: Broward County Resource Re~c~o~v~e~r~yL--~N~o~r~t=h~-------------------------------, \Schedule ~_e: 326 Line No.: 5 Column':a_____ _ Complete Name: Broward County Resource Recovery - South -----~~:--~~-::~:.:~:.. :~~-=-~~=~-----------, ~cflidiiiii-Page:- 326 LJIJ.~li'?..::.....6~....:c=.:o:==t-=u:.::m:..::n:.:..:_,_a_=------:::-----;-c:-----------·....._______.............- . Complete Name: Broward County Resource Recovery - South --..... ----·-·----------------, [Checiiifeiiige;·326 L!!!~ N~?_::__!_C =-=-o=-=lu:.o:m:.:.:n:.:.:::....:a=---~------=--;--;---;::-,;:----------· _____ Complete Name: Broward County Resource Recovery - South AA ,. _ _1 lc-chedule Page: 326 Line-f.io::-li---Column: a ~ ............... - ... -·--------------------------------' Complete Name: Broward County Resource Rec?"..~:CY -. §_C?.~!:.l?- ___.1_\A _____..............------------------------, \Schedule Pag~;}26 Line No.: 13 Column: a ____ ...... _________ ] THE FOLLOWING FOOTNOTE APPLIES TO ALL OCCURRENCES OF "FLORIDA MUNICIPAL POWER AGENCY" ON ALL 326 & 327 PAGES: -J St. Lucie Unit 2 is jointly owned by Florida Power & Light Company (85.10449%), Florida Municipal Power Agency (8.806%) and Orlando Utilities Commission (6.08951%) )Schedule Page: 326 ----Line-No~-: 14 Column_;_f!...... ...... __ _____ . THE FOLLOWING FOOTNOTE APPLIES TO ALL OCCURRENCES OF "FLORIDA MUNICIPAL POWER AGENCY" ON ALL 326 & 327 PAGES: St. Lucie Unit 2 is jointly owned by Florida Power & Light Company (85.10449%), Florida Municipal Power Agency (8.806%) and Orlando Utilities Commission (6.08951%) ~-ch-ecii.iFe Page: 32f!~.1 ....... 1:-l!l~_!'l·-=o-=.:.;:;.3:__....:c=co::.::l-=u:.::-m:.:,.n:.:.:-=a~-.-...-:----;---:;o-._ ....._-;__________ .....-;.....,....____ ....._. -_ .. _ ....._...._... _____. _ .. _ ...._ ...._..._... _ ....._...-==========-~~~-= Complete Name: Indiantown Cogeneration Limited Partnership )Schedule Page: 32if1·····i..T;ie-No.: 6 Column: o! .......... ................... ----------···--· ....... . Jacksonville Electric Authority is a Non-FERC Jurisdictional seller. These purchases are made under the Agreement for Joint Ownership of St. Johns River Power Park between Jacksonville Electric Authority and Florida Power and Light Company. . -................... 1 /Schedule Page.~326.1 Lin_f!! No.; !. _~'!I!!n: a Jacksonville Electric Authority is a No-n--~F~E~R~C~J~u-r-;i~s-d'~'·c-;t~~··o-n-.a-l,_s--e~l~l-e-r-.--~T'h_e_s_e__p_u_r_c-;-h-a_s_e_s__a_r_e_J made under the Agreement for Joint Ownership of St. Johns River Power Park between Jacksonville Electric Authority and Florida Power and Light Company. !Schedule Pa{}e:3'26.1-Line No.: 14.. .... ~C?Iu~_fJ.:_F!_ __ . . THE FOLLOWING FOOTNOTE APPLIES TO ALL OCCURRENCES OF "ORLANDO UTILITIES COMMISSION" ON ALL 326 & 327 PAGES: St. Lucie Unit 2 is jointly owned by Florida Power & Light Company (85.10449%), Florida Municipal Power Agency (8 . 806%) and Orlando Utilities Commission (6.08951%) ~chedute Page: 326.2 uneNo.:·-.,·--caiiimn':·a __ .. ________ -----· ·---=~THE FOLLOWING FOOTNOTE APPLIES TO ALL OCCURRENCES OF "ORLANDO UTILITIES COMMISSION" ON ALL 326 & 327 PAGES: . -..-. .-. -..-. -..-. -..-._-_-._ -_. .,] St. Lucie Unit 2 is jointly owned by Florida Power & Light Company (85.10449%), Florida Municipal Power Agency (8.806%) and Orlando Utilities Commission (6.08951%) !scfreduie . pagi:32.6.2 Line No.: 2 Column: a --------) Complete Name : Soi Ict-Wa.sfe Author'-;ci:.c-t:.:.y-=-o--,f:;-::P:c-a'l:-m----;B::-e-a-c'h--C;:;-o-u-n-t.,.-y---:-('4"0:-:MW=-c-)- - - - - - - - - - - - - - - - - - - - - - - - _ _ j l§chedule Page: 326.2 caTumn: a "un·e-"iio::"J. . . . . Wchedu/e Page: 326.2 Line'Na:::4·-"caliimn: a IFERC FORM NO. 1 (ED. 12-87) Cornplete Name: Solid Waste Authority of Palm Bea-ch.·~-CQ\lli·t·y·~--·(.rQMW} Page 450.1 ________ ·------------ [Nameof ~rs·· r&l~~-is: """'tJU"UCIIl Florida Power & Ught Company (2) T Date ofa~~ort (Mo, Da, I I jA Resuur"''""'ur, ~iin;,:lr~ln;'f,~~J~t?cl~:r~We~e~~~~.JieeTinQ:~ •456) (Continued) I T earwenoc of Report 2015/04 End of 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues frqm energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges Qn bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11 011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. DI=\/Ef"ll u::: FROM TDAO.IC! Energy Charges ($) (I) .-Demand Charges ($) (k) I.C:.C:I()"' OF ELEC'I Kll,;ll y FOROTHERS (Other Charges) Total ·~"1 'Line ($) (k+l+m) (n) ($) {m) No. 5,90( s,9oo 1 2,940 2,940 2 162 162 3 147 147 176 m 4 86G 860 2,679 2,679 5 6 i 49 49 -8 25 25 9 35,37€ ~ 42,8n -34,76.2 35.376 1o 42,815 11 -34,762 12 11C 110 13 63f 636 14 475 15 475 11f??R --18,246 16 60C 600 17 76€ 766 Ia 12:3 123 19 19,474 3,32f 3,328 2o 4,20:l 4,203 21 27~ 274 22 5C 5o 23 32 50,861 1,563 2,771 24 3~ 50,86 1,56~ 2,n 25 26 27 4~ 49 28 4,856 4,856 27,27~ 27,274 29 -30 93 93 3i 7,798 7,798 -32 314 33 314 4,300 34 4,300 55,702,558 FERC FORM NO. 1 (ED. 12-90) 1,026,599 Page 330.13 1,399,111 58,128,268 This ~ort Is: (1) X An Original (2) Resubmission Name of Respondent [lA Florida Power & Light Company I Date of Report (Mo, Da, Yr) I I Year/Period of Report End of 2015/04 KAN~rn6~~d~~ t~fnia'ci~~sKI~~r;e~?oRa~Uh~~~}f)ccount 456.1) Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO- Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP- "Long-Term Firm Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF- non-firm transmission service, OS - Other Transmission Service and AD -Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. 1. Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Payment By (Company of Public Authority) (Footnote Affiliation) (a) Line No. Statistical Classification (d) 1. The Energy Authority JEA Gainesville Regional Utilities SFP 2 The Energy Authority JEA City of New Smyrna Beach NF 3 The Energy Authority 4 The Energy Authority Seminole Electric Cooperative Gainesvllle Regional Utilities SFP JEA Gainesville Regional Utilities NF 5 The Energy Authority Southern Company Services, Inc. Gainesville Regional Utilities NF 6 The Energy Authority JEA Tampa Electric Company NF 7 The Energy Authority Florida Power & Light Company Gainesville Regional Utilities NF 8 The Energy Authority Florida Power & Light Company JEA NF 9 The Energy Authority Florida Power & Light Company Southern Company Services, Inc. NF The Energy Authority Gainesville Regional Utilities City of New Smyrna Beach NF The Energy Authority Florida Power & Light Company City of New Smyrna Beach NF The Energy Authority Gainesville Regional Utilities Orlando Utilities Commission NF The Energy Authority Gainesville Regional Utilities JEA NF The Energy Authority Gainesville Regional Utilities Southern Company Services, Inc. NF The Energy Authority Gainesville Regional Utilities Tampa Electric Company NF The Energy Authority JEA Gainesville Regional Utilities NF 10 11 12 13 14 15 16 17 18 19 20 21 The Energy Authority JEA City of Homestead Utilities NF The Energy Authority JEA City of New Smyrna Beach NF The Energy Authority Tampa Electric Company Gainesville Regional Utilities NF The Energy Authority JEA Orlando Utilities Commission NF The Energy Authority JEA Tampa Electric Company NF 22 The Energy Authority JEA Florida Power & Light Company NF 23 24 25 26 27 28 29 30 31 32 33 34 The Energy Authority Southern Company Services, Inc. JEA NF The Energy Authority Orlando Utilities Commission Gainesville Regional Utilities NF The Energy Authority Southern Company Services, Inc. Florida Power & Light Company NF The Energy Authority Southern Company Services, Inc. Gainesville Regional Utilities OS The Energy Authority Southern Company Services, Inc. Gainesville Regional Utilities NF The Energy Authority Seminole Electric Cooperative Gainesville Regional Utilities NF The Energy Authority Southern Company Services, Inc. City of Homestead Utilities NF The Energy Authority Southern Company Services, Inc. City of New Smyma Beach NF The Energy Authority Southern Company Services, Inc. Tampa Electric Company NF The Energy Authority Southern Company Services, Inc. Orlando Utilities Commission NF The Energy Authority Florida Power & Light Company Gainesville Regional Utilities SFP The Energy Authority N/A N/A OS TOTAL FERC FORM NO. 1 (ED. 12-90) Page 328.14 Name of Respondent 00rl Florida Power & Light Company I rv"\t" This ort Is: Date of Report (1) X An Original (Mo, Da, Yr) (2) A Resubmission I I ! QF E\,.t:t.; 1K!~ll Y-~.\,J_K_ u,! n~t<,'> .(Jl ccount 456)(COntrnued} ~(lncludina transactions reffered to as 'wtieeling'1 1 Year/Period of Report 2015104 End of i 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, ~point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and 0) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) Point of Receipt (Subsatation or Other Designation) (f) Point of Delivery (Substation or Other Designation) (g) Billing Demand TRANSFER OF ENERGY Megawatt Hours Received (MW) (h) Line No. MegaWatt Hours Delivered m (i) 234 System Deerhaven Substation 112 System Smyrna Substation 234 System Oeerhaven Substation 593 593 5~ 3 112 System Deerhaven Substation 1,25E 1,192 1,19~ 4 535 535 52<; 5 7 2,116 2,002 1,97C 1 20 25 2~ 2 112 System Deerhaven Substation 112 System System 112 System Deerhaven Substation 966 906 901 112 System System 195 195 195 8 112 System System 153 83 82 9 113 Deerhaven Substation Smyma Substation 26 26 26 10 114 System Smyrna Substation 46 46 4€ 112 Deerhaven Substation System 65 65 112 Deerhaven Substation System 705 112 Deerhaven Substation System 1,499 112 Deerhaven Substation System 983 25 21 15 112 System Deerhaven Substation 2,960 2,898 2,851 16 112 System Lucy Substation 112 System Smyrna Substation 6 11 -s; 12 653 s4i 13 1,464 1,45: 14 36 36 3€ 17 107 107 10s 18 112 System Oeerhaven Substation 71 71 70 19 112 System System 1,169 1,169 1,147 20 21 112 System System 5,168 5,007 4,913 112 System System 268 268 2Eli 22 112 System System 586 540 531 23 112 System Deerhaven Substation 20 20 2( 24 112 System System 30 26 25 112 System Deerhaven Substation 231 231 22[ 112 System Deerhaven Substation 16,673 15,728 15,521 27 112 System Deerhaven Substation 65 65 6• 28 112 System Lucy Substation 165 165 16 29 112 System Smyma Substation 532 518 51! 30 112 System System 125 105 10~ 31 112 System System 700 700 68 32 129 System Deerhaven Substation 140 800 78E 33 NJA N/A 34 748,966 FERC FORM NO. 1 (ED. 12-90) Page 329.14 13,656,658 13,317,34f I Name of ~his ~J?~rt Is: '" (1) (2) Florida Power & Light Company ~IAn jA Date of Report (Mo, Da, Yr) · nal Resubn"''"'v" .., .. v~ End of of Report 2015104 I I 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k.}, provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bms or vouchers rendered, including lout of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n} the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (11011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i) and 0) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. REVENUE FRO~ rRAfi.IC::ul<:!'::lnN OF Energ\-~~?harges Dem ELE{:;'I~ 1y FOR U 1Ht:.K::> (Other Charges} ($} (m} I One Total Revenues ($) No. (k+l+m) (n) 14,626 14,62€ 1 2 2,56:3 2,563 3 3,76~ 3,764 4 1,332 5 7,259 6 1,332 ~ 3,887 3,887 7 835 835 8 477 477 9 10 127 127 115 115 11 319 319 12 2,82a 2,828 13 4,969 4,969 14 4,817 4,817 15 13,036 13,036 16 121 121 17 47€ 476 18 177 177 19 5,728 5,728 20 25,036 25,036 21 1,313 1,313 22 2,368 2,368 23 98 98 24 75 75 25 59,583 59,583 27 319 319 28 26 570 570 29 1,698 1_,698 30 410 410 31 1,743 1,743 32 8,028 8,028 33 -17 34 55,702,558 FERC FORM NO. 1 (ED. 12-90) 1,026,599 Page 1,399,111 330.14 58,128,268 Name of Respondent This ~ort Is: (1) X An Original (2) A Resubmission Florida Power & Light Company 0 TKAN Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/Q4 End of I.OF ELE,CT_R~9_1J.i79R_ OJt'jER§ ~~~ccount 456.1) (lncludh1g transactions referred to as 'wheeling' 1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. 2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). 3. Report in column (a) the company or public authority that paid for the transmission service. fkeport in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns {a), {b) or (c) 4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO- Firm Network Service for Others, FNS- Firm Network Transmission Service for Self, LFP- "Long-Term Firm Point to Point Transmission Service, OLF- Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point to Point Transmission Reservation, NF- non-firm transmission service, OS - Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. Payment By (Company of Public Authority) (Footnote Affiliation) (a) Line No. Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) Statistical Classification (d) 1 Troplcana NIA N/A OS 2 Tropicana N/A N/A OS 3 Wheelabrator South Broward 4 Wheelabrator South Broward 5 Wheelabrator South Broward NIA N/A N/A N/A OS OS N/A N/A OS 6 City of Vero Beach Florida Power & Light Company Florida Municipal Power Pool FNO 7 City of Wauchula Florida Power & Light Company Progress~ Energy Florida FNO 8 City of Winter Park Florida Power & Light Company Progress' Energy Florida FNO 9 Journal Voucher Adjustment NIA N/A AD 10 Journal Voucher Adjustment N/A N/A AD 11 Journal Voucher Adjustment NIA N/A AD 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 TOTAL FERC FORM NO. 1 (ED. 12-90) Page 328.15 YearfPeriod of Report 2015/Q4 End of Date of R~ort {Mo, Da, r) X An Original I I OA Resubmission TRANSMISSlO qf E~CTR!CITY FgR l!THER,S (Account 456){Contlnued) (Including transactions reffered to as 'wheeling') This~rtls: Name of Respondent Florida Power & Light Company (1) (2) 5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. 6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. 7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. 8. Report in column (i) and (J) the total megawatthours received and delivered. FERC Rate Schedule of Tariff Number (e) Point of Receipt (Subsatation or Other Designation) (f) Billing Demand Point of Delivery (Substation or Other Designation) (g) TRANSFER OF ENERGY MegaWatt Hours Received (i) (MW) (h) Megawatt Hours Delivered Line No. (j) N/A NIA 1 2 N/A NIA NIA N/A 3 NIA N/A 4 NIA N/A 5 406 System 191,638 188,09 6 264 System 299 System System 32 15,137 14,651 7 325 System System 128 43,375 43,304 8 N/A N/A N/A 9 N/A 10 N/A N/A 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 748,966 FERC FORM NO. 1 (ED. 12-90) Page 329.15 13,656,658 13,317,34f Florida Power & Light Company 9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k}, provide revenues from demand charges related to the billing demand reported in column (h). In column (1), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero {11 011) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 10. The total amounts in columns (i) and U) must be reported as Transmission Received and Transmission Delivered tor annual report rposes only on Page 401, Lines 16 and 17, respectively. 11. Footnote entries and provide explanations following all required data. Total Revenues($) (k+l+m) (n) 55,702,658 FERC FORM NO.1 {ED. 12-90) 1,399,111 1,026,599 Page 330.15 58,128,268 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA \Schedule Page:-328--Liiieiio:·:·-1 Cf:![ld_f!ln_;_i!_ ___________~---,----,-------==-The "Balancing Authority'' from which the energy was received by FloridaP.ower & Light Company is used in all li~~i~g~s~l~·n~=c=o=l~u~m~n~(~b~)~·------------------'§chedule Page: 328 Line No.: 1 Column: d Terminates on May 1, 2017. [Schedule Page: 328 Line No.: 1 Cot.umn: tp_ _ _ ______,-=----.,-=--=--..,... Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty--Revenue refunded for non-of fending t ransact_":l=·-=-o=n-::=s--'.-=------------------------- ______ ...........·------------------------------. [Schedule Page: 328 ____ 1/iiii No.: 2 Column: m Credit for Energy Imbalance Penalty Revenue--and-Unreserved Use Penalty Revenue-r-efunded for non-offending transactions. ;=,::.-=--===-=-~-=-=-===--"---~=;;o=-=---':;::-'----'-"'-::::---'--:--------- ....................... @chedule Page: 328 Line No.: 3 __r:;_C?:::I::::um~n::...:~m:.......,.----=----------=--=------;-,-----,---unreserved Use Penalty Revenue refunded for non-offending transactions. i$..~hef!..u.~ ~t~Jl_e: 328 Line N0.:4-- .. Column: m _.: . : ___:-'----'---_ _ _ _ _ _ _ _---, FERC Assessment Fee for 2014 and credit for Energy Imha1ance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-of_f:~~-9:~1!-g transactions. ---------1 I fj;Cii'edulePage: 328 Line No.: 5 Colum~: !71 __ _____ _ Credit for Energy Imbalance Penalty Revenue and credit for Unreserved-Use Penalty Revenue refunded for non-offending t=r-=-a~n~s-=-a~c__::t__::i__::o__::n:::s~·~-------------~~~~~ul~ Page:m--Line-No::if' Column: m __________ ............. --FERC Assessment Fee for 201_4_·~~-------------------l§!?__hedule Page":'32ii- ·Line7.Jo::·-io Column: c This footnote applies to all occurrences of "JEA" on pages 328-328 .14-~---Fior'fda Power & Light Company and "JEA" are co-owners of St. Johns River Power Park, Scherer Unit No. 4, the Duval -Hatch and Duval-Thalman SOOkV transmission lin=--=--e-=-s.....________________ ..... _. ---~ ~CiieCiule"i'aile: 328 Line No.: 12 -~9 '-~-'!!_ll..:J!! _ __ __j Credit for Energy Imbalance Penalty Revenue and credit for Unreserve'd:-use Penalty Revenue refunded for non-offending transactions. _______________________ ~ule Page; ~?.~ __ L..~IJ.f!..fi.o:::. _! 6=--------=_·c_o....;.--,-=----u-::..:.;n:..:..:·r,:.:..:.::.:c·m-=...._ - - - - - - - , - - - - - credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refundedfor non-offending transactions. !Schedule Page: 328 Lin£! Nf?.:_1.!} __ f:_o""lu--=m:,:.=n:.:..:.c.:.m.::_--=--,-----=-------.,--_-_-""-~---~~------- ..... · --FERC Assessment Fee for 2014 and Energy Imbalance Penalty Revenu-e--.------------------------~ !SChedule Page: 328 Line f!l]:: 1.£!.. .. Column: Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. f$Cileiiuie.Paiie: 328 Line No.: 22 Colu_mnJ_J!L ___ _ Credit for Energy Imbalance Penalty Revenue and Unreserved Use P-enalty Revenue refunded for non-offending transactions. \Schedule Page: 328 Line No.: 24 calumn:--ii Terminates on January -1: -262'""oc-.--=-.::'-'-"-'-:..:.:.:.:2...C=-------------------~~hf!_q~-~-P.a_g(l: 328 Line-No.:24 Column: m '''"] Credit for Energy Imbalance Penalty Revenue ar1ci'--l.Jnreserved Use Penalty Revenue refunded for non-offending transactions. ·----.............- - - - - - - - \SCiieciuie Page--:328 Line No.: 27 Column: m Credit for Energy Imbalance PenaTty--Rev_e__n_u_e__a_n_d-,-:U:::-n-r__ e ....s_e_r_v_e_d~u-=--s-e---oPenalty Revenue refunded for non-offending transactio~n=--=--s_._____________________ i§£.1J.~~-~(~_f'age: 328 LTiieNo~:Ti Column: m _ ____________ -~ Credit for Energy Imbalance Penalty Revenue and· -credit for Unreserved Use Penalty Revenue refunded for non-offending transactions. [sciiedule Page: 328 Line No.: 32 _____f~lumn: m ... -----------credit for Energy Imbalance Penalty Revenue and credit for Unreserved Use Penalty Revenue refunded for non-offending transactions. [chedule Page:32if --Line No.: 34 Column: m --- ·----------··- ----Credit for Energy Imbalance Penalty Revenue--and credit for Unreservecf Use Penalty Revenue m- . ------ lFERC FORM N0.1 (ED.12-87) Page45D.1 Name of Respondent Thls Report is: (1) ~An Original 121 A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 FOOTNOTE DATA refunded for non-offending transactions. [Schedule Page: 328.1 Line No.: 5 Column: m · · · - - - - - FERC Assessment Fe<: for 2014 and Energy Imbalance-P:;:::-e-~-a'""'l-,-t-y----.R'e:-v-e_n._u_e_________ ~hedu/e Page: 328.1 Line No.: 9 Column: m Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. lecheduie Page: 328.1 Line No.: 11 Column: m Credit for Energy Imbalance Penaity ::::R-'-e-'-v"-e-n_u_e_a_n--,d ·unreserved Use Penalty Revenue refunded for non-offen~ing transactions:·--~-----fSchedule _ _f~ge: 328.1 Line No.: 12 Column: m Credit for Energy Imbalance Penalty Revenue and credit for Unreserved-Use Penalty Revenue refunded for non-offending transactions. ISCiiedule Page;_328. { ''Line No.: 13 "Column: m - - - - - ....... ---- -~ Credit for Energy Imbalance Penalty Revenue .-ii'nd credit for Un-reserved Use Penalty Revenue refunded for non-offending transactions. l$chedu{f! Page:-328.1 Linfi!__No.: 14 Column: m---,-----;-;Credi t for Energy Imbalance Penalty Revenue and credit ...for Unreserved Use Penalty Revenue refunded for non-offending transactions. !Schedule Pagf!: 328.1-- Line No._:_1'L column--:-m--______-_FERC Assessment Fee for 2014, Energy Imbalanc-e--=P:-e_n_a-o;lcc-t-y-=Ro-evenue and Unre-served Use Penalty Revenue refunded for non-offending transactions. ~fi!.!!I!Je 328.1 _ype Na~:-18 ColumrJ_:J_ ·- ---------~---------~ credit for Energy Imbalance Penalty Rev~e_n_u_e_._ __ WCiledule Page: }_28.1 Line No.: 19 Column:--in FERC Assessment Fee for 2014. !Schedule Pa~_:,_ 328:1· ..Line No.: 20 Column: m Credit for Energy Imbalance Penalty Revenue and Unreserved Use #enalty Revenue refunded for non-offending transactions. ~~hediiie Page: 3?.~:.1 Line No.: 21 Colum_:::n:-=-:-=-=m"---· ----~ Credit for Energy Imbalance Penalty Revenue and credit for Unreserved Use Penalty Revenue refunded for non-offending transactions. !Schedule ~~g_e:-3f2'8.1 Line}:!_f!.: 23 Column: m Credit for Energy Imbalance Penalty Revenue and credit. for Unreserve·d--Use Penalty Revenue refunded for non-offending transactio~n~s~·------/SCiledule Pag~;}_28:i . -Line No.: 24 ___ Column: m Energy Imbalance Penalty Revenue. ISchedulf}_ ~age:-328.1 Lln_f!: No~-:-iif-- ·-c-o-lu_m_n_:_m__ FERC Assessment Fee for 2014. -----------\Schedul~_f.?age': 328.1 Line No::-'iii Column: I Credit for Energy Imbalance Penalty Revenue and Unreserved for non-offending transactions. J5Chedu/e Pag_~;--~Jiit --Line No.: 28 Caii.iiiin: m Credit for Energy Imbalance--Penalty Revenue. and Unreserved for non-offending transactions.~---------'§chedul~_ Page; -328.1 Line No.: 29 Column: m Credit for Energy ImJ:)aiance Penalty Reven_u_e_a_n_d..,-;U:-:-n-rese.rved for non-offending transactions. ~C:iiedule Pag_*!_: 32ifT Line No.: 30 coiumn: 1 Credit for Energy Imbalance:-/Schedu/e PaJie: 3iif1 Line No.: 30 Column: m Credit for Energy Imbalance Penalty Revenue and credit for Unreserved ·::u:-s-e----;:P:-e-n-a'l--;-t-y--;:Revenu"J refunded for non-offending transactions. l§.c.heduTe Page: 3_28.1 Line No.: 31 Coluriiii: -:-/------=~-----credit for Energy Imbalance. '!§£hedu/e Page: 328.1 ·Line No.: 32 Column: m Credit for Energy Imbalance Penalty Revenue and credit for ·unreserved Use Penalty Revenue n Page: ··-----~ IFERC FORM NO. 1 (ED. 12-87) Page 450.2 This Report is: (1) ~An Original (2} A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) 2015/04 I I FOOTNOTE DATA refunded for non-offending transactions. Line No.: 33 __Coc;..:lu::.:m~n.'-'·' ' - - - - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ __ Credit for Energy Imbalance Penalty Revenue. \Schedule Page: 328.1 \Schedule Page: 328.1 ----------:=-;=---;-.----:;::--:-::-:~-:- Line No.: if- Column: m Unreserved Use J?"enal ty Revenue refunded for non-offending transact"ions. __________________ -------. \Schedule Pag_e: 328.1 Line No.?34 Column: m ---------=-----::-:----==--FERC Assessment Fee for 2014 and Energy Imbalance Penalty Revenue_._____________________, l$chedule fiage;-328.2 Line No.: 1 -~~umn: m ----Credit for Energy Imbalance Penal t-y--::R:-e_v_e_n_u_e__ a_n~d,.--c_r_e--;dlt"-'for Unreserved Use Penalty Revenue refunded for non-offending transactions. -------··-··---~ \Schedule Page: 328.2_ Line No.: 3"-··c-=-o...,l:-u-m_n_:_m____-_- - - - - Credit for Energy Imbalance Penalty Revenue ··and credit for Unrese-rved Use Penalty Revenue refunded for non-offending transactio~n=s~-~--------------- ISciiedule Page: 328.2 Line No~_:._-4______=-c=-o=lu:;:m:.:.:--n.:.:-·:-..:.m:.:..,-...,---- ISch-ec:iiiie Page: 328.2 Line No_:;_?_ ___ Colum"ii: m -I unreserved Use Penalty Revenue refunded for non-off'emdin<;L transactions-:---·---··-----·-·· · ..... ----- --·--·----- ___··--'] FERC Assessment Fee for 2014 and Energy Irnbalance"'}'€malty Revenue. \Schedule P_~g_~ ~?_!}~?- LineNo.:·6 · Column: m ... ____ -----;----:,....-;---:::---;;:: Credit for Energy Imbalance Penalty Revenue and credit for Urtreserved Use Penalty Revenue refunded for non-offending transactions. ~chedule Page":--328.2 =:J Line No.: 8 ___ t:;o_!'!m::..:.:.:.n=::::..:.:mc::...···_---·-·_··-----,--- Credit for Energy Imbalance Penalty Revenue and cred.:Ct. for Unreserved Use Penalty Re-venue refunded for non-offending transactions. ~hed_LI.!~-~!!ge: 328.2____£Tiie-ivo.: 10 Colf.!:r_rJ_IJ.: m ·· ·-- ·- FERC Assessment Fee for 2014, Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. - - - - - - - - - - - · .......... ··--· [Si::iledule Page: 328.2 ~lEf!.~o..~.: 11 [§!?_hedule Page:32"8.2 Line No.: 1.~---- pol:..::u::.:.;m:.::..:nc:..:::....:m.::..:__ _ _ __ coiumn: c This footnote applies to all occurences of "Ci ty···~Of New Smyrna 328.1-328.15. BeaCh'• ori pages ----- I FERC Assessment Fee for 2014. ~chedule-Pa[;ie: 328.2 Line No~-~·..1..~---- Column: m . ""] Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. I§£Jyecf_tJ}e_fag_e: i2ii:2-- Line No.: 18 Column: m Credit for Energy Imbalance PenaTt·y--=R,...e_v_e_n_u_e__a_n--;d--:-:U,-n_r_e_s_eived Use Penalty Revenue___refunded for non-offending transactions. I§Ciie"duiePage: 328.2 Line_fl!_o_~.= 19 -----------------···. Column: d ·•····· Terminates on January 1,2032. [Schedule Page: 32fl.:.2 Line .No.:-2.-o--c---o_/_u_m_n_:_m__ FERC Assessment Fee for 2014, Energy Imbal_a_n_c_e---=P=--e-n-a""l-:-t-y---=R-e-v-enue and Unreserved Use Penalty Revenue refunded for non-offending transactions. f$cheduie7~age: 328.2 Line No.: 21 -Coiumn: m Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. [Schedule Page: 328.2 Line No.: 2:-::::2=-:.-=c:-o-=-lu_m_n_:_m__ Credit for Energy Imbalance Penalty Rev-en_u_e__a_n_d-,--U""n __ r_e_s_e_r_v_e--.d....Use Penalty Revenue refunded" for non-offending transactions. [sCiieduie Page: 328.2 Line No.: 23 Column: m Credit for Energy .f"ffibaTa"i!ce Penalty Revenu·e· and·-·unreserved Use·--Penal ty Revenue refunded for non-offending trans_a_c_t_i_o_n_s_.___________ !Schedule Pag~:___32B.2 ---Line-No.: 26 Colu_P.n: m ........... __ =:] Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. [Schedule Page: 328.2 Line No.: 29 --=c=-o-::-lu_m_n-.-.m - - - - - Credit for Energy ·yffib-alance Penalty Revenue---a-n'd--.::u=--n_r_e_s_e_r_v_e_d..,.--;T}se Penalty Revenue refunded IFERC FORM NO. 1 (ED. 12-87) Page 450.3 Name of Respondent This Report is: (1) ~An Original (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/Q4 FOOTNOTE DATA for non-offending transactions. !Schedi!.ll!_.Page: 328.2 Line No.: 31 Columii:m Energy adjustment for January, 2015. [Cbeiiute Page: 328.2 Line No.: 32 Column: m Credit for Energy Imbalance Penalty Revenu-e. [Schedule Page: 328.2 Line No.: 33 Column: m Credit for Energy Imbalance Penalty Rev-enue:--_------------'---------··--------------·-..---l§.ched':!J.~ f!age: 328.2 _ Line No.: 34 ---- Column:·m-~------..-_ . -......-.. ----·- - - - - - - - - ........__ ,______ ..............._ Credit for Energy Imbalance Penalty revenue. ~ctiedule Page: 328.3 Line No.: 3 Column: m Dynamic Schedule charges. ----[Schedule Page: 328.3 Line No.: 10 Column: m Dynamic Schedule charges. !Schedule P~~-~~8~____4!!!£!}!~-~-~__14 Column: k ·-------- -] Generation Dynamic Transfer Service charge pursuant to the agreement for specified services and Treasure Coast Energy Center Parallel Operation between Florida Power & Light Company and Florida Municipal Power Agency. !Schedule Page: 328.3 Line No.: 15 ... -~/Uf!!_!l;_m. --- ----·___________ ---------------~ FERC Assessment Fee for 2014, Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. Also, Generation Dynamic Transfer Service charge pursuant to the agreement for specified services and Treasure Coast Energy Center Parallel Operation between Flor~da Power & Light Company and Florida Municipal Power Agency. ~EIJ..~t!...l!le Page: 328.3 Line-No~: 1icoiiiliin: m Interconnection Agreement between Florida Power & Light Company and Georgia Pacific Corporation. 8 e-c-,-t'i_o_n---:A:-g_r_e-em-enf Company and Georgia Pacific Corporation. [Sctieciiiie-Page:-328:3.. Line No.: 19 Column: e Interconnection Agreement between Florida Power & Light Company and Georgia Pac"iiic____ · ___..1 Corporation. ~~!!*'!~'!.!..~-Page: 328.3 Line No.: 19 Column: m Generation Dynamic Transfer Service charge pursuant to the agreement for specified services and Treasure Coast Energy Center Parallel Operation between Florida Power & Light Company and Florida Municipal -~c:l'::'el':"_~g~n~_~Y,____·- - - - - - - - - · l$chedulf!_ Pif!ge: ~.?_8.3 ___ !-:-j!!_e No.: 22 Column: k Regulation Service Charge for Interconnection Agreeme:iit -between Florida Power & Light Company and Georgia Pacific Corporation. ·-------·-· ..... [C/iedu/e Page: 328.3 Line No.: 25 Column: m----,---=--------.~ 1_ Credit for Energy Imbalance Pen-aif.Y RevEmue and Unreserved u·se--i?e'iialty"R.evenue refunded for non-offending transactions. !Schedule Pag_~l?~_l___ Line No.: 26 ......... __ - ~--------------------'I Generation Dynamic Transfer Service Charge. ~chedu/e Page: 32ii-:3 - Line No.: 26 Column: m FERC Assessment Fee for 2~0_1~4~--~~--------ISchedu/e Pajj""ii:32ii-:3··--Line No.: 27 Column: m ~~~~i~~g~:e~~~~e---~::~i--·=""/~o_r_---::-~:--~--:-~-~-:-~-~-~-·~- · between·~~=:~~: -~=e~- -~--L-i-g~~-~ Columii:ic -------· . . . ...... -_=:=J ~~~~:;~~e ;;;:.-d;::.3 ch~~:=~~.: 30 m ____..,...--;:::------ ----------··-- Colum_--:n=-·-· ··---·-------·-----~ Credit for Energy Imbalance Penalty Revenue and Unreserved. Use Benalty Revenue refunded for non-offending transactions. fSC'heiiuTei>age:-32if3 --=L::.::i::.::n=e=-=N=-=o:...:.:..:::'='3~1=-:..-=c-oJ-:-u-m_n_:_m_ _ __ Unreserved Use Penalty Revenue refunded ___for ·n--o-n-_~-?-:_f""_~=-e-n-d"""i-n~g---;:t~r=-=accn:-::-s·-a-ctions-.- ---· fSchedufePage?-328.3 Line No.: 33 Column: m I FERC Assessment Fee for 2014. --··---------------, [Schedule Page: 328.4 411J_~--!'t~::_}___ Column: d Page 450.4 JFERC FORM N0.1 (ED. 12-87) , .. .----- ...... _ , _ . . . _ _ _ _ _ _ _ _ _ _ __ j This Report is: {1) ~An Original I(2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 FOOTNOTE DATA Terminates January 1, 2040. · ----·-·-l ~chedule Page: 328.4 Lin~ No.: 3 Column: m ··----------···-----------·--------------------__1 Radial Line charges for the fourth quarter. ....______........- - - - - - - - - - - - - - - - - - - - - , !schedule Page:-328.4-----rineNo.: 4 Column: m · credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. -···----..- - - - - · - - - - - - - - - - - - - - - - - , [sch__~dule Pag_e: 328.4 Line No.: 5 ___::C..::o.;:lu:.:m:.:n:.:..·:..:·m:.:.:__ _ _--.-----,-..,....,-----;:----;::;-----:-::;-=-:-:--=~-,-;:~~=-=-=-:-:--=--' Credit for Energy Imbalance Penalty revenue and credit for Unreserved Use Penalty Revenue refunded for non-offending transactions. [Schedule Page: 328.4 Line No.: 6 Column: m ;..:R:::a:.:d::i:.:a::.:l:::..,..:L=:~:::·n:::e=--=c~h:::a:::r:..;gLe::..:s=-=:-.-=------=--=----=,----=----:--------------- ........- ................ ~~!Jec(y!~_f_(!g(!_:__ ~?.l!:~.--- . L.:!!J.!!....~..E..:/.!.....__ f;gi~!J!n:..!!!..........._________,,----- ----,~--=--~--,=---------;=--,---;--_j Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. t=:IS-=c:.:.fi.::.:id= ...u=l;=-e..:..P..:;:.asz!i.::.:e.'-':3:o:-:.2::.:··a:..::..:4-=---.----.......:-i=_ . .._;..:.;;n-;=e--=.N-o..::..::-:""'-8=--,····;-·-...-:-c=-=o'-'-I=Liin""' .......::..:,_:_:-'--m_ ..._--_·- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 .... _ .................. Transmission Service Radial Line charges. l$chedule Page: 328.4 Line No.: 9 Column: m ________________. __ .. ________..... _----,---;::;---~~--_-...._....._ ....._.___. _-;::_,-___ . . . _--;:;. ..._.. --_--........ . ,;-; ...._... FERC Assessment Fee for 2014, Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending 1"-.transactions. .........................................................._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _, ~ch_f!_dule Page: 328.4 Line No.: 10 Column: I Generator Imbalance charges. [SChedule Page: 328.4 Line No.: 10 Column: m Credit for Energy Imbalance Penalty Revenue and Unreserved Use ..Penalty Revenue refunded for non-offending transactions. ~£!J*!rJY!f!..f.~9.f!.;}..?lJ..:"!-____ !-ine _No.~:--'!_! --~()!E.!!!_fJ:_J____ --_-_. . ..._-_--_-_---_--_--_. . _ ....._. .-_----_-~----------~----------~------------~---_-_-_--=:1 Generator Dynamic Transfer Service charge. rsc-tiediiiePage":-321i:4 Line No.: 11 Colum=n=:=-m"'--=-:..__ _ _ _ _ _ _ _ _ _.. _-_.... _-__-_.._-__-__ -___ --~----, Credit for FERC Assessment Fee for 2014. !SChedule Page: 328.4 Line No.: 22 Column: m Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalt~Revenue refunded for non-offending transactions. fSchediiie'f.iiijjii:328:4 .. Diiei~o::·28 Column: m Credit for Energy Imbalance Penalty Revenue and unreserved Use Pen-aTty. for non-offending transactions. !Schedule Page: 328.4 Line No.: 34 Column: m Credit for Energy Imbalance Penalty Revenue arid creci:Lt ·-for Unreserved Use Penalty Revenue refunded for non-offending transactions. f§(:iieCiiiie--Page: 328.5 Line No.: 18 Column: m --·-] Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. r=IS-c~h-e--=d,....u/-=-e--=P=-a-g_e_:-=3-=-2-c:-8-::.5'---,L--:in-e---:-N""'o-.:-2,-1=---eo-l-um_n_:_m ______________. ___ - - - - - - - - - - - - - - - - - - - - , __j .. ] -_====---=--_-_-_ ·:Revenue-re:Eunded.··---- ------------------~ FERC Assessment Fee for 2014, Energy Irnbai'ance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. rsctiecii:iie-Page: 328.5 Line No.: 30 Column: 1 Generator Dynamic Transfer charges. !Schedule Page: 328.5 Line No!!.l1___Column: !!! . _ Dynamic Schedule charges. l§chedu/e Page: 328.5 _L:fne !!_~~; 32 __ Colyp1J: !._ ____ - - : : ; - - - ; - - - - - : ; - - - c ; - - - - - - - - - - - - - - - - - - - - - - - - ' Charge for Generator Imbalance and Dynamic Schedule. !Schedule Page: 32B.5 ____i..."iii"'id·io~:-32____ Credit for Energy Imbalance Penalty Revenue and credit for Unreserved--Us-e Penalty Revenue refunded for non-offending transactions. !Schedule Page: 328.5 Line No.: 33 Column: I Dynamic Schedule charges. l§~fJ*!5!E_!~-t:~g~~: ~?11..~5.. . __ L.:ifJ_f!._f-.!~:.:__~ Columnc:..:..::..:k'----,---=--7"··-_-----=··-_··~-··_····_--_---_--_----_--·_----_--=_-=_-=_-=_-=_-=_-=_-=_-=_-=_-=_-=_-=_-=.._-___-___ -___-_-__-....-....-... _-_----, Charge for Generator Imbalance and Dynamic Schedule. columii:·;n-----------------------........, IFERC FORM NO. 1 (ED. 12-87) Page 450.5 Name of Respondent This Report is: ( 1) ~An Original (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA ~chedu/e Page:· 328.6 Line No.: 1 Column: k Charge for Generator Imbalance and -·Dynamic Schedule. ~£!.!.!du/e Page: 328.6 Line No.: 2 . ~1umn: a -~----___:c-'------This footnote applies to all occurences of "Orlando Utillf·i..--e-s---;:Co:-o-min.l.---,.,s-s-~.,--.o-n-:::,.-o-n pages 328.6-328.15. St. Lucie Unit #2 is jointly owned by Florida Power & Light Company (85.10449%), Florida Municipal Power Agency (8.806%), and Orlando Utilities Commission (6.08951%). i§chedule Page;_~?8.6 . Line No.: 2 Column: m Unreserved Use Penalty Revenue. i§chedule Pa9.e: 328.6 Line~No.-:-4-::----c-=-o....,l,..-um_n_:_m_____ _ - - - - - - - - - - - · - - - · · · · · ·····--·-··Distribution Wheeling charges. -----------~hedule Page: 328.6 Line No.: 1lJ.... Column: m ·--·--· ----·"] Credit for Energy Imbalance Penalty Revenue and Unres-erv-ed Use Penalty Revenue refunded for non-offending transactions. l§chedu/e Page: 328.6 . . Line No.: {j"···-,c:::--o--:1-um_n_:_m_ _ _ __ Distribution WheeB.:ng charges. ----------· J f$_chedu/e Page: 328.tf·--Line No.: 17 Column: m FERC-A.s:iie-ssment Fee for 2014 and Energy--I~mb--;--a~l-a_n_c_e--,P=-e-n-a"'"l.,..t-y-Revemile. ~ciiedliie f:iage: 328.6 une No.: 19 cotumn:--m ------- unreserved Use Penalty Revei1.ue refunded for non-cif:EE:mding ..._t_r __ ans<~tctions·:-------------' [Schedule Page: 328.6 Ll.n..~_f!q:.;. 23 ~~hedu/e Paii£: 328.6 Line No.: 2-4.. ....... Column: m Column: m -- Credit for Energy Imbalance Penalty Revenue and ·unr_e_s_e_r_v_e_d~u=-s-e---:±1!>-e-n-a""lty Revenue refunded for non-offending transactions. q ·---~ Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty··-Revenue refunded for non-offending transactions. [Schedule Pag~~~~l!.~-~- Line No.: 26 -c=--o--=ru_m_n_:m--..... -.- - Credit for Energy Imbalance Penalty Revenue a-n-d,.--c_r_e_d7 J.7• t.,---=f-o-r--=u=-n-re"::ierved use Penalty Revenue refunded for non-offending transactions. r§ch-ec:iiiFe-·Page: 328.6 L..i.l!e..N.r:?·: 3i _____coiiim_n_:_m________________ --··· Credit for Energy Imbalance Penalty Revenue and. Unreserved Use Penalty Revenue refunded for non-offending transactions. !schedule ~~gf!.: 328.7 ··cine No.-.:--=1:---=eo,..-,--Ju_m_n_:_m_ __ FERC Assessment Fee for 2014. ~hedule Page: 328.7 ----~ ----------------- Line No_~_:__11___ Column: m __ -,--;-:----:::---=---- Credit for Energy Imbalance Penalty Revenue and credit for UnreservecfTJse Penalty Revenue refunded for non-offending transactions. Also included is an adjustment for an overbilling made in December, 2014 in the amount of $10,512. 'M~ul~_!!_l!_ge: 32if'i-- Line No.: 30 Column: m ····· .. =--------- ··· · - -·-----~ Credit for Energy Imbalance PenafEy- Revenue and Unreserved ··use Penalty Revenue refunded for non-offending transaction_s_._________________ ~edule Page: 32l!.:IJ. ·-· Line No::·-9 Column: m ........... _·----c----=----- FERC Assessment Fee for 2014, Energy Imbalance Penalty Revenue "iind Unreserved Use ·Penalty Revenue refunded for non-offending transactions. ~ule_f'!!.9_f!: 3iii/i ··-Line No.: 17 Column: m ·····--····---------- ... ·-·----] Credit for Energy Imbalance Penalty Revenue and Unreserved---Use Penalty Revenue refunded for non-offending transactions. rschedule Page: 3?1!.:!1. Line No.: 2=-:5=--.....,c=--o---=lu_m_n_:_m____ -~-:J Credit for Energy Imbalance Penalty Revenue and Unreserved Use .Penalty Revenue refunded for non-offending transactions. '@£.1Jf!t!':!.!e. . Page:-"328-:8 Line No.: 27 ____ c;olumn: m . . . . -···-----=----=---.,....---' Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty-Revenue refunded for non-offending transactions. !Schedule Pag_~;_ 328.8 Line N-o-.:-2::-c9,----c=-o--=J:-u-m_n_:_m_ ··· - ····----··] Credit for Energy Imbalance Penalty Revenue and Unreserved-·{Jse- P,enal ty Reven\ie ...refunded for non-offending transactions. IFERC FORM N0.1 (E0.12-87) Page 450.6 This Report is: (1) ~An Original .(2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA /§chedule Page: 328.8 Line No.: 31 Column: m ___________ ..---=--------······_---_--_--_--_-.~_-__ ......_-~----' FERC Assessment Fee for 2014 and Energy Imbalance Penalty~R~e~v~e~n~u_e~·~------------------------, [Schedule Page:·328.8 Line No.: 32 Column: m ----·-····--··. ---Dis!.:::.~!J_u_i;-ion W~ee!_~ng charges ...... -·-·---·------..·-·-------------------------------------------------, 't5~ch~e~d~u~le~P~ag;t_e~::,.:3~2~8::.:.8~~L::::in:.:..:e~N~o~.:..::3~3-:-:-:--..::C:..;:;o~lum.;;.n:..::.:.....:"m:.:..:.__________________________........................- - - . . . . . . J 7 Energy Adjustment for February, 2015. .. ---···-·---- ... ----------------· ......... '$._chedu/e Page: 328.8 Line No.: 34 Column: m ;:;_D..::i~s:..::t:.::r:.;i:.:b::.:u::;:t::-:~::.·o::_n:..:._W~h:;e:..::e:.:l:.:i::n:--'g~c=h:;.;a;:=r2 g~e:.:s:....:·~----;-----------------------------------..- . . -....................... . l$_~hedy!f!e!!9~~~J..!l.JL Line No.: 1 ____f'?.[Y!"n: m_____ _ Credit for Energy Imbalance Penalty Revenue--a.-nd-Unreserved Use Penalty Revenue refunded for non-offending transactions. ---·-·--.. -·----·---==:] \Schedule Page: 328.9 Line No.: 2 Column: m Distribution Wheeling charges. .. ________ ..................................... !Schedule Page: 328.9 Line No.: 3 Column: m ;:::.E~n:.::e::r:...:;gLJyl.........:I:..:mb::.=-a=l.:::a.:.:n:.:c:.:e:.......:P:....:e::.:n.:.:a=.:l:::..t:::..Y,L....::.:R:.:e....:v....:e:..:.n.:..:u::ce:....:....________________________ .............................. ______________________________-, ~.C:!!.~~u/e Page: 32§~f!.... _f:i~f!t!~:;_!!_ ___c;ol'!_f!!r!:. ..m Wheeling charges for fourth quarter, 20=.:1::.5~·--------------------------------------------. -~ ,. -~ <:=:[S-=c.:. :. il-=ciw:;:.cu;:.:l-=e;;.P. . ::.a::,;;g'-Oe=:-:-=3::::.2:::...8·=-=·9_ .....-:;:.-=·L~Tn...::..:e,_ ......::..:N-=-·c;"-'-.:......:·5'-;_....;:;--c'-:-o"--;"i;-:;'u"-'-m.:..:..n.:;::-::-'-.m-::-:--=-=-:-:-::-~-::--:;---;:;:-:-:::-::-::-::-=-----::-::;---;:-;-=-=---· ....................., . .______ _ Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. --·I l$.chedu/e !!.~9!:_:1..?_8.9 Line No.: 6 _t:;~!~mn;_i!__ This footnote applies to all occurrences-·ciT'"'sern.fnole Electric Cooperative" on pages 328.9-328.10. l$.chedule Page: 328.9 Line No.: 11 Column: m Transmission Service Radial Line charge and Distribution. wh."eeli~SJ~--. ... .. .. ·------·-------------·-·- ..... """I !Schedule Page: 328.9 Line No.: 12 Column: m ________ . ···- __ . Credit for Transmission re-sales to Rainbow Energy Marketing Corporation. ~~-IJ.~dule Page: 328.9 !:-_ine No . : 13 ----Column: m ----H ....... · · . - ---- -----"-----"-----------...=..~---------------------~---, Credit for Energy Imbalance Penalty Revenue and Credit for Unreserved Use Penalty Revenue refunded for non-offending transactions. r-IS_c_h-ed_u_l_e_P_a_g_e_:_3_2_8_.9__-cL--=-in_e_N_o=-.:-2,......6,-----C.,.--o,..--l,......u_m_n_:_m_____________________________ . ______.. Transmission Service Radial Line charge and Dist_:Q~lJ.~ion W.h~~_i_i_n~g,___.___________________----, i:('!~ . JII..o:_:_?_f!__ ......Q!l'-!'!'...f1_;_ m______-=-=------........,....--=-----=----o----=---------==---:-""7"""............J Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. ~-cfieilule Page: 328: 1ci' . . Urie-iio:-:4--c-ot_u_m_n_:__ m _ _ _ _ _ _ _ _ _ _ _ _ __ -_-_-_-_·____. _ ..--_·--·_·--_----~-___.J Distribution Wheeling and Radial Line charges. [Schedule Page: 328.10 Line No.: 6 __ ~CJ..!L!__mn: f!l........ FERC Assessment Fee for 2014, Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-off~!l_d,ing tran,s.3_c~?:'?l1~__:_______________________________________. . . ., ~~~llf!c!__ule f'age: 328.J() L~rl..~_f:!CJ..:£"'=7:-o---=C=-o-=1-=u:..:..m:..:..n:..:.:....:. .k=-=-~::-;=-------------------Rate adjustment from July,2014-February,2015. ~cilei:JuiePage: 3iif 1iJ .... · 1-:-3::---c-:::o-t7u:..:..m:..:..n::..::'--'m----__:____________________ -=-=-=---------.-.. ---_ ..____......J_l Distribution Wheeling and Radial Line charges for fourth q~~!~~~.?:..:..O:..:..l:..:..5~·----------------------, !Schedule Page: 328.10 Line No.: 16 Column: m ______ ... _. . . ----.. ---~=----=:----=----=---------=---=--=-___) Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions.~~---'@ih~r:Jule Page: 328.10 _!:-jne No.: 20- Column: m ----- ------ ...... _ Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penafty--Revenue-re:funded for non-offending transactions. [$.C?Il~c!..'!!f!.. ..E'!I9..e: :J..?~~ .!J. H _ .... _____ .... __ Line-No:.-. r::[c-~-=-!!_-~d--:: __u-_J=-.~-=-B=-_;:t-_g_-_~-~--:I..-_?-=-~.~..1_'-:-0__-_--:-L-=-in-_~-N-:-:_-~-.~-,..--?,-"!-. . -__-=_9=...c?-=!¥-_m-_"'-.~-;_-f!l___-.. __-____-=_-=_-:-=..-=..-=_-,~-~--=""'--_-_·---;-··,.....··--_·-_--=_-=_-=_-=_-=_~-=-~-=--=-~~-=--=-~-=_-=_-=_--::.:-=_-=_-=_-=_-=_~......, Credit for Energy Imbalance Penalty Revenue and credit for Unreserved Ose Penalty Revenue for non-offending transactions. rrefunded ·-·-·----·--·-.................. - . . --. . . . . . . . --------·-· ............................... ---....................... :Schedule Page: 328.10 Line No.: 28 Column: m Credit for Transmission re-sales to Rainbow Energy Marketing corporatl"cin- from Tampa --·-------~ IFERC FORM NO. 1 (ED. 12-87) Page450.7 Name of Respondent This Report is: (1) 2S An Original (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 FOOTNOTE DATA -.. . . _, _____:J Electric Company. '$chedule Page: 3_?.~·.!..1 Line No.: 4 Column: I Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. [Cfiedule Page: 328.11 Une No.: 16 -Colurrm: m FERC Assessment Fee for 2014, Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. ~«t!!!e Page: 3lti11 Line No.: 31 ColumfJ_:._f!!_ ··········· Credit for Energy Imbalance Penalty Reven_u_e_a_n_d.,---;U:;-n-r_e_s_e_r_v_e_d ... Yfse- Penalty Revenue refunded for non-offending transactions. l§chedu/e e!!.9~E-~28.12 Line No.: 13 -c-=-o_l_u_m_n_:_m_____.. . . --.~---o-,...,---_,-:_-_-=-_-~----------···· Credit for Energy Imbalance Penalty Revenue and credit for Unreserved Use Penalty Revenue refunded for non-offending transactions. ~-hedule.Page:328.13 Line No.: 11 ____c;_~tumn: m·--credi t for Energy Imbalance Penalty Revenue and Unreserve-d use Penalty Revenue refunded______.J for non-offending transactions. - - - - - - - - - - - - ............... --, l§.cheduffl f1.~9~:~ 328. 13·----[.iiie_N_o-.:--,1~6--=c,.-o-=-ru_m_n-.-.m - - Billing adjustment for July,2015. -------'§_chedf!f.(!J__f:_~g_~; 3i8.14-·-·une No.: 6 Co/urn_(!_~~-!!'.---,:------,=----=--,---.,.-FERC Assessment Fee for 2014, Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. l$chedule Pag_f!!_~}?_IJ_,.J4 LineNo::34--- Column: m .. ----·---=----~,----;c:,--credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. ~11_e.dule Page:·32B.15 Line No.: 3 ___ c;C!J.l!.m_n_:_l _ _ _ _ __ Generator Imbalance charges. - - - - - - - - .................... . !Schedule Page: 3?8.1_!? ___ _Line ti0::4- ····column: 1 Generator Dynamic Transfer charges. '$chedule Page: 3_?~:.~-~ __ Line fi- --~Co-l-=-u_m_n_:_m--..-.. Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. ---------- ··f§CiieCiuie Page: 328.15 . !:!(!f!!._~f!.~.:J. m Credit for Energy Imbalance Penalty Revenue and Unreserved Use Penalty Revenue refunded for non-offending transactions. i$chedule P.~gf!.;.~28.15 .. i.ine N-o-.:-8=---c-=-o-1:-u-m_n_:_J_n ....----. Credit for Energy Imbalance Penalty Revenue and Unreserved Use ... Penalty Revenue refunded for non-offending transactions. - - - - - - - - - - - ........___________ _ ~hedule Page: 328.1.!?.. ... Line N0.: .9.. ··Column: m Journal Voucher adjustment due to timing of _:fit"o. ~~hly entry. '§.chedule.ff!.g~;328.1S-.......Line No.: 10 Co/Uf1l!!.=L. -=~---------·---·---·· . ·Adjustment is due to timing of journal entry posted in January,_?0~_5_._ _ _ _ _ _ _ _ _ _ _--, l§cheduf'!!__f_ag_~_:_328.15 ···Line No.: 11 Column: I :;:--7'_--""'" ...._....._.. - - = . - - - - . . ....... -. _] Journal Voucher adjustment for Generafar· Imbalance Charges not included on initial Journal Voucher entry. ~hedule Page: 328.15. ... _b!_ne No.: 11-- .... Column: m June 2014 Journal Voucher adjustment. _________ -----~ --=-----,---;-:-- No.: --column: ··~ --==----;--;;:;------;- \FERC FORM NO.1 (ED.12-87) Page 450.8 Date of Report {Mo, Da, Yr) Florida Power & Light Company I I End of 2015/Q4 1. Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. 2. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. 3. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS- Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP- Short-Term Firm Point-to- Point Transmission Reservations, NF -Non-Firm Transmission Service, and OS- Other Transmission Service. See General Instructions for definitions of statistical classifications. 4. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. 5. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 6. Enter "TOTAL" in column (a) as the last line. 7. Footnote entries and provide explanations following all required data. Name of Company or Public Statistical Authority (Footnote Affiliations} Classification (a) (b) TOTAL FERC FORM NO. 1/3-Q (REV. 02-04) 10,978,481 Page 332 47,51 47,513,067 Name of Florida Power & Light Company 1. Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. 2. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. 3. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS- Firm Network Transmission Service for Self, LFP- Long-Term Firm Point-to-Point Transmission Reservations. OLF- Other Long-Tenn Firm Transmission Service, SFP- Short-Term Firm Point-to- Point Transmission Reservations, NF- Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. 4. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. 5. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all component~ of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. 6. Enter "TOTAL" in column (a) as the last line. 7. Footnote entries and provide explanations following all required data. Name of Company or Public Statistical (Footnote Affiliations) Classification (a) TOTAL FERC FORM NO. 1/3-Q (REV. 02-ll4) (b) 10,978,461 Page 332.1 47,513,067 This Report is: (1) ~An Original I(2) A Resubmission Name of Respondent Florida Power & Ught Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 FOOTNOTE DATA rSciled_u_l_e_P_a_g_e_:3-3-2---~-JIJ-.e-f\lo-o-.:-3-·-c-o-/u_m_n_:a--------~------~----_·_---_·--_·-_···-=_-=_-=_-=_-=_-=_-=_-=_-=_-=_-=_-=_-=_-=_-=_-=_-=-=:J Complete Name: Jacksonville Electric Authority ,5ched~le Pa_g_~__332 LineNo.: 4 Co~f!.'IJ_ c;;.n.'-·a'i'----==----------------····---·---------------~ Complete Name: Southern Company Services, Inc ···-·-··--·---·--------------[Schedule Pag_~;_~32 Line No.: if· Colu'!'_!].L!!. __________ --~ Complete Name: Southern Company Services,_I_n_c_ _ _ _ _ _ _ _ _ _ _ _ __ lschedule Page:-332 -~if!e No.: 7 cotuinri:·;;-... Complete Name: Orlando Utilities Commission _______________________ \~chedule Page: 3J2 f.:!E.f!..!'IO:.~ ..B Column:·-a··-···-_ ________ ____j Complete Name: Seminole Electric Cooperative l$ched_E.l~ p_~g~: 332.1 Line-fio:: 3 r;;g!~~ n:. :;·:. .:a:=:--,.-,------.-.,-----··_····-_---_····_-_--------·-··---···-······-·· ________----~_j 7 · ~omplete Name: Jackson"!.~!J.-e Electric Authority ..... ----------------------- -=:J [Sched~[~l!g_e_:_332.1 Line No.: 4 G_Q!'!'E·..:.:n:.:;-:-=a----=:-------------- complete Name: Southern Company Servi_c_e_s-',_I_n_c_ _ _ _ _ _ _ _ _ _ _ __ iSchediiie-Pagi:332_:1 .... Line No.: 8 Coluiiln: a . ···--··------·---------------- _ --~ Complete Name: Orlando Utilities Commission l§c;_IJ~dule Page: 33if Line No.;__!!_ ..... Column: a ·-- --·- -- ----- ___ _____ _ -~ Complete Name: Cargill Power Markets, LLC ~chedule Page..:_!J.~_?: 1 Line No.: {j Tennessee Valley Authority IFERC FORM N0.1 (ED. 12-87) Column: a Page450.1 :I BLANK PAGE (Next Page is 335) Name of Respondent Florida Power & Light Company I Date of ReP.ort This 7iJ'ort Is: (Mo, Da, Yr) (1) An Original I I (2) A Resubmission MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC) I 0 (a 2015/Q4 2,517,367 1 Industry Association Dues 2 End of Amount (b) Descrl~tion Line No. I Year/Period of Report Nuclear Power Research Expenses 3 Other Experimental and General Research Expenses 4 Pub & Dis! Info to Stkhldrs ... expn servicing outstanding Securities 5 Oth Expn >-5,000 show purpose, recipient, amount. Group if< $5,000 6,982,075 6 Membership Fees/Dues 10,510 7 Agency Fees -Third Party 8 2,900,072 Directors' Fees and Expenses 484,321 9 Environmental Expenses 10 PSL Joint Ownership -183,037 Payroll Related Items 59,909 11 5,000 12 Political & Charitable Contributions 1,751,913 13 Acquisition Transaction Costs (Retail Only) 14 Other Mise write-offs (Wholesale) 94,000 15 Other General Mise Expenses {Loc 1 0) -1 ,592 149 16 Other Expenses< $5,000 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 TOTAL FERC FORM NO. 1 (ED. 12-94) 14,620,687 Page 335 Name of Respondent Florida Power & Light Company This wort Is: (1) An Original (2) FJA Resubmission Date of Report Year/Period of Report (Mo. Da, Yr} 2015/04 End of I I DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Account 403, 404, 405) (Except amortization of aquisitlon adjustments) 1. Report in section A for the year the amounts for : (b) Depreciation Expense (Account 403; (~ Depreciation Expense for Asset Retirement Costs (Account 403.1; (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405). 2. Report in Section 8 the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. 3. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification Listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. 4. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related. Line No. Functional Classification (a) 1 Intangible Plant A. Summary of Depreciation and Amortization Charges Amortizaticm of Depreciation Expense for Asset Limited "farm D~eciation pense Retirement Costs Electric Plant (Account 403) (Account 403.1) (Account 404) (b) (c) (d) 2,524,374 73,842,189 Amortization of Other Electric Plant (Ace 405) (e) Total (f) 76,366,563 2 Steam Production Plant 103,128,926 1,459,593 1,198,805 105,787,324 3 Nuclear Production Plant 156,503,636 1,636,939 8,619,672 166,760,247 351,573,895 197,797 1,959,600 353,731 ,292 4 Hydraulic Production Plant-Conventional 5 Hydraulic Production Plant-Pumped Storage 6 Other Production Plant 7 Transmission Plant 115,166,176 4,230 115,170,406 8 Distribution Plant 431,679,355 41,730 431,721,085 9 Regional Transmission and Market Operation 10 General Plant 9,321,221 62,451,875 71,773,096 148,072,141 1,321,310,013 11 Common Plant-Electric 12TOTAL 3,340,289 1,169,897,583 B. Basis for Amortization Charges FERC FORM N0.1 (REV. 12-03) Page 336 Name of p~b: of Report T~is ~~~Fis: Original Ill Florida Power & Light Company (2) , '"'"' -""u..J of Report Da, Yr) End of 2015/04 A Resubmission OEPRECIAllON AND AMUK riZATION OF ELECTRIC PLANT (Continued) Une Account No. No. C. Factors Used in Estimating Depreciation Charges Net t:sumatea Salvage Avg. Service fal (lnFf~.1~~ase {Pe[g~nt) 7gr 12 Icutler 13 IManatee 686,11€ 14 IMartin 956,09C 15 !Martin Pipeline 37 16 IPt. Evergl 17 !Scherer Coal Cars 33,149 1,758 18 IScherer 19 St. Johns River Power 39B,326 20 Park 21 St. Johns River Power 22 jPark Coal Cars 23 !Turkey Point 52 142,054 24 :316.3 -25 1316.5 26 316.7 2i ,317 28 Subtotal ·Steam 3,314,450 28 30 'st. I 31 st. ~- "'" 4,039,61€ Lucie · Uprates I' urKey Point I 33 Turkey 3,71l,82C •Uprates 34 I~?"~ 35 ;325.5 ' 36 i325.7 37 Subtotal Nuclear 7,816,945 38 1~ nQ~n+.., Solar 4n ll"'onQ Canaveral . 146,541 881 '101 41 1Ft. Myers GT's 85,48E 42 IFt. Myers Unit 3 99,65C 43 !Ft. Myers CC 44 45 ""'"'""'"'"" GT's '" 'rl"'rrl"l"' 4R iManatf"" Unit 3 696,47( 1,081 619,724 504,007 47 Martin Unit 8 539,527 48 Martin CC 588,262 49 !Martin 419,71~ 50 Pl. Everglades GT's FERC FORM NO. 1 (REV. 12-03) 61,654 Page 337 O:g(':~s (Pe[~int) Mortality Trf ;::~~~g 7~ I Name of (1) This Florida Power & Light company ~~~fi~~iginalI Date of Report (Mo, Da, Yr) IIII~~IUII (2) Year/Period of Report End of I I 2015104 Ut.PRECIATION AND AMORTIZATION OF ELECTRIC PlANT tuonu11u..u1 C. Factors Used in Estimating Depreciation Charges [Line No. L:_":"f''""'""'" Account No. (In Th·t~f~ds) .lil) Ner -~•n••w•~~ Avg. Service ~~} (~:z'-~ 42 364 1,479,602 43 1365 1,785,647 44 !366.6 1,551,464 45 :366.7 79,082 46 367.5 8,833 47 ·367.6 1,770,190 48 367.7 49 367.9 482,065 ::";_:·;;,._.,. 50 368 FERC FORM NO. 1 (REV. 12-03) .·,,·.:·:·~""'"'' 0';;·, ;e:•. ,.•,•t;:'c~ 2,141,961 Page 337.1 MOrtalll:')l D5ir! ~rca ~ver~g~ """''~!ff""~ Name Florida Power & Light Company C. Factors Used in Estimating Depreciation Charges Account No. FERC FORM NO.1 (REV. 12-03) Page 337.2 illjg~~~~~~~JUII Name of , w~"v"~""' Florida Power & Light Company Oat~ g~~~~ort Year/Period of Report ~Mo, End of I I 2015/04 DEPRECIA"1 iON}V;IDAMORTIZATIOI'II OF ELECTRIC PLANT (Continued) C. Factors Used in Estimating Depreciation Charges jline No. Account No. .(a} 12 [398 13 l~uhtnt .. l ·General Pit 14 15 [Total · T&D and GP 16 17 390.1 (Leasehu•uS) 18 1 19 [END PLANT BALANCE 20 ~ Net t::.Stlmatea (~:[~~~) Avg.~f ·. 1,101 ,22E -: 1a rum ~;n~ 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 FERC FORM NO. 1 (REV. 12-03} Page 337.3 ~~s wer~nl) Mortality JW~r~~~ rfie "C'~~f"'~ This Report is: (1) ~An Original (2) A Resubmission Name of Respondent I Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) II 2015104 FOOTNOTE DATA ISchedule Page: 336 Line No.: 24 _ColumtJ~:~b _ _ _ _ __ 3 Year Amortizable Property - - - - - - - - - - - · - ··--------, f§Ciiedule Page: 336 Lin~_No.: 25 Column: b 5 Year Amortizable Property~~~--~~------­ ~dule Page: 336 Llne No:·:-"26 Column: b 7 Year Amortizable Property !,schedule Page: 336 ---i.~in=-e-=.,N<=co=-=.=-:~27=-_____-_c=-o-l=-u-m-n;;: b::______,-o-_ __ 7 Asset Retirement Costs for Stearn Production !Schedule Page: 336-- Line No.; 34 Column: 6·---------------------=------3 Year Amortizable Property [Ciiidliii Page: 336 Lin_*!_ No.: 35 Column: b 5 Ye9-.E.. Arnorti zable Proper_!y__ ---:::--::------:----ISCiJEidu/e Page: 336 Line_ No.: 36 Column: b 7 Year Amortizable Pro~e~p~r~t~y--------:---~· !Schedule Pi}g~:-~~.1 -Line No.: 18 __c:;_~~Y'!'.!l=:'--'b'-···_···· _ _ _ __ 3 Year Amortizable Property ·-·····----] l~fl~~!!ule Page;· 336.1 Line No.: 19 Column: b 5 Year Amortizable Property -~ 1@£1J.edule Page: 336.1 Line No.: 20 Column: b 7 Year amortizable Pro_,e_ii:rty @chedule Page: 3~f>.:.1..... Line No~.:'--=2:-:1---=c:-o--:-/u_m_fl____:·....,_-=b~-=------· Asset Retirement Costs for Other Production !Schedule Pag~~!J.~-~.1 i]ne No.: 36 .92.[LI:!l!..''F--=b=-=~-----,---­ Asset Retirement Costs for Transmission Plant l§chedule Page":"336.1 Line No.: 41 Coii.iirm: b 5-Year Amortizable Prop_~~~~y·--=---~--:--------,-­ iSCiiedule Page: 336.! Line No.: 49 Column: b Account represents Cab~~~njection inves-t:-rn-e-_n-t,... __arn __o_r_t,.-·1''z-e·cr over 10 years [Schedule Page: 3~.€!~?__ Line No.: 13 Column: =b_ _ _ _ __ Formerly known as 3~69~.7~---'{;chedyfe__fage: 33if2' Line No.: 18 Column: b 5 Year Amortizable Proerty ~q'!.!~ _ fage": 336.2 Line No.: 20 Column: b 5 Year Amortizable Property_ _ _ _ _ _ __ Page: 336.2 __i:_~l}_e 22 Column:-~-Asset Retirement Costs for Distribuion Pl~a-n-t~--------rteheciiife.Page: 336.2 .. Line-No:.: 25 Column: b _ _ _ _ _ __ FPL Only Excludes Lea_~s_e_h_o_l_d~s~--,-,-,---------] !Schedu/e Pag(;!: 336.2 --Tine No.: 26 Colum:.:.:.:..:n:.::..:-=b_ _ _ __ 7 Year Amortizable Property '§cl]_f!_dule_ Page:"336.2 Line No.: 27 Column: b 5 Year Amortizable prope-rty ~cf!_f!_dule Page:-336.2 Line No.: 28 Column: b 7 Year Amortizable Pror:)~~t~·y'----------[Schedule Page: 336_:~-- _Line No.: 29 Column: b________ 7 Year Amortizable Pro~~~~y [Schedule Page: 336:?._._ Line No.-"-:-=-3o--=----c-=-o-l=-u-m_n_:--=-b=------ - - - ----~ 5 Year Amortizable Property ~!l!l!._f'_f!:ge: 33if2--- Line No.: 32 Column: b 5 Year Amortizable Proper!:_i-[Chiiciuie..f:liage: 336.2 Line No.: 37 ·-c-o-1-um_n_:_b_ __ _____ __] 5 Year Amortizable Pr-operty ·----------· ~heciuie--Page: 336.2 Line No.: 40 Column: b . _] 7 Year Amortizable Property ---------~ ··------~ ..... J ···--~ ----~ [Sciieiiuie No:: -----·-----=:J ---··---~ __ IFERC FORM N0.1 (ED.12~87} Page450.1 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original (21 A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/Q4 FOOTNOTE DATA f§chedule Page: 336.2 Line No.: 41 Column: b 7 Year Amortizable Proper'Ey~hedu/e Page: 336.2 _Line"!..~:= 42 Column: b 7 Year Amortizable Property ~chedulfi!Page: 336.2 ---Line No~.:'--4=-=3---=cc---o--:-lu_m_n_.-. 7 Year Amortizable Property IScheduie Page: 336.2 Line No.: 44 Column: b 7 Year Amortizable Properfy··----=-=:.:.=:..:.:c.::.::..:._::::___ _ _ __ b::--==-=--=--=------- ~hecfute Page: 336.2 Line No.: 45 Column: b 5 Year amorti zabl~--.R_~op~-~-!__ , Y ' - - - - - - - - - I§chedul~uf'._- ~~ ~---..,..,.,- - ,~:· ~--~ • ~rr-e<>-•"""':_"""~" - - FERC FORM NO.1 (ED.12·96} Page 351 Name of Respondent This Report is: Date of Report Year/Period of Report (1) An Originat (Mo, Da, Yr) Florida Power 8: Light Company A Resubmission I I 20151Q4 FOOTNOTE DATA ISchedule Page: 350 Line No.: 18 Column: Deferred in account 186. iSchedule Page: 350 Line No.: 18 Column: I Deferred in account 186 FORM No. 1 (ED. 12-371 Page 450.1 BLANK PAGE (Next Page is 352) Name of Respondent Florida Power & Light Company This~ortls: (1) An Original (2) [)A Resubmission Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/04 End of RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES 1. Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D & D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(ldentify recipient regardless of affiliation.) For any R, D & D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts). 2. Indicate in column (a) the applicable classification, as shown below: Classifications: A. Electric R, D & D Performed Internally: (1) Generation a. hydroelectric i. Recreation fish and wildlife ii Other hydroelectric b. Fossil-fuel steam c. Internal combustion or gas turbine d. Nuclear e. Unconventional generation f. Siting and heat rejection {2) Transmission Line No. a. Overhead b. Underground (3) Distribution (4) Regional Transmission and Market Operation (5) Environment (other than equipment) (6) Other (Classify and include items in excess of $50,000.) (7) Total Cost Incurred B. Electric, R, D & D Performed Externally: (1) Research Support to the electrical Research Council or the Electric Power Research Institute Description Classification (a) (b) 1 B4 Center for Energy Advancement through Technological innovation 2 84 Center for Energy Advancement through Technological Innovation 3 84 Center for Energy Advancement through Technological Innovation 4 84 Center for Energy Advancement through Technological Innovation 584 Center for Energy Advancement through Technological Innovation 6 81 EPRI -Advanced Nuclear Technology 7 84 Conservation Research & Development Project 8 84 Renewable Research & Development Project 9 A6 Conservation Research & Development 10 84 Energy Power & Sustain ability Project 11 84 Conservation Research & Development 12 A6 Renewable Research & Development 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 FERC FORM NO.1 (ED. 12-87) Page 352 Thls~rtls: An Original {1) (2) [)A Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Oa, Yr) Year/Period of Report 2015/Q4 End of I I RESEARCH, DEVELOPMENT, AND DEMONSTRATIC N ACTIVITIES (Continued} (2) Research Support to Edison Electric Institute (3) Research Support to Nuclear Power Groups (4) Research Support to Others (Classify) (5) Total Cost Incurred 3. Include in column {c) all R, D & D items performed internally and In column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D & D {such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6} and B (4)) classify items by type of R, D & D activity. 4. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work In Progress, first. Show In column (f) the amounts related to the account charged in column (e) 5. Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year. 6. If costs have not been segregated for R, D &D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by Esl" 7. Report separately research and related testing facilities operated by the respondent 11 Costs Incurred Internally Costs Incurred Externally currefc~ Year Current Year (d) 4,769 Unamortized Accumulation (g) AMOUNTS CHARGED IN CURRENT YEAR Account (e) 560 Amount (f) Line No. 4,769 1 454 566 454 2 2,272 568 2,272 3 4,149 580 4,149 4 88,456 5 2,635,469 517 2,635,469 6 255,032 910 255,032 7 134,795 908 134,795 8 910 42,240 9 10 88,456 107.1 42,240 586 70,000 58,566 70,000 910 58,566 11 28,273 908 28,273 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 FERC FORM NO.1 (ED. 12-87) Page 353 Florida Power & Light Company Report below the distribution of total salaries and wagel? for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used. Line No. FERC FORM NO. 1 (ED. 12·88) Classification Page 354 Florida Power & Light Company Classification Total '- : - - . . ~ ~= ~~ ~ ~ -~-~~- ~-~ ~-- 733,545,845 -~: -~---~- -=~~- -~-~ ~-=--~~~=----=~-~- l., ___" -----278,042,102 278,042,102 278,042,102 f~~·:7:-~~"':~ . L.::.¥.::::.~'"---~'-'- .....,..,_~~~--~·- .... _.....-::-------~..,---c"-~ ------~- ----- - kL ·-· __ .....,_ 278,042,102 -- -·-~,_,.---~. ·~ 32,243,203 FERC FORM NO. 1 (ED. 12-88) Page 355 Date Report (Mo. Da, Yr) Name of Respondent Florida Power & Light Company I I Report End of 2015104 Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff. In columns for usage, report usage-related billing determinant and the unit of measure. (1) On line 1 columns (b), (c), (d), (e), (f) and (g) report the amount of ancillary services purchased and sold during the year. (2) On line 2 columns (b) (c), (d), (e), (f), and (g) report the amount of reactive supply and voltage control services purchased and sold during the year. {3) On line 3 columns (b) (c), (d), (e), (f), and (g) report the amount of regulation and frequency response services purchased and sold during the year. (4) On line 4 columns (b), (c), (d), (e), (f), and (g) report the amount of energy imbalance services purchased and sold during the year. (5) On lines 5 and 6, columns (b), (c), (d), (e), (f), and (g) report the amount of operating reserve spinning and supplement services purchased and sold during the period. (6) On line 7 columns (b), (c), (d), (e), (f), and (g) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided. Type of Ancillary Service FERC FORM NO. 1 (New 2-04) Page 398 This Report is: (1) XAn Original _{_2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/Q4 FOOTNOTE DATA !Schedule Page: 398 Line No.: 1 _Co,-"lu=m.:,:.:-:-n·::_:·b:.;--;---==----.-,-----=:-----=-------;--o--=-Does not include 444,376 MW of sales by Florida Power & Light Company to Florida Power & Light Company's Energy Marketing and Trading (EMT) group related to EMT's off-system sales. ~hedule Page: 398 Line No.: 1 CoiUf!lf!_~_cj__ __ -··---..-------- Does not include $38,876.54 of sales by Florida Power & Light Company to Florida Power & Light Company's Energy Marketing and Trading (EMT) group related to EMT's off-system sales. 'f$chedule Page: 398 Line No.: 1 Column: e ---·· -- --- ------~ Does not include 4-4 4, 3 76-··Mw of sales by Florida Power & Light ColliPany to Florida Power Light Company's Energy Marketing and Trading (EMT) group related to EMT's off-system sales. & Does not include $38, 87 6. 54 of sales by Florida Power & Light Company.t"o- Florida Power Light Company's Energy Marketing and Trading (EMT) group related to EMT's off-system sal·es. & I$Ched'u-,..le-P=-a-g_e_:-=3c-::9--=8---=L--=in-e__..,.,N=--o-.:-1:----:c=-o--=lc-um_n_:_g_____________............................ -3-98--,-----L.,....,-_n_e_N...,..o-..-.2-=---c=-o-l=--u_m_n_:--=-b--- ________ ............... ····-···- ~-...,d,-u--le-P=-a-g_e_: ---:=-1 Does not include 444,376 MW of-·-s·ares·-·--sy··-Florida Power & Light Compcin.y to Florida Power Light Company's Energy Marketing and Trading (EMT) group related to EMT's off-system sales. r5'CiieciuiePage': 398 Line No.: 2 Column: d & ---------- ----- Does not include $422,129.29 of sales by Florida Power & Light Company'to .. Florida Power & Light Company's Energy Marketing and Trading (EMT) group related to EMT's off-system sales. ~l!_f!dule Page:-39ii"-'i3iie"Fici:··2 Column: e Does not include 444,376 MW of sales by Florida Power & Light Company to Flor:Cd'a Power & Light Company's Energy Marketing and Trading (EMT) group related to EMT's off-system sales. 1... - - - - · - - - · -......... --·--·-""""---- ·--.. -- !Schedule Page: 398 Line No.: 2 Column: g______ ·;;o;---.---;--=---,--"""'--.--,---=-- ooes not include $422,129.29 of sales by Florida Power & Light Compa'ii.Y"-to Florida Power Light Company's Energy Marketing and Trading (EMT) group related to EMT's off-system sales. ~~IJ~ule Pagi:3ii8--i_ine.No.:·4 Column: b Number of units represents over-scheduled :MWhs by transmission customers···under--Florida Power & Light Company's Open Access Transmission Tariff. '/Schedule P:fl_g(!~ ~!!_8_ . . __ Line No.: 4 ·-coFuiiin: ii --Dollars shown are net dollars refunded for Energy ImbaTance purchased and sold for. th-e · year under Florida Power & Light Company's Open Acc~~-~-:r:J:".<:!:C:_smission Tariff. --· ___ _ !schedule Paiie:..398 Tine No.: 4 Column: e ____ _ _____ -----c--~-;--:----' Number of units represents over-scheduled MWhs by transmission customers under Florida Power & Light Company's Open Access Transmission Tariff. \FERC FORM N0.1 (ED.12-87) Page450.1 & Florida Power & Light Company (1) Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. (2) Report on Column (b) by month the transmission system's peak load. (3) Report on Columns (c) and (d) the specified information for each monthly transmission- system peak load reported on Column (b). (4) Report on Columns (e) through ij) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification. Monthly Peak tvMJ- Total Day of Monthly Hour of Firm Network Monthly Service for Self Peak Firm Network Service for Others Long-Term Firm Point-to-point Reservations Other longTerm Firm Service Short-Term Firm Point-to-point Other Service U) FERC FORM NO. 1/3-Q (NEW. 07-04) Page 400 Florida Power & Light Company This (1) (2) End of 2015tQ4 Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year. Line No. Item Item MegaWatt Hours (Enter Total of Lines 22 Through (MUST EQUAL LINE 20) (Enter Total of lines 9, 10, 14, 18 19) FERC FORM N0.1 (ED.12-90) Page 401a MegaWatt Hours Florida Power & Light Company 1. Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system. 2. Report in column (b) by month the system's output in Megawatt hours for each month. 3. Report In column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales. 4. Report In column (d) by month the system's monthly maximum megawatt load (60 minute integration) associated with the system. 5. Report in column (e) and (f) the specified information for each monthly peak load reported In column (d). Total Monthly Energy 41 TOTAL FERC FORM NO.1 {ED. 12-90) Megawatts 126,928,900 Page (See lnstr. 4) (d) (c) (b) 401b Hour This Report is: (1) 2S. An Original [j~ A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA ~cheduje Page: 401 Line tio~-:-22 --~:=-o::..:l=u:..om::..::n=-=-:-=b'---------------· _ _ _ _ _ _ _ _ _ _ _ _ Includes 506,287MW in unbilled revenue ISciiedule Page: 401 .~l'!e No.: 23 ·· Column: b . - - · - - - - - - Includes 120,465MW increase in unbilled revenue ~hedule Page: 401 Line No~:-3o Column: f?__ ·-----Reflects correction of amount previously recorded in File--f.,-1.--.r-s-t,--q_u_a_r.....,t-_e__~ as 8, 4 73, 993 ~~fl~ft~le Page: 4o1· Line No.: 33 Column:·b· Reflects correction of amount previously recorded in second quarter as 11,067,261 [$.gl!~qute Page:-·401 Line No~;.;!!_ Column: b Excludes MW produced by Cedar Bay plant m IFERC FORM N0.1 (ED. 12-87) Page450.1 _j This ~ort Is: (1) ~An Original (2) OA Resubmlssion Name of Respondent Florida Power & Light Company Dale Report ReP.Ort (Mo, Da, Yr} I I End of 2015/04 1. Report data for plant in Service only. 2. Large plants are steam plants with installed capacity (name plate rating} of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants. 3. Indicate by a footnote any plant leased or operated as a joint facility. 4. If net peak demand for 60 minutes is not available, give data which is available, specifying period. 5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant. 6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Met. 7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20. 8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned. Line No. FERC FORM N0.1 (REV. 12-03) Item Plant Name: Cape Canaveral Page 402 Plant Name: West County This~rtls: An Original (1) (2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) 0 YeariPeriod of Report 2015/Q4 End of I I STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plarits)(Continued) 9. Items under Cost of Plant are based on U. S. of A. Accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as other Power Supply Expenses. 10. For IC and GT plal'lts, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on L'lne 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants. 11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, If a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant. 12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other Informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant. Plant Name: Turkey Point 5 (d) Plant Name: Riviera Plant Name: Sanford (e) Line No. (f) Combined Cycle Combined Cycle Combined Cycle 1 Conventional Conventional Conventional 2 2007 2014 2002 3 2007 2014 2003 4 1225.00 1295.00 2378.00 5 1222 1292 2217 6 8649 8481 8504 7 0 0 0 8 1159 1237 2030 9 1091 1212 1900 10 32 34 55 11 7119846000 6982871000 9024623000 12 0 12488526 2271090 13 31588563 77003321 86003657 14 ,~f~[~~~~~~;;'l~~~~B,f:t't~I~~~;~~,~~~lt~~Y(81~~~E;{;j~~i~JR~m,~1S1~~;~l~~iflt~¥&lr~~~j®1'b?!OP·:tf~~f'~£lfj~s{;,~:;;,ilf!'i~~fi~!~,f~~IT~~it':~[ji1g%i;t.'4§~~B.1~~ 15 0 1203562 63991 16 523406589 1117703832 837196887 17 427.2707 863.0918 352.0592 18 1399649 1056004 2109503 19 224295697 208406900 299341847 20 0 0 0 21 0 264 0 22 0 0 0 23 24 0 0 0 1271763 1055959 1400731 25 2038356 1200707 1952528 26 0 0 0 27 0 0 0 28 731797 1055939 806007 29 397610 1143807 3388660 30 0 369 0 31 2559365 1653875 6289894 32 256697 1131354 33 232950934 216705178 520603 315809773 0.0327 0.0310 0.0350 Gas 34 35 Oil Gas 36 Barrels Mcf 4094 45691464 0 65958243 0 0 38 140881 1023095 0 1023036 0 0 39 Oil Gas Barrels Mcf 11890 48992271 0 137476 1023210 0 60.517 4.563 0.000 136.449 4.549 0.000 4.538 0.000 0.000 40 60.517 4.563 0.000 136.449 4.549 0.000 4.538 0.000 0.000 41 42 37 Mcf 10.481 4.563 0.000 23.061 4.549 0.000 4.538 0.000 0.000 0.000 0.032 0.000 0.000 0.030 0.000 0.033 0.000 0.000 43 0.000 7050.000 0.000 0.000 6698.000 0.000 7477.000 0.000 0.000 44 FERC FORM NO.1 {REV.12-03) Page 403 Date Report (Mo, Da, Yr) Respondent Florida Power & Light Company I I End of 2015/04 1. Report data for plant in Service only. 2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report In this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants. 3. Indicate by a footnote any plant leased or operated as a joint facility. 4. If net peak demand for 60 minutes Is not available, give data which is available, specifying period. 5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant. 6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Met. 7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20. 8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned. Line No. FERC FORM NO.1 (REV. 12-03) Item Plant Name: Turkey Point Page 402.1 Plant Name: Manatee Report (Mo, Da, Yr) Florida Power & Light Company I I End of 2015104 9. Items under Cost of Plant are based on U. S. of A. Accounts. Production expenses do not Include Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses. 10. For IC and GT plarilts, report Operating Expenses, Account Nos. 547 and 549 on Llne 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Une 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants. 11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, Internal combustion or gas-turbine equipment, report each as a separate plant. However, If a gas-turbine unit functions in a combined cycle operation wlth a conventional steam unit, include the gas-turbine with the steam plant. 12. If a n~clear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the and other and characteristics of Plant Name: Martin 8 FERC FORM NO. 1 (REV. 12-03) Plant r · •···· ••::·:.:; Page 403.1 Une No. Year/Period of Report Florida Power & Light Company End of 2015/Q4 1. Report data for plant in Service only. 2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants. 3. Indicate by a footnote any plant leased or operated as a joint facility. 4. If net peak demand for 60 minutes is not available, give data which is available, specifying period. 5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant. 6. If gas is used and purchased on a thenm basis report the Btu content or the gas and the quantity of fuel burned converted to Met. 7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20. 8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned. Line FERC FORM NO. 1 (REV. 12-03) Item Plant Page 402.2 Plant Florida Power & Light Company This~rtls: (1) ~An Original (2) OA Resubmlsslon Date of ReRort (Mo, Da, Yr) I I End of 2015/Q4 9. Items under Cost of Plant are based on U.S. of A Accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses. 10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants. 11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant. 12. If a nuclear power generating plant. briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the and other and characteristics of FERC FORM NO. 1 (REV. 12-03) Page 403.2 This ~ort Is: ~An Original A Resubmlsslon Name of {1) (2) Florida Power & Light Company 0 of Report Da, Yr) I I End of 2015/Q4 1. Report data for plant in Service only. 2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report In this page gas-turbine and Internal combustion plants of 10,000 Kw or more, and nuclear plants. 3. Indicate by a footnote any plant leased or operated as a joint facility. 4. If net peak demand for 60 minutes is not available, give data which is available, specifying period. 5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each planl 6. If gas is used and purchased on a !harm basis report the Btu content or the gas and the quantity of fuel burned converted to Met. 7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20. 8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned. Line No. FERC FORM NO. 1 (REV. 12--03) Item Plant Name: Martin 3 & 4 Page 402.3 Plant Name: Ft. Myers This ~rtls: (1) An Original {2) DA Resubmission Name of Respondent Florida Power & Light Company Date qf Report (Mo, Da, Yr) Year/Period of Report End of I I 2015/04 STEAM-ELECTRIC GENERATING PLA.NT STATISTICS (Large Pla!)ts)(Continued) 9. Items under Cost of Plant are based on U. S. of A. Accounts. Production expenses do not include PJrchased Power, System Control and Load Dispatching, and Other Expenses Classified as other Power Supply Expenses. 10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants. 11. For a plant equipped wi~h combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, If a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant. 12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to resaarch and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant. Plant Name: Lauderdale Plant Name: Manatee Plant Name: (e) (d) Line No. (f) Combined Cycle Combined Cycle Conventional Conventional 1993 2005 2005 1225.00 1213 8587 0 1156 1085 25 7342340000 0 28993716 1993 1053.00 909 8641 0 894 876 39 4382910000 5498219 90018838 1 2 3 0.00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ;ft~~~'i\i&~H~f~,~~trt~~tt,~1fii~li~~t~~k\i~M~~~2it~Wif~'\r.;\;~~Ttirsi:i~i,i:~¥~fl;~~i,~t:~;i~'t~~E4'f':~~~~%?4?~1~~1~1 0 626345005 594.8196 1317825 163161499 0 0 305142 504714662 412.0120 854495 227610119 0 0 0 0 0 1197405 701265 257032 0 3197078 296640 172240563 0.0393 Gas Barrels Met 1935 131833 154.854 154.854 27.967 0.000 0.000 35950329 1022825 4.530 4.530 4.530 0.037 8392.000 FERC FORM NO.1 (REV.12-03) 0 0 0 0 0 0 0 0 0 0 0 0 0.0000 0 776419 1388886 0 0 591847 240047 0 1397414 158724 233017951 0,0317 2111819 0 0 Oil 0 0 0 Gas Met 0 0 0.000 0.000 0.000 0.000 0.000 49940273 1023076 4.558 4.558 4,558 0.031 6959.000 0 0 0.000 0.000 0.000 0.000 0.000 Page 403.3 0 0 0.000 0.000 0.000 0.000 0.000 0 0 0.000 0.000 O.OQO 0,000 0.000 0 0 0.000 0.000 0.000 0.000 0.000 0 0 0.000 0.000 0.000 0.000 0.000 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 Florida Power & Light Company 1. Report data for plant in Service only. 2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants. 3. Indicate by a footnote any plant leased or operated as a joint facility. 4. If net peak demand for 60 minutes is not available, give data which Is available, specifying period. 5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant. 6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Met. 7. Quantities offuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on line 20. B. If more than one fuel Is burned in a plant furnish only the composite heat rate for all fuels burned. FERC FORM NO. 1 (REV. 12-03) Page 402.4 ···. of Report Florida Power & Light Company End of 2015/Q4 9. Items under Cost of Plant are based on U.S. of A. Accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses. 10. For IC and GT plant$, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants 1...1 .... ;,,"''" for peak load service. Designate automatically operated plants. 11. For a plant equipped with combinations of fossil fuel steam, nuclear , hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, If a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant. 12. If a nuclear power generating plant, briefly explain by tfn,ntn,nt.. (a) accounting method for cost of power generated including any excess costs attributed to reseanch and development; (b) types of cost units used for the various components of fuel cost: and (c) any other Informative data concerning plant type fuel used, fuel enrichment type and quantity for the and other and characteristics of Plant Space Coast FERC FORM NO.1 (REV.12-03) Page 403.4 Line No. This Report is: (1) ~An Original I(2) A Resubmission Name of Respondent Florida Power & Ught Company Date of Report Year/Period of Report (Mo, Da, Yr) II 2015/04 FOOTNOTE DATA ---·-·-=:::J ~edule Page: 402 ___ Line No.: 15 Column:_b Equipment costs include capitalized spare parts of $3,126,976 which are physically located in the Central Distribution facility in Martin County; and capitalized spare parts of $15,952,827 which are physically located in the Central Distribution facility in Collier Count~Y~·~------~~f§C-fiedule Pag!!: 402 Line No.: 15 Column: c Equipment costs include capitalized spare parts of $10,288,750 which are physically located in a vendor warehouse in Chatham County, Georgia; and capitalized spare parts of $65,933,557 which are physically located in the Central Distribution facility in Martin County. ~_Eflec!ule Page: 403 Line fo!._o.: 15 Column: d --------:----:o--= Equipment costs include capitalized spare parts of $1"6~ 392, 305 which ·ar-e physically located in the Central Distribution facility in Mart_~~ County. [SChedule Pa~:.._1-fJ3 Lin-e-No.: 15 CQ{'!mn: e___ _ .... ____ Equipment costs include the Riviera Beach Energy Center-Martin County Pipeline of $60,443,321 which is physically located in Martin County, capitalized spare parts of $19,739,661 which are physically located in the Central Distribution facility in Martin County; and capitalized spare parts of $19,732,200 which are physically located in the Central Distribution facility in Collier County. !§Efjidule Page: 403 Line Ng::_!S ··column: t ____ - -Equipment costs include capitalized spare parts of $2"6,467,251 which are physically located in the Central Distribution facility in ~artin County. !Schedule ~E!_ge: 4iii'1" Line No.:_-1_ column: e __ __ . Data shown relates to FPL's 76.36% ownership portion except: The number of employees represents 100%. Capacity and generation reflect FPL's 73.923% ownership share available at point of interchange. Jacksonville Electric Authority owns the remaining 23.64% of Scherer #4. ~yle Piige:-403.1 Line f'!.c:!:; M1 Column: f ·------,-~.,---,--=-c-complete Name: St. Johns River Power Park (SJRPP) Data shown relates to FPL's 20% ownership portion except: The number of employees represents 100%. Jacksonville Electric Authority owns the remaining 8Q:S.?.f"_SJRPP. '$_chedule-Page: 402.1 Line No.: ;is Column: b ... -·----Equipment costs inciu'cte capitalized spare parts o{ $I76, 696 which' are physically located in the Central Distribution facility in Martin County;_:_._ _ _ __ /Schedule Pagf!::_LJ03.1 Line No.: 15_____Column:--d .. __ · · --~ Equipment costs include capitalized spare parts of $45, 970-;'4'48 which are physically located in the Central Distribution facility in Marti_[lCounty. ~t?.IJ.~diile Page: 402.2_ ~_ine -1 Colum_fJ: b ___ __ .. -- -] Amounts reflect FPL's 100% ownership of St. Lucie Unit No. 1 and 85.10449% ownershlp of St Lucie Unit No. 2. The other co-owners of Unit No. 2 and their percentage of ownership are: (1) Orlando Utilities Commission: 6.08951%, and (2) Florida Municipal Power Agency: 8.80600%. Data shown relates to FPL's ownership portion only, except for the number of employees. JSciiedule P~g~; 403.2- Line No.: -1 ___column: d Ft. Myers GTs are designed for peak load service and also.. have remote start and load control capability. l§!jjjic!ple Page: 403.2 Lin_~ _fjo.: -1 Column: e_ ~ Lauderdale GTs are designed for peak load service and also have remote start and loa-d -control capability_·~-------fSchedu/e_f'c:r_ge: 4o3.2- Line No.:_-_1 Column: f ------ ·--c,------,---Port Everglades GTs are designed for peak load service also have remote start and load control capability. '§_c:_l)~c!iiie Page: 402.2 !::fne No:: 1 Column: b _____ -·] The St. Lucie Nuclear Units have pre.ssuri zed water reactors. The nuclear fuel assemblies in the reactors contain enriched uranium. The cost of nuclear fuel is amortized to fuel expense based on the quantity of heat produced for the generation of electric energy. =:J ----=:J :=J -No:: and. IFERC FORM NO. 1 (ED. 12-87) Page 450.1 Name of Respondent Florida Power & Light Company This Report is: (1) 6 An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) II 2015/04 FOOTNOTE DATA Under t~e Nuclear Waste Policy Act of 1982, the U.S. Department of Energy (DOE) is respons1ble for the ultimate storage and disposal of spent nuclear fuel removed from nuclear reactors. Additional information on FPL's nuclear dec0mmissioning is detailed in the Notes to Consolidated Financial Statements. ~chedule Page": 402.2 Line No.: 1 Column: c -----The Turkey Point Nuclear Units have pr-essurized water reactors. The nuciear--fuei_ .. _ assemblies in the reactors contain enriched uranium. The cost of nuclear fuel is amortized to fuel expense based on the quantity of heat produc~d for the generation of electric energy. Under the Nuclear Waste Policy Act of 1982, the U.S. Department of Energy (DOE) is responsible for the ultimate storage and dispo~al of spent nuclear fuel removed from nuclear reactors. Additional information on FPL's nuclear decommissioning is detailed in the Notes to Consolidated Financial Statements. l§chedulf!_f?age: 403.2 Line-Fi0.:---11 Column: e ------ ---Lauderdale GT employees and non-fuel productic)r! ___e_xp_e_n_s_e_s_a-=-=-r~e-----,i~n-c--;l----:u-d-;-e-d-;--1•·n-'t-;-h-e-----::P::-o-r-,t_ _ __ Everglades GT value since they jointly operate and maintain both GT sites in Broward County. f$ihedu/e Page: 403_~g_ __ .. !::f.ne No.:- {1- -·-Column: f --- - - ---Lauderdale GT employees and non-fuel production expenses are-1'.-n-c~l-u-d~e-d~i~n-t~h~e~P-o-r~t----~ Everglades GT value since they jointly operate and maintain both GT sites in Broward Count_~Y~·---------------I$Chedu/e Page: 402.3 Lin_f!.NCJ..·L~_?. Co!ilmii:iJ___ --Equipment costs include capitalized spare parts of $44,266;123-which are physically located in the Central Distribution facility in _Martin County. ,fSchedule Page': 402.3 LineNo.:_1§_ _____ c;_g_~f!l!!~_c · ---- -----~--------Equipment costs include capitalized spare parts of $97,621,992 which ar_e_p~h-y-s-1''c_a_l,l_y_ _ __ located in the Central Distribution facility in Martin County.__ \§chedule Pag!!_~_1:fl.~~-~ Line No:: 15 -Column: d . __ _ Equipment costs include capitalized spare parts o{--$39, 687,544 which are physically located in the Central Distribution facility in Martin County. rg'hedule Page: 403.3 Lil)_~ f!o.: 15 coiufiiii:e-Equipment costs include capitalized spare parts of $17, 6'64·;·9-43 which are physically located in the Central Distribution facility in M~:r:!:~:r1. (;chedule Page: 402.1 __ _~.i.12e No.":_44__ "co-,lu_m_n_:----,d=--=-2--------____ --··-··· ___ Martin Oni t 8 heat rate reflects the benefit of the--75 -Mw Martin Solar Energy Center capability contributi~o~n~·----------------------~~f}_i!!!f!!f!_!:_age: 4ii2.4____ Line No.: 36 Colum!_J_;_r:J_!_ -------- - - --~ DeSoto is a photovoltaic (PV) solar plant and as such, fuel related---Information is not applicable. !Schedule Pa!~!!_;_"!f!_:?:~ Line No.: 36 Column: e1 Martin Solar is a solar thermal plant and as such, fuel related informatio·n.---r.s---not Page 450.2 JFERC FORM N0.1 (ED. 12~87) Name of Respondent Florida Power & Light Company This Report is: ( 1) ~ An Original I(2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 FOOTNOTE DATA applicable. ~C...JJedule Page: 402.4 Line No.: 36 Column: f1 Space Coast is a photovoltaic (PV) solar plant and as such;·fuel related information is not applicable. IFERC FORM N0.1 (ED. 12-87) Page450.3 BLANK PAGE (Next Page is 422) Name of Respondent Date of Report (Mo, Da, Yr) This 'f8Jort Is: (1) An Original (2) [JA Resubmisslon Florida Power & Light Company Year/Period of Report 2015/Q4 End of I I TRANSMISSION LINE STATISTICS 1. Report information concerning transmission lines, cost of lll)es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutllity Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4} underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report In columns (f) and (g) the total pole miles of each transmission line. Show in column (f) tlhe pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. DESIGNATION Line No. \(()LTAGE (KV) (Indicate wliere other than 60 cycle, 3 phase) LENG~H role ~iles) u f.~teascro ergroun hnes report circuit miles) Type of Supporting 1 From To (b) (a) Operating (c) Designed Structure (e) (d) on ~t[l,lcwre of Line Desimated Number Of u~f,~~r.ures of IJOther rne (g) Circuits (h) 1 ANDYTOWN CORBETT 500.0( 500.00 H 52.46 2 ANDYTOWN LEVEE 1 500.0C 500.00 H 15.69 1 3 ANDYTOWN LEVEE 2 500.0( 500.00 H 15.6.: 1 1 4 ANDYTOWN MARTIN 500.0( 500.00 H 81.84 1 5 ANDYTOWN MARTIN 500.0( 500.00 H 2.11 6 ANDYTOWN ORANGE RIVER 500.()( 500.00 H 106.73 1 1 7 CONSERVATION CORBETT 500.0( 500.00 H 56.75 1 8 CORBETT MARTIN 1 500.0( 500.00 H 0.99 1 H H H H H H H H H H 34.48 1 9 CORBETT 10 CORBETT MARTIN 1 500,0( 500.00 MARTIN2 500.0[ 500.00 11 CORBETT MARTIN2 500.0[ 500.00 MIDWAY soo.oc 500.00 HATCH (GAP) 500.0( 500.00 POINSETT 500.0( 500.00 12 CORBETT 13 .l'lH\iAI :c):' 14 DUVAL 15 DUVAL 16 DU\i'Ati! RICE 'i;]';( THALMANN (GAP) 500.0C 500.00 500.0( 500.00 30.22 1 1.30 1 56.56 1 37.39 1 173.03 1 45.98 1 37.45 1 1.74 1 26.68 1 17 MARTIN MIDWAY 500,()( 500.00 18 MARTIN MIDWAY 500.0( 500.00 19 MARTIN POINSETT 500.0( 500.00 H 109.49 1 20 MIDWAY POINSETI 500.0[ 500.00 H 92.76 1 1 21 POINSETT ROBERTS 500.0C 500.00 H 105.43 22 RICE ROBERTS soo.oc 500.00 21.43 23 137TH AVENUE DAVIS 230.0C H 230.00 H 24 137TH AVENUE DAVIS 230.0C 230.00 25 137TH AVENUE DAVIS 230.0C 230.00 26 137TH AVENUE DAVIS 230.00 230.00 137TH AVENUE LEVEE 230.00 230.00 27 SP SP SP SP 1 0.96 2 0.17 1 18.42 1 1.79 2 4.70 1 2 1 14.40 2 2.98 28 All CO COLLJER 230.00 230.00 H 29 ALl CO COLLIER 230.00 230.00 H 0.21 30 ALl CO COLLIER 230.00 230.00 H 7.54 31 ALl CO COLLIER 230.0 230.00 0.1~ 32 All CO COLLIER 230.0( SP 230.00 SP 0.43 1 33 All CO ORANGE RIVER 230.0( 230.00 H 4.70 2 34 ALl CO ORANGE RIVER 230,0( 230,00 H 5.32 35 All CO ORANGE RIVER 230.0( 230.00 H 1.08 5.45 2 6,205.67 691.36 1,594 TOTAL 36 FERC FORM NO.1 (ED. 12-87} Page 422 1 1 Name of Respondent Date of.~{port (Mo, Da~ Yr) This 7!Jort Is: (1) An Original (2) Resubmission Florida Power & Light Company []A I I RANSM!SSION LINE STATISTICS (Continued) Year/Period of Report 2015/04 End of I 'f 7. Do not report the same transmission nne structure twice. ~eport Lower voltage Lines and higher volta! e lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structure ~ support lines of the same voltage, report the pole miles of the primary structure In column (f) and the pole miles of the other line(s) in column (g) ' B. De•lg- aoy tr.m•m.,loo lloe " portOo th"eof"' whWner, basis of sharing expenses of the Une, and how the expenses borne by the respondent are accounted for, and accounts a cted. Specify whether lessor, co-owner, or other party Is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terms Iof lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 1o. Base the plant cost figures called for in columns (j) to (I) on the book cost at end of year. I 1 I i COST OF L!NE (Jndudeln-corur;·m (j) Land, Size of Conductor and Material (i) EXPENSES, EXCEfT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land {j) Construction and Other Costs (k) Total Cost Operation Expenses (m) (I) Maintenanqe Expenses (n) Rents Total Expenses (p) (o) Line No. fl-1127 AAAC 1 3-1272ACSRAZ 2 i 3 3-1272ACSRAW ' 5 3-1127 AAAC I 6 ;3-1272 ACSR AW ~1127 AAAC 4 3-1435AAAC 7 ~1127 AAAC 8 ~-1272 ACSR AW 9 3-1127 AAAC 10 f>-1272ACSR AW 11 I ~-1272ACSRAW 12 3-1113ACSR 13 3-1272 ACSR AW 14 3-1272ACSRAW 15 3-1113ACSR 16 3-1127 AAAC 17 -1272ACSRAW 18 ~-1272ACSRAW 19 ~-1272 ACSR AW 20 3-1272ACSRAW 21 ~-1272 ACSR AW I 1-954 ACSR AW i 23 1-1431 ACSRAW I 24 22 25 1-954 ACSR AW ' ~-954 ACSR AW 1-954 ACSR AW I 26 i 27 28 1-1431 ACSRAW i 1-1431 ACSRAZ I 29 1-1431 ACSRAZ I' 30 1-1431 ACSR AW 31 1-1431 ACSRAZ 32 1-1431 ACSRAW I 33 1-1431 ACSRAZ ! 34 35 1-1431 ACSRAZ I 363,243,903 FERC FORM NO. 1 (ED. 12-87) 2,298,820,876 2,662,064,779 Page 15,003,893 423 18,j72.936 2,400 33,179,229 36 This ~ortls: An Original [JA Resubmission Name of Respondent Date of Report (Mo, Da, Yr) (1) (2) Florida Power & Light Company Year/Period of Report End of I I TRANSMISSION LINE STATIST 2015/04 cs 1. Report information concerning transmission lines, cost of lil)es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include allllnes covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual fines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H·frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report In columns (f) and (g) the total pole miles of each transmission line. Show ln column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. DESIGNATION Line No. To From (a) 1 2 3 4 5 (b) ALICO ORANGE RIVER ALICO ORANGE RIVER ALVA CORBETT ALVA CORBETT ALVA CORBETT 6 ALVA CORBETT 7 8 9 10 11 12 13 14 15 VOLI AGE (K.'!J (Indicate wtiere other than 60 cycle 3 phase) ALVA Operating {c) 230.0( 230.0( 230.0( 230.0C 230.0( 230.0C 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0! 230.0( 230.0( 230.0( 230.0! 230.0 230.0( 230.0( 230.0C 230.0( 230.0( 230.0( 230.0( 230.0C 230.0C 230.0C 230.0( 230.0( 230.0! 230.0( 230.0( 230.0( 230.0( CORBETT ALVA ORANGE RIVER ALVA ORANGE RIVER ALVA ORANGE RIVER ANDYTOWN CONSERVATION 1 ANDYTOWN CONSERVATION 1 ANDYTOWN CONSERVATION 1 ANDYTOWN CONSERVATION 1 ANDYTOWN CONSERVATION 2 16 ANDYTOWN CONSERVATION 2 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 ANDYTOWN CONSERVATION 2 ANDYTOWN CONSERVATION 2 ANDYTOWN CONSERVATION 2 ANDYTOWN CONSERVATION 2 ANDYTOWN CONSERVATION 2 ANDYTOWN ANDYTOWN DADE DADE ANDYTOWN DADE ANDYTOWN DADE ANDYTOWN DADE ANDYTOWN DADE ANDYTOWN FlAGAMf ANDYTOWN FLAGAMI ANDYTOWN FlAGAMI ANDYTOWN FlAGAMI ANDYTOWN FLAGAMI ANDYTOWN FLAGAMI ANDYTOWN FLAGAMI ANDYTOWN FLAGAMI FERC FORM NO.1 (ED. 12-87) Supporting Designed (d) Structure (e) 230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 UG 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 UG TOTAL 36 Page 422.1 LENG~ ~ole ~ifes) t e Scf!.O u~~ergroun lines report circuit miles) Type of 1 un ~~r/~ure Desi(l)ated 1 Number Of u~f,p!f,~res of l)ot er 1ne (g) (h) 0.37 2.42 2.11 0.17 0.15 67.77 9.70 0.15 2.23 10.77 4.09 0.27 1.98 11.42 0.15 0.13 1.88 10.48 0.12 0.15 0.02 0.06 D.O.< 14.80 4.19 0.02 0.09 0.50 12.83 5.57 4.41 0.07 0.33 0.23 0.39 0.53 6,205,67 Circuits 4.96 1 1 2 1 2 1 2 1 2 1 2 2 1 2 1 2 2 1 2 1 8.17 7.91 2 1 1 2 1 1 1 1 2 1 1 1 2 1 1 691.36 1,594 I Name of Respondent EJ Florida Power & Light Company Year/Period of Report Date oQf,eport (Mo, Da,1Yr) This '[!Jort Is: (1) An Original (2) A Resubmission II TRANSMISSION LINE STATISTICS (Continued} End of ! 2015/Q4 I 'l Lower voltage Lines and higher voltag lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 7. Do not report the same transmission line structure twice. 8. D"lgoate "'Y IM"""Osi'" '"" " portloo ~eport """"'foe whloh ..., ~poodooll• oot ~. ~I• owooc. • prnp•rty • ~osed fn>m '"""'"' ~''"'· give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line othe than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation o , fum ish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the lin , name of co-owner, basis of sharing expenses of the Une, and how the expenses borne by the respondent are accounted for, and accounts afti cted. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terms tf lease, annual rent for year, and how determined. Specify whether lessee is an associated company. . 1o. Base the plant cost figures called for in columns 0) to (I) on the book cost at end of year. I 1 i I i ' COST OF LINE (Include in Column 0) Land, Size of Conductor and Material (i) EXPENSES, EXCE~T DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land 0) Construction and Other Costs (k) ! Total Cost Operation Expenses (m) (I) Maintenana Expenses (n) Rents Total Expenses {p) (o) 1-1431 ACSR AW 1-1431 ACSR AZ 1-1431 ACSR 1W 1-1431 ACSR AW Line No. 1 2 3 4 5 6 7 8 9 10 ~-1431 ACSRAW ~-954 ACSR AZ 1-954 ACSR AZ ~-954 ACSR AZ 1-954 ACSR AZ 1-954 ACSR AZ 1-1431 ACSRAW 1-1431 ACSR AZ. 1-1431 ACSRAW 1-1431 ACSRAW 1-1431ACSRAW 1-1431 ACSRAW 1-1431 ACSRAZ 1-1431 ACSR AW 1-1431 ACSRAW 1-1431 ACSRAZ -1431 ACSR AZ 1-1431 ACSRAW -1431 ACSR AZ. 1-1431 ACSR AZ 1-1431 ACSRAW 1-1431 ACSRAZ 1-3750 AL-HP 1-1431 ACSRAZ 1-1431 ACSRAZ 12-556.5 ACSR AZ 1-1431 ACSRAW 1-1431 ACSR AZ. 1-1431 ACSRAZ 12-556.5 ACSR AZ. 1-3750 AL-HP 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 I i ! l I i i' I r 1 I I i 30 i 31 32 33 34 35 : i I ' : 363,243,903 FERC FORM N0.1 {ED.12-B7) 2,298,820,876 2,662,064,779 Page 15,003,893 423.1 18,1f2,936 2,400 33,179,22~ 36 This ~ort Is: (1) An Original (2) _fjA Resubmission Name of Respondent Florida Power & light Company Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015104 End of TRANSMISSION LINE STATIST CS 1. Report information concerning transmission lines, cost of li~es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is ·reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. From (a) 1 ANDYTOWN 2 ANDYTOWN 3 4 5 6 7 )(QLT~~~ (~)Q (Indicate wliere other than SO cycle 3 phase) DESIGNATION Line No. ANDYTOWN To (b) HUNTINGTON HUNTINGTON ANDYTOWN LAUDERDALE 1 ANDYTOWN ANDYTOWN LAUDERDALE 1 LAUDERDALE 2 8 ANDYTOWN LAUDERDALE 2 9 ANDYTOWN LAUDERDALE 2 ANDYTOWN LAUDERDALE 3 ANDYTOWN LAUDERDALE 3 ANDYTOWN LAUDERDALE 3 ANDYTOWN NOB HILL BALDWIN DUVAL BALDWIN DUVAL BAREFOOT EMERSON BAREFOOT EMERSON EMERSON BAREFOOT BAREFOOT BAREFOOT EMERSON BAREFOOT MAlABAR 22 BAREFOOT MALABAR MALABAR MALABAR 23 BAREFOOT 24 BAREFOOT 25 26 27 28 29 30 EMERSON BARNA CAPE CANAVERAL BARNA CAPE CANAVERAL BARNA CAPE CANAVERAL BARNA NORRIS NORRIS BARNA BARNA 31 BOBWHITE 32 BOBWHITE 33 BOBWHITE 34 BOBWHITE 35 BOBWHITE 230.0! 230.0( 230.0( 230.0( 230.0( 230.0! 230.0[ 230.0! 230.0! 230.0! 230.0( 230.0( 230.0( 230.0( 230.0( 230.(]( 230.0( 230.0 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0[ 230.0C 230.0C 230.0C 230.0C 230.0C 230.DC 230.0C 230.0( 23D.OC 230.DC HUNTINGTON HUNTINGTON ANDYTOWN 10 11 12 13 14 15 16 17 18 19 20 21 Operating (c) NORRIS CHARLOTIE CHARLOTTE CHARLOTTE CHARLOTIE LAURELWOOD (d) LE~G~ ~~le 6riles) Supporting report circuit miles) Structure (e) 230.00 H 230.00 SP 138.00 SP 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 SP TOTAL 36 FERC FORM NO. 1 (ED. 12-87) Designed Type of Page 422.2 u~~ergmuniflmes Numbe Of Circuits ! un c;n~~ure 1U!J~~t.rul~~res of 'l_not er Desip;aled 1ne (g) (h) 2.65 2.04 1.16 4.84 5.88 7.75 0.33 12.50 0.09 0.29 4.96 0.10 18.78 1.87 0.34 15.78 3.36 4.08 11.63 2.86 0.03 6.43 9.80 5.08 6.44 8.63 0.18 0.71 10.48 3.21 8.09 0.16 0.22 33.05 2.91 4.94 0.06 0.95 0.09 6,205.67 691.36 2 1 1 1 1 2 1 2 1 1 2 1 1 1 1 1 2 1 2 1 1 2 1 1 2 1 2 1 1 2 1 2 1 1 1 1,594 This ~ort Is: (1) An Original (2) [lA Resubmission Name of Respondent Florida Power & Light Company Date ~~ Report (Mo, a, Yr) Year/Period of Report End of I I ; 2015/04 TRANSMISSION LINE STATISTICS (Continued)· 7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher volt ~ge lines as one line. Designate In a footnote If you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structu es support lines of the same voltage, report the pole mites of the primary structure In column (f) and the pole miles of the other line(s) In column (g) B. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If fuch property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot er than a leased line, or portion thereof, for which the respondent Is not the sole owner but which the respondent operates or shares in the operatic of, furnish a succinct statement eXplaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the ~ne, name of co-owner, basis of sharing expenses of the Line, and how the eXpenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party is an associated company. I 9. Designate any transmission line leased to another company and give name of Lessee, date and ter1s of lease, annual rent for year, and how : determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns (j) to (I) on the book cost at end of year. I ! COST OF LINE (Include in Column (j) Land, Size of Conductor and Material (i) EXPENSES, EXC$PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land 0) Construction and Other Costs (k) Total Cost Operation Expenses (m) (I) 1-1431 ACSR AZ 1-954 ACSR AZ 1-1431 ACSR AW 1-954 ACSR AZ 1-954 ACSR AZ 1-1431 ACSR AZ 1-1431 ACSRAW 1-1431 ACSRAZ tl-954 ACSR AW Maintena~ce Rents Expenset(n) i (o) Total EXpenses (p) 1 2 3 4 5 6 7 8 9 10. ' : ' ; I ~-1431 ACSRAW 1-954 ACSR AZ ' 11 12 13 : 1-954 ACSR AZ M-954 ACSR AZ 1-954 ACSR AZ M-1431 ACSR AZ 1-1431ACSRAW 1-1431 ACSRAZ 1-1431 ACSRAZ 1-1431 ACSR AZ 1-1431 ACSR AZ 1-1431 ACSR AZ 1-795 ACSR AZ 1-1431 ACSR AW 1-1431 ACSR AW 1-1431 ACSR AW 2-795 ACSR AW 1-954 ACSR AZ 1-954 ACSR AW 2-795 ACSR AZ 1-1431 ACSR AZ 1-1431 ACSRAZ -1431ACSRAZ 1-1431 ACSRAZ 1-1431ACSRAW 1-1431 ACSR AW Line No. 14 15 16 ' 17 18 _i I 19 20 21 22 ' 23 24 25 26 27 28 29 ' ' ! I 30 ! 31 32 33 . 34 35 363,243,903 FERC FORM NO. 1 (ED. 12-87) 2,298,820,876 2,662,064,779 Page 15,003,893 423.3 1a.m,93B 2,400 33,179,229 36 Name of Respondent Date of Report (Mo, Da, Yr) This 'mort Is: (1) An Original (2) EJA Resubmission Florida Power & Light Company Year/Period of Report 2015/04 End of I I TRANSMISSION LINE STATIST cs 1. Report information concerning transmission lines, cost of li~es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included In Account 121, Non utility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns {f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the fine designated. Dl::ti IGNA liON Line No. )!OlT AGE (K'Q (Indicate wliere other than 60 cycle 3 phase) LE~G~ ~~le Jriles) Type of u ~ergrouniflmes report circuit miles) Supporting 1 To From (a) (b) Operating (c) Designed Structure (e) (d) SP SP SP SP SP 1 BRIDGE PLUMOSUS 230.0( 230.00 2 BRIDGE PLUMOSUS 230.0( 230.00 3 BRIDGE TURNPIKE 230.0( 230.00 4 BROWARD DELMAR 230.0( 230.00 5 BROWARD DELMAR 230.0( 230.00 6 BROWARD FESTIVAL1 230.0( 230.00 H SP 7 BROWARD FESTIVAL 1 230.0( 230.00 8 BROWARD FESTIVAL2 230.0( 230.00 H 9 BROWARD FESTIVAL2 230.0( 230.00 10 BROWARD KIMBERLY 230.0( 230.00 H 11 BROWARD KIMBERLY 230.0( 230.00 12 BROWARD KIMBERLY 230.0( 230.00 13 BROWARD SUGAR-YAMATO 230.0C 230.00 H 14 BROWARD SUGAR-YAMATO 230.0C 230.00 H 15 BROWARD SUGAR-YAMATO 230.0( 230.00 16 BROWARD SUGAR-YAMATO 230.0( 230.00 17 BROWARD SUGAR-YAMATO 230.0( 230.00 18 BROWARD SUGAR-YAMATO 230.0( 230.00 19 BUNNELL PELLICER 230.0( 230.00 20 BUNNELL PELLICER 230.0( 230.00 21 BUNNELL PUTNAM 230.0C 22 BUNNELL VOL USIA 230.0C 23 BUNNELL VOLUSIA 230.0C SP SP SP SP SP SP SP SP {h) 0.15 1 2.59 1 18.92 1 724 1 2.46 1 0.25 2 1.00 4.78 2 0.25 2 1.00 2 10.81 2 6.12 2 0.07 1 31.01 2 8.20 2 12.89 5.30 1 1.82 0.16 2 2 0.15 2 1 2 230.00 H 27.12 1 230.00 H 17.82 1 0.61 1 4.45 1 20.33 1 VOLUSIA 230.0C CHARLOTTE 230.0C 26 CALUSA CHARLOTTE 230.0C 27 CAL USA FT MYERS PLANT 1 230.0( 28 CAL USA FT MYERS PLANT 1 230.0( 29 CALUSA FT MYERS PLANT 2 230.0( 30 CALUSA FT MYERS PLANT 2 230.00 31 CALUSA LEE 1 230.00 230.00 H 32 CAL USA LEE 1 230.00 33 CAL USA LEE 1 230.0C 230,0( 34 CALUSA LEE2 230.0C 230.00 35 CAL USA LEE2 230.0( 230.00 230.00 230.00 SP SP SP SP TOTAL 422.4 L1ne (g) Circuits 3.97 25 CALUSA Page o{ Lme Des1fDated Of unf~tr~1J.~res o ATJo er 12.55 24 BUNNELL FERC FORM NO. 1 (ED. 12-87) ~tfl:lctUre SP SP 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 SP 36 un Number 0.37 1 1.12 2 0.31 2 0.47 2 0.96 2 9.13 1 0.98 1 0.90 2 1 10.08 6,205.67 0.91 2 691.36 1,594 This ~art Is: (1) An Original (2) EJA Resubmission Name of Respondent Florida Power & Light Company Year/Period of Report Date of ReiJort {Mo, Dp. Yr) I I RANSMISSION LINE STATISTICS (Continued) End of 2015/Q4 i 7. Do not report the same transmission line structure twice. R;eport Lower voltage Lines and higher volt~ge lines as one line. Designate in a footnote if you do not Include Lower voltage lines with higher voltage lines. If two or more transmission line structur~s support lines of the same voltage, report the I pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If srh property Is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line oth r than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details} of such matters as percent ownership by respondent in the li~e, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts a acted. Specify whether lessor, co-owner, or other party Is an associated company. I 9. Designate any transmission line leased to another company and give name of Lessee, date and term$ of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. ! I 10. Base the plant cost f~gures called for in columns G) to (I) on the book cost at end of year. ! i i COST OF LINE (Include In Column (j) Land, Size of Conductor and Material (I) EXPENSES, EXC~PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way} Land 0) Construction and Other Costs (k) Operation Expenses (m) Total Cost (I) Maintenaf Expense (n} • Rents Total Expenses (p) (o} 1 1-1431 ACSR TW ~-795 ACSR AW 1-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSRAZ 1-1431 ACSR AZ 1-1431 ACSRAW 1-1431 ACSRAZ 1-1431 ACSR AW 1-1431 ACSRAZ 1-1431 ACSRAW 1-1431 ACSRAZ 1 2 3 4 5 6 7 8 I 1 i ! I I 9 ! . Line No. ' ' 10 11 12 13 14 15 16 -1431 ACSRAZ 1-1431 ACSR TW -1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSR AZ i 17 18 19 -1431 ACSR TW n-1431 ACSR AW 1-1431 ACSRAW 1-954 ACSR AZ -954 ACSR AZ 20 n ; 21 : 22 ~-954 ACSR AW M-954 ACSR AZ ~-556.5 ACSR AZ 12-795 ACSR AW -1431 ACSRAW 12-556.5 ACSR AZ 23 24 25 I 26 27 28 I ! 1-1431 ACSR AW 12-556.5 ACSR AZ 1-1272ACSRAW ! 29 I 30 31 32 33 ! 1·1272 ACSR AW 1-1272 ACSR AW 1-1780 ACSRTW 1-1780 ACSRTW ! 34 ! 35 363,243,903 FERC FORM NO. 1 (ED. 12-87) 2,298,820,876 2,662,064,779 Page 15,003,893 423.4 18,1172,936 2,400 33,179,22! 36 Name of Respondent This (1) (2) Florida Power & Light Company wort Date of Report (Mo, Da, Yr) Is: An Original []A Resubmission Year/Period of Report End of I I 2015/04 TRANSMISSION LINE STATIST CS 1. Report Information concerning transmission lines, cost of lil)es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a S1ate commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Non utility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole mites of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. To (b) From (a) 1 2 3 4 \f,~_ET~GE.JJS_y) (Indicate wliere other than 60 cycle 3 phase) DESIGNATION Line No. CAPE CANAVERAL INDIAN RIVER (OUC) 1 CAPE CANAVERAL INDIAN RIVER (OUC) 1 CAPE CANAVERAL INDIAN RIVER (DUG) 2 CAPE CANAVERAL BIG BEND (TEC) 6 CASTLE BIG BEND (TEC) 7 CASTLE 8 CASTLE BIG BEND (TEC) 9 CASTLE BIG BEND (TEC) RINGLING CASTLE RINGLING CASTLE RINGLING RINGLING CASTLE CASTLE RINGLING CEDAR CORBETT CEDAR CORBETT CEDAR CORBETT CEDAR CORBETT CEDAR CORBETT CEDAR DELTRAIL CEDAR DELTRAIL FOUNTAIN CEDAR CEDAR 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230,0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0< 230.0( 230.0[ 230.0< 230.0( 230.0[ INDIAN RIVER (OUC) 2 5 CASTLE 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 Operating (c) CEDAR CEDAR FOUNTAIN RANCH RANCH CEDAR RANCH CEDAR RANCH CHARLOTTE FT MYERS PLANT 1 CHARLOTTE CHARLOTTE FT MYERS PLANT 1 CHARLOTTE FT MYERS PLANT 1 FT MYERS PLANT 1 CHARLOTTE CHARLOTTE CHARLOTTE FT MYERS PLANT 2 FT MYERS PLANT 2 CHARLOTTE FT MYERS PLANT 2 CHARLOTTE PEACHLAND FT MYERS PLANT 2 FERC FORM N0.1 (ED. 12-87) Supporting 1 Designed Structure (e) (d) 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230,00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 H SP SP SP H H SP SP H SP SP SP SP H H SP SP SP H SP SP SP H Page 422.5 un ~t[l,lcture of,L1n~ Des1ftla ed H SP SP SP H H SP SP H Number Of I unf~rt[Ures of I)Other me (g) 0.71 1.59 0.70 1.59 5.44 3.63 13.25 3.89 0.07 0.06 9.71 1.03 0.16 5.87 8.49 9.88 (h) 2 2 1 2 1 1 1 1 1 1 2 1 2 2 1 2 1 0.17 0.05 5.58 1.57 5.54 0.21 5.95 0.27 9.02 0.55 0.19 19.04 2.37 12.03 0.03 0.18 10.62 4.71 6,205.67 Circuits 1 3.15 H SP SP TOTAL 36 LE~Gtf!1 role miles) lot e a~ of u i'!ergroun hnes report circuit miles) Type of 691.36 1 1 1 1 1 2 1 2 1 1 2 1 1 1 1 1 1 1,594 Date~R~ort This ~ort Is: (1) An Original (2) flA Resubmission Name of Respondent Florida Power & Light Company (Mo, I I TRANSMISSION LINE STATISTICS (Continued) a, Year/Period of Report 2015/04 End of r) I I 7.. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltte lines as one line. Designate in a footnote if you do not Include Lower voltage lines with higher voltage lines. If two or more transmission line structur s support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If tech property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot er than a leased line, or portion thereof, for 1 wh'h the ~poodeol 0 oollhe Mle - • • bot wh•h the ""'"""""' "'""'"' " '"''" ;, the """""'"" ~fuml•h e '""''" otatement ""''""'• the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the li e, name of co-owner, basis of sharing ed. Specify whether lessor, co-owner, or expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts a other party is an associated company. ; 9. Designate any transmission line leased to another company and give name of Lessee, date and termt of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. , 10. Base the plant cost figures called for In columns (j) to (I) on the book cost at end of year. ! i COST OF LINE (Include in Column (j) Land, Size of Conductor and Material (i) EXPENSES, EXCEjPT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land (j) Construction and Other Costs (k) Total Cost Operation Expenses (m) (I) 1-954 ACSSHS AW 1-954 ACSSHS AW Maintenanpe Expense~ (n) I Rents Total Expenses (p) (o) 1 2 ; i 1 1-954 ACSSHS AW 1-954 ACSSHS AW 1-954 ACSR AW 3 4 5 ! 1-954 ACSR Al -954ACSRAW -954ACSRAZ 1-954ACSRAW 6 7 i 8 9 10 i i 1-1431 ACSRAZ 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR Al 1-1431 ACSR AZ 11 12 13 14 15 i l 1-1431 ACSR TW 1-1431 ACSR AW 1-1431 ACSR AW -1431 ACSR TW I I 16 17 I 18 i 1-1431 ACSRAZ 19 20 21 ! ~-1431 ACSR AZ 1-1431 ACSRAW 1-1431 ACSR TW 1-1431 ACSR AZ 1-1431 ACSR AZ 1-1431 ACSRAW 1-1431 ACSR AZ 1-954 ACSR AZ 1-1431 ACSRAW 1-1431 ACSR AW 1-954 ACSR AZ 1-1431 ACSRAZ 1-4x4x5116 IWCB 1-1431 ACSR AW 1-1431 ACSR AZ 1-1431 ACSRAZ Line No. ' I 22 23 24 25 26 27 i ! i 28 29 30 ' i I 31 ! 32 33 34 35 363,243,903 FERC FORM NO. 1 (ED. 12-87) 2,298,820,876 2,662,064,779 Page 15,003,893 423.5 18,1f2,936 2,400 33,179,22[ 36 Name of Respondent Date of Report {Mo, Da, Yr) This wort Is: {1) An Original {2) EJA Resubmission Florida Power & Light Company Year/Period of Report End of I I 2015/04 TRANSMISSION LINE STATISTICS 1. Report information concerning transmission lines, cost of ll~es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines Include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; {2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. From (a) 1 2 3 4 5 22 23 24 25 26 27 28 29 30 31 32 33 34 35 To {b) CHARLOTTE PEACHLAND CHARLOTTE PEACHLAND CHARLOTTE SADDLEWOOD CHARLOTTE SADDLEWOOD CHARLOTTE 6 CHARLOTTE 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 VOJT~~E.J~~ {Indicate wliere other than 60 cycle 3 phase} uESIGNATION Line No. Operating (c) 230.0( 230,0[ 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.0( 230.0( 230.0( 230.0C 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0C 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0C 230.0( 230.0( SADDLEWOOD VANDOLAH (DEF) CHARLOTTE WHIDDEN 1 CLINTMOORE DELMAR CLINTMOORE DELMAR CLINTMOORE YAMATO CLINTMOORE YAMATO CLINTMOORE YAMATO COAST PEACHLAND COLLIER ORANGE RIVER 1 COLLIER ORANGE RIVER 1 COLLIER ORANGE RIVER 2 COLLIER TERRY COLLIER TERRY COLLIER TERRY CONSERVATION FESTIVAL CONSERVATION FESTIVAL CONSERVATION FESTIVAL CONSERVATION CONSERVATION MALLARD MALLARD CONSERVATION MALLARD CONSERVATION MOTOROLA CONSERVATION MOTOROLA CONSERVATION NOB HILL CONSERVATION NOB HILL CONSERVATION OAKLAND PARK CONSERVATION OAKLAND PARK CORBETT PINEWOOD CORBETT PINEWOOD CORBETT PINEWOOD CORBETT PINEWOOD FERC FORM NO. 1 (ED. 12-87) Page 422.6 t e asJ' hnes of u ~d1ergroun report circuit miles) Supporting un Designed Structure (e) (d) 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 SP SP H SP SP SP SP SP SP H SP SP SP SP SP SP H H SP H SP SP H ~tp,Jcture of,L1ne Des1[t)ated 0.1ole miles) Type of 1 Number Of un,qt~!_mres of Jtno er 1ne (g) Circuits (h) 1 1 1 1 2 1 1 1 1 1 1 1 1 1 2 1 1 2 1 3.59 0.50 5.51 0.31 1.27 4.91 4.15 1.21 8.08 11.53 0.06 8.46 2 1 2 1 2 2 2 1 1 2 1 2 1 2 1 3.28 2.05 9.11 2 6,205.67 691.36 1,594 Date ~~ Report {Mo, a, Yr.) This ~ort Is: An Original []A Resubmisslon Name of Respondent .{1) {2) Florida Power & Light Company I I Year/Period of Report End of :I 2015fQ4 TRANSMISSION LINE STATISTICS (Continued). 7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher vol;~e lines as one line. Designate In a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structu~ s support lines of the same voltage, report the ! pole miles of the primary structure in column {f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If ~uch property is leased from another company, give name of lessor, date and terms of Lease, and amount of ffint for year. For any transmission line ot er than a leased line, or portion theffiof, for which the respondent is not the sole owner but which the respondent operates or shares in the operatlon~f, fum ish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent In the li e, name of co-owner, basis of sharing expenses of the Line, and how the expenses bome by the respondent are accounted for, and accounts a ectad. Specify whether lessor, co-owner, or other party is an associated company. ! 9. Designate any transmission line leased to another company and give name of lessee, date and term~ of lease, annual rent for year, and how I determined. Specify whether lessee is an associated company. I I 10. Base the plant cost figures called for in columns 0) to (I) on the book cost at end of year. ' I t;U::> 1 ut- LINt: (InClude 1n Column 0) lana, Size of Conductor and Material (i) EXPENSES, EXCE\PT DEPRECIATION AND TAXES I Land rights, and clearing right-of-way) I Land 0) Construction and Other Costs (k) Operation Expenses (m) Total Cost (I) ~-1431 ACSRAW Maintena~fe Expense (n) ; Total Expenses (p) Rents (o) 1 2 3 4 i ~-1431 ACSRAZ 1-2156ACSR ' ~-2156ACSR I Line No. 1-2156 ACSR ! 5 ~-795 ACSR AW I 6 ~-954 ACSR AW I 1-1431 ACSR AW 1-1431 ACSR AZ 1-1431 ACSR AZ 1-1431 ACSR AW 1-1431 ACSRAZ 1-954 ACSR AW 1-1431 ACSR AW 1-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSR AZ 1-1431 ACSR AZ 1-1431 ACSRAW 1-1431 ACSRAZ 1-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSR AZ 1-1431 ACSR AZ 1-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSRAZ i-1431 ACSR AW 1-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSR AW 1-1431 ACSR TW 1-1431 ACSR TW 1-1431 ACSRAW 1-1431 ACSRAW 7 8 9 I 10 11 12 ' ~ 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 I i i I I I ! I 34 ' 35 363,243,903 FERC FORM NO. 1 {ED. 12-87) 2,298,820,876 2,662,064,779 Page 15,003,893 423.6 18,1~2,936 2,400 33,179,22~ 36 Name of Respondent Date of Report (Mo. Da, Yr) This '[!]art Is: (1) An Original (2) EJA Resubmisslon Florida Power & Light Company Year/Period of Report End of I I TRANSMISSION LINE STATIST 2015/Q4 cs 1. Report information concerning transmission lines, cost of lifleS, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages In group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual iines for all voltages if so required by a State commission. 4. Exclude from this page any transmission fines for which plant costs are included in Account 121, Nonutillty Property. 5. Indicate whether the type of supporting structure reported In column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. DE:>IGNATIUN Line No. ~~dl~~~~~~ LE~G~~ ~~le b?iles) Type of other than 60 cycle 3 phase) 1 To (b) From (a) 1 CORBETT PINEWOOD 2 CORBETT PINEWOOD 3 CORBETT 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 CORBETT RANCH 1 RANCH 1 CORBETT RANCH 1 CORBETT RANCH 1 CORBETT SUGAR CORTEZ JOHNSON CORTEZ JOHNSON DADE DORAL DADE DORAL DADE DORAL DADE DORAL DADE GRATIGNY DADE GRATIGNY DADE GRATIGNY DADE LEVEE 1 DADE LEVEE 1 DADE LEVEE 1 DADE LEVEE 1 22 DADE LEVEE 1 LEVEE 2 24 25 26 27 28 29 30 31 DADE 230.0( 230.0( 230.0( 230.0C 230.00 230.00 230.0C 230.0C 230.0( 230.0( 230.0( 230.0C 230.0C 230.0C 230.0C 230.0 230.0 230.0 230.0C 230.0 230.0 230.0 230.0( 230.0C 230.00 230.00 230.0 230.0( 230.0 230.00 230.00 230.0C 230.0( 230.0C 230.0C RANCH 1 CORBETT 23 DADE Operating (c) LEVEE2 DADE LEVEE2 DADE LEVEE 2 DADE LEVEE 3 DADE MIAMI SHORES DADE MIAMI SHORES DADE MIAMI SHORES DADE OVERTOWN 32 DADE OVERTOWN 33 DADE 34 DAVIS 35 DAVIS OVERTOWN LEVEE 1 LEVEE 1 (d) Structure (e) 230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 H TOTAL 36 FERC FORM NO. 1 (ED. 12-87) Designed Page 422.7 Number u ~ergrounifllnes report circuit miles) Supporting un ~tp;~cture of Line Deslp;ated Of Circuits v~V~lf!,th~res of not er Line (g) (h) 1 1 2 1 1 2 1 1 1 1 1 2 1 1 1 2 1 1 1 2 1 1 1 2 1 1 1 2 1 7.74 023 3.77 0.27 2.94 0.52 0.05 1.27 0.04 10.75 0.10 1.50 0.83 0.57 2.67 0.44 0.88 0.04 0.09 2.71 4.64 0.10 0.11 6.88 0.85 1.37 9.03 0.44 0.06 8.61 1.57 7.71 0.01 0.14 1.06 12.33 1 2 1 1 2 6,205.67 691.36 1,594 4.73 5.03 1 Name of Respondent Date ~f Report (Mo, a, Yr) This [!Jort Is: (1) An Original (2) EJA Resubmission Florida Power & Light Company I I Year/Period of Report 2015/04 End of i RANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. ~eport Lower voltage Lines and higher volt ~ge lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structu es support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. lf~uch property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line o er than a leased line, or portion thereof, for which the ~poodeot I• oot the oole .,.,., b"' wt;oh the ~poodoot ope- " . , _ lo the ope~t•~ of, fumi•h • '""''"' -moot ""'""''' .,. arrangement and giving particulars (details) of such matters as percent ownership by respondent in the I ne, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party Is an associated company. : 9. Designate any transmission line leased to another company and give name of Lessee, date and termf of lease, annual rent for year, and how : determined. Specify whether lessee Is an associated company. I 10. Base the plant cost figures called for In columns {j) to (I) on the book cost at end of year. ! i : COST OF LINE (Include Ill L:olurnn {J) Land, Size of Conductor and Material (i) EXPENSES, EXC$PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) . i Land G) Construction and Other Costs (k) Total Cost Operation Expenses (m) (I) 1-1431 ACSRAZ 1-1431 ACSRTW 1-1431 ACSR TW 1-1431 ACSRAW 1-1431 ACSRTW 1-1431 ACSR TW 1-954 ACSR AW 2-954 ACSR AW 1-954 ACSR AW 1-954ACSRAW 1-1431 ACSR f-Z 1-1431 ACSRAZ Maintena_1ce Expenset (n) Rents Total Expenses (p) (o) 1 2 3 i : 4 5 6 7 8 9 10 11 12 13 14 15 16 17 ! ! I i : I ?-556.5 ACSR AZ 1-1431 ACSR AZ 1-1431 ACSR AZ 1-1431 ACSRAZ 1-1431 ACSR AZ 1-1431 ACSR AW 1-1431 ACSR AZ 1-1431 ACSR AZ 1-1431 ACSR AW 1-1431 ACSR f-Z 1-1431 ACSRAZ 1-1431 ACSR AZ 2-556.5 ACSR AZ 1-1431 ACSRAZ 2-954ACSR AW 1-1431 ACSR AZ 1-1431 ACSRAW 1-1431 ACSR AZ 1-1431 ACSR AW 1-1431 ACSR AW 1-1431 ACSRAZ 1-1431 ACSR AZ 1-1431 ACSRAZ Line No. I I 18 I 19 20 I 21 22 I 23 24 25 26 27 I 28 I 29 30 31 32 33 34 35 i 363,243,903 FERC FORM NO. 1 (ED. 12-87) 2,296,820,876 2,662,064,779 Page 15,003,893 423.7 18,172,936 2,400 33,179,22t 36 This ~ort Is: (1) An Original (2) [JA Resubmission Name of Respondent Florida Power & Light Company Date of Report {Mo, Da, Yr) I I TRANSMISSION LINE STATIST Year/Period of Report End of 2015/Q4 cs 1. Report Information concerning transmission lines, cost of lil)eS, and expenses for year. list each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Non utility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the Una. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on struc:!ures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. DESIGNATION Line No. VOLTAGE (KV) (Indicate wtiere other than 60 cycle 3 phase) To (b) From (a) DAVIS LEVEE 1 DAVlS LEVEE 2 DAVIS LEVEE 2 DAVIS TURKEY POINT 1 DAVIS TURKEY POINT 1 DAVIS TURKEY POINT 1 DAVIS TURKEY POINT 2 DAVIS TURKEY POINT 2 9 DAVIS TURKEY POINT 3 10 DAVIS TURKEY POINT 3 11 12 13 14 15 16 17 18 DELTRAIL YAMATO DELTRAIL YAMATO DORAL (RRDC) DADE RES RCVRY (DADE 1 2 3 4 5 6 7 8 DUVAL BRANDY BRANCH (JEA) 1 DUVAL BRANDY BRANCH (JEA) 1 DUVAL BRANDY BRANCH (JEA) 2 DUVAL BRANDY BRANCH (JEA) 2 DWAL BRANDY BRANCH (JEA) 3 19 DUVAL BRANDY BRANCH (JEA) 3 20 21 22 23 24 25 DWAL JACKSONVILLE HEIGHTS DUVAL JACKSONVILLE HEIGHTS DUVAL KINGSLAND (GAP) DUVAL KINGSLAND (GAP) DUVAL KINGSLAND (GAP) DUVAL KINGSLAND (GAP) 26 DUVAL 27 DUVAL KINGSLAND (GAP) 28 29 30 31 32 33 34 35 SPRiNGBANK DUVAL Operating (c) 230.0C 230.0C 230.00 230.00 230.00 230.00 230.00 230.DC 230.0C 230.0C 230.0C 23D.OC 230.0( 230.0( 230.0( 230.0( 230.00 230.00 230.0C 230.0[ 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.DC 230.0( 230.0( 230.0( 230.()( 230.0( 230.0( SPRINGBANK DUVAL SPRINGBANK EMERSON TREASURE EMERSON TREASURE EMERSON TREASURE EMERSON TREASURE FESTIVAL MALLARD FESTIVAL MALLARD Supporting Designed (d) Structure {e) 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 H 230.00 H 230.00 H 230.00 H 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 H TOTAL 36 FERC FORM NO. 1 (ED. 12-87) Type of Page 422.8 LENG~ ~ole wiles) e uh~t ergroun lines report circuit mites) S tha re•po"ole wiles) t e ascr lines 0 uhi&,ergroun report circuit miles) Supporting : un !::!:lfl:lctUre . unt~~!fWes o I)O er of Lin~ Structure me Desift)a ed (e) (g) Type of Page 422.10 2 1 1 1 -· 2 1 1 26.18 1 1 1 2 2 1 1 1 1 1 2 1 1 1 2 1 1 1 1 1 2 1 1 0.81 2 2 1 691.36 1,594 0.10 0.05 6,205.67 (h) 1 2 0.25 3.58 0.39 0.09 10.53 4.36 3.15 0.65 9.15 1.91 9.72 0.18 13.37 23.47 0.06 9.16 0.72 3.35 8.51 16.83 Number Of Circuits 3f This ~ort Is: (1) An Original {2) A Resubmission Name of Respondent Florida Power & Light Company Year/Period of Report Date Report (Mo, ,a, Yr) 0 End of I I TRANSMISSION LINE STATISTICS (Continued) 2015/04 i 7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher volt~ge lines as one line. Designate in a footnote if you do not Include Lower voltage lines with higher voltage lines. If two or more transmission line structuies support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) , 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If ~uch property is leased from another company, T' of"'"'· gl~ oomo date ond tern" of""""· ood omooot of reo! foe-· Foc ooy bom•"'"'"' Uoe lhoo • •~• lloe, "port;oo thereof, foe which the respondent Is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the I ne, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and term~ of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. i 10. Base the plant cost figures called for in columns 0) to (I) on the book cost at end of year. L;U:S 1 Size of Conductor and Malarial (i) ut- LINt: tlnclude 1n Column (j) Land, EXPENSES, EXCI$PT DEPRECIATION AND TAXES I Land rights, and clearing right-of-way) ' Land 0) Construction and Other Costs (k} Total Cost Operation Expenses {m) {I) Maintenate Expense (n) i 1-1431 ACSR TW 1-1431ACSRTW 1-1431 ACSRAW 1-1431 ACSR AZ 1-900 CU HT 1-1431 ACSRAW 1-1431 ACSR AW 1-1431 ACSRAW Rents Total Expenses (p) (o) Line No. 1 2 3 4 5 6 ! ! ' 7 8 9 10 11 12 13 14 15 : 1-3000 AL-HP 1-3750 AL-HP 1-1431 ACSR AZ 1-900 CU HT 1-900 CU HT 1-1431 ACSRAW 1-1431 ACSRTW 1-1431 ACSRAW i ! ' i 16 ' 1-1431 ACSR TW 1-1431 ACSRAW -1431 ACSRTW 1-1431 ACSRTW 1-954 ACSR AW 2-795 ACSR AW 2-795 ACSR AW 2-795 ACSR AW ?-795 ACSR AW 2-954 ACSR AZ ?-954 ACSR AW 2-954 ACSR AZ 1-1431 ACSRAW 1-1431 ACSRAW 2-795 ACSR AW ?-1431 ACSR AZ 2-1431 ACSRAZ 2-1431 ACSRAW 2-1431 ACSR AZ 17 18 19 20 21 22 23 i ! ! I I ! 24 25 26 27 28 29 I I I ' 30 I' 31 32 33 i 34 35 363,243,903 FERC FORM NO. 1 (ED- 12-87} 2,298,820,876 2,662,064,779 Page 15,003,893 423.10 18, ~72,936 I I --1- 2,400 33,179,22!: 36 This ~art Is: (1) An Original (2) (]A Resubmission Name of Respondent Florida Power & Light Company Date of Report {Mo, Da, Yr) I I Year/Period of Report End of 2015/04 TRANSMISSION LINE STATIST CS 1. Report information concerning transmission lines, cost of liQes, and expenses for year. List ·each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages In group totals only for each voltage. 2. Transmission lines Include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are Included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported In column {e) is: {1) single pole wood or steel; {2) H-frame wood, or steel poles; {3) tower; or {4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column {f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. 1 JOHNSON 2 JOHNSON 3 JOHNSON 4 JOHNSON 5 KEENTOWN 6 KEENTOWN 7 KEENTOWN 8 KEENTOWN 9 KEENTOWN 10 KIMBERLY 11 KIMBERLY 12 KIMBERLY 13 KORONA 14 KORONA 15 KORONA 16 KORONA 17 KORONA 18 KORONA 19 KORONA 20 KORONA 21 LAUDANIA 22 LAUDANIA 23 LAUDANIA 24 LAUDERDALE 25 LAUDERDALE 26 LAUDERDALE 27 LAUDERDALE 28 LAUDERDALE 29 LAUDERDALE 30 LAUDERDALE 31 LAUDERDALE 32 LAUDERDALE 33 LAUDERDALE 34 LAURELWOOD LAURELWOOD (KV) (Indicate wtiere other than 60 cvcle 3 ohase) To (b) From {a) 35 Y,O~ T~GE DESIGNATION Line No. Operating (c) MOTOROLA 230.00 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0< 230.0< 230.0( 230.0( 230.0( 230.0< 230.0C 230.0C 230.0( 230.0( 230.0( 230.0( 230.0< 230.0< 230.0( 230.0( 230.0( 230.0C 230.0( PINEWOOD 230.0( PINEWOOD 230.0( 230.0( 230.0( 230.0C 230.0C 230.0( 230.0( 230.0( MANATEE RINGLING RINGLING RINGLING MANATEE MANATEE WHIDDEN WHIDDEN WHIDDEN RANCH RANCH RANCH PUTNAM PUTNAM PUTNAM VOLUSIA VOLUSIA VOLUSIA VOLUSIA VOLUSIA LAUDERDALE LAUDERDALE PORT EVERGLADES MOTOROLA MOTOROLA PINEWOOD PINEWOOD PINEWOOD PORT EVERGLADES 1 PORT EVERGLADES 1 MYAKKA MYAKKA Supporting Designed (d) Structure {e) 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 SP TOTAL 36 FERC FORM NO. 1 (ED. 12-87) Type of Page 422.11 LE~~~~ ~~le Jriles) u aergrounWI!nes report circuit miles) un ~t['t~~ure Desir;ated 1 U!VJ{r~~~res o IJO er L1ne (g) 2 1 2 2 1 1 1 0.31 13.24 20.16 0.08 32.98 0.05 0.77 16.22 0.05 0.09 0.08 0.12 4.45 0.42 2.65 0.46 0.12 7.74 19.63 1.02 1.49 0.06 1 2 1 2 1 1 1 1 1 1 1 2 1 1 1 1 1 1 1 1 2 1 1.45 2 1 1 1 1 1 691.36 1,594 4.29 4.45 3.05 0.08 16.75 6,205.67 Circuits (h) 0.08 8.87 0.81 0.14 16.19 3.05 24.43 0.61 0.21 Number Of qf This ~ort Is: (1) An Original (2) EJA Resubmission Name of Respondent Florida Power & Light Company Year/Period of Report Date ReP.ort (Mo, a, Yr) End of 2015/Q4 "I TRANSMISSION LINE STATISTICS (Continued) · ~aport lower voltage Lines and higher volt ge lines as one line. Designate In a footnote if you do not include lower voltage lines with higher voltage lines. If two or more transmission line structur~s support lines of the same voltage, report the pole miles of the primary structure In column (f) and the pole miles of the other line(s) in column (g) 7. Do not report the same transmission line structure twice. 1•• oc portloo thernof fa' wh;oh the ~pood~t '' oot the oole - • • · ff ~oh prnperty r. """"' from eoothe• oompooy, 6. Des;gmrte ooy "'"'""""'"" give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot er than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the li e, name of co-owner, basis of sharing ectad. Specify whether lessor, co-owner, or expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts other party is an associated company. . 9. Designate any transmission line leased to another company and give name of Lessee, date and termr of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns (j} to (I) on the book cost at end of year. ! I COST OF LINE (lnc1uae Size of Conductor and Material (i) I m t.;Oiumn (j) Land, EXPENSES, EXC~PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) i ! Land G) Construction and Other Costs (k) Total Cost Operation Expenses {m) (I) 2-1431 ACSRAZ 2-1431 ACSRAZ 2-1431 ACSRAZ ~-795 ACSR AW 1-1431 ACSRAZ ~-1431 ACSR AZ 1-1431 ACSRAZ 1-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSRAZ 1-1431 ACSRAZ 1-1431 ACSRAZ 1-954 ACSR AZ 1-1431 ACSRAW 1-954 ACSR AZ Maintenanr Expense (n) . Total Expenses (p) Rents {o) 1 2 3 4 5 i I I I 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 26 ~-954 ACSR AZ ~-1431 ACSRAW 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AZ 1-1431 ACSRAZ 1-900 CU HT 1-900 CU HT 1-1431 ACSRAZ 1-1431 ACSR AW 1-1431 ACSRAZ 1-1431 ACSRAZ 1-1431 ACSR AZ ~-1431 ACSRAW ~-1431 ACSR AW r-1431 ACSRAZ 1-1431 ACSRAZ 1-900CU HT 1-1431 ACSRAW 1-1431 ACSR AZ Line No. I ! ! i 29 I 30 31 32 33 34 35 ! i i 363,243,903 FERC FORM NO. 1 {ED. 12-87) 2,298,820,876 2,662,064,779 Page 15,003,893 423.11 18,1f2,936 2,400 33,179,22l: 36 This ~ort Is: (1) An Original {2) EJA Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) Year/Period of Report End of I I 2015/Q4 TRANSMISSION LINE STATIST CS 1. Report information concerning transmission lines, cost of li~es. and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Non utility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. Y,OL~AGE {~(,:'!:) DESIGNATION Line No. LE~GJ;~ ra~le Jriles) Type of (Indicate wtiere other than 60 cycle 3 phase) 1 From (a) To (b) 1 LAURELWOOD PEACHLAND 2 LAURELWOOD PEACHLAND 3 LAURELWOOD 4 LAURELWOOD PEACHLAND 5 LAURELWOOD RINGLING 1 6 LEE 7 LEE 8 LEVEE SADDLEWOOD TURKEY POINT 9 LEVEE TURKEY POINT 230.0C 230.0C 230.0C 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0C 230.0C 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0( 230.0C 230.00 230.0C 230.0 230.0 230.0 230.0( 230.0( 230.0( 230.01 230.01 230.01 230.0( SADDLEWOOD TURKEY POINT 11 12 13 14 15 16 17 18 19 20 21 22 23 LEVEE TURKEY POINT LINDGREN PENNSUCO LINDGREN PENNSUCO 24 25 26 27 28 29 30 31 32 33 34 35 230.0( 230.0( 230.0( RINGLING 1 10 LEVEE LINDGREN PENNSUCO LINDGREN TURKEY POINT LINDGREN TURKEY POINT LINDGREN TURKEY POINT MAGNOLIA Operating (c) -· MAGNOLIA SANFORD PLANT SANFORD PLANT MAGNOLIA SANFORD PLANT MAGNOLIA SANFORD PLANT MAGNOLIA MAGNOLIA SANFORD PLANT SANFORD PLANT MAGNOLIA VOL USIA MAGNOLIA VOLUSIA MAGNOLIA VOLUSIA MALABAR MIDWAY MALABAR MIDWAY MALABAR MIDWAY MANATEE BIG BEND (TEC) 1 MANATEE BIG BEND (TEC) 2 MANATEE BIG BEND (TEC) 2 MANATEE BIG BEND (TEC} 2 MANATEE RINGLING 2 MANATEE RINGLING 2 (d) Structure (e) 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 H 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 H TOTAL 36 FERC FORM NO. 1 (ED. 12-87) Designed Page 422.12 Number Of u ~ergrouniflmes report circuit miles} Supporting un ~tp,acture of.L1n~d 0 es1ft)a 1 u~f~~:fJWes o no er me (g) (h) 0.42 4.17 21.34 20.99 0.06 3.11 8.74 1.18 12.53 18.28 0.10 3.16 1 2 1 1 1 1 2 1 2 2 1 12.53 0.01 0.06 4.24 18.29 26.21 0.42 0.54 5.40 0.30 0.57 5.72 0.52 1 2 1 1 2 2 1 2 1 2 1 1 1 5.40 54.43 0.16 0.04 10.07 0.12 9.93 24.27 6,205.67 Circuits 1 2 1 1 1 1 1 2 2 1 1.50 2 691.36 1,594 9a This ~ort Is: (1) An Original (2) [JA Resubmisslon Name of Respondent Florida Power & Light Company Year/Period of Report Report Date (Mo, a, Yr) I I End of 2015/Q4 i TRANSMISSION LINE STATISTICS (Continued) ' 7. Do not report the same transmission line struclure twice. Report Lower voltage Lines and higher voltte lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structu~ pole miles of the primary structure in column (f) and the pole mnes of the other line(s) in column (g) support lines of the same voltage, report the 6. ""''"''' ony t~o.ml"""'" ''"' " portloo '"''"" '" whlcl> tho "'""'""""' 0 ""' tho M~ ~~. If ~"' pm- I• ''""" fmm '"''""' oompooy, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot r than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the li e, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts a acted. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and termt of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. . 10. Base the plant cost figures called for in columns G) to (I) on the book cost at end of year. I ! i COST OF LINE (Include 1n Column (j} Land, Size of Conductor and Material (i) EXPENSES, Land rights, and clearing right-of-way) Land Construction and other Costs (j) (k) EXC~PT DEPRECIATION AND TAXES ! Total Cost Operation Expenses (m) {I) Maintenan re Expensel {n) Rents Total Expenses (P) (o) i 1-1431ACSRAW 1-1431 ACSRAW 1-1431 ACSRAZ 1-1431 ACSRAZ 1-1431 ACSR AZ 1 2. 3 4 5 6 I ' i 1-2156 ACSR 1-2156 ACSS TW 1-1431 ACSR AZ 1-1431 ACSRAZ 1-1691 MAC 1-1431 ACSRAZ 1-1431 ACSRAZ 1-1431 ACSRAZ 1-1431 ACSRAW 1-1431 ACSR AZ 1-1431 ACSR AZ 1-1691 AAAC 1-954 ACSR AZ 1-954 ACSR AZ 1-1431 ACSRAW -1431 ACSRAW 1-954ACSRAW 1-954 ACSR AZ 1-954 ACSR AZ 1-1431 ACSRAW 1-1431 ACSR AW 1-795 ACSR AZ 1-1431 ACSR AW 1-795 ACSR AW ~-795 ACSR AZ ~-795 ACSR AZ ~-1431 ACSR AZ ~-795 ACSR AZ 2-1431 ACSRAZ ~-1431 ACSRAZ Line No. 7 8 9 10 11 12 13 14 I I i 15 16 17 18 19 2.0 2.1 22 2.3 24 25 26 27 2.8 2.9 30 31 32 33 34 l I i I ' I i 35 I 363,243,903 FERC FORM N0.1 (ED. 12-87) 2,298 ,82.0 ,876 2,662,004,779 Page 15,003,893 423.12 18,1p,936 2,400 33,179,22~ 36 This ~ort Is: (1) An Original a, Yr) This ~ort Is: {1) An Original {2) EJA Resubmission Name of Respondent Florida Power & Light Company II Year/Period of Report 2015/04 End of j RANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. ~eport Lower voltage Lines and higher volt~ge lines as one line. Designate in a footnote if you do not Include Lower voltage lines with higher voltage lines. If two or more transmission line structurs support lines of the same voltage, report the. pole miles of the primary structure In column (f) and the pole miles of the other line(s) in column {g) 8. Designate any transmission line or portion thereof for which the respondent Is not the sole owner. If ~uch property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot er than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the ope ratio of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in there, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns G) to (f) on the book cost at end of year. cus 1 utSize of Conductor and Material (i) LINt: {Include i m Column UJ Lana, EXPENSES, EXC~PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land 0) Construction and Other Costs (k) Total Cost Operation Expenses (m) (I} 1-795 ACSR AZ 1-954ACSR AW 1-795 ACSR AZ 1-1431 ACSRAW -1431 ACSR AW 1-954 ACSR AW 1-1431 ACSRAZ 1-1431 ACSR AZ 1-1431 ACSRAW 1-1431 ACSR AZ 1-795 ACSR AZ 1-1431 ACSR AW 1-1272ACSR AW 1-1431 ACSR AW 1-1431 ACSRAW ?-954 ACSR AW Maintena~ce Expense (n} 1 Total Expenses (p} Rents (o) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 i I ' ' ' ! ~-1272 ACSR AW n~1272ACSR AW ~-1431·ACSR TW I 1-1272 ACSR AW ~-3000 AL-HP 22 1-3750 AL ~-954 ACSR Line No. AZ 23 24 25 26 27 28 29 30 31 32 33 34 35 I ~-954 ACSR AW 2-954 ACSR AZ 2-954 ACSR AZ 1-1431 ACSRAW 1-954 ACSR AZ 1-954 ACSR AZ 1-954 ACSR AZ ~-1431 ACSR AW 1-1431 ACSRAW 1-1431 ACSRAZ 1-1431 ACSR AZ 2-556.5 ACSR AZ I ! ! ! ' ! ! 363,243,903 2,296,620,876 2,662,064, 779 15,003,893 18,m,936 ! FERC FORM NO. 1 (ED. 12-87) Page 423.14 2,400 33,179,229 36 This~rtls: (1) An Original (2) [jA Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) Year/Period of Report End of I I 2015/Q4 TRANSMISSION LINE STATISTICS 1. Report information concerning transmission lines, cost of li~es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages If so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) Is: (1) single pole wood or steel; (2) H-trame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, Indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and {g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. Type of other than 60 cvcle 3 phase} To (b) From (a) 1 2 3 4 5 6 7 6 9 10 11 12 13 ~2bJ:~~~~~ DESK>NA IIUN Line No. PUTNAM SEMINOLE PlANT (SEC) PUTNAM SEMINOLE PLANT (SEC) PUTNAM SEMINOLE PLANT (SEC) PUTNAM TOCOI PUTNAM TOCOI RAlLS TCEC (TCEC) RAlLS TURNPIKE RAlLS TURNPIKE RANCH RIVIERA RANCH RIVIERA RANCH TREASURE RANCH TREASURE RANCH TREASURE 14 RANCH TREASURE 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 RANCH TREASURE Operating {c) RANCH TREASURE RANCH TREASURE RANCH TREASURE RANCH TREASURE RICE SEMINOLE PlANT (SEC) 1 RICE SEMINOLE PlANT (SEC) 2 SAMPSON (JBH} SWITZERLAND (JEA) SANDPIPER TURNPIKE SANDPIPER TURNPIKE SANFORD PLANT ALTAMONTE (DEF) SANFORD PLANT BITHLO (DEF) SANFORD PLANT BITHLO (DEF) SANFORD PLANT BITHLO (DEF) SANFORD PLANT DEBARY (DEF) SANFORD PLANT NORTH LONGWOOD (DEF) SANFORD PLANT NORTH LONGWOOD (DEF) SHERMAN TREASURE SHERMAN TREASURE SHERMAN TREASURE SPRINGBANK SEMINOLE PLANT (SEC) 230.0( 230.0( 230.0( 230.0( 230.0( 230.0C 230.0( 230.0[ 230.0[ 230.0[ 230.0( 230.0( 230.0[ 230.0( 230.0C 230.0C 230.0C 230.0C 230.0( 230.0C 230.0( 230.0C 230.0C 230.0C 230.0C 230.0C 230.0C 230.0C 230.0C 230.0C 230.0( 230.00 230.00 230.00 230.00 Designed Structure (e) (d) 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 230.00 SP SP SP H SP H SP SP SP SP H SP SP SP Page 422.15 u l?ergrounWimes report circuit miles) Number Of 1 un ~t.ll!cture 1 unLtj_truth~res Circuits of. Line Des ated 1ft) 0.51 2.62 0.04 16.24 2.12 0.04 11.52 0.09 9.55 5.23 16.83 0.37 0.14 4.91 SP SP SP SP H H H SP SP SP SP SP 1.74 0.31 1.80 6.69 0.01 H SP H SP SP H 1 0.10 1 1 12.11 1 2 1 2 1 2 2 2 1 1 2 1 1.11 6,205.67 1 1 2 1 2 1 0.01 0.05 7.68 0.30 23.71 0.14 0.61 7.49 {h) 1 1 2. 1 0.08 4.34 1.65 0.05 25.46 0.25 SP SP of .I)_Jlol er me (g) 9.18 SP TOTAL 36 FERC FORM N0.1 (ED.12-87) Supporting LE~Gfu~ ra~le JPiles) 1 1 2 1 1 1 1 1 0.60 2 1 691.36 1,594 I Date ~~ Report (Mo, a, Yr) I I I This ~ort Is: (1) An· Original (2) (]A Resubmission Name of Respondent Florida Power & Light Company Year/Period of Report 2015/Q4 End of TRANSMISSION LINE STATISTICS (Contlnue(j} 7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher volt ~ge lines as one line. Designate in a footnote if you do not Include Lower voltage lines with higher voltage lines. If two or more transmission line structu es support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) I B. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If ~uch property is leased from another company, gNe "'m' '"''''"· ,,,, '"" te~ of L~. ·"' amou"t of~"' fM ''"· Fo""' .. "~''"'" lloo ·r'"'"'. . . " "· ""'"'" tho,..,, "' which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the I ne, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and term~ of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. I 10. Base the plant cost figures called for in columns 0) to (I) on the book cost at end of year. I I I I j COST OF LINE (Include 1n Column U) Land, Size of Conductor and Material (i} EXPENSES, EXC*PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land G) Construction and Other Costs (k) I Total Cost Operation Expenses (m} (I) Maintenan ce Expense {n) Rents Total Expenses (p) (o) 1-1431 ACSRAW 1-1431 ACSRAZ ~-1431 ACSRAZ 1-954ACSRAZ 1-954ACSRAZ Line No. 1 2 3 4 5 1-954 ACSR AW 6 1-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSR AW 2-795 ACSR AZ 7 8 I 9 10 1-1431 ACSRAW ?-795 ACSR AW 2-795 ACSR AZ 11 12 13 ' 14 15 2-795 ACSR AZ ~-954 ACSR AW ~-954 ACSR AW 2-954 ACSR AZ 12-954 ACSR AZ 2-1780 ACSR SO 2-1780 ACSR SO 1-954 ACSR AZ 16 17 I 18 19 20 21 22 i I : i 1-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSRAW 1-1272 ACSR AW 23 24 25 26 27 28 29 30 I ! ' 1-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSRAW 1-954 ACSR AZ I ! 1-954 ACSR AW 1-1431 ACSRAZ 1-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSR AZ 31 32 33 34 35 I ! I I 363,243,903 2,298,820,876 2,662,064,779 15,003,893 18, 1172,936 ! FERC FORM NO. 1 (ED. 12-87) Page 423.15 2,400 33,179,22~ 36 Name of Respondent Date of Report (Mo, Da, Yr) This wart Is: (1) An Original (2) [jA Resubmlsslon Florida Power & Light Company I I Year/Period of Report 20151Q4 End of TRANSMISSION LINE STATIST cs 1. Report Information concerning transmission lines, cost of lil)es, and expenses for year. list each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines Include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by Individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Non utility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H·frame wood, or steel poles; (3} tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f} the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. Type of other than 60 cvcle 3 ohasel From (a) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 X~chJ~~~~~ Ut:::> IL:;NA IIUN Line No. SPRINGBANK SPRINGBANK ST JOHNS STLUCIE STLUCIE ST LUCIE STLUCIE STLUCIE STLUCIE WHIDDEN WHIDDEN WHIDDEN 40TH STREET 40TH STREET AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT AIRPORT ALl CO ALl CO ALl CO 34 ALl CO 35 ALl CO To (b) Operating (c) SEMINOLE PLANT (SEC) SEMINOLE PLANT (SEC) 230.0[ 230.0[ TOCOI HUTCHINSON ISLAND HUTCHINSON ISLAND TREASURE TREASURE 230.0C 230.0C 230.0C 230.0C 230.0( 230.0( 230.0( 230.0( TREASURE TREASURE DESOTO (D.C.G.C.) VANDOLAH (DEF) VANDOLAH (DEF) LITTLE RIVER LITTLE RIVER DADE DADE DADE DADE DADE DADE DADE DADE DADE DADE RIVERSIDE RIVERSIDE RIVERSIDE RIVERSIDE RIVERSIDE RIVERSIDE BUCKINGHAM BUCKINGHAM BUCKINGHAM BUCKINGHAM BUCKINGHAM 230.0[ 230.0( 138.0C 138.0( 13B.OC 13B.OC 138.0C 138.0C 138.0C 138.0( 138.0! 138.0 138.0( 138.DC 138.0 138.0 138.0 138.0! 138.0! 138.0( 138.0( 138.0[ 138.0( 138.0{ 138.0{ Page 422.16 SJlO Supporting e hnes u~'Btl ergroun report circuit miles) Structure (e) un ~lfl:ICture un.:;,.u:~'fh~res of 't_IJOt er of L1ne 10e Desimated (g) 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 SP 138.00 UG 138.00 UG 138.00 H 138.00 H 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 H 138.00 SP 138.00 SP 138.00 SP 138.00 SP TOTAL 36 FERC FORM NO.1 (ED. 12-87) Designed (d) LENG~H ~ole !Jliles) Number Of Circuits (h) 10.26 2.61 1 1 11.16 0.12 0.13 2.12 0.12 1.62 8.08 0.12 1 1 1 1 1 0.50 12.64 3.63 2.47 0.22 0.14 1 1 1 1 2 1 1 1 2 6.86 13.55 3.56 0.78 1.08 0.86 1 1 1 2 1 2 1 1 1 1 2 1 1 2 1 1 2 1 2 6,205.67 691.36 1,594 0.42 0.15 0.68 0.30 0.31 0.1L 1.26 0.57 0.06 1.06 0.06 0.89 2.01 0.39 0.11 3.22 This~rtls: (1) An Original (2) (]A Resubmission Name of Respondent Florida Power & Light Company Date f Report (Mo,l a, Yr) Year/Period of Report 2015/Q4 End of I I RANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. ~eport Lower voltage Lines and higher volt ~ge lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structutes support lines of the same voltage, report the , pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) Iff"' O..igoote ~Y mmom-.oo """ "'''""" the,..,f fo< ,.,poodeot '' oot .,, "'' ~""'· property'' . .~,""'" ooothe< """'''"'· give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot er than a leased line, or portion thereof, for which the respondent Is not the sole owner but which the respondent operates or shares in the operatfo of, furnish a succinct statement explaining the arrangement and giving particulars (details} of such matters as percent ownership by respondent in the I ne, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party is an associated company. , 9. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns 0) to (I) on the book cost at end of year. a. wruoh""' i t;u::; 1 Ul- LINI:: (Include 1n t;olumn U) Land, Size of Conductor and Material (i) EXPENSES, Land rights, and clearing right-of-way) Land 0) Construction and other Costs (k) EXC~PT DEPRECIATION AND TAXES I I Total Cost Operation Expenses (m) (I) Maintenar ce Expense (n) 2-556.5 ACSR AZ 1-1431 ACSR AZ 1-954 ACSR AZ 1-954 ACSR AW 1-9272AAAC 1-3400 ACSR AW 2-1691 AAAC 12-1431 ACSR AW Total Expenses (p) Rents (o) 1 2 3 4 5 6 7 8 9 10 11 12 13 i I i I I ~-1691 AAAC 1-1431 ACSR AW 12-795 ACSR AW 2-795 ACSR AW 1-1250 CU-HP SD 1-2000 CU-HP SD 1-795AAC I I I 14 I 1-795AAC 1-556.5 ACSR AZ 1-GOOCU HT 15 16 17 18 19 20 21 22 23 I ~-795AAC 1-795AAC 1-795 ACSR p;z 1-795 ACSR /lZ 1-954ACSRAW 1-954 ACSR p;z 1-350CU HT 1-556.5 ACSR AZ 1-556.5 ACSR AZ 1-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AZ 1-954 ACSR AZ 1-954 ACSR AW 1-954ACSRAW 1-954"ACSRAZ 1-954 ACSR AZ ine No. 24 25 26 27 28 29 30 31 32 33 34 35 I I ! ' 363,243,903 FERC FORM NO. 1 (ED. 12-87) 2,298,820,876 2,662,064,779 Page 18,1 72,936 15,003,893 2,400 423.16 --------------------- -~- - -- - -- - - 33,H9,22S 36 This~rtls: Ail Original (1) (2) (]A Resubmission Name of Respondent Florida Power & Ught Company Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/04 End of TRANSMISSION LINE STATIST CS 1. Report Information concerning 'transmission lines, cost of lil)es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission llnes include all lines covered by the defin.ition of transmission system plant as given In the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. To (b) ALICO BUCKINGHAM ALICO BUCKINGHAM ALICO COLLIER 1 ALICO COLLIER 1 ALICO COLLIER 1 ALICO COLLIER 1 ALICO COLLIER 1 ALICO COLLIER 1 9 ALICO COLLIER 1 10 11 12 13 14 15 16 17 18 19 20 21 22 ALl CO COLLIER 1 ALl CO COLLIER 1 ALl CO COLLIER 1 ALl CO COLLIER 1 AUCO COLLIER 1 ALl CO ESTERO RADIAL ALl CO ESTERO RADIAL ALl CO FT MYERS PLANT 1 ALl CO FT MYERS PLANT 1 ALl CO FT MYERS PLANT 1 AUCO FT MYERS PLANT 1 FT MYERS PLANT 1 FT MYERS PLANT 1 FT MYERS PLANT 1 FT MYERS PLANT 1 FT MYERS PLANT 1 FT MYERS PLANT 1 FT MYERS PLANT 2 FT MYERS PLANT 2 FT MYERS PLANT 2 FT MYERS PLANT 2 FT MYERS PLANT 2 All CO ALl CO 23 ALl CO 24 25 26 27 28 29 30 31 Type of ALl CO ALl CO ALl CO ALl CO ALl CO ALl CO ALl CO ALl CO 32 ALl CO TERRY 33 ALl CO TERRY 34 ALl CO TERRY 35 ARCH CREEK BOULEVARD RADIAL 1 Operating (c) 138.0C 138.0C 138.0( 138.0C 138.0G 138.0C 138.0C 138.0C 138.0C 138.0C 138.0C 138.0 138.0! 138.0( 13B.OC 138.00 138.00 138.00 138.00 138.00 138.00 138.0( 138.0( 138.0( 138.0C 138.0( 138.0( 138.0( 138.0( 138.0( 138.0( 138.0( 138.0( 138.0C 138.0( report circuit miles) u~dergrounSJlhnes Number Of Designed Structure (e) un~tr/~ure : un.~~!f,~res of Ano er Une Desimated (g) Circuits (d) FERC FORM NO. 1 (ED. 12-87) 138.00 SP 138.00 SP 138.00 H 138.00 H 138.00 H 230.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 UG 138.00 SP 138.00 SP 138.00 SP 230.00 SP 230.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 H 138.00 H 138.00 SP 138.00 SP 138.00 SP 138.00 H 138.00 SP 138.00 SP 138.00 UG TOTAL 36 Page 422.17 LE~.fth~ ~ole J'Files) Supporting other than 60 cycle 3 phase) From (a) 1 2 3 4 5 6 7 8 ~~~datd~~~~ DESIGNATIUN Line No. 0.17 1.67 1.39 5.12 4.77 0.11 1.95 0.12 3.68 4.68 2.00 0.01 1.06 1.60 0.06 4.73 1.04 1.06 2.90 0.19 2.16 0.01 3.56 9.40 0.35 (h) 1 2 1 1 1 1 1 1 2 1 2 1 2 1 1 2 1 1 2 2 1 2 4.91 1.54 1.06 0.40 0.06 3.92 5.2.9 9.95 0.07 4.79 1.07 8.63 6,205.67 691.36 2 1 1 2 1 2 1 1 2 1 1 1 1 1,594 ! Date ~~ Report (Mo, a, Yr) This ~ort Is: (1) An Original (2) []A Resubmission Name of Respondent Florida Power & Light Company Year/Period of Report End of 11i 2015/04 RANSMISSION LINE STATISTICS (Continued) ~eport Lower voltage Lines and higher volt ge lines as one line. Designate In a footnote If you do not Include Lower voltage lines with higher voltage lines. If two or more transmission line structu~~s support lines of the same voltage, report the pole miles of the primary structure In column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If s uch property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ott er than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent In the li[le, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts arrected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and term* of lease, annual rent for year, and now determined. Specify whether lessee is an associated company. I 10. Base the plant cost figures called for In columns (j) to (I) on the book cost at end of year. 7. Do not report the same transmission line structure twice. I I i I cu::; 1 Ul- UN!: (Include In l,;alumn (jJ LaM, Size of Conductor and Material (i) EXPENSES, Land rights, and clearing right-of-way) Land (j) Construction and Other Costs (k) EXC~PT DEPRECIATION AND TAXES I Total Cost Operation Expenses (m) (I) 1-954 ACSR TW 1-954 ACSR TW 1-795ACSRAW 1-795 ACSR AZ 1-954 ACSR AZ 1-795 ACSR AW Maintenan ::e Expense (n) Rents Total Expenses (p) (a) Line No. 1 2 3 4 5 6 7 I 1-795 ACSR AW 1-795 SSAC AW 1-795SSACAW 1-954 ACSR AW 1-954ACSR AW 1-954 ACSR AZ 1-954 ACSR AZ 1-2500 CU-XLPE 1-954 ACSR AW 1-954 ACSR AW 8 9 10 11 12 13 14 15 16 17 18 ~-795 ACSR AW -795ACSRAW 1-795 ACSR AW -795ACSRAW -795ACSRAZ -795ACSRAZ -954ACSRAW -954ACSRAZ 1-954 ACSR TW 1-954 ACSR TW 1-954 ACSR AZ 1-954 ACSR AZ 1-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AZ 1-954 ACSR AZ 1-1431 ACSRAW 1-954 ACSR AW 1-2000 CU-HP SD 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 i i ! I 363,243,903 FERC FORM NO.1 (ED. 12-87) ~-~ 2,298,820,876 2,662,064,779 15,003,893 Page - -~ 423.17 18,1 2,936 2,40C 33,179,22!: 36 Name of Respondent Date of Report (Mo, Da, Yr) I I This wort Is: (1) An Original (2) []A Resubmlssion Florida Power & Light Company TRANSMISSION LINE STATIST Year/Period of Report 2015/04 End of cs 1. Report information concerning transmission lines, cost of li~Jes, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines Include all lines covered by the definition of transmission system plant as given In the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by Individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included In Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; {2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, Indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. DESIGNATION Line No. n~d1d~~~~~~ Type of other than 60 gycle 3 ohase) From (a) 1 ARCH CREEK 2 ARCH CREEK 3 ARCH CREEK 4 ARCH CREEK 5 ARCH CREEK 6 ARCH CREEK 7 ARCHCREEK 8 ARCH CREEK 9 ARCH CREEK 10 ASHMONT 11 BAREFOOT 12 BAREFOOT 13 BAREFOOT 14 BAREFOOT 15 BAREFOOT 16 BAREFOOT 17 BELLE MEADE 18 BELLE MEADE 19 BELLE MEADE 20 BELLE MEADE 21 BELLE MEADE 22 BELLE MEADE 23 BELLE MEADE 24 BELLE MEADE 25 BELLE MEADE 26 BELLE MEADE 27 BELLE MEADE 28 BELLE MEADE 29 BELLE MEADE 30 BEN EVA 31 BENEVA 32 BE NEVA 33 BE NEVA 34 BENEVA 35 BEN EVA To {b) Operating {c) 138.0( 138.0( 138.0( 138.0( 138.0( 138.0( 138.0( GREYNOLDS GREYNOLDS GREYNOLDS MIAMI SHORES NORMANDY BEACH NORMANDY BEACH WESTON VILLAGE WESTON VILLAGE WESTON VILLAGE LAUDERDALE MICCO MICCO WEST (VER) WEST(VER) WEST(VER) WEST(VER) COLLIER 1 COLLIER 1 COLLIER 1 COLLIER 1 COLLIER 1 COLLIER2 COLLIER2 COLLIER2 COLLIER2 COLLIER 2 COLLIER 2 COLLIER 2 COLLIER2 HOWARD HOWARD HOWARD HOWARD RINGLING RINGLING 138.0C 138.0C 138.0C 138.0C 138.0( 138.0( 138.0( 138.0[ 138.0( 138.0( 138.0!: 138.DC 138,()( 138.0C 138.0C 138.0C 138.0C 138.0C 138.0C 138.0C 138.0C 138.0G 138.00 138.00 138.00 138.00 138.0( 138.0( Supporting u aergroun~lmes report circuit miles) Structure (e) un ~t[l!C~ure 1 u!V}.!r~'ff,~res o no er of. Lin~ Line Des11J}a ed 138.00 SP 138.00 SP 138.00 UG 138.00 SP 138.00 UG 138.00 UG 138.00 SP 138.00 SP 138.00 SP 138.00 SP 230.00 SP 138.00 SP 138.00 SP 230.00 SP 138.00 SP 138.00 SP 138.00 H 138.00 H 138.00 SP 138.00 SP 138.00 SP 230.00 H 138.00 SP 230.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 230.00 SP 138.00 SP 138.00 SP 230.00 SP 138.00 SP 230.00 SP 138.00 SP TOTAL 36 FERC FORM NO. 1 (ED. 12-87) Designed (d) Page 422.18 LE~~J;~ ~ole o'files) (g) 3.49 0.06 1.02 5.86 1.45 2.34 1 1 1 2 1 1 1.07 0.37 18.24 2.83 0.35 0.24 8.12 0.05 0.06 0.66 7.71 0.41 1.0£ 6,205.67 {h) 1 2 1 1 1 1 1 0.47 1.09 4.42 0.35 1.07 1.15 0.53 0.43 0.31 0.08 0.14 2.02 0.04 2.85 13.73 0.03 1.37 Number Of Circuits 691.36 2 2 1 1 2 1 2 2 1 1 1 2 1 2 1 1 1 1 2 1 1 1 1,594 Name of Respondent ar This '[!]ort Is: (1) An Original (2) (]A Resubmisslon Florida Power & Light Company Year/Period of Report 2015/Q4 End of Date Report (Mo, a, Yr) IIi TRANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. R:eport Lower voltage Lines and higher volt ge lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structu ~ support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) B. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If 1 uch property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ott er than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the II ne, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts a ffected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and term of lease, annual rent for year, and how determined. Specify whether lessee Is an associated company. 10. Base the plant cost figures called for in columns 0) to (I) on the book cost at end of year. I CU::il UF LINE (Include in r..:olumn Q) Lana, Size of Conductor and Material (i) EXPENSES, EXC~PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) i Land Construction and Other Costs (j) (k) Total Cost Operation Expenses .(m) (I) Main ten an ce ExpensEll (n) 1-954ACSRAZ 1-954 ACSR AZ 1-2000 CU-HP SD 1-954 ACSR AW 1-1500 CU-HP 1-2000 CU-HP SD 1-1431 ACSRAW 1-1431 ACSR AZ 1-954 ACSR AZ 1.556.5 ACSR AW 1-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AZ 1-795 ACSR AZ 1-795 ACSRAZ 1-795 ACSR AZ 1-795 ACSR AZ 1-954 ACSR AW 1-954 ACSR AZ 1-1431 ACSRAW 1-1431 ACSRAZ 1-795 ACSR AZ 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AZ 1-795 ACSR AZ 1-954ACSRAW 1-954 ACSR AW 1-954 ACSR AZ 1-795 ACSR AW 1-795 ACSR AW Rents Total Expenses (p) (o) Line No. 1 2 3 I ! 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 I ! 30 31 32 33 34 35 I i 363,243,903 FERC FORM NO.1 (ED. 12-87) 2,298,820,876 2,662,064,779 Page 18,1 2,936 15,003,893 2,400 423.18 -- ---- 33,179,22[ 36 Name of Respondent Year/Period of Report Date of Report (Mo, Da, Yr) This wort Is: (1) An Original (2) A Resubmission FJ Florida Power & Light Company End of I I 2015/Q4 TRANSMISSION LINE STATISTICS 1. Report Information concerning transmission lines, cost of lil)es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported In column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. Line No. ~-· Y.O~JAGEJKV) ITION LE~ff'J.~ ~gle J?iles) Type of (Indicate wliere other than 60 cvcle 3 phase) Supporting 1 To (b) From (a) 1 2 3 4 5 6 7 BENEVA RINGLING BENEVA RINGLING BRADENTON CORTEZ BRADENTON CORTEZ BRADENTON FRUIT INDUSTRIES BRADENTON FRUIT INDUSTRIES BRADFORD HAMPTON 8 BRADFORD HAMPTON 9 BRANDON LAUDERDALE 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 BRANDON LAUDERDALE BRANDON LAUDERDALE BRANDON LAUDERDALE BRANDON LAUDERDALE BRANDON MIAMI SHORES BRANDON MIAMI SHORES BRANDON MIAMI SHORES BREVARD CLEARLAKE RADIAL BREVARD CLEARLAKE RADIAL BREVARD CLEARLAKE RADIAL BREVARD BREVARD CLEARLAKE RADIAL BREVARD COCOA BEACH BREVARD COCOA BEACH BREVARD EAU GALLIE BREVARD EAU GALLIE BREVARD EAUGALLIE BREVARD EAU GALLIE BREVARD EAU GALUE BREVARD OLEANDER (CST) Operating (c) 138.0C 138.& 138.0( 138.0( 138.0( 138.0( 138.0( 138.0( 138.0( 138.0C 138.0C 138.0C 138.0C 138.0C 138.0C 138.DC 138.0C 138.0< 138.0( 138.0( 138.0[ 138.0< 138.()( 138.0< 138.0( 138.0( 138.0( 138.()( 138.0< 138.0( 138.0( 138.0< 138.0C 138.0( 138.0( COCOA BEACH BREVARD ROCKLEDGE RADIAL BREVARD ROCKLEDGE RADIAL BREVARD ROCKLEDGE RADIAL BREVARD ROCKLEDGE RADIAL BROWARD DEERFIELD BEACH 1 BROWARD DEERFIELD BEACH 1 Structure (e) (d) 138.00 138.00 138.00 138,00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 136.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 230.00 138.00 SP Page 422.19 1 5.14 1.02 SP SP SP SP SP SP SP H SP 8.75 0.12 0.86 0.87 0.03 5.82 0.80 2.46 024 SP SP SP SP SP SP SP SP 0.24 8.58 0.03 2.02 2.14 0.54 1.70 2.19 SP SP SP SP SP SP SP SP SP SP SP SP 3.32 11.75 0.09 0.90 0.14 4.29 14.68 1.27 1.33 0.20 0.12 SP SP SP SP 2.19 4.03 1.22 6.19 SP TOTAL 36 FERC FORM NO. 1 (ED. 12·87) Designed u aergrouniflmes report circuit miles) on s_tructure on,~ru~wres o no er of Lin~ me Desir; a ed (g) 3.53 0.06 0.14 0.92 6,205.67 691.36 Numbe Of Circuits (h) 1 2 1 1 1 1 1 1 1 1 2 1 1 1 1 1 2 1 2 1 1 2 1 1 2 1 1 2 1 1 2 1 2 1 1 1,594 Name of Respondent Date[ fReport (Mo, a, Yr) This wort Is; (1) An Original (2) (]A Resubmlssion Florida Power & Light Company I I Year/Period of Report End of I 2015/Q4 TRANSMISSION LINE STATISTICS (Continued) ~eport Lower voltage Lines and higher volt ~ge lines as one line. Designate in a footnote if you do not Include Lower voltage lines with higher voltage lines. If two or more transmission line structu tes support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If uch property Is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot er than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, fum ish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the I ne, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and term ~ of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for In columns (j) to (I) on the book cost at end of year. 7. Do not report the same transmission line structure twice. I' GUST Ur LINE (Include in Column (j) Land, Size of Conductor and Material (i) EXPENSES, EXC*PT DEPRECIATlON AND TAXES Land rights, and clearing right-of-way) Land (j) Construction and Other Costs (k) Total Cost Operation Expenses (m) (I) Maintenar ce Expense (n) 1-1431 ACSR AW 1-1431 ACSR AW 1-954 ACSR AW 1-954 ACSR AW 1-1431 ACSR Al. 1-1431 ACSR Al. 1-1431 ACSR AZ 1-1431 ACSR Al. 1-1431 ACSR Al. 1-1431 ACSR Al. 1-1431 ACSR Al. 1-1431 ACSR Al. 1-1431 ACSR AW Rents Total Expenses (p) (o) Line No. 1 2 3 i i 4 5 6 7 8 9 10 11 12 13 1-954 ACSR AZ 1-954 ACSR Al. 1-795 ACSR Al. 1-954 ACSR AW 1-1431 ACSR AW 1-1431 ACSRAW 1-795 ACSR AZ 1-795 ACSR Al. 1-1431 ACSR AW 1-795 ACSR AZ 1-954 ACSR AW 1-1431 ACSR Al. 1-954 ACSR Al. 1-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AZ -954ACSRAZ 1-1431 ACSR AW 1-954 ACSR AZ 1-1431 ACSRAW 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 I 33 34 35 363,243,903 2,298,820,876 2,662,064,779 FERC FORM NO. 1 (ED. 12-87} Page ----·· --· 15,003,893 18,1 72,936 2,400 423.2 - ----- ------- -·-·- - 33,179,229 36 Name of Respondent Date of ReJJOrt (Mo, Da, Yr) This [!prt Is: (1) An Original (2) [JA Resubmission Florida Power & Light Company Year/Period of Report 2015/Q4 End of I I TRANSMISSION LINE STATISTICS 1. Report infonmation concerning transmission lines, cost of lil)eS, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given In the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages If so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; {3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show In column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which Is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included In the expenses reported for the line designated. DESIGNATION Line No. Y,OJ'fAGE (KV) (Indicate wtiere other than 60 cycle 3 phase) To (b) From (a) Operating (c) LE~G~ role miles) 11:1 t e of u dergroun lines report circuit miles) a11 Type of Supporting 1 Designed Structure (e) (d) un -~tfi:IC!ure of. Lin~ Des1(;a ed 1 BOBWHITE lAURELWOOD 230,0[ 230.00 SP 14.66 2 BOBWHITE RINGLING 1 230.00 230.0( 230.00 H 6.34 230.00 138.00 SP SP SP 0.06 230.0C 230.0( 230.0( 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 230.00 BOBWHITE RINGLING 1 BOBWHITE BOBWHITE RINGLING 1 RINGLING 1 BOBWHITE RINGLING 2 BOBWHITE RINGLING 2 RINGLING 2 230.01 230.0C 230.00 BOBWHITE BOBWHITE SR-70 230.0C 7.63 BRADFORD DUVAL 230.0C 230.00 230.00 H BRADFORD DUVAL 230.0C 230.0( 230.00 H 27.01 138.00 H 3.87 230.0( 230,0[ 230.00 H 22.96 230.0C 230.0( 230.00 H BRADFORD RICE BRADFORD RICE BRADFORD RICE CAPE CANAVERAL 1 BREVARD 1 1 1 1 2 1.41 2 0.09 1 4.97 1 1 1 1 1 1 1 0.19 0.62 8.38 1 1 230.00 0.05 1 230.00 H 8.34 CAPE CANAVERAL 2 230.0[ 230.00 SP 0.10 1 1 CAPE CANAVERAL 3 CAPE CANAVERAL 3 230.01 230.0[ 230.00 H 230.00 SP 8.37 0.06 230.01: 230.0 25.72 230.0( 230.00 H 230.00 SP 230.00 SP BREVARD BREVARD MAlABAR 1 MALABAR 1 MALABAR2 230.00 BREVARD OLEANDER {CST) 230.0C 230.0( 230.00 230.00 MALABAR3 SP SP H SP 0.04 0.34 25.74 25.83 0.27 BREVARD POINSETT 1 230.0( 230.00 BREVARD POINSETT 1 230.0C 230.00 BREVARD BREVARD POINSETT 2 POINSETT 2 230.0( 230.0( 230.00 H 230.00 SP 7.53 0.19 BRIDGE BRIDGE HOBE 230.0( 230.0( 230.00 H 0.03 6.07 BRIDGE BRIDGE INDIANTOWN 1 INDIANTOWN 2 230.0( BRIDGE PLUMOSUS 230.0C HOBE 230.0C Page 422.3 6.91 4.45 230.00 SP 230.00 H 10.02 SP SP 28.33 230.00 230.00 TOTAL 36 FERC FORM NO.1 (ED. 12-87) (h) 230.0( CAPE CANAVERAL 2 BREVARD BREVARD Circuits 230.0[ CAPE CANAVERAL 1 BREVARD BREVARD BREVARD SP of1_1JO er 1ne (g) SP SP CAPE CANAVERAL 1 BREVARD BREVARD BREVARD 230.00 SP SP SP 9 U!J.~t!l-1 '[h~res 0.03 0.03 230.00 H 230.00 Number Of 1 1 1 1 1 10.03 6,205.67 1 1 1 1 2 2 1 1 1 2 1 691.36 1,594 I Date ~r Report (Mo. a, Yr) Thls~ort Is: (1) An Original (2) EJA Resubmisslon Name of Respondent Florida Power & Light Company Year/Period of Report End of "i 2015/04 TRANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltte lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structu s support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. " " ' " - aoYtnm•m;,o, •~ " po~"" ......, fa< "'"' tt.a ""poO>dMtl• oot tt.e '"'" ...,.,. "!""' property I• le~d •om ' " - ' """""''' give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot er than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent In the I ne, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and termF of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. ! 10. Base the plant cost figures called for in columns 0) to (I) on the book cost at end of year. I I I I I I COST OF LINE (Include 1n Column Q) Land, Size of Conductor and Material (i) EXPENSES. Land rights, and clearing right-of-way) EXC~PT DEPRECIATION AND TAXES ! Land U) Construction and Other Costs (I<) Total Cost Maintenan e Expense (n) Operation Expenses (m) (I) 1-795 ACSR AZ 1-795 ACSR AZ 1-795 ACSR AZ 1-954 ACSR AW -795ACSRAZ 1-954 ACSR AW Total Expenses (p) Rents (o) Line No. 1 2 3 4 5 6 ! 1-795 ACSR AW 1-795 ACSR AZ I 7 8 9 I 10 'I I2-556.5AAC 1-1431 ACSR AZ ~-1431 ACSR AZ ! ! 11 12 I 1-350 CU HT ~-556.5AAC 13 14 1-1431 ACSR AW 1-1431 ACSR AZ 2-350CU HT 15 16 17 1-556.5AAC 1-954 ACSR AW 18 19 20 ~-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AZ 21 22 i ' ' 23 24 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR TW 1-954ACSRTW 25 26 27 28 29 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AW . 1-954 ACSR AZ 1-954 ACSR AZ 1-1431 ACSRAZ 1-1431 ACSRAZ 30 31 32 33 34 I 35 ' ' '' I 363,243,903 2,298,820,876 2,662,064,779 2,400 18,1 2,936 15,003,893 ' 33,179,225 36 ., FERC FORM NO. 1 {ED. 12-87) Page ·-- 423.19 - -- -~-------- -- ---------- - Name of Respondent Dale of Report (Mo, Da, Yr} This wort Is: (1) An Original {2) FiA Resubmission Florida Power & Light Company I I Year/Period of Report End of 2015/04 TRANSMISSION LINE STATIST cs 1. Report information concerning transmission lines, cost of llr:tes, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual fines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutllity Property. 5. Indicate whether the type of supporting structure reported in column (e) Is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or {4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. BROWARD DEERFIELD BEACH 1 BROWARD DEERFIELD BEACH 2 BROWARD DEERFIELD BEACH 2 BROWARD DEERFIELD BEACH 2 BROWARD DEERFIELD BEACH 2 BROWARD LYONS BROWARD LYONS MCARTHUR BROWARD BROWARD BROWARD MCARTHUR BROWARD MCARTHUR BROWARD MCARTHUR MCARTHUR BROWARD BROWARD PALMAIRE BROWARD POMPANO POMPANO BROWARD TRADEWINDS WESTINGHOUSE BROWARD BROWARD BROWARD BROWARD BUCKINGHAM BUCKINGHAM BUCKINGHAM BUCKINGHAM 138.0C 138.0C 138.0( 138.0( 138.0( 138.0( 138.0( 138.0C 138.0( 138.0C 138.0C 138.0C 138.0 138.0 138.0( 138.0( 138.0( 138.0C 138.0 138.01 138.()( 136.01 138.0( 138.0( 138.0! 138.0! 138.01 138.01 138.0( 138.0C 138.0( 138.01 138.0( 138.0( 138.0( PALMAIRE BROWARD BROWARD Operating (c) MCARTHUR BROWARD WESTINGHOUSE WESTINGHOUSE WESTINGHOUSE WESTINGHOUSE FT MYERS PLANT FT MYERS PLANT FT MYERS PLANT BUCKINGHAM LAZY ACRES (LCCR) LAZY ACRES (LCCR) BUCKINGHAM LEHIGH ACRES (LCEC) BUCKINGHAM LEHIGH ACRES (LCEC} CEDAR CEDAR CEDAR GERMANTOWN GERMANTOWN GERMANTOWN CEDAR GERMANTOWN CEDAR HYPOLUXO ROAD (LWU) 1 Page 422.20 LEMGth~ ra~le ~iles} u lrergrounlftmes report circuit miles) lYn~fl!cture unf~ru~~res of Lm~ o not er Structure 1ne Desi(l}a ed (e) (g) Supporting Designed (d) 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 230.00 138.00 138.00 230.00 138.00 138.00 138.00 138.00 230.00 138.00 230.00 138.00 138.00 SP H SP SP SP SP SP H H SP SP SP SP SP SP SP SP SP H H H SP SP H SP SP SP SP 3.72 0.03 0.10 4.86 2.70 0.28 8.10 3.43 4.61 0.07 1.43 0.17 4.52 1.04 7.06 0.16 2.74 0.99 4.5( 3.28 0.55 3.38 1.47 2.50 0.12 2.04 1.22 0.11 H SP SP SP SP SP SP TOTAL 36 FERC FORM NO.1 (ED. 12-87) Type of (Indicate wtiere other than 60 cvcle 3 ohasel To (b) From (a) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 Y,"Ol,T~GE (KV) DESIGNATION Line No. 0.06 0.08 10.10 1.61 0.54 0.06 6,205.67 691.36 Numbe Of Circuits (h) 1 1 1 1 1 1 1 1 1 1 1 1 2 1 1 1 1 1 2 1 1 2 1 1 1 2 1 1 1 1 1 1 2 2 1 1,594 Date ~~ Report (Mo, a, Yr) This ~ort Is: (1) An Original (2) []A Resubmission Name of Respondent Florida Power & Light Company I I Year/Period of Report 2015/04 End of I TRANSMISSION LINE STATISTICS (Continued) ~eport Lower voltage Lines and higher volt ~ge lines as one line. Designate in a footnote if support lines of the same voltage, report the you do not Include Lower voltage lines with higher voltage lines. If two or more transmission line structu pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If uch property Is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot rer than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares In the operatior of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the ine, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party Is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terrr s of lease, annual rent for year, and how determined. ·specify whether lessee is an associated company. 10. Base the plant cost figures called for In columns Q) to (I) on the book cost at end of year. 7. Do not report the same transmission line structure twice. res COST OF LINE {Include In Column (j) Land, Size of Conductor and Material (i) EXPENSES,EXC PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way} Land Q) Total Cost Construction and Other Costs (k) Maintenar ce Expense s (n) Operation Expenses (m) (I) Total Expenses (p) Rents (o) ine No. 1-954 ACSR AZ 1-954 ACSR AZ 1-1431 ACSRAZ 1 2 3 1-954 ACSR AZ 2-556.5AAC 4 5 1-954 ACSR AW 6 1-954 ACSR AZ 7 8 1-954 ACSR AZ t1-336.4 ACSR AZ 9 10 11 12 13 1-1431 ACSR AZ 1-954 ACSR AW 1-954 ACSR AZ ~-336.4 ACSR AZ ~-954 ACSR AW 14 15 1-954 ACSR AZ 1-954 ACSR AW 16 17 18 19 1-954 ACSR AZ 1-556.5 ACSRAW H431ACSRAZ 1-954 ACSR AZ !2-336.4 ACSR AZ 20 l 21 22 1-1431 ACSRAW 1-954 ACSR AW 23 24 25 26 27 28 1-954 ACSR AZ 1-954 ACSR AZ 1-954 ACSR AZ 1-336.4 ACSR AZ 1-795ACSRAW 1-1 Dummy ConduGI 29 30 i 1-795ACSRAW 1-954 ACSR AZ I 1-954 ACSR AZ 1-954 ACSR AZ 1-954ACSRAZ 1-954 ACSR AW 31 32 33 34 35 I i 363,243,903 2,298,820,876 2,662,064,779 FERC FORM NO. 1 (ED. 12-87) Page -- 15,003,893 18, 72,936 423.20 ---~ ------ 2,400 33,179,225 36 :: This ~ort Is: (1) An Original (2) A Resubmission Name of Respondent Date of Report (Mo, Da, Yr) EJ Florida Power & Light Company I I Year/Period of Report End of 2015/04 TRANSMISSION LINE STATISTICS 1. Report information concerning transmission lines, cost of lil)es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines Include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; {2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, Indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report In columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which Is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. DESIGNATION Line No. To (b) From (a} 1 CEDAR 2 CEDAR V.Ol,TAGE (KV) (Indicate wliere other than 60 cvcle 3 chase) HYPOLUXO ROAD (LWU) 1 3 CEDAR HYPOLUXO ROAD (LWU) 2 HYPOLUXO ROAD (LWU) 2 6 CEDAR RANCH 7 CEDAR RANCH 8 CEDAR RANCH 24 25 26 27 28 29 30 31 32 33 34 35 HYPOLUXO ROAD (LWU) 2 CEDAR RANCH CEDAR RANCH CEDAR RANCH CHARLOTTE CLEVELAND RADIAL CHARLOTTE CHARLOTTE HARBOR CHARLOTTE . HARBOR HARBOR CHARLOTTE PUNTA GORDA RADIAL CHARLOTTE PUNTA GORDA RADIAL CHARLOTTE PUNTA GORDA RADIAL CHARLOTTE PUNTA GORDA RADIAL COAST HARBOR HARBOR COAST COAST 23 COAST COAST COAST COAST HARBOR MYAKKA MYAKKA MYAKKA MYAKKA COCOA BEACH PATRICK COCOA BEACH PATRICK COCOA BEACH COCOA BEACH PATRICK PATRICK COCOA BEACH SOUTH CAPE COCOA BEACH SOUTH CAPE SOUTH CAPE COCOA BEACH COCOA BEACH COCONUT GROVE 138.0C 138.0C 138.0 138.0( 138.0( 138.0( 138.0[ 138.00 138.00 138.0 138.0( 138.0! 138.0( 138.01 138.0( 138.01 138.0( 13B.rn 13B.rn 138.01 138.01 138.01 138.01 138.01 138,1)( 138.rn 138.01 138.01 138.0! 138.0{ 138.0( 138.0( 138.0( 138.0{ 138.0( HYPOLUXO ROAD (LWU) 1 4 CEDAR 5 CEDAR 9 10 11 12 13 14 15 16 17 18 19 20 21 22 Operating (c) SOUTH CAPE MIAMI Designed (d) 138.00 138.00 138.00 138.00 138.00 138.00 230.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 230.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 138.00 1 SP SP SP SP SP H H SP SP SP SP H SP SP SP H SP SP SP SP SP SP SP SP SP SP H SP SP UG SP SP SP SP UG TOTAL 36 FERC FORM NO. 1 (ED. 12-87) LENGTH ~ole ~lies) ~Ill the sJ' P u dergroun l1nes report circuit miles) Supporting 1un ::?_lf'JCture un.qtruwres of '(?ot er of,Lm~ Structure me Des1ara ed (e) (g) Type of Page 422.21 Circuits (h) 1 2 1 2 1 1 1 1 6.79 0.53 2.27 0.97 2.26 0.21 4.27 0.22 6.16 5.76 1 1 0.97 0.13 1.95 15.13 0.06 2.72 0.02 6.38 2.12 2.86 2.26 0.61 13.78 2.62 0.46 0.22 2.25 1.84 6.40 0.96 0.39 0.02 2 1 1 1 1 1 1 1 1 1 1 1 1 1 1 2 1 1 1 1 2 1 1 1 1 7.8~ 0.01 4.97 6,205.67 Numbe Of 691.36 1,594 i This ~ort Is: {1) An Original {2) OA Resubmission Name of Respondent Florida Power & Light Company Year/Period of Report 2015/Q4 End of Date f Report {Mo, I a, Yr) I I RANSM!SS!ON LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. ~eport Lower voltage Lines and higher volt ge Jines as one line. Designate In a footnote if you do not include Lower voltage lines with higher voltage Jines. If two or more transmission line structu es support lines of the same voltage, report the pole miles of the primary structure in column {f) and the pole miles of the other line{s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent Is not the sole owner. If!, uch property is leased from another company, give name of lessor, dale and terms of Lease, and amount of rent for year. For any transmission line ott er than a leased line, or portion thereof, for which the respondent Is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars {details) of such matters as percent ownership by respondent in the I ne, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts E ffected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and term s of lease, annual rent for year, and how determined. Specify whether lessee Is an associated company. 10. Base the plant cost figures called for in columns G) to (ij on the book cost at end of year. i COST OF LINt: {lnctuae 1n Column G) Land, Size of Conductor and Material {i) EXPENSES, EXC~PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land Ul Construction and other Costs {k) I Total Cost Operation Expenses (m) (I) Maintenan Fe Expense (n) Rents Total Expenses (p) {o} Line No. 1-954 ACSR AZ 1 1-954 ACSR AZ 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AZ 2 3 4 5 6 1-954 ACSR AW 1-954ACSRAW 7 8 9 1-1431 ACSR AW 1-954ACSRAW 1-954 ACSR AZ 10 11 12 13 14 1-954 ACSR AZ 1-556.5 ACSR AZ 1-795 ACSR AZ 1-954ACSRAW 1-954 ACSR AZ 1-954 ACSR AZ 1-556.5 ACSR AZ 1-954 ACSR AW 15 16 17 i i 18 19 20 21 I 1-954 ACSR AZ 1-795 ACSR AW 1-795 ACSR AZ i I 1-954ACSRAW 1-795ACSRAZ 1-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AZ 1-350CUHT 1-350CU HT 1-652.4 AAAC 1-1250 CU-HP SD i 22 23 24 25 26 27 28 29 30 31 32 i 33 I \ I I 1-556.5 ACSR AW 1-600CU HT 1-927.2 AAAC 1-954 ACSR AW 1-700CU-HP I 34 35 363,243,903 2,298,820,876 FERC FORM NO. 1 (ED. 12-87) -- 2,662,064,779 Page ----- ~-- 15,003,893 18,1 2,936 423.21 --~-1--- ----- 2,400 33,179,22S 36 Name of Respondent Date of Report (Mo, Da, Yr) This wort Is: (1) An Original (2) fiA Resubmission Florida Power & Light Company Year/Period of Report 2015104 End of I I TRANSMISSION LINE STATIST cs 1. Report information concerning transmission lines, cost of li~es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages In group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Non utility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; {3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. DESIGNATION Line No. From (a) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 COCONUT GROVE COCONUT GROVE COCONUT GROVE COCONUT GROVE COCONUT GROVE COLLIER COLLIER COLLIER COLLIER COLLIER COLLIER COLLIER COLLIER COLLIER COLLIER COLLIER COLLIER CORTEZ CORTEZ CORTEZ CORTEZ CORTEZ COURT COURT COURT COURT COURT COURT COURT CUTLER CUTLER CUTLER CUTLER CUTLER CUTLER VOLTAGE (KV) (Indicate wliere other than 60 cvcle 3 phase) To (b) Operating (c) RIVERSIDE RIVERSIDE RIVERSIDE SOUTH MIAMI 138.0C 138.0 138.0( 138.0( SOUTH MIAMI ALLIGATOR RADIAL ALLIGATOR RADIAL ALLIGATOR RADIAL NAPLES RADIAL NAPLES RADIAL NAPLES RADIAL 138.0( 138.0( 138.0 138.00 138.00 13B.OC 13B.OG 138.00 TERRY TERRY TERRY TERRY TERRY TERRY JOHNSON JOHNSON 138.0G 138.0( WOODS WOODS WOODS CUTLER CUTLER CUTLER CUTLER CUTLER CUTLER DAVIS DAVI$2 DAVIS2 DAVIS2 DAVIS 2 DAVIS4 DAVIS4 138.0! 138.0( 138,0( 138.0( 138.0( 138.0! 138.0( 138.0{ 138.0{ 138.0{ 138.0{ 138.0! 138.0{ 138.0( 138.0( 138.0( 138.00 138.00 138,0( 13B.OC 138.0( FERC FORM NO. 1 (ED. 12-87) Page 422.22 report Clrcu it miles) Supporting 1 Designed Structure {e) (d) 138.00 138.00 138.00 138.00 138.00 un ~tfl!aure of. Line Des1[t}ated SP SP SP SP 6.06 0.04 SP 138.00 SP 138.00 SP 138.00 SP 138.00 H 138.00 SP 138.00 SP 138.00 H 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 230.00 H 138.00 SP 138.00 SP 138.00 SP 138.00 SP 230.00 H 230.00 H 138.00 H 138.00 H 138.00 SP 138.00 SP 138.00 H 230.00 H 230.00 H 138.00 H 138.00 H 3.02 138.00 H 230.00 H TOTAL 36 LE~~~ ~~le 0rpiles) u aergroun1flmes Type of unf~rulh~res o l)ot er 1ne (g) 0.05 0.01 Number Of Circuits (h) 1 2 1 1 0.26 1.76 1.07 0.04 0.11 2.35 1.56 10.80 1.07 2.98 1.70 2.36 0.18 0.05 8.81 6.73 0.50 1.15 0.29 1.97 3.62 0.23 0,19 1 1 2 1 1 1 2 1 1 1 1 2 1 1 1 1 1 0.71 0.04 0.03 0.33 2.76 3.69 0.23 2 1 2 1 1 1 1 1 1 2 0.30 0.17 0.79 1 1 2 2 6,205.67 691.36 1,594 Name of Respondent Date f Report (Mo, a, Yr) This 'mort Is: (1-) An Original (2) EJA Resubmisslon Florida Power & Light Company Year/Period of Report 2015/Q4 End of I I TRANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher volt ge lines as one line. Designate In a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structu es support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line{s) in column (g) B. """""''" aoy t~ooml""" ttre "portioo lhe~offo' whloh tho ~poodeot '' oot the"~ ~re,. 'l"' property" """"'from oooth" ~paoy, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot er than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operatic of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the I ne, name of co-owner, basis of sharing . expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party is an associated company. , 9. Designate any transmission line leased to another company and give name of Lessee, date and termj of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns (j) to (I) on the book cost at end of year. 'I I {.;U:S 1 ut- LINt= (Include 1n [.;QIUmn Si2:eof Conductor and Material {~ I O> Lancl, EXPENSES, EXC~PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land Construction and other Costs {k) G) Total Cost Operation Expenses (m) (1) Maintenanpe Expense (n} Total Expenses (p) Rents (o) 1-795 ACSR AZ 1-795 ACSR AZ Line No. 1 2 3 1-954 ACSR AZ 1-954 ACSR AW 1-954 ACSR AZ 4 5 1-556.5 ACSR AW 6 1-556.5 ACSR AW 1-795 ACSR AZ 7 8 1·954 ACSR AZ 1-954 ACSR AZ 9 10 1-954 ACSR AZ 1-954 ACSR AW 1-336.4 ACSR AZ 11 12 13 1-795 ACSR AZ 1-954 ACSR AW 14 15 16 I 1-954 ACSR AW i 1-954ACSR AZ 1-1691 AAAC 1-954 ACSR AZ 17 18 I i 19 20 21 22 I 1-795 ACSR AZ 1-954 ACSR AW ~-954ACSR AW ~-1431 ACSR AZ 23 24 25 ~-1431ACSRAZ ~-350CU HT 26 -556.5 ACSR AZ ~-1431 ACSRAZ 27 ' ~-350CU HT 1-1431 ACSR AZ 1-1431 ACSRAZ 1-1431 ACSR AZ 1-350CU HT 1-556.5 ACSR AZ 1-SOOCU HT 1-954 ACSR AZ 28 29 30 31 32 33 34 35 I I ! 363,243,903 2,298,820,876 FERC FORM NO. 1 (ED. 12-87} 2,662,064,779 15,003,893 Page - ------ - - - 18,1 2,936 2,400 423.22 -- ------ ~~ ' ~~ ~---- ----~- -~ 33,179,2.29 36 This ~art Is: An Original (1) (2) (]A Resubmlssion Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) I I TRANSMISSION LINE STATIST Year/Period of Report 2015104 End of cs 1. Report infonmation concerning transmission lines, cost of ll~es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given In the Unifonm System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported In column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, Indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the nne. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. UtSIGNATION Line No. VOL 1/)GE {KV) (Indicate where other than 60 cycle 3 phase) To (b) From (a} Operating (c) Type of Supporting LE~G~ ~ate Wiles) ~ t e ascr 0 u ergroun lines report circuit mites} 1 un ~trycture Designed Structure (e) (d) of. line Des1r;ated i Number Of Circuits U!lf~f~~~res of TJOt er Line (g) (h) 138.0C SP 138.00 SP 138.00 SP 138.00 SP 2.11 1 GALLOWAY 138.0C 138.00 H 0.17 6 CUTLER GALLOWAY 138.0C 138.00 GALLOWAY 138.0{ 138.00 8 CUTLER GALLOWAY 138.0C 9 CUTLER GALLOWAY 138.0C 10 CUTLER SOUTH MIAMI 138.0C 11 CUTLER SOUTH MIAMI 138.0C SP SP 138.00 SP 138.00 SP 138.00 SP 138.00 UG 0.01 7 CUTLER 2 1 1 12 DADE FLAGAMI 138.0C 138.00 H 0.51 13 DADE FLAGAMI 138.0C 138.00 14 DADE FLAGAMI 138.0C 138.00 15 DADE FLAGAMI 138.0C 138.00 16 DADE FLAGAMI 138.0C 138.00 17 DADE FLAGAMI 138.0C 138.00 1 CUTLER DAVIS4 138.0C 2 CUTLER DAVIS4 13B.OC 3 CUTLER DAVIS4 138.0C 4 CUTLER DAVIS4 5 CUTLER 138.00 SP SP SP SP UG 0.35 1 4.41 1 0.16 1 0.29 6.94 1 1.56 2 7.42 1 1 1 0.74 281 1 0.46 1 0.23 2 285 1 1 0.38 18 DADE GRATIGNY1 138.0G 230.00 H 19 DADE GRATIGNY 1 138.0( 138.00 H 20 DADE GRATlGNY 1 138.0( 230.00 21 DADE GRATJGNY 1 138.0( 138.00 22 DADE 138.01 138.0C 230.00 230.00 H 0.06 23 DADE GRATIGNY 1 GRATIGNY2 138.00 011 1 230.00 0.61 1 3.05 1 0.76 1 SP SP SP 0.44 2 3.06 1 0.34 1 0.03 1 1 0.44 2 24 DADE GRATIGNY 2 138.0C 25 DADE GRATtGNY2 138.0C 26 DADE GRATlGNY2 138.0C 27 DADE GRATtGNY2 138.0C 28 DADE GRATIGNY 2 138.0C 29 DADE GRATIGNY2 138.0( 30 DADE GRATJGNY 2 138.0( SP SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 31 DADE LITTLE RIVER 2 138.0( 138.00 H 0.05 32 DADE LITTLE RIVER 2 138.0{ 138.00 H 0.24 33 DADE LITTLE RIVER 2 138.0{ 138.00 1 UTILE RIVER 2 138.0( 138.00 SP SP 0.67 34 DADE 0.10 1 35 DADE LITTLE RIVER 2 138.0( 138.00 SP 0.01 1 TOTAL 36 FERC FORM N0.1 {ED.12-87) Page 422.23 0.16 1 7.04 1 0.26 6,205.67 0.26 2 1 1 691.36 1,594 Name of Respondent Dateg R~rt (Mo, a, r) This wort Is: (1) An Original (2) [JA Resubmission Florida Power & Light Company Year/Period of Report End of I I 2015/Q4 TRANSMISSION LINE STATISTICS (Continued) ~aport Lower voltage Lines and higher volta ge lines as one line. Designate in a footnote if you do not Include Lower voltage lines with higher voltage lines. If two or more transmission line structur s support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) ' 7. Do not report the same transmission line structure twice. l"' ~poodoort .,.reef a. lo~d Doslgoote .,, ""''"""''" liM " portk>o fu< whioh tho ;, oot the oolo """"· If proporty • from '""'"" oomp...,, give name of lessor, date and terms of lease, and amount of rent for year. For any transmission line oth r than a leased line, or portion thereof, for which the respondent Is not the sole owner but which the respondent operates or shares in the operation f, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the li e, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts a ected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and term, of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. . 10. Base the plant cost figures called for in columns (j) to (I) on the book cost at end of year. I ! ! i I i .:;u~ 1 ut- LIN~ Size of Conductor and Material 0) tlnclude 1n Column (j) Land, EXPENSES,EXCE PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land (j) Construction and Other Costs (k) Total Cost Operation Expenses (m} (I} Maintenan :e Expenses (n) Rents Total Expenses (o) (p) 1-SOOCU HT 1-795AAC 1-954 ACSR AW 1-954 ACSR AZ 1-600 CU HT 1-350CU HT 1-600 CU HT 1-954 ACSR AZ 1-954 ACSR AZ 1-954 ACSR AZ 1-2000 CU-HP SO 1-954 ACSR AZ 1-795 ACSR AZ 1-954 ACSR AW 1-954 ACSR AW 1-954ACSRJl\Z. 1-2000 CU-HP SO 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 1-1431 ACSRAZ 1-795 ACSR AZ 1-1431 ACSR AZ 1-795 ACSR AZ 1-795 ACSR AZ 1-1431 ACSRAZ ~-1431 ACSR AW 1-1431 ACSRAZ 1-600 CU HT 1-795 AAC 1-795 ACSRJl\Z. 1-954ACSRJl\Z. 1-954ACSRJl\Z. 1-1431 ACSRAZ 1-600 CU HT 1-266 CU HO 1-336.4 ACSRAZ 1-350 CU HT 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 I 363,243,903 2,298,820,876 2,662,064, 779 FERC FORM NO. 1 (ED. 12-87) Page - ' Line No. 15,003,893 423.23 18,17 ,936 2,400 33,179,22! 36 Name of Respondent Date of Report (Mo, Da, Yr) This I!Jort Is: (1) An Original (2) A Resubmisslon Fi Florida Power & Light Company I I Year/Period of Report 2015104 End of "TRANSMISSION LINE STATIST CS 1. Report Information concerning transmission lines, cost of lil)es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4} underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column {g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. yOLTAGE (KV} (1\'hdlcate w!iere ot er than 60 cvcle 3 ohasel DESIGNATION Line No. From {a) To (b) Operating {c) Type of Supporting LE~GihH ~ole wiles) nt e s3o -unqlj'qcfure of Lm~ Structure DesiHna ed (e) f) Designed (d) Number u aergroun lines report circuit miles) 1 Of Ont~"t>l/ires o 110 er Line (g) Circuits (h) 9 DADE LITTLE RIVER 2 138.0[ SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 0.14 1 10 DADE LITTLE RIVER 3 138.0[ 138.00 H 0.15 2 11 DADE LITTLE RIVER 3 138.0C 138.00 H 0.14 2 12 DADE LITTLE RIVER 3 138.0[ 138.00 0.06 1 13 DADE LITTLE RIVER 3 138.0[ 138.00 0.22 1 14 DADE LITTLE RIVER 3 138.0( 138.00 15 DADE LITTLE RIVER 3 138.0( 138.00 16 DADE LITTLE RIVER 3 138.0( 138.00 17 DADE LITTLE RIVER 3 138.0( 138.00 1 DADE LITTLE RIVER 2 138.0( 2 DADE LITTLE RIVER 2 138,0( 3 DADE LITTLE RIVER 2 138.0( 4 DADE LITTLE RIVER 2 138.0( 5 DADE LITTLE RIVER 2 138.0( 6 DADE LmLE RIVER2 138.0( 7 DADE LITTLE RIVER 2 138.0( 8 DADE LITTLE RIVER 2 138.0( 138.00 SP SP SP SP SP SP SP 0.52 1 0.12 2 4.84 1 0.08 2 0.94 1 0.05 1 2.73 1 0.11 2 3.08 1 0.59 2 4.29 1 0.46 2 18 DADE LITTLE RIVER 3 138.0 138.00 19 DATURA STREET 20 DATURA STREET RANCH 138.0( 230.00 H RANCH 138.o< 230.00 6.95 21 DATURA STREET RANCH 138.0( 138.00 0.43 0.37 2 22 DATURA STREET RANCH 7.06 RANCH 138.0( 138.0( 3.33 23 DATURA STREET 24 DATURA STREET 0.03 2 1 RANCH 138.0( 0.32 1 25 DATURA STREET RANCH 138.0( 0.21 1 26 DATURA STREET RANCH 138.0( 27 DATURA STREET RANCH 138.0( 28 DATURA STREET WEST PALM BEACH 138.0( 29 DATURA STREET WEST PALM BEACH 138.0( 30 DATURA STREET WEST PALM BEACH 138.0( 31 DAVIS FLORIDA CITY 2 138.0C 32 DAVIS FLORIDA CITY 2 138.0C 33 DAVIS FLORIDA CITY 2 138.0C 34 DAVIS FLORIDA CITY 2 138.()( 35 DAVIS FLORIDA CITY 2 138.0( TOTAL 36 FERC FORM N0.1 (ED.12-87) SP SP 230.00 SP 230.00 SP 138.00 SP 138.00 SP 230.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 230.00 SP 138.00 SP 138.00 SP 138.00 UG Page 422.24 0.72 1 0.33 1 1 0.28 1 0.44 2 0.31 1 0.55 2 0.19 1 24.39 1 0.25 2 2.95 0.70 2 0.80 1 0.30 1 6,205.67 691.36 1,594 This ~ort Is: (1) An Original (2) [JA Resubmisslon Name of Respondent Florida Power & Light Company Date f Report (Mo, [ a, Yr) I I Year/Period of Report 2015/04 End of TRANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. ~eport Lower voltage Lines and higher volt ge lines as one line. Designate in a footnote if you do not Include Lower voltage lines with higher voltage lines. If two or more transmission line structu es support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If uch property is leased from another company, give name of lessor, date and tenms of Lease, and amount of rent for year. For any transmission line ot er than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the I ne, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ~ ffected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and term ~ of lease, annual rent for year, and how detenmined. Specify whether lessee is an associated company. 1D. Base the plant cost figures called for in columns (j) to (I) on the book cost at end of year. GO~ I Size of Conductor and Material (i) OF LINt (Include In Gotumn (iJ Land, EXPENSES,EXCE PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land (j) Construction and Other Costs (k) Total Cost Operation Expenses (m) (I) Maintenance Expense1 (n) 1-410 CU HD 1-4/0 CU HD 1-600CU HT 1-600CU HT 1-795AAC 1-795ACSR AW 1-795 ACSR AZ 1-795ACSR AZ 1-954 ACSR AZ 1-795AAC 1-795ACSR AZ 1-1431 ACSRAW 1-SOOCU HT -795AAC -795AAC 1-795ACSR AZ 1-795ACSR AZ -954ACSRAW 1-1431 ACSR AW 1-1431 ACSR AW 1-1431ACSRAW 1-1431 ACSRAZ 1-900CU HT 1-954 ACSR AW 1-954ACSRAZ 1-954 ACSR AZ 1-954 ACSR AZ 1-795AAC 1-795AAC 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AW 1-954ACSRTW 1-2500 CU-XPLE Total Expl':nses Rents (o) (p) Une No. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 i' 363,243,903 FERC FORM NO. 1 (ED. 12-87) 2,298,820,876 2,662,064,ns Page 15,003,893 18,1' ,936 2,400 423.24 ------ -~ 33,179,22S 36 ' This ~art Is: (1} An Original (2} [jA Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) Year/Period of Report 2015/04 End of I I TRANSMISSION LINE STATIST cs 1. Report information concerning transmission lines, cost of lir:wes, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines Include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1} single pole wood or steel; (2} H-frame wood, or steel poles; (3) tower; or (4} underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets arid extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are induded in the expenses reported for the line designated. VOLTfi)GE,J~,Yl (Indicate wtiere other than 60 cvcle 3 ohase) DESIGNATION Line No. To (b) From (a) Operating (c) 1 Designed Structure (e) (d) SP SP SP SP SP LUCY (HST) 138.0( 138.00 2 DAVIS 3 DAVIS LUCY (HST) 138.0( 138.00 LUCY (HST) 138.0( 138.00 4 DAVIS LUCY (HST) 138.0( 138.00 5 DAVIS LUCY (HST) 138.0{ 138.00 6 DAVIS PRINCETON 1 138.0< 138.00 H SP SP 138.00 SP 138.00 SP 138.00 SP 7 DAVIS PRINCETON 1 138.()( PRINCETON 1 138.()( PRINCETON 1 138.()( 10 DAVIS PRINCETON 1 138.()( 11 DAVIS PRINCETON 1 138.()( IB,t e fjfD u ergroun lines report circuit miles) Supporting 1 DAVIS 8 DAVIS 9 DAVIS LEMG~H ~ole wiles) Type of un ~tp,lcture of. Line Des1Qlated Number Of Circuits U!Jl*~!f,~res o no er Line (g) (h) 3.30 1 5.06 1 0.12 1,10 1 1 5.81 1 0.15 2 138.00 0.05 1 138.00 0.40 1 1.23 1 14.14 1 0.80 2 12 DAVIS PRINCETON2 138.0( 138.00 H 0.15 2 13 DAVIS PRINCETON2 138.DC 138.00 7.11 1 14 DAVIS PRINCETON2 13B.OC 138.00 15 DAVIS PRINCETON2 138.0( 138.00 SP SP SP 0.79 16 DAVIS VILLAGE GREEN 13B.OC 230.00 H 17 DAVIS VILLAGE GREEN 138.0( 138.00 18 DAVIS VILLAGE GREEN 138.0( 138.00 19 DAVIS VILLAGE GREEN 138.0( 138.00 SP SP SP 2.78 1 0.80 2 0.31 2.10 2 1 4.33 1 0.16 2 20 DEERFIELD BEACH YAMATO 1 138.0( 138.00 H 0.52 0.59 2 21 DEERFIELD BEACH YAMATO 1 138.0( 230.00 H 1.02 0.95 2 22 DEERFIELD BEACH 23 DEERFIELD BEACH YAMATO 1 YAMATO 1 138.0( 138.0( 0.19 9.51 24 DEERFIELD BEACH YAMATO 1 138.0( 25 DEERFIELD BEACH YAMATO 1 138.0( 26 EAU GALLIE HARRIS 138.0C 27 EAU GALLIE HARRIS 138.0( 28 EAU GALLIE HARRIS 138.0( 29 EAU GALLIE HARRIS 13B.OC 30 EAU GALLIE HARRIS 138.0C 31 EAU GALLIE MALABAR 138.0C SP SP 230.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 32 EAU GALLIE PATRICK 138.0C 33 EAU GALLIE PATRICK 138.0C 34 EAU GALLIE PATRICK 35 EAU GALLIE PATRICK 138.0 138.0( 138.00 Page 422.25 0.55 1 1 1.12 2 1.21 2 7.38 1 1 1.90 1 0.09 1 0.12 0.24 1 11.71 1 138.00 H 0.44 1 SP 138.00 SP 138.00 SP 7.32 1 0.20 2 0.02 1 138.00 TOTAL 36 FERC FORM NO.1 (ED.12-87) 138.00 6,205.67 691.36 1,594 Name of Respondent Date ~f R~ort (Mo, )a, r) I I This {!jort Is: (1) An Original (2) (]A Resubmlsslon Florida Power & Light Company Year/Period of Report 2015/04 End of TRANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. ~eport Lower voltage Lines and higher vol age lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line slructu es support lines of the same voltage, report the pole miles of the primary structure In column {f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent Is not the sole owner. If uch property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot er than a leased line, or portion thereof, for which the respondent Is not the sole owner but which the respondent operates or shares in the operatlor of, fum ish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the I ne, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terrr s of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns (j) to (1) on the book cost at end of year. t.;u::; 1 ut- LIN!= {Include in Column (i) Land, Size of Conductor and Material Q) EXPENSES,EXC PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land G) Construction and Other Costs (k) Total Cost Maintenar ce Expense (n) Operation Expenses (m) (I) Rents Total Ex~nses (o) (p) ~-795AAC Line No. 1 2 3 4 5 6 7 8 9 10 ~-795 ACSR AW 1-795 ACSR AZ 1-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AZ 1-1431 ACSRAW 1-795 AAC 1-954 ACSR AW 1-954ACSR AZ 1-954 ACSR AZ 1-954 ACSR AZ 1-1431 ACSR AW 1-954 ACSR AZ 1-954 ACSR AZ 1·954ACSR AZ 1-954 ACSR AW 1-954 ACSR AZ 11 12 13 14 15 16 17 18 19 1·954 ACSR AZ 1-954 ACSR AZ 1-954 ACSR AZ 20 21 22 1-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AZ 1-954 ACSR AZ 1-795ACSRAW 1-795 ACSR AZ 1-954ACSRAW 2-350CU HT 2-450AAC 23 24 25 26 I 27 28 29 30 31 32 33 34 1-795 ACSR AZ -1127 AAAC 1-1127 AAAC 1-1127 AAAC 1-954 ACSR AZ 35 I i i I 363,243,903 FERC FORM NO.1 (ED.12-87) 2,298,820,876 2,662,064,779 Page 15,003,893 18,1 2,93E 423.25 ~~ ----~-~ ~- 2,400 33,179,22[ 36 This ~ort Is: (1} An Original (2} EJA Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) Year/Period of Report End of I I 2015/Q4 TRANSMISSION LINE STATIST CS 1. Report information concerning transmission Jines, cost of lil)es, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage .. 2. Transmission Jines Include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission Jines for which plant costs are included in Account 121, Nonutrllty Property. 5. Indicate whether the type of supporting structure reported in column (e) is: {1) single pole wood or steel; (2) H-frame wood, or steel poles; {3} tower; . or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of constructron by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g), In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. VOkTAGE ~J)GE(~ lJt:.SIGNATION Line No. Operating (c) To (b) From (a) Type of (Indicate wtiere other than 60 cvcle 3 phase) Supporting Designed Structure (e) (d) LE~G~~ ra~le 0rpi!es) u ~ergroun1f11nes report circuit miles) Numbe Of Vn~Qctlire i on.&t~ures Circuits of L1n~ Des18)a ed of '(_nother 1ne (g) (h) 1 MIAMI RAILWAY2 138.0( 138.00 UG 1.18 1 2 MIAMI RAILWAY2 138.0( 138.00 UG 0.18 1 3 MIAMI RIVERSIDE 138.0( 138.00 0.01 1 4 MIAMI RIVERSIDE 138.0( 138.00 5 MIAMI RIVERSIDE 138.0( 138.00 SP SP SP 3.21 1 0.06 2 1 6 MIAMI RIVERSIDE 138.0( 138.00 UG 2.65 7 MIDWAY HARTMAN (FTP) 1 138.0( 230.00 H 3.51 1 8 MIDWAY HARTMAN (FTP) 1 13B.OC 138.00 0.10 1 3.62 1 0.77 1 0.52 1 6.00 1 9 MIDWAY HARTMAN (FTP) 1 138.0C 138.00 10 MIDWAY HARTMAN (FTP) 2 138.0C 138.00 11 MIDWAY HARTMAN (FTP) 2 138.0( 138.00 12 MIDWAY HARTMAN (FTP) 2 13B.OC 138.00 13 MIDWAY HARTMAN (FTP) 2 138.0( 138.00 14 MIDWAY HARTMAN (FTP) 2 138.0C 138.00 15 MIDWAY SANDPIPER 138.0C 138.00 16 MIDWAY SANDPIPER 138.0[ 138.00 17 MIDWAY SANDPIPER 138.0C 230.00 18 MIDWAY SANDPIPER 138.0( 138.00 19 MIDWAY SANDPIPER 138.0( 230.00 SP SP SP SP SP SP SP SP SP SP SP SP SP SP SP SP SP SP 20 MIDWAY SANDPIPER 138.0[ 138.00 21 MIDWAY SANDPIPER 138.DC 138.00 22 MIDWAY SANDPIPER 138.0( 23 MYAKKA ROTONDA RADIAL 138.0( 138.00 138.00 24 MYAKKA ROTONDA RADIAL 138.0( 138.00 25 MYAKKA ROTONDA RADIAL 138.DC 138.00 26 MYAKKA VENICE 138.0( 138.00 H 27 MYAKKA VENICE 138.(){ 230.00 H 28 MYAKKA VENICE 138.()( 138.00 29 MYAKKA VENICE 138.0( 138.00 30 MYAKKA VENICE 138.0( 138.00 31 MYAKKA VENICE 138.0( 138.00 32 OAKLAND PARK OAKLAND PARK 13KV DIST 138.0( 138.00 H 33 OAKLAND PARK POMPANO 138.0( 138.00 34 OAKLAND PARK POMPANO 138.0( 138.00 35 OAKLAND PARK POMPANO 138.0( 138.00 SP SP SP TOTAL 36 FERC FORM NO.1 (ED.12-87) SP SP SP SP Page 422.32 2.89 1 2.24 2 2 0.82 4.66 1 0.04 1 1.46 1 1.62 2 3.85 1 2.89 1.94 2 2 6.26 1 12.63 0.41 1 0.09 0.53 0.04 2 2 2 9.44 1 1.48 1 4.61 1 0.10 2 0.03 1 0.19 1 0.8:< 2 0.11 1 6,205,67 69t36 1,594 i : Date ~f Report (Mo, pa, Yr) I I This ~art Is: (1) An Original (2) []A Resubmission Name of Respondent Florida Power & Light Company Year/Period of Report 2015104 End of TRANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher val ~ge lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structu es support lines ofthe same voltage, report the pole miles of the primary structure In column (f) and the pole miles of the other llne(s) in column (g) B. Designate any transmission line or portion thereof for which the respondent Is not the sole owner. If ~uch property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line o rer than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares In the operatic of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the ine, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts ffected. Specify whether lessor, co-owner, or other party Is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and terrr s of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for In columns (j) to (I) on the book cost at end of year. cu::n Size of Conductor and Material (I) UF LINE (lnclu 1 Ul- LIN I:: Size of Conductor and Material (i) (Include In Column (J) Land, EXPENSES,EXCE PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land 0) Construction and Other Costs (k) Total Cost Operation Expenses (m) (f) Maintenan e Expense (n) Rents Total Expenses (p) (o) ~-2400 AL-XLPE Line No. 1 2 3 4 5 6 7 8 ~-1431 ACSRAW ~-900CU HT 1-1431 ACSRAW ~-1431 ACSRAW ~-1431 ACSRAZ 1-900CU HT ~-954 ACSR AW ~-2000 CU-HP SD ~-1431 ACSRAW 9 10 ~-954 ACSR AZ 11 12 13 14 15 16 17 18 ~-1431 ACSRAZ ~-556.5 ACSR AZ ~-556.5 ACSR AZ ~-1431 ACSRAW ~-1431 ACSRAW 1-1431 ACSR AW ACSR AW 2-556.5 ACSR AW ~-556.5 ACSR AZ ~-556.5 ACSR AZ 1-1431 ACSRAZ 1-1431 ACSRAW ~-1431 19 2{) 21 22 23 24 25 26 27 28 29 30 31 32 ~-1431 ACSRAW 1-1431 ACSRAW 1-1431 ACSRAZ 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AW 1-954 ACSRAZ ~-556.5 ACSR AW ~-556.5P ACSR AZ 1-1431 ACSR AZ 1-954 ACSR AW 33 34 35 ! I I 363,243,903 2,298,820,876 FERC FORM N0.1 (ED.12-87) 2,662,064, 779 Page ---- 18,1 172,936 15,003,893 2,400 423.34 -------------- -- --- ---- ------ 33,179,2~ 36 ; This ~ort Is: (1) An Original (2) A Resubmission Name of Respondent Date of Report (Mo, Da, Yr) EJ Florida Power & Light Company I I TRANSMISSION LINE STATIST Year/Period of Report 2015/Q4 End of cs 1. Report information concerning transmission lines, cost of li~es, and expenses for year. list each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Non utility Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g}. In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included In the expenses reported for the line designated. DESIGNATION Line No. To (b) From (a) 1 2 3 4 5 6 7 8 9 10 11 12 13 VOLTAGE (KV) (Indicate wnere other than 60 cycle 3 phase) RANCH WESTINGHOUSE RANCH WESTINGHOUSE RANCH WESTINGHOUSE RANCH WESTINGHOUSE RECWAY RIVIERA RECWAY RIVIERA RECWAY RIVIERA RECWAY RIVIERA RECWAY RIVIERA RINGLING PAYNE RADIAL RINGLING PAYNE RADIAL RINGLING PAYNE RADIAL RINGLING PAYNE RADIAL 14 RINGLING WOODS 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 RINGLING WOODS RINGLING WOODS RINGLING WOODS RINGLING WOODS RINGLING WOODS RINGLING WOODS RIVIERA WEST PALM BEACH RIVIERA WEST PALM BEACH RIVIERA WEST PALM BEACH RIVIERA WEST PALM BEACH RIVIERA WEST PALM BEACH RIVIERA WEST PALM BEACH RIVIERA WEST PALM BEACH RIVIERA WEST PALM BEACH RIVIERA WEST PALM BEACH RIVIERA WEST PALM BEACH SISTRUNK SISTRUNK DIST RADIAL YAMATO CALDWELL RADIAL YAMATO CALDWELL RADIAL YAMATO CALDWELL RADIAL Operating (c) 138.0( 138.0( 13B.OC 138.0( 138.0C 138.0C 138.0C 138.0( 138.0( 138.0( 138.0C 138.0( 138.0( 138.0C 138.0C 138.0U 138.0U 138.00 138.0( 138.0G 138.0 138.0 138.0 138.0( 138.0( 138.00 138.00 138.00 138.00 138.00 138.0! 138.0( 138.0( 138.0( 115.0( 115 KV LINES Supporting Designed (d) Page 422.35 LE~GJ,l;l role ~iles) Structure (e) 138.00 H 138.00 SP 138.00 SP 138.00 SP 138.00 H 230.00 SP 230.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 230.00 H 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 138.00 SP 230.00 H 138.00 H 138.00 H 138.00 H 138.00 H 138.00 SP 230.00 SP 230.00 SP 138.00 SP 138.00 SP 138.00 H 138.00 SP 138.00 SP 138.00 SP 115.00 H Number ot e asc:ro u dergroun lines report circuit miles} 1 un ~t[l!ctUre TOTAL 36 FERC FORM NO. 1 (ED. 12-87) Type of of Lm~ Desi(;a ed Of un_;::1.tru1h~res of 'l_IJO er Circuits (g) (h) me 6.25 9.05 0.26 11.75 2.31 0.43 1 1 1 1 1 1 0.85 2.62 0.57 2.84 1.06 1.29 0.01 0.07 0.68 0.03 1.08 8.77 0.05 0.92 1.13 0.45 0.70 0.03 2.00 3.60 0.10 0.32 2.65 0.07 0.02 4.96 1.08 0.23 141.84 7.68 6,205.67 691.36 2 1 1 1 1 2 1 2 1 1 1 2 1 2 1 1 1 1 1 1 1 2 1 2 1 1 2 1 1,594 Name of Respondent Year/Period of Report 2015/Q4 End of Date~ Report This f!prt Is: (1) An Original (2) [JA Resubmission Florida Power & Light Company (Mo, a, Yr) I I TRANSMISSION LINE STATISTICS (Continued) 7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher volt< ge lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structur as support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent Is not the sole owner. If such property Is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line ot~ er than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, fum ish a succinct statement expl!!ining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the II ne, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts a ffected. Specify whether lessor, co-owner, or other party is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and ternn of lease, annual rent for year, and how deternnined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns (j) to (I) on the book cost at end of year. I I I ~u;:; Size of Conductor and Material (I) 1 ur LIN I: (tncluae 1n Column {j) Land, EXPENSES,EXCE PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land (j) Construction and Other Costs (k) Total Cost Operation Expenses (m) (I) Maintenan e Expense: (n) Rents Total Expenses (p) (o) 2.J36.4 ACSR fliZ. 1-954ACSR AW 1-954 ACSR AZ ~-336.4 ACSR fliZ. -1431 ACSRAZ ~-1431 ACSR AW 1-1431 ACSRAZ 1-556.5 ACSR AW 1-900CU HT 1-795AAC 1-795ACSRfliZ 1-795ACSRfliZ 1-954 ACSR AW 1-795ACSRAZ 1-795AAC Line No. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 ~-795 ACSR AW M-795 ACSR AZ r-795 ACSR AZ 1-954 ACSR AW 1-954ACSR AW 1-1431ACSRAW 1-1431 ACSR AZ 1-900 CU HT ~-350 CU HT ~-556.5 ACSR AZ 1-1431 ACSR AW 1-1431 ACSR AW 1-1431 ACSR AW 1-1431 ACSR AZ ~-556.5 ACSR fliZ. 1-1431 ACSR fliZ. 1-954ACSRAW 1-954ACSR AW 1-954 ACSRAZ 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 I I 363,243,903 2,298,820,876 FERC FORM N0.1 (ED.12-87} 2,662,064,779 Page ---- - - - - - 15,003,893 18,1 72,936 2,400 423.35 ---- 33,179,22!1 36 This ~art Is: (1) An Original (2) [JA Resubmission Name of Respondent Florida Power & Light Company Date of Report (Mo, Da, Yr) I I Year/Period of Report 2015/04 End of TRANSMISSION LINE STATISTICS 1. Report Information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines Include all lines covered by the definition of transmission system plant as given In the Uniform System of A=unts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included In Account 121, Nonutlllty Property. 5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3} tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and {g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated: conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. Y,OJ,TAGE i~ (Indicate wliere other than 60 cycle 3 phase} LJt:::iiGNATION Line No. To (b) From (a) 1 2 Operating (c) 115KV LINES 115KV LINES Type of Supporting Designed (d) Structure (e) LENGTH ~ole wiles) the Scf IPrnes uhW,ergroun report circuit miles) ungn~~ure Desip;ated 115.0( 115.00 SP 566.73 115.0( 69.0( 115.00 UG 69.00 H 17.17 u~t\7~~eres of no er ne (g) Number Of Circuits (h) 42.10 0.29 3 4 69 KV LINES sg KVUNES 69.()( 69.00 SP 147.25 5 69KVLINES 69.00 69.00 UG 13.62 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 Costs TOTAL 36 FERC FORM NO.1 (ED. 12-87) Page 422.36 6,205.67 691.36 1,594 This ~ort Is: (1) An Original (2) DA Resubmission Name of Respondent Florida Power & Light Company Daleo Report (Mo, D a, Yr) Year/Period of Report 2015/04 End of I I RANSMISSION LINE STATISTICS (Continued) ~eport Lower voltage Lines and higher volta ge lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structur ~support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If s uch property Is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line oth er than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the II e, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts a fected. Specify whether lessor, co-owner, or other party Is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and term of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns (j) to (I) on the book cost at end of year. 7. Do not report the same transmission line structure twice. COST OF LINE (Include In Column (J) Land, Size of EXPENSES,EXCE PT DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Conductor and Material Land (i) (j) Construction and Other Costs (k) Total Cost Operation Expenses (m) (I) Maintenan e ExpensBl (n) Rents Total Expenses (p) (o) Line No. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 363,243,90 2,298,820,876 2,662,064,779 15,003,893 18,17 2,936 2,400 33,179,225 35 I 363,243,903 FERC FORM NO. 1 (ED. 12-87) 2,298,820,876 2,662,064,779 Page 15,003,893 18,1 2,936 423.36 ~-- ----- 2,400 33,179,22[ 36 Name of Respondent This Report is: (1) ~An Original I(2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015104 FOOTNOTE DATA \Scheduie-Paga:·42.·r-rTne No.~J.3 Column: a - The Duval-Hatch SOOkv line is jointly owned by the respondent (0.5%) and Jacks_o_n-v'i'l'l-e----~ Electric Authority (99.5%). Expenses of the line are shared based upon ownership percentages. The respondent's share of operation and maintenance expenses are charged to the normal transmission 0 & M expense accounts. The Jacksonville Electric Authority is not an associated compan~Y~·~----~------------- f$chedu/ePiige:422Line No.: 16 Co(t!_~!.'..~-~- ..... J The Duval-Thalmann 500kv line is jointly owned by the respondent (0.5%) and Jacksonville Electric Authority (99.5%). Expenses of the line are shared based upon ownership percentages. The respondent's share of operation and maintenance expenses are charged to the normal transmission 0 & M expense accounts. The Jacksonville Electric Authority is not an associated company. IFERC FORM NO. 1 (ED. 12-87) Page 450.1 BLANK PAGE (Next Page is 424) This Date of Report (Mo. Da, Yr) I f (1) (2) Florida Power & Light Company End of 2015/04 1. Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines. 2. Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (I) to (o), it is permissible to report in these columns the To 44 TOTAL FERC FORM NO. 1 (REV. 12-03) 19 Page 424 : ' (1) (2) Florida Power & Light Company Year/Period of Report 2015/04 End of Date of Report (Mo, D , Yr) This~ortls: Name of Respondent An Original f'iA Resubmission I I RANSMISSION LINE STATISTICS (Continued} 7. Do not report the same transmission line structure twice. ~eport Lower voltage Lines and higher volta e lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structure s support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line{s) in column (g) 8. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If s ch property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line oth r than a leased line, or portion thereof, for which the respondent Is not the sole owner but which the respondent operates or shares in the operation f, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the lir e, name of co-owner, basis of sharing expenses of the Line, and how the expenses bome by the respondent are accounted tor, and accounts af ected. Specify whether lessor, co-owner, or other party Is an associated company. 9. Designate any transmission line leased to another company and give name of Lessee, date and term s of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. 10. Base the plant cost figures called for in columns (j) to (I) on the book cost at end of year. COST OF LINE (Include 1n Column 0) Land, Size of Conductor and Material (I) EXPENSES,EXCE "T DEPRECIATION AND TAXES Land rights, and clearing right-of-way) Land (j) Construction and Other Costs (k) Total Cost Operation Expenses (I) (m) Maintenan !e Expenses (n) Total Expenses Rents (o) (p) ~-1431 ACSRAW Line No. 1 2 12-1431 ACSR AZ 12-1431 ACSR AZ ~-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AZ 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 -795ACSRAW -795ACSRAW 1-1431ACSRAW 1-3400ACSRAW 7-1691 AAAC 1-3400 ACSR AW -1691 AAAC -795ACSRAZ ?-954 ACSR AW 1-1431 ACSR AZ 1-1431 ACSR AW 1-954 ACSR AZ 1-954 ACSR AW 1-954 ACSR AW 1-954 ACSR AZ 1-954 ACSR AW 1-954 ACSR AZ 1-1431 ACSR AW 1-954 ACSR AZ 1-1431 ACSRAZ 1-1431 ACSRAZ 1-1431 ACSRAW 1-1431 ACSRAZ 12-954 ACSR AW 29 30 12-954 ACSR AW 1-795 ACSR AZ 1-1431 ACSRAW 1-1431 ACSR AW 1-795ACSRAW 31 32 33 34 35 363,243,903 FERC FORM NO. 1 (ED. 12-87) -·- 2,298,820,876 2,662,064,n9 Page 15,003,893 423.13 18,1 2,936 2,400 33,179,22[ 36 This~rtls: (1) An Original (2) [JA Resubmission Name of Respondent Florida Power & Ught Company Date of Report (Mo, Da, Yr) Year/Period of Report End of I I TRANSMISSION LINE STATIST 2015/04 cs 1. Report information concerning transmission lines, cost of II!JeS, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. 2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. 3. Report data by individual lines for all voltages if so required by a State commission. 4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. 5. Indicate whether the type of supporting structure reported In column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. 6. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. To (b) From {a) 1 2 3 4 5 6 7 8 9 10 11 Y,O~! AGt.J~:Vl (Indicate wtiere other than 60 cycle 3 phase) DE:.SIGNATION Line No. OSTEEN SANFORD PlANT OSTEEN SANFORD PlANT OSTEEN VOL USIA OSTEEN VOL USIA OSTEEN VOLUSIA OSTEEN VOLUSIA PENNSUCO DORAL (RRDC) PENNSUCO DORAL (RRDC) PENNSUCO DORAL (RRDC) PENNSUCO DORAL (RRDC) PENNSUCO MAULE (TARMAC) 12 PLUMOSUS PLUMOSUS DIST. 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 POINSETT BITHLO (DEF) POINSETT BITHLO (DEF) POINSETT BITHLO (DEF) POINSETT HOLOPAW (DEF) POINSETT SANFORD PlANT 1 POINSETT SANFORD PlANT 1 POINSETT SANFORD PlANT 1 POINSETT SANFORD PlANT 3 PORT EVERGlADES SISTRUNK 1 PORT EVERGlADES SISTRUNK 1 PRATT & WHITNEY RANCH PRATT & WHITNEY RANCH PRATT & WHITNEY RANCH PRATT & WHITNEY RANCH PRINCETON TURKEY POINT PUTNAM RICE PUTNAM RICE PUTNAM RICE PUTNAM ROBERTS PUTNAM SEMINOLE PlANT (SEC) PUTNAM SEMINOLE PlANT (SEC) PUTNAM SEMINOLE PlANT (SEC) PUTNAM SEMINOLE PlANT (SEC) 230.()( 230.()( 230.0C 230,()( 230.()( 230.()( 230,()( 230.0( 230.()( 230.0( 230.0( 230.()( 230.0( 230.()( 230.0( 230.0( 230.0C 230.0( 230.()( 230.0C 230.0C 230.0( 230.0( 230.0C 230.0C 230.0C 230.0C 230.0C 230.0C 230.0C 230.00 230.00 230.0 230.0( 230.0{ Designed (d) Structure (e) 230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 SP ·230.00 SP 230.00 SP 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 UG 230.00 UG 230.00 H 230.00 SP 230.00 SP 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 SP 230.00 SP 230.00 H 230.00 H 230.00 H 230.00 H TOTAL Page 422.14 Number Of u dergroun hnes report circuit miles) Supporting 1 Operating (c) 36 FERC FORM N0.1 (ED.12-87) LENG~H ~ole miles) ~In t e scf pf Type of un ~t[I,JCture of. Line Destmated 1 u~.q,l!_i!cttU!es of 'tjother ne (g) 1 1 1.05 1.78 2.74 0.88 0.04 6.12 45.13 3.44 1.03 16.60 0.33 0.12 3.85 10.57 14.08 1.33 0.13 0.21 0.43 7.06 1 2 1 1 2 1 1 1 1 1 1 2 1 1 2 2 2 1 1 1 1 1 2 1.33 3.71 6,205.67 (h) 1 2.4l 0.31 20.25 8.69 0.32 0.16 0.10 0.03 19.64 0.20 1.11 4.47 0.01 44.91 6.08 Circuits 691.36 1 1 2 1 1 2 1 2 1 1,594 Name of Respondent Florida Power & Light Company 1------.---=---r--1----r------..-------1 Line No. 6,339,826 FERC FORM NO. 1 (REV. 12-03) Page 425 44 This Report is: (1) ~An Original I(2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report {Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA !Schedule Page: 424 Line No.: 1 Column: a --------.--,---;---.--,-,----;- ---,----,-,;-:--=:::-=---.--,--~~~ Mileage correction occurred in 2015 filing associated with using as-built GPS data of 0.02 miles ~~~:~~::~~~2~;~-- a~in::a~·~;d~fo~~::,:~~ion inFo.th_e_H~ #2 230kv·: Festival station was cut and the net result of the two lines, Broward-Festival #1 230kV and Conservation-Festival 230kV, is 0.92 miles. !,Schedule Page: 4'24[ifii;;-fio::3· Column: a ___ ________ --------------------· Reported in 2014 as Broward-Conservation #2 230kV. Festival station---wa·s···cut into the line and the net result of the two lines, Broward-Festival #1 230kV and Conservation-Festival 230kV, is 0.92 miles. ~cheduJ.~f.~9~.:.~~'!_. Line No.: 3 -··coTufiin": .. Line costs are included in the Broward - Festival' r· c:l_esignation -----·--···--·----------, I,SCheiiiiie-Pagi:-424 · Line No.: 4 Column: a ... ~-=~~-~-~~---Reported in 2014 as Broward-Mallard 230kV. Festival station was cut into the line and the net result of the two lines, Broward-Festival #2 230kV and Festival-Mallard 230kV, is 0.77 miles. ----------------------------------------~~-~q~le Page': 424-·unfiFio~:-;;. Column: o Line costs are included in the Broward - Fetitiv.al 1 designation ~chedufe Page: 424 Line No.: 5 _ t;o.f.umn: a .... Reported in 2014 as Broward-Mallard 230kV. Festival station was cut into the line and the net result of the two lines, Broward-Festival #2 230kV and Festival-Mallard 230kV, is 0.77 miles. [chiduie-Page?424" - Line No.: 5 c~f~f!!!?.:_t:'_ _ Line costs are included in the Broward --~~~--~~-~~--Festival 1 designat:i'?!._l _ ' - - - - - - _ - _ -__-______-_____-_____-___ -___ !schedule P~~~?.t!___ ~i.'1.~f!.C).: 6 ci>iumn: a Reported in 2014 as Cedar-Riviera 230kV. Breakers were installed at Fountain station and the net result of the two lines, Cedar-Fountain 230kV and Fountain-Riviera 230kV, is 0.05 miles. [SChedule Page: 424 Line N~::_I_ ____f~o:..:,lu:::.:m~n'"'=:7a-==--=----,----Reported in 2014 as Midway-Ranch 230kV. Breakers were installed at Treasure station and -the net result of the two lines, Midway-Treasure #1 230kV and Ranch-Treasure 230kV, is 3.43 miles. [Schedule Page: 424 __ Mf!~_!i(;)~:_l! Column: a . ~ Reported in 2014 as Midway-Ranch 230kV. Breakers -:wer:e-'lnstalled at Treasure-sEat:Lon-- and the net result of the two lines, Midway-Treasure ~1 230kV and Ranch-Treasure 230kV, is 3.43 miles. 1$-ciiedu/e Page: 424 Line No.: B___~f?!'!.!!!!!:_o_----==-------::---.--=-_____________________________ _ Line costs are included in the Midway - Treasure 1 desig!"i~tion !Schedule Page: 424 - --~!n~_ fio.: 9 ·--coiuliin":"a ----------Reported in 2014 as Midway-Ranch 230kV. Breakers were installed at 'fr.easure-·s-tation and the net result of the two lines, Midway-Treasure 111 230kV and Ranch-Treasure 230kV, is 3.43 miles. ~chedu-=-le-P=-a-g_e_:_4::-:2--=4,---=-L-=-in_e_N-:-:-o-.:-1=-=o,-----=c=-o--=tu,--m_n_:-a Reported in 2014 as Midway-Ranch 230""k;-;V~.-::::B-r_e_a..,.k_e_r_s_w_e_r_e-installed at Treasure statTon---ancf-the net result of the two lines, Midway-Treasure #1 230kV and Ranch-Treasure 230kV, is 3.43 miles. IScheiiule Page: 424 Line No=-~ 1f!. . ____c;_olumn: o ... ______ ____] Line costs are included in the R_a_n_c-;-h-----=T=-r_e_a_s_u_r_e_d:-e-signafion [chedule Page: 424 Line No~:.1L Coluliiii?·a · --Reported in 2014 as Midway-Ranch 230kV. Breakers w-ere-Installed at Treasure--station and the net result of the two lines, Midway-Treasure #1 230kV and Ranch-Treasure 230kV, is 3.43 miles. '"'] !schedule Page: 424 Line No.: 11 coliimri:-a· Line costs are incl udecCinth-e---:R:::-a-n-'---'c""h----=T:-r-e_a_s_u_r_e_designa tion o ______________ --] -_-:::=J--, 'I lFERC FORM N0.1 (ED.12-87) Page450.1 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original (2) A Resubmission D< te of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA fScii;dule Page: 424 Une No.;_!2 coiiimn.-·a---------·---------+-----------Reported in 2014 as Emerson-Midway 230kV. The new line name is Emerson-Treasure 230kV with a net result of an additional 3.15 miles. ------------+--------------------, !Schedule Page: 424 Line No.: 13 Column: ~----m-=,-----:---.------·-·----,--+------=------:::-oc------~ Reported in 2014 as Emerson-Midway 230kV. The new line name is Emerson-Treasure 230kV with a net result of an additional 3.15 miles. !Schedule Page:~?.~ Line No.: 13 Column: o ________ j Line costs are included in the Emerson - Treasure designation ·--------------. !Schedule Page: 424 Line No.: 14 Column: a_____ --Reported in 2014 as Emerson-Midway 23DkV . The new line niiiTLe· is Emerson-Treasure 230k\Y". with a net result of an additional 3.15 miles. ~chedule Page: 424 Une No.: 14·---Column: o _______-;_----.-,.-_-_---,-_--,-____~ __+-_-------~-~~----_--_. ·_·····_----_---_··--_--=_-=_-=_-=_-=_-=.-=--=--=-----------,_1 Line costs are included in the Emerson ~ Treasure designation ~hedule Page: 424 Line No.: 15 Column: a --- -·- -cJ Reported in 2014 as Midway-St Lucie #3 230kV. The new line name-is St Lucie-Treasure 230kV with a net result of an additional 0.08 miles. r,Sciile-Ciiife -Page: 424 Line No_._;_J,_~_ Column: a ___ _ - -·· ----- --Mileage correction occurred in 2015 filing associated with usipg as.:.::built GPS data of 0.57 miles [Schedule Page:~?.~. Lineiio.: 17 Column: a ---- --- ·· · --Reported in 2014 as Collier-Belle Meade Radial 138kV. The n-e-w-t-l..,.i_n_e_n_a_m_e----oi-s----=B,---e...,l,...l--e- - Meade-Collier #1 138kV with a net result of -0.15 miles. -_·-========:-._-__ _-_;_-_-_-_-:__-··_·--_______________ ---..-J ~::~~~:~;e:2~~~ -it-f!;:i~i :~-Be~~~~~~:a~e Radla 1 1 ~~--~~==-.=--T=--h.::..e_n_e_-;;;--·l-r-I-n~e~~n--a-·-~--e-····-...,-~--s---=B-e-=1-=l-e____ -·· · j Meade-Collier #1 138kV with a net result of -0.15 miles. ~ch_!.~l.![e. !:!._age: 42i .Line No.: 18 CCJ!I.!IJln: o ·--. _ --. --+----___-___ -___ -_-__ -_---------~~~-------···-_-··_--_··-_--_.-1 Line costs are included in the Belle Meade - Collier 1 designc: tion __ . ___ --·-·--------, !sciiiMiuie Page: 424 Lin! f>!C?.-_; 19 Column: a __ .. ___ --_ .. -----------.------;:~--;;------- ___] Reported in 2014 as Collier-Rattlesnake Radial 13BkV. The new line name is Belle Meade-Collier #2 138kV with a net result of an additional 0.2E miles. ~~f.!edule Page: 424 Line No.:~!! __ folumn: c,--· __ ·- _ .... ___-_--_--_··_··_····:_~---_-_-_-_-_-_- -.__, Line costs are included in the Belle Meade - Collier 1 designction ~chedule Page·:--424 Line N_o_~-= 2o__ Column: a - -. -·· -- -Reported in 2014 as Collier-Rattlesnake Radial 13BkV. The new line name is Belle Meade-Collier #2 138kV with a net result of an additional 0.2E miles. [chegf!_l~f'_~ge:-424 --Line No.: 20 C~-~U_f!ln: o --- _____ -···---··· _____________-·_·_····_·--_-··---~===== Line costs are included in the Belle Meade - Collier 1 desi~g~-n~thers, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated unde lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by rea ~on of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between th parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, o other party is an associated company. Capacity of Substation (In Service) (In MVa) Number of Transformers In Service (f) {g) Number of Spare Transformers Type of Equipment (h) (i) CONVERSION APPAR 1\TUS AND SPECIAL EQUIPMENT 55 1 0 Number of Units Total Capacity (In MVa) 0) (k) i Line No. 1 90 3 0 2 110 2 0 3 85 2 0 4 110 2 0 5 44 2 0 6 90 2 0 7 110 2 0 8 60 2 a 9 110 2 0 1a 1120 2 a 11 14 1 0 12 110 2 0 13 60 2 0 14 1120 2 0 15 14 1 0 16 110 2 0 17 0 19 0 20 1435 18 10 0 21 0 22 0 23 0 24 0 25 0 26 0 27 0 28 0 29 0 30 a a a 32 31 33 34 35 36 37 38 39 40 FERC FORM NO. 1 {ED. 12-96) Page 427.16 ------ --- -- Name of Respondent This Report is: (1) 6An Original I{2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA !Schedule Page: 426.16 Line_~N~o~.::_1~8~~C~o~l!!.;um=n_,_:!....f Capacity Summary (MVA) : ----------·====---_--_------=-==~-------·-·--==--····_---_-_-_-_-_-_-_-_-_-_-_-_------, Transmission Distribution Total IFERC FORM NO.1 (ED. 12-87) 94,688 48,304 142,992 Page450.1 BLANK PAGE (Next Page is 429) Date of Report {Mo, Da, Yr} I I nt Florida Power & Light Company 1. Report below the information called for concerning all non-power goods or services received from or Year/Period of End of 2015/04 to associated (affiliated) companies. 2. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not such as "general". attempt to Include or aggregate amounts in a nonspecific 3. Where amounts billed to or received from the associated are based on an allocation process, explain in a footnote. Name of Associated/Affiliated Company Line No. FERC FORM NO. 1 (New) FERC FORM NO. 1-F (New) Page 429 nt Charged or Credited ' i I Name of R~spond~:mt This (1) (2) Florida Power & Light Company m Dateg~ ~~ort ~~~Fis: An Original I I A Resubmission riONS WITH Ac:tc:tnr Year/Period of Report 2015/04 End of (Mo, IJ\TED IAI:I:II I..TED) 1. Report below the "I""' 1""1u1, called for concerning all non-power goods or seJVices received from or p~ lvided to associated ·'''"~~~~·~~(e~L 1ies. 2. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount ~itled to the respondent or to an associated/affiliated company for non-power goods and seJVices. The good or seJVice must be speci fie in nature. Respondents should not attempt to include or aggregate amounts in a nonspeclfl~ ;:!;.?_~~such as "general". 3. Where amounts billed to or received from the associated '·" company are based on an process, explain in a footnote. Account Amount Name of Line Charged or Charged or Asso~ated/Affiliated No, Description of the Non-Power Good or SeJVice Credited Credited ~u" "I (a) 1 "' I~U" ....... ~ .., · Goods or.,, u,.o ·"· "~"'" ~ lby ~· 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 N:..., -........ ~,·Goods 21 c:t .. n.l~~ or~~ Provided by FPL 22 23 ·~·- 1umu•n• for Affiliate ~ 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 FERC FORM NO. 1 (New) FERC FORM NO. 1-F (New) Page 429.1 ---- -· ~--- ---- --· Name of Respondent This Report is: (1) ~An Original (2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report {Mo, Da, Yr) I I 2015104 FOOTNOTE DATA r;;;~""c-'-"h"""ed~u""l""e__,_-fi~a="'g..,-e,__:-'-"4""2-'0.9-.-7L:=:.in!=e::=N:::-o~.,__:""2'--..~!!l'!!!Jn: d=--------=---~-----~services Services Services Services Total Received Received Received Received by by by by FPL FPL FPL FPL Account Account Account Account _______________] 234 588 916 923 87,778 26,920 572,723 434 687,855 !Schedule Page:_~29 ____ f:}ne ~o._:___~---~C-=-o=-=Ju7m::.:ne:.::--=d=------=-----:------· 2:3_2 _________ _ Fiber Network and Telephone Services Account Services Received by FPL Account 234 TOTAL r.::--:----::--:---=::---:-::-:::-----:-:-----:-:----=----- ............................. ._ __ 13,560,973 1,223 13,562,196 ~---------------------- ~d~~E~g~:429=--~L=i~n~e~N~o~.:_4~~C~o~/~u~m~n~:~d----~~-~--- Inventory Purchase Account 234 39,200 Services Received by FPL Account 234 355,233 Services Received by FPL Account 517 274,706 Services Received by FPL Account 520 316,086 Services Received by FPL Account 524 800,530 Services Received by FPL Account 528 278,317 Services Received by FPL Account 532 2,861 Services Received by FPL Account 922 1,519 Total 2,068,452 l§cl!~'!!~ _f?Eig_~: 42~_---.:L=-in:.:..e=-N~o.c:..:--=-6--=-C-=-o/::.::u:.::.:m..:.::n..::.:_;:·d'--···-_-_-_·---------:;;----,------------------------,-,~---------------. _--...""' ..... "" .....-c .....""'-~~ Inventory Purchase Account 234 33,496 Services Received by FPL Account 234 83,106 Services Received by FPL Account 517 62,117 Services Received by FPL Account 520 72,462 Services Received by FPL Account 524 73,743 Services Received by FPL Account 528 44,950 Services Received by FPL Account 531 5,500 Services Received by FPL Account 532 7,186 Total 382,560 l§chedufe Pag__~_: ~?.~ _ Line No.: 10 Column: d Services Received 'byFi>r;--- _______::_:::.::.:c:.::_:_:_:c_::___ _ _ _ _--::A-c_c_o_u_n-ct,-----Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account IFERC FORM NO.1 (ED.12-87) Page 450.1 ------ 234 426 500 501 506 512 517 524 528 531 532 546 549 553 557 560 561 580 588 901 903 908 ------~ 5,128,924 17,662 30,366 786,038 2,483,957 96,190 8,276 662,909 6,304 5,712 721 59,474 64,613 52,379 3,341 157,800 666 196,643 99,475 20,557 4,817 (2, 739) Name of Respondent This Report is: D~te ts Florida Power & Light Company Services Services Services Services Total Received Received Received Received ~~~qf!le Page: 429 Services Services Services Services Total Received Received Received Received by by by by FPL FPL FPL FPL Account Account Account Account Received Received Received Received Received Received Received Received Received Received Received Received Received Page: 2015/04 910 916 922 923 119,463 1,578 1,839,417 90,682 11,935,225 J Line No::·":,-:{-----:c=-o---:1:-um_n_:-::d=------------by FPL -----·--····-A=-c_c_o_u_n-:t-----+----:2:-c3o-4-:------·--·--·----33~-159 by FPL Account 426 609 by FPL Account 501 273,691 by FPL Account 922 188,759 798,218 ----·- ~hec!.Lil~f.~g~;.·~?..~___ f-ine No::-;;2·-- Column: d Services Services Services Services Services Services Services Services Services Services Services Services Services Total of Report Year/Period of Report Mo, Da, Yr) I I (1) An Original (2) A Resubmission FOOTNOTE DATA by by by by by by by by by by by by by .. --~---t---2:::-:3,-;4c------------=-420, 151.J Account -•·-····~·w·-- FPL FPL FPL FPL FPL FPL FPL FPL FPL FPL FPL FPL FPL ·------ Account Account Account Account Account Account Account Account Account Account Account Account ~C:Ileciule .i29 Line No.: 14 Services Received by FPL Services Received by FPL Total Column: d ····---··-··-- ~Ciiedu/e Page: 429 Line No.: 15 Inventory Purchase Services Received by FPL Services Received by FPL Services Received by FPL Services Received by FPL Services Received by FPL Services Received by FPL Services Received by FPL Total Column: d 426 500 501 506 513 517 524 552 553 907 910 922 ·----, ·---· ·····--·· ····--·-=2"3""-4·-------5=-1•1=--,1•5~o;o;--' 583 3,108 514,258 Account Account - ·····• ··---·-··- - - - - - - - - + - - · · · · · Account Account Account Account Account Account Account Account ----. ~---- [Schedule Page: 429 Line No.:_1_6 _____c_o_l_u-'in--'--n_. :_d--'---·-_·~~~~~~~~:~~~~-=----·--·-···· Inventory Purchase Accounf-Services Received by FPL Account Services Received by FPL Account Services Received by FPL Account Total ~C!ie-d=-u-,-le-P-=a_g_e_:_4-=-=2=-=9,-----=L--=in-e----=-N-=-o-.:-,2=-_1=______-___-c=-o-,l:-u-m_n_:_d--,----·- ------,r----------- 12~87) ---···· 234 234 517 520 524 528 531 922 ... ·-·-·-·----· ····---~ 25,331 438,010 28,716 132,076 132,746 103,231 1,582 49,540 911,232 ·- · -----------------, 234 234 922 923 5,474,361 549,060 359,948 141,198 6,524,567 ---·-·--------------+---·-·---·-- · · - · - - - - - - - - - - - - - - , Corporate Real Estate Services----------=A:-c_c_o_u_n_t.,--·--·----··-·· -··-·· Information Management Support Account Project Development Account Total FERC FORM NO.1 {ED. 7,564 1,199 254,714 147,295 5,929 253,342 181,142 36,451 6,682 7,969 514 891,878 2,214,830 Page 450.2 146 146 146 990 215,929 676,953 893, 872 This Report is: ( 1) ~ An Original (2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) 20151Q4 I I FOOTNOTE DATA Line No.: 22 Col~um=n~:~d--------=-----:-------::--:-:.--Revenue Enhancement Support Account 146 Corporate Services Charge Account 922 Customer Care Center Charges Account 146 Space & Furniture Billing Account 454 Corporate Finance Services Account 146 Corporate Real Estate Services Account 146 General Counsel Services Account 146 Human Resources Services Account 146 Bill Insert Services Account 146 Corporate Services Account 146 Sale of Asset/Inventory Account 146 IM Management Support Account 146 Total /§chedule Page: 429 ~~edule Page: 429 Line No.: 23 · - - - - - o - - : - - - - - - - - - - - - - - - - - - -.. -·-"··----------------, Column: C!_ ______ _ Account Account Account Account Account Account Account Account Account Account Account Account Account Account Account Account Corporate Services Charge Transmission & Substation Support Pole Attachment Revenue Human Resources Services Integrated Supply Chain Services Information Management Support Space & Furniture Billing Internal Audit Services Corporate Real Estate Services General Counsel Services Corporate Finance Services Corporate Services Marketing and Communication Strategy and Corporate Development Sale of Asset/Inventory Fleet Services Total ~~-e..ct.!lle Page: 429 Line No.: 26 2,534,530 1,281,930 948,642 198,270 68,858 1,994 26,424 97,786 106,248 4,597 4,346 693 5,274,318 Column: d ___............ . . Human Resources Services Information Management Support Power Generation Division Support Transmission and Substation Support Sale of Asset/Inventory Sale of Asset/Inventory Total Account Account Account Account Account Account 3,279,905 4,242,518 1,714,561 406,634 357,067 398,500 146,151 97,299 81,958 44,3!34 27,959 21,347 18,459 7,283 3,122 389 10,847,536 922 146 146 146 146 146 454 146 146 146 146 146 146 146 146 146 . ___::=J 146 146 146 850 53,986 431,561 25,098 1,164 5,889 518,548 146 146 146 ---······--·-···------------------- ~CiuleP"iige: 429 Line."!'!.::.. 2!_ Column: d Human Resources Services · --==~~~~-------A~c_c_o_u_n~t--------Information Management Support Account Power Generation Division Support Account Transmission and Substation Support Account Sale of Asset/Inventory Account Corporate Services Account Total l§j;h~£!..Ie Page: 429 Line No.: 28-- ·-c'OTii/nn:d Corporate Services Charge Corporate Services Corporate Real Estate Services General Counsel Services Human Resources Services IFERC FORM NO. 1 (ED. 12-87) lf6" . 904 45,948 202,945 15,037 146 146 146 146 146 32,060 2,608 299,502 ··--·---··-·· --·xccount Account Account Account Account Page450 .. 3 922 146 146 146 146 ···-····-- - - - - - - - - - , ··goT; ;g5 46,266 16,617 80,349 21,277 Name of Respondent Florida Power & Light Company This Report is: 1 (1) ~An Original {2) A Resubmission D;;te of Report Year/Period of Report (~o. Da, Yr) I I 2015/04 FOOTNOTE DATA Information Management Support Regulatory Affairs Support Transmission and Substation Project Estimating,Design Support Space & Furniture Billing Fleet Services Sale of Asset/Inventory Total Account Account Account Account Account Account Account 146 146 146 146 454 146 146 106,558 6,708 230,405 107,175 27,381 4,978 4,541 1,559,710 ~ched__u/e eFJ:g_~__42~- Line No.: 29 Coium·-n--:- - ; d - - - - - - - - - - - - - - 1 - - - - - - - - - · · · · - - - - - - - - - - , Corporate Real Estate Services Account -- · ·-·-,-------,1'4"6,.-----------;;-3""'6""7,...,"""8"'5"0-' General Counsel Services Account 146 19,819 Human Resources Services Account 146 106,863 Information Management Support Account 146 684,457 Power Generation Support Account 146 2,426,770 Project Estimating,Design Support Account 146 16,309 Marketing and Communication Account 146 3,472 Corporate Services Account 146 94,616 Total 3,720,156 =·--=-------·==========:::=::::: 281,452 ~ched_L!'-!! f.I!Jg~; :~?_!}.__ Line No.: 30 - colUm--n-:-cd:------------..-.. .-.. .-.~~r----··~·-· Corporate Services Charge Account 922 Corporate Finance Support Account 146 Space & Furniture Billing Account 454 Corporate Real Estate Support Account 146 Executive Services Account 146 General Counsel Support Account 146 Information Management Support Account 146 Regulatory Affairs Support Account 146 Strategy & Corporate Development Account 146 Integrated Supply Chain Services Account 146 Marketing & Communication Services Account 146 Total ..... 668,614 248,323 44,407 104,185 74,938 33,185 8,325 84,101 5,385 21,063 1,573,978 - ···-····--· .. 146 146 146 146 146 146 146 146 146 146 146 146 '§chedule Page: -~2..~_____ L:fne No.: 32 ----coiiim_n_:-d,--------------=·--r-r-·----.,..---,-·--""'---_·-----:;--~;o--;"""" Energy Marketing & Trading Support Account______ ·····--146 1, 565,891 Corporate Services Account 146 8,090 Corporate Real Estate Services Account 146 4,373 General Counsel Services Account 146 407,165 Human Resources Services Account 146 110,011 Information Management Support Account 14 6 521, 168 Fleet Services Account 146 3, 602 Total 2,620,300 FERC FORM NO. 1 (ED. 12-87) Page 450.4 Name of Respondent Florida Power & Light Company This Report is: (1) ~An Original (2) A Resubmission Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA lschedule Pag~; 429 Line !J_p.:}~-----~C~o~lu~m~n:__:d=--------=------c------corporate Services Charge Account ··-sr~r2-Information Management Services Account 146 Space & Furniture Billing Account 454 Corporate Finance Services Account 146 Corporate Services Account 146 Corporate Real Estate Services Account 146 Distribution/Quality Support Account 146 General Counsel Services Account 146 Environmental Support Account 146 Human Resources Services Account 146 Production Assurance Support-WMS Account 146 Regulatory Affairs Support Account 146 Strategy & Corporate Development Account 146 Integrated Supply Chain Services Account 146 Power Generation Division Support Account 146 Transmission & Substation Support Account 146 Internal Audit Services Account 146 Fleet Services Account 146 Marketing & Communication Services Account 146 External Affairs Account 146 Sale of Asset/Inventory Account 146 Sale of Asset/Inventory Account 146 Project Estimating & Design Services Account 146 Total 71,623,611 17,565,604 7,089,345 2, 511, 581 351,321 833,107 64,414 953,061 50,528 2,204,570 2,074,295 242,911 113,838 655,770 946,198 645,369 1,418,581 70,446 65,798 25,000 538 555 1,119,566 11o-;626, oo1 ~hedule Page: 429 Line No.: 34 c;o!!!!!!/!:._r!______= - - - - - - - - , - - - - Nuclear Operations Support Account Power Generation Division Support Account Transmission & Substation Support Account Corporate Finance Services Account Corporate Real Estate Services Account General Counsel Services Account Human Resources Services Account Marketing and Communications Account Corporate Services Account Sale of Asset/Inventory Account Information Management Support Account Integrated Supply Chain Services Account Fleet Services Account Strategy and Corp Development Account Total !Schedule Page: 429 Line No.: 35 Coiumn: d Nuclear Op-e rat ions-Supp_o_r_t __ ·----==~:.:_:=-------:A=-c-c_o_u_n-,-t_ __ Power Generation Division Support Account Corporate Finance Services Account General Counsel Services Account Human Resources Services Account Marketing and Communications Account Sale of Asset/Inventory Account Sale of Asset/Inventory Account Information Management Support Account Integrated Supply Chain Services Account Fleet Services Account Strategy and Corp Development Account Total IFERC FORM NO. 1 (ED. 12-87) Page 450,5 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 146 8,041,665 494,339 3,237 55,069 720 56, 167 117,126 122,079 3,232 84,812 2,118,281 423,682 351 1,500 11,521,660 7,504,941 256,752 26,319 73,661 170,682 133,791 16,411 7,628 2,018,213 366,762 1,335 --------=:1, 0 50 10, 577·, 545 Name of Respondent This Report is: ( 1) ~ An Original I(2) A Resubmission Florida Power & Light Company Date of Report Year/Period of Report {Mo, Da, Yr) I I 20151Q4 FOOTNOTE DATA [SChedule Page: 429 Line No.: 36 Column: d Corporate Services Charge Space & Furniture Billing Corporate Services Corporate Real Estate Services General Counsel Services Human Resources Services Information Management Support Regulatory Affairs Support Operations Support Project Estimating & Design Support Total .------m----------------·--- Account Account Account Account Account Account Account Account Account Account 331,034 258,291 5,481 24,891 169,180 36,626 9,776 48,104 6,010 45,771 935,164 454 146 146 146 146 146 146 146 146 -·--··----~~-- '[SCiiedule Page: 429 Line No.: 37 Corporate Finance Services General Counsel Services Human Resources Services Corporate Services Total Column: d -·······---··-------·-------;::-----,------ --------Account Account Account Account -- · --] --~-=--=-----------------::c-=-~~- 146 146 146 146 -·-··· ·---· - - - - - - - - - - - - - ' ........._. __________ [Schedule Page: 429 Line_N_q._: 3_1!.. __ Column: d 7 -······-· Corporate Services Charge -~~~~~----~~-Account Corporate Finance Services Account Corporate Real Estate Services Account Human Resources Services Account Information Management Support Account Marketing & Communication Services Account Total l§cii"idliie Page: 429 Line No.: 39 Column: d Power Generation Division Suppoi"f--······· ·.. ·n-~ Transmission & Substation Support General Counsel Services Human Resources Services Information Management Support Sale of Asset/Inventory Strategy & Corporate Development Total --·-·· .. ............... - .... 922 146 146 146 146 146 . . . '. ---1 ---+----:;-~---------,:--;--.-----,"""- 146 146 146 146 146 146 146 Account Account Account Account Account Account Account ~--- ·-·- 341,780 17,815 410 3,032 10,300 2,396 1,110 376,843 ................,.. ___l 308,964 8,359 6,034 3,135 26,308 64 9 986 354,435 ····--··· -------·· ·--·-··- - - - - - + - - : : - - - ·-------·--------------· ----- "' ---- 146 146 146 Account Account Account _::,J 279,759 20,624 8,982 309,365 --·-· \§_~1)-~!!..'!!~...?,~g~: ~?:_9 _____pne No_:-42 ___ iialiiliin: d Power Generation Division Support Project Estimating & Design Services FERC FORM N0.1 (ED. 12-87) 220,601 12,654 24,757 6,443 1,020 40,400 305,875 --------- ---------1----------------------- .. ---------------:---::--::----::------- ------------------1--------------- ............... . [Ciiedu/e Page: 429 Line No.: 40 Column: d .. --Power Generation Division Supporf"'"---------=------:----146 Account Transmission & Substation Support 146 Account General Counsel Services Account 146 Human Resources Services 146 Account Information Management Support 146 Account Sale of Asset/Inventory Account 146 Sale of Asset/Inventory 146 Account Total [~c_fJ..i!!!~l~ f?_~g_£!_;_~_~!!_ Line ·iia::41"-- Column: d Project Estlffiating & Design Services Power Generation Division Support Corporate Finance Support Total 39,434 9,205 399,206 62,969 510,814 ------------- --:------t---,;;---;-;=------.-.,....--c· ___ .,] Account Account 146 146 l Page 450.6 -------- 174,716 162,072 --~--- This Report is: {1) ~An Original I(2) A Resubmission Name of Respondent Florida Power & Light Company Date of Report Year/Period of Report (Mo, Da, Yr) I I 2015/04 FOOTNOTE DATA Account Account Account Account Account Account Account Account 146 146 146 146 146 146 146 146 60,491 14,449 87,125 12,847 18,897 3,504 5,119 1,150 540,370 Line No.: 21 Co/um.:..:..n.:..:..:-=d'---------==--Account HEI Acquisition Activities Account Information Management Support Account Transmission & Substation Support Account Power Generation Division Support Account Project Estimating & Design Services Account Corporate Finance Services Total 146 146 146 146 146 146 5,981,846 62, 941 5,507 2,425 2,691 1,479 056,889 Transmission & Substation Support General Counsel Services Human Resources Services Information Management Support Corporate Finance Services Corporate Real Estate Services Corporate Services Internal Audit Services Total ~cty_Le._!'age:-42.if1 fSchedule Page: ~g!J:.1__Line 6: Nt;::· 22 Column: r! _ THIS FOOTNOTE APPLIES TO ALL ACTIVITY Pos=T=E=D~T=o::--:A=-c=--c=--o=u=N-=T=--'i4..6 ON PAGE 4 2 9: Services provided to affiliates are recorded in FERC Account 146 (Accounts Receivable from Associated Companies). In FPL records, activity is netted at the GAAP account level before the balances are translated to FERC accounts. Therefore, the FERC account offset to the 146 account is not separately identifiable. THIS FOOTNOTE APPLIES TO ALL ACTIVITY WITH THE DESCRIPTION "CORPORATE SERVICES CHARGE" ON PAGE 429: Services provided by FPL primarily include executive & governance, finance & accounting, corporate communications, legal, corporate real estate, human resources, payroll, security, internal audit, information management operations and maintenance, and license fees. Services are allocated to affiliates using specific drivers such as headcount or number of workstations. If costs cannot be attributed, the services are allocated using the Massachusetts Formula. lFERC FORM NO.1 (ED. 12-87) Page 450.7 INDEX Schedule Page No. Accrued and prepaid taxes .............................. , .....• , ..•..•....•....•.................. 262-263 Accumulated Deferred Income Taxes .....•.... , . . . . . . • . . . . • . . . . • . . . . . . . • . . . . . . . ..........•.•....•..•... 234 272-277 Accumulated provisions for depreciation of common utility plant . , ........ , .... , .................................. . 356 219 .......... , . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .... , .......•.... , .. 200-201 utility plant ......................................................... . utility plant (summary) Advances from associated companies ............................................. . Allowances ................................................................ . Amortization 256-257 228-229 miscellaneous ..............••.... , .....•....•.......................... . ................ - ....... 340 of nuclear fuel ..•....•................................................ 202-203 Appropriations of Retained Earnings ....................................... . llB-119 Associated Companies advances from . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . .................... 256-257 corporations controlled by respondent .............•.... , . . . . . . . . . . . . . . . . ............ , . . . . . . . . . . . 103 control over respondent .•... , ......•... , .... , ..... , .............................................. 102 interest on debt to ..................................•.....• , ....•........................... 256-257 Attestation ....................... , , •...•.... , ...................................... , .....•. , .........• i Balance sheet comparative 110-113 notes to .........................................................................•........... 122-123 Bonds ............................................................................................ 256-257 Capital Stock ................................ , ............. , ....................................... , . 251 expense .....•......................................................... , .......................... 254 premiums .....................................•................................................... 252 reacquired .................. , .........•.......................................................... 251 subscribed . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 252 cash flows, statement of ............... , ..................................................•...... 120-121 Changes important during year Construction 108-109 work in progress - common utility plant .......................................................... 356 work in progress - electric .................... , ................................................. 216 work in progress- other utility departments ................................................. 200-201 control corporations controlled by respondent . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . • . . . . . . . . . . • . . . . . . . 103 over respondent ..•.......•.......................................•......••....................... 102 corporation controlled by ............•....•...•......................................... , .................... 103 incorporated ......•.............................................................................. 101 CPA, background information on . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101 CPA Certification, this report form ................................................................. i-ii FERC FORM NO.1 (ED.12-93) Index INDEX (continued) Page No. Schedule Deferred credits, other .......•.............•............................................................. 269 debits, miscellaneous .................•••.•.•....••....•...••.•... , .•...••.....•................. 233 income taxes accumulated - accelerated amortization property ...............••...•..........•••....•.•••........ , , ................... 272-273 income taxes accumulated other property ....................•..............•....••.•..•..... 274-275 income taxes accumulated - other ...••....•.•................................................. 276-277 income taxes accumulated- pollution control facilities ...•...................................... 234 Definitions, this report form ...••................................................................... iii Depreciation and amortization of common utility plant ..... : . ...................................•.........................•..... 356 of electric plant . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 219 336-337 Directors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . 105 Discount - premium on long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 256-257 Distribution of salaries and wages . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 354-355 Dividend appropriations . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 118-119 Earnings, Retained . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . . 118-119 Electric energy account ...........................................................................••• 401 Expenses electric operation and maintenance ................................•......... , ................ 320-323 electric operation and maintenance, summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 323 unamortized debt ...........•..........•..........................••..................•........... 256 Extraordinary property losses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . 230 Filing requirements, this report. form General information ............................................•.••.......•••...........•............ 101 Instructions for filing the FERC Form 1 .....•....................................................... i-iv Generating plant statistics hydroelectric (large) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 406-407 pumped storage (large) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 408-409 small plants . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 410-411 steam-electric (large) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 402-403 Hydro-electric generating plant statistics ......... , , ........................•................... 406-407 Identification ...•........................................... , ..............................• , .••.... 101 Important changes during year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 108-109 Income statement of, by departments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 114-117 statement of, for the year (see also revenues) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 114-117 deductions, miscellaneous amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 340 deductions, other income deduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 340 deductions, other j_nterest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , ................... 340 Incorporation information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . • . . . . . . . . . . • . • . . . . 101 FERC FORM NO.1 {ED. 12-95) Index 2 INDEX (continued) Page No. Schedule Interest charges, paid on long-tem debt, advances, etc . . . . . . . . . . . . . . . . . . . . . . . . . . .................... 256-257 Investments nonutility property . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 221 subsidiary companies . . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ...................• 224-225 Investment tax credits, accumulated deferred .•• , ..... , , , . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 266-267 Law, excerpts applicable to this report form . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • ...... , ...••............. iv List of schedules, this report form ................•.....••.•..••.........••........................ 2-4 Long-term debt ............... , .....• , , , , .... , , •.. , ....... , . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . 256-257 Losses-Extraordinary property . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • • . . . . . . . . . . . . . . . . . . . . . . • . • . . . . . . . . . . 230 Materials and supplies . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . • • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 227 Miscellaneous general expenses .........•..............................•.... 335 Notes to balance sheet .. , ......... , . , .. , , ... , , , , , . , ........ , . . . . . . . . . . . . . . . . . . . . , .... , ............ 122-123 to statement or changes in financial position .....................•..•.......•..•............ 122-123 to statement of income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122-123 to statement of retained earnings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122-123 Nonutility property . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 221 Nuclear fuel materials . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 202-203 Nuclear generating plant, statistics ................................•............••.......•...••. 402-403 Officers and officers' salaries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . 104 Operating expenses-electric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 320-323 expenses-electric (summary) ....•.......•........••.•........................................... ,'. 323 Other paid-in capital . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 53 donations received from stockholders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . . 253 gains on resale or cancellation of reacquired capital stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 253 miscellaneous paid-in capital . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 253 reduction in par or stated value of capital stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 253 regulatory assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 232 regulatory liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 278 Peaks, monthly, and output . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 401 Plant, Common utility accumulated provision for depreciation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 356 acquisition adjustments .....••.•........•..•.......•............................................. 356 allocated to utility departments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . 356 completed construction not classified . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 356 construction work in progress . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 356 expenses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 356 held for future use . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 356 in service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 356 leased to others . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 356 Plant data . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . • . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 336-337 401-429 FERC FORM NO.1 (ED. 12-95) Index 3 INDEX (continued) Page No. Schedule Plant - electric accumulated provision for depreciation ....•.............................................•....•..• 219 construction work in progress .................................................................... 216 held for future use . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 214 in service ..............................................................................•.... 204-207 leased to others . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 213 Plant - utility and accumulated provisions for depreciation amortization and depletion (summary) ..•..................................••...................... 201 Pollution control facilities, accumulated deferred income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . • . . . . . . . . . . . . . . . . . . . . . 234 Power Exchanges , ................................................................................. 326-327 Premium and discount on long-term debt ............................................................... 256 Premium on capital stock ............................................................................. 251 Prepaid taxes ..................................................................................•. 262-263 Property - losses, extraordinary .......................................•............................. 230 . Pumped storage generating plant statistics ....................................................... 408-409 Purchased power (including power exchanges) ...............................................•.... , . 326-327 Reacquired capital stock ............................................................................. 250 Reacquired long-term debt ........................................................................ 256-257 Receivers' certificates .......................................................................... 256-257 Reconciliation of reported net income with taxable income from Federal income taxes ................................................................ , ..... 2 61 Regulatory commission expenses deferred 233 Regulatory commission expenses for year 350-351 Research, development and demonstration activities .............................•......•.......... 352-353 Retained Earnings amortization reserve Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . • . . 119 appropriated ................................................................................. 118-119 statement of, for the year ................................................................... 118-119 unappropriated ....................................................................•.......... 118-119 Revenues - electric operating ..........................................•......................... 300-301 Salaries and wages directors fees .......................................................... , . • • . . . . . . . . . . . . . . . . . . . . . 105 distribution of ............................................................................. , . 354-355 officers' ........................................................................................ 104 Sales of electricity by rate schedules ............................................................... 304 Sales - for resale .........•.........................••................................... , .... , . 310-311 Salvage - nuclear fuel ........................................................................... 202-203 Schedules, this report form ............................................ , .. , ........................ , . 2-4 Securities exchange registration ........................................................................ Statement of Cash <"lows .......................................................................... Statement of income for the year ................................................................. Statement of retained earnings for the year ...................................................... Steam-electric generating plant statistics ....................................................... 250-251 120-121 114-117 118-119 402-403 Substations .................................. , • , , . , .. , . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 42 6 Supplies - materials and ..............• , , ......................... , .. , , . , ............................ 227 FERC FORM NO. 1 (ED. 12-90) Index 4 INDEX (continued) Page No. Schedule Taxes accrued and prepaid 262-263 charged during year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ... , ............... 262-263 on income, deferred and accumulated . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ....................... 234 272-277 reconciliation of net income with taxable income for . . . . . . . . . . . • • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 261 Transformers, line - electric 429 Transmission lines added during year .......................•...•.•..........•....... lines statistics ..................................•................•.•• 424-425 422~423 of electricity for others ....•..............................••......... 328-330 of electricity by others . . . . . . . . . . . . . . . . . . • . . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • • . . . . . . . . . . . . . . . . 332 Unamortized debt discount ...............................................•.......... debt expense ................•..•....................................••. premium on debt ........................................•........•...... . ................... Unrecovered Plant and Regulatory Study Costs .............................. . . . . . . . . . . . . . . . . . . . . . Index FERC FORM NO. 1 (ED. 12-90} ----- ----------- 5 --+---- ------- 256-257 256-257 256-257 . . . . 230 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 For each Director & Officer of the Company, list the principal occupation or;usiness affiliation & all affiliations or connections with any other business or financial organizations, firms, or partn rships. For purposes of this part, the official will be considered to have an affiliation with any business or financial or anization, firm or partnership in which he is an officer, director, trustee, partner, or a person exercising similar function~. I OFFICERS & DIRECTORS OF FLORIDA POWER & Ll HT COMPANY Robo, James L. - Director and Chairman of the Board NextEra Energy, Inc.-Director; President and Chief Executive Officer I NextEra Energy Partners GP, Inc.-Director; Chairman of the Board and Chief $xecutive Officer ' ClearSky Power & Technology Fund I LLC-Member, Board of Managers Contra Costa Capital, LLC-Vice President EFH Merger Co., LLC-Chief Executive Officer FPL Investments, LLC-President Mendocino Capital, LLC-Vice President ! NEE Acquisition Sub I, LLC-Chief Executive Officer NEE Acquisition Sub II, Inc.-Director; Chairman of the Board and Chief Executive Officer NextEra Energy Capital Holdings, Inc.-Director; Chairman of the Board, Presid~nt and Chief Executive Officer NextEra Energy Equipment Leasing, LLC-Vice President · NextEra Energy Foundation, Inc., Director-Chairman of the Board Surry Capital LLC-Member, Board of Managers JB Hunt Transportation, Inc.-Director 1 Dewhurst Mora P.- Director Executive Vice President Finance and Chie Financial Officer NextEra Energy, Inc.-Vice Chairman and Chief Financial Officer, and Executiv Vice President-Finance NextEra Energy Partners GP, Inc.-Director; Chief Financial Officer ClearSky Power & Technology Fund I LLC-Member-Board of Managers Contra Costa Capital, LLC-Vice President EFH Merger Co., LLC-Chief Financial Officer FPL Recovery Funding LLC-President Mendocino Capital, LLC-Vice President NEE Acquisition Sub I, LLC-Chief Financial Officer ~, NEE Acquisition Sub II, Inc.-Chief Financial Officer NextEra Energy Capital Holdings, Inc.-Director; Senior Vice President, Finane~ and Chief Financial Officer Palms Insurance Company, Limited-Director Pipeline Funding Company, LLC-President Silagy. Eric E. - Director. President and Chief Executive Officer N/A Nazar Manoochehr K. - President Nuclear Division and Chief Nuclear Offic r NextEra Energy, Inc.-President Nuclear Division and Chief Nuclear Officer NextEra Energy Duane Arnold, LLC-Vice President NextEra Energy Point Beach, LLC-Vice President NextEra Energy Seabrook, LLC-Senior Vice President & Nuclear Chief Operating Officer 451·1 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Arechabala. Miguel - Executive Vice President, Power Generation Division NextEra Energy, Inc.-Executive Vice President, Power Generation Division Cedar Bay Cogeneration, LLC-President Cedar II Power, LLC-President ESI Northeast Energy LP, LLC-President Evacuacion Valdecaballeros, S.L.-Director FPL Historical Museum, Inc.-Director; President NextEra Energy Canadian Operating Services, Inc.-Director; President NextEra Energy Espana Operating Services, S. L.-Joint & Several Administrator NextEra Energy Espana, S.L.-Joint and Several Director NextEra Energy Operating Services, LLC-President NextEra Energy Pipeline Services, LLC-President Caplan, Deborah H. - Executive Vice President, Human Resources and Corporate Services NextEra Energy, Inc.-Executive Vice President, Human Resources and Corporate Services NextEra Energy Equipment Leasing, LLC-President NextEra Energy Foundation, Inc.-Vice President Sieving, Charles E. - Executive Vice President NextEra Energy, Inc.-Executive Vice President & General Counsel NextEra Energy Partners GP, Inc.-Director; General Counsel EFH Merger Co., LLC-General Counsel NEE Acquisition Sub I, LLC-General Counsel NEE Acquisition Sub II, Inc.-General Counsel NextEra Energy Foundation, Inc.-Director Yeager. William L.- Executive Vice President. Engineering, Construction and Integrated Supply Chain NextEra Energy, Inc.-Executive Vice President, Engineering, Construction and Integrated Supply Chain NextEra Energy Resources, LLC-Vice President GR Woodford Properties, LLC-Vice President Hickson, Mark E. - Senior Vice President, Corporate Development and Strategic Initiatives NextEra Energy, Inc.-Senior Vice President, Corporate Development and Strategic Initiatives NextEra Energy Partners GP, Inc.-Director; Vice President, Strategy and Corporate Development Common Unit Holdings, LLC-Vice President NEP US SeiiCo, LLC-Vice President NextEra Energy Equity Partners GP, LLC-Vice President NextEra Energy Management Partners GP, LLC-Vice President NextEra Energy Operating Partners GP, LLC-Vice President NextEra Energy Partners Acquisitions, LLC-Vice President NextEra Energy Partners Solar Acquisitions, LLC-Vice President NextEra Energy Partners Ventures, LLC-Vice President NextEra Energy Resources Partners Holdings, LLC-Vice President NextEra Energy Resources Partners, LLC-Vice President NextEra Energy Resources, LLC-Vice President, Strategy and Corporate Development NextEra Energy US Partners Holdings, LLC-Vice President Solar Holdings SeiiCo, LLC-Vice President Miranda, Manuel B. - Senior Vice President, Power Delivery N/A 451-2 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Arcari, Craig W. -Vice President. Power Generation Technical Services Cedar Bay Cogeneration, LLC, Vice President Cedar II Power, LLC, Vice President Energy Storage Holdings, LLC, Vice President Golden West Power Partners, LLC, Vice President Barrett. Robert E. Jr. -Vice President, Finance GR Woodford Properties, LLC-Vice President Broad. Tom F. -Vice President. Engineering and Construction NextEra Energy, Inc.-Vice President, Engineering and Construction Adelanto Solar II, LLC-Vice President Adelanto Solar, LLC-Vice President Aries Solar Holding, LLC-Vice President Ashtabula Wind IV, LLC-Vice President Barrett Repowering, LLC-Vice President Battersea Solar GP, Inc.-Vice President BCSD Solar, LLC-Vice President Beacon Solar, LLC-Vice President Blythe Solar 110, LLC-Vice President Blythe Solar II, LLC-Vice President Blythe Solar Ill, LLC-Vice President Barnish Wind GP, ULC-Vice President Brady Wind II, LLC-Vice President Brady Wind, LLC-Vice President Breckinridge Wind Holdings, LLC-Vice President Breckinridge Wind Project, LLC-Vice President Canadian Combined Cycle Station I GP, Inc.-Vice President Carousel Wind Farm, LLC-Vice President Cedar Bluff Wind, LLC-Vice President Chaves County Solar II, LLC-Vice President Chaves County Solar, LLC-Vice President Cheyenne Wind Holdings, LLC-Vice President Clarabelle I Solar GP, Inc.-Vice President Clarabelle II Solar GP, Inc.-Vice President Clarabelle Ill Solar GP, Inc.-Vice President Clean Energy Generation, LLC-Vice President Cordukes Solar GP, Inc.-Vice President Costigan Wind GP, Inc.-Vice President Cottonwood Wind Project, LLC-Vice President CP II Holdings GP, Inc.-Vice President Crowned Ridge Wind, LLC-Vice President Day County Wind II, LLC-Vice President Desert Sunlight 250, LLC-Vice President Desert Sunlight 300, LLC-Vice President Desert Sunlight Holdings, LLC-Vice President DG Bethlehem Solar, LLC-Vice President DG BP Solar One, LLC-Vice President DG Cherry Hill, LLC-Vice President 451·3 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Broad (continued) DG CSU Solar, LLC-Vice President DG HD Hawaii, LLC-Vice President DG Ka Makana Ali'i, LLC-Vice President DG Minnesota CSG 1, LLC-Vice President DG Minnesota CSG 10, LLC-Vice President DG Minnesota CSG 2, LLC-Vice President DG Minnesota CSG 3, LLC-Vice President DG Minnesota CSG 4, LLC-Vice President DG Minnesota CSG 5, LLC-Vice President DG Minnesota CSG 6, LLC-Vice President DG Minnesota CSG 7, LLC-Vice President DG Minnesota CSG 8, LLC-Vice President DG Minnesota CSG 9, LLC-Vice President DG Monmouth, LLC-Vice President DG Moorestown, LLC-Vice President DG Newark, LLC-Vice President DG North Carolina Solar Holding, LLC-Vice President DG Pearl City, LLC-Vice President DG Project Construction Co., LLC-Vice President DG Residential Acquisition Co., LLC-Vice President DG Waipio, LLC-Vice President DG Walnut Creek, LLC-Vice President DG Willowbrook, LLC-Vice President DG Woodbury Solar, LLC-Vice President Distributed Energy Storage Associates, LLC-Vice President East Durham Wind GP, ULC-Vice President East Durham Wind, ULC-Vice President EFB Constructors, LLC-Vice President Elmira Energy Storage GP, ULC-Vice President EW Solar, LLC-Vice President Florida Southeast Connection, LLC-Vice President Foxtail Wind, LLC-Vice President FPL Energy Hancock County Wind, LLC-Vice President FPL Energy Mojave Operating Services, LLC-Vice President FPL Energy Texas Wind Marketing GP, LLC-Vice President Gateway Energy Center, LLC-Vice President Genesis Solar Holdings, LLC-Vice President Genesis Solar, LLC-Vice President Georgia Longleaf Solar 1, LLC-Vice President Ghost Pine Energy Storage GP, Inc.-Vice President Golden Hills Interconnection, LLC-Vice President Golden Hills North Wind, LLC-Vice President Golden Hills Wind, LLC-Vice President Golden West Power Partners, LLC-Vice President Goshen Wind GP, ULC-Vice President Goshen Wind, ULC-Vice President Hale Wind Energy, LLC-Vice President Hardy Creek Wind GP, Inc.-Vice President HCSD Solar, LLC-Vice President HD Hatillo Solar One, LLC-Vice President High Hills Wind GP, Inc.-Vice President Island Park Energy Center, LLC-Vice President 451-4 FLORIDA PUBLIC SERVICE CO!YiMISSION SIGNATURE PAGE I certify that I am the responsible accounting officer of FLORIDA POWER & LIGHT COMPA~Y; That I have examined the following report; that to the best of my knowledge, information, and belief, all statements of fact contained in t~e said report are true and the said report is a correct statement of the business ~nd affairs of the above named respondent in respect to each and every matter se~ forth therein during the period from January 1, 2015 to December 31, 2015, in~lusive. I also certify that all affiliated transfer prices and affiliated qost allocations were determined consistent with the methods reported to this Cd>mmission on the · appropriate forms included in this report. I am aware that Section 837.06, Florida Statutes, provides: Whoever knowingly makes a false statement in writing ~ith the intent to mislead a public servant in the performance of his official duty shall be guilty of a misdemeanor of the second degree, puni$hable as provided in s. 775.082, s. 775.083 or s. 775.084. April 30, 2016 Date Kim Ousdahl Name Signature Vice President, Controller and Ch1ef Accountilng Officer Title · Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Broad (continued) Jacumba Solar, LLC-Vice President Javelina Interconnection, LLC-Vice President Javelina Wind Energy, LLC-Vice President Javelina Wind Holdings II, LLC-Vice President Jericho Wind GP, ULC-Vice President Jericho Wind, ULC-Vice President Joshua Tree Solar Farm, LLC-Vice President Ka La Nui Solar, LLC-Vice President Kerwood Wind GP, ULC-Vice President Kerwood Wind, ULC-Vice President Kingman Wind Energy I, LLC-Vice President Kingman Wind Energy II, LLC-Vice President Kingman Wind Holding I, LLC-Vice President Kingman Wind Holding II, LLC-Vice President La Palma DG Solar, LLC-Vice President LCSD Solar 1, LLC-Vice President LCSD Solar 2, LLC-Vice President Lee North, LLC-Vice President Ll Energy Storage System, LLC-Vice President Ll Solar Generation, LLC-Vice President Limon Wind Ill, LLC-Vice President Live Oak Solar, LLC-Vice President Lone Star Transmission, LLC-Vice President Long Island Energy Storage Holdings, LLC-Vice President Long Island Peaker Holdings, LLC-Vice President Long Island Solar Holdings, LLC-Vice President M Boulevard Solar, LLC-Vice President M Cross County Solar, LLC-Vice President M Greece Ridge Solar, LLC-Vice President M Nanuet Solar, LLC-Vice President M Queens Rego Solar, LLC-Vice President M Schenectady Solar, LLC-Vice President M White Plains Solar, LLC-Vice President Mammoth Plains Wind Project Holdings, LLC-Vice President Mammoth Plains Wind Project, LLC-Vice President Mantua Creek Solar, LLC-Vice President Marshall Solar, LLC-Vice President McAdam Wind GP, Inc.-Vice President McCoy Solar, LLC-Vice President Minco Wind IV, LLC-Vice President Minco Wind, LLC-Vice President Minudie Wind GP, Inc.-Vice President Moore Solar, ULC-Vice President Moose Wind, LLC-Vice President Morongo DG Solar, LLC-Vice President Mountain View Solar, LLC-Vice President Mt. Storm Wind Force Holdings, LLC-Vice President Mt. Storm Wind Force, LLC-Vice President New Hampshire Transmission, LLC-Vice President NextEra Canada Development & Acquisitions, Inc.-Vice President NextEra Canada Transmission Investments, Inc.-Vice President NextEra Desert Sunlight Holdings, LLC-Vice President 451-5 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Broad (continued) NextEra Energy Bluff Point, LLC-Vice President NextEra Energy Canada GP, LLC-Vice President NextEra Energy Canada Partners Holdings, ULC-Vice President NextEra Energy Honey Creek Wind, LLC-Vice President NextEra Energy Mt. Storm, LLC-Vice President NextEra Energy NextBridge Holding, ULC-Vice President NextEra Energy NextBridge Holdings GP, LLC-Vice President NextEra Energy NextBridge Holdings GP, ULC-Vice President NextEra Energy Resources, LLC-Vice President NextEra Energy Transmission New York, Inc.-Vice President NextEra Energy Transmission Southwest, LLC-Vice President NextEra Energy Transmission, LLC-Vice President NextEra Energy UCT Holding, Inc.-Vice President NextEra Energy Victory Solar I, LLC-Vice President Ninnescah Wind Energy LLC-Vice President Northpoint I Wind GP, Inc.-Vice President Northpoint II Wind GP, Inc.-Vice President Old Mill Solar, LLC-Vice President Oliver Wind Ill, LLC-Vice President Oneida DG Solar, LLC-Vice President Osborn Wind Energy, LLC-Vice President Pacific Energy Solutions, LLC-Vice President Palo Duro Wind Energy, LLC-Vice President Parry Energy Storage GP, ULC-Vice President Penobscot Wind, LLC-Vice President Pheasant Run Wind Holdings, LLC-Vice President Pheasant Run Wind, LLC-Vice President Pima Energy Storage System, LLC-Vice President Prairie View Wind Holdings, LLC-Vice President Red Raider Wind Holdings, LLC-Vice President Red Raider Wind, LLC-Vice President River Bend Solar, LLC-Vice President Roswell Solar, LLC-Vice President Rush Springs Wind Energy, LLC-Vice President San Jacinto Solar 14.5, LLC-Vice President San Jacinto Solar 5.5, LLC-Vice President SEC SUSD Solar One, LLC-Vice President Seiling Wind Holdings, LLC-Vice President Seiling Wind II, LLC-Vice President Seiling Wind Interconnection Services, LLC-Vice President Seiling Wind Portfolio, LLC-Vice President Seiling Wind, LLC-Vice President Sentry Solar, LLC-Vice President Shafter Solar, LLC-Vice President Silver State Solar Power South, LLC-Vice President Sombra Solar, ULC-Vice President Sonoran Solar Energy I, LLC-Vice President Sonoran Solar Energy, LLC-Vice President Southwest Solar Holdings, LLC-Vice President Stark Wind, LLC-Vice President Thames Solar GP, Inc.-Vice President Trenton Diocese DG Solar, LLC-Vice President 451-6 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Broad (continued) Trout Lake I Solar GP, Inc.-Vice President Trout Lake II Solar GP, Inc.-Vice President Trout Lake Ill Solar GP, Inc.-Vice President Tuscola Wind II, LLC-Vice President Tuscola Wind Ill, LLC-Vice President UC Solar, LLC-Vice President Upper Canada Transmission, Inc.-Vice President USG Midstream Bakken I, LLC-Vice President Varna Wind GP, ULC-Vice President Varna Wind, ULC-Vice President Venable Solar, LLC-Vice President Victory Renewables, LLC-Vice President West Hills Wind, LLC-Vice President Westside Solar, LLC-Vice President White Oak Solar, LLC-Vice President White Pine Solar, LLC-Vice President Whitney Point Solar, LLC-Vice President Wilton Wind IV, LLC-Vice President Zuni Solar, LLC-Vice President Chapel. Christopher - Vice President. Governmental Affairs - Federal NextEra Energy, Inc.-Vice President, Governmental Affairs- Federal Charanjiva. Lakshman -Vice President and Chief Information Officer NextEra Energy, Inc.-Vice President and Chief Information Officer Coneys. John J. -Vice President and Chief Tax Officer NextEra Energy, Inc.-Vice President and Chief Tax Officer Costanzo, Christopher- Vice President. St. Lucie Nuclear Power Plant N/A Forrest. Sam A. -Vice President, Energy Marketing & Trading Cedar Bay Cogeneration, LLC-Vice President Cedar Bay Holdings, LLC-President Cedar II Power, LLC-Vice President FPL Energy Services, Inc.-Director; President FPL Enersys, Inc.-Director; President FPL Readi-Power, LLC-President FPL Services, LLC-President GR Woodford Properties, LLC-President Goldstein, Mitchell P.- Vice President Finance, Nuclear Fleet NextEra Energy Duane Arnold, LLC-Vice President NextEra Energy Point Beach, LLC-Vice President NextEra Energy Seabrook, LLC-Vice President 451-7 ------------ Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Gould, Robert -Vice President. Marketing & Communication FPL Historical Museum, Inc.-Director Hardy. G. Keith - Vice President FPL Historical Museum, Inc.-Vice President Hoffman. Kenneth A. -Vice President. Regulatory Affairs N/A Jensen, Joseph N. -Vice President, Fleet Support Services N/A Kennedy, Roxane R. - Vice President, Power Generation Operations N/A Kiley, Michael W.- Vice President, Fleet Support Projects N/A LaBauve. Randall R. - Vice President, Environmental Services NextEra Energy, Inc.-Vice President, Environmental Services Litchfield. R. Wade -Vice President & General Counsel FPL Recovery Funding LLC-Manager; Secretary Murphy. Brian R -Vice President. Tax NextEra Energy, Inc.-Vice President, Tax BAC Investment Corp.-Director EFH Merger Co., LLC-Vice President EMB Investments, Inc.-Director; Vice President Gray Sky Investments, LLC-Vice President KPB Financial Corp.-Director; Vice President NextEra Energy Capital Holdings, Inc.-Vice President NextEra Energy Global Holdings Cooperatieve U.A.-Managing Director (A) Northern Cross Investments, Inc.-Director RGS Realty Holdings, LLC-Vice President RGS Realty, LLC-Vice President Square Lake Holdings, Inc.-Director Sullivan Street Investments, Inc.-Director Olnick. Bryan -Vice President, Distribution Operations N/A 451-8 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Ousdahl, Kimberly ·Vice President, Controller and Chief Accounting Officpr GR Woodford Properties, LLC-Vice President Rauch, Pamela M. ·Vice President. Development and External Affairs N/A Reagan, Ronald R ·Vice President, Integrated Supply Chain NextEra Energy, Inc.-Vice President, Integrated Supply Chain NextEra Energy Canada Equipment, Inc.-Vice President NextEra Energy Resources, LLC-Vice President Tech Testing Solutions Holdings, LLC-President Tech Testing Solutions, LLC-President Santos. Marlene M. ·Vice President. Customer Service N/A Seeley. W. Scott ·Vice President, Compliance & Corporate Secretary NextEra Energy, Inc.-Vice President, Compliance & Corporate Secretary 4263766 Canada Inc.-Secretary Adelanto Solar Funding, LLC-Assistant Secretary Adelanto Solar Holdings, LLC-Assistant Secretary Adelanto Solar II, LLC-Assistant Secretary Adelanto Solar, LLC-Assistant Secretary Alandco I, Inc.-Secretary Alandco Inc.-Secretary Alandco/Cascade, Inc.-Secretary Albercas Wind Energy II, LLC-Assistant Secretary Altamont Power LLC-Assistant Secretary Aquilo Holdings LP, ULC-Secretary Aquilo LP, ULC-Secretary Aries Solar Holding, LLC-Assistant Secretary Ashtabula Wind II, LLC-Assistant Secretary Ashtabula Wind Ill, LLC-Assistant Secretary Ashtabula Wind, LLC-Assistant Secretary Backbone Mountain Windpower LLC-Assistant Secretary Backbone Windpower Holdings, LLC-Assistant Secretary Baldwin Wind Holdings, LLC-Assistant Secretary Baldwin Wind, LLC-Assistant Secretary Barrett Repowering, LLC-Assistant Secretary Battersea Solar LP, ULC-Secretary Battery Testing and Modeling, LLC-Assistant Secretary Bayhawk Wind Funding, LLC-Assistant Secretary Bayhawk Wind Holdings, LLC-Assistant Secretary Bayhawk Wind SeiiCo, LLC-Assistant Secretary Bayhawk Wind, LLC-Assistant Secretary Bayswater Peaking Facility, LLC-Assistant Secretary BCSD Solar, LLC-Assistant Secretary Beacon Solar, LLC-Assistant Secretary 451-9 I -----~--- Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) Bison Wind GP, LLC-Assistant Secretary Bison Wind Holdings, LLC-Assistant Secretary Bison Wind Investments, LLC-Assistant Secretary Bison Wind LP, LLC-Assistant Secretary Bison Wind Portfolio, LLC-Assistant Secretary Bison Wind, LLC-Assistant Secretary Blackwell Wind, LLC-Assistant Secretary Blue Heron Land Associates, LLC-Assistant Secretary Blue Summit Generation Tie, LLC-Assistant Secretary Blue Summit II Wind, LLC-Assistant Secretary Blue Summit Wind, LLC-Assistant Secretary Bluebell Solar, LLC-Assistant Secretary Blythe Solar 11 0, LLC-Assistant Secretary Blythe Solar Holdings, LLC-Assistant Secretary Blythe Solar II, LLC-Assistant Secretary Blythe Solar Ill, LLC-Assistant Secretary Blythe Solar IV, LLC-Assistant Secretary Barnish Wind BC Holdings, ULC-Secretary Barnish Wind Funding GP, LLC-Assistant Secretary Barnish Wind GP, LLC-Assistant Secretary Barnish Wind Holdings GP, LLC-Assistant Secretary Barnish Wind LP, ULC-Secretary Boulevard Associates Canada, Inc.-Assistant Secretary Boulevard Associates, LLC-Assistant Secretary Boulevard Gas Associates, LLC-Assistant Secretary Brady Wind II, LLC-Assistant Secretary Brady Wind, LLC-Assistant Secretary Breckinridge Wind Class A Holdings, LLC-Assistant Secretary Breckinridge Wind Funding, LLC-Assistant Secretary Breckinridge Wind Holdings, LLC-Assistant Secretary Breckinridge Wind Project, LLC-Assistant Secretary BSGA Gas Producing, LLC-Assistant Secretary Buffalo Ridge Wind Energy, LLC-Assistant Secretary Butler Ridge Wind Energy Center, LLC-Assistant Secretary Cabo Solar Farm, LLC-Assistant Secretary Canadian Combined Cycle Station I LP, ULC-Secretary Canyon Wind Holdings, LLC-Assistant Secretary Canyon Wind, LLC-Assistant Secretary Capricorn Ridge B Holdings, LLC-Assistant Secretary Capricorn Ridge B, LLC-Assistant Secretary Capricorn Ridge Power Seller, LLC-Assistant Secretary Capricorn Ridge Wind Funding, LLC-Assistant Secretary Capricorn Ridge Wind Holdings, LLC-Assistant Secretary Capricorn Ridge Wind II, LLC-Assistant Secretary Capricorn Ridge Wind, LLC-Assistant Secretary Carousel Wind Farm, LLC-Assistant Secretary Carousel Wind Holdings, LLC-Assistant Secretary Cedar Bay Cogeneration, LLC-Secretary Cedar Bay Holdings, LLC-Secretary Cedar Bluff Wind, LLC-Assistant Secretary Cedar II Power, LLC-Secretary Centennial Wind Class B, LLC-Assistant Secretary 451-10 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) FPLE Rhode Island State Energy LP, LLC-Assistant Secretary FPLE Texas Wind I, LLC-Assistant Secretary FPLE Upton Leasing GP, LLC-Assistant Secretary FPLE Upton Leasing LP, LLC-Assistant Secretary Garden Wind, LLC-Assistant Secretary Gateway Energy Center Holdings, LLC-Assistant Secretary Gateway Energy Center, LLC-Assistant Secretary Generation Repair and Service, LLC-Assistant Secretary Genesis Solar Funding Holdings, LLC-Assistant Secretary Genesis Solar Funding, LLC-Assistant Secretary Genesis Solar Holdings, LLC-Assistant Secretary Genesis Solar, LLC-Assistant Secretary Georgia Longleaf Solar 1, LLC-Assistant Secretary Gexa Energy California, LLC-Assistant Secretary GEXA Energy GP, LLC-Assistant Secretary Gexa Energy Solutions, LLC-Assistant Secretary Ghost Pine Energy Storage LP, ULC-Secretary Ghost Pine Holdings, ULC-Assistant Secretary Golden Hills Energy Storage, LLC-Assistant Secretary Golden Hills Interconnection, LLC-Assistant Secretary Golden Hills North Wind, LLC-Assistant Secretary Golden Hills Wind, LLC-Assistant Secretary Golden West Power Partners, LLC-Assistant Secretary Golden West Wind Holdings, LLC-Assistant Secretary Golden Winds Funding, LLC-Assistant Secretary Golden Winds Holdings, LLC-Assistant Secretary Golden Winds, LLC-Assistant Secretary Goshen Wind BC Holdings, ULC-Secretary Goshen Wind Funding GP, LLC-Assistant Secretary Goshen Wind GP, LLC-Assistant Secretary Goshen Wind Holdings GP, LLC-Assistant Secretary Goshen Wind, ULC-Assistant Secretary GR Bage (DE), LLC-Assistant Secretary GR Bage (FL), Inc.-Assistant Secretary GR Woodford Properties, LLC-Secretary Gray County Wind Energy, LLC-Assistant Secretary Gray Sky Investments, LLC-Assistant Secretary Green Mountain Storage, LLC-Assistant Secretary Green Ridge Power LLC-Assistant Secretary Green Ridge Services LLC-Assistant Secretary Hale Wind Energy, LLC-Assistant Secretary Hardy Creek Wind, ULC-Assistant Secretary Hardy Creek Wind, ULC-Assistant Secretary Harper Lake Company VIII-Assistant Secretary Harper Lake Solar Funding Corporation-Assistant Secretary Hatch Solar Energy Center I LLC-Assistant Secretary Hawkeye Power Partners, LLC-Assistant Secretary HCSD Solar, LLC-Assistant Secretary HD Hatillo Solar One, LLC-Assistant Secretary Heartland Wind Funding, LLC-Assistant Secretary Heartland Wind Holding II, LLC-Assistant Secretary Heartland Wind Holding, LLC-Assistant Secretary 451-15 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) Heartland Wind II, LLC-Assistant Secretary Heartland Wind, LLC-Assistant Secretary High Ground Investments, LLC-Assistant Secretary High Hills Wind LP, ULC-Secretary High Majestic II Funding, LLC-Assistant Secretary High Majestic II Holdings, LLC-Assistant Secretary High Majestic II Wind Properties, LLC-Assistant Secretary High Majestic Interconnection Services, LLC-Assistant Secretary High Majestic Wind Energy Center, LLC-Assistant Secretary High Majestic Wind II, LLC-Assistant Secretary High Point Wind, LLC-Assistant Secretary High Winds, LLC-Assistant Secretary HLC IX Company-Assistant Secretary Horse Hollow Generation Tie Holdings, LLC-Assistant Secretary Horse Hollow Generation Tie, LLC-Assistant Secretary HWFII, LLC-Assistant Secretary Hyperion IX, Inc.-Assistant Secretary Hyperion VIII, Inc.-Assistant Secretary Indian Mesa Wind Farm, LLC-Assistant Secretary Inventus Holdings, LLC-Assistant Secretary Iowa Clean Energy Express, LLC-Assistant Secretary Jacumba Solar, LLC-Assistant Secretary Jamaica Bay Peaking Facility, LLC-Assistant Secretary Javelina Interconnection, LLC-Assistant Secretary Javelina Wind Class B, LLC-Assistant Secretary Javelina Wind Energy Holdings, LLC-Assistant Secretary Javelina Wind Energy, LLC-Assistant Secretary Javelina Wind Funding Holdings, LLC-Assistant Secretary Javelina Wind Funding, LLC-Assistant Secretary Javelina Wind Holdings II, LLC-Assistant Secretary Jericho Wind BC Holdings, ULC-Secretary Jericho Wind Funding GP, LLC-Assistant Secretary Jericho Wind GP, LLC-Assistant Secretary Jericho Wind Holdings GP, LLC-Assistant Secretary Jericho Wind, ULC-Assistant Secretary Joshua Tree Solar Farm, LLC-Assistant Secretary Ka La Nui Solar, LLC-Assistant Secretary Kerwood Wind BC Holdings, ULC-Secretary Kerwood Wind Funding GP, LLC-Assistant Secretary Kerwood Wind GP, LLC-Assistant Secretary Kerwood Wind Holdings GP, LLC-Assistant Secretary Kerwood Wind, ULC-Assistant Secretary Kingman Wind Energy I, LLC-Assistant Secretary Kingman Wind Energy II, LLC-Assistant Secretary Kingman Wind Holding I, LLC-Assistant Secretary Kingman Wind Holding II, LLC-Assistant Secretary KW San Gorgonio Transmission, Inc.-Assistant Secretary La Frontera Generation, LLC-Assistant Secretary La Frontera Holdings, LLC-Assistant Secretary La Frontera Ventures, LLC-Assistant Secretary La Palma DG Solar, LLC-Assistant Secretary La Salle County Gas Producing, LLC-Assistant Secretary 451-16 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) Lake Benton Power Partners II, LLC-Assistant Secretary Lakeco Holding, LLC-Assistant Secretary Lamar Power Partners II, LLC-Assistant Secretary Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) ESI Tehachapi Acquisitions, Inc.-Assistant Secretary ESI Tractebel Urban Renewal Corporation-Assistant Secretary ESI Vansycle GP, Inc.-Assistant Secretary ESI Vansycle LP, Inc.-Assistant Secretary ESI VG IV, LLC-Assistant Secretary ESI Victory, Inc.-Assistant Secretary ESI West Texas Energy LP, LLC-Assistant Secretary ESI West Texas Energy, Inc.-Assistant Secretary EV Battery Storage, LLC-Assistant Secretary EW Solar, LLC-Assistant Secretary Florida Southeast Connection, LLC-Assistant Secretary Fortuna GP, LLC-Assistant Secretary Fortuna Limited Partner, ULC-Secretary Foxtail Wind, LLC-Assistant Secretary FPL Energy American Wind Holdings, LLC-Assistant Secretary FPL Energy American Wind, LLC-Assistant Secretary FPL Energy Burleigh County Wind, LLC-Assistant Secretary FPL Energy Cabazon Wind, LLC-Assistant Secretary FPL Energy Callahan Wind GP, LLC-Assistant Secretary FPL Energy Callahan Wind LP, LLC-Assistant Secretary FPL Energy Cape, LLC-Assistant Secretary FPL Energy Cowboy Wind, LLC-Assistant Secretary FPL Energy Green Power Wind, LLC-Assistant Secretary FPL Energy Hancock County Wind, LLC-Assistant Secretary FPL Energy Horse Hollow Wind II, LLC-Assistant Secretary FPL Energy Horse Hollow Wind, LLC-Assistant Secretary FPL Energy Illinois Wind, LLC-Assistant Secretary FPL Energy Island End GP, LLC-Assistant Secretary FPL Energy Marcus Hook LLC-Assistant Secretary FPL Energy Mason LLC-Assistant Secretary FPL Energy MH50 GP, LLC-Assistant Secretary FPL Energy MH50 LP, LLC-Assistant Secretary FPL Energy MH700, LLC-Assistant Secretary FPL Energy Mojave Operating Services, LLC-Assistant Secretary FPL Energy Montezuma Wind, LLC-Assistant Secretary FPL Energy Morwind, LLC-Assistant Secretary FPL Energy Mower County, LLC-Assistant Secretary FPL Energy National Wind Holdings, LLC-Assistant Secretary FPL Energy National Wind Investments, LLC-Assistant Secretary FPL Energy National Wind Portfolio, LLC-Assistant Secretary FPL Energy National Wind, LLC-Assistant Secretary FPL Energy New Mexico Holdings, LLC-Assistant Secretary FPL Energy New Mexico Wind Financing, LLC-Assistant Secretary FPL Energy New Mexico Wind Holdings II, LLC-Assistant Secretary FPL Energy New Mexico Wind II, LLC-Assistant Secretary FPL Energy New Mexico Wind, LLC-Assistant Secretary Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) Minco Redwood Holdings, LLC-Assistant Secretary Minco Wind II, LLC-Assistant Secretary Minco Wind Ill, LLC-Assistant Secretary Minco Wind Interconnection Services, LLC-Assistant Secretary Minco Wind IV, LLC-Assistant Secretary Minco Wind, LLC-Assistant Secretary Minudie Wind LP, ULC-Secretary Moca Solar Farm, LLC-Assistant Secretary Mojave Holdings, LLC-Assistant Secretary Mojave Red Venturez, LLC-Assistant Secretary Moore Solar GP, LLC-Assistant Secretary Moore Solar, ULC-Assistant Secretary Moose Wind, LLC-Assistant Secretary Morongo DG Solar, LLC-Assistant Secretary Mount Miller Holdco, LLC-Assistant Secretary Mount Miller Holdco, ULC-Assistant Secretary Mount Miller Holdings GP, LLC-Assistant Secretary Mount Miller LP, ULC-Secretary Mountain Prairie Wind Holdings, LLC-Assistant Secretary Mountain Prairie Wind, LLC-Assistant Secretary Mountain View Solar Holdings, LLC-Assistant Secretary Mountain View Solar, LLC-Assistant Secretary Mt. Storm Wind Force Holdings, LLC-Assistant Secretary Mt. Storm Wind Force, LLC-Assistant Secretary NAPS Wind, LLC-Assistant Secretary NEE Acquisition Sub I, LLC-Secretary NEE Acquisition Sub II, Inc.-Secretary NEP US SeiiCo, LLC-Assistant Secretary NEPM II Holdings, LLC-Assistant Secretary NEPM II, LLC-Assistant Secretary NET General Partners, LLC-Secretary NET Holdings Management, LLC-Secretary NET Mexico Pipeline Partners, LLC-Secretary NET Midstream, LLC-Secretary NET Pipeline Holdings LLC-Secretary New Hampshire Transmission, LLC-Assistant Secretary New Mexico Energy Investments, LLC-Assistant Secretary New Mexico Wind Investments, LLC-Assistant Secretary NextEra Blythe Solar Energy Center, LLC-Assistant Secretary NextEra Canada Development & Acquisitions, Inc.-Assistant Secretary NextEra Canada Transmission Investments, Inc.-Assistant Secretary NextEra Canadian IP, Inc.-Assistant Secretary NextEra Desert Center Blythe, LLC-Assistant Secretary NextEra Desert Sunlight Holdings, LLC-Assistant Secretary NextEra Energy Bluff Point, LLC-Assistant Secretary NextEra Energy Canada Equipment, Inc.-Assistant Secretary NextEra Energy Canada GP, LLC-Secretary NextEra Energy Canada Partners Holdings, ULC-Secretary NextEra Energy Canadian Holdings, ULC-Assistant Secretary NextEra Energy Canadian Operating Services, Inc.-Assistant Secretary NextEra Energy Capital Holdings, Inc.-Secretary 451-18 I I ..._ --· YIV_.wr, ~-.....,-VVVIV\OIJ Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) Centennial Wind Funding, LLC-Assistant Secretary Centennial Wind Holdings, LLC-Assistant Secretary Centennial Wind, LLC-Assistant Secretary Central States Wind Holdings, LLC-Assistant Secretary Central States Wind, LLC-Assistant Secretary Chaves County Solar Holdings, LLC-Assistant Secretary Chaves County Solar II Holdings, LLC-Assistant Secretary Chaves County Solar II, LLC-Assistant Secretary Chaves County Solar Resources, LLC-Assistant Secretary Chaves County Solar, LLC-Assistant Secretary Cimarron Wind Energy Holdings II, LLC-Assistant Secretary Cimarron Wind Energy Holdings, LLC-Assistant Secretary Cimarron Wind Energy, LLC-Assistant Secretary Clarabelle I Solar LP, ULC-Secretary Clarabelle II Solar LP, ULC-Secretary Clarabelle Ill Solar LP, ULC-Secretary Colonial Penn Capital Holdings, Inc.-Secretary Common Unit Holdings, LLC-Assistant Secretary Cordukes Solar LP, ULC-Secretary Costigan Wind LP, ULC-Secretary Cottonwood Wind Project Holdings, LLC-Assistant Secretary Cottonwood Wind Project, LLC-Assistant Secretary CP II CAD Holdings LP GP, LLC-Assistant Secretary CP II Holdings LP, ULC-Secretary Crowned Ridge Wind, LLC-Assistant Secretary Crystal Lake Wind II, LLC-Assistant Secretary Crystal Lake Wind Ill, LLC-Assistant Secretary Crystal Lake Wind, LLC-Assistant Secretary Day County Wind II, LLC-Assistant Secretary Day County Wind, LLC-Assistant Secretary Delaware Mountain Wind Farm, LLC-Assistant Secretary Desert Sunlight 250, LLC-Assistant Secretary Desert Sunlight 300, LLC-Assistant Secretary Desert Sunlight Holdings, LLC-Assistant Secretary DG 1 Acquisition Co., LLC-Assistant Secretary DG 1, LLC-Assistant Secretary DG Bethlehem Solar, LLC-Assistant Secretary DG BP Solar One, LLC-Assistant Secretary DG Cherry Hill, LLC-Assistant Secretary DG CID Solar, LLC-Assistant Secretary DG Clean Energy Solutions, LLC-Assistant Secretary DG CSU Solar, LLC-Assistant Secretary DG HD Hawaii, LLC-Assistant Secretary DG Irvine Solar I, LLC-Assistant Secretary DG Minnesota CSG 1, LLC-Assistant Secretary DG Minnesota CSG 10, LLC-Assistant Secretary DG Minnesota CSG 2, LLC-Assistant Secretary DG Minnesota CSG 3, LLC-Assistant Secretary DG Minnesota CSG 4, LLC-Assistant Secretary DG Minnesota CSG 5, LLC-Assistant Secretary DG Minnesota CSG 6, LLC-Assistant Secretary 451-11 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) DG Minnesota CSG 7, LLC-Assistant Secretary DG Minnesota CSG 8, LLC-Assistant Secretary DG Minnesota CSG 9, LLC-Assistant Secretary DG Monmouth, LLC-Assistant Secretary DG Moorestown, LLC-Assistant Secretary DG Newark, LLC-Assistant Secretary DG North Carolina Solar Holding, LLC-Assistant Secretary DG Pearl City, LLC-Assistant Secretary DG Project Construction Co., LLC-Assistant Secretary DG Residential Acquisition Co., LLC-Assistant Secretary DG Somerdale Solar, LLC-Assistant Secretary DG SUNY Solar 1, LLC-Assistant Secretary DG Waipio, LLC-Assistant Secretary DG Willowbrook, LLC-Assistant Secretary DG Woodbury Solar, LLC-Assistant Secretary Diablo Winds, LLC-Assistant Secretary Distributed Energy Storage Associates, LLC-Assistant Secretary EarthEra, LLC-Assistant Secretary East Durham Wind BC Holdings, ULC-Secretary East Durham Wind Funding GP, LLC-Assistant Secretary East Durham Wind GP, LLC-Assistant Secretary East Durham Wind Holdings GP, LLC-Assistant Secretary East Durham Wind, ULC-Assistant Secretary EFB Constructors, LLC-Assistant Secretary EFH Merger Co., LLC-Secretary Elk City II Wind Holdings, LLC-Assistant Secretary Elk City II Wind, LLC-Assistant Secretary Elk City Wind Holdings Ill, LLC-Assistant Secretary Elk City Wind Holdings, LLC-Assistant Secretary Elk City Wind Ill, LLC-Assistant Secretary Elk City Wind, LLC-Assistant Secretary Elmira Energy Storage GP, LLC-Assistant Secretary Elmira Energy Storage LP, ULC-Secretary EMB Investments, Inc.-Assistant Secretary Energy Storage Holdings, LLC-Assistant Secretary Energy Storage Projects (Distributed), LLC-Assistant Secretary Energy Storage Projects (Utility), LLC-Assistant Secretary Energy Storage Systems Holdings, LLC-Assistant Secretary Ensign Wind, LLC-Assistant Secretary ESI Altamont Acquisitions, Inc.-Assistant Secretary ESI Bay Area GP, Inc.-Assistant Secretary ESI Bay Area, Inc.-Assistant Secretary ESI California Holdings, Inc.-Assistant Secretary ESI Ebensburg, Inc.-Assistant Secretary ESI Energy, LLC-Assistant Secretary ESI Mojave LLC-Assistant Secretary ESI Mojave, Inc.-Assistant Secretary ESI Northeast Energy GP, Inc.-Assistant Secretary ESI Northeast Energy LP, LLC-Assistant Secretary ESI Northeast Fuel Management, Inc.-Assistant Secretary ESI Sierra, Inc.-Assistant Secretary 451-12 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) NextEra Energy DG Operations, LLC-Assistant Secretary NextEra Energy Duane Arnold, LLC-Assistant Secretary NextEra Energy Equipment Leasing, LLC-Secretary NextEra Energy Equity Partners GP, LLC-Assistant Secretary NextEra Energy Foundation, Inc.-Secretary NextEra Energy Gas Producing Wyoming, LLC-Assistant Secretary NextEra Energy Gas Producing, LLC-Assistant Secretary NextEra Energy Honey Creek Wind, LLC-Assistant Secretary NextEra Energy Infrastructure, LLC-Assistant Secretary NextEra Energy Maine Operating Services, LLC-Assistant Secretary NextEra Energy Maine, LLC-Assistant Secretary NextEra Energy Management Partners GP, LLC-Assistant Secretary NextEra Energy Montezuma II Wind, LLC-Assistant Secretary NextEra Energy Mt. Storm, LLC-Assistant Secretary NextEra Energy New Mexico Operating Services, LLC-Assistant Secretary NextEra Energy NextBridge Holding, ULC-Assistant Secretary NextEra Energy NextBridge Holdings GP, LLC-Assistant Secretary NextEra Energy NextBridge Holdings GP, ULC-Assistant Secretary NextEra Energy Operating Partners GP, LLC-Assistant Secretary NextEra Energy Operating Services, LLC-Assistant Secretary NextEra Energy Partners Acquisitions, LLC-Assistant Secretary NextEra Energy Partners GP, Inc.-Corporate Secretary NextEra Energy Partners Solar Acquisitions, LLC-Assistant Secretary : NextEra Energy Partners Ventures, LLC-Assistant Secretary NextEra Energy Pipeline Development and Acquisitions, LLC-Assistant Secre~ary NextEra Energy Pipeline Holdings, LLC-Secretary ! NextEra Energy Pipeline Services, LLC-Assistant Secretary NextEra Energy Point Beach, LLC-Assistant Secretary NextEra Energy Power Marketing, LLC-Secretary NextEra Energy Producer Services, LLC-Assistant Secretary NextEra Energy Project Management, LLC-Assistant Secretary NextEra Energy Resources Acquisitions, LLC-Assistant Secretary NextEra Energy Resources Partners Holdings, LLC-Assistant Secretary NextEra Energy Resources Partners, LLC-Assistant Secretary NextEra Energy Resources, LLC-Secretary NextEra Energy Sabal Trail Transmission Holdings, LLC-Assistant Secretary NextEra Energy Seabrook, LLC-Assistant Secretary NextEra Energy Services Arizona, LLC-Assistant Secretary NextEra Energy Services Connecticut, LLC-Assistant Secretary NextEra Energy Services Delaware, LLC-Assistant Secretary NextEra Energy Services District of Columbia, LLC-Assistant Secretary NextEra Energy Services Illinois, LLC-Assistant Secretary NextEra Energy Services Maine, LLC-Assistant Secretary NextEra Energy Services Maryland, LLC-Assistant Secretary NextEra Energy Services Massachusetts, LLC-Assistant Secretary NextEra Energy Services New Hampshire, LLC-Assistant Secretary NextEra Energy Services New Jersey, LLC-Assistant Secretary NextEra Energy Services New York, LLC-Assistant Secretary NextEra Energy Services Ohio, LLC-Assistant Secretary NextEra Energy Services Pennsylvania, LLC-Assistant Secretary NextEra Energy Services Rhode Island, LLC-Assistant Secretary 451-19 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) NextEra Energy Services, LLC-Assistant Secretary NextEra Energy Solar Holdings, LLC-Assistant Secretary NextEra Energy Solutions, LLC-Assistant Secretary NextEra Energy Transmission Mid-Atlantic, LLC-Assistant Secretary NextEra Energy Transmission Midwest, LLC-Assistant Secretary NextEra Energy Transmission Southwest, LLC-Assistant Secretary NextEra Energy Transmission West, LLC-Assistant Secretary NextEra Energy UCT Holding, Inc.-Assistant Secretary NextEra Energy US Partners Holdings, LLC-Assistant Secretary NextEra Energy Victory Solar I, LLC-Assistant Secretary NextEra Fibernet, LLC-Assistant Secretary NextEra Maine Fossil, LLC-Assistant Secretary NextEra Retail of Texas GP, LLC-Assistant Secretary NextEra Solar DG Fund I, LLC-Assistant Secretary NextEra Texas Acquisition Holdco, LLC-Assistant Secretary NextEra Texas Acquisition LP, LLC-Assistant Secretary NextEra Transmission Asset Acquisition Holdings, LLC-Assistant Secretary NextEra US Gas Assets, LLC-Assistant Secretary NG Pipeline of America, LLC-Assistant Secretary NG Storage of America, LLC-Assistant Secretary Ninnescah Wind Energy LLC-Assistant Secretary Niyol Wind, LLC-Assistant Secretary North American Power Systems Solar, LLC-Assistant Secretary North American Power Systems, LLC-Assistant Secretary North Coast Solar, LLC-Assistant Secretary North Sky River Energy Holdings, LLC-Assistant Secretary North Sky River Energy, LLC-Assistant Secretary North Sky River Land Holdings, LLC-Assistant Secretary Northern Colorado Wind Energy, LLC-Secretary Northern Colorado Wind Holdings, LLC-Assistant Secretary Northern Frontier Wind Funding, LLC-Assistant Secretary Northern Frontier Wind Holding, LLC-Assistant Secretary Northern Frontier Wind, LLC-Assistant Secretary Northpoint I Wind LP, ULC-Secretary Northpoint II Wind LP, ULC-Secretary Novus Wind VI, LLC-Assistant Secretary NWE Holding, LLC-Assistant Secretary NY Sun DG Solar, LLC-Assistant Secretary NY Sun Zone C2 LLC-Assistant Secretary NY Sun Zone C3 LLC-Assistant Secretary NY Sun Zone E1 LLC-Assistant Secretary NY Sun Zone E2 LLC-Assistant Secretary NY Sun Zone E3 LLC-Assistant Secretary NY Sun Zone E4 LLC-Assistant Secretary NY Sun Zone F1 LLC-Assistant Secretary NY Sun Zone F2 LLC-Assistant Secretary NY Sun Zone F3 LLC-Assistant Secretary NY Sun Zone F4 LLC-Assistant Secretary Oklahoma Wind Portfolio, LLC-Assistant Secretary Old Mill Holdings, LLC-Assistant Secretary Old Mill Solar, LLC-Assistant Secretary 451-20 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) Oliver Wind Ill, LLC-Assistant Secretary Oneida DG Solar, LLC-Assistant Secretary Osborn Wind Energy, LLC-Assistant Secretary Osceola Windpower II, LLC-Assistant Secretary Osceola Windpower, LLC-Assistant Secretary OTG, LLC-Assistant Secretary Pacific Energy Solutions, LLC-Assistant Secretary Palo Duro Wind Energy II, LLC-Assistant Secretary Palo Duro Wind Energy, LLC-Assistant Secretary Palo Duro Wind Holdings SeliGa, LLC-Assistant Secretary Palo Duro Wind Interconnection Services, LLC-Assistant Secretary Palo Duro Wind Portfolio, LLC-Assistant Secretary Palo Duro Wind Project Holdings, LLC-Assistant Secretary Paradise Solar Urban Renewal, L.L.C.-Assistant Secretary Parry Energy Storage GP, LLC-Assistant Secretary Parry Energy Storage LP, ULC-Secretary Peace Garden Wind Funding, LLC-Assistant Secretary Peace Garden Wind Holdings, LLC-Assistant Secretary Peace Garden Wind, LLC-Assistant Secretary Peetz Energy, LLC-Assistant Secretary Peetz Logan Interconnect, LLC-Assistant Secretary Peetz Table Transmission Line, LLC-Assistant Secretary Peetz Table Wind Energy, LLC-Assistant Secretary Pennsylvania Windfarms, LLC-Assistant Secretary Penobscot Wind, LLC-Assistant Secretary Penta Wind Holding, LLC-Assistant Secretary Penta Wind, LLC-Assistant Secretary Perrin Ranch Wind, LLC-Assistant Secretary Pheasant Run Wind Holdings II, LLC-Assistant Secretary Pheasant Run Wind Holdings, LLC-Assistant Secretary Pheasant Run Wind, LLC-Assistant Secretary Pima Energy Storage System, LLC-Assistant Secretary Pioneer Plains Wind Funding, LLC-Assistant Secretary Pioneer Plains Wind Holdings, LLC-Assistant Secretary Pioneer Plains Wind, LLC-Assistant Secretary Porta del Sol Solar, LLC-Assistant Secretary Prairie View Wind Holdings, LLC-Assistant Secretary Pubnico Point Wind Farm Inc.-Assistant Secretary PWEC, LLC-Assistant Secretary Red Mesa Wind Investments, LLC-Assistant Secretary Red Mesa Wind, LLC-Assistant Secretary Red Raider Wind Holdings, LLC-Assistant Secretary Red Raider Wind, LLC-Assistant Secretary Red River Wind Funding, LLC-Assistant Secretary Red River Wind Holdings, LLC-Assistant Secretary Red River Wind, LLC-Assistant Secretary Redwood Trails Wind Holdings, LLC-Assistant Secretary Redwood Trails Wind, LLC-Assistant Secretary RGS Realty Holdings, LLC-Assistant Secretary RGS Realty, LLC-Assistant Secretary River Bend Solar, LLC-Assistant Secretary Roswell Solar Holdings, LLC-Assistant Secretary 451-21 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) Roswell Solar, LLC-Assistant Secretary Rush Springs Wind Energy, LLC-Assistant Secretary Sagebrush Partner Fifteen, Inc.-Assistant Secretary San Jacinto Solar 14.5, LLC-Assistant Secretary San Jacinto Solar 5.5, LLC-Assistant Secretary SCI Holding, ULC-Assistant Secretary SDGF 1 Funding, LLC-Assistant Secretary SEC Amherst Solar One, LLC-Assistant Secretary SEC CRSD Solar One, LLC-Assistant Secretary SEC ESSD Solar One, LLC-Assistant Secretary SEC HSD Solar One, LLC-Assistant Secretary SEC LHNY Solar One, LLC-Assistant Secretary SEC MC Solar One, LLC-Assistant Secretary SEC Northeast Solar One, LLC-Assistant Secretary SEC PASO Solar One, LLC-Assistant Secretary SEC SUSD Solar One, LLC-Assistant Secretary Seiling Wind Holdings, LLC-Assistant Secretary Seiling Wind II, LLC-Assistant Secretary Seiling Wind Interconnection Services, LLC-Assistant Secretary Seiling Wind Portfolio, LLC-Assistant Secretary Seiling Wind, LLC-Assistant Secretary Sentry Solar, LLC-Assistant Secretary Shafter Solar Holdings, LLC-Assistant Secretary Shafter Solar SeiiCo, LLC-Assistant Secretary Shafter Solar, LLC-Assistant Secretary Silver State Solar Power South, LLC-Assistant Secretary Silver State South Solar, LLC-Assistant Secretary Sirius Solar, LLC-Assistant Secretary Sky River Asset Holdings, LLC-Assistant Secretary Sky River LLC-Assistant Secretary Smart Energy Capital, LLC-Assistant Secretary Solar DG Fund 1 Holdings, LLC-Assistant Secretary Solar Holdings SeiiCo, LLC-Assistant Secretary Sombra Solar GP, LLC-Assistant Secretary Sombra Solar, ULC-Assistant Secretary Somerset Windpower LLC-Assistant Secretary Sonoran Solar Energy I, LLC-Assistant Secretary Sonoran Solar Energy, LLC-Assistant Secretary Sooner Trails Pipeline, LLC-Assistant Secretary South Texas Gen-Tie Holding, LLC-Assistant Secretary South Texas Gen-Tie, LLC-Assistant Secretary South Texas Wind Energy, LLC-Assistant Secretary South Texas Wind Holdings, LLC-Assistant Secretary Southwest Solar Holdings, LLC-Assistant Secretary St. Clair GP, LLC-Assistant Secretary St. Clair Holding, ULC-Assistant Secretary St. Clair Moore Holding LP, LLC-Assistant Secretary St. Clair MS Investment GP, LLC-Assistant Secretary St. Clair Sombra Holding LP, LLC-Assistant Secretary Stark Wind, LLC-Assistant Secretary Steele Flats Wind Project, LLC-Assistant Secretary Story Wind, LLC-Assistant Secretary 451-22 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) Stuttgart Solar, LLC-Assistant Secretary Tech Testing Solutions Holdings, LLC-Assistant Secretary Tech Testing Solutions, LLC-Assistant Secretary Thames Solar LP, ULC-Secretary Tower Associates Canada, Inc.-Assistant Secretary Tower Associates, LLC-Assistant Secretary Trenton Diocese DG Solar, LLC-Assistant Secretary Trout Lake I Solar LP, ULC-Secretary Trout Lake II Solar LP, ULC-Secretary Trout Lake Ill Solar LP, ULC-Secretary Tuscola Bay Wind, LLC-Assistant Secretary Tuscola Wind II, LLC-Assistant Secretary Tuscola Wind Ill, LLC-Assistant Secretary U. S. Windpower Transmission Corporation-Assistant Secretary UC Solar, LLC-Assistant Secretary US Marcellus Gas Infrastructure, LLC-Assistant Secretary US Sooner Trails Gas Infrastructure, LLC-Assistant Secretary US Southeastern Gas Infrastructure, LLC-Assistant Secretary USG Energy Gas Investment, LLC-Assistant Secretary USG Energy Gas Producer Holdings, LLC-Assistant Secretary USG Midstream Bakken I, LLC-Assistant Secretary USG Midstream Haynesville Sands I, LLC-Assistant Secretary USG Midstream Holdings, LLC-Assistant Secretary USG Midstream Mississippian Lime I, LLC-Assistant Secretary USG Properties Austin Chalk Holdings, LLC-Assistant Secretary USG Properties Austin Chalk I, LLC-Assistant Secretary USG Properties Bakken Holdings, LLC-Assistant Secretary USG Properties Bakken I, LLC-Assistant Secretary USG Properties Bakken II, LLC-Assistant Secretary USG Properties Barnett Holdings, LLC-Assistant Secretary USG Properties Barnett II, LLC-Assistant Secretary USG Properties Eagle Ford Holdings, LLC-Assistant Secretary USG Properties Eagle Ford Ill, LLC-Assistant Secretary USG Properties Eagle Ford IV, LLC-Assistant Secretary USG Properties Granite Wash Holdings, LLC-Assistant Secretary USG Properties Granite Wash I, LLC-Assistant Secretary USG Properties Haynesville Sand I, LLC-Assistant Secretary USG Properties Haynesville Sands Holdings, LLC-Assistant Secretary USG Properties Jackfork Holdings, LLC-Assistant Secretary USG Properties Jackfork I, LLC-Assistant Secretary USG Properties Marcellus Holdings, LLC-Assistant Secretary USG Properties Mississippian Lime Holdings, LLC-Assistant Secretary USG Properties Mississippian Lime I, LLC-Assistant Secretary USG Properties Mississippian Lime II, LLC-Assistant Secretary USG Properties Niobrara Holdings, LLC-Assistant Secretary USG Properties Permian Basin Holdings, LLC-Assistant Secretary USG Properties Permian Basin I, LLC-Assistant Secretary USG Properties Permian Basin II, LLC-Assistant Secretary USG Properties Wilcox Holdings, LLC-Assistant Secretary USG Properties Wilcox I, LLC-Assistant Secretary USG Properties Woodford Holdings, LLC-Assistant Secretary USG Properties Woodford I, LLC-Assistant Secretary 451-23 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Seeley (continued) USG Properties Woodford II, LLC-Assistant Secretary USG Surface Facilities Holdings, LLC-Assistant Secretary USG Surface Facilities I, LLC-Assistant Secretary USG Surface Facilities II, LLC-Assistant Secretary USG Surface Facilities Mississippian Lime I, LLC-Assistant Secretary USG Technology Holdings, LLC-Assistant Secretary USG West Relay, LLC-Assistant Secretary USG Wheatland Pipeline, LLC-Assistant Secretary USW Land Corporation-Assistant Secretary Valencia Energy Storage, LLC-Assistant Secretary Vansycle Ill Wind, LLC-Assistant Secretary Varna Wind Funding GP, LLC-Assistant Secretary Varna Wind GP, LLC-Assistant Secretary Varna Wind Holdings GP, LLC-Assistant Secretary Varna Wind, ULC-Assistant Secretary Vasco Winds, LLC-Assistant Secretary Venable Solar, LLC-Assistant Secretary Victory Renewables, LLC-Assistant Secretary Watkins Glen Wind, LLC-Assistant Secretary Watonga Wind, LLC-Assistant Secretary Waymart Storage, LLC-Assistant Secretary Wessington Wind Energy Center, LLC-Assistant Secretary West Hills Wind, LLC-Assistant Secretary West Texas Wind, LLC-Assistant Secretary Western Wind Holdings, LLC-Assistant Secretary Westside Solar, LLC-Assistant Secretary White Oak B Company, LLC-Assistant Secretary White Oak Energy Backleverage Holding, LLC-Assistant Secretary White Oak Energy Funding Holding, LLC-Assistant Secretary White Oak Energy Funding, LLC-Assistant Secretary White Oak Energy Holdings, LLC-Assistant Secretary White Oak Energy LLC-Assistant Secretary White Oak Solar, LLC-Assistant Secretary White Pine Solar, LLC-Assistant Secretary Whitewater Wind, LLC-Assistant Secretary Whitney Point Solar, LLC-Assistant Secretary Wild Prairie Wind Holdings, LLC-Assistant Secretary Wild Prairie Wind, LLC-Assistant Secretary Wilton Wind II, LLC-Assistant Secretary Wilton Wind IV, LLC-Assistant Secretary Wind Holdings, Inc.-Assistant Secretary WindCo LLC-Assistant Secretary Windlogics Inc.-Assistant Secretary Windpower Partners 1993, LLC-Assistant Secretary Wolf Ridge Wind, LLC-Assistant Secretary WSGP Gas Producing, LLC-Assistant Secretary Wyman Cape Holdings, LLC-Assistant Secretary 451-24 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Sole. Michael W.- Vice President. State Governmental Affairs N/A Spoor. Michael G. -Vice President, Transmission and Substation N/A Summers. Thomas -Vice President, Turkey Point Nuclear Power Plant N/A Cutler. Paul I. -Treasurer NextEra Energy, Inc.-Treasurer and Assistant Secretary Adelanto Solar Funding, LLC-Vice President Adelanto Solar Holdings, LLC-Vice President Adelanto Solar II, LLC-Vice President Adelanto Solar, LLC-Vice President Alandco I, Inc.-Treasurer Alandco Inc.-Treasurer Alandco/Cascade, Inc.-Treasurer Albercas Wind Energy II, LLC-Vice President Altamont Power LLC-Vice President Aquilo Holdings LP, ULC-Vice President Aquilo LP, ULC-Director; Vice President Ashtabula Wind Ill, LLC-Vice President Ashtabula Wind, LLC-Vice President and Assistant Treasurer Backbone Mountain Windpower LLC-Vice President and Treasurer Backbone Mountain Windpower LLC-Executive Manager, Vice President and :rreasurer Backbone Windpower Holdings, LLC-Executive Manager, Baldwin Wind Holdings, LLC-Vice President Baldwin Wind, LLC-Vice President Barrett Repowering, LLC-Vice President Battersea Solar LP, ULC-Vice President Battery Testing and Modeling, LLC-Vice President Bayhawk Wind Funding, LLC-Vice President Bayhawk Wind Holdings, LLC-Vice President Bayhawk Wind SeiiCo, LLC-Vice President Bayhawk Wind, LLC-Vice President Bayswater Peaking Facility, LLC-Vice President Bayswater Peaking Facility, LLC-Treasurer BCSD Solar, LLC-Vice President Bison Wind Holdings, LLC-Executive Manager; Vice President and Treasurer i Bison Wind Investments, LLC-Executive Manager; Vice President and Treasurer Bison Wind Portfolio, LLC-Vice President and Treasurer Bison Wind Portfolio, LLC-Executive Manager Bison Wind, LLC-Executive Manager; Vice President and Treasurer Blackwell Wind, LLC-Vice President Blue Summit II Wind, LLC-Vice President Bluebell Solar, LLC-Vice President Blythe Solar 110, LLC-Vice President Blythe Solar Holdings, LLC-Vice President 451·25 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Cutler (continued) Blythe Solar II, LLC-Vice President Blythe Solar Ill, LLC-Vice President Blythe Solar IV, LLC-Vice President Bornish Wind BC Holdings, ULC-Vice President Bornish Wind Funding GP, LLC-Vice President Bornish Wind GP, LLC-Vice President Bornish Wind Holdings GP, LLC-Vice President Bornish Wind LP, ULC-Vice President Brady Wind II, LLC-Vice President Brady Wind, LLC-Vice President Breckinridge Wind Class A Holdings, LLC-Vice President Breckinridge Wind Funding, LLC-Vice President Breckinridge Wind Holdings, LLC-Vice President Breckinridge Wind Project, LLC-Vice President Butler Ridge Wind Energy Center, LLC-Vice President Cabo Solar Farm, LLC-Vice President Canadian Combined Cycle Station I LP, ULC-Vice President Canyon Wind Holdings, LLC-Vice President Canyon Wind, LLC-Vice President Capricorn Ridge B Holdings, LLC-Vice President Capricorn Ridge B, LLC-Vice President Capricorn Ridge Power Seller, LLC-Vice President Capricorn Ridge Wind Funding, LLC-Vice President Capricorn Ridge Wind Holdings, LLC-Vice President Carousel Wind Farm, LLC-Vice President Carousel Wind Holdings, LLC-Vice President Cedar Bay Cogeneration, LLC-Treasurer Cedar Bay Holdings, LLC-Treasurer Cedar Bluff Wind, LLC-Vice President Cedar II Power, LLC-Treasurer Centennial Wind Class B, LLC-Vice President Centennial Wind Funding, LLC-Vice President Centennial Wind Holdings, LLC-Vice President Centennial Wind, LLC-Vice President Central States Wind Holdings, LLC-Vice President Central States Wind, LLC-Vice President Chaves County Solar Holdings, LLC-Vice President Chaves County Solar II Holdings, LLC-Vice President Chaves County Solar II, LLC-Vice President Chaves County Solar Resources, LLC-Vice President Chaves County Solar, LLC-Vice President Cimarron Wind Energy, LLC-Vice President Clarabelle I Solar LP, ULC-Vice President Clarabelle II Solar LP, ULC-Vice President Clarabelle Ill Solar LP, ULC-Vice President Colonial Penn Capital Holdings, Inc.-Director; Vice President and Treasurer Common Unit Holdings, LLC-Treasurer Cordukes Solar LP, ULC-Vice President Costigan Wind LP, ULC-Vice President Cottonwood Wind Project Holdings, LLC-Vice President Cottonwood Wind Project, LLC-Vice President 451-26 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Cutler (continued) CP II CAD Holdings LP GP, LLC-Vice President CP II Holdings LP, ULC-Vice President Crowned Ridge Wind, LLC-Vice President Crystal Lake Wind, LLC-Vice President and Assistant Treasurer Desert Sunlight 250, LLC-Vice President Desert Sunlight 300, LLC-Vice President Desert Sunlight Holdings, LLC-Vice President DG 1 Acquisition Co., LLC-Vice President DG 1, LLC-Vice President DG Bethlehem Solar, LLC-Vice President DG BP Solar One, LLC-Vice President DG Cherry Hill, LLC-Vice President DG CID Solar, LLC-Vice President DG Clean Energy Solutions, LLC-Vice President DG CSU Solar, LLC-Vice President DG HD Hawaii, LLC-Vice President DG Irvine Solar I, LLC-Vice President DG Minnesota CSG 1, LLC-Vice President DG Minnesota CSG 10, LLC-Vice President DG Minnesota CSG 2, LLC-Vice President DG Minnesota CSG 3, LLC-Vice President DG Minnesota CSG 4, LLC-Vice President DG Minnesota CSG 5, LLC-Vice President DG Minnesota CSG 6, LLC-Vice President DG Minnesota CSG 7, LLC-Vice President DG Minnesota CSG 8, LLC-Vice President DG Minnesota CSG 9, LLC-Vice President DG Monmouth, LLC-Vice President DG Moorestown, LLC-Vice President DG Newark, LLC-Vice President DG North Carolina Solar Holding, LLC-Vice President DG Pearl City, LLC-Vice President DG Project Construction Co., LLC-Vice President DG Residential Acquisition Co., LLC-Vice President DG Somerdale Solar, LLC-Vice President DG SUNY Solar 1, LLC-Vice President DG Waipio, LLC-Vice President DG Willowbrook, LLC-Vice President DG Woodbury Solar, LLC-Vice President Diablo Winds, LLC-Vice President Distributed Energy Storage Associates, LLC-Vice President East Durham Wind BC Holdings, ULC-Vice President East Durham Wind Funding GP, LLC-Vice President East Durham Wind GP, LLC-Vice President East Durham Wind Holdings GP, LLC-Vice President EFH Merger Co., LLC-Treasurer Elk City II Wind Holdings, LLC-Vice President and Treasurer Elk City Wind Holdings, LLC-Vice President and Treasurer Elk City Wind, LLC-Vice President Elmira Energy Storage GP, LLC-Vice President Elmira Energy Storage LP, ULC-Vice President 451-27 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Cutler (continued) Energy Storage Projects (Distributed), LLC-Vice President Energy Storage Projects (Utility), LLC-Vice President Energy Storage Systems Holdings, LLC-Vice President ESI Energy, LLC-Treasurer ESI Mojave LLC-Vice President ESI Vansycle GP, Inc.-Vice President and Treasurer ESI Vansycle LP, Inc.-Vice President and Treasurer ESI VG IV, LLC-Vice President ESI West Texas Energy LP, LLC-Executive Manager ESI West Texas Energy LP, LLC-Vice President ESI West Texas Energy LP, LLC-Treasurer ESI West Texas Energy, Inc.-Vice President ESI West Texas Energy, Inc.-Treasurer EV Battery Storage, LLC-Vice President EW Solar, LLC-Vice President Florida Southeast Connection, LLC-Treasurer Fortuna GP, LLC-Vice President Fortuna Limited Partner, ULC-Vice President FPL Energy American Wind Holdings, LLC-Vice President FPL Energy American Wind Holdings, LLC-Treasurer FPL Energy American Wind Holdings, LLC-Executive Manager FPL Energy American Wind, LLC-Executive Manager, Vice President and Treasurer FPL Energy Burleigh County Wind, LLC-Executive Manager; Vice President and Treasurer FPL Energy Cabazon Wind, LLC-Vice President FPL Energy Cowboy Wind, LLC-Executive Manager, Vice President and Treasurer FPL Energy Hancock County Wind, LLC-Executive Manager; Vice President and Treasurer FPL Energy Horse Hollow Wind II, LLC-Executive Manager, Vice President and Treasurer FPL Energy Horse Hollow Wind, LLC-Executive Manager; Vice President and Treasurer FPL Energy Marcus Hook LLC-Executive Manager; Vice President FPL Energy MH700, LLC-Executive Manager; Vice President FPL Energy Morwind, LLC-Vice President FPL Energy National Wind Holdings, LLC-Executive Manager; Vice President and Treasurer FPL Energy National Wind Investments, LLC-Executive Manager; Vice President and Treasurer FPL Energy National Wind Portfolio, LLC-Executive Manager; Vice President and Treasurer FPL Energy National Wind, LLC-Executive Manager; Vice President and Treasurer FPL Energy New Mexico Holdings, LLC-Executive Manager; Vice President and Treasurer FPL Energy New Mexico Wind Financing, LLC-Executive Manager; Vice President and Treasurer FPL Energy New Mexico Wind Holdings II, LLC-Executive Manager, Vice President and Treasurer FPL Energy New Mexico Wind II, LLC-Executive Manager; Vice President and Treasurer FPL Energy New Mexico Wind, LLC-Executive Manager; Vice President and Treasurer FPL Energy New York, LLC-Vice President and Treasurer FPL Energy North Dakota Wind II, LLC-Executive Manager; Vice President and Treasurer FPL Energy North Dakota Wind, LLC-Executive Manager; Vice President and Treasurer FPL Energy Oklahoma Wind Finance, LLC-Vice President and Treasurer FPL Energy Oklahoma Wind Finance, LLC-Executive Manager; Vice President and Treasurer FPL Energy Post Wind GP, LLC-Executive Manager; Vice President and Treasurer FPL Energy Post Wind LP, LLC-Executive Manager; Vice President and Treasurer FPL Energy Rockaway Peaking Facilities, LLC-Vice President FPL Energy SEGS Ill-VII GP, LLC-Vice President FPL Energy SEGS Ill-VII LP, LLC-Vice President FPL Energy Services, Inc.-Treasurer 451-28 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Cutler (continued) FPL Energy Sooner Wind, LLC-Executive Manager; Vice President and Treast:Jrer FPL Energy South Dakota Wind, LLC-Executive Manager; Vice President and lreasurer FPL Energy Stateline Holdings, L.L.C.-Vice President and Treasurer FPL Energy Stateline II Holdings, LLC-Vice President and Treasurer FPL Energy Stateline II, Inc.-Vice President and Treasurer FPL Energy Texas Wind GP, LLC-Vice President and Treasurer FPL Energy Tyler Texas LP, LLC-Vice President and Treasurer FPL Energy Upton Wind I, LLC-Vice President FPL Energy Upton Wind II, LLC-Vice President FPL Energy Upton Wind Ill, LLC-Vice President FPL Energy Upton Wind IV, LLC-Vice President FPL Energy Vansycle L.L.C.-Vice President FPL Energy Waymart GP, LLC-Executive Manager; Vice President and Treasurer FPL Energy Waymart LP, LLC-Executive Manager; Vice President and Treasurer FPL Energy Wind Financing, LLC-Executive Manager; Vice President and Treasurer FPL Energy Wind Funding Holdings, LLC-Executive Manage ; Vice President a!nd Treasurer FPL Energy Wind Funding, LLC-Executive Manager; Vice President and Treasurer · FPL Enersys, Inc.-Treasurer FPL FiberNet Holdings, LLC-Treas.urer FPL FiberNet, LLC-Treasurer FPL Group Capital Trust !-Administrative Trustee FPL Historical Museum, Inc.-Director; Vice President and Assistant Treasurer FPL Holdings Inc-Director; Vice President and Treasurer FPL Investments, LLC-Treasurer and Controller FPL Readi-Power, LLC-Treasurer FPL Recovery Funding LLC-Manager; Treasurer FPL Services, LLC-Treasurer FPLE Forney Pipeline, LLC-Assistant Treasurer FPLE Forney, LLC-Assistant Treasurer Gateway Energy Center Holdings, LLC-Vice President Genesis Solar Funding Holdings, LLC-Vice President Genesis Solar Funding, LLC-Vice President Georgia Longleaf Solar 1, LLC-Vice President Ghost Pine Energy Storage LP, ULC-Vice President Ghost Pine Holdings, ULC-Vice President Golden Hills Energy Storage, LLC-Vice President Golden Hills Interconnection, LLC-Vice President Golden Hills North Wind, LLC-Vice President Golden Hills Wind, LLC-Vice President Golden West Power Partners, LLC-Vice President Golden West Wind Holdings, LLC-Vice President Golden Winds Funding, LLC-Vice President Golden Winds Holdings, LLC-Vice President Golden Winds, LLC-Vice President Goshen Wind BC Holdings, ULC-Vice President Goshen Wind Funding GP, LLC-Vice President Goshen Wind GP, LLC-Vice President Goshen Wind Holdings GP, LLC-Vice President GR Woodford Properties, LLC-Treasurer Gray Sky Investments, LLC-Treasurer Green Mountain Storage, LLC-Vice President Green Ridge Power LLC-Vice President Green Ridge Services LLC-Vice President 451-29 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Cutler (continued) Hale Wind Energy, LLC-Vice President Hardy Creek Wind, LLC-Vice President Hardy Creek Wind, ULC-Vice President Hawkeye Power Partners, LLC-Executive Manager HCSD Solar, LLC-Vice President HD Hatillo Solar One, LLC-Vice President Heartland Wind Funding, LLC-Vice President and Assistant Treasurer Heartland Wind Holding II, LLC-Vice President and Assistant Treasurer Heartland Wind Holding, LLC-Vice President and Assistant Treasurer Heartland Wind II, LLC-Vice President and Assistant Treasurer Heartland Wind, LLC-Vice President and Assistant Treasurer High Hills Wind LP, ULC-Vice President High Majestic II Funding, LLC-Vice President High Majestic II Holdings, LLC-Vice President High Majestic II Wind Properties, LLC-Vice President High Majestic Interconnection Services, LLC-Vice President High Majestic Wind Energy Center, LLC-Vice President High Majestic Wind II, LLC-Vice President High Winds, LLC-Executive Manager ; Vice President and Treasurer Horse Hollow Generation Tie Holdings, LLC-Vice President HWFII, LLC-Vice President and Assistant Treasurer Inventus Holdings, LLC-Vice President Jacumba Solar, LLC-Vice President Jamaica Bay Peaking Facility, LLC-Vice President and Treasurer Javelina Interconnection, LLC-Vice President Javelina Wind Class B, LLC-Vice President Javelina Wind Energy Holdings, LLC-Vice President Javelina Wind Energy, LLC-Vice President Javelina Wind Funding Holdings, LLC-Vice President Javelina Wind Funding, LLC-Vice President Javelina Wind Holdings II, LLC-Vice President Jericho Wind BC Holdings, ULC-Vice President Jericho Wind Funding GP, LLC-Vice President Jericho Wind GP, LLC-Vice President Jericho Wind Holdings GP, LLC-Vice President Joshua Tree Solar Farm, LLC-Vice President KaLa Nui Solar, LLC-Vice President Kerwood Wind BC Holdings, ULC-Vice President Kerwood Wind Funding GP, LLC-Vice President Kerwood Wind GP, LLC-vice President Kerwood Wind Holdings GP, LLC-Vice President Kingman Wind Energy I, LLC-Vice President Kingman Wind Energy II, LLC-Vice President Kingman Wind Holding I, LLC-Vice President Kingman Wind Holding II, LLC-Vice President La Frontera Generation, LLC-Vice President La Frontera Holdings, LLC-Vice President La Frontera Ventures, LLC-Vice President La Palma DG Solar, LLC-Vice President Lake Benton Power Partners II, LLC-Executive Manager Lakeco Holding, LLC-Vice President Lamar Power Partners, LLC-Assistant Treasurer 451-30 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Cutler (continued) Langdon Wind, LLC-Vice President and Assistant Treasurer LCSD Solar 1, LLC-Vice President LCSD Solar 2, LLC-Vice President Legacy Renewables Holdings, LLC-Vice President Legacy Renewables, LLC-Vice President Legends Wind Class 8, LLC-Vice President Legends Wind Funding, LLC-Vice President Legends Wind Holdings, LLC-Vice President Legends Wind, LLC-Vice President Limon Wind Ill Funding, LLC-Vice President Limon Wind Ill Holdings, LLC-Vice President Limon Wind Ill, LLC-Vice President Live Oak Solar, LLC-Vice President Lone Star Transmission Capital, LLC-Vice President and Treasurer Lone Star Transmission Holdings, LLC-Vice President and Treasurer Lone Star Transmission, LLC-Vice President Lone Star Wind Holdings, LLC-Vice President and Treasurer Lone Star Wind Holdings, LLC-Executive Manager Lone Star Wind, LLC-Vice President and Treasurer Lone Star Wind, LLC-Manager Long Island Energy Generation, LLC-Vice President Long Island Energy Storage Holdings, LLC-Vice President Long Island Peaker Holdings, LLC-Vice President Long Island Solar Holdings, LLC-Vice President M Boulevard Solar, LLC-Vice President M Cross County Solar, LLC-Vice President M Greece Ridge Solar, LLC-Vice President M Nanuet Solar, LLC-Vice President M Queens Rego Solar, LLC-Vice President M Schenectady Solar, LLC-Vice President M White Plains Solar, LLC-Vice President Mammoth Plains Wind Project Holdings, LLC-Vice President Mammoth Plains Wind Project, LLC-Vice President Mantua Creek Solar, LLC-Vice President Marshall Solar, LLC-Vice President McCoy Solar Funding, LLC-Vice President McCoy Solar Holdings, LLC-Vice President McCoy Solar, LLC-Vice President Meadowlark Wind Holdings, LLC-Vice President Meadowlark Wind, LLC-Vice President Meyersdale Storage, LLC-Vice President Meyersdale Windpower, LLC-Executive Manager ; Vice President and Treasurer Mill Run Windpower LLC-Vice President Minco Redwood Holdings, LLC-Vice President Minco Wind Ill, LLC-Vice President Minco Wind Interconnection Services, LLC-Vice President Minco Wind IV, LLC-Vice President Minudie Wind LP, ULC-Vice President Maca Solar Farm, LLC-Vice President Mojave Holdings, LLC-Vice President Mojave Red Venturez, LLC-Vice President 451-31 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Cutler (continued) Moore Solar GP, LLC-Vice President Moore Solar GP, ULC-Vice President Moore Solar, ULC-Vice President Moose Wind, LLC-Vice President Morongo DG Solar, LLC-Vice President Mount Miller Holdco, LLC-Vice President Mount Miller Holdings GP, LLC-Vice President Mount Miller LP, ULC-Vice President Mountain Prairie Wind Holdings, LLC-Vice President Mountain Prairie Wind, LLC-Vice President Mountain View Solar Holdings, LLC-Vice President Mountain View Solar, LLC-Vice President Mt. Storm Wind Force Holdings, LLC-Vice President Mt. Storm Wind Force, LLC-Vice President NAPS Wind, LLC-Vice President NEE Acquisition Sub I, LLC-Treasurer NEE Acquisition Sub II, Inc.-Treasurer NEP US SeiiCo, LLC-Vice President NET General Partners, LLC-Vice President NET Holdings Management, LLC-Vice President NET Midstream, LLC-Vice President NET Pipeline Holdings LLC-Vice President NextEra Blythe Solar Energy Center, LLC-Vice President NextEra Energy Canada GP, LLC-Vice President & Treasurer NextEra Energy Canada Partners Holdings, ULC-Vice President NextEra Energy Canadian Holdings, ULC-Treasurer NextEra Energy Canadian Holdings, ULC-Vice President NextEra Energy Canadian Operating Services, Inc.-Vice President NextEra Energy Capital Holdings, Inc.-Director; Vice President and Treasurer NextEra Energy DG Operations, LLC-Vice President NextEra Energy Equipment Leasing, LLC-Treasurer NextEra Energy Equity Partners GP, LLC-Treasurer NextEra Energy Foundation, Inc.-Vice President and Assistant Treasurer NextEra Energy Infrastructure, LLC-Treasurer NextEra Energy Management Partners GP, LLC-Treasurer NextEra Energy Mt. Storm, LLC-Vice President NextEra Energy Operating Partners GP, LLC-Treasurer NextEra Energy Partners Acquisitions, LLC-Vice President NextEra Energy Partners GP, Inc.-Treasurer and Assistant Secretary NextEra Energy Partners Solar Acquisitions, LLC-Vice President NextEra Energy Partners Ventures, LLC-Vice President NextEra Energy Pipeline Holdings, LLC-Treasurer NextEra Energy Pipeline Services, LLC-Vice President & Treasurer NextEra Energy Resources Acquisitions, LLC-Vice President NextEra Energy Resources Partners Holdings, LLC-Treasurer NextEra Energy Resources Partners, LLC-Treasurer NextEra Energy Resources, LLC-Treasurer NextEra Energy Solar Holdings, LLC-Vice President NextEra Energy US Partners Holdings, LLC-Treasurer NextEra Energy Victory Solar I, LLC-Vice President NextEra Fibernet, LLC-Treasurer NextEra Maine Fossil, LLC-Vice President 451-32 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Cutler (continued) NextEra Solar DG Fund I, LLC-Vice President Ninnescah Wind Energy LLC-Vice President Niyol Wind, LLC-Vice President North Coast Solar, LLC-Vice President North Sky River Energy Holdings, LLC-Vice President Northern Colorado Wind Energy, LLC-Vice President Northern Frontier Wind Funding, LLC-Executive Manager; Vice President Northern Frontier Wind, LLC-Vice President Northpoint I Wind LP, ULC-Vice President Northpoint II Wind LP, ULC-Vice President Novus Wind VI, LLC-Vice President NWE Holding, LLC-Vice President NY Sun DG Solar, LLC-Vice President NY Sun Zone C2 LLC-Vice President NY Sun Zone C3 LLC-Vice President NY Sun Zone E1 LLC-Vice President NY Sun Zone E2 LLC-Vice President NY Sun Zone E3 LLC-Vice President NY Sun Zone E4 LLC-Vice President NY Sun Zone F1 LLC-Vice President NY Sun Zone F2 LLC-Vice President NY Sun Zone F3 LLC-Vice President NY Sun Zone F4 LLC-Vice President Oklahoma Wind Portfolio, LLC-Vice President Old Mill Holdings, LLC-Vice President Old Mill Solar, LLC-Vice President Oneida DG Solar, LLC-Vice President Osborn Wind Energy, LLC-Vice President Pacific Energy Solutions, LLC-Vice President Pacific Power Investments, LLC-Executive Manager; Vice President Palms Insurance Company, Limited-Director and Limited Treasurer Palo Duro Wind Energy II, LLC-Vice President Palo Duro Wind Energy, LLC-Vice President Palo Duro Wind Holdings SeiiCo, LLC-Vice President Palo Duro Wind Interconnection Services, LLC-Vice President Palo Duro Wind Portfolio, LLC-Vice President Palo Duro Wind Project Holdings, LLC-Vice President Paradise Solar Urban Renewal, L.L.C.-Vice President Parry Energy Storage GP, LLC-Vice President Parry Energy Storage LP, ULC-Vice President Peace Garden Wind Funding, LLC-Vice President and Treasurer Peace Garden Wind Holdings, LLC-Vice President and Treasurer Peace Garden Wind, LLC-Vice President and Treasurer Pennsylvania Windfarms, LLC-Vice President Penobscot Wind, LLC-Vice President Penta Wind Holding, LLC-Vice President and Assistant Treasurer Penta Wind, LLC-Vice President and Assistant Treasurer Pheasant Run Wind Holdings II, LLC-Vicfil President Pheasant Run Wind Holdings, LLC-Vice President Pheasant Run Wind, LLC-Vice President Pima Energy Storage System, LLC-Vice President Pioneer Plains Wind Funding, LLC-Vice President 451-33 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Cutler (continued) Pioneer Plains Wind Holdings, LLC-Vice President Pioneer Plains Wind, LLC-Vice President Pipeline Funding Company, LLC-Vice President and Treasurer Porta del Sol Solar, LLC-Vice President Prairie View Wind Holdings, LLC-Vice President Pubnico Point Wind Farm Inc.-Vice President Red Raider Wind Holdings, LLC-Vice President Red Raider Wind, LLC-Vice President Red River Wind Funding, LLC-Vice President Red River Wind Holdings, LLC-Vice President Red River Wind, LLC-Vice President RGS Realty Holdings, LLC-Treasurer RGS Realty, LLC-Treasurer River Bend Solar, LLC-Vice President Roswell Solar Holdings, LLC-Vice President Roswell Solar, LLC-Vice President Rush Springs Wind Energy, LLC-Vice President Sagebrush Partner Fifteen, Inc.-Vice President San Jacinto Solar 14.5, LLC-Vice President San Jacinto Solar 5.5, LLC-Vice President SCI Holding, ULC-Vice President SCIH GP, ULC-Vice President SDGF 1 Funding, LLC-Vice President SEC Amherst Solar One, LLC-Vice President SEC CRSD Solar One, LLC-Vice President SEC ESSD Solar One, LLC-Vice President SEC HSD Solar One, LLC-Vice President SEC LHNY Solar One, LLC-Vice President SEC MC Solar One, LLC-Vice President SEC Northeast Solar One, LLC-Vice President SEC PASO Solar One, LLC-Vice President SEC SUSD Solar One, LLC-Vice President Seiling Wind Holdings, LLC-Vice President Seiling Wind II, LLC-Vice President Seiling Wind Interconnection Services, LLC-Vice President Seiling Wind Portfolio, LLC-Vice President Seiling Wind, LLC-Vice President Shafter Solar Holdings, LLC-Vice President Shafter Solar SeiiCo, LLC-Vice President Shafter Solar, LLC-Vice President Silver State Solar Power South, LLC-Vice President Silver State South Solar, LLC-Vice President Sirius Solar, LLC-Vice President Sky River Asset Holdings, LLC-Vice President Sky River LLC-Vice President Smart Energy Capital, LLC-Vice President Solar DG Fund 1 Holdings, LLC-Vice President Solar Holdings SeiiCo, LLC-Vice President Sombra Solar GP, LLC-Vice President Sombra Solar GP, ULC-Vice President Sombra Solar, ULC-Vice President Somerset Wind power LLC-Vice President 451-34 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Cutler (continued) South Texas Gen-Tie Holding, LLC-Vice President South Texas Gen-Tie, LLC-Vice President South Texas Wind Energy, LLC-Vice President South Texas Wind Holdings, LLC-Vice President Southwest Solar Holdings, LLC-Vice President St. Clair GP, LLC-Vice President St. Clair GP, ULC-Vice President St. Clair Holding, ULC-Vice President St. Clair Moore Holding LP, LLC-Vice President St. Clair Moore Holding LP, ULC-Vice President St. Clair MS Investment GP, LLC-Vice President St. Clair Sombra Holding LP, LLC-Vice President St. Clair Sombra Holding LP, ULC-Vice President Stark Wind, LLC-Vice President Steele Flats Wind Project, LLC-Vice President Story Wind, LLC-Vice President and Assistant Treasurer Stuttgart Solar, LLC-Vice President Tech Testing Solutions Holdings, LLC-Treasurer Tech Testing Solutions, LLC-Treasurer Thames Solar LP, ULC-Vice President Trenton Diocese DG Solar, LLC-Vice President Trout Lake I Solar LP, ULC-Vice President Trout Lake II Solar LP, ULC-Vice President Trout Lake Ill Solar LP, ULC-Vice President Tuscola Wind Ill, LLC-Vice President UC Solar, LLC-Vice President USG Properties Bakken I, LLC-Vice President USG Properties Granite Wash I, LLC-Vice President USG Properties Haynesville Sand I, LLC-Vice President USG Properties Mississippian Lime I, LLC-Vice President Valencia Energy Storage, LLC-Vice President Varna Wind Funding GP, LLC-Vice President Varna Wind Funding GP, ULC-Vice President Varna Wind GP, LLC-Vice President Varna Wind GP, ULC-Vice President Varna Wind Holdings GP, LLC-Vice President Varna Wind Holdings GP, ULC-Vice President Venable Solar, LLC-Vice President Victory Renewables, LLC-Vice President Watkins Glen Wind, LLC-Vice President Waymart Storage, LLC-Vice President Wessington Wind Energy Center, LLC-Vice President West Hills Wind, LLC-Vice President West Texas Wind, LLC-Vice President Western Wind Holdings, LLC-Vice President Westside Solar, LLC-Vice President White Oak B Company, LLC-Vice President and Assistant Treasurer White Oak Energy Backleverage Holding, LLC-Vice President and Assistant Treasurer White Oak Energy Funding Holding, LLC-Vice President and Assistant Treasurer White Oak Energy Funding, LLC-Vice President and Assistant Treasurer White Oak Solar, LLC-Vice President White Pine Solar, LLC-Vice President 451-35 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Plotsky {continued) FPL Energy Waymart LP, LLC-Secretary FPL Energy Wind Financing, LLC-Secretary FPL Energy Wind Funding Holdings, LLC-Secretary FPL Energy Wind Funding, LLC-Secretary FPL Energy WPP94 GP, LLC-Secretary FPL Energy WPP94 LP, LLC-Secretary FPL Energy Wyman IV LLC-Secretary FPL Energy Wyman LLC-Secretary FPL Enersys, Inc.-Assistant Secretary FPL FiberNet Holdings, LLC-Assistant Secretary FPL FiberNet, LLC-Assistant Secretary FPL Group International, Inc.-Secretary FPL Historical Museum, Inc.-Assistant Secretary FPL Holdings Inc-Assistant Secretary FPL Investments, LLC-Secretary FPL Readi-Power, LLC-Assistant Secretary FPL Tel, LLC-Secretary FPLE Forney Pipeline, LLC-Secretary FPLE Forney, LLC-Secretary FPLE Pecos Leasing GP, LLC-Secretary FPLE Pecos Leasing LP, LLC-Secretary FPLE Rhode Island State Energy GP, LLC-Secretary FPLE Rhode Island State Energy LP, LLC-Secretary FPLE Texas Wind I, LLC-Secretary FPLE Upton Leasing GP, LLC-Secretary FPLE Upton Leasing LP, LLC-Secretary Garden Wind, LLC-Secretary Gateway Energy Center Holdings, LLC-Secretary Gateway Energy Center, LLC-Secretary Generation Repair and Service, LLC-Secretary Genesis Solar Funding Holdings, LLC-Secretary Genesis Solar Funding, LLC-Secretary Genesis Solar Holdings, LLC-Secretary Genesis Solar, LLC-Secretary Georgia Longleaf Solar 1, LLC-Vice President Gexa Energy California, LLC-Secretary GEXA Energy GP, LLC-Secretary Gexa Energy Solutions, LLC-Secretary Ghost Pine Energy Storage GP, Inc.-Secretary Ghost Pine Holdings, ULC-Secretary Golden Hills Energy Storage, LLC-Secretary Golden Hills Interconnection, LLC-Secretary Golden Hills North Wind, LLC-Secretary Golden Hills Wind, LLC-Secretary Golden West Power Partners, LLC-Secretary Golden West Wind Holdings, LLC-Secretary Golden Winds Funding, LLC-Secretary Golden Winds Holdings, LLC-Secretary Golden Winds, LLC-Secretary Goshen Wind BC Holdings, ULC-Assistant Secretary Goshen Wind Funding GP, LLC-Secretary Goshen Wind Funding GP, ULC-Secretary Goshen Wind GP, LLC-Secretary Goshen Wind GP, ULC-Secretary 451-42 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Goshen Wind Holdings GP, LLC-Secretary Goshen Wind Holdings GP, ULC-Secretary Goshen Wind, ULC-Secretary GR Bage (DE), LLC-Secretary GR Bage (FL), Inc.-Secretary GR Woodford Properties, LLC-Assistant Secretary Gray County Wind Energy, LLC-Secretary Gray Sky Investments, LLC-Secretary Green Mountain Storage, LLC-Secretary Green Ridge Power LLC-Secretary Green Ridge Services LLC-Secretary Hale Wind Energy, LLC-Secretary Hardy Creek Wind GP, Inc.-Secretary Hardy Creek Wind, ULC-Secretary Hardy Creek Wind, ULC-Secretary Harper Lake Company VIII-Secretary Harper Lake Solar Funding Corporation-Secretary Hatch Solar Energy Center I LLC-Secretary Hawkeye Power Partners, LLC-Secretary HCSD Solar, LLC-Secretary HD Hatillo Solar One, LLC-Secretary Heartland Wind Funding, LLC-Secretary Heartland Wind Holding II, LLC-Secretary Heartland Wind Holding, LLC-Secretary Heartland Wind II, LLC-Secretary Heartland Wind, LLC-Secretary High Ground Investments, LLC-Secretary High Hills Wind GP, Inc.-Secretary High Majestic II Funding, LLC-Secretary High Majestic II Holdings, LLC-Secretary High Majestic II Wind Properties, LLC-Secretary High Majestic Interconnection Services, LLC-Secretary High Majestic Wind Energy Center, LLC-Secretary High Majestic Wind II, LLC-Secretary High Point Wind, LLC-Secretary High Winds, LLC-Secretary HLC IX Company-Secretary Horse Hollow Generation Tie Holdings, LLC-Secretary Horse Hollow Generation Tie, LLC-Secretary HWFII, LLC-Secretary Hyperion IX, Inc.-Secretary Hyperion VIII, Inc.-Secretary Indian Mesa Wind Farm, LLC-Secretary Inventus Holdings, LLC-Secretary Iowa Clean Energy Express, LLC-Secretary Island Park Energy Center, LLC-Secretary Jacumba Solar, LLC-Secretary Jamaica Bay Peaking Facility, LLC-Secretary Javelina Interconnection, LLC-Secretary Javelina Wind Class B, LLC-Secretary Javelina Wind Energy Holdings, LLC-Secretary Javelina Wind Energy, LLC-Secretary Javelina Wind Funding Holdings, LLC-Secretary Javelina Wind Funding, LLC-Secretary 451-43 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Plotsky (continued) Javelina Wind Holdings II, LLC-Secretary Jericho Wind BC Holdings, ULC-Assistant Secretary Jericho Wind Funding GP, LLC-Secretary Jericho Wind Funding GP, ULC-Secretary Jericho Wind GP, LLC-Secretary Jericho Wind GP, ULC-Secretary Jericho Wind Holdings GP, LLC-Secretary Jericho Wind Holdings GP, ULC-Secretary Jericho Wind, ULC-Secretary Joshua Tree Solar Farm, LLC-Secretary Ka La Nui Solar, LLC-Secretary Kerwood Wind BC Holdings, ULC-Assistant Secretary Kerwood Wind Funding GP, LLC-Secretary Kerwood Wind Funding GP, ULC-Secretary Kerwood Wind GP, LLC-Secretary Kerwood Wind GP, ULC-Secretary Kerwood Wind Holdings GP, LLC-Secretary Kerwood Wind Holdings GP, ULC-Secretary Kerwood Wind, ULC-Secretary Kingman Wind Energy I, LLC-Secretary Kingman Wind Energy II, LLC-Secretary Kingman Wind Holding I, LLC-Secretary Kingman Wind Holding II, LLC-Secretary KPB Financial Corp.-Assistant Secretary Kramer Junction Solar Funding, LLC-Secretary KW San Gorgonio Transmission, Inc.-Secretary La Frontera Generation, LLC-Secretary La Frontera Holdings, LLC-Secretary La Frontera Ventures, LLC-Secretary La Palma DG Solar, LLC-Secretary La Salle County Gas Producing, LLC-Secretary Lake Benton Power Partners II, LLC-Secretary Lakeco Holding, LLC-Secretary Lamar Power Partners II, LLC-Secretary Lamar Power Partners, LLC-Secretary Langdon Wind, LLC-Secretary LCSD Solar 1, LLC-Secretary LCSD Solar 2, LLC-Secretary Lee North, LLC-Secretary Legacy Renewables Holdings, LLC-Secretary Legacy Renewables, LLC-Secretary Legends Wind Class B, LLC-Secretary Legends Wind Funding, LLC-Secretary Legends Wind Holdings, LLC-Secretary Legends Wind, LLC-Secretary LET Holdings, LLC-Secretary Ll Energy Storage System, LLC-Secretary Ll Solar Generation, LLC-Secretary Limon Wind II, LLC-Secretary Limon Wind Ill Funding, LLC-Secretary Limon Wind Ill Holdings, LLC-Secretary Limon Wind Ill, LLC-Secretary Limon Wind, LLC-Secretary 451-44 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Plotsky (continued) Live Oak Solar, LLC-Secretary Logan Connect LLC-Secretary Logan Energy Holdings, LLC-Secretary Logan Wind Energy LLC-Secretary Lone Star Transmission Capital, LLC-Secretary Lone Star Transmission Holdings, LLC-Secretary Lone Star Transmission, LLC-Assistant Secretary Lone Star Wind Holdings, LLC-Secretary Lone Star Wind, LLC-Secretary Long Island Energy Generation, LLC-Secretary Long Island Energy Storage Holdings, LLC-Secretary Long Island Peaker Holdings, LLC-Secretary Long Island Solar Holdings, LLC-Secretary Lucerne Solar, LLC-Secretary M Boulevard Solar, LLC-Secretary M Cross County Solar, LLC-Secretary M Greece Ridge Solar, LLC-Secretary M Nanuet Solar, LLC-Secretary M Queens Rego Solar, LLC-Secretary M Schenectady Solar, LLC-Secretary M White Plains Solar, LLC-Secretary Mammoth Plains Wind Project Holdings, LLC-Secretary Mammoth Plains Wind Project, LLC-Secretary Mantua Creek Solar, LLC-Secretary Marshall Solar, LLC-Secretary McCoy Solar Funding, LLC-Secretary McCoy Solar Holdings, LLC-Secretary McCoy Solar, LLC-Secretary Meadowlark Wind Holdings, LLC-Secretary Meadowlark Wind, LLC-Secretary Meyersdale Storage, LLC-Secretary Meyersdale Windpower, LLC-Secretary Mill Run Windpower LLC-Secretary Minco Redwood Holdings, LLC-Secretary Minco Wind II, LLC-Secretary Minco Wind Ill, LLC-Secretary Minco Wind Interconnection Services, LLC-Secretary Minco Wind IV, LLC-Secretary Minco Wind, LLC-Secretary Minudie Wind GP, Inc.-Secretary Moca Solar Farm, LLC-Secretary Mojave Holdings, LLC-Secretary Mojave Red Venturez, LLC-Secretary Moore Solar GP, LLC-Secretary Moore Solar GP, ULC-Secretary Moore Solar, ULC-Secretary Moose Wind, LLC-Secretary Morongo DG Solar, LLC-Secretary Mount Copper GP, Inc.-Secretary Mount Miller GP, ULC-Secretary Mount Miller Holdco, LLC-Secretary 451-45 ---~-~~ -----~ Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Plotsky (continued) Mount Miller Holdco, ULC-Secretary Mount Miller Holdings GP, LLC-Secretary Mount Miller Holdings GP, ULC-Secretary Mountain Prairie Wind Holdings, LLC-Secretary Mountain Prairie Wind, LLC-Secretary Mountain View Solar Holdings, LLC-Secretary Mountain View Solar, LLC-Secretary Mt. Storm Wind Force Holdings, LLC-Secretary Mt. Storm Wind Force, LLC-Secretary NAPS Wind, LLC-Secretary NEE Acquisition Sub I, LLC-Assistant Secretary NEE Acquisition Sub II, Inc.-Assistant Secretary NEP US SeiiCo, LLC-Secretary NEPM II Holdings, LLC-Secretary NEPM II, LLC-Secretary New Hampshire Transmission, LLC-Secretary New Mexico Energy Investments, LLC-Secretary New Mexico Wind Investments, LLC-Secretary NextEra Blythe Solar Energy Center, LLC-Secretary NextEra Canada Development & Acquisitions, Inc.-Secretary NextEra Canada Transmission Investments, Inc.-Secretary NextEra Canadian IP, Inc.-Secretary NextEra Desert Center Blythe, LLC-Secretary NextEra Desert Sunlight Holdings, LLC-Secretary NextEra Energy Bluff Point, LLC-Secretary NextEra Energy Canada Equipment, Inc.-Secretary NextEra Energy Canada GP, LLC-Assistant Secretary NextEra Energy Canadian Holdings, ULC-Secretary NextEra Energy Canadian Operating Services, Inc.-Secretary NextEra Energy Capital Holdings, Inc.-Assistant Secretary NextEra Energy DG Operations, LLC-Secretary NextEra Energy Duane Arnold, LLC-Secretary NextEra Energy Equipment Leasing, LLC-Assistant Secretary NextEra Energy Equity Partners GP, LLC-Secretary NextEra Energy Foundation, Inc.-Assistant Secretary NextEra Energy Gas Producing Wyoming, LLC-Secretary NextEra Energy Gas Producing, LLC-Secretary NextEra Energy Hawaii Land Holdings, LLC-Secretary NextEra Energy Hawaii, LLC-Secretary NextEra Energy Honey Creek Wind, LLC-Secretary NextEra Energy Infrastructure, LLC-Secretary NextEra Energy Maine Operating Services, LLC-Secretary NextEra Energy Maine, LLC-Secretary NextEra Energy Management Partners GP, LLC-Secretary NextEra Energy Montezuma II Wind, LLC-Secretary NextEra Energy Mt. Storm, LLC-Secretary NextEra Energy New Mexico Operating Services, LLC-Secretary NextEra Energy NextBridge Holding, ULC-Secretary NextEra Energy NextBridge Holdings GP, LLC-Secretary NextEra Energy NextBridge Holdings GP, ULC-Secretary NextEra Energy Operating Partners GP, LLC-Secretary 451-46 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Plotsky (continued) NextEra Energy Operating Services, LLC-Secretary NextEra Energy Partners Acquisitions, LLC-Secretary NextEra Energy Partners GP, Inc.-Assistant Secretary NextEra Energy Partners Solar Acquisitions, LLC-Secretary NextEra Energy Partners Ventures, LLC-Secretary NextEra Energy Pipeline Development and Acquisitions, LLC-Secretary NextEra Energy Pipeline Holdings, LLC-Assistant Secretary NextEra Energy Pipeline Services, LLC-Secretary NextEra Energy Point Beach, LLC-Secretary NextEra Energy Producer Services, LLC-Secretary NextEra Energy Project Management, LLC-Secretary NextEra Energy Resources Acquisitions, LLC-Secretary NextEra Energy Resources Partners Holdings, LLC-Secretary NextEra Energy Resources Partners, LLC-Secretary NextEra Energy Resources, LLC-Assistant Secretary NextEra Energy Sabal Trail Transmission Holdings, LLC-Secretary NextEra Energy Seabrook, LLC-Secretary NextEra Energy Services Arizona, LLC-Secretary NextEra Energy Services Connecticut, LLC-Secretary NextEra Energy Services Delaware, LLC-Secretary NextEra Energy Services District of Columbia, LLC-Secretary NextEra Energy Services Holdings, LLC-Secretary NextEra Energy Services Illinois, LLC-Secretary NextEra Energy Services Maine, LLC-Secretary NextEra Energy Services Maryland, LLC-Secretary NextEra Energy Services Massachusetts, LLC-Secretary NextEra Energy Services New Hampshire, LLC-Secretary NextEra Energy Services New Jersey, LLC-Secretary NextEra Energy Services New York, LLC-Secretary NextEra Energy Services Ohio, LLC-Secretary NextEra Energy Services Pennsylvania, LLC-Secretary NextEra Energy Services Rhode Island, LLC-Secretary NextEra Energy Services, LLC-Secretary NextEra Energy Solar Holdings, LLC-Secretary NextEra Energy Solutions, LLC-Secretary NextEra Energy Transmission Investments, LLC-Secretary NextEra Energy Transmission Mid-Atlantic, LLC-Secretary NextEra Energy Transmission Midwest, LLC-Secretary NextEra Energy Transmission New York, Inc.-Secretary NextEra Energy Transmission Southwest, LLC-Secretary NextEra Energy Transmission West, LLC-Secretary NextEra Energy Transmission, LLC-Secretary NextEra Energy UCT Holding, Inc.-Secretary NextEra Energy US Partners Holdings, LLC-Secretary NextEra Energy Victory Solar I, LLC-Secretary NextEra Fibernet, LLC-Secretary NextEra Maine Fossil, LLC-Secretary NextEra Retail of Texas GP, LLC-Secretary NextEra Solar DG Fund I, LLC-Secretary NextEra Texas Acquisition Holdco, LLC-Secretary NextEra Texas Acquisition LP, LLC-Secretary NextEra Transmission Asset Acquisition Holdings, LLC-Secretary NextEra US Gas Assets, LLC-Secretary 451-47 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Plotsky (continued) NG Pipeline of America, LLC-Secretary NG Storage of America, LLC-Secretary Ninnescah Wind Energy LLC-Secretary Niyol Wind, LLC-Secretary North American Power Systems Solar, LLC-Secretary North American Power Systems, LLC-Secretary North Coast Solar, LLC-Secretary North Sky River Energy Holdings, LLC-Secretary North Sky River Energy, LLC-Secretary North Sky River Land Holdings, LLC-Secretary Northern Colorado Wind Energy, LLC-Assistant Secretary Northern Colorado Wind Holdings, LLC-Secretary Northern Frontier Wind Funding, LLC-Secretary Northern Frontier Wind Holding, LLC-Secretary Northern Frontier Wind, LLC-Secretary Northpoint I Wind GP, Inc.-Secretary Northpoint II Wind GP, Inc.-Secretary Novus Wind VI, LLC-Secretary NWE Holding, LLC-Secretary NY Sun DG Solar, LLC-Secretary NY Sun Zone C2 LLC-Secretary NY Sun Zone C3 LLC-Secretary NY Sun Zone E1 LLC-Secretary NY Sun Zone E2 LLC-Secretary NY Sun Zone E3 LLC-Secretary NY Sun Zone E4 LLC-Secretary NY Sun Zone F1 LLC-Secretary NY Sun Zone F2 LLC-Secretary NY Sun Zone F3 LLC-Secretary NY Sun Zone F4 LLC-Secretary Oklahoma Wind Portfolio, LLC-Secretary Old Mill Holdings, LLC-Secretary Old Mill Solar, LLC-Secretary Oliver Wind Ill, LLC-Secretary Oneida DG Solar, LLC-Secretary Osborn Wind Energy, LLC-Secretary Osceola Windpower II, LLC-Secretary Osceola Windpower, LLC-Secretary OTG, LLC-Secretary Pacific Energy Solutions, LLC-Secretary Palo Duro Wind Energy II, LLC-Secretary Palo Duro Wind Energy, LLC-Secretary Palo Duro Wind Holdings SeiiCo, LLC-Secretary Palo Duro Wind Interconnection Services, LLC-Secretary Palo Duro Wind Portfolio, LLC-Secretary Palo Duro Wind Project Holdings, LLC-Secretary Paradise Solar Urban Renewal, L.L.C.-Secretary Parry Energy Storage GP, LLC-Secretary Parry Energy Storage GP, ULC-Secretary Peace Garden Wind Funding, LLC-Secretary Peace Garden Wind Holdings, LLC-Secretary Peace Garden Wind, LLC-Secretary 451-48 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Plotsky (continued) Peetz Energy, LLC-Secretary Peetz Logan Interconnect, LLC-Secretary Peetz Table Transmission Line, LLC-Secretary Peetz Table Wind Energy, LLC-Secretary Pennsylvania Windfarms, LLC-Secretary Penobscot Wind, LLC-Secretary Penta Wind Holding, LLC-Secretary Penta Wind, LLC-Secretary Perrin Ranch Wind, LLC-Secretary Pheasant Run Wind Holdings II, LLC-Secretary Pheasant Run Wind Holdings, LLC-Secretary Pheasant Run Wind, LLC-Secretary Pima Energy Storage System, LLC-Secretary Pioneer Plains Wind Funding, LLC-Secretary Pioneer Plains Wind Holdings, LLC-Secretary Pioneer Plains Wind, LLC-Secretary Pipeline Funding Company, LLC-Secretary Porta del Sol Solar, LLC-Secretary Prairie View Wind Holdings, LLC-Secretary Pubnico Point GP, Inc.-Secretary Pubnico Point Wind Farm Inc.-Secretary PWEC, LLC-Secretary Red Mesa Wind Investments, LLC-Secretary Red Mesa Wind, LLC-Secretary Red Raider Wind Holdings, LLC-Secretary Red Raider Wind, LLC-Secretary Red River Wind Funding, LLC-Secretary Red River Wind Holdings, LLC-Secretary Red River Wind, LLC-Secretary Redwood Trails Wind Holdings, LLC-Secretary Redwood Trails Wind, LLC-Secretary RGS Realty Holdings, LLC-Secretary RGS Realty, LLC-Secretary River Bend Solar, LLC-Secretary Roswell Solar Holdings, LLC-Secretary Roswell Solar, LLC-Secretary Rush Springs Wind Energy, LLC-Secretary Sagebrush Partner Fifteen, Inc.-Secretary San Jacinto Solar 14.5, LLC-Secretary San Jacinto Solar 5.5, LLC-Secretary SCI Holding, ULC-Secretary SCIH GP, ULC-Secretary SDGF 1 Funding, LLC-Secretary SEC Amherst Solar One, LLC~Secretary SEC CRSD Solar One, LLC-Secretary SEC ESSD Solar One, LLC-Secretary SEC HSD Solar One, LLC-Secretary SEC LHNY Solar One, LLC-Secretary SEC MC Solar One, LLC-Secretary SEC Northeast Solar One, LLC-Secretary SEC PASO Solar One, LLC-Secretary SEC SUSD Solar One, LLC-Secretary 451-49 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Plotsky (continued) Seiling Wind Holdings, LLC-Secretary Seiling Wind II, LLC-Secretary Seiling Wind Interconnection Services, LLC-Secretary Seiling Wind Portfolio, LLC-Secretary Seiling Wind, LLC-Secretary Sentry Solar, LLC-Secretary Shafter Solar Holdings, LLC-Secretary Shafter Solar SeiiCo, LLC-Secretary Shafter Solar, LLC-Secretary Silver State Solar Power South, LLC-Secretary Silver State South Solar, LLC-Secretary Sirius Solar, LLC-Secretary Sky River Asset Holdings, LLC-Secretary Sky River LLC-Secretary Smart Energy Capital, LLC-Secretary Solar DG Fund 1 Holdings, LLC-Secretary Solar Holdings SeiiCo, LLC-Secretary Sombra Solar GP, LLC-Secretary Sombra Solar GP, ULC-Secretary Sombra Solar, ULC-Secretary Somerset Wind power LLC-Secretary Sonoran Solar Energy I, LLC-Secretary Sonoran Solar Energy, LLC-Secretary Sooner Trails Pipeline, LLC-Secretary South Texas Gen-Tie Holding, LLC-Secretary South Texas Gen-Tie, LLC-Secretary South Texas Wind Energy, LLC-Secretary South Texas Wind Holdings, LLC-Secretary Southwest Solar Holdings, LLC-Secretary St. Clair GP, LLC-Secretary St. Clair GP, ULC-Secretary St. Clair Holding, ULC-Secretary St. Clair Moore Holding LP, LLC-Secretary St. Clair Moore Holding LP, ULC-Secretary St. Clair MS Investment GP, LLC-Secretary St. Clair Sombra Holding LP, LLC-Secretary St. Clair Sombra Holding LP, ULC-Secretary Stark Wind, LLC-Secretary Steele Flats Wind Project, LLC-Secretary Story Wind, LLC-Secretary Strathroy Wind GP, Inc.-Secretary Stuttgart Solar, LLC-Secretary Tech Testing Solutions Holdings, LLC-Secretary Tech Testing Solutions, LLC-Secretary Thames Solar GP, Inc.-Secretary Tower Associates Canada, Inc.-Secretary Tower Associates, LLC-Secretary Trenton Diocese DG Solar, LLC-Secretary Trillium Funding GP Holding, Inc.-Secretary Trillium Funding GP, Inc.-Secretary Trillium HoldCo GP, Inc.-Secretary 451-50 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Plotsky (continued) Trout Lake I Solar GP, Inc.-Secretary Trout Lake II Solar GP, Inc.-Secretary Trout Lake Ill Solar GP, Inc.-Secretary Tuscola Bay Wind, LLC-Secretary Tuscola Wind II, LLC-Secretary Tuscola Wind Ill, LLC-Secretary U. S. Windpower Transmission Corporation-Secretary UC Solar, LLC-Secretary Upper Canada Transmission, Inc.-Secretary US Marcellus Gas Infrastructure, LLC-Secretary US Sooner Trails G~s Infrastructure, LLC-Secretary US Southeastern Gas Infrastructure, LLC-Secretary USG Energy Gas Investment, LLC-Secretary USG Energy Gas Producer Holdings, LLC-Secretary USG Midstream Bakken I, LLC-Secretary USG Midstream Haynesville Sands I, LLC-Secretary USG Midstream Holdings, LLC-Secretary USG Midstream Mississippian Lime I, LLC-Secretary USG Properties Austin Chalk Holdings, LLC-Secretary USG Properties Austin Chalk I, LLC-Secretary USG Properties Bakken Holdings, LLC-Secretary USG Properties Bakken I, LLC-Secretary USG Properties Bakken II, LLC-Secretary USG Properties Barnett Holdings, LLC-Secretary USG Properties Barnett II, LLC-Secretary USG Properties Eagle Ford Holdings, LLC-Secretary USG Properties Eagle Ford Ill, LLC-Secretary USG Properties Eagle Ford IV, LLC-Secretary USG Properties Granite Wash Holdings, LLC-Secretary USG Properties Granite Wash I, LLC-Secretary USG Properties Haynesville Sand I, LLC-Secretary USG Properties Haynesville Sands Holdings, LLC-Secretary USG Properties Jackfork Holdings, LLC-Secretary USG Properties Jackfork I, LLC-Secretary USG Properties Marcellus Holdings, LLC-Secretary USG Properties Mississippian Lime Holdings, LLC-Secretary USG Properties Mississippian Lime I, LLC-Secretary USG Properties Mississippian Lime II, LLC-Secretary USG Properties Niobrara Holdings, LLC-Secretary USG Properties Permian Basin Holdings, LLC-Secretary USG Properties Permian Basin I, LLC-Secretary USG Properties Permian Basin II, LLC-Secretary USG Properties Wilcox Holdings, LLC-Secretary USG Properties Wilcox I, LLC-Secretary USG Properties Woodford Holdings, LLC-Secretary USG Properties Woodford I, LLC-Secretary USG Properties Woodford II, LLC-Secretary USG Surface Facilities Holdings, LLC-Secretary USG Surface Facilities I, LLC-Secretary USG Surface Facilities II, LLC-Secretary USG Surface Facilities Mississippian Lime I, LLC-Secretary USG Technology Holdings, LLC-Secretary 451-51 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Plotsky (continued) USG West Relay, LLC-Secretary USG Wheatland Pipeline, LLC-Secretary USW Land Corporation-Secretary Valencia Energy Storage, LLC-Secretary Vansycle Ill Wind, LLC-Secretary Varna Wind Funding GP, LLC-Secretary Varna Wind Funding GP, ULC-Secretary Varna Wind GP, LLC-Secretary Varna Wind GP, ULC-Secretary Varna Wind Holdings GP, LLC-Secretary Varna Wind Holdings GP, ULC-Secretary Varna Wind, ULC-Secretary Vasco Winds, LLC-Secretary Venable Solar, LLC-Secretary Victory Renewables, LLC-Secretary Watkins Glen Wind, LLC-Secretary Watonga Wind, LLC-Secretary Waymart Storage, LLC-Secretary Wessington Wind Energy Center, LLC-Secretary West Hills Wind, LLC-Secretary West Texas Wind, LLC-Secretary Western Wind Holdings, LLC-Secretary Westside Solar, LLC-Secretary White Oak B Company, LLC-Secretary White Oak Energy Backleverage Holding, LLC-Secretary White Oak Energy Funding Holding, LLC-Secretary White Oak Energy Funding, LLC-Secretary White Oak Energy Holdings, LLC-Secretary White Oak Energy LLC-Secretary White Oak Solar, LLC-Secretary White Pine Solar, LLC-Secretary Whitewater Wind, LLC-Secretary Whitney Point Solar, LLC-Secretary Wild Prairie Wind Holdings, LLC-Secretary Wild Prairie Wind, LLC-Secretary Wilton Wind II, LLC-Secretary Wilton Wind IV, LLC-Secretary Wind Holdings, Inc.-Secretary WindCo LLC-Secretary Windlogics Inc.-Secretary Windpower Partners 1993, LLC-Secretary Wolf Ridge Wind, LLC-Secretary WSGP Gas Producing, LLC-Secretary Wyman Cape Holdings, LLC-Secretary Zuni Solar, LLC-Secretary Portales, Aldo -Assistant Treasurer NextEra Energy, Inc.-Assistant Treasurer Adelanto Solar Funding, LLC-Assistant Treasurer Adelanto Solar Holdings, LLC-Assistant Treasurer Aries Solar Holding, LLC-Assistant Treasurer 451-52 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Portales (continued) Ashtabula Wind II, LLC-Assistant Treasurer Ashtabula Wind Ill, LLC-Assistant Treasurer Ashtabula Wind, LLC-Assistant Treasurer Backbone Mountain Windpower LLC-Assistant Treasurer Backbone Windpower Holdings, LLC-Assistant Treasurer Baldwin Wind Holdings, LLC-Assistant Treasurer Baldwin Wind, LLC-Assistant Treasurer Bayhawk Wind Funding, LLC-Assistant Treasurer Bayhawk Wind Holdings, LLC-Assistant Treasurer Bayhawk Wind SeiiCo, LLC-Assistant Treasurer Bayhawk Wind, LLC-Assistant Treasurer Bison Wind GP, LLC-Assistant Treasurer Bison Wind Holdings, LLC-Assistant Treasurer Bison Wind Investments, LLC-Assistant Treasurer Bison Wind LP, LLC-Assistant Treasurer Bison Wind Portfolio, LLC-Assistant Treasurer Bison Wind, LLC-Assistant Treasurer Blackwell Wind, LLC-Assistant Treasurer Blue Summit Wind, LLC-Assistant Treasurer Bornish Wind BC Holdings, ULC-Assistant Treasurer Bornish Wind Funding GP, LLC-Assistant Treasurer Bornish Wind GP, LLC-Assistant Treasurer Bornish Wind Holdings GP, LLC-Assistant Treasurer Bornish Wind LP, ULC-Assistant Treasurer Breckinridge Wind Class A Holdings, LLC-Assistant Treasurer Breckinridge Wind Funding, LLC-Assistant Treasurer Breckinridge Wind Holdings, LLC-Assistant Treasurer Breckinridge Wind Project, LLC-Assistant Treasurer Butler Ridge Wind Energy Center, LLC-Assistant Treasurer Canyon Wind Holdings, LLC-Assistant Treasurer Canyon Wind, LLC-Assistant Treasurer Capricorn Ridge B Holdings, LLC-Assistant Treasurer Capricorn Ridge B, LLC-Assistant Treasurer Capricorn Ridge Power Seller, LLC-Assistant Treasurer Capricorn Ridge Wind Funding, LLC-Assistant Treasurer Capricorn Ridge Wind Holdings, LLC-Assistant Treasurer Capricorn Ridge Wind II, LLC-Assistant Treasurer Capricorn Ridge Wind, LLC-Assistant Treasurer Carousel Wind Farm, LLC-Assistant Treasurer Carousel Wind Holdings, LLC-Assistant Treasurer Cedar Bay Cogeneration, LLC-Assistant Treasurer Cedar Bay Holdings, LLC-Assistant Treasurer Cedar Bluff Wind, LLC-Assistant Treasurer Cedar II Power, LLC-Assistant Treasurer Centennial Wind Class B, LLC-Assistant Treasurer Centennial Wind Funding, LLC-Assistant Treasurer Centennial Wind Holdings, LLC-Assistant Treasurer Centennial Wind, LLC-Assistant Treasurer Central States Wind Holdings, LLC-Assistant Treasurer Central States Wind, LLC-Assistant Treasurer Cimarron Wind Energy Holdings II, LLC-Assistant Treasurer 451-53 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Portales (continued) Cimarron Wind Energy Holdings, LLC-Assistant Treasurer Cimarron Wind Energy, LLC-Assistant Treasurer Common Unit Holdings, LLC-Assistant Treasurer CP II CAD Holdings LP GP, LLC-Assistant Treasurer Crystal Lake Wind II, LLC-Assistant Treasurer Crystal Lake Wind Ill, LLC-Assistant Treasurer Crystal Lake Wind, LLC-Assistant Treasurer Day County Wind, LLC-Assistant Treasurer Desert Sunlight 250, LLC-Assistant Treasurer Desert Sunlight 300, LLC-Assistant Treasurer Desert Sunlight Holdings, LLC-Assistant Treasurer Diablo Winds, LLC-Assistant Treasurer East Durham Wind BC Holdings, ULC-Assistant Treasurer East Durham Wind Funding GP, LLC-Assistant Treasurer East Durham Wind GP, LLC-Assistant Treasurer East Durham Wind Holdings GP, LLC-Assistant Treasurer EFH Merger Co., LLC-Assistant Treasurer Elk City II Wind Holdings, LLC-Assistant Treasurer Elk City II Wind, LLC-Assistant Treasurer Elk City Wind Holdings Ill, LLC-Assistant Treasurer Elk City Wind Holdings, LLC-Assistant Treasurer Elk City Wind Ill, LLC-Assistant Treasurer Elk City Wind, LLC-Assistant Treasurer Elmira Energy Storage GP, LLC-Assistant Treasurer Ensign Wind, LLC-Assistant Treasurer ESI Vansycle GP, Inc.-Assistant Treasurer ESI Vansycle LP, Inc.-Assistant Treasurer ESI West Texas Energy LP, LLC-Assistant Treasurer ESI West Texas Energy, Inc.-Assistant Treasurer Fortuna GP, LLC-Assistant Treasurer FPL Energy American Wind Holdings, LLC-Assistant Treasurer FPL Energy American Wind, LLC-Assistant Treasurer FPL Energy Burleigh County Wind, LLC-Assistant Treasurer FPL Energy Cabazon Wind, LLC-Assistant Treasurer FPL Energy Callahan Wind GP, LLC-Assistant Treasurer FPL Energy Callahan Wind LP, LLC-Assistant Treasurer FPL Energy Cowboy Wind, LLC-Assistant Treasurer FPL Energy Hancock County Wind, LLC-Assistant Treasurer FPL Energy Horse Hollow Wind II, LLC-Assistant Treasurer FPL Energy Horse Hollow Wind, LLC-Assistant Treasurer FPL Energy Marcus Hook LLC-Assistant Treasurer FPL Energy MH700, LLC-Assistant Treasurer FPL Energy Montezuma Wind, LLC-Assistant Treasurer FPL Energy Morwind, LLC-Assistant Treasurer FPL Energy Mower County, LLC-Assistant Treasurer FPL Energy National Wind Holdings, LLC-Assistant Treasurer FPL Energy National Wind Investments, LLC-Assistant Treasurer FPL Energy National Wind Portfolio, LLC-Assistant Treasurer FPL Energy National Wind, LLC-Assistant Treasurer FPL Energy New Mexico Holdings, LLC-Assistant Treasurer FPL Energy New Mexico Wind Financing, LLC-Assistant Treasurer FPL Energy New Mexico Wind Holdings II, LLC-Assistant Treasurer 451-54 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Portales (continued) FPL Energy New Mexico Wind II, LLC-Assistant Treasurer FPL Energy New Mexico Wind, LLC-Assistant Treasurer FPL Energy North Dakota Wind II, LLC-Assistant Treasurer FPL Energy North Dakota Wind, LLC-Assistant Treasurer FPL Energy Oklahoma Wind Finance, LLC-Assistant Treasurer FPL Energy Oklahoma Wind, LLC-Assistant Treasurer FPL Energy Oliver Wind I, LLC-Assistant Treasurer FPL Energy Oliver Wind II, LLC-Assistant Treasurer FPL Energy Post Wind GP, LLC-Assistant Treasurer FPL Energy Post Wind LP, LLC-Assistant Treasurer FPL Energy Rockaway Peaking Facilities, LLC-Assistant Treasurer FPL Energy SEGS Ill-VII GP, LLC-Assistant Treasurer FPL Energy SEGS Ill-VII LP, LLC-Assistant Treasurer FPL Energy Sooner Wind, LLC-Assistant Treasurer FPL Energy South Dakota Wind, LLC-Assistant Treasurer FPL Energy Stateline Holdings, L.L.C.-Assistant Treasurer FPL Energy Texas Wind GP, LLC-Assistant Treasurer FPL Energy Texas, LLC-Assistant Treasurer FPL Energy Upton Wind I, LLC-Assistant Treasurer FPL Energy Upton Wind II, LLC-Assistant Treasurer FPL Energy Upton Wind Ill, LLC-Assistant Treasurer FPL Energy Upton Wind IV, LLC-Assistant Treasurer FPL Energy Vansycle L.L.C.-Assistant Treasurer FPL Energy Waymart GP, LLC-Assistant Treasurer FPL Energy Waymart LP, LLC-Assistant Treasurer FPL Energy Wind Financing, LLC-Assistant Treasurer FPL Energy Wind Funding Holdings, LLC-Assistant Treasurer FPL Energy Wind Funding, LLC-Assistant Treasurer FPL FiberNet Holdings, LLC-Assistant Treasurer FPL FiberNet, LLC-Assistant Treasurer FPLE Forney Pipeline, LLC-Assistant Treasurer FPLE Forney, LLC-Assistant Treasurer Garden Wind, LLC-Assistant Treasurer Genesis Solar Funding Holdings, LLC-Assistant Treasurer Genesis Solar Funding, LLC-Assistant Treasurer Genesis Solar Holdings, LLC-Assistant Treasurer Genesis Solar, LLC-Assistant Treasurer Golden Hills Interconnection, LLC-Assistant Treasurer Golden Hills Wind, LLC-Assistant Treasurer Golden West Power Partners, LLC-Assistant Treasurer Golden West Wind Holdings, LLC-Assistant Treasurer Golden Winds Funding, LLC-Assistant Treasurer Golden Winds Holdings, LLC-Assistant Treasurer Golden Winds, LLC-Assistant Treasurer Goshen Wind BC Holdings, ULC-Assistant Treasurer Goshen Wind Funding GP, LLC-Assistant Treasurer Goshen Wind GP, LLC-Assistant Treasurer Goshen Wind Holdings GP, LLC-Assistant Treasurer Hawkeye Power Partners, LLC-Assistant Treasurer Heartland Wind Funding, LLC-Assistant Treasurer Heartland Wind Holding II, LLC-Assistant Treasurer Heartland Wind Holding, LLC-Assistant Treasurer 451-55 -------------- ---- - -------------------------- Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Portales (continued) Heartland Wind II, LLC-Assistant Treasurer Heartland Wind, LLC-Assistant Treasurer High Majestic II Funding, LLC-Assistant Treasurer High Majestic II Holdings, LLC-Assistant Treasurer High Majestic II Wind Properties, LLC-Assistant Treasurer High Majestic Interconnection Services, LLC-Assistant Treasurer High Majestic Wind Energy Center, LLC-Assistant Treasurer High Majestic Wind II, LLC-Assistant Treasurer High Winds, LLC-Assistant Treasurer HWFII, LLC-Assistant Treasurer Javelina Interconnection, LLC-Assistant Treasurer Javelina Wind Class B, LLC-Assistant Treasurer Javelina Wind Energy Holdings, LLC-Assistant Treasurer Javelina Wind Energy, LLC-Assistant Treasurer Javelina Wind Funding Holdings, LLC-Assistant Treasurer Javelina Wind Funding, LLC-Assistant Treasurer Jericho Wind BC Holdings, ULC-Assistant Treasurer Jericho Wind Funding GP, LLC-Assistant Treasurer Jericho Wind GP, LLC-Assistant Treasurer Jericho Wind Holdings GP, LLC-Assistant Treasurer Kerwood Wind BC Holdings, ULC-Assistant Treasurer Kerwood Wind Funding GP, LLC-Assistant Treasurer Kerwood Wind GP, LLC-Assistant Treasurer Kerwood Wind Holdings GP, LLC-Assistant Treasurer La Frontera Generation, LLC-Assistant Treasurer La Frontera Holdings, LLC-Assistant Treasurer Lake Benton Power Partners II, LLC-Assistant Treasurer Lamar Power Partners, LLC-Assistant Treasurer Langdon Wind, LLC-Assistant Treasurer Legacy Renewables Holdings, LLC-Assistant Treasurer Legacy Renewables, LLC-Assistant Treasurer Legends Wind Class B, LLC-Assistant Treasurer Legends Wind Funding, LLC-Assistant Treasurer Legends Wind Holdings, LLC-Assistant Treasurer Legends Wind, LLC-Assistant Treasurer Limon Wind II, LLC-Assistant Treasurer Limon Wind Ill Funding, LLC-Assistant Treasurer Limon Wind Ill Holdings, LLC-Assistant Treasurer Limon Wind Ill, LLC-Assistant Treasurer Limon Wind, LLC-Assistant Treasurer Logan Connect LLC-Assistant Treasurer Logan Energy Holdings, LLC-Assistant Treasurer Logan Wind Energy LLC-Assistant Treasurer Lone Star Transmission Capital, LLC-Vice President and Assistant Treasurer Lone Star Transmission Holdings, LLC-Vice President and Assistant Treasurer Lone Star Transmission, LLC-Assistant Treasurer Lone Star Wind Holdings, LLC-Assistant Treasurer Lone Star Wind, LLC-Assistant Treasurer Mammoth Plains Wind Project Holdings, LLC-Assistant Treasurer Mammoth Plains Wind Project, LLC-Assistant Treasurer McCoy Solar Funding, LLC-Assistant Treasurer McCoy Solar Holdings, LLC-Assistant Treasurer 451-56 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Portales (continued) McCoy Solar, LLC-Assistant Treasurer Meadowlark Wind Holdings, LLC-Assistant Treasurer Meadowlark Wind, LLC-Assistant Treasurer Meyersdale Windpower, LLC-Assistant Treasurer Mill Run Windpower LLC-Assistant Treasurer Minco Redwood Holdings, LLC-Assistant Treasurer Minco Wind II, LLC-Assistant Treasurer Minco Wind Ill, LLC-Assistant Treasurer Minco Wind Interconnection Services, LLC-Assistant Treasurer Minco Wind, LLC-Assistant Treasurer Moore Solar GP, LLC-Assistant Treasurer Moore Solar GP, ULC-Assistant Treasurer Mount Miller Holdco, LLC-Assistant Treasurer Mount Miller Holdings GP, LLC-Assistant Treasurer Mountain Prairie Wind Holdings, LLC-Assistant Treasurer Mountain Prairie Wind, LLC-Assistant Treasurer Mountain View Solar Holdings, LLC-Assistant Treasurer Mountain View Solar, LLC-Assistant Treasurer NEP US SeiiCo, LLC-Assistant Treasurer NET General Partners, LLC-Assistant Treasurer NET Holdings Management, LLC-Assistant Treasurer NET Midstream, LLC-Assistant Treasurer NET Pipeline Holdings LLC-Assistant Treasurer NextEra Desert Center Blythe, LLC-Assistant Treasurer NextEra Energy Canada GP, LLC-Assistant Treasurer NextEra Energy Canada Partners Holdings, ULC-Assistant Treasurer NextEra Energy Canadian Holdings, ULC-Assistant Treasurer NextEra Energy Capital Holdings, Inc.-Assistant Treasurer NextEra Energy Montezuma II Wind, LLC-Assistant Treasurer NextEra Energy Resources Partners, LLC-Assistant Treasurer NextEra Energy Transmission New York, Inc.-Assistant Treasurer North Sky River Energy Holdings, LLC-Assistant Treasurer North Sky River Energy, LLC-Assistant Treasurer Northern Colorado Wind Energy, LLC-Assistant Treasurer Northern Colorado Wind Holdings, LLC-Assistant Treasurer Northern Frontier Wind Funding, LLC-Assistant Treasurer Northern Frontier Wind Holding, LLC-Assistant Treasurer Northern Frontier Wind, LLC-Assistant Treasurer Oklahoma Wind Portfolio, LLC-Assistant Treasurer Palo Duro Wind Energy II, LLC-Assistant Treasurer Palo Duro Wind Energy, LLC-Assistant Treasurer Palo Duro Wind Holdings SeiiCo, LLC-Assistant Treasurer Palo Duro Wind Interconnection Services, LLC-Assistant Treasurer Palo Duro Wind Portfolio, LLC-Assistant Treasurer Palo Duro Wind Project Holdings, LLC-Assistant Treasurer Parry Energy Storage GP, LLC-Assistant Treasurer Peace Garden Wind Funding, LLC-Assistant Treasurer Peace Garden Wind Holdings, LLC-Assistant Treasurer Peace Garden Wind, LLC-Assistant Treasurer Peetz Logan Interconnect, LLC-Assistant Treasurer Peetz Table Transmission Line, LLC-Assistant Treasurer Peetz Table Wind Energy, LLC-Assistant Treasurer 451-57 ------ -------- Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Portales (continued) Pennsylvania Windfarms, LLC-Assistant Treasurer Penta Wind Holding, LLC-Assistant Treasurer Penta Wind, LLC-Assistant Treasurer Perrin Ranch Wind, LLC-Assistant Treasurer Pheasant Run Wind Holdings, LLC-Assistant Treasurer Pheasant Run Wind, LLC-Assistant Treasurer Pioneer Plains Wind Funding, LLC-Assistant Treasurer Pioneer Plains Wind Holdings, LLC-Assistant Treasurer Pioneer Plains Wind, LLC-Assistant Treasurer Pipeline Funding Company, LLC-Assistant Treasurer Red River Wind Funding, LLC-Assistant Treasurer Red River Wind Holdings, LLC-Assistant Treasurer Red River Wind, LLC-Assistant Treasurer Redwood Trails Wind Holdings, LLC-Assistant Treasurer Redwood Trails Wind, LLC-Assistant Treasurer Sagebrush Partner Fifteen, Inc.-Assistant Treasurer SCI Holding, ULC-Assistant Treasurer SCIH GP, ULC-Assistant Treasurer SDGF 1 Funding, LLC-Assistant Treasurer Seiling Wind Holdings, LLC-Assistant Treasurer Seiling Wind II, LLC-Assistant Treasurer Seiling Wind Interconnection Services, LLC-Assistant Treasurer Seiling Wind Portfolio, LLC-Assistant Treasurer Seiling Wind, LLC-Assistant Treasurer Shafter Solar Holdings, LLC-Assistant Treasurer Shafter Solar SeliGa, LLC-Assistant Treasurer Silver State Solar Power South, LLC-Assistant Treasurer Silver State South Solar, LLC-Assistant Treasurer Sky River Asset Holdings, LLC-Assistant Treasurer Sky River LLC-Assistant Treasurer Solar DG Fund 1 Holdings, LLC-Assistant Treasurer Solar Holdings SeliGa, LLC-Assistant Treasurer Sombra Solar GP, LLC-Assistant Treasurer Sombra Solar GP, ULC-Assistant Treasurer Somerset Wind power LLC-Assistant Treasurer South Texas Wind Energy, LLC-Assistant Treasurer South Texas Wind Holdings, LLC-Assistant Treasurer St. Clair GP, LLC-Assistant Treasurer St. Clair GP, ULC-Assistant Treasurer St. Clair Moore Holding LP, LLC-Assistant Treasurer St. Clair Moore Holding LP, ULC-Assistant Treasurer St. Clair MS Investment GP, LLC-Assistant Treasurer St. Clair Sombra Holding LP, LLC-Assistant Treasurer St. Clair Sombra Holding LP, ULC-Assistant Treasurer Steele Flats Wind Project, LLC-Assistant Treasurer Story Wind, LLC-Assistant Treasurer Tuscola Bay Wind, LLC-Assistant Treasurer Tuscola Wind II, LLC-Assistant Treasurer Varna Wind Funding GP, LLC-Assistant Treasurer Varna Wind Funding GP, ULC-Assistant Treasurer Varna Wind GP, LLC-Assistant Treasurer Varna Wind GP, ULC-Assistant Treasurer 451-58 Affiliation of Officers & Directors Florida Power & Light Company For the Year Ended December 31, 2015 Portales (continued) Varna Wind Holdings GP, LLC-Assistant Treasurer Varna Wind Holdings GP, ULC-Assistant Treasurer Vasco Winds, LLC-Assistant Treasurer Wessington Wind Energy Center, LLC-Assistant Treasurer White Oak B Company, LLC-Assistant Treasurer White Oak Energy Backleverage Holding, LLC-Assistant Treasurer White Oak Energy Funding Holding, LLC-Assistant Treasurer White Oak Energy Funding, LLC-Assistant Treasurer White Oak Energy Holdings, LLC-Assistant Treasurer White Oak Energy LLC-Assistant Treasurer Wild Prairie Wind Holdings, LLC-Assistant Treasurer Wild Prairie Wind, LLC-Assistant Treasurer Wilton Wind II, LLC-Assistant Treasurer Windpower Partners 1993, LLC-Assistant Treasurer Wolf Ridge Wind, LLC-Assistant Treasurer 451-59 Business Contracts with Officers, Directors and Affiliates Florida Power & Light Company For the Year Ended December 31, 2015 List all contracts, agreements, or other business arrangements* entered into during the calendar year (other than compensation-related to position with respondent) between the respondent and each officer and director listed in Part 1 of the Executive Summary. In addition, provide the same information with respect to professional services for each firm, partnership, or organization with which the officer or director is affiliated. Note: * Business agreement, for this schedule, shall mean any oral or written business deal which binds the concerned parties for products or services during the reporting year or future years. Name of Officer or Director Name and Address of Affiliated Entity Amount Identification of Product or Service No such contracts, agreements or other business arrangements to report. Note: The above listing excludes contributions, payments to educational institutions, hospitals and industry associations and other dues. See pages 454 through 463 for disclosure of diversification activity. Page 452 Reconciliation of Gross Operating Revenues Annual Report versus Regulatory Assessment Fee Return Company: Florida Power & Light Company For the YTD period ended December 31, 2015 For the current year, reconcile the gross operating revenues as reported on Page 300 of this report with the gross operating revenues as reported on the utility's regulatory assessment fee return. Explain and justify any differences between the reported gross operating revenues in column (h). (d) (e) (f) Adjusted tn\lastate Gross Operating Interstate and lal Adjusted Intrastate (h) Gross Operating lcl Interstate and Revenues per Sales for Resale Gross Operating Revenues per Sales for Resale Gross Operating Difference Page 300 Adjustments Revenues RAF Return Adjustments Revenues (d)-(g) (b) (a) Line No. Description 1 Total Sales to Ultimate Customers (440-446, 448) 2 Sales for Resale (447) 3 4 Total Sales of Electricity 5 Total Net Sales of Electricity 6 Total Other Operating Revenues (450-456) 01 7 Other (Specify) "' 8 Storm Recovery BondfTax Charges·RAF Exclusion $10,696,290,800 $10,696,290,800 $10,773,013,743 $1 0, 773,013,743 ($76, 722,943) 0 (76,722,943) 500,059,041 500,059,041 0 500,059,041 500,059,041 0 11 '196,349,840 500,059,041 10,696,290,800 11 ,273,072, 783 500,059,041 10,773,013,743 41,796 0 41,796 $41,796 0 41,796 0 11 '196,391 ,636 500,059,041 10,696,332,596 11 ,273,114,579 500,059,041 10, 773,055,539 (76, 722,943) 271,347,740 51,327,478 220,020,261 $300,300,784 51,327,478 248,973,305 (28,953,044) 0 0 0 0 0 (114,897,904) 114,897,904 $11,467,739,376 $551,386,519 $10,916,352,857 $11 ,573,415,363 $551 ,386,519 Provision for Rate Refunds (449.1) -1> 9 10 Notes: Total Gross Operating_Revenues The differences are due to: 1) Storm Recovery Revenues which are adjustments to Gross Operating Revenues on the return and are not subject to Regulatory Assessment Fees. 114,897,904 2) The Regulatory Assessment Fee (RAF) return is required to be filed on a consolidated basis, versus the requirement for the FERC Form 1 to be unconsolklated. Based on this, the following adjustments have been made: a. Pass Through revenue recorded by the utility on behalf of FPL Recovery, LLC (76,722,943) b. Revenues generated by FPL's Enersys subsidiary. (28,953,044l 9,221,917 ----- ---- --- $10,907,130,941 $9,221,917 FLORIDA PUBLIC SERVICE COMMISSION DIVERSIFICATION REPORT FLORIDA POWER 8: LIGHT COMPANY 2015 ANALYSIS OF DIVERSIFICATION ACTIVITY Changes In Corporate Structure Florida Power & Light Company For the Year Ended December 31, 2015 Provide any changes in corporate structure including partnerships, Minority interests and joint ventures, and an updated organizational chart Line No Effective Date (a) 1/2/2015 1/9/2015 1/12/2015 1/13/2015 1/13/2015 1/13/2015 1/15/2015 1/15/2015 1/15/2015 1/16/2015 Description of Change (b) GR Woodford Properties, LLC, a Delaware limited liability company, was formed as a subsidiary of Florida Power & Light Company, a Florida corporation Palo Duro Wind Holdings SeiiCo, LLC, a Delaware limited liability company, assigned its interest in Palo Duro Wind Project Holdings, LLC, a Delaware limited liability company to Palo Duro Wind Portfolio LLC a Delaware limited liability company La Palma DG Solar, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC a Delaware limited liability company RGS Realty Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of Florida Power & Light Company, a Florida corporation RGS Realty, LLC, a Delaware limited liability company, was formed as a subsidiary of RGS Realty Holdings, LLC, a Delaware limited liability company Gray Sky Investments, LLC, a Delaware limited liability company, was formed as a subsidiary of RGS Realty Holdings LLC a Delaware limited liability company Chaves County Solar, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Roswell Solar, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LL C a DelawareJimited liabilitv comoanv NextEra Energy Transmission Midwest, LLC, a Delaware !limited liability company, was formed as a subsidiary of NextEra Energy Transmission LLC a Delaware limited liability company NextEra Energy Pipeline Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Capital Holdings, Inc., a Florida corporation 1/16/2015 NextEra Energy Pipeline Services, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Pipeline Holdings, LLC, a Delaware limited liability company 1/16/2015 Oneida DG Solar, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC a Delaware limited liability company USG West Relay, LLC, a Delaware limited liability company, was formed as a subsidiary of USG Midstream Holdings LLC a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned its interest in Mojave Holdings, LLC to Mojave Red Venturez LLC a Delaware limited liability company FPL Group Resources Marketing Holdings, LLC, a Delaware limited liability company, merged with and into GR Sage (DE), LLC FPL Energy Virginia Power Services, Inc., a Florida corporation, merged with and into GR Bage (FL), Inc., a Florida corporation Javelina Wind Holdings II, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Cherokee Power, LLC a Texas limited liability company, was terminated Barrett CC Repowering, LLC, a Delaware limited liability company, changed its name to Barrett Repowering, LLC a Delaware limited liability company Maine Fossil Seller, LLC, a Delaware limited liability company, assigned its interest in Wyman Cape Holdings, LLC a Delaware limited liability company, to NextEra Main Fossil LLC Maine Fossil Seller, LLC, a Delaware limited liability company, merged with and into Wyman Cape Holdings LLC, a Delaware limited liability com_Q_any 1/16/2015 1/20/2015 1/21/2015 1/21/2015 1/28/2015 2/4/2015 2/5/2015 2/10/2015 2/10/2015 454 A-1 Line No Effective Date (a) 2/13/2015 2/13/2015 2/13/2015 2/18/2015 2/18/2015 2/18/2015 2/18/2015 2/18/2015 2/18/2015 2/18/2015 2/18/2015 2/19/2015 2/20/2015 2/27/2015 3/5/2015 3/5/2015 3/11/2015 3/16/2015 3/17/2015 3/25/2015 3/25/2015 3/25/2015 3/26/2015 3/26/2015 Description of Change (b) Chaves County Solar Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Roswell Solar Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Golden Hills North Wind, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Adelanto Solar SeiiCo, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC a Delaware limited liability company Adelanto Solar Funding, LLC, a Delaware limited liability company, was formed as a subsidiary of Adelanto Solar SeiiCo, LLC a Delaware limited liability company Adelanto Solar Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of Adelanto Solar Funding, LLC DG Willowbrook, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC, a Delaware limited liability company DG Cherry Hill, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co., LLC, a Delaware limited liability company DG Monmouth, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co., LLC, a Delaware limited liability company DG Moorestown, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co., LLC a Delaware limited liability company DG Pearl City, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co., LLC, a Delaware limited liability company Bluebell Solar, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Adelanto Solar SeiiCo, LLC, a Delaware limited liability company, changed its name to NEP US SeiiCo, LLC Shafter Solar SeiiCo, LLC, a Delaware limited liability company, assigned 100% of its interest in Shafter Solar, Delaware limited liability company, to Shafter Solar Holdings, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in Chaves County Solar, LLC, a Delaware limited liability company, to Chaves County Solar Holdings, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company assigned 100% of its interest in Roswell Solar, LLC, a Delaware limited liability company, to Roswell Solar Holdings, LLC, a Delaware limited liability company Battery Testing and Modeling, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC a Delaware limited liability company EV Battery Storage, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability_ company Javelina Wind Holdings II, LLC acquired 100% of the membership interest in Albercas Wind Energy II, LLC, a Delaware limited liability company Stuttgart Solar, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC a Delaware limited liability company_ Meyersdale Storage, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Green Mountain Storage, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company NextEra Energy Partners Acquisitions, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Partners US Holdings, LLC, a Delaware limited liability company NextEra Energy Partners Solar Acquisitions, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Partners US Holdings, LLC, a Delaware limited liability company 454A-2 line No Effective Date (a) 3/26/2015 4/3/2015 4/3/2015 4/6/2015 4/16/2015 Description of Change (b) McCoy Solar Holdings SeiiCo, LLC, a Delaware limited liability company changed its name to Solar Holdings SeiiCo LLC ESI Energy, LLC assigned 100% its interest in BSGA Gas Producing, LLC to NextEra Energy Resources, LLC NextEra Energy Resources, LLC, a Delaware limited liability company, assigned 100% of its interest in BSGA Gas Producing, LLC, a Delaware limited liability company, to NextEra Energy Power Marketing, LLC a Delaware limited liabili!Y company Blythe Solar 250, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Blythe Solar Energy Center, LLC NextEra Energy Power Marketing, LLC, a Delaware limited liability company, assigned 1OOo/o of its interest in BSGA Gas Producing, LLC, a Delaware limited 1iability company, to USG Energy Gas Producer Holdings LLC, a Delaware limited liability compclmy NEP US SeiiCo, LLC, a Delaware limited liability company, assigned 100% of its interest in Adelanto Solar Funding, LLC, a Delaware limited liability company, to Solar Holdings SellCo, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, as$igned 100% of its interest in Ashtabula Wind Ill, LLC, a Delaware limited liability company, to NEP US SeiiCo, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in Baldwin Wind Holdings, LLC, a Delaware limited liability company, to N8P US SeiiCo, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, as$igned 100% of its interest in FPL Energy Stateline Holdings, L.L.C., a Delaware limited liability company, to NEP US SeiiCo, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in Mammoth Plains Wind Holdings, Delaware limited liability company, to NEP US SeiiCo, LLC, a Delaware limited liability company Waymart Storage, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability_company Mt. Storm Wind Force Holdings, LLC, a Delaware limited !liability company, acquired 100% of the membership interest in Mt. Storm Wind Force LLC a Delaware limited liability company Aries Solar Holdings, LLC, a Delaware limited liability company, assigned 100% of its interest in Adelanto Solar, LLC, a Delaware limited liability company, to Adelanto Solar Holdings, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in Adelanto Solar II, LLC, a Delaware limited liability company, to Adelanto 13olar Holdings, LLC, a Delaware limited liability company Solar Holdings Sei!Co, LLC a Delaware limited liability company, assigned its 75% interest in Adelanto Solar Funding, LLC, a Delaware limited liability company, to NextEra Energy Partners Solar Acquisitions LLC a Delaware limited liability company Solar Holdings Sei!Co, LLC, a Delaware limited liability company, assigned its 75% Interest in McCoy Solar Holdings, LLC, a Delaware limited liability companyi to NextEra Energy Partners Solar Acquisitions, LLC, a Delaware limited liability company NEP US SeiiCo, LLC, a Delaware limited liability company, assigned 100% of its interest in Ashtabula Wind Ill, LLC, a Delaware limited liability company, to NextEra Energy Partners Acquisitions, LLC, a Delaware limited liability company NEP US SeiiCo, LLC, a Delaware limited liability company, assigned 100% of its interest In Baldwin Wind Holdings, LLC, a Delaware limited liability company, to NextEra Energy Partners Acquisitions, LLC a Delaware limited liability company NEP US SeiiCo, LLC, a Delaware limited liability company, assigned 100% of its interest in FPL Energy Stateline Holdings, L.L.C., a Delaware limited liability company, to NextEra Energy Partners Acquisitions LLC, a Delaware limited liability company 1 4/20/2015 4/20/2015 4/20/2015 4/20/2015 4/20/2015 4/27/2015 4/28/2015 4/28/2015 4/28/2015 4/30/2015 4/30/2015 5/12/2015 5/12/2015 5/12/2015 454 A-3 Line No Effective Date (a) 5/12/2015 5/13/2015 5/22/2015 5/22/2015 5/22/2015 5/22/2015 5/22/2015 5/22/2015 5/22/2015 5/22/2015 5/22/2015 5/22/2015 5/22/2015 5/22/2015 5/22/2015 5/22/2015 5/26/2015 5/26/2015 5/27/2015 5/27/2015 5/27/2015 5/27/2015 5/27/2015 5/27/2015 5/27/2015 5/27/2015 Description of Change (b) NEP US SeiiCo, LLC assigned 100% of its interest in Mammoth Plains Wind Project Holdings, LLC to NextEra Energy Partners Acquisitions, LLC USG Properties Woodford II, LLC, a Delaware limited liability company, was formed as a subsidiary of USG Properties Woodford Holdings, LLC, a Delaware limited liabillli'_ company Osborn Wind Energy, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI EnerQV, LLC a Delaware limited liability company Cordukes Solar GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada, LP an Ontario limited partnership Battersea Solar GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada, LP, an Ontario limited partnership Belleville I Solar GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada LP an Ontario limited partnership Belleville II Solar GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada, LP an Ontario limited partnership Clarabelle I Solar GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra EnerQV Canada, LP an Ontario limitedpartnership Clarabelle II Solar GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada LP, an Ontario limited partnership Clarabelle Ill Solar GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada LP, an Ontario limited partnership Trout Lake I Solar GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada LP, an Ontario limited partnership Trout Lake II Solar GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra EnerQY Canada LP, an Ontario limited partnership Trout Lake Ill Solar GP., an Ontario limited partnership Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada, LP NorthPoint I Wind GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada LP an Ontario limited partnership NorthPoint II Wind GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra EnerQV Canada, LP an Ontario limited partnership Hardy Creek Wind GP, Inc., a, an Ontario limited partnership New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada, LP Meadowlark Wind Holdings, LLC,, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Partners Acquisitions, LLC , a Delaware limited liabiJM co~ai}Y Meadowlark Wind, LLC, a Delaware limited liability company, was formed as a subsidiary of Meadowlark Wind Holdings, LLC , a Delaware limited liability company Northpoint I Wind LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada LP, an Ontario limited partnership Battersea Solar LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada, LP an Ontario limited partnership Northpoint II Wind LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada, LP an Ontario limited partnership Cordukes Solar LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada, LP an Ontario limited partnership Belleville I Solar LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada, LP, an Ontario limited partnership Belleville II Solar LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra EnerQY Canada LP an Ontario limited partnership Clarabelle I Solar LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada, LP, an Ontario limited~artnershlj:)_ Clarabelle II Solar LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra EnergyCanada LP an Ontario limited~artnershlj:)_ 454A-4 Line No Effective Date (a) 5/27/2015 5/27/2015 5/27/2015 5/27/2015 512712015 5/27/2015 5127/2015 5/28/2015 5/28/2015 5/28/2015 5/28/2015 5/28/2015 5/28/2015 5/2812015 5/28/2015 5/2812015 5/28/2015 5/28/2015 5/28/2015 5/28/2015 6/1/2015 6/1/2015 6/3/2015 6/3/2015 6/15/2015 6/15/2015 6/15/2015 Description of Change (b) Clarabelle Ill Solar LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada, LP, an Ontario limited partnership Trout Lake I Solar LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada, LP, an Ontario limi~ed partnership Trout Lake II Solar LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary_ of NextEra Energy Canada, LP, an Ontario limited __Qartnership Trout Lake Ill Solar LP, ULC, a British Columbia unlimited:liability corporation, was formed as a subsidiary of NextEra Energy Canada LP an Ontario limited partnership M Clay Solar LLC a Delaware limited liability company, was cancelled M Shoppingtown Solar, LLC, a Delaware limited liability cC)mpany, was cancelled M Eastern Hills Solar, LLC, a Delaware limited liability company, was cancelled Battersea Solar, LP, an Ontario limited partnership, was formed as a subsidiary of Battersea Solar GP, Inc. a New Brunswick corporation Belleville I Solar, LP, an Ontario limited partnership, was formed as a subsidiary of Belleville I Solar GP, Inc. a New Brunswick corporation Belleville II Solar, LP, an Ontario limited partnership, was formed as a subsidiary of Belleville II Solar GP Inc. a New Brunswick corporation Clarabelle I Solar, LP, an Ontario limited partnership, was formed as a subsidiary of Clarabelle I Solar GP, Inc., a New Brunswick corporation Clarabelle II Solar, LP, an Ontario limited partnership, was formed as a subsidiary of Clarabelle II Solar GP, Inc. a New Brunswick com_oration Clarabelle Ill Solar, LP, an Ontario limited partnership, was formed as a subsidiary of Clarabelle Ill Solar GP Inc. a New Brunswick corporation Cordukes Solar, LP, an Ontario limited partnership, was formed as a subsidiary of Hardy Creek Wind GP, Inc., a New Brunswick corporation Hardy Creek Wind, LP, an Ontario limited partnership, wa,s formed as a subsidiary of Battersea Solar GP, Inc. a New Brunswick corporation Northpoint I Wind, LP, an Ontario limited partnership, was formed as a subsidiary of Northpoint I Wind GP, Inc., a New Brunswick corporation 1 Northpoint II Wind, LP, an Ontario limited partnership, was formed as a subsidiary of Northpoint II Wind GP, Inc. a New Brunswick corporation Trout Lake I Solar, LP, an Ontario limited partnership, wa~ formed as a subsidiary of Trout Lake I Solar GP, Inc., a New Brunswick corporation Trout Lake II Solar, LP, an Ontario limited partnership, was formed as a subsidiary of Trout Lake II Solar GP Inc., a New Brunswick corporation Trout Lake Ill Solar, LP, an Ontario limited partnership, was formed as a subsidiary of Trout Lake Ill Solar GP, Inc., a New Brunswick corporation White Pine Wind, Inc., a New Brunswick corporation converted to a British Columbia unlimited liability corporation White Pine Wind, Inc., a British Columbia unlimited liabilit:y corporation, changed its name to Hardy Creek Wind ULC US Sooner Trails Gas Infrastructure, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Pipeline Holdings, LLC a Delaware limited liability company DP II LLC, a Virginia limited liability company, was cancelled NextEra Transmission Asset Acquisition Holdings, LLC, Delaware limited liability company, was formed as a subsidiary of NextEra Energy Transmission, LLC, a Delaware limited liability company a NextEra Energy Partners Ventures, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy US Partners Holdings LLC a Delaware limited liability company Tuscola Wind Ill, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company 454 A-5 Line No Effective Date (a) 6/16/2015 Description of Change (b) 6/19/2015 Ll Peaker Generation, LLC, , a Delaware limited liability company, changed its name to Clean Energy Generation, LLC NextEra Energy Partners Acquisitions, LLC, a Delaware limited liability company, assigned 100% of its interest in Ashtabula Wind Ill, LLC, a Delaware limited liability company, to Meadowlark Wind, LLC, a Delaware limited liability company NextEra Energy Partners Acquisitions, LLC,, a Delaware limited liability company, assigned 100% of its interest in FPL Energy Stateline Holdings, L.L.C., a Delaware limited liability company to Meadowlark Wind, LLC, a Delaware limited liability company Blythe Solar 125, LLC, a Delaware limited liability company, changed its name to Blythe Solar II, LLC 6/19/2015 Blythe Solar 250, LLC, a Delaware limited liability company, changed its name to Blythe Solar Ill, LLC 6/19/2015 DG 1 Acquisition Co., LLC, a Delaware limited liability company, acquired 100% of the membership interest in Old Mill Solar, LLC, an Oregon limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in Golden West Wind Holdings, LLC, a Delaware limited liability company, to Northern Colorado Wind Holdings, LLC, , a Delaware limited liability company Dickinson Wind, LLC, a Delaware limited liability company, changed its name to Brady Wind, LLC 6/17/2015 6/17/2015 6/22/2015 6/25/2015 6/29/2015 6/29/2015 6/30/2015 6/30/2015 7/8/2015 7/8/2015 7/8/2015 7/21/2015 7/22/2015 7/22/2015 7/23/2015 7/23/2015 7/24/2015 7/24/2015 7/24/2015 7/27/2015 NextEra Energy Partners Acquisitions, LLC, a Delaware limited liability company assigned 24.99% of its interest in McCoy Solar Holdings, LLC, a Delaware limited liability company, to Solar Holdings SeiiCo, LLC a Delaware limited liability company NextEra Energy Partners Acquisitions, LLC, a Delaware limited liability company, assigned 24.99% of its interest in Adelanto Solar Funding, LLC, a Delaware limited liability company, to Solar Holdings SeiiCo, LLC, , a Delaware limited liability company ESI Tractebel Funding Corp., a Delaware corporation, was cancelled ESI Tractebel AcQuisition Corp., a Delaware corporation was cancelled Hale Wind Energy, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company NextEra Energy Transmission Mid-Atlantic, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Transmission, LLC, a Delaware limited liability company Rush Springs Wind Energy, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC a Delaware limited liability company DG North Carolina Solar Holding, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co., LLC a Delaware limited liability company Belleville II Solar GP, Inc., a New Brunswick corporation, changed its name to Canadian Combined Cycle Station I GP, Inc. Belleville II Solar LP, ULC, a British Columbia unlimited liability corporation, changed its name to Canadian Combined Cycle Station I LP, ULC Breckinridge Wind Funding, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC Breckinridge Wind Class A Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of Breckinridge Wind Funding, LLC, a Delaware limited liability company Chaves County Solar Resources, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Belleville II Solar, LP, an Ontario limited partnership, changed its name to Canadian Combined Cycle Station I LP ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in Breckinridge Wind Holdings, LLC, a Delaware limited liability company, to Breckinridge Wind Funding, LLC, a Delaware limited liability company Belleville I Solar GP, Inc., a New Brunswick corporation, changed its name to Thames Solar GP, Inc. 454A-6 Line No Effective Date (a) 7/27/2015 7/28/2015 7/29/2015 7/30/2015 7/31/2015 7/31/2015 8/6/2015 8/6/2015 8/6/2015 8/6/2015 8/6/2015 8/6/2015 8/20/2015 8/20/2015 8125/2015 8/25/2015 8/26/2015 8/26/2015 8/26/2015 8/26/2015 8/26/2015 8/26/2015 8/26/2015 8/26/2015 8/27/2015 Description of Change (b) Belleville 1Solar LP, ULC, a British Columbia unlimited liability company, changed its name to Thames Solar LP ULC Breckinridge Wind Holdings, LLC, a Delaware limited liability company, assigned 5% of its interest in Breckinridge Wind Project, LLC, a Delaware limited liability company, to Breckinridge Wind Class A Holdings, LLC, , a Delaware limited liability company DG Waipio, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co., LLC Belleville I Solar LP an Ontario limited partnership changed its name to Thames Solar, LP Stark Wind, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company DG CSU Solar, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC a Delaware limited liability company . Sooner Trails Pipeline, LLC, a Delaware limited liability company, was formed as a subsidiary of US Sooner Trails Gas Infrastructure, LLC, a Delaware limited liability com_pany DG Clean Energy Solutions, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition .Co. LLC a Delaware limited liability company Bayhawk Wind, LLC, a Delaware limited liability company, was formed as a subsidiary of Baywind SeiiCo LLC a Delaware limited liability company Bayhawk Wind Sellco, LLC, a Delaware limited liability company, was formed as a subsidiary of B~hawk Wind Funding, LLC, a Delaware limited liability dompany Bayhawk Wind Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of Bayhawk Wind Funding, LLC, a Delaware limited liability company Bayhawk Wind Funding, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC a Delaware limited liabilit~ company Blythe Solar IV, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra BM_he Solar Ener9y Center LLC, a Delaware limited liability company_ DG SUNY Solar 1, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 A~uisltion Co., LLC, a Delaware limited liability_ company DG CID Solar, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co., LLC, a Delaware limited liability company Golden Hills Energy Storage, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Battersea Solar LP, ULC, a British Columbia unlimited liability corporation, sold 10% of its interest in Battersea Solar, LP to an outside 3rd party Clarabelle I Solar LP, ULC, a British Columbia unlimited liability corporation, sold 10% of its Interest in Clarabelle I Solar LP to an outside 3rd party Clarabelle II Solar LP, ULC, a British Columbia unlimited liability corporation, sold 10% of its interest in Clarabelle II Solar, LP to an outside 3rd party Cordukes Solar LP, ULC, a British Columbia unlimited liability corporation, sold 10% of its interest in Cordukes Solar LP to an outside 3rd party Hardy Creek Wind LP, ULC, a British Columbia unlimited liability corporation, sold 10% of its interest in Hardy Creek Wind LP to an outside 3rd party Northpoint I Wind LP, ULC, a British Columbia unlimited liability corporation, sold 10% of its interest in Northpoint I Wind LP to an outside 3rd party Northpoint II Wind LP, ULC, a British Columbia unlimited liability corporation, sold 10% of its interest in Northpoint II Wind LP to an outside 3rd party Trout Lake I Solar LP, ULC, a British Columbia unlimited liability corporation, sold 10% of its interest in Trout Lake I Solar LP to an outside 3rd party Golden Hills Interconnection, LLC, a Delaware limited liability company, was formed as a subsidiary of Golden Hills Wind, LLC, a Delaware limited liability company, and Golden Hills Wind North, LLC, a Delaware limited liability company 454 A-7 ------------------~---~~- ----~~--------~ ~ Line No Effective Date (a) 8/28/2015 8/28/2015 8/28/2015 8/28/2015 8/28/2015 8/28/2015 8/28/2015 8/28/2015 8/28/2015 8/28/2015 8/28/2015 8/28/2015 8/28/2015 8/28/2015 9/3/2015 9/11/2015 9/11/2015 9/11/2015 9/11/2015 Description of Change (b) NY Sun DG Solar, LLC, a Delaware limited liability company, assigned 100% of its interest in NY Sun Zone C3 LLC, a Delaware limited liability company, to DG 1 Acquisition Co., LLC, a Delaware limited liability company NY Sun DG Solar, LLC, a Delaware limited liability company, assigned 100% of its interest in, NY Sun Zone E1 LLC, a Delaware limited liability company, to DG 1 Acquisition Co., LLC, a Delaware limited liability company NY Sun DG Solar, LLC, a Delaware limited liability company, assigned 100% of its interest in NY Sun Zone E2 LLC, a Delaware limited liability company, to DG 1 Acquisition Co., LLC, a Delaware limited liability company NY Sun DG Solar, LLC, a Delaware limited liability company, assigned 100%.of its interest in NY Sun Zone F1 LLC, a Delaware limited liability company, to DG 1 Acquisition Co., LLC, a Delaware limited liability company NY Sun DG Solar, LLC, a Delaware limited liability company, assigned 100% of its interest in, NY Sun Zone F2 LLC, a Delaware limited liability company, to DG 1 Acquisition Co., LLC, a Delaware limited liability company NY Sun DG Solar, LLC, a Delaware limited liability company, assigned 100% of its interest in NY Sun Zone F4 LLC, a Delaware limited liability company, to DG 1 Acquisition Co., LLC, a Delaware limited liability company DG 1 Acquisition Co., LLC, a Delaware limited liability company, assigned 100% of its interest in NY Sun Zone C3 LLC, a Delaware limited liability company, to DG SUNY Solar I, LLC, a Delaware limited liability company DG 1 Acquisition Co., LLC, a Delaware limited liability company, assigned 100% of its interest in NY Sun Zone E1 LLC, a Delaware limited liability company, to DG SUNY Solar I, LLC, a Delaware limited liability company DG 1 Acquisition Co., LLC, a Delaware limited liability company, assigned 100% of its interest in NY Sun Zone E2 LLC, a Delaware limited liability company, to DG SUNY Solar I, LLC, a Delaware limited liability comoany DG 1 Acquisition Co., LLC, a Delaware limited liability company, assigned 100% of its interest in NY Sun Zone F1 LLC, a Delaware limited liability company, to DG SUNY Solar I, LLC, a Delaware limited liability company DG 1 Acquisition Co., LLC, a Delaware limited liability company, assigned 100% of its interest in NY Sun Zone F2 LLC, a Delaware limited liability company, to DG SUNY Solar I, LLC, a Delaware limited liability company DG 1 Acquisition Co., LLC, a Delaware limited liability company, assigned 100% of its interest in NY Sun Zone F4 LLC, a Delaware limited liability company, to DG SUNY Solar I, LLC, a Delaware limited liability company DG 1 Acquisition Co., LLC, a Delaware limited liability company, assigned 100% of its interest in M Schenectady Solar, LLC, a Delaware limited liability company, to DG SUNY Solar I, LLC, a Delaware limited liability company DG 1 Acquisition Co., LLC, a Delaware limited liability company, assigned 100% of its interest in EW Solar, LLC, a Delaware limited liability company, to DG SUNY Solar I, LLC, a Delaware limited liability company DG Newark, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC a Delaware limited liability company DG Minnesota CSG 1, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co., LLC, a Delaware limited liability company DG Minnesota CSG 2, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC a Delaware limited liability company DG Minnesota CSG 3, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC, a Delaware limited liability company DG Minnesota CSG 4, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co., LLC a Delaware limited liability comQ_aQY_ 454 A-8 Line No Effective Date (a) 9/11/2015 9/11/2015 9/11/2015 9/11/2015 9/11/2015 9/11/2015 9/18/2015 9/21/2015 9/21/2015 9/23/2015 9/28/2015 10/1/2015 10/1/2015 10/1/2015 10/1/2015 10/112015 10/1/2015 10/8/2015 10/8/2015 Description of Change (b) DG Minnesota CSG 5, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co., LLC, a Delaware limited liability company DG Minnesota CSG 6, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 A~uisition Co., LLC, a Delaware limited liability company DG Minnesota CSG 7, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC a Delaware limited liability company DG Minnesota CSG 8, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC a Delaware limited liability company DG Minnesota CSG 9, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC, a Delaware limited liability com13_any DG Minnesota CSG 10, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC a Delaware limited liability company Respondent acquired 100% of the stock in CBAS Power, Inc., a Delaware corporation, and its subsidiaries, Cedar Bay Holdings, LLC, Gray Hawk Powe~ Corporation, Cedar Power, LLC, Cedar I Power, LLC, Cedar II Power, LLC, Cedar Bay Cogeneration, LLC and Cedar Bay Generating Company, Limited Partnership Gray Hawk Power Corporation, a Delaware corporation, merged with and into Cedar Bay Holdings, LLC a Delaware limited liability company Cedar 1 Power, LLC, a Delaware limited liability company, merged with and into Cedar Power, LLC, a Delaware limited liability_ company CBAS Power, Inc., a Delaware corporation, merged with and into Cedar Bay Holdings, LLC, a Delaware limited liability company Cedar Power, LLC, a Delaware limited liability company, merged with and into Cedar Bay Holdings, LLC, a Delaware limited liability company NEPM II Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Resources, LLC a Delaware limited liability company Golden West Power Partners II, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company NextEra Energy Partners Ventures, LLC, a Delaware limited liability company acquired 100% of the interest in NET Holdings Management, LLC, a Delaware limited liability company and its subsidiaries, NET Midstream, LLC, a Texas limited liability company, NET Pipeline Holdings, LLC, a Delaware limited liability company NET General Partners, LLC, a Texas limited liability company, Monument Pipeline, LP, a Texas limited partnership, South Shore Pipeline L.P., a Texas limited partnership, Mission Valley Pipeline Company, LP, a Texas limited partnership, Red Gate Pipeline, LP, a Texas limited partnership, Mission Natural Gas Company, LP, a Texas limited partnership, LaSalle Pipeline, LP, a Texas limited partnership, Eagle Ford Midstream, LP, a Texas limited partnership, NET Mexico Pipeline, LP, a Texas limited partnership and NET Mexico Pipeline, LP, a Texas limited partnership, which owns 90% of the interest in NET Mexico Partners, LLC, a Delaware limited liability company NextEra Energy Canada, LP, an Ontario limited partnership, assigned its interest in Jericho Wind BC Holdings, ULC, a British Columbia unlimited liability corporation to NextEra Energy Operating Partners, LP, a Delaware limited partnership NextEra Energy Operating Partners, LP, a Delaware limited partnership, assigned 100% of its interest in Jericho Wind BC Holdings, ULC, a British Columbia unlimited liability company to NextEra Energy Canada Partners Holdings ULC a British Columbia unlimited liability company NextEra Energy Resources, LLC, a Delaware limited liability company, assigned 100% of its interest in NEPM II, LLC, a Delaware limited liability company to NEPM II Holdings, LLC, a Delaware limited liability companv Tech Testing Solutions Holdings, LLC, a Delaware limited liability company, was formed as a subsidiarv of NextEra Enen:w Capital Holdings, Inc., a Florida corporation Tech Testing Solutions, LLC, a Delaware limited liability company, was formed as a subsidiary of Tech Testing Solutions Holding~s, LLC, a Delaware limited liabUity company 454 A-9 Line No Effective Date (a) 10/8/2015 10/8/2015 10/8/2015 10/8/2015 10/8/2015 10/9/2015 10/13/2015 10/13/2015 10/13/2015 10/13/2015 10/15/2015 10/15/2015 10/15/2015 10/15/2015 10/15/2015 10/21/2015 10/21/2015 10/22/2015 10/26/2015 10/26/2015 10/26/2015 10/26/2015 Description of Change (b) Ghost Pine Energy Storage GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada LP, an Ontario limited partnership_ Ghost Pine Energy Storage LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada, LP an Ontario limited partnershle_ Chaves County Solar II Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC a Delaware limited liabiiJ!y_ comQ_any Chaves County Solar II, LLC, a Delaware limited liability company, was formed as a subsidiary of Chaves County Solar II Holdings LLC a Delaware limited liability company Blythe Solar Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC a Delaware limited liability company Ghost Pine Energy Storage, LP, an Alberta limited partnership, was formed as a subsidiary of Ghost Pine Energy Storage, Inc., a New Brunswick corporation South Texas Wind Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC a Delaware limited liability compai]Y_ DG Waipio, LLC, a Delaware limited liability company acquired 100% of the interest in Pacific Energy Solutions, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company assigned 100% of its interest in Cedar Bluff Wind, LLC, a Delaware limited liability company to Bayhawk Wind Funding, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company assigned 100% of its interest in Golden Hills Wind, LLC, a Delaware limited liability company to Bayhawk Wind Funding, LLC, a Delaware limited liability company Bayhawk Wind Funding, LLC, a Delaware limited liability company assigned 100% of its interest in Cedar Bluff Wind, LLC, a Delaware limited liability company to Bayhawk Wind SeiiCo, LLC, a Delaware limited liability company Bayhawk Wind Funding, LLC, a Delaware limited liability company assigned 100% of its interest in Golden Hills Wind, LLC, a Delaware limited liability company to Bayhawk Wind SeiiCo, LLC, a Delaware limited liability compan't Bayhawk Wind Sell Co, LLC, a Delaware limited liability company assigned 100% of its interest in Cedar Bluff Wind, LLC, a Delaware limited liability company to Bayhawk Wind, LLC, a Delaware limited liability company Bayhawk Wind SeiiCo, LLC, a Delaware limited liability company assigned 100% of its interest in Golden Hills Wind, LLC, a Delaware limited liability company to Bayhawk Wind, LLC, a Delaware limited liability company Bayhawk Wind SeiiCo, LLC, a Delaware limited liability company assigned 5% of its interest in Bayhawk Wind, LLC, a Delaware limited liability company, to Bayhawk Wind SeiiCo, LLC, a Delaware limited liability company Brady Wind II, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Crowned Ridge Wind, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in Javelina Wind Energy Holdings, LLC to South Texas Wind Holdings, LLC, a Delaware limited liability company Energy Storage Systems Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC Energy Storage Projects (Utility), LLC, a Delaware limited liability company, was formed as a subsidiary of Energy Storage Systems Holdings, LLC a Delaware limited liability company Energy Storage Projects (Distributed), LLC, a Delaware limited liability company, was formed as a subsidiary of Energy Storage Systems Holdings, LLC, a Delaware limited liability company Sonoran Energy Storage System, LLC, a Delaware limited liability company, was formed as a subsidiary of Energy Storage Projects (Utility), LLC a Delaware limited liabiiJ!y_ comoanv 454 A-10 Line No Effective Date (a) Description of Change (b) 10/26/2015 Distributed Energy Storage Associates, LLC, a Delaware limited liability company, was formed as a subsidiary of Energy Storage Projects (Distributed), LLC, a Delaware limited liability company 10/29/2015 Minco Wind IV, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC a Delaware limited liability company Old Mill Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC, a Delaware limited liability company DG HD Hawaii, LLC, a Delaware limited liability company, was formed as a subsidiary of DG 1 Acquisition Co. LLC, a Delaware limited liability company Mojave Red Venturez, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Elmira Energy Storage GP, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Canada LP an Ontario limited partnership Elmira Energy Storage LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada LP an Ontario limlted partnership Elmira Energy Storage GP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of Elmira Energy Storage GP, LLC, a Delaware limited liability company Parry Energy Storage GP, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Canada LP, an Ontario limited partnership Parry Energy Storage LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada, LP, an Ontario limited partnership Parry Energy Storage GP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of .Parry Energy Storage GP LLC, a Delaware limited liability company High Hills Wind GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada, LP, an Ontario limitedQ_artnership High Hills Wind LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra EnergyGanada LP an Ontario limited partnership_ Costigan Wind LP, ULC, a British Columbia unlimited liability corporation, was formed as a subsidiary of NextEra Energy Canada LP an Ontario limited partnership Costigan Wind GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada LP an Ontario limited partnership Minudie Wind GP, Inc., a New Brunswick corporation, was formed as a subsidiary of NextEra Energy Canada LP an Ontario limited partnership ESI Sky River Inc., a Florida corporation was dissolved ESI Northeast Enen:~y Funding, Inc., a Florida corporation was dissolved ESI Montgomery Countv. LLC a Delaware limited liability; company, was cancelled Common Unit Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Resources, LLC a Delaware limited liability company ESI Northeast Energy Acquisition Funding, Inc., a Florida corJ)_oration was dissolved NextEra Energy Pipeline Development and Acquisitions, LLC, a Delaware limited liability company, was formed as a subsidiary of NextEra Energy Pipeline Holdings, LLC, a Delaware limited liability company 11/4/2015 11/4/2015 11/5/2015 11/12/2015 11/12/2015 11/12/2015 11/12/2015 11/12/2015 11/12/2015 11/12/2015 11/12/2015 11/1212015 11/12/2015 11/12/2015 11/12/2015 11/12/2015 11/12/2015 11/13/2015 11/13/2015 11/16/2015 11/16/2015 11/16/2015 11/16/2015 11/16/2015 11/17/2015 11/17/2015 Multitrade of Pittsylvania County, L.P. a Delaware limited partnership, was cancelled Thunderhead Lake Wind, LLC, a Delaware limited liability company, was merged with and into GR Bage (DE), LLC a Delaware limited liability company FPL Energy WPP 93 LP, LLC, a Delaware limited liability company, was merged with and into GR Bage (DE), LLC, a Delaware limited liability company FPL Energy WPP 93 GP, LLC, a Delaware limited liability company, was merged with and into GR Bage {DE), LLC, a Delaware limited liability company Elmira Energy Storage, LP, an Ontario limited partnershi!P, was formed as a subsidiary of Elmira Energy Storage GP ULC a British Columbia unlimited liability comDanv Parry Energy Storage, LP, an Ontario limited partnership~ was formed as a subsidiary of Parry Energy Storage GP, ULC, a British Columbia unlimited liability company 454 A-11 Line No Effective Date (a) 11/17/2015 11/17/2015 11/17/2015 11/17/2015 11/18/2015 11/18/2015 11/18/2015 11/23/2015 11/24/2015 11/25/2015 11/25/2015 11/25/2015 11/25/2015 11/25/2015 11/25/2015 11/25/2015 11/25/2015 11/25/2015 11/25/2015 11/25/2015 11/25/2015 Description of Change (b) High Hills Wind, LP, a New Brunswick limited partnership, was formed as a subsidiary of High Hills Wind GP, Inc. a New Brunswick corporation Costigan Wind, LP, a New Brunswick limited partnership, was formed as a subsidiary of Costigan Wind GP, Inc. a New Brunswick corporation Minudie Wind, Inc. a New Brunswick corporation converted to a British Columbia unlimited liability corporation Minudie Wind, Inc., a British Columbia unlimited liability company changed its name to Minudie Wind LP ULC Minudie Wind, LP, a New Brunswick limited partnership, was formed as a subsidiary of Minudie Wind GP, Inc., a New Brunswick corporation ESI Mulitrade LP, Inc. a Florida corporation was cancelled ESI Pittsylvania, Inc., a Florida corporation, was cancelled La Frontera Ventures, LLC, a Delaware limited liability company, was formed as a subsidiary of FPL Energy T~er Texas LP LLC a Delaware limited liability company FPL Energy Tyler Texas LP, LLC, a Delaware limited liability company, assigned its interest in La Frontera Holdings LLC to La Frontera Ventures LLC, a Delaware limited liability company NextEra Blythe Solar Energy Center, LLC, a Delaware limited liability company, assigned 100% of its interest in Blythe Solar 110, LLC, a Delaware limited liability company, to ESI Energy, LLC, a Delaware limited liabilih' company. NextEra Blythe Solar Energy Center, LLC, a Delaware limited liability company assigned 100% of its interest in Blythe Solar II, LLC, a Delaware limited liability company to ESI Energy, LLC, a Delaware limited liability company NextEra Blythe Solar Energy Center, LLC, a Delaware limited liability company, assigned 100% of its interest in Blythe Solar Ill, LLC, a Delaware limited liability company, to ESI Energy, LLC, a Delaware limited liability company NextEra Blythe Solar Energy Center, LLC, a Delaware limited liability company, assigned 100% of its interest in Blythe Solar IV, LLC, a Delaware limited liability company, to ESI Energy, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in NextEra Blythe Solar Energy Center, LLC, a Delaware limited liability company, to Blythe Solar Holdings, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in Blythe Solar 11 0, LLC, a Delaware limited liability company, to Blythe Solar Holdings, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in Blythe Solar II, LLC, a Delaware limited liability company, to Blythe Solar Holdings, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in Blythe Solar Ill, LLC, a Delaware limited liability company, to Blythe Solar Holdings, LLC, a Delaware limited liability company ESI Energy, LLC, a Delaware limited liability company, assigned 100% of its interest in Blythe Solar IV, LLC, a Delaware limited liability company, to Blythe Solar Holdings, LLC, a Delaware limited liability company Blythe Solar Holdings, LLC, a Delaware limited liability company, assigned 25% of its interest in NextEra Blythe Solar Energy Center, LLC, a Delaware limited liability company, to Blythe Solar 110, LLC, a Delaware limited liability company Blythe Solar Holdings, LLC, a Delaware limited liability company, assigned 25% of its interest in NextEra Blythe Solar Energy Center, LLC, a Delaware limited liability company to Blythe Solar II, LLC, a Delaware limited liability company Blythe Solar Holdings, LLC, a Delaware limited liability company, assigned 25% of its interest in NextEra Blythe Solar Energy Center, LLC, a Delaware limited liability company to Blythe Solar Ill, LLC, a Delaware limited liability company 454 A-12 Line No Effective Date (a) 11/25/2015 1211/2015 12/8/2015 12/8/2015 12/8/2015 12/10/2015 12/10/2015 12/10/2015 12/10/2015 12/14/2015 12/15/2015 12/18/2015 12/18/2015 12/18/2015 12/18/2015 12/21/2015 12/21/2015 12/29/2015 12129/2015 12/29/2015 12129/2015 12129/2015 12129/2015 12/29/2015 12/29/2015 12/29/2015 12/29/2015 12/31/2015 Description of Change (b) Blythe Solar Holdings, LLC, a Delaware limited liability company, assigned 25% of its Interest in NextEra Blythe Solar Energy Center, LLC, a Delaware limited liability company to Blythe Solar IV, LLC., a Delaware limited liability company Javelina Interconnection, LLC, a Delaware limited liability company, was formed as a subsidiary of Javelina Wind Energy, LLC, a Delaware limited liability company, and Albercas Wind Energy II, LLC., a Delaware limited liability company West Hills Wind, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Moose Wind, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liabil~ company Penobscot Wind, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liabili!Ycompany_ South Texas Wind Energy, LLC, a Delaware limited liability company, was formed as a subsidiary of South Texas Wind Holdings, LLC a Delaware limited liability company Javelina Wind Funding Holdings, LLC, a Delaware limited liability company, was formed as a subsidiary of South Texas Wind Energy, LLC a Delaware limited liability company Javelina Wind Funding, LLC, a Delaware limited liability company, was formed as a subsidiary of Javelina Wind Funding Holdings LLC a Delaware limited liability company Sonoran Energy Storage System, LLC, a Delaware limited liability company, changed its name to Pima Energy Storage LLC Pima Energy Storage, LLC, a Delaware limited liability company, changed its name to Pima Energy Storage System LLC, a Delaware limited liability company South Texas Wind Holdings, LLC, a Delaware limited liability company, assigned 100% of its interest in Javelina Wind Energy Holdings, LLC, a Delaware limited liability company, to Javelina Wind Funding, LLC, a Delaware limited liability company Kingman Wind Holding I, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Enen:~v. LLC, a Delaware limited liability company Kingman Wind Energy I, LLC, a Delaware limited liability company, was formed as a subsidiary of KinQman Wind Holding I, LLC, a Delaware limited liability company Kingman Wind Holding II, LLC, a Delaware limited liability company, was formed as a subsidiary of ESI Energy, LLC, a Delaware limited liability company Kingman Wind Energy II, LLC, a Delaware limited liability company, was formed as a s'ubsidiary of Kingman Wind Energy Holding II, LLC a Delaware limited liability company DG North Carolina Solar Ventures, LLC, a De.laware limited liability company, was formed as a subsidiary_ of DG 1 Acquisition Co. LLC Javelina Wind Class B, LLC, a Delaware limited liability company, was formed as a subsidiary of South Texas Wind Holdings LLC Javelina Wind Funding Holdings, LLC assigned its interest in Javelina Wind Funding, LLC to South Texas Wind Holdings, LLC Mojave HoldinQs LLC a Delaware limited liability company was sold to an outside 3rd party Mojave 3/4/5 LLC a Delaware limited liability company was sold to an outside 3rd party Eurus Mojave 3/5 LLC a Delaware limited liability company was sold to an outside 3rd party Eurus Mojave 4 LLC, a Delaware limited liability company was sold to an outside 3rd pa_l'l:y Alpha Mariah (Prime), Inc., a California corporation was sold to an outside 3rd party Alpha Mariah LLC a Delaware limited liability company was sold to an outside 3rd party_ Beta Mariah (Prime}, Inc. a California corporation was sold to an outside 3rd Q_a_rty Beta Mariah LLC, a Delaware limited liability company wa$ sold to an outside 3rd party Gamma Mariah LLC, a Delaware limited liability company was sold to an outside 3rd pa_rty NextEra Energy US Gas Assets, LLC, a Delaware limited liability company, assigned 100% of its interest in US Marcellus Gas Infrastructure, LLC, a Delaware limited liability company, to NextEra Energy Pipeline Holdings LLC a Delaware limited liability company 454 A-13 Line No Effective Date (a) 12/31/2015 12/31/2015 12/31/2015 Description of Change (b) NextEra Energy Capital Holdings, Inc., a Florida corporation, assigned 100% of its interest in NextEra Energy Sabal Trail Transmission Holdings, LLC, a Delaware limited liability company, to NextEra Energy Pipeline Holdings, LLC, a Delaware limited liability company NextEra Energy Capital Holdings, Inc., a Florida corporation, assigned its interest in Florida Southeast Connection, LLC, a Delaware limited liability company, to NextEra Energy Pipeline Holdings, LLC, a Delaware limited liability company NextEra Energy Capital Holdings, Inc., a Florida corporation, assigned its interest in NextEra Energy Pipeline Holdings, LLC, a Delaware limited liability company, to USG Energy Gas Producer Holdings, LLC, a Delaware limited liability company 454 A-14 NextEra Energy, Inc. Florida Power & Light Company Common 100% APOG, LLC Percentage Ownership Interest 20 % FPL Enersys, Inc. Common 100% FPL Services, LLC Membership Interest 100% KPB Financial Corp. Common 100% Private Fuel Storage L.L.C. Membership Interest 12.5% FPL Recovery Funding LLC Percentage OWnership Interest 100% GR Woodford Properties, LLC Percentage Ownership Interest 100 % RGS Realty Holdings, LLC Percentage Ownership Interest 100% RGS Realty, LLC Percentage Ownership Interest 100% Gray Sky Investments, LLC Percentage Ownership Interest 100% Cedar Bay Holdings, LLC Percentage Ownership Interest 100 % Cedar II Power, LLC Percentage Ownership Interest 100% Cedar Bay Generating Company, Limited Partnership Percentage Ownership Interest 20 % Cedar Bay Cogeneration, LLC Percentage Ownership Interest 100 % Cedar Bay Generating Company, Limited Partnership Percentage Ownership Interest 80 % Page 454 B-1 NextEra Energy Capital Holdings, Inc. Common 100% NextEra Energy Resources, LLC Membership Interest 100% ESI Energy, LLC Membership Interest 100 % GR Bage (DE), LLC Membership Interest 100 % ESI Mojave LLC Membership Interest 99% FPLE Rhode Island State Energy LP, LLC Percentage Ownership Interest 100 % FPL Energy Island End GP, LLC Membership Interest 100 % FPL Energy MH50 LP, LLC Membership Interest 100 % FPL Energy MH50, L.P. Partnership Interest 99 % FPL Energy MHSO GP, LLC Membership Interest 100 % FPL Energy MH50, L.P. Partnership Interest 1 % FPL Energy Marcus Hook LLC Membership Interest 100% FPL Energy Marcus Hook, L.P. Partnership Interest 99 % FPL Energy MH700, LLC Membership Interest 100% FPL Energy Marcus Hook, L.P. Partnership Interest 1 % Tower Associates, LLC Membership Interest 100% FPL Energy Morwind, LLC Membership Interest 100% Page454 8-2 Boulevard Associates, LLC Membership Interest 100 % High Desert Land Acquisition LLC Membership Interest 90% Green Ridge Services LLC Membership Interest 100% LET Holdings, LLC Percentage Ownership Interest 100% FPLE Texas Wind I, LLC Percentage Ownership Interest 100% FPLE Pecos Leasing GP, LLC Percentage Ownership Interest 100 % FPLE Pecos Wind Leasing Co., LP Partnership Interest 1 % FPLE Pecos Leasing LP, LLC Percentage Ownership Interest 100 % FPLE Pecos Wind Leasing Co., LP Partnership Interest 99 % FPLE Upton Leasing GP, LLC Percentage Ownership Interest 100 % FPLE Upton Wind Leasing Co., LP Partnership Interest 1 % FPLE Upton Leasing LP, LLC Percentage Ownership Interest 100 % FPLE Upton Wind Leasing Co., LP Partnership Interest 99 % FPL Energy Mojave Operating Services, LLC Percentage Ownership Interest 100% Gray County Wind Energy, LLC Membership Interest 100 % NextEra Energy Seabrook, LLC Membership Interest 100% FPL Energy VG Wind, LLC Membership Interest 50 % Page 454 8-3 ----~---~------~-- ~---~-- FPL Energy New York, LLC Membership Interest 100% FPL Energy Rockaway Peaking Facilities, LLC Membership Interest 100 % Bayswater Peaking Facility, LLC Membership Interest 100 % Jamaica Bay Peaking Facility, LLC Membership Interest 100 % OTG, LLC Membership Interest 100% FPL Energy Wind Funding Holdings, LLC Percentage Ownership Interest 100% FPL Energy Wind Funding, LLC Membership Interest 100 % FPL Energy Wind Financing, LLC Percentage Ownership Interest 100 % FPL Energy American Wind Holdings, LLC Membership Interest 100% FPL Energy American Wind, LLC Membership Interest 100% High Winds, LLC Membership Interest 100 % Lake Benton Power Partners II, LLC Membership Interest 100% Hawkeye Power Partners, LLC Membership Interest 100 % FPL Energy Hancock County Wind, LLC Membership Interest 100% ESI West Texas Energy LP, LLC Membership Interest 100% West Texas Wind Energy Partners, L.P. Partnership Interest 99 % Page 454 B-4 ESI West Texas Energy, Inc. Common 100% West Texas Wind Energy Partners, L.P. Partnership Interest 1 % FPL Energy Stateline II Holdings, LLC Percentage Ownership Interest 100% FPL Energy Stateline II, Inc. Common 100% FPL Energy WPP94 GP, LLC Percentage Ownership Interest 100% Windpower Partners 1994, L.P. General Partnership Interest 33 % LQGP, LLC Membership Interest 100 % Windpower Partners 1994, L.P. General Partnership Interest 34 % FPL Energy WPP94 LP, LLC Membership Interest 100% Wind power Partners 1994, L.P. General Partnership Interest 33 % LQC LP, LLC Membership Interest 100% Wind power Partners 1994, L.P. Limited Partnership Interest 24.909091 % FPL Energy SEGS Ill-VII GP, LLC Membership Interest 100 % Luz Solar Partners Ltd., Ill Partnership Interest 0.333 % Luz Solar Partners Ltd., IV Partnership Interest 0.25 % Luz Solar Partners Ltd., V Partnership Interest 0.25% Luz Solar Partners Ltd., VI Partnership Interest 0.583 % Page454 B-5 Luz Solar Partners Ltd., VII Partnership Interest 0.679 % Kramer Junction Solar Funding, LLC Percentage Ownership Interest 25 % FPL Energy SEGS Ill-VII LP, LLC Membership Interest 100 % Luz Solar Partners Ltd., Ill Partnership Interest 45.1216 % Luz Solar Partners Ltd., IV Partnership Interest 37.5788 % Luz Solar Partners Ltd., V Partnership Interest 45.5862% Luz Solar Partners Ltd., VI Partnership Interest 40.5793% Luz Solar Partners Ltd., VII Partnership Interest 49.321 % Kramer Junction Solar Funding, LLC Percentage Ownership Interest 25% FPL Energy National Wind Investments, LLC Membership Interest 100 % FPL Energy National Wind Portfolio, LLC Membership Interest 100% FPL Energy National Wind Holdings, LLC Membership Interest 100% FPL Energy National Wind, LLC Membership Interest 100 % Backbone Windpower Holdings, LLC Membership Interest 100% Backbone Mountain Windpower LLC Membership Interest 100 % FPL Energy Oklahoma Wind, LLC Membership Interest 100% FPL Energy Oklahoma Wind Finance, LLC Membership Interest 100% Page 454 B-6 FPL Energy Sooner Wind, LLC Membership Interest 100% FPL Energy North Dakota Wind, LLC Membership Interest 100 % FPL Energy South Dakota Wind, LLC Membership Interest 100% FPL Energy North Dakota Wind II, LLC Membership Interest 100 % FPL Energy Waymart GP, LLC Membership Interest 100% Waymart Wind Farm L.P. Partnership Interest 1 % FPL Energy Waymart LP, LLC Membership Interest 100% Waymart Wind Farm L.P. Partnership Interest 99% Meyersdale Windpower, LLC Membership Interest 100 % ESI Vansycle LP, Inc. Common 100% ESI Vansycle Partners, L.P. Partnership Interest 99 % ESI Vansycle GP, Inc. Common 100% ESI Vansycle Partners, L.P. Partnership Interest 1 % FPL Energy Solar Partners 111-VII, LLC Membership Interest 100 % High Point Wind, LLC Membership Interest 100 % FPL Energy Texas, LLC Membership Interest 100 % NextEra Energy Duane Arnold, LLC Membership Interest 100% Page 454 B-7 FPL Energy Tyler Texas LP, LLC Membership Interest 100 % Delaware Mountain Wind Farm, LLC Membership Interest 100% FPL Energy Pecos Wind I, LLC Membership Interest 100% FPL Energy Pecos Wind II, LLC Membership Interest 100 % Indian Mesa Wind Farm, LLC Membership Interest 100 % Lamar Power Partners II, LLC Membership Interest 100 % La Frontera Ventures, LLC Percentage Ownership Interest 100% La Frontera Holdings, LLC Percentage Ownership Interest 100% La Frontera Generation, LLC Percentage Ownership Interest 100 % FPLE Forney Pipeline, LLC Membership Interest 100% FPLE Forney, LLC Membership Interest 100% LamarPowerPartne~,LLC Membership Interest 100% FPL Energy Texas Wind Marketing GP, LLC Membership Interest 100 % FPL Energy Texas Wind Marketing LP Partnership Interest 1 % FPL Energy Texas Wind Marketing LP, LLC Membership Interest 100 % FPL Energy Texas Wind Marketing LP Partnership Interest 99 % FPL Energy Texas Keir, LLC Membership Interest 100 % Page 454 B-8 Bison Wind LP, LLC Membership Interest 100 % Bison Wind Investments, LLC Membership Interest 99 % Bison Wind Portfolio, LLC Membership Interest 100 % Bison Wind Holdings, LLC Membership Interest 100% Bison Wind, LLC Membership Interest 100 % FPL Energy Cowboy Wind, LLC Membership Interest 100% FPL Energy Burleigh County Wind, LLC Membership Interest 100 % Bison Wind GP, LLC Membership Interest 100% Bison Wind Investments, LLC Membership Interest 1 % Peetz Energy, LLC Membership Interest 100% North American Power Systems Solar, LLC Membership Interest 100 % Osceola Windpower, LLC Membership Interest 100% NextEra Energy Point Beach, LLC Membership Interest 100 % EFB Constructors, LLC Membership Interest 100 % Northern Frontier Wind Holding, LLC Membership Interest 100 % Northern Frontier Wind Funding, LLC Membership Interest 100 % Northern Frontier Wind, LLC Class A Membership Interest 100% Page 454 B-9 FPL Energy Mower County, LLC Membership Interest 100 % Peetz Table Wind Energy, LLC Membership Interest 100% Peetz Table Transmission Line, LLC Membership Interest 100% Peetz Logan Interconnect, LLC Membership Interest 50 % FPL Energy Oliver Wind II, LLC Membership Interest 100% Logan Energy Holdings, LLC Membership Interest 100% Logan Connect LLC Membership Interest 100% Peetz Logan Interconnect, LLC Membership Interest 50 % Logan Wind Energy LLC Membership Interest 100% FPL Energy Oliver Wind I, LLC Membership Interest 100% Crystal Lake Wind II, LLC Membership Interest 100 % Foxtail Wind, LLC Membership Interest 100 % NextEra Energy Services Holdings, LLC Membership Interest 100% GEXA Energy GP, LLC Membership Interest 100 % Gexa Energy, LP Partnership Interest 1 % Gexa Energy Solutions, LLC Percentage Ownership Interest 100 % Page 454 B-1 0 NextEra Energy Services, LLC Membership Interest 100% Gexa Energy, LP Partnership Interest 99 % NextEra Energy Services New York, LLC Membership Interest 100 % NextEra Energy Services Connecticut, LLC Membership Interest 100 % NextEra Energy Services Illinois, LLC Membership Interest 100 % NextEra Energy Services Maryland, LLC Membership Interest 100 % NextEra Energy Services New Jersey, LLC Membership Interest 100% NextEra Energy Services District of Columbia, LLC Membership Interest 100 % NextEra Energy Services Rhode Island, LLC Membership Interest 100 % NextEra Energy Services New Hampshire, LLC Membership Interest 100 % NextEra Energy Services Pennsylvania, LLC Membership Interest 100 % NextEra Energy Services Delaware, LLC Membership Interest 100% NextEra Energy Services Ohio, LLC Membership Interest 100 % NextEra Energy Services Massachusetts, LLC Membership Interest 100 % Gexa Energy California, LLC Percentage Ownership Interest 100% NextEra Energy Services Maine, LLC Percentage Ownership Interest 100 % NextEra Energy Services Arizona, LLC Percentage Ownership Interest 100 % Page 454 B-11 NextEra Energy Solutions, LLC Percentage Ownership Interest 100% ESI Sierra, Inc. Common 100% Western Wind Holdings, LLC Membership Interest 100 % ESI Ebensburg, Inc. Common 100% ESI Victory, Inc. Common 100% FPL Energy VG Wind, LLC Membership Interest 50 % ESI Bay Area, Inc. Common 100% Wlndpower Partne-rs 1991, l.P. Partnership Interest 99 % KW San Gorgonio Transmission, Inc. Common 100% Altamont Infrastructure Company LLC Membership Interest 11.83% U. S. Windpower Transmission Corporation Common 100% Windpower Partners 1990, l.P. Partnership Interest 99 % Altamont Infrastructure Company LLC Membership Interest 6.74% Windpower Partners 1991-2, l.P. Partnership Interest 99 % Altamont Infrastructure Company LLC Membership Interest 13.84% Windpower Partners 1992, l.P. Partnership Interest 99% Altamont Infrastructure Company LLC Membership Interest 12.3% Page 454 B-12 Hyperion VIII, Inc. Common 100% _ Luz Solar Partners Ltd., VIJJ Partnership Interest 49.9 % Harper Lake Company Vlll Common 100% Luz Solar Partners Ltd., Vlll Partnership Interest 0.1 % ESI California Holdings, Inc. Common 100% FPL Energy Green Power Wind, LLC Percentage Ownership Interest 100% Hyperion IX, Inc. Common 100% Luz Solar Partners Ltd., IX Partnership Interest 49 % HLC IX Company Common 100% Luz Solar Partners Ltd., IX Partnership Interest 1 % ESI Bay Area GP, Inc. Common 100% Wind power Partners 1991, L.P. Partnership Interest 1 % Windpower Partners 1990, L.P. Partnership Interest 1 % Windpower Partners 1991-2, L.P. Partnership Interest 1 % Windpower Partners 1992, L.P. Partnership Interest 1 % ESI Altamont Acquisitions, Inc. Common 100% Green Ridge Power LLC Membership Interest 100 % Page 454 B-13 -------- - ~~-- - ---- USW Land Corporation Common 100% Altamont Infrastructure Company LLC Membership Interest 8.97 % ESI Mojave, Inc. Common 100% ESI Mojave LLC Membership Interest 1 % ESI Tehachapi Acquisitions, Inc. Common 100% WindCo LLC Membership Interest 100% Altamont Power LLC Membership Interest 100 % ESI Northeast Energy GP, Inc. Common 100% Northeast Energy, LP Partnership Interest 1 % Northeast Energy, LLC Membership Interest 100% North Jersey Energy Associates, A Limited Partnership Partnership Interest 1 % ESI Tractebel Urban Renewal Corporation Common 100% Northeast Energy Associates, A Limited Partnership Partnership Interest 1 % North Jersey Energy Associates, A Limited Partnership Partnership Interest 99% Northeast Energy Associates, A Limited Partnership Partnership Interest 99% Northern Cross Investments, Inc. Common 100% Sullivan Street Investments, Inc. Common 100% Page 454 8-14 GR Bage (FL), Inc. Common 100% ESI Northeast Fuel Management, Inc. Common 100% FPL Energy Solar Funding Corp. Common 100% Harper Lake Solar Funding Corporation Common 50% Wind Holdings, Inc. Common Stock 100 % Windlogics Inc. Common 100% Beacon Solar, LLC Percentage Ownership Interest 100% Osceola Windpower II, LLC Membership Interest 100% Northern Colorado Wind Holdings, LLC Membership Interest 100 % Centennial Wind Holdings, LLC Percentage Ownership Interest 100 % Centennial Wind Funding, LLC Percentage Ownership Interest 100 % Centennial Wind, LLC Class A Membership Interest 100% Limon Wind, LLC Percentage Ownership Interest 100 % Limon Wind II, LLC Percentage Ownership Interest 100 % Centennial Wind Class B, LLC Percentage Ownership Interest 100 % Carousel Wind Holdings, LLC Percentage Ownership Interest 100% Carousel Wind Farm, LLC Class A Units 100% Page 454 B-15 Golden West Wind Holdings, LLC Percentage Ownership Interest 100% Golden West Power Partners, LLC Class A Membership Interest 100 % Limon Wind Ill Funding, LLC Percentage Ownership Interest 100 % Limon Wind Ill Holdings, LLC Percentage Ownership Interest 100 % Limon Wind Ill, LLC Class A Membership Interest 100 % Generation Repair and Service, LLC Membership Interest 100% Blue Summit Generation Tie, LLC Membership Interest 100 % PWEC, LLC Membership Interest 100 % Legacy Renewables Holdings, LLC Membership Interest 100% Legacy Renewables, LLC Membership Interest 100% Mill Run Windpower LLC Membership Interest 100% Somerset Wind power LLC Membership Interest 100 % FPL Energy Cabazon Wind, LLC Percentage Ownership Interest 100% Diablo Winds, LLC Membership Interest 100% FPL Energy Upton Wind II, LLC Membership Interest 100 % FPL Energy Upton Wind Ill, LLC Membership Interest 100% FPL Energy Upton Wind IV, LLC Membership Interest 100% Page 454 B-16 FPL Energy Upton Wind I, LLC Membership Interest 100% Sky River LLC Percentage Ownership Interest 100% Sagebrush Partner Fifteen, Inc. Common 100% Sagebrush Partnership Interest 17.546491 % Sky River Asset Holdings, LLC Percentage Ownership Interest 100% Lee North, LLC Percentage Ownership Interest 100 % FPL Energy Illinois Wind, LLC Membership Interest 100% Pennsylvania Windfarrns, LLC Percentage Ownership Interest 100 % NextEra Energy Operating Services, LLC Percentage Ownership Interest 100 % Crystal Lake Wind Ill, LLC Percentage Ownership Interest 100 % South Texas Gen-Tie Holding, LLC Percentage Ownership Interest 100 % South Texas Gen-Tie, LLC Percentage Ownership Interest 100% FPL Energy Texas Wind GP, LLC Membership Interest 100% FPL Energy Texas Wind Holdings, LP Partnership Interest 0.1 % FPL Energy Texas Wind, LP Partnership Interest 99.9 % FPL Energy Callahan Wind GP, LLC Membership Interest 100 % FPL Energy Callahan Wind, LP Percentage Ownership Interest 1 % Page 454 8-17 ----------- -- ---- FPL Energy Callahan Wind LP, LLC Membership Interest 100 % FPL Energy Callahan Wind, LP Percentage Ownership Interest 99 % FPL Energy Horse Hollow Wind, LLC Membership Interest 100% FPL Energy Texas Wind, LP Partnership Interest 0.1 % Lone Star Wind Holdings, LLC Membership Interest 100 % Lone Star Wind, LLC Membership Interest 100% FPL Energy Post Wind GP, LLC Membership Interest 100% Post Wind Farm LP Partnership Interest 1 % FPL Energy Post Wind LP, LLC Membership Interest 100 % Post Wind Farm LP Partnership Interest 99 % FPL Energy Horse Hollow Wind II, LLC Membership Interest 100 % West Texas Wind, LLC Percentage Ownership Interest 100 % FPL Energy Texas Wind Holdings, LP Partnership Interest 99.9% Horse Hollow Generation Tie Holdings, LLC Percentage Ownership Interest 100 % Horse Hollow Generation Tie, LLC Membership Interest 100 % Sentry Solar, LLC Percentage Ownership Interest 100% Mantua Creek Solar, LLC Percentage Ownership Interest 100% Page 454 B-18 Sonoran Solar Energy, LLC Percentage Ownership Interest 100% Vansycle Ill Wind, LLC Percentage Ownership Interest 100% Oliver Wind Ill, LLC Percentage Ownership Interest 100% Iowa Clean Energy Express, LLC Percentage Ownership Interest 100% Peace Garden Wind Holdings, LLC Percentage Ownership Interest 100 % Peace Garden Wind Funding, LLC Percentage Ownership Interest 100 % Peace Garden Wind, LLC Class A Membership Interest 100 % Wilton Wind II, LLC Membership Interest 100% Ashtabula Wind II, LLC Membership Interest 100 % Day County Wind II, LLC Percentage Ownership Interest 100 % Osborn Wind Energy, LLC Percentage Ownership Interest 100% Paradise Solar Urban Renewal, L.L.C. Percentage Ownership Interest 100 % ESI Northeast Energy LP, LLC Percentage Ownership Interest 100 % Northeast Energy, LP Partnership Interest 49 % FPL Tel, LLC Membership Interest 100 % North American Power Systems, LLC Percentage Ownership Interest 100 % NAPS Wind, LLC Percentage Ownership Interest 100% Page 454 B-19 NextEra Energy New Mexico Operating Services, LLC Membership Interest 100 % New Mexico Energy Investments, LLC Membership Interest 98 % FPL Energy New Mexico Wind Holdings II, LLC Membership Interest 100 % FPL Energy New Mexico Wind II, LLC Percentage Ownership Interest 100 % FPL Energy New Mexico Wind Financing, LLC Percentage Ownership Interest 100 % FPL Energy New Mexico Holdings, LLC Membership Interest 100 % FPL Energy New Mexico Wind, LLC Percentage Ownership Interest 100% Pacific Power Investments, LLC Membership Interest 100% New Mexico Wind Investments, LLC Membership Interest 99 % New Mexico Energy Investments, LLC Membership Interest 1 % Red Mesa Wind Investments, LLC Percentage Ownership Interest 100 % Red Mesa Wind, LLC Percentage Ownership Interest 100% Ensign Wind, LLC Percentage Ownership Interest 100 % NextEra Energy Honey Creek Wind, LLC Percentage Ownership Interest 100 % Sonoran Solar Energy I, LLC Percentage Ownership Interest 100 % Lucerne Solar, LLC Percentage Ownership Interest 100 % Wild Prairie Wind Holdings, LLC Percentage Ownership Interest 100 % Page 454 B-20 Wild Prairie Wind, LLC Percentage Ownership Interest 100 % Garden Wind, LLC Membership Interest 100 % Day County Wind, LLC Percentage Ownership Interest 100% Southwest Solar Holdings, LLC Percentage Ownership Interest 100 % Hatch Solar Energy Center I LLC Percentage Ownership Interest 100 % HWFII, LLC Percentage Ownership Interest 100 % Heartland Wind Funding, LLC Class A Membership Interest 100% Heartland Wind Holding, LLC Membership Interest 100 % Heartland Wind, LLC Membership Interest 100 % Crystal Lake Wind, LLC Membership Interest 100% Langdon Wind, LLC Membership Interest 100% Elk City II Wind Holdings, LLC Percentage Ownership Interest 100% Elk City II Wind, LLC Percentage Ownership Interest 100% Watonga Wind, LLC Percentage OWnership Interest 100 % Penta Wind Holding, LLC Percentage Ownership Interest 100 % Penta Wind, LLC Class A Membership Interest 100% Heartland Wind Holding II, LLC Percentage Ownership Interest 100 % Page 454 B-21 Heartland Wind II, LLC Percentage Ownership Interest 100% Ashtabula Wind, LLC Membership Interest 100% Story Wind, LLC Membership Interest 100% Central States Wind Holdings, LLC Percentage Ownership Interest 100% Central States Wind, LLC Percentage Ownership Interest 100 % Wessington Wind Energy Center, LLC Percentage Ownership Interest 100 % High Majestic Wind Energy Center, LLC Percentage Ownership Interest 100 % High Majestic Interconnection Services, LLC Percentage Ownership Interest 50% Butler Ridge Wind Energy Center, LLC Percentage Ownership Interest 100% Elk City Wind Holdings Ill, LLC Percentage Ownership Interest 100% Elk City Wind Ill, LLC Percentage Ownership Interest 100 % Redwood Trails Wind Holdings, LLC Percentage Ownership Interest 100 % Redwood Trails Wind, LLC Percentage Ownership Interest 100 % FPL Energy Montezuma Wind, LLC Membership Interest 100 % Minco Redwood Holdings, LLC Percentage Ownership Interest 100 % Minco Wind, LLC Percentage Ownership Interest 100% Minco Wind II, LLC Percentage Ownership Interest 100% Page 454 B-22 Minco Wind Interconnection Services, LLC Percentage Ownership Interest 100 % NextEra Energy Bluff Point, LLC Percentage Ownership Interest 100 % White Oak Energy Backleverage Holding, LLC Percentage Ownership Interest 100 % White Oak Energy Funding Holding, LLC Percentage Ownership Interest 100 % White Oak Energy Funding, LLC Class A Membership Interest 100 % White Oak Energy Holdings, LLC Percentage Ownership Interest 100 % White Oak Energy LLC Percentage Ownership Interest 100% White Oak B Company, LLC Percentage Ownership Interest 100 % Energy Storage Holdings, LLC Percentage Ownership Interest 100 % Wilton Wind IV, LLC Percentage Ownership Interest 100 % North Sky River Land Holdings, LLC Percentage Ownership Interest 100% Buffalo Ridge Wind Energy, LLC Percentage Ownership Interest 100% NextEra Desert Sunlight Holdings, LLC Percentage Ownership Interest 100 % Desert Sunlight Investment Holdings, LLC Class A Membership Interest 100 % Desert Sunlight Holdings, LLC Percentage Ownership Interest 100 % Desert Sunlight 250, LLC Percentage Ownership Interest 100% Desert Sunlight 300, LLC Percentage Ownership Interest 100% Page 454 B-23 Capricorn Ridge Wind Funding, LLC Percentage Ownership Interest 100 % Capricorn Ridge Wind Holdings, LLC Class A Membership Interest 100% Capricorn Ridge Wind II, LLC Membership Interest 100 % Capricorn Ridge Wind, LLC Membership Interest 100 % Capricorn Ridge Power Seller, LLC Percentage Ownership Interest 100% Golden Winds Funding, LLC Percentage Ownership Interest 100 % Golden Winds Holdings, LLC Percentage Ownership Interest 100% Golden Winds, LLC Class A Membership Interest 100 % Vasco Winds, LLC Membership Interest 100 % NextEra Energy Montezuma II Wind, LLC Percentage Ownership Interest 100 % Wlndpower Partners 1993, LLC Percentage Ownership Interest 100% FPLE Rhode Island State Energy GP, LLC Percentage Ownership Interest 100 % Capricorn Ridge 8 Holdings, LLC Percentage Ownership Interest 100% Capricorn Ridge 8, LLC Percentage Ownership Interest 100 % Capricorn Ridge Wind Holdings, LLC Class B Membership Interest 25.580472 % Watkins Glen Wind, LLC Percentage Ownership Interest 100% Sirius Solar, LLC Percentage Ownership Interest 100 % Page 454 B-24 Tuscola Wind II, LLC Percentage Ownership Interest 100% High Majestic II Funding, LLC Percentage Ownership Interest 100 % High Majestic II Holdings, LLC Percentage Ownership Interest 100% High Majestic II Wind Properties, LLC Class A Membership Interest 100% High Majestic Wind II, LLC Percentage Ownership Interest 100 % High Majestic Interconnection Services, LLC Percentage Ownership Interest 50% Cimarron Wind Energy Holdings, LLC Percentage Ownership Interest 100 % Cimarron Wind Energy Holdings II, LLC Percentage Ownership Interest 100% Cimarron Wind Energy, LLC Percentage Ownership Interest 1 % Cimarron Wind Energy, LLC Percentage Ownership Interest 99% NextEra Energy Victory Solar I, LLC Percentage Ownership Interest 100 % Victory Renewables, LLC Percentage Ownership Interest 100% NextEra Energy Solar Holdings, LLC Percentage Ownership Interest 100 % NextEra Energy Resources Acquisitions, LLC Percentage Ownership Interest 100 % Aries Solar Holding, LLC Percentage Ownership Interest 100 % Joshua Tree Solar Farm, LLC Percentage Ownership Interest 100 % Whitney Point Solar, LLC Percentage Ownership Interest 100 % Page 454 B-25 Westside Solar, LLC Percentage Ownership Interest 100% Jacumba Solar, LLC Percentage Ownership Interest 100% San Jacinto Solar 5.5, LLC Percentage Ownership Interest 100% San Jacinto Solar 14.5, LLC Percentage Ownership Interest 100 % Shafter Solar SeiiCo, LLC Percentage Ownership Interest 100% Pheasant Run Wind Holdings, LLC Percentage Ownership Interest 100 % Pheasant Run Wind, LLC Percentage Ownership Interest 100 % Porta del Sol Solar, LLC Percentage Ownership Interest 100 % North Coast Solar, LLC Percentage Ownership Interest 100% Moca Solar Farm, LLC Percentage Ownership Interest 100% Cabo Solar Farm, LLC Percentage Ownership Interest 100 % Cottonwood Wind Project Holdings, LLC Percentage Ownership Interest 100 % Cottonwood Wind Project, LLC Percentage Ownership Interest 100 % Pioneer Plains Wind Funding, LLC Percentage Ownership Interest 100% Pioneer Plains Wind Holdings, LLC Percentage Ownership Interest 100 % Pioneer Plains Wind, LLC Class A Membership Interest 100% Minco Wind III, LLC Percentage Ownership Interest 100% Page 454 8-26 Blackwell Wind, LLC Percentage Ownership Interest 100% DG 1, LLC Percentage Ownership Interest 100 % DG 1 Acquisition Co., LLC Percentage Ownership Interest 100 % Smart Energy Capital, LLC Percentage Ownership Interest 100 % lakeco Holding, LLC Percentage Ownership Interest 100% SEC Amherst Solar One, LLC Percentage Ownership Interest 100 % SEC ESSD Solar One, LLC Percentage Ownership Interest 100 % SEC PASO Solar One, LLC Percentage Ownership Interest 100% SEC MC Solar One, LLC Percentage Ownership Interest 100 % SEC SUSD Solar One, LLC Percentage Ownership Interest 100% SEC CRSD Solar One, LLC Percentage Ownership Interest 100% SEC HSD Solar One, LLC Percentage Ownership Interest 100 % SEC LHNY Solar One, LLC Percentage Ownership Interest 100% SEC Northeast Solar One, LLC Percentage Ownership Interest 100% DG BP Solar One, LLC Percentage Ownership Interest 100 % DG Woodbury Solar, LLC Percentage Ownership Interest 100 % DG Somerdale Solar, LLC Percentage Ownership Interest 100% DG Bethlehem Solar, LLC Page 454 B-27 Percentage Ownership Interest 100% Trenton Diocese DG Solar, LLC Percentage Ownership Interest 100 % HCSD Solar, LLC Percentage Ownership Interest 100 % BCSD Solar, LLC Percentage Ownership Interest 100 % LCSD Solar 1, LLC Percentage Ownership Interest 100% LCSD Solar 2, LLC Percentage Ownership Interest 100% UC Solar, LLC Percentage Ownership Interest 100% M Greece Ridge Solar, LLC Percentage Ownership Interest 100 % M Boulevard Solar, LLC Percentage Ownership Interest 100% M Cross County Solar, LLC Percentage OWnership Interest 100 % M Queens Rego Solar, LLC Percentage Ownership Interest 100% M White Plains Solar, LLC Percentage Ownership Interest 100 % M Nanuet Solar, LLC Percentage Ownership Interest 100% HD Hatlllo Solar One, LLC Percentage Ownership Interest 100 % SDGF 1 Funding, LLC Percentage Ownership Interest 100% Solar DG Fund 1 Holdings, LLC Percentage Ownership Interest 100 % Page 454 B-28 NextEra Solar DG Fund I, LLC Percentage Ownership Interest 100 % Zuni Solar, LLC Percentage Ownership Interest 100 % Venable Solar, LLC Percentage Ownership Interest 100 % DG Irvine Solar I, LLC Percentage Ownership Interest 100 % Morongo DG Solar, LLC Percentage Ownership Interest 100 % NY Sun DG Solar, LLC Percentage Ownership Interest 100 % NY Sun Zone C2 LLC Percentage Ownership Interest 100 % NY Sun Zone E3 LLC Percentage Ownership Interest 100 % NY Sun Zone E4 LLC Percentage Ownership Interest 100% NY Sun Zone F3 LLC Percentage Ownership Interest 100% NY Sun Zone F4 LLC Percentage Ownership Interest 100 % La Palma DG Solar, LLC Percentage Ownership Interest 100% Oneida DG Solar, LLC Percentage Ownership Interest 100% DG Monmouth, LLC Percentage Ownership Interest 100 % DG Moorestown, LLC Percentage Ownership Interest 100% DG Willowbrook, LLC Percentage Ownership Interest 100% DG Cherry Hill, LLC Percentage Ownership Interest 100% Page 454 8-29 DG Pearl City, LLC Percentage Ownership Interest 100% Old Mill Solar, LLC Percentage Ownership Interest 100 % DG North Carolina Solar Holding, LLC Percentage Ownership Interest 100% DG Walplo, LLC Percentage Ownership Interest 100 % ' Pacific Energy Solutions, LLC Percentage Ownership Interest 100 % DG CSU Solar, LLC Percentage Ownership Interest 100% DG Clean Energy Solutions, LLC Percentage Ownership Interest 100% DG SUNY Solar 1, LLC Percentage Ownership Interest 100 % EW Solar, LLC Percentage Ownership Interest 100 % M Schenectady Solar, LLC Percentage Ownership Interest 100% NY Sun Zone C3 LLC Percentage Ownership Interest 100% NY Sun Zone E1 LLC Percentage Ownership Interest 100 % NY Sun Zone E2 LLC Percentage Ownership Interest 100% NY Sun Zone F1 LLC Percentage Ownership Interest 100 % NY Sun Zone F2 LLC Percentage Ownership Interest 100% DG CID Solar, LLC Percentage Ownership Interest 100 % DG Minnesota CSG 1, LLC Percentage Ownership Interest 100 % Page 454 B-30 DG Minnesota CSG 9, LLC Percentage Ownership Interest 100 % DG Minnesota CSG 10, LLC Percentage Ownership Interest 100 % DG Minnesota CSG 8, LLC Percentage Ownership Interest 100 % DG Minnesota CSG 7, LLC Percentage Ownership Interest 100 % DG Minnesota CSG 6, LLC Percentage Ownership Interest 100% DG Minnesota CSG 5, LLC Percentage Ownership Interest 100 % DG Minnesota CSG 4, LLC Percentage Ownership Interest 100% DG Minnesota CSG 3, LLC Percentage Ownership Interest 100 % DG Minnesota CSG 2, LLC Percentage Ownership Interest 100% DG Newark, LLC Percentage Ownership Interest 100% Old Mill Holdings, LLC Percentage Ownership Interest 100 % DG HD Hawaii, LLC Percentage Ownership Interest 100% DG North Carolina Solar Ventures, LLC Percentage Ownership Interest 100% NextEra Energy DG Operations, LLC Percentage Ownership Interest 100 % DG Residential Acquisition Co., LLC Percentage Ownership Interest 100 % DG Project Construction Co., LLC Percentage Ownership Interest 100 % Oklahoma Wind Portfolio, LLC Percentage Ownership Interest 100 % Page 454 8-31 Pheasant Run Wind Holdings II, LLC Percentage Ownership Interest 100% North Sky River Energy Holdings, LLC Percentage Ownership Interest 100% North Sky River Energy, LLC Percentage Ownership Interest 100% NextEra Energy Mt. Storm, LLC Percentage Ownership Interest 100 % Blue Summit II Wind, LLC Percentage OWnership Interest 100 % Silver State South Solar, LLC Percentage Ownership Interest 100 % Silver State Solar Power South, LLC Percentage Ownership Interest 100% Legends Wind Funding, LLC Percentage Ownership Interest 100 % Legends Wind Holdings, LLC Percentage Ownership Interest 100 % Legends Wind, LLC Class A Membership Interest 100 % Steele Flats Wind Project, LLC Percentage Ownership Interest 100 % Legends Wind Class B, LLC Percentage Ownership Interest 100% ESI VG IV, LLC Percentage Ownership Interest 100% Red River Wind Funding, LLC Percentage Ownership Interest 100 % Red River Wind Holdings, LLC Percentage Ownership Interest 100 % Red River Wind, LLC Class A Membership Interest 100 % Wolf Ridge Wind, LLC Membership Interest 100 % Page 454 8-32 Blue Summit Wind, LLC Membership Interest 100 % NWE Holding, LLC Percentage Ownership Interest 100% Novus Wind VI, LLC Percentage Ownership Interest 100% Long Island Energy Generation, LLC Percentage Ownership Interest 100 % Long Island Energy Storage Holdings, LLC Percentage Ownership Interest 100% Ll Energy Storage System, LLC Percentage Ownership Interest 50 % Long Island Solar Holdings, LLC Percentage Ownership Interest 100 % Ll Solar Generation, LLC Percentage Ownership Interest 50% Long Island Peaker Holdings, LLC Percentage Ownership Interest 100% Clean Energy Generation, LLC Percentage Ownership Interest 50 % Barrett Repowering, LLC Percentage Ownership Interest 100 % Island Park Energy Center, LLC Percentage Ownership Interest 50 % Prairie View Wind Holdings, LLC Percentage Ownership Interest 100 % Ninnescah Wind Energy LLC Percentage Ownership Interest 100% Niyol Wind, LLC Percentage Ownership Interest 100% Mountain VIew Solar Holdings, LLC Percentage Ownership Interest 100% Mountain View Solar, LLC Percentage Ownership Interest 100% Page 454 B-33 NextEra Energy Resources Partners Holdings, LLC Percentage Ownership Interest 100 % NextEra Energy Resources Partners, LLC Percentage Ownership Interest 100 % NextEra Energy Management Partners GP, LLC Percentage Ownership Interest 100% NextEra Energy Management Partners, LP General Partnership Interest 100 % NextEra Energy Partners GP, Inc. Common 100% NextEra Energy Partners, LP General Partnership Interest 100 % NextEra Energy Operating Partners GP, LLC Percentage Ownership Interest 100 % NextEra Energy Operating Partners, LP General Partnership Interest 100% NextEra Energy US Partners Holdings, LLC Percentage Ownership Interest 100% Mountain Prairie Wind Holdings, LLC Percentage OWnership Interest 100 % Mountain Prairie Wind, LLC Percentage Ownership Interest 100% Northern Colorado Wind Energy, LLC Membership Interest 100 % Canyon Wind Holdings, LLC Percentage Ownership Interest 100 % Canyon Wind, LLC Percentage Ownership Interest 100% Perrin Ranch Wind, LLC Percentage Ownership Interest 100% Tuscola Bay Wind, LLC Percentage Ownership Interest 100 % Genesis Solar Funding Holdings, LLC Percentage Ownership Interest 100 % Page 454 B-34 Genesis Solar Funding, LLC Percentage Ownership Interest 100% Genesis Solar Holdings, LLC Percentage Ownership Interest 100% Genesis Solar, LLC Membership Interest 100% NextEra Desert Center Blythe, LLC Percentage Ownership Interest 50 % Elk City Wind Holdings, LLC Percentage Ownership Interest 100% Elk City Wind, LLC Percentage Ownership Interest 100 % Shafter Solar Holdings, LLC Percentage Ownership Interest 100% Shafter Solar, LLC Percentage Ownership Interest 100 % Palo Duro Wind Portfolio, LLC Percentage Ownership Interest 100% Palo Duro Wind Project Holdings, LLC Percentage Ownership Interest 100 % Palo Duro Wind Energy, LLC Class A Membership Interest 100 % Palo Duro Wind Interconnection Services, LLC Percentage Ownership Interest 88% NextEra Energy Partners Solar Acquisitions, LLC Percentage Ownership Interest 100% McCoy Solar Holdings, LLC Percentage Ownership Interest 50.01 % McCoy Solar Funding, LLC Percentage Ownership Interest 100 % McCoy Solar, LLC Percentage Ownership Interest 100% NextEra Desert Center Blythe, LLC Percentage Ownership Interest 50% Page 454 B-35 Adelanto Solar Funding, LLC Percentage Ownership Interest 50.01 % Adelanto Solar Holdings, LLC Percentage Ownership Interest 100% Adelanto Solar, LLC Percentage Ownership Interest 100 % Adelanto Solar II, LLC Percentage Ownership Interest 100% NextEra Energy Partners Acquisitions, LLC Percentage Ownership Interest 100% Baldwin Wind Holdings, LLC Percentage Ownership Interest 100 % Baldwin Wind, LLC Percentage Ownership Interest 100 % Mammoth Plains Wind Project Holdings, LLC Percentage Ownership Interest 100 % Mammoth Plains Wind Project, LLC Class A Membership Interest 100% Meadowlark Wind Holdings, LLC Percentage Ownership Interest 100 % Meadowlark Wind, LLC Percentage Ownership Interest 100% FPL Energy Stateline Holdings, L.L.C. Percentage Ownership Interest 100% FPL Energy Vansycle L.L.C. Membership Interest 100 % Ashtabula Wind Ill, LLC Percentage Ownership Interest 100 % NextEra Energy Partners Ventures, LLC Percentage Ownership Interest 100 % NET Holdings Management, LLC Percentage Ownership Interest 100 % NET Midstream, LLC Percentage Ownership Interest 100 % Page 454 B-36 NET Pipeline Holdings LLC Percentage Ownership Interest 100% Monument Pipeline, LP Percentage Ownership Interest 99.9% Mission Natural Gas Company, LP Percentage Ownership Interest 99.9% South Shore Pipeline L.P. Percentage Ownership Interest 99.9% Mission Valley Pipeline Company, LP Percentage Ownership Interest 99.9% LaSalle Pipeline, LP Percentage OWnership Interest 99.9% NET Mexico Pipeline, LP Percentage Ownership Interest 99.9 % NET Mexico Pipeline Partners, LLC Percentage Ownership Interest 90 % Red Gate Pipeline, LP Percentage Ownership Interest 99.9% Eagle Ford Midstream, LP Percentage Ownership Interest 99.9 % NET General Partners, LLC Percentage Ownership Interest 100 % Monument Pipeline, LP Percentage Ownership Interest 0.1 % Mission Natural Gas Company, LP Percentage Ownership Interest 0.1 % South Shore Pipeline L.P. Percentage Ownership Interest 0.1 % Mission Valley Pipeline Company, LP Percentage Ownership Interest 0.1 % LaSalle Pipeline, LP Percentage Ownership Interest 0.1 % NET Mexico Pipeline, LP Percentage Ownership Interest 0.1 % Page 454 8-37 Red Gate Pipeline, LP Percentage Ownership Interest 0.1 % Eagle Ford Midstream, LP Percentage Ownership Interest 0.1 % NextEra Energy Canada Partners Holdings, ULC Common 100% Trillium Funding GP Holding, Inc. Common Stock 100% Trillium Funding GP, Inc. Common Stock 100% Trillium Windpower, LP Percentage Ownership Interest 0.01 % Conestoga Wind GP,Inc. Common 100% Conestoga Wind, LP Partnership Interest 0.01 % Strathroy Wind GP, Inc. Common 100% Summerhaven Wind, LP Percentage Ownership Interest 0.01 % Conestoga Wind, LP Partnership Interest 99.99% Summerhaven Wind, LP Percentage Ownership Interest 99.99 % Trillium HoldCo GP, Inc. Common Stock 100 % Trillium HoldCo, LP Percentage Ownership Interest 0.01 % Trillium Wind Holdings, LP Percentage Ownership Interest 99.99% Trillium Windpower, LP Percentage Ownership Interest 99.99% Trillium Wind Holdings, LP Percentage Ownership Interest 0.01 % Page 454 B-38 Trillium HoldCo, LP Percentage Ownership Interest 99.99% St. Clair MS Investment GP, LLC Percentage Ownership Interest 100% SCIH GP, ULC Common Stock 100 % St. Clair Investment Holding, LP Percentage Ownership Interest 0.0001 % SCI Holding, ULC Common 100% St. Clair Holding, ULC Common 100% St. Clair Moore Holding LP, LLC Percentage Ownership Interest 100% St. Clair Moore Holding LP, ULC Common Stock 100 % St. Clair Moore Holding, LP Percentage Ownership Interest 0.0001 % St. Clair GP, LLC Percentage Ownership Interest 100% St. Clair GP, ULC Common Stock 100 % St. Clair Solar, LP Percentage Ownership Interest 0.0001 % St. Clair Sombra Holding LP, LLC Percentage Ownership Interest 100% St. Clair Sombra Holding LP, ULC Common Stock 100 % St. Clair Sombra Holding, LP Percentage Ownership Interest 0.0001 % St. Clair Sombra Holding, LP Percentage Ownership Interest 99.9999 % Sombra Solar, ULC Common 100% Page 454 B-39 St. Clair Solar, LP Percentage Ownership Interest 49.99995% St. Clair Moore Holding, LP Percentage Ownership Interest 99.9999% Moore Solar, ULC Common 100% St. Clair Solar, LP Percentage Ownership Interest 49.99995 % Varna Wind Holdings GP, LLC Percentage Ownership Interest 100% Varna Wind Holdings GP, ULC Common Stock 100 % Varna Wind Holdings, LP Percentage Ownership Interest 0.0001 % Varna Wind Funding GP, LLC Percentage Ownership Interest 100 % Varna Wind Funding GP, ULC Common Stock 100% Varna Wind Funding, LP Percentage Ownership Interest 0.0001 % Varna Wind GP, LLC Percentage Ownership Interest 100% Varna Wind GP, ULC Common Stock 100% Varna Wind, LP Percentage Ownership Interest 99.9999 % Varna Wind, ULC Common Shares 100 % Varna Wind Funding, LP Percentage Ownership Interest 99.9999 % Varna Wind Holdings, LP Percentage Ownership Interest 99.9999% St. Clair Investment Holding, LP Percentage Ownership Interest 99.9999% Page 454 B-40 Jericho Wind BC Holdings, ULC Common 100% Jericho Wind Holdings GP, LLC Percentage Ownership Interest 100 % Jericho Wind Holdings GP, ULC Common Stock 100 % Jericho Wind Holdings, LP Percentage Ownership Interest 0.0001 % Jericho Wind Funding GP, LLC Percentage Ownership Interest 100% Jericho Wind Funding GP, ULC Common Stock 100% Jericho Wind Funding, LP Percentage Ownership Interest 0.0001 % Jericho Wind GP, LLC Percentage Ownership Interest 100 % Jericho Wind, LP Percentage OWnership Interest 99.9999 % Jericho Wind, ULC Class B Common 100 % Jericho Wind Funding, LP Percentage Ownership Interest 99.9999% Jericho Wind Holdings, LP Percentage Ownership Interest 99.9999% NextEra Energy Operating Partners, LP Limited Partnership Interest 23.167189 % NextEra Energy Equity Partners GP, LLC Percentage Ownership Interest 100% NextEra Energy Equity Partners, LP General Partnership Interest 100% NextEra Energy Partners, LP Special Voting LP Units 100% Page 454 B-41 NextEra Energy Operating Partners, LP Limited Partnership Interest 76.829327 % NextEra Energy Management Partners, LP Limited Partnership Interest 100% NextEra Energy Equity Partners, LP Limited Partner Class B Units 100 % Valencia Energy Storage, LLC Percentage Ownership Interest 100% Georgia Longleaf Solar 1, LLC Percentage Ownership Interest 100 % White Oak Solar, LLC Percentage Ownership Interest 100% Live Oak Solar, LLC Percentage Ownership Interest 100% White Pine Solar, LLC Percentage Ownership Interest 100 % Red Raider Wind Holdings, LLC Percentage Ownership Interest 100% Red Raider Wind, LLC Percentage Ownership Interest 100 % Ka La Nui Solar, LLC Percentage Ownership Interest 100 % Marshall Solar, LLC Percentage Ownership Interest 100 % Palo Duro Wind Energy II, LLC Percentage Ownership Interest 100% Palo Duro Wind Interconnection Services, LLC Percentage Ownership Interest 12% Whitewater Wind, LLC Percentage Ownership Interest 100% Palo Duro Wind Holdings SeiiCo, LLC Percentage Ownership Interest 100 % Page 454 B-42 Seiling Wind Holdings, LLC Percentage Ownership Interest 100 % Seiling Wind Portfolio, LLC Class A Membership Interest 100% Seiling Wind, LLC Percentage Ownership Interest 100 % Seiling Wind Interconnection Services, LLC Percentage Ownership Interest 67% Selling Wind II, LLC Percentage Ownership Interest 100 % Seiling Wind Interconnection Services, LLC Percentage Ownership Interest 33 % Solar Holdings SeiiCo, LLC Percentage Ownership Interest 100% McCoy Solar Holdings, LLC Percentage Ownership Interest 49.99% Adelanto Solar Funding, LLC Percentage Ownership Interest 49.99% Gateway Energy Center Holdings, LLC Percentage Ownership Interest 100 % Gateway Energy Center, LLC Membership Interest 100% River Bend Solar, LLC Percentage Ownership Interest 100 % Brady Wind, LLC Percentage Ownership Interest 100% Mt. Storm Wind Force Holdings, LLC Percentage Ownership Interest 100% Mt. Storm Wind Force, LLC Percentage Ownership Interest 100% Javelina Wind Holdings II, LLC Percentage Ownership Interest 100% Albercas Wind Energy II, LLC Percentage Ownership Interest 100 % Page 454 B-43 Javelina Interconnection, LLC Percentage Ownership Interest 45% Roswell Solar Holdings, LLC Percentage Ownership Interest 100 % Roswell Solar, LLC Percentage Ownership Interest 100 % Chaves County Solar Holdings, LLC Percentage Ownership Interest 100% Chaves County Solar, LLC Percentage Ownership Interest 100% Golden Hills North Wind, LLC Percentage Ownership Interest 100 % Golden Hills Interconnection, LLC Percentage Ownership Interest 32.4 % Bluebell Solar, LLC Percentage Ownership Interest 100 % NEP US SeiiCo, LLC Percentage Ownership Interest 100 % Battery Testing and Modeling, LLC Percentage Ownership Interest 100% EV Battery Storage, LLC Percentage Ownership Interest 100 % Stuttgart Solar, LLC Percentage Ownership Interest 100 % Meyersdale Storage, LLC Percentage Ownership Interest 100% Green Mountain Storage, LLC Percentage Ownership Interest 100 % Waymart Storage, LLC Percentage Ownership Interest 100% Tuscola Wind Ill, LLC Percentage Ownership Interest 100 % Rush Springs Wind Energy, LLC Percentage Ownership Interest 100% Page 454 B-44 Hale Wind Energy, LLC Percentage Ownership Interest 100 % Breckinridge Wind Funding, LLC Percentage Ownership Interest 100% Brecklnrldge Wind Holdings, LLC Percentage Ownership Interest 100% Breckinridge Wind Class A Holdings, LLC Percentage Ownership Interest 100% Breckinridge Wind Project, LLC Class A Membership 100 % Chaves County Solar Resources, LLC Percentage Ownership Interest 100 % Stark Wind, LLC Percentage Ownership Interest 100% Bayhawk Wind Funding, LLC Percentage Ownership Interest 100 % Bayhawk Wind Holdings, LLC Percentage Ownership Interest 100% Bayhawk Wind, LLC Class A Units 100 % Golden Hills Wind, LLC Percentage Ownership Interest 100% Golden Hills Interconnection, LLC Percentage Ownership Interest 67.6% Cedar Bluff Wind, LLC Percentage Ownership Interest 100 % Bayhawk Wind SeiiCo, LLC Percentage Ownership Interest 100% Golden Hills Energy Storage, LLC Percentage Ownership Interest 100 % Golden West Power Partners II, LLC Percentage Ownership Interest 100 % Chaves County Solar II Holdings, LLC Percentage Ownership Interest 100 % Page 454 B-45 Chaves County Solar II, LLC Percentage Ownership Interest 100% Blythe Solar Holdings, LLC Percentage Ownership Interest 100% Blythe Solar II, LLC Percentage Ownership Interest 100% NextEra Blythe Solar Energy Center, LLC Percentage Ownership Interest 25 % Blythe Solar 110, LLC Percentage Ownership Interest 100% NextEra Blythe Solar Energy Center, LLC Percentage Ownership Interest 25% Blythe Solar Ill, LLC Percentage Ownership Interest 100 % NextEra Blythe Solar Energy Center, LLC Percentage Ownership Interest 25% Blythe Solar IV, LLC Percentage Ownership Interest 100% NextEra Blythe Solar Energy Center, LLC Percentage Ownership Interest 25% South Texas Wind Holdings, LLC Percentage Ownership Interest 100 % South Texas Wind Energy, LLC Percentage Ownership Interest 100 % Javelina Wind Funding Holdings, LLC Percentage Ownership Interest 100 % Javelina Wind Funding, LLC Percentage Ownership Interest 100 % Javelina Wind Energy Holdings, LLC Percentage Ownership Interest 100% Javelina Wind Energy, LLC Percentage Ownership Interest 100 % Javelina Interconnection, LLC Percentage Ownership Interest 55% Page 454 B-46 Javelina Wind Class B, LLC Percentage Ownership Interest 100% Energy Storage Systems Holdings, LLC Percentage Ownership Interest 100 % Energy Storage Projects (Utility), LLC Percentage Ownership Interest 100 % Pima Energy Storage System, LLC Percentage Ownership Interest 100 % Energy Storage Projects (Distributed), LLC Percentage Ownership Interest 100% Distributed Energy Storage Associates, LLC Percentage Ownership Interest 100 % Brady Wind II, LLC Percentage Ownership Interest 100 % Mojave Red Venturez, LLC Percentage Ownership Interest 100 % Minco Wind IV, LLC Percentage Ownership Interest 100 % Crowned Ridge Wind, LLC Percentage Ownership Interest 100 % West Hills Wind, LLC Percentage Ownership Interest 100% Penobscot Wind, LLC Percentage Ownership Interest 100% Moose Wind, LLC Percentage Ownership Interest 100% Kingman Wind Holding I, LLC Percentage Ownership Interest 100% Kingman Wind Energy I, LLC Percentage Ownership Interest 100 % Kingman Wind Holding II, LLC Percentage Ownership Interest 100 % Kingman Wind Energy II, LLC Percentage Ownership Interest 100 % Page 454 B-47 KM Acquisitions, LLC Membership Interest 50% KM Acquisitions X GP, LLC Membership Interest 100 % KM Acquisitions XI GP, LLC Membership Interest 100 % KM Acquisitions XII GP, LLC Membership Interest 100% KM Acquisitions XIII GP, LLC Membership Interest 100 % FPL Group International, Inc. Common 100% High Ground Investments, LLC Membership Interest 100 % NextEra Energy Global Holdings Cooperatieve U.A. Percentage Ownership Interest 0.1 % NextEra Energy Global Holdings B.V. Authorized Share Capital 100 % NextEra Energy Canada Holdings B.V. Authorized Share Capital 100 % NextEra Energy Canada GP, LLC Percentage Ownership Interest 100 % NextEra Energy Canada, LP General Partnership Interest 100 % Aquila Holdings LP, ULC Class B Common 100 % Aquila LP, ULC Common 100% Mount Copper, LP Partnership Interest 99.99 % Pubnico Point, LP Partnership Interest 99.99% Pubnico Point Wind Farm Inc. Common 100% Page 454 B-48 Mount Copper, LP Partnership Interest 0.01 % Pubnico Point GP, Inc. Common 100% Pubnico Point, LP Partnership Interest 0.01 % NextEra Energy UCT Holding, Inc. Common 100% Upper Canada Transmission, Inc. Common Stock 50 % NextBridge Infrastructure LP General Partnership Interest 100 % CP II Holdings GP, Inc. Common Shares 100 % Cedar Point II GP Inc. Common 50% Cedar Point II Limited Partnership Percentage Ownership Interest 0.01 % NextEra Energy Equity Partners, LP Limited Partner Class A Units 100 % Mount Miller Holdings GP, LLC Percentage Ownership Interest 100 % Mount Miller Holdings GP, ULC Common Stock 100 % Mount Miller Holdings, LP Percentage Ownership Interest 0.0001 % Mount Miller Holdco, LLC Percentage Ownership Interest 100 % Mount Miller Holdco, ULC Common 100% 4263766 Canada Inc. Common 100% Mount Miller GP, ULC Class A Common 100 % Page 454 B-49 Mount Miller Wind Energy Limited Partnership Percentage Ownership Interest 0.01 % Mount Miller LP, ULC Common 100% Mount Miller Wind Energy Limited Partnership Percentage Ownership Interest 99.99% CP II CAD Holdings LP GP, LLC Percentage Ownership Interest 100 % CP II Holdings LP GP, ULC Common Stock 100% CP II Holdings, LP Percentage Ownership Interest 0.0001 % CP II Holdings LP, ULC Common 100% Cedar Point II Limited Partnership Percentage Ownership Interest 49.995% NextEra Energy NextBridge Holdings GP, LLC Percentage Ownership Interest 100 % NextEra Energy NextBridge Holdings GP, ULC Common Stock 100 % NextBridge Infrastructure LP Limited Partnership Units 50 % NextEra Energy Nextbridge Holdings, LP Percentage Ownership Interest 0.0001 % NextEra Energy NextBrldge Holding, ULC Common 100% Fortuna GP, LLC Percentage Ownership Interest 100 % Fortuna GP, ULC Common 100% Ghost Pine Windfarm, LP Percentage Ownership Interest 0.01 % NextEra Energy Canadian Holdings, ULC Common Stock 100 % Page 454 B-50 NextEra Energy Canadian Operating Services, Inc. Common 100% Boulevard Associates Canada, Inc. Common Stock 100 % Tower Associates Canada, Inc. Common Shares 100 % NextEra Energy Canada Equipment, Inc. Common 100% NextEra Canada Development & Acquisitions, Inc. Common 100% NextEra Canada Transmission Investments, Inc. Common 100% NextEra Canadian IP, Inc. Common Shares 100% CP II Holdings, LP Percentage Ownership Interest 99.9999% Mount Miller Holdings, LP Percentage Ownership Interest 99.9999% NextEra Energy Nextbridge Holdings, LP Percentage Ownership Interest 99.9999% Ghost Pine Holdings, ULC Common Stock 100 % Fortuna Limited Partner, ULC Common 100% Ghost Pine Windfarm, LP Percentage Ownership Interest 99.99% Bornlsh Wind BC Holdings, ULC Common 100% Barnish Wind Holdings GP, LLC Percentage Ownership Interest 100 % Barnish Wind Holdings GP, ULC Common Stock 100 % Bomish Wind Holdings, LP Percentage Ownership Interest 0.0001 % Page 454 8-51 Bornlsh Wind LP, ULC Common 100% Born ish Wind Funding GP, LLC Percentage Ownership Interest 100 % Bornish Wind Funding GP, ULC Common Stock 100 % Bornish Wind Funding, LP Percentage Ownership Interest 0.0001 % Bornish Wind, LP Limited Partnership Interest 100% Bornlsh Wind GP, LLC Percentage Ownership Interest 100 % Bornish Wind GP, ULC Common 100% Bornish Wind, LP General Partnership Interest 100 % Bornish Wind Funding, LP Percentage Ownership Interest 99.9999% Bornish Wind Holdings, LP Percentage Ownership Interest 99.9999% East Durham Wind BC Holdings, ULC Common 100% East Durham Wind Holdings GP, LLC Percentage Ownership Interest 100% East Durham Wind Holdings GP, ULC Common Stock 100 % East Durham Wind Holdings, LP Percentage Ownership Interest 0.0001 % East Durham Wind Funding GP, LLC Percentage Ownership Interest 100 % East Durham Wind Funding GP, ULC Common Stock 100 % East Durham Wind Funding, LP Percentage Ownership Interest 0.0001 % Page 454 8-52 East Durham Wind GP, LLC Percentage Ownership Interest 100 % East Durham Wind GP, ULC Common Stock 100% East Durham Wind, LP Percentage Ownership Interest 0.0001 % East Durham Wind, LP Percentage Ownership Interest 99.9999% East Durham Wind, ULC Common 100% East Durham Wind Funding, LP Percentage Ownership Interest 99.9999% East Durham Wind Holdings, LP Percentage Ownership Interest 99.9999 % Goshen Wind BC Holdings, ULC Common 100% Goshen Wind Holdings GP, LLC Percentage Ownership Interest 100 % Goshen Wind Holdings GP, ULC Common Stock 100 % Goshen Wind Holdings, LP Percentage Ownership Interest 0.0001 % Goshen Wind Funding GP, LLC Percentage Ownership Interest 100 % Goshen Wind Funding GP, ULC Common Stock 100 % Goshen Wind Funding, LP Percentage Ownership Interest 0.0001 % Goshen Wind GP, LLC Percentage Ownership Interest 100 % Goshen Wind GP, ULC Common Stock 100 % Goshen Wind, LP Percentage Ownership Interest 0.0001 % Page 454 B-53 ---- ---- --- --- Goshen Wind, LP Percentage Ownership Interest 99.9999% Goshen Wind, ULC Common 100% Goshen Wind Funding, LP Percentage Ownership Interest 99.9999% Goshen Wind Holdings, LP Percentage Ownership Interest 99.9999% Kerwood Wind BC Holdings, ULC Common 100% Kerwood Wind Holdings GP, LLC Percentage Ownership Interest 100% Kerwood Wind Holdings GP, ULC Common Stock 100 % Kerwood Wind Holdings, LP Percentage Ownership Interest 0.0001 % Kerwood Wind Funding GP, LLC Percentage Ownership Interest 100 % Kerwood Wind Funding GP, ULC Common Stock 100 % Kerwood Wind Funding, LP Percentage Ownership Interest 0.0001 % Kerwood Wind GP, LLC Percentage Ownership Interest 100 % Kerwood Wind GP, ULC Common Stock 100% Kerwood Wind, LP Percentage Ownership Interest 0.0001 % Kerwood Wind, LP Percentage Ownership Interest 99.9999% Kerwood Wind, ULC Common 100% Kerwood Wind Funding, LP Percentage Ownership Interest 99.9999% Page 454 B-54 Kerwood Wind Holdings, LP Percentage Ownership Interest 99.9999% Trout Lake Ill Solar GP, Inc. Common 100% Trout Lake Ill Solar, LP Percentage Ownership Interest 0.0001 % Cordukes Solar GP, Inc. Common 100% Cordukes Solar, LP Percentage Ownership Interest 0.0001 % Clarabelle I Solar GP, Inc. Common 100% Clarabelle I Solar, LP Percentage Ownership Interest 0.0001 % Clarabelle II Solar GP, Inc. Common 100% Clarabelle II Solar, LP Percentage Ownership Interest 0.0001 % Clarabelle Ill Solar GP, Inc. Common 100% Clarabelle Ill Solar, LP Percentage Ownership Interest 0.0001 % Northpoint I Wind LP, ULC Common 100% Northpoint I Wind, LP Percentage Ownership Interest 89.9999 % Battersea Solar GP, Inc. Common 100% Battersea Solar, LP Percentage Ownership Interest 0.0001 % Thames Solar GP, Inc. Common 100% Thames Solar, LP Percentage Ownership Interest 0.0001 % Page 454 B-55 Canadian Combined Cycle Station I GP, Inc. Common 100% Canadian Combined Cycle Station I, LP Percentage Ownership Interest 0.0001 % Trout Lake II Solar GP, Inc. Common 100% Trout Lake II Solar, LP Percentage Ownership Interest 0.0001 % Trout Lake I Solar GP, Inc. Common 100% Trout Lake I Solar, LP Percentage Ownership Interest 0.0001 % Northpoint I Wind GP, Inc. Common 100% Northpoint I Wind, LP Percentage Ownership Interest 0.0001 % North point II Wind GP, Inc. Common 100% Northpoint II Wind, LP Percentage Ownership Interest 0.0001 % Hardy Creek Wind GP, Inc. Common 100% Hardy Creek Wind, LP Percentage Ownership Interest 0.0001 % Battersea Solar LP, ULC Common 100% Battersea Solar, LP Percentage Ownership Interest 89.9999% Hardy Creek Wind, ULC Common 100% Hardy Creek Wind, LP Percentage Ownership Interest 89.9999% Clarabelle II Solar LP, ULC Common 100% Page 454 B-56 Clarabelle II Solar, LP Percentage Ownership Interest 89.9999% Trout Lake I Solar LP, ULC Common 100% Trout Lake I Solar, LP Percentage Ownership Interest 89.9999% Cordukes Solar LP, ULC Common 100% Cordukes Solar, LP Percentage Ownership Interest 89.9999% Clarabelle I Solar LP, ULC Common 100% Clarabelle I Solar, LP Percentage Ownership Interest 89.9999% Clarabelle Ill Solar LP, ULC Common 100% Clarabelle Ill Solar, LP Percentage Ownership Interest 99.999% Northpoint II Wind LP, ULC Common 100% Northpoint II Wind, LP Percentage Ownership Interest 89.9999% Trout Lake Ill Solar LP, ULC Common 100% Trout Lake Ill Solar, LP Percentage Ownership Interest 99.999% Canadian Combined Cycle Station I LP, ULC Common 100% Canadian Combined Cycle Station I, LP Percentage Ownership Interest 99.999% Thames Solar LP, ULC Common 100% Thames Solar, LP Percentage Ownership Interest 99.999 % Page 454 B-57 Trout Lake II Solar LP, ULC Common 100% Trout Lake II Solar, LP Percentage Ownership Interest 99.999% Ghost Pine Energy Storage GP, Inc. Common 100% Ghost Pine Energy Storage, LP Percentage Ownership Interest 0.0001 % Ghost Pine Energy Storage LP, ULC Common 100% Ghost Pine Energy Storage, LP Percentage Ownership Interest 99.9999% Elmira Energy Storage LP, ULC Common 100% Elmira Energy Storage, LP Percentage Ownership Interest 99.9999% Parry Energy Storage LP, ULC Common 100% Parry Energy Storage, LP Percentage Ownership Interest 99.9999% Parry Energy Storage GP, LLC Percentage Ownership Interest 100 % Parry Energy Storage GP, ULC Common 100% Parry Energy Storage, LP Percentage Ownership Interest 0.0001 % Elmira Energy Storage GP, LLC Percentage Ownership Interest 100 % Elmira Energy Storage GP, ULC Common 100% Elmira Energy Storage, LP Percentage Ownership Interest 0.0001 % High Hills Wind LP, ULC Common 100% Page 454 B-58 High Hills Wind, LP Percentage Ownership Interest 99.999 % Costigan Wind LP, ULC Common 100% Costigan Wind, LP Percentage Ownership Interest 99.999% High Hills Wind GP, Inc. Common 100% High Hills Wind, LP Percentage Ownership Interest 0.0001 % Costigan Wind GP, Inc. Common 100% Costigan Wind, LP Percentage Ownership Interest 0.0001 % Minudle Wind GP, Inc. Common 100% Minudie Wind, LP Percentage Ownership Interest 0.0001 % Minudle Wind LP, ULC Common Stock 100% Minudie Wind, LP Percentage Ownership Interest 99.999% NextEra Energy Canada, LP Limited Partnership Interest 100% NextEra Energy Spain Holdings B.V. Authorized Share Capital 100 % NextEra Energy Espana, S.L. Common 100% Planta Termosolar de Extremadura, S.L. Common 100% Evacuacion Valdecaballeros, S.L. Membership Interest 14.285714 % Planta Termosolar de Extremadura 2, S.L. Common 100% Page 454 B-59 Evacuacion Valdecaballeros, S.L. Membership Interest 14.285714 % NextEra Energy Espana Operating Services, S. L. Common - 1DO % Tuvalu Directorship, S.L. Common 100% Short Pines International Limited Capital Share Class 100 % Karaha Sodas Investment Corp. Ordinary Shares 100% NextEra Energy Global Holdings Cooperatieve U.A. Percentage Ownership Interest 99.9 % Square Lake Holdings, Inc. Common 100% BAC Investment Corp. Common 100% Inventus Holdings, LLC Membership Interest 100 % NextEra Energy Maine, LLC Percentage Ownership Interest 100% NextEra Energy Project Management, LLC Percentage Ownership Interest 100 % NextEra Energy Power Marketing, LLC Percentage Ownership Interest 100 % EarthEra, LLC Membership Interest 100% NextEra Texas Acquisition Holdco, LLC Percentage Ownership Interest 100 % NextEra Retail of Texas GP, LLC Percentage Ownership Interest 1DO % NextEra Retail of Texas, LP Percentage Ownership Interest 1 % NextEra Texas Acquisition LP, LLC Percentage Ownership Interest 100% Page 454 8-60 NextEra Retail of Texas, LP Percentage Ownership Interest 99% USG Energy Gas Producer Holdings, LLC Percentage Ownership Interest 100 % NextEra Energy Gas Producing, LLC Membership Interest 100% NextEra Energy Producer Services, LLC Membership Interest 100 % WSGP Gas Producing, LLC Percentage Ownership Interest 100% USG Properties Woodford I, LLC Percentage Ownership Interest 100 % NextEra Energy Gas Producing Wyoming, LLC Percentage Ownership Interest 100% BSGA Gas Producing, LLC Percentage Ownership Interest 100 % La Salle County Gas Producing, LLC Percentage Ownership Interest 100% USG Surface Facilities Holdings, LLC Percentage Ownership Interest 100% USG Surface Facilities I, LLC Percentage Ownership Interest 100 % USG Surface Facilities II, LLC Percentage Ownership Interest 100 % USG Properties Austin Chalk Holdings, LLC Percentage Ownership Interest 100 % · USG Properties Austin Chalk I, LLC Percentage Ownership Interest 100 % USG Properties Jackfork Holdings, LLC Percentage Ownership Interest 100 % USG Properties Jackfork I, LLC Percentage Ownership Interest 100 % USG Properties Bakken Holdings, LLC Percentage Ownership Interest 100% Page 454 8-61 USG Properties Bakken I, LLC Percentage Ownership Interest 100 % USG Properties Bakken II, LLC Percentage Ownership Interest 100% USG Properties Barnett Holdings, LLC Percentage Ownership Interest 100% USG Properties Barnett II, LLC Percentage Ownership Interest 100% USG Properties Granite Wash Holdings, LLC Percentage Ownership Interest 100% USG Properties Granite Wash I, LLC Percentage Ownership Interest 100 % USG Properties Haynesville Sands Holdings, LLC Percentage Ownership Interest 100 % USG Properties Haynesville Sand I, LLC Percentage Ownership Interest 100 % USG Properties Mississippian Lime Holdings, LLC Percentage Ownership Interest 100% USG Properties Mississippian Lime I, LLC Percentage Ownership Interest 100 % USG Surface Facilities Mississippian Lime I, LLC Percentage Ownership Interest 100% USG Properties Mississippian Lime II, LLC Percentage Ownership Interest 100 % USG Properties Eagle Ford Holdings, LLC Percentage Ownership Interest 100 % USG Properties Eagle Ford Ill, LLC Percentage Ownership Interest 100% USG Properties Eagle Ford IV, LLC Percentage Ownership Interest 100% USG Properties Niobrara Holdings, LLC Percentage Ownership Interest 100% USG Properties Woodford Holdings, LLC Percentage Ownership Interest 100 % Page 454 8-62 USG Properties Woodford II, LLC Percentage Ownership Interest 100 % USG Midstream Holdings, LLC Percentage Ownership Interest 100 % USG Midstream Bakken I, LLC Percentage OWnership Interest 100% USG Midstream Mississippian Lime I, LLC Percentage Ownership Interest 100% USG Midstream Haynesville Sands I, LLC Percentage Ownership Interest 100% USG Wheatland Pipeline, LLC Percentage Ownership Interest 100% USG West Relay, LLC Percentage Ownership Interest 100% West Relay Gathering Company, L.L.C. Percentage Ownership Interest 50 % USG Properties Wilcox Holdings, LLC Percentage OWnership Interest 100% USG Properties Wilcox I, LLC Percentage Ownership Interest 100% USG Properties Permian Basin Holdings, LLC Percentage Ownership Interest 100 % USG Properties Permian Basin I, LLC Percentage Ownership Interest 100% USG Properties Permian Basin II, LLC Percentage Ownership Interest 100 % USG Energy Gas Investment, LLC Percentage Ownership Interest 100% USG Technology Holdings, LLC Percentage Ownership Interest 100 % NextEra Energy Pipeline Holdings, LLC Percentage Ownership Interest 100 % Florida Southeast Connection, LLC Percentage Ownership Interest 100 % Page 454 B-63 ------------------- NextEra Energy Sabal Trail Transmission Holdings, LLC Percentage Ownership Interest 100 % US Southeastern Gas Infrastructure, LLC Percentage Ownership Interest 100% Sabal Trail Transmission, LLC Percentage Ownership Interest 33% US Marcellus Gas Infrastructure, LLC Percentage Ownership Interest 100 % Mountain Valley Pipeline, LLC Percentage Ownership Interest 35% NextEra Energy Pipeline Services, LLC Percentage Ownership Interest 100% US Sooner Trails Gas Infrastructure, LLC Percentage Ownership Interest 100% Sooner Trails Pipeline, LLC Percentage Ownership Interest 100 % NextEra Energy Pipeline Development and Acquisitions, LLC Percentage Ownership Interest 100 % NextEra Maine Fossil, LLC Percentage Ownership Interest 100% NextEra Energy Maine Operating Services, LLC Membership Interest 100 % FPL Energy Mason LLC Membership Interest 100% Wyman Cape Holdings, LLC Percentage Ownership Interest 100% FPL Energy Cape, LLC Membership Interest 100 % FPL Energy Spruce Point LLC Membership Interest 100 % FPL Energy Wyman LLC Membership Interest 100% FPL Energy Wyman IV LLC Membership Interest 100% Page 454 B-64 NEPM II Holdings, LLC Percentage Ownership Interest 100% NEPM II, LLC Percentage Ownership Interest 100% Common Unit Holdings, LLC Percentage Ownership Interest 100% NextEra Energy Partners, LP Common LP Units 0.085401 % FPL Readl-Power, LLC Membership Interest 100% NextEra Energy Infrastructure, LLC Membership Interest 100 % NextEra Energy Transmission, LLC Membership Interest 100 % New Hampshire Transmission, LLC Percentage OWnership Interest 100 % Lone Star Transmission Holdings, LLC Percentage Ownership Interest 100 % Lone Star Transmission Capital, LLC Percentage Ownership Interest 100% Lone Star Transmission, LLC Membership Interest 100 % NextEra Energy Transmission Investments, LLC Percentage Ownership Interest 100% NextEra Energy Hawaii, LLC Percentage Ownership Interest 100% NextEra Energy Hawaii Land Holdings, LLC Percentage Ownership Interest 100% NextEra Energy Transmission New York, Inc. Common Stock 100% NextEra Energy Transmission Southwest, LLC Percentage Ownership Interest 100 % NextEra Energy Transmission West, LLC Percentage Ownership Interest 100 % Page 454 B-65 Blue Heron Land Associates, LLC Percentage Ownership Interest 100 % NextEra Energy Transmission Midwest, LLC Percentage Ownership Interest 100 % NextEra Transmission Asset Acquisition Holdings, LLC Percentage Ownership Interest 100 % NextEra Energy Transmission Mid-Atlantic, LLC Percentage Ownership Interest 100% NextEra US Gas Assets, LLC Membership Interest 100 % NG Storage of America, LLC Membership Interest 100% NG Pipeline of America, LLC Membership Interest 100% Boulevard Gas Associates, LLC Percentage Ownership Interest 100 % Palms Insurance Company, Limited Class A Common 100% Alandco Inc. Common 100% Alandco I, Inc. Common 100% Alandco/Cascade, Inc. Common 100% FPL Holdings Inc Common 100% Colonial Penn Capital Holdings, Inc. Common 100% FPL Energy Services, Inc. Common 100% EMB Investments, Inc. Common 100% Pipeline Funding Company, LLC Membership Interest 100 % Page 454 B-66 Contra Costa Capital, LLC Membership Interest 100 % Nodal Exchange Holdings, LLC Percentage Ownership Interest 15.28 % NodaiExchange,LLC Percentage Ownership Interest 100 % ClearSky Power & Technology Fund I LLC Membership 27.42988% Verengo, Inc. Percentage OWnership Interest 46.2 % NextEra Fibemet, LLC Percentage Ownership Interest 100 % FPL Investments, LLC Percentage Ownership Interest 100 % NextEra Energy Equipment Leasing, LLC Percentage OWnership Interest 100 % Mendocino Capital, LLC Percentage Ownership Interest 100 % Verengo, Inc. Percentage Ownership Interest 0.09% HCPCIV 1, LLC Percentage Ownership Interest 15 % Pioneer Parent, Inc. Percentage Ownership Interest 4.6% Pike Corporation Percentage Ownership Interest 100 % FPL FlberNet Holdings, LLC Percentage OWnership Interest 100% FPL FlberNet, LLC Membership Interest 100% Surry Capital LLC Membership Interest 37.2066 % Pioneer Parent, Inc. Percentage Ownership Interest 17.23% Pike Corporation Percentage Ownership Interest 100 % Page 454 B-67 Tech Testing Solutions Holdings, LLC Percentage Ownership Interest 100% Tech Testing Solutions, LLC Percentage Ownership Interest 100% EFH Merger Co., LLC Percentage Ownership Interest 100% NEE Acquisition Sub I, LLC Percentage Ownership Interest 100 % NEE Acquisition Sub II, Inc. Common 100% Page 454 B-68 Analysis of Diversification Activity New or Amended Contracts with Affiliated Companies Florida Power & Light Company For the Year Ended December 31, 2015 Provide a synopsis of each new or amended contract, agreement, or arrangement with affiliated companies for the purchase, lease, or sale ofland, goods, or services (excluding tariffed items). The synopsis shall include, at a minimum, the terms, price, quantity, amount, and duration of the contracts. Synopsis of Contract Name of Affiliated Company Nextera Energy Resources, LLC On April29, 2015, FPL and NEER executed a Memorandum of Understanding related to a Photovoltaic Module Master Supply Agreement (MSA) between NEER and Hanwha SolarOne USA. The MSA agreement allows FPL to purchase photovoltaic modules from SolorOne for use in 3 identified solar energy production facilities. The MSA also requires that NEER provide SolarOne with an upfront deposit payment representing 63% of the cost ofthe modules. FPL will not be responsible for making any of the upfront payment. In addition, SolarOne will post a letter of credit (LOC) as security to NEER for receipt of the PV modules to which the upfront payment relates, which then will cover costs should SolarOne fail to meet its delivery obligations. NEER will act on behalf ofFPL for any claims related to the LOC, and NEER will receive no benefit from making any claims on behalf ofFPL. Florida Southeast Connection, On October 20, 2015, FPL amended its September 23, 2014 agreement with Florida Southeast Connection, LLC (FSC) LLC whereas FSC agreed to pay FPL an additional $36,227 for a the previously granted permanent perpetual pipeline easement for its property located at Section 20, Township 39 South, Range 38 East in Martin County, Florida. FPL Energy Services Inc. FPL entered into three agreements with FPL Energy Services to include FPL Energy Services bill inserts with its monthly utility bills to customers. The three agreements were entered into on May 6, 2015 and each was valid for one billing period (June-2015 thru August-2015). The agreement requires that FPLES pay to FPL a drop count insertion fee of $19.00 per 1,000 sent to FPL customers, plus $0.06 per enrollment response. FPL FiberNet, LLC Right of Way Consent Agreement with FPL FiberNet to allow FPL FiberNet to install underground fiber cables on FPL property. Address is 7930 NW 36th Street, Dora!, Florida. FiberNet pays FPL a one time application fee of$500 and an annual rental amount based on the amount of property occupied. Under this agreement the licensee may utilize and occupy the land solely for the purpose of constructing, operating, inspecting and maintaining underground conduit and fiber optic cable. No termination date specified. Effective August 25, 2015. FPL FiberNet, LLC Right of Way Consent Agreement with FPL FiberNet to allow FPL FiberNet to install underground fiber cables on FPL pmperty. Address is 1301 NW 84th Ave, SuitelOl, Dora!, FL. FiberNet pays FPL a one time application fee of$500 and an annual rental amount based on the amount of property occupied. Under this agreement the licensee may utilize and occupy the land solely for the purpose of constructing, operating, inspecting and maintaining underground conduit and fiber optic cable. No termination date specified. Effective August 11,2015. FPL FiberNet, LLC Land Use Agreement to allow FiberNet to repair and install underground fiber optic cable on FPL easement property along the transmission corridor from Flagami to State Road 836. Address is 10601 Washington St., Hollywood, FL. FiberNet pays FPL a one time application fee of $500. Under this agreement, Fibemet may utilize and occupy the land solely for the purpose of repairing, constructing, operating, inspecting and maintaining underground conduit and fiber optic cable. No termination date specified. Effective July 6, 2015. NextEra Energy, Inc. In past years, every time a subsidiary was added to or deleted from the consolidated income tax return, such subsidiary generally became a party to, or was deleted from, the Tax Allocation Agreement ofNextEra Energy, Inc. (NEE) and subsidiaries. Therefore, any corporate structure changes noted on pages 454-1 through 454-15 would also be reflected in NEE's tax arrangement. Palms Insurance Company, Limited Palms Insurance Company, Limited provides various lines of insurance coverage to FPL. Palms provides insurance for FPL employees' workers' compensation liability excess of an annual aggregate retention of$350,000 up to $2,000,000 per accident or per employee. Premium for the term January 1, 2015 to December 31, 2015 was $4,297,315. Workers' compensation and employer's liability coverage for certain FPL contractors is provided excess of an annual aggregate retention of$40,000 up to $500,000 per accident or per contractor employee. Premium for the term January 1, 2015 to December 31, 2015 was $1,144,386. Palms insures the FPL fleet vehicles for third-party auto liability up to $3,000,000 per occurrence excess of a $25,000 per accident retention. Premium for the term January 1, 2015 to December 31, 2015 was $2,674,414. Page 455-1 Analysis of Diversification Activity New or Amended Contracts with Affiliated Companies Florida Power & Light Company For the Year Ended December 31, 2015 Provide a synopsis of each new or amended contract, agreement, or arrangement with affiliated companies for the purchase, lease, or sale ofland, goods, or services (excluding tariffed items). The synopsis shall include, at a minimum, the terms, price, quantity, amount, and duration of the contracts. Name of Affiliated Companv Palms Insurance Company, Limited Synopsis of Contract Palms writes a 5% line ofFPL's Fort Lauderdale and Fort Myers Combustion Turbine Projects builder's all risk with a limit of$250,000,000 per occurrence excess of a $5,000,000 deductible. Premium for Fort Lauderdale and Fort Myers Combustion Turbine Projects builder's risk was $42,005. Coverage will expire upon completion of the project. WindLogics Inc. On January 5, 2015, FPL entered into an agreement with Windlogics, Inc. Under this agreement, Windlogics will dedicate 2 full time service employee resources to projects or tasks identified and requested by Customer Service business unit as part of the Smart Grid Analytics Projects. FPL shall pay service fees billed on an hourly basis for time incurred plus Windlogics actual travel expenses. Annual combined hourly payroll costs and travel expenses will not exceed $300,000. WindLogics Inc. On September 8, 2015 FPL entered into an agreement with WindLogics Inc. Under this agreement WindLogics will develop an estimated energy output to optimize for selected modules: I) Inverter, 2) Azimuth, and 3) DC:AC Ratio for the Manatee solar site in Florida. FPL will reimburse WindLogics the lower of fully loaded cost or the fair market value of the implementation services. WindLogics Inc. On September 8, 2015 FPL entered into an agreement with WindLogics Inc. Under this agreement WindLogics will develop an estimated energy output to optimize for selected modules: I) Inverter, 2) Azimuth, and 3) DC:AC Ratio for the Babcock Ranch solar site in Florida. FPL will reimburse WindLogics the lower of fully loaded cost or the fair market value of the implementation services. WindLogics Inc. On September 8, 2015 FPL entered into an agreement with WindLogics Inc. Under this agreement WindLogics will develop an estimated energy output to optimize for selected modules: I) Inverter, 2) Azimuth, and 3) DC:AC Ratio for the Citrus solar site in Florida. FPL will reimburse WindLogics the lower of fully loaded cost or the fair market value of the implementation services. Page 455-2 ANALYSIS OF DIVERSIFICATION ACTIVITY Individual Affiliated Transactions in Excess of $500,000 FLORIDA POWER & UGHTCOMPANY For the Year EndedDecember31, 2015 Provide information regarding individual affiliated transactions in excess of$500,000. Recurring monthly affiliated transactionsn which exceed $500,000 per month should be reported annually in the aggregate. However, each land or property sales transaction even though similar sales recur, should be reported as a 11non-recurring" item for the period in which it occurs. Description of Transaction (b) Name of Affiliate (a) Line No. Dollar Amount DR/(CR) (c) 14,674,510 1 Cedar Bay (CBAS) Power, LLC Funding of Operations 2 Cedar Bay (CBAS) Power, LLC Purchased Power 2,188,432 3 FPL Fibemet, LLC Fiber Network and Telephone Services 7,324,228 4 FPL Fibemet, LLC Pole Attachment Revenue (1 ,371 ,343) 5 FPL Fibemet, LLC Tower Lease Revenue (1,107,796) 6 FPL Recovery Funding, LLC Remittance of Bond Serving Amounts Collected 76,706,201 7 GR Woodford Properties LLC Excess Funding - Gas Reserves (9,481 ,356) 8 GR Woodford Properties, LLC Cash Funding of Operations 9 GR Woodford Properties, LLC Natural Gas Purchases 25,664,849 10 KPB Financial Corporation Nuclear Decommission Fund Tax Payment (15,588,509) 11 KPB Financial Corporation Storm Fund Bond Tax Payment (10,658,301) 12 NextEra Energy 13 NextEra Energy Duane Arnold, LLC Support for Nuclear Operations 14 NextEra Energy Point Beach, LLC Department of Energy- 2014 15 Next Era Energy Power Marketing, LLC EMT Systems Support 16 NextEra Energy Resources, LLC Information Management Support (7,335,395) 17 NextEra Energy Resources, LLC Information Systems Implementation Support (2, 179,058) 18 NextEra Energy Resources, LLC Space & Furniture Billing (5,912,396) 19 NextEra Energy Seabrook, LLC Department of Energy- 2014 20 NextEra Energy Seabrook, LLC Support for Nuclear Operations 21 NextEra Energy, Inc. Compensation, Deferred Comp, Incentives, Stock Awards, RSA Amortization, Pension & other Employee Benefrts Plans 22 NextEra Energy, Inc. Compensation, Deferred Comp, Incentives, Stock Awards, RSA Amortization, Pension & Other Employee Benefrts Plans 23 NextEra Energy, Inc. Estimated Federal Tax Payment 24 NextEra Energy, Inc. Estimated State Tax Payment 62,142,666 25 NextEra Energy, Inc. Federal Tax Payment on BehaW of KPB 10,655,532 26 NextEra Energy, Inc. Federal Tax Refund 27 NextEra Energy, Inc. IRS Reimbursement 3,590,422 28 NextEra Energy, Inc. Political Contribution 1,025,000 29 NextEra Energy, Inc. Inventory Purchase from Affiliate 5,474,361 Cap~al Holdings, Inc. Insurance Reimbursement Page 456-1 163,714,568 (1 '143,457) (502,835) 4,268,147 (770,662) 3,096,226 (1,011,689) 730,757,855 (5,056,793) 374,078,792 (34,616,014) ANALYSIS OF DIVERSIFICATION ACTIVITY Individual Affiliated Transactions in Excess of $500,000 FLORIDA POWER & UGHT COMPANY For the Yetlr Ended December 31 2015 Provide information regarding individual affiliated transactions in excess of $500,000. Recurring monthly affiliated transactions which exceed $500,000 per month should be reported annually in the aggregate. However, each land or property sales transaction even though similar sales recur, should be reported as a ''non-recurring11 item for the period in which it occurs. Name of Affiliate (a) Line No. Description of Transaction (b) Dollar Amount DR/(CR) (c) 30 Nex!Era Energy, Inc. State Tax Payment 31 Nex!Era Energy, Inc. State Tax Refund 32 Palms Insurance Company, Limited Contractor Workers' Compensation Insurance 1,025,375 33 Palms Insurance Company, Limited Employee Workers' Compensation Insurance 4,297,315 34 Palms Insurance Company, Limited Fleet Vehicle LiabiiHy Insurance 2,674,414 35 Palms Insurance Company, Limited Reimbursement of Claim Expenses Paid by FPL (4,473,094) 36 Zuni Solar, LLC Solar Panels General Comments: Items exclude payments of cash collected on behalf of Affiliates. Page 456-2 36,698,083 (680,540) 1,419,292 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAjJilillted Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the Year Ended December 31, 2015 Grouped by affiliate, list each contract, agreement, or other business transaction exceeding a cumulative amount of $300 in any one year, entered into between the Respondent and an affiliated business or financial organization, firm, or partnership identifying parties, amounts, dates, and product, asset, or service Involved. (a) Enter name of affiliate. (b) Give description of type of service, or name the product involved. (c) Enter contract or agreement effective dates. (d) Enter the letter "p" if the service or product is purchased by the Respondent: "s" if the service or product is sold by the Respondent. (e) Enter utility account number in which charges are recorded. (f ) Enter total amount paid, received, or accrued during the year for each type of service or product listed in column (c). Do not net amounts when services are both received and provided. Name of Affiliate Ia\ Type of Service and/or Name of Product lbl Relevant Contract or Agreement and Effective Date lc\ "Pnor "S" (d) Total Charae for Year Account Dollar Amount Number (e) (11 Transmission & Substation Support s 146 5,672 Corporate Finance Support s 146 1,162 Adelanto Solar, LLC Information Management Support s 146 43,964 Adelanto Solar, LLC Transmission & Substation Support s 146 8,158 AE Langdon Wind II, LLC Power Generation Technical Services s 146 667 AE Langdon Wind II, LLC Transmission & Substation Support s 146 519 Corporate Real Estate Services s 146 12,015 Transmission & Substation Support s 146 1,173 Ashtabula Wind II, LLC Power Generation Technical Services s 146 3,948 Ashtabula Wind II, LLC Transmission & Substation Support s 146 6,584 Ashtabula Wind Ill, LLC Corporate Finance Support s 146 6,997 Adelanto Solar II, LLC Adelanto Solar, LLC Alandco Inc. Altamont Infrastructure Company, LLC Ashtabula Wind Ill, LLC Information Management Services s 146 14,140 Ashtabula Wind Ill, LLC Power Generation Technical Services s 146 683 Ashtabula Wind, LLC Power Generation Technical Services s 146 4,770 Ashtabula Wind, LLC Transmission & Substation Support s 146 903 Backbone Mountain Windpower, LLC Information Management Support s 146 5,551 Backbone Mountain Windpower, LLC Power Generation PA & Technical Services s 146 22,895 Backbone Mountain Windpower, LLC Transmission & Substation Support s 146 5,123 Baldwin Wind, LLC Information Management Support s 146 14,140 Baldwin Wind, LLC Power Generation Division Support s 146 434 Baldwin Wind, LLC Transmission & Substation Support s 146 785 Bayswater Peaking Facility, LLC Human Resources Support s 146 24,659 Bayswater Peaking Facility, LLC Information Management Support s 146 26,650 Bayswater Peaking Facility, LLC Power Generation Services s 146 70,005 Bayswater Peaking Facility, LLC Corporate Finance Support s 146 611 Bayswater Peaking Facility, LLC Transmission & Substation Support s 146 1,480 146 14,140 Blackwell Wind, LLC Information Management Support s Blackwell Wind, LLC Power Generation Technical Services s 146 407 Blackwell Wind, LLC Transmission &Substation Support s 146 1,521 Blue Summit Wind, LLC Information Management Support s 146 22,113 Blue Summit Wind, LLC Power Generation Technical Services s 146 2,460 Blue Summit Wind, LLC Transmission &Substation Support s 146 43,066 Blue Summit Wind, LLC Sale of AsseVInventory s 146 16,888 Blythe Solar 110, LLC Project Estimating, Design and Management Support s 146 33,371 Blythe Solar 125, LLC Project Estimating, Design and Management Support s 146 50,241 Page 457-1 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAjJiliated Transfers and Cost Allocations FLORIDA POWER & UGHT COMPANY For the Year EndedDecember31, 2015 Type of Service Relevant Contract Name of and/or or Agreement and Affiliate Name of Product Effective Date lcl (a) lbl Total Charge for Year "P" or "S" ldl Account Number Amount lel (f) Dollar Breckinridge Wind Project, LLC Information Management Support s 146 51,990 Breckinridge Wind Project, LLC Transmission & Substation Support s 146 15,146 Bnackinridge Wind Project, LLC Project Estimating, Design and Management Support s 146 17,851 Breckinridge Wind Project, LLC General Counsel/Environmental Support s 146 8,102 Burleigh County Wind, LLC Power Generation Division Support s 146 848 Burleigh County Wind, LLC Transmission & Substation Support s 146 695 Butler Ridge Wind Energy, LLC Transmission & Substation Support s 146 3,116 Corporate Finance Support s 146 651 Transmission & Substation Support s 146 1,670 Inventory Purchase p 234 10,897 Human Resources Services s 146 605 Capricorn Ridge Wind, LLC Information Management Support s 146 3,602 Capricorn Ridge Wind, LLC Power Generation Technical Services s 146 12,601 Capricorn Ridge Wind, LLC Transmission & Substation Support s 146 66,145 Sale of Asset/Inventory s 146 105,305 lnfonmation Management Support s 146 12,328 Canyon Wind, LLC Capricorn Ridge Wind II, LLC Capricorn Ridge Wind II, LLC Capricorn Ridge Wind, LLC Capricorn Ridge Wind, LLC Carousel Wind Farm, LLC Carousel Wind Fanm, LLC Transmission & Substation Support s 146 29,429 Carousel Wind Fanm, LLC Project Estimating, Design and Management Support s 146 25,498 General Counsel Support s 146 18,385 CBAS Power, LLC Corporate Services s 146 763 CBAS Power, LLC Energy Marketing & Trading Services s 146 199,195 CBAS Power, LLC Funding of Operations p 234 484,271 CBAS Power, LLC Coal Inventory Purchase p 234 199,195 Carousel Wind Holdings, LLC Transmission & Substation Support s 146 48,765 Cimarron Wind Energy, LLC Human Resources Services s 146 850 Cimarron Wind Energy, LLC Information Management Support s 146 14,140 Cimarron Wind Energy, LLC Transmission & Substation Support s 146 15,552 ClearSky Power & Technology Fund I LLC Operations Support s 146 47,755 ClearSky Power & Technology Fund I LLC Space & Furniture Billing s 454 107,849 Power Delivery Support s 146 (410) Crystal Lake Wind II, LLC Power Generation Technical Services s 146 5,147 Crystal Lake Wind II, LLC Transmission & Substation Support s 146 1,221 Crystal Lake Wind Ill, LLC Power Generation Division Support s 146 890 Crystal Lake Wind, LLC Human Resources Services s 146 850 Crystal Lake Wind, LLC Power Generation Division Support s 146 2,859 Crystal Lake Wind, LLC Transmission & Substation Support s 146 1,835 Day County Wind, LLC Human Resources Services s 146 850 Cedar Bluff Wind, LLC Conestogo Wind, L.P. Day County Wind, LLC lnfonmation Management Support s 146 15,788 Day County Wind, LLC Power Generation Division Support s 146 2,512 Day County Wind, LLC Transmission & Substation Support s 146 523 Delaware Mountain Wind Fanm, LLC Power Generation Division Support s 146 4,550 Page 457-2 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAffiliated Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the YearErukdDecember31, 2015 Total Cha e for Year Relevant Contract Type of Service and/or Name of Product or Agreement and Effective Date (b) lc\ "P"or "S" ldl Account Dollar Number (e) Amount (f) Corporate Finance Services s 146 1,736 Desert Sunlight 250, LLC Power Generation Division Support s 146 7,443 Desert Sunlight 250, LLC Transmission & Substation Support s 146 7,287 Desert Sunlight 300, LLC Corporate Finance Services s 146 1,736 Desert Sunlight 300, LLC Power Generation Division Support s 146 5,274 Desert Sunlight 300, LLC Transmission & Substation Support s 146 3,430 Desert Sunlight Investment Holding, LLC Corporate Finance Services s 146 9,227 DG 1 Acquistion Co., LLC Human Resources Support s 146 50,896 Diablo Winds, LLC Power Generation Division Support s 146 2,129 Diablo Winds, LLC Transmission & Substation Support s 146 478 Information Management Support s 146 20,624 ELK City II Wind, LLC Power Generation Division Support s 146 2,047 ELK City II Wind, LLC Transmission & Substation Support s 146 5,383 Elk City Wind, LLC Information Management Support s 146 20,624 Elk City Wind, LLC Transmission & Substation Support s 146 12,217 Name of Affiliate Ia\ Desert Sunlight 250, LLC ELK City II Wind, LLC Ensign Wind, LLC Information Management Support s 146 14,140 Ensign Wind, LLC Power Generation Division Support s 146 666 Ensign Wind, LLC Transmission & Substation Support s 146 17,719 Sale of Asset/Inventory s 146 17,834 Transmission & Substation Support s 146 4,419 ESI Vansycle Partners, L.P. Power Generation Division Support s 146 1,751 ESI Vansycle Partners, L.P. Transmission & Substation Support s 146 1,117 Florida SE Connection LLC Corporate Real Estate Services s 146 990 Florida SE Connection LLC Information Management Support s 146 215,929 Florida SE Connection LLC Project Development s 146 676,952 FPL Energy Cabazon Wind, LLC Power Generation Division Support s 146 2,434 FPL Energy Cabazon Wind, LLC Transmission & Substation Support s 146 7,569 Ensign Wind, LLC ESI Sky River Partnership Sale of Asset/Inventory s 146 737 FPL Energy Callahan Wind, LP Information Management Support s 146 3,902 FPL Energy Callahan Wind, LP Power Generation Division Support s 146 3,275 Transmission & Substation Support s 146 3,040 FPL Energy Cape, LLC Information Management Support s 146 44,586 FPL Energy Cape, LLC Power Generation Support s 146 5,875 FPL Energy Cape, LLC Services Received by FPL p 234 24,948 FPL Energy Cowboy Wind, LLC Human Resources Support s 146 850 FPL Energy Cowboy Wind, LLC Power Generation Division Support s 146 8,429 FPL Energy Cowboy Wind, LLC Transmission & Substation Support s 146 1,700 FPL Energy Cowboy Wind, LLC Sale of Asset/Inventory s 146 592 FPL Energy Forney, LLC Human Resources Support s 146 850 FPL Energy Forney, LLC Information Management Support s 146 53,986 FPL Energy Cabazon Wind, LLC FPL Energy Callahan Wind, LP Page 457-3 ANALYSIS UFD1Vh'KSJFJCA11UN AC11VJTY Summary ofAffiliated Transfers and Cost Allocations FLORIDA POWER & UGHT COMPANY For the Year Ended December 31 2015 Name of Affiliate (a\ Type of Setvice and/or Name of Product lb\ Relevant Contract or Agreement and Effective Date lc\ "P"or "S" I d) Total Charge for Year Account Dollar Number Amount le\ (f) FPL Energy Forney, LLC Power Generation Division Support s 146 431,561 FPL Energy Forney, LLC Transmission & Substation Support s 146 25,098 FPL Energy Forney, LLC Sale of Asset/Inventory- Power Generation s 146 1,164 FPL Energy Forney, LLC Sale of AsseVInventory s 146 5,889 FPL Energy Green Power Wind, LLC Power Generation Division Support s 146 548 FPL Energy Hancock County Wind, LLC Power Generation Division Support s 146 8,280 FPL Energy Hancock County Wind, LLC Transmission & Substation Support s 146 2,329 FPL Energy Horse Hollow Wind II, LLC Human Resources Services s 146 850 FPL Energy Horse Hollow Wind II, LLC Information Management Support s 146 1,709 FPL Energy Horse Hollow Wind II, LLC Power Generation Division Support s 146 20,590 FPL Energy Horse Hollow Wind II, LLC Transmission & Substation Support s 146 10,948 FPL Energy Horse Hollow Wind II, LLC Sale of AsseVInventory s 146 760 FPL Energy Horse Hollow Wind, LLC Power Generation Division Support s 146 5,170 FPL Energy Horse Hollow Wind, LLC Transmission & Substation Support s 146 586 FPL Energy Illinois Wind, LLC General Counsel Services s 146 7,017 FPL Energy Illinois Wind, LLC Human Resources Services s 146 2,973 FPL Energy Illinois Wind, LLC Power Generation Division Support s 146 3,091 FPL Energy Illinois Wind, LLC Transmission & Substation Support s 146 19,042 FPL Energy Maine Hydro, LLC Corporate Services s 146 3,224 FPL Energy Marcus Hook, LP General Counsel Services s 146 6,034 FPL Energy Marcus Hook, LP Human Resources Support s 146 3,135 FPL Energy Marcus Hook, LP Information Management Support s 146 26,308 FPL Energy Marcus Hook, LP Power Generation Division Support s 146 308,964 FPL Energy Marcus Hook, LP Transmission & Substation Support s 146 8,359 FPL Energy Marcus Hook, LP Sale of Asset/Inventory- Power Generation s 146 649 FPL Energy Marcus Hook, LP Sale of AsseVInventory- Power Delivery s 146 986 Operations Support s 146 7,706 FPL Energy Mojave Operating Services, LLC Human Resources Support s 146 850 FPL Energy Mojave Operating Services, LLC Transmission & Substation Support s 146 2,011 FPL Energy Montezuma Wind, LLC Power Generation Division Support s 146 3,091 FPL Energy Montezuma Wind, LLC Transmission & Substation Support s 146 659 FPL Energy Montezuma Wind, LLC Sale of AsseVInventory s 146 556 FPL Energy New Mexico Wind, LLC Power Generation Division Support s 146 16,589 FPL Energy New Mexico Wind, LLC Strategy & Corporate Development s 146 9,385 FPL Energy New Mexico Wind, LLC Transmission & Substation Support s 146 980 FPL Energy North Dakota Wind, LLC Power Generation Division Support s 146 1,238 FPL Energy North Dakota Wind, LLC Transmission & Substation Support s 146 1,483 FPL Energy Oklahoma Wind, LLC Transmission & Substation Support s 146 165,692 FPL Energy Oklahoma Wind, LLC Sale of Asset/Inventory s 146 59,311 FPL Energy MH50, LP. FPL Energy Oliver Wind I, LLC Power Generation Division Support s 146 3,739 FPL Energy Oliver Wind I, LLC Transmission & Substation Support s 146 592 FPL Energy Pecos Wind I, LLC Information Management Support s 146 4,235 Page 457-4 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAjfi/illted Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the Year Ended December 31, 2015 Name of Affiliate lal Type of Service Relevant Contract and/or or Agreement and "P"or Account Total Cha eforYear Dollar Name of Product Effective Date Amount lcl "S" ldl Number (b) (e) (f) s 146 14,874 FPL Energy Pecos Wind I, LLC Power Generation Division Support FPL Energy Pecos Wind I, LLC Transmission & Substation Support s 146 3,492 Corporate Services Charge s 922 1,281,930 FPL Energy Services, Inc. Corporate Finance Services s 146 68,858 FPL Energy Services, Inc. Corporate Real Estate Services s 146 1,994 FPL Energy Services, Inc. Revenue Enhancement Support s 146 2,534,530 FPL Energy Services, Inc. General Counsel Services s 146 26,424 FPL Energy Services, Inc. Human Resources Services s 146 97,786 FPL Energy Services, Inc. FPL Energy Services, Inc. lnfonmation Management Support s 146 693 FPL Energy Services, Inc. Space & Furniture Billing s 454 198,270 FPL Energy Services, Inc. Customer Care Center Charges s 146 948,642 FPL Energy Services, Inc. Bill Insert Charges s 146 106,248 FPL Energy Services, Inc. Corporate Services s 146 4,597 FPL Energy Services, Inc. Sale of AsseVInventory s 146 4,346 FPL Energy Services, Inc. Care to Share Contributions s 146 530 FPL Energy Services, Inc. Doc Stamp Tax Payments s 146 448 FPL Energy Services, Inc. Services Received by FPL p 234 87,778 FPL Energy Services, Inc. Services Received by FPL p 588 26,920 FPL Energy Services, Inc. Services Received by FPL p 916 572,723 FPL Energy Services, Inc. Services Received by FPL p 923 434 FPL Energy Solar Partners Ill-VII, LLC General Counsel Services s 146 589 FPL Energy Solar Partners Ill-VII, LLC Human Resources Support s 146 3,119 FPL Energy Solar Partners Ill-VII, LLC Power Generation Division Support s 146 24,589 FPL Energy South Dakota Wind, LLC Power Generation Division Support s 146 2,921 FPL Energy Stateline II, LLC Power Generation Division Support s 146 3,657 FPL Energy Stateline II, LLC Transmission & Substation Support s 146 2,497 FPL Energy Upton Wind I, LLC lnfonmation Management Support s 146 4,415 FPL Energy Upton Wind I, LLC Power Generation Division Support s 146 11,382 FPL Energy Upton Wind I, LLC Transmission & Substation Support s 146 4,511 FPL Energy Upton Wind I, LLC Integrated Supply Chain Support s 146 8,604 Sale of AsseVInventory s 146 870 FPL Energy Vansycle, LLC Power Generation Division Support s 146 21,217 FPL Energy Vansycle, LLC Transmission & Substation Support s 146 4.966 FPL Energy Wyman IV,LLC Power Generation Division Support s 146 32,904 FPL Energy Wyman IV,LLC Transmission & Substation Support s 146 2,616 FPL Energy Wyman, LLC Human Resources Support s 146 1,325 FPL Energy Wyman, LLC lnfonmation Management Support s 146 8,990 FPL Energy Wyman, LLC Power Generation Division Support s 146 16,712 FPL Energy Wyman, LLC Transmission & Substation Support s 146 8,214 FPL Energy Upton Wind I, LLC Sale of Asset/Inventory s 146 1,000 FPL Fibernet, LLC Corporate Services Charge s 922 3,279,905 FPL Fibemet, LLC Fiber Network and Telephone Services p 232 6,236,745 FPL Energy Wyman, LLC Page 457-5 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAffiliated Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the Year Ended December 3JJ 2015 Type of SeiVice and/or Name of Product lb\ Relevant Contract or Agreement and Effective Date lc\ Total Cha eforYear "P" or Account "S" ld\ Number Dollar Amount le\ (f) Corporate Finance Services s 146 27,959 FPL Fibemet, LLC Corporate Services s 146 21,347 FPL Fibernet, LLC Corporate Real Estate Services s 146 81,958 FPL Fibernet, LLC General Counsel Services s 146 44,384 FPL Fibernet, LLC Human Resources Services s 146 406,634 FPL Fibernet, LLC Information Management Support s 146 398,500 FPL Fibernet, LLC Marketing & Communications Services s 146 18,459 FPL Fibemet, LLC Strategy & Corporate Development s 146 7,283 FPL Fibemet, LLC Transmission & Substation Support s 146 4,242,518 FPL Fibemet, LLC Space & Furniture Billing s 454 146,151 FPL Fibemet, LLC Integrated Supply Chain Services s 146 357,067 FPL Fibemet, LLC Internal Audit Services s 146 97,299 FPL Fibemet, LLC Fleet Services s 146 389 FPL Fibemet, LLC Pole Attachment Revenue s 454 343,218 FPL Fibemet, LLC Tower Lease Revenue s 454 99,326 s 146 2,603 146 1,376 3,122 Name of Affiliate (a) FPL Fibernet, LLC FPL Fibemet, LLC Care to Share Contributions FPL Fibernet, LLC Doc Stamp Tax Payments s FPL Fibernet, LLC Sale of AsseVInventory s 146 Services Received by FPL p 234 1,223 FPL Group International, Inc. Corporate Finance Services s 146 18,897 FPL Group International, Inc. Corporate Real Estate Services s 146 3,504 FPL Group International, Inc. General Counsel Services s 146 14,449 FPL Group International, Inc. Human Resources Services s 146 87,125 FPL Group International, Inc. Information Management Support s 146 12,847 FPL Group International, Inc. Power Generation Division Support s 146 174,716 FPL Group International, Inc. Corporate Services s 146 5,119 FPL Group International, Inc. Transmission & Substation Support s 146 60,491 FPL Fibernet, LLC FPL Group International, Inc. Project Estimating, Design and Management Support s 146 162,072 FPL Group International, Inc. Internal Audit Services s 146 1,150 FPL Group International, Inc. Transfer Pricing Activity p 234 (9,099) Services Provided to FPL p 234 5,119 Business Revenue Enhancement Support s 146 38,827 FPL Readi-Power, LLC Information Management Support s 146 337 FPL Readi-Power, LLC Space and Furniture Billing s 454 9,799 Fleet Services s 146 35,246 Service and Admin Fees s 146 451,000 FPL Group International, Inc. FPL Readi-Power, LLC FPL Readi-Power, LLC FPL Recovery Funding, LLC Storm Bond True Up p 234 16,742 FPL Services, LLC Revenue Enhancement Support s 146 1,835,147 FPL Services, LLC Funding of Cash Disbursements Account s 146 4,305,692 Garden Wind, LLC Power Generation Division Support s 146 5,292 Garden Wind, LLC Transmission & Substation Support s 146 1,386 FPL Recovery Funding, LLC Page 457-6 ANALYSIS OF DIVERSIFICATION AC11VITY Summary ofAffiliated Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the Year EndedDecember31, 2015 Name of Affiliate (a) Generation Repair & Service, LLC Type of Service Relevant Contract and/or or Agreement and Effective Date Total Cha e for Year Dollar "P"or "S" (d) Account General Counsel Services s 146 4,162 9,102 Name of Product (b) (c) Number Amount (e) (f) Generation Repair & Service, LLC Information Management Support s 146 Generation Repair & Service, LLC Marketing & Communication Services s 146 1,700 Generation Repair & Service, LLC Power Generation Division Support s 146 14,598 Generation Repair & Service, LLC Corporate Services s 146 778 Services Received by FPL p 546 1,014 Corporate Finance Services s 146 3,472 Genesis Solar, LLC Human Resources Services s 146 1,484 Genesis Solar, LLC Power Generation Division Support s 146 51,303 Genesis Solar, LLC Transmission & Substation Support s 146 8,502 Genesis Solar, LLC Corporate Services s 146 2,031 Genesis Solar, LLC Project Estimating, Design and Management Support s 146 19,139 Genesis Solar, LLC Services Received by FPL p 234 2,031 Corporate Finance Services s 146 2,469 Gexa Energy, LP Human Resources Services s 146 2,075 Gexa Energy, LP Information Management Support s 146 147,830 Gexa Energy, LP Strategy & Corporate Development s 146 7,110 Gexa Energy, LP Integrated Supply Chain Services s 146 745 Corporate Real Estate Services s 146 10,311 Golden Hills Wind, LLC Information Management Support s 146 126,952 Golden Hills Wind, LLC Transmission & Substation Support s 146 16,748 Golden West Power Partners, LLC Human Resources Services s 146 639 Golden West Power Partners, LLC Information Management Support s 146 17,239 Golden West Power Partners, LLC Transmission & Substation Support s 146 53,158 Golden West Power Partners, LLC Generation Repair & Service, LLC Genesis Solar, LLC Gexa Energy, LP Golden Hills Wind, LLC Project Estimating, Design and Management Support s 146 16,543 GR Woodford Properties, LLC Cash Funding of Operations p 234 50,367 GR Woodford Properties, LLC Return of Excess Cash for Cash Call s 146 433,778 GR Woodford Properties, LLC Interest Due on Note Receivable s 146 1,478,787 Gray County Wind Energy, LLC Information Management Support s 146 8,426 Gray County Wind Energy, LLC Power Generation Division Support s 146 7,455 Gray County Wind Energy, LLC Transmission & Substation Support s 146 780 Gray Sky Investments, LLC Corporate Real Estate Services s 146 5,000 Gray Sky Investments, LLC Funding of Cash Disbursements s 146 150,000 Gray Sky Investments, LLC Services Received by FPL p 234 3,523 Green Ridge Services, LLC Human Resources Services s 146 850 Hatch Solar Energy Center I, LLC Information Management Support s 146 4,038 Hatch Solar Energy Center I, LLC Power Generation Division Support s 146 576 Hawkeye Power Partners, LLC Power Generation Division Support s 146 4,822 Hawkeye Power Partners, LLC Transmission & Substation Support s 146 1,344 Hawkeye Power Partners, LLC Sale of Asset/Inventory s 146 797 Page 457-7 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAjJiliated Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the Year Ended December 31, 2015 and/or Name of Product Relevant Contract or Agreement and Effective Date "P"or (b\ lc\ Type of Service Name of Affiliate Ia\ ·s· Total Cha eforYear Account Dollar Amount Number ld\ te\ High Majestic Wind Energy, LLC Power Generation Division Support s 146 1,743 High Majestic Wind II, LLC Transmission & Substation Support s 146 1,047 Sale of Asset/Inventory s 146 9,551 General Counsel Services s 146 312 High Winds, LLC Information Management Support s 146 1,201 High Winds, LLC Power Generation Division Support s 146 29,007 High Winds, LLC Transmission & Substation Support s 146 478 Horse Hollow Generation Tie, LLC General Counsel Services s 146 8,674 Horse Hollow Generation Tie, LLC Transmission & Substation Support s 146 11,888 Indian Mesa Wind Farm, LLC Power Generation Division Support s 146 1,617 Indian Mesa Wind Farm, LLC Transmission & Substation Support s 146 1,001 High Majestic Wind II, LLC High Winds, LLC (f\ General Counsel Services s 146 8,967 Human Resources Services s 146 24,659 Jamaica Bay Peaking Facility, LLC Information Management Support s 146 10,300 Jamaica Bay Peaking Facility, LLC Power Generation Division Support s 146 93,779 Jamaica Bay Peaking Facility, LLC Transmission & Substation Support s 146 1,001 Inventus Holdings, LLC Jamaica Bay Peaking Facility, LLC Javelina Wind Energy, LLC Transmission & Substation Support s 146 2,936 Javelina Wind Energy, LLC Sale of Asset/Inventory- Nuclear s 146 4,699 KPB Financial Corporation Decommissioning Fund Tax Payment s 146 422,963 KPB Financial Corporation Storm Fund Bond Issue Admin Fees p 234 277,027 KPB Financial Corporation Decommissioning Fund Tax Payment p 234 (381,326) KPB Financial Corporation State Tax Payments p 234 (63,584) KPB Financial Corporation Storm Fund Tax Payment p 234 (63,410) Lake Benton Power Partners II,LLC Power Generation Division Support s 146 7,463 Lake Benton Power Partners II,LLC Transmission & Substation Support s 146 706 Lake Benton Power Partners JI,LLC Sale of Asset/Inventory- Nuclear s 146 576 Lamar Power Partners, LLC Human Resources Support s 146 904 Lamar Power Partners, LLC Information Management Support s 146 45,948 Lamar Power Partners, LLC Power Generation Division Support s 146 202,945 Lamar Power Partners, LLC Transmission & Substation Support s 146 15,037 Lamar Power Partners, LLC Corporate Services s 146 2,608 LamarPowerPartners,LLC Sale of Assetflnventory s 146 32,060 Lamar Power Partners, LLC Inventory Purchase p 234 8,908 Langdon Wind, LLC Power Generation Division Support s 146 5,665 Langdon Wind, LLC Transmission & Substation Support s 146 7,556 Limon Wind II, LLC Power Generation Division Support s 146 3,017 Limon Wind II, LLC Transmission & Substation Support s 146 1,390 Limon Wind Ill, LLC Power Generation Division Support s 146 2,581 Human Resources Support s 146 850 Limon Wind, LLC Power Generation Division Support s 146 8,594 Limon Wind, LLC Transmission & Substation Support s 146 2,138 Limon Wind, LLC Page 457-8 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAffillaud Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the YearEndedDecember31, 2015 Name of Affiliate (a) Type of Service and/or Relevant Contract or Agreement and Name of Product (b) Effective Date Logan Wind Energy, LLC Power Generation Division Support Logan Wind Energy, LLC Transmission & Substation Support (c) Corporate Support SeNices Total Charae for Year IDollar "P"or "S" (d) Account Number (e) s 146 5,080 s 146 523 Amount f) Lone Star Transmission, LLC Corporate Services Charge Agreement daled 5/1512013 s 922 907,455 Lone Star Transmission, LLC Corporate Services Corporate Support Services Agreement dated 5/1512013 s 146 46,266 Corporate Real Estate Services Corporate Support Services Agreement dated 511512013 s 146 16,617 Lone Star Transmission, LLC Corporate Support Services General Counsel Services Agreement dated 5/1512013 s 146 80,349 Human Resources Support Corporate Support Services Agreement dated 5/15/2013 s 146 21,277 Lone Star Transmission, LLC Information Management Support Corporate Support Services Agreement dated 5/15/2013 s 146 106,558 Lone Star Transmission, LLC Regulatory Affairs Support Corporate Support Services Agreement dated 5/1512013 s 146 6,708 Transmission & Substation Support Corporate Support Services Agreement dated 5/15/2013 s 146 230,405 Space & Furniture Billing Corporate Support Services Agreement dated 5/1512013 s 454 27,381 Project Estimating, Design and Management Support Corporate Support SeMces Agreement dated 5/1512013 s 146 107,175 Lone Star Transmission, LLC Fleet Services Corporate Support SeMces Agreement dated 5115/2013 s 146 4,978 Lone Star Transmission, LLC Sale of Asset/Inventory Corporate Support Services Agreement dated 5/15/2013 s 146 4,541 Lone Star Transmission, LLC Vested Performance Dollars Transfer p 234 2,600 Luz Solar Partners LTD., Ill General Counsel Services 146 43,921 Luz Solar Partners LTD., Ill Information Management Support s s 146 7,725 Luz Solar Partners LTD., Ill Power Generation Division Support s 146 2,502 Luz Solar Partners LTO., Ill Transmission & Substation Support 1,349 Power Generation Division Support s s 146 Luz Solar Partners LTD., IV 146 9,662 Lone Star Transmission, LLC Lone Star Transmission, LLC Lone Star Transmission, LLC Lone Star Transmission, LLC Lone Star Transmission, LLC Luz Solar Partners LTO., IV Transmission & Substation Support s 146 1,389 Luz Solar Partners LTO., V Power Generation Division Support s 146 6,429 Luz Solar Partners LTO., V Transmission & Substation Support s 146 1,868 Luz Solar Partners LTD., VI Power Generation Division Support s 146 43,278 Luz Solar Partners LTO., VI Transmission & Substation Support s 146 1,480 Luz Solar Partners LTD., VII Power Generation Division Support s 146 24,475 Luz Solar Partners LTD., VII Transmission & Substation Support s 146 1,741 Luz Solar Partners, Ltd. IX Power Generation Division Support s 146 4,613 Luz Solar Partners, Ltd. IX Transmission & Substation Support 146 3,894 Luz Solar Partners, Ltd. VIII Human Resources Support s s 146 1,854 Luz Solar Partners, Ltd. VIII Information Management Support s 146 7,725 Luz Solar Partners, Ltd. VIII Power Generation Division Support s 146 21,954 Luz Solar Partners, Ltd. VIII Transmission & Substation Support s 146 5,023 Page 457-9 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAjJiliated Transfers and Cost A//Qcations FLORIDA POWER & LIGHT COMPANY For the Year Ended December 31, 2015 Name of and/or Affiliate Name of Product Relevant Contract or Agreement and Effective Date Jill lcl Type of Service Ia\ "P"or "S" ldl Total Charae for Year Account 1Dollar Number Amount lei f) Mammoth Plains Wind Project, LLC Power Generation Division Support s 146 3,242 Mammoth Plains Wind Project, LLC Transmission & Substation Support s 146 1,544 Transmission & Substation Support s 146 907 Corporate Finance Services s 146 8,982 McCoy Solar, LLC Power Generation Division Support s 146 20,624 McCoy Solar, LLC Project Estimating, Design and Management Support s 146 279,759 Meyersdale Windpower, LLC Information Management Support s 146 2,602 Meyersdale Windpower, LLC Transmission & Substation Support s 146 2,531 Mill Run Windpower, LLC Power Generation Division Support s 146 33,523 Mill Run Windpower, LLC Transmission & Substation Support s 146 752 Mill Run Windpower, LLC Sale of Asset/Inventory s 146 6,898 Minco Wind II, LLC Information Management Support s 146 20,624 Minco Wind II, LLC Power Generation Division Support s 146 1,163 Minco Wind Ill, LLC Information Management Support s 146 20,624 Minco Wind Ill, LLC Power Generation Division Support s 146 662 Minco Wind Ill, LLC Transmission & Substation Support s 146 53,825 Minco Wind, LLC Information Management Support s 146 27,774 Minco Wind, LLC Power Generation Division Support s 146 1,030 Minco Wind, LLC Transmission & Substation Support s 146 1,630 Mojave 3/4/5 LLC Transmission & Substation Support s 146 3,216 Project Estimating, Design and Management Support s 146 7,353 Mountain View Solar, LLC Power Generation Division Support s 146 2,730 Mower County Wind, LLC Power Generation Division Support s 146 2,009 Transmission & Substation Support s 146 5,854 Corporate Services Charge s 922 87,356 Mantua Creek Solar, LLC McCoy Solar, LLC Morongo DG Solar, LLC Mower County Wind, LLC New Hampshire Transmission, LLC New Hampshire Transmission, LLC Corporate Services s 146 6,668 New Hampshire Transmission, LLC Corporate Real Estate Services s 146 2,072 New Hampshire Transmission, LLC General Counsel Services s 146 11,586 New Hampshire Transmission, LLC Human Resources Support s 146 1,410 New Hampshire Transmission, LLC Information Management Support s 146 889 New Hampshire Transmission, LLC Regulatory Affairs Support s 146 800 New Hampshire Transmission, LLC Transmission & Substation Support s 146 42,805 New Hampshire Transmission, LLC Space & Furniture Billing s 454 19,826 NextEra Energy Seabrook, LLC Corporate Real Estate Services s 146 720 Next Era Energy Seabrook, LLC Corporate Finance Services s 146 55,069 NextEra Energy Seabrook, LLC Corporate Services s 146 3,232 NextEra Energy Seabrook, LLC General Counsel Services s 146 56,167 NextEra Energy Seabrook, LLC Human Resources Services s 146 117,126 Next Era Energy Seabrook, LLC Information Management Support s 146 2,118,281 NextEra Energy Seabrook, LLC Marketing & Communications Services s 146 122,079 NextEra Energy Seabrook, LLC Strategy & Corporate Development s 146 1,500 Integrated Supply Chain Services s 146 423,682 NextEra Energy Seabrook, LLC Page 457-10 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAjJiliated Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the YearEndedDecember31, 2015 Type of SeiVice Affiliate and/or Name of Product (a) (b) Name of NextEra Energy Seabrook, LLC Fleet Servioes Relevant Contract or Agreement and Total Charge for Year IDollar "P"or Effective Date ·s· Account Number (c) (d) (e) s 146 351 Amount (f) NextEra Energy Seabrook, LLC Power Generation Division Support s 146 494,339 NextEra Energy Seabrook, LLC Transmission & Substation Support s 146 3,237 NextEra Energy Seabrook, LLC Nuclear Operations Support s 146 7,029,376 NextEra Energy Seabrook, LLC Sale of AsseUinventory s 146 84,812 NextEra Energy Seabrook, LLC Inventory Purchase p 234 39,200 NextEra Energy Seabrook, LLC Services Received by FPL p 234 355,233 Next Era Energy Seabrook, LLC Services Reoeived by FPL p 517 274,706 NextEra Energy Seabrook, LLC Services Reoeived by FPL p 520 316,086 NextEra Energy Seabrook, LLC Services Received by FPL p 524 800,530 NextEra Energy Seabrook, LLC Servioes Reoeived by FPL p 528 278,317 NextEra Energy Seabrook, LLC Servioes Received by FPL p 532 2,861 NextEra Energy Seabrook, LLC Services Received by FPL p 923 1,519 NextEra Energy Acquisition Sub I, LLC Corporate Finance Services- HEI Acquisition 1,479 Information Management Support- HEI Acquisition 146 62,941 NextEra Energy Acquisition Sub I, LLC Power Generation Division Support- HEI Acquisition s s s 146 NextEra Energy Acquisition Sub I, LLC 146 2,425 146 5,507 NextEra Energy Acquisition Sub I, LLC Transmission & Substation Support- HEI Acquisition NextEra Energy Acquisition Sub I, LLC Project Estimating, Design and Mgmt Support- HEI Acquisition s s NextEra Energy Acquisition Sub I, LLC HEI Acquisition Activities NextEra Energy Capital Holdings, Inc. Corporate Services Charge NextEra Energy Capital Holdings, Inc. Corporate Finance Services NextEra Energy Capital Holdings, Inc. Corporate Real Estate Services NextEra Energy Capital Holdings, Inc. NextEra Energy Capital Holdings, Inc. NextEra Energy Capital Holdings, Inc. NextEra Energy Capital Holdings, Inc. NextEra Energy Capital Holdings, Inc. Regulatory & State Government Affairs 146 2,691 s 146 5,981,846 s 922 281,452 s 146 668,614 s 146 44,407 Executive Services s 146 104,185 General Counsel Services s 146 74,938 Human Resources Services s 146 2,060,905 Information Management Support s 146 33,815 s 146 8,325 NextEra Energy Capital Holdings, Inc. Strategy & Corporate Development s 146 84,101 NextEra Energy Capital Holdings, Inc. Integrated Supply Chain Services s 146 5,385 NextEra Energy Capital Holdings, Inc. Marketing & Communications s 146 21,063 NextEra Energy Capital Holdings, Inc. Corporate Services s 146 278,568 NextEra Energy Capital Holdings, Inc. Electric Vehicle Chargebacks s 146 1,018 NextEra Energy Capital Holdings, Inc. Space & Furniture Billing s 454 248,323 NextEra Energy Capital Holdings, Inc. Affiliate portion of Medicare Subsidy p 234 210,330 NextEra Energy DG Operations, LLC Human Resources Services s 146 610 NextEra Energy Duane Arnold, LLC Corporate Finance Services s 146 26,319 NextEra Energy Duane Arnold, LLC General Counsel Services s 146 73,661 NextEra Energy Duane Arnold, LLC Human Resources Services s 146 170,682 NextEra Energy Duane Arnold, LLC Information Management Support s 146 2,018,213 NextEra Energy Duane Arnold, LLC Marketing & Communications Services s 146 133,791 NextEra Energy Duane Arnold, LLC Strategy & Corporate Development s 146 1,050 NextEra Energy Duane Arnold, LLC Nuclear Operations Support s 146 7,002,106 Page 457-11 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAffiliated Transfers and Cost Alwcations FLORIDA POWER & LIGHT COMPANY For the Year Ended December 31, 2015 Name of Affiliate Name of Product Relevant Contract or Agreement and Effective Date Ia\ (b) lc\ Type of Service and/or Total Charas for Year IDollar "P"or "S" I d) Account Number le\ NextEra Energy Duane Arnold, LLC Integrated Supply Chain Services s 146 NextEra Energy Duane Arnold, LLC Fleet Services s 146 1,335 NextEra Energy Duane Arnold, LLC Power Generation Division Support s 146 256,752 NextEra Energy Duane Arnold, LLC Sale of Asset/Inventory- Nuclear s 146 16,411 NextEra Energy Duane Arnold, LLC Sale of Asset/Inventory - Power Delivery s 146 7,628 NextEra Energy Duane Arnold, LLC DOE Settlement p 234 488,595 NextEra Energy Duane Arnold, LLC Inventory Purchase p 234 33,496 NextEra Energy Duane Arnold, LLC Services Received by FPL p 234 83,106 NextEra Energy Duane Arnold, LLC Services Received by FPL p 517 62,117 NextEra Energy Duane Arnold, LLC Services Received by FPL p 520 72,462 NextEra Energy Duane Arnold, LLC Services Received by FPL p 524 73,743 NextEra Energy Duane Arnold, LLC Services Received by FPL p 528 44,950 NextEra Energy Duane Arnold, LLC Services Received by FPL p 531 5,500 NextEra Energy Duane Arnold, LLC Services Received by FPL p 532 7,186 NextEra Energy Gas Producing, LLC General Counsel Services s 146 879 Corporate Finance Services s 146 20,500 NextEra Energy Montezuma II Wind ,LLC Power Generation Division Support s 146 368 NextEra Energy Montezuma II Wind ,LLC Transmission & Substation Support s 146 4,713 NextEra Energy Operating Partners, L.P. Corporate Finance Services s 146 11,863 NextEra Energy Operating Partners, L.P. Marketing & Communication Services s 146 2,779 NextEra Energy Operating Services, LLC Human Resources Support s 146 11,258 NextEra Energy Operating Services, LLC Care to Share Contributions s 146 535 NextEra Energy Operating Services, LLC Vested Performance Dollars Transfer p 234 13,000 NextEra Energy Operating Services, LLC Services Received by FPL p 506 50,093 NextEra Energy Operating Services, LLC Services Received by FPL p 546 1,288 NextEra Energy Operating Services, LLC Services Received by FPL p 568 1,532 NextEra Energy Operating Services, LLC Services Received by FPL p 588 1,875 NextEra Energy Operating Services, LLC Services Received by FPL p 234 25,565 Services Received by FPL p 501 524,615 Corporate Finance Services s 146 28,872 NextEra Energy Point Beach, LLC Corporate Services s 146 893 NextEra Energy Point Beach, LLC Corporate Real Estate Services s 146 1,135 NextEra Energy Global Holdings Cooperative UA NextEra Energy Pipeline Services, LLC NextEra Energy Point Beach, LLC Amount f) 366,762 NextEra Energy Point Beach, LLC General Counsel Services s 146 41,151 NextEra Energy Point Beach, LLC Human Resources Services s 146 239,462 NextEra Energy Point Beach, LLC Information Management Support s 146 2,508,509 NextEra Energy Point Beach, LLC Marketing & Communication Services s 146 130,351 NextEra Energy Point Beach, LLC Strategy & Corporate Development s 146 2,608 NextEra Energy Point Beach, LLC Nuclear Operations Support s 146 8,469,887 NextEra Energy Point Beach, LLC Integrated Supply Chain Support s 146 430,966 NextEra Energy Point Beach, LLC Power Generation Division Support s 146 501,730 NextEra Energy Point Beach, LLC Sale of Asset/Inventory s 146 150,739 Vested Performance Dollars Transfer p 234 36,400 NextEra Energy Point Beach, LLC Page 457-12 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAffilioted Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the YearEndedDecember31, 2015 Name of Affiliate (a) NextEra Energy Point Beach, LLC Type of Service Relevant Contract and/or or Agreement and Name of Product Effective Date (b) (c) Total CharQe for Year "P"or "S" (d) Account Number (e) Inventory Purchase p 234 25,331 1Dollar Amount (f) NextEra Energy Point Beach, LLC Services Received by FPL p 234 438,010 NextEra Energy Point Beach, LLC Services Received by FPL p 517 28,716 NextEra Energy Point Beach, LLC Services Received by FPL p 520 132,076 NextEra Energy Point Beach, LLC Services Received by FPL p 524 132,746 103,231 NextEra Energy Point Beach, LLC Services Received by FPL p 528 NextEra Energy Point Beach, LLC Services Received by FPL p 531 1,582 NextEra Energy Point Beach, LLC Services Received by FPL p 923 49,540 NextEra Energy Resources, LLC Corporate Services Charge s 922 71,623,611 NextEra Energy Resources, LLC Corporate Finance Services s 146 2,511,581 NextEra Energy Resources, LLC Corporate Services s 146 351,321 NextEra Energy Resources, LLC Corporate Real Estate Services s 146 833,107 NextEra Energy Resources, LLC Distribution - Quality Support s 146 64,414 NextEra Energy Resources, LLC General Counsel Services s 146 953,061 NextEra Energy Resources, LLC Environmental Support s 146 50,528 NextEra Energy Resources, LLC Human Resources Services s 146 2,204,570 NextEra Energy Resources, LLC Information Management Support s 146 8,051,151 NextEra Energy Resources, LLC Power Generation Division Support s 146 946,198 NextEra Energy Resources, LLC Power Generation Division ~ Work Management System s 146 2,074,295 NextEra Energy Resources, LLC Regulatory & State Government Affairs s 146 242,911 NextEra Energy Resources, LLC Strategy & Corporate Development s 146 113,838 NextEra Energy Resources, LLC Transmission & Substation Support s 146 645,369 NextEra Energy Resources, LLC Space & Furniture Billing s 454 1,176,949 NextEra Energy Resources, LLC Integrated Supply Chain Services s 146 655,770 NextEra Energy Resources, LLC Project Estimating, Design and Management Support s 146 1,119,566 NextEra Energy Resources, LLC Internal Audit Services s 146 1,418,581 NextEra Energy Resources, LLC Fleet Services s 146 70,446 NextEra Energy Resources, LLC Marketing & Communications Services s 146 65,798 NextEra Energy Resources, LLC External Affairs s 146 25,000 NextEra Energy Resources, LLC Sale of Asset/Inventory • Power Delivery s 146 538 NextEra Energy Resources, LLC Sale of Asset/Inventory s 146 555 NextEra Energy Resources, LLC Care to Share Contributions s 146 11,545 NextEra Energy Resources, LLC Doc Stamp Tax Payments s 146 5,048 NextEra Energy Resources, LLC Services Received by FPL p 234 5,128,924 NextEra Energy Resources, LLC Transfer Pricing Activity p 234 9,099 NextEra Energy Resources, LLC Vested Performance Dollars Transfer p 234 462,795 NextEra Energy Resources, LLC Services Received by FPL p 426 17,662 NextEra Energy Resources, LLC Services Received by FPL p 500 30,366 NextEra Energy Resources, LLC Services Received by FPL p 501 786,038 NextEra Energy Resources, LLC Services Received by FPL p 506 2,483,957 NextEra Energy Resources, LLC Services Received by FPL p 512 96,190 Page 457-13 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAffiliated Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the Year Ended December 31, 2015 Type of Service Relevant Contract and/or or Agreement and Name of Product Effective Date fc\ Name of Affiliate (ai (b) "P'' 0 "S" (d\ Total Charae for Year Account lDollar Number Amount (e\ If) Services Received by FPL p 517 8,276 NextEra Energy Resources, LLC Services Received by FPL p 524 662,909 NextEra Energy Resources, LLC Services Received by FPL p 528 6,304 NextEra Energy Resources, LLC Services Received by FPL p 531 5,712 NextEra Energy Resources, LLC Services Received by FPL p 532 721 NextEra Energy Resources, LLC Services Received by FPL p 546 59,474 NextEra Energy Resources, LLC Services Received by FPL p 549 64,613 NextEra Energy Resources, LLC Services Received by FPL p 553 52,379 NextEra Energy Resources, LLC Services Received by FPL p 557 3,341 NextEra Energy Resources, LLC Services Received by FPL p 560 157,800 NextEra Energy Resources, LLC Services Received by FPL p 561 666 NextEra Energy Resources, LLC Services Received by FPL p 580 196,643 NextEra Energy Resources, LLC Services Received by FPL p 588 99.475 NextEra Energy Resources, LLC Services Received by FPL p 901 20,557 NextEra Energy Resources, LLC Services Received by FPL p 903 4,817 NextEra Energy Resources, LLC Services Received by FPL p 908 (2,739) NextEra Energy Resources, LLC Services Received by FPL p 910 Services Received by FPL p 916 1,578 NextEra Energy Resources, LLC Services Received by FPL p 923 1,839,417 NextEra Energy Resources, LLC Services Received by FPL p 923 90,682 NextEra Energy Transmission West, LLC General Counsel Services s 146 53,345 NextEra Energy Transmission West, LLC Regulatory & State Government Affairs s 146 12,252 NextEra Energy Transmission West, LLC Project Estimating, Design and Management Support s 146 4,653 Corporate Services Charge s 922 331,034 NextEra Energy Transmission, LLC Corporate Services s 146 5,481 NextEra Energy Transmission, LLC Corporate Real Estate Services s 146 24,891 NextEra Energy Transmission, LLC General Counsel Services s 146 169,180 NextEra Energy Transmission, LLC Human Resources Support s 146 36,626 NextEra Energy Transmission, LLC Information Management Support s 146 9,776 Regulatory Affairs Support s 146 48,104 NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Transmission, LLC NextEra Energy Transmission, LLC 119.463 NextEra Energy Transmission, LLC Operations Support s 146 6,010 NextEra Energy Transmission, LLC Space & Furniture Billing s 454 258,291 NextEra Energy Transmission, LLC Project Estimating, Design and Management Support s 146 45,771 NextEra Energy Transmission, LLC Vested Performance Dollars Transfer p 234 16,250 NextEra Energy Transmission, LLC Services Received by FPL p 500 399 NextEra Energy Transmission, LLC Services Received by FPL p 561 552 NextEra Energy Transmission, LLC Services Received by FPL p 588 368 NextEra Energy Transmission, LLC Care to Share Contributions s 146 561 NextEra Energy, Inc. Corporate Finance Services s 146 39,434 NextEra Energy, Inc. Compensation, Deferred Comp, Incentives, Stock Awards, RSA Amortization, Pension & Other Employee Benefits Plans s 146 2,854,095 NextEra Energy, Inc. General Counsel Services s 146 9,205 NextEra Energy, Inc. Human Resources Services s 146 399,206 Page 457-14 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAjfi/Ulted Transfers and Cost Alwcadons FLORIDA POWER & LIGHT COMPANY For the Year Ended December31, 2015 Name of Affiliate a Type of Service and/or Relevant Contract or Agreement and Name of Product Effective Date "P"o "S" lc\ (d\ lb\ Total Charoe for Year Account Dollar Number Amount (f) (o\ I NextEra Energy, Inc. Corporate Services s 146 62,969 NextEra Energy, Inc. Care to Share Contributions s 146 1,752 NextEra Energy, Inc. Compensation, Deferred Comp, Incentives, Stock Awards, RSA Amortization, Pension & Other Employee Benefits Plans p 920 36,063,380 NextEra Energy, Inc. Services Received by FPL p 234 549,060 NextEra Energy, Inc. Services Received by FPL p 923 359,948 NextEra Energy, Inc. Services Received by FPL p 923 141,198 NextEra Energy, Inc. Affiliate Portion of Medicare Subsidy p 234 11,618 NextEra Energy, Inc. Risk Management Activities p 234 18,911 NextEra Energy, Inc. Tax Payments p 234 524,380 Contributions p 234 12,898 Corporate Services Charge s 922 220,601 NextEra Energy, Inc. NextEra Fibernet, LLC NextEra Fibarnet, LLC Corporate Finance Support s 146 12,654 NextEra Fibarnet, LLC Corporate Real Estate Services s 146 24,757 NextEra Fibarnet, LLC Human Resources Support s 146 6,443 NextEra Fibernet, LLC Information Management Support s 146 1,020 NextEra Fibarnet, LLC Marketing & Communications Services s 146 40,400 NextEra Maine Fossil, LLC General Counsel Services s 146 9,314 NextEra Maine Operating Services, LLC Human Resources Support s 146 93,809 NextEra Energy Power Marketing, LLC Corporate Services s 146 8,090 NextEra Energy Power Marketing, LLC Corporate Real Estate Services s 146 4,373 NextEra Energy Power Marketing, LLC General Counsel Services s 146 407,165 NextEra Energy Power Marketing, LLC Human Resources Support s 146 110,011 NextEra Energy Power Marketing, LLC Information Management Support s 146 521,168 NextEra Energy Power Marketing, LLC Fleet Services s 146 3,602 NextEra Energy Power Marketing, LLC Energy Marketing & Trading Services s 146 795,229 NextEra Energy Power Marketing, LLC Care to Share Contributions s 146 4,183 NextEra Energy Power Marketing, LLC Doc Stamp Tax Payment s 146 959 NextEra Energy Power Marketing, LLC Vested Performance Dollars Transfer p 234 16,900 NextEra Energy Power Marketing, LLC Services Received by FPL p 426 609 NextEra Energy Power Marketing, LLC Services Received by FPL p 501 273,691 NextEra Energy Power Marketing, LLC Services Received by FPL p 923 188,759 NextEra Energy Power Marketing, LLC Services Received by FPL p 234 335,159 NextEra Energy Project Management, LLC Corporate Services s 146 94,616 NextEra Energy Project Management, LLC Corporate Real Estate Services s 146 367,850 General Counsel Services s 146 19,819 Human Resources Support s 146 106,863 NextEra Energy Project Management, LLC Information Management Support s 146 684,457 NextEra Energy Project Management, LLC Marketing & Communications Services s 146 3,472 NextEra Energy Project Management, LLC Power Generation Division Support s 146 2,426,770 NextEra Energy Project Management, LLC Project Estimating, Design and Management Support s 146 16,309 NextEra Energy Project Management, LLC Care to Share Contributions s 146 719 NextEra Energy Project Management, LLC NextEra Energy Project Managemen~ LLC Page 457-15 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAffiliated Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the YearEndedDecember31, 2015 Name of Type of Service and/or Affiliate lal Name of Product (b) Relevant Contract or Agreement and Effective Date lcl "P" o "S" ldl Total Charge for Year Account \Dollar Number lel Amount Ill Vested Performance Dollars Transfer p 234 NextEra Energy Project Management, LLC Services Received by FPL p 234 2,152 NextEra Energy Project Management, LLC Services Received by FPL p 426 7,564 NextEra Energy Project Management, LLC Services Received by FPL p 500 1,199 NextEra Energy Project Management, LLC Services Received by FPL p 501 254,714 NextEra Energy Project Management, LLC Services Received by FPL p 506 147,295 NextEra Energy Project Management, LLC Services Received by FPL p 513 5,929 NextEra Energy Project Management, LLC Services Received by FPL p 517 253,342 NextEra Energy Project Management, LLC Services Received by FPL p 524 181,142 NextEra Energy Project Management, LLC Services Received by FPL p 552 36,451 NextEra Energy Project Management, LLC Services Received by FPL p 553 6,682 Services Received by FPL p 907 7,969 NextEra Energy Project Management, LLC Services Received by FPL p 910 514 NextEra Energy Project Management, LLC Services Received by FPL p 923 891,878 NextEra Energy Project Management, LLC Services Received by FPL p 234 417,999 Corporate Finance Services s 146 2,303 Project Estimating, Design and Management Support s 146 1,945 NextEra Energy Project Management, LLC NextEra Energy Project Management, LLC NET Holdings Mgt, LLC Ninnescah Wind Energy, LLC 91,000 Sale of Asset/Inventory s 146 21,337 North American Power Systems, LLC Space & Furniture Billing s 454 76,123 North American Power Systems, LLC Corporate Services s 146 24,125 North American Power Systems, LLC Inventory Purchase p 234 511,386 Northern Colorado Wind Energy, LLC Power Generation Division Support s 146 4,729 Northern Colorado Wind Energy, LLC Transmission & Substation Support s 146 1,542 General Counsel Services s 146 410 North American Power Systems Wind, LLC North Jersey Energy Associates North Jersey Energy Associates Human Resources Services s 146 3,032 North Jersey Energy Associates Information Management Support s 146 10,300 North Jersey Energy Associates Power Generation Division Support s 146 341,780 North Jersey Energy Associates Strategy & Corporate Development s 146 1,110 North Jersey Energy Associates Transmission & Substation Support s 146 17,815 Sale of Asset'lnventory s 146 2,396 North Sky River Energy, LLC Power Generation Division Support s 146 2,057 North Sky River Energy, LLC Transmission & Substation Support s 146 2,974 Northeast Energy Associates Human Resources Services s 146 5,578 Northeast Energy Associates Power Generation Division Support s 146 58,215 Northeast Energy Associates Transmission & Substation Support s 146 7,127 Old Mill Solar, LLC Project Estimating, Design and Management Support s 146 1,653 Oliver Wind II, LLC Power Generation Division Support s 146 1,510 Oliver Wind II, LLC Transmission & Substation Support s 146 523 North Jersey Energy Associates Osceola Windpower II, LLC Transmission & Substation Support s 146 1,356 Osceola Windpower, LLC Power Generation Division Support s 146 2,792 Osceola Windpower, LLC Transmission & Substation Support s 146 2,199 Osceola Windpower, LLC Sale of Asset'lnventory s 146 928 Page 457-16 ANALYSIS OF DIVERSIFICAllON ACTIVITY Summary ofAjJilillted Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the Year Ended December 31, 2015 Name of Affiliate (a) Type of Service Relevant Contract and/or or Agreement and "P" or Name of Product Effective Date "S" (d) (b) (c) Total Charge for Year Account Number (e) IDollar Amount (f) Builders Risk Insurance Premium p 234 42,005 Contractor Workers Compensation Premium p 234 119,011 Transmission & Substation Support s 146 1,432 Corporate Services s 146 4,359 Paradise Solar Urban, LLC Transmission & Substation Support s 146 696 Peetz Table Wind Energy, LLC Power Generation Division Support s 146 5,048 Peetz Table Wind Energy, LLC Transmission & Substation Support s 146 29,821 Peetz Table Wind Energy, LLC Sale of AsseVInventory s 146 19,849 Pennsylvania Windfarms, LLC Human Resources Services s 146 850 Palms Insurance Company, Limited Palms Insurance Company, Limited Palo Duro Wind Energy, LLC Palo Duro Wind Project Holdings, LLC Sale of AsseVInventory s 146 2,479 General Counsel Services s 146 887 Perrin Ranch Wind, LLC Power Generation Division Support s 146 4,154 Perrin Ranch Wind, LLC Transmission & Substation Support s 146 1,406 Pheasant Run Wind, LLC Corporate Finance Services s 146 714 Information Management Support s 146 2,555 Pennsylvania Windfarms, LLC Perrin Ranch Wind, LLC Post Wind Farm, L.P. Post Wind Farm, L.P. Power Generation Division Support s 146 1,362 Post Wind Farm, L.P. Transmission & Substation Support s 146 4,601 Post Wind Farm, L.P. Sale of AsseVInventory s 146 6,495 Red Mesa Wind, LLC Power Generation Division Support s 146 1,449 Red Mesa Wind, LLC 7,045 Transmission & Substation Support s 146 RGS Realty , LLC Corporate Real Estate Services s 146 5,000 RGS Realty , LLC Funding of Cash Disbursements s 146 344,000 RGS Realty , LLC Services Received by FPL p 234 3,523 RGS Realty Holdings, LLC Corporate Real Estate Services s 146 5,000 RGS Realty Holdings, LLC Funding of Cash Disbursements s 146 100,000 RGS Realty Holdings, LLC Services Received by FPL p 234 3,523 Power Generation Division Support s 146 1,138 Seiling Wind II, LLC Transmission & Substation Support s 146 1,376 Seiling Wind II, LLC Project Estimating, Design and Management Support s 146 44,211 Seiling Wind II, LLC Corporate Services s 146 4,359 Seiling Wind, LLC Power Generation Division Support s 146 2,188 Seiling Wind, LLC Transmission & Substation Support s 146 5,150 Shafter Solar, LLC Corporate Finance Services s 146 324 Shafter Solar, LLC Information Management Support s 146 41,342 Shafter Solar, LLC Transmission & Substation Support s 146 7,537 AE Seiling Wind, LLC Silver State Silver Power South, LLC Corporate Finance Services s 146 11,313 Silver State Silver Power South, LLC General Counsel Support s 146 709 Silver State Silver Power South, LLC Transmission & Substation Support s 146 18,666 Project Estimating, Design and Management Support s 146 38,431 Smart Energy Capital, LLC Information Management Support s 146 7,364 Somerset Windpower, LLC Power Generation Division Support s 146 1,382 Somerset Windpower, LLC Sale of AsseVInventory s 146 4,338 Silver State Silver Power South, LLC Page 457-17 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAffiliated Transfers and Cost Allocations FLORIDA POWER & LIGHT COMPANY For the Year Ended December 31, 2015 Name of Affiliate lal Type of Service and/or Name of Product Relevant Contract (b) (c) or Agreement and Effective Date "P"or "S" ld\ Total Chal"!le for Year Account J Dollar Number Amount te\ Ill Steele Flats Wind Project, LLC Power Generation Division Support s 146 1,532 Steele Flats Wind Project, LLC Transmission & Substation Support s 146 3,979 Story Wind, LLC Human Resources Services s 146 1,000 Story Wind, LLC Power Generation Division Support s 146 4,945 Story Wind, LLC Transmission & Substation Support s 146 10,706 Tuscola Bay Wind, LLC General Counsel Services s 146 2,657 Tuscola Bay Wind, LLC Information Management Support s 146 20,624 Tuscola Bay Wind, LLC Power Generation Division Support s 146 1,532 Tuscola Bay Wind, LLC Transmission & Substation Support s 146 1,367 Tuscola Wind II, LLC Information Management Support s 146 20,624 Tuscola Wind II, LLC Power Generation Division Support s 146 331 Tuscola Wind II, LLC Transmission & Substation Support s 146 902 Tuscola Wind II, LLC Integrated Supply Chain Services s 146 478 US Marcellus Gas Infrastructure, LLC Corporate Real Estate Services s 146 11,208 US Marcellus Gas Infrastructure, LLC Project Estimating, Design and Management Support s 146 5,321 US Marcellus Gas Infrastructure, LLC Gas Infrastructure Support s 146 7,931 US Sooner Trails Gas Infrastructure, LLC General Counsel Services s 146 905 3,912 21,246 US Sooner Trails Gas Infrastructure, LLC Marketing & Communication Services s 146 US Southeastern Gas lnfrastructuns, LLC Project Estimating, Design and Management Support s 146 US Southeastern Gas Infrastructure, LLC Marketing & Communications Services s 146 5,405 US Southeastern Gas Infrastructure, LLC General Counsel Services s 146 11,190 US Southeastern Gas Infrastructure, LLC Project Development s 146 19,560 USG Midstream Bakken I, LLC Corporate Real Estate Services s 146 2,027 USG Midstream Bakken I, LLC Information Management Support s 146 23,254 USG Midstream Bakken I, LLC Power Generation Division Support s 146 89,805 USG Midstream Bakken I, LLC Integrated Supply Chain Services s 146 801 USG Midstream Bakken I, LLC Engineering & Construction Services s 146 121,448 USG Properties Eagle Ford IV, LLC General Counsel Services s 146 5,850 Vasco Winds, LLC General Counsel Services s 146 636 Vasco Winds, LLC Power Generation Division Support s 146 1,617 Vasco Winds, LLC Transmission & Substation Support s 146 523 Waymart Wind Farm, LP General Counsel Services s 146 486 Waymart Wind Farm, LP Human Resources Services s 146 850 Waymart Wind Farm, LP Information Management Support s 146 412 Waymart Wind Farm, LP Power Generation Division Support s 146 1,756 Waymart Wind Farm, LP Transmission & Substation Support s 146 5,516 Information Management Support s 146 7,018 Wessington Wind Energy, LLC Power Generation Division Support s 146 2,167 Wessington Wind Energy, LLC Transmission & Substation Support s 146 523 West Texas Wind Energy, LLC Information Management Support s 146 4,267 West Texas Wind Energy, LLC Power Generation Division Support s 146 16,757 West Texas Wind Energy, LLC Transmission & Substation Support s 146 564 Wessington Wind Energy, LLC Page 457-18 ANALYSIS OF DIVERSIFICATION ACTIVITY Summary ofAffiliated Transfers and Cost A/wcations FLORIDA POWER & LIGHT COMPANY For the YearEndedDecember31, 2015 Type of Service and/or Name of Affiliate Name of Product Relevant Contract or Agreement and Effective Date Ia\ (b) lc\ "P"or "S" (d) Total Charge for Year Account IDollar Number lei Amount (f) White Oak Energy, LLC Power Generation Division Support s 146 4,272 White Oak Energy, LLC Transmission & Substation Support s 146 523 Wild Prairie Wind, LLC Corporate Finance Services s 146 961 Transmission & Substation Support s 146 1,087 Windlogics Inc. Corporate Real Estate Services s 146 1,964 Windlogics Inc. General Counsel Services s 146 49,974 Windlogics Inc. Human Resources Support s 146 4,053 Windlogics Inc. Corporate Services s 146 35,900 Windlogics Inc. Transmission & Substation Support s 146 5,198 Windlogics Inc. Information Management Support s 146 1,575 Windlogics Inc. Services Received by FPL p 234 511,150 Windlogics Inc. Services Received by FPL p 583 3,108 Vested Performance Dollars Transfer p 234 16,250 Power Generation Division Support 146 1,949 146 6,528 146 621 Wilton Wind II, LLC Windlogics Inc. Wlndlogics agreements dated 1/512015 and 918J2015 Wolf Ridge Wind, LLC Power Generation Division Support Wolf Ridge Wind, LLC Transmission & Substation Support s s s s s s Solar Panel Purchase p Windpower Partners 1991-2, L.P. Windpower Partners 1993, LLC Power Generation Division Support Windpower Partners 1993, LLC Transmission & Substation Support Windpower Partners 1993, LLC Zuni Solar, LLC Corporate Services 146 430 146 4,329 146 1,689 234 387,903 Footnotes and General Comments: Note 1: Services provided by FPL primarily include executive & governance, finance & accounting , corporate communications, legal, corporate real estate, human resources, payroll, security, internal audit, information management operations and maintenance, and license fees. Note 2: Services provided to affiliates are recorded in FERC account 146 (Accounts Receivable from Associated Companies). In FPL records, activity is netted at the GAAP account level before the balances are translated to FERC accounts, therefore the FERC account offset to account 146 is not separately identifiable. Note 3: Column (c) Relevant Contract or Agreement and Effective Date- all activity between FPL and its affiliates is in accordance with FPL's Cost Allocation Manual (CAM) General Comments: Items exclude payments of cash collected on behalf of Affiliates. Items exclude FPL Consolidating Entities. Page 457-19 Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset orRioht Name of Affiliate CosUOrig. Cost Accumulated Depreciation Net Book Value Fair Market Value Title Passed Yes/No Purchase or Sales Price Purchases!Transfers from Affiliates: 185 148 148 YES Pressure Switch 93 360 93 YES FPL Energy Marcus Hook LLC Pressure Switch 169 360 169 YES Lamar Power Partners, LLC Pressure Switch 949 360 360 YES Lamar Power Partners, LLC Transfer Valve FPL Energy Marcus Hook LLC Thermistor FPL Energy Marcus Hook LLC 169 11,431 169 YES 5,586 5,586 YES Lamar Power Partners, LLC Kit:SCR 5,704 Nex!Era Energy Duane Arnold, LLC Pipe 9,929 13,599 9,929 YES NextEra Energy Duane Arnold, LLC Recorder 8,285 18,433 8,285 YES Nex!Era Energy Duane Arnold, LLC Connector 1,518 1,510 1,510 YES NextEra Energy Duane Arnold, LLC Overload Relay 111 58 58 YES NextEra Energy Duane Arnold, LLC Cable 6,447 6,021 6,021 YES NextEra Energy Duane Arnold, LLC PC Control Board 4,483 4,012 4,012 YES NextEra Energy Duane Arnold, LLC Converter 2,893 6,095 2,893 YES YES NextEra Energy Duane Arnold, LLC Drive Sleeve 407 2,039 407 NextEra Energy Duane Arnold, LLC Roller Bearing Cone 234 948 234 YES NextEra Energy Point Beach, LLC Detector Assembly 158 250 158 YES Nex!Era Energy Point Beach, LLC Terry Turbine 50,000 35,000 YES NextEra Energy Point Beach, LLC Washer 484 663 484 YES NextEra Energy Point Beach, LLC Oil Pump 2,546 2,237 2,237 YES NextEra Energy Point Beach, LLC Contact Auxilary 681 526 526 YES NextEra Energy Point Beach, LLC Voltage Regulator 11,343 16,742 11,343 YES NextEra Energy Point Beach, LLC Relay 11,694 17,230 11,694 YES 46 46 YES 35,000 NextEra Energy Point Beach, LLC Elbow Tube 74 NextEra Energy Point Beach, LLC Insulation Kit 715 25,475 715 YES NextEra Energy Seabrook, LLC Switch 453 2,000 453 YES NextEra Energy Seabrook, LLC Bolt 164 780 164 YES NextEra Energy Seabrook, LLC Bellows 131 124 124 YES 456 55 55 YES 7,800 3,049 YES NextEra Energy Seabrook, LLC Transformer Output NextEra Energy Seabrook, LLC Plunger Rod 3,049 NextEra Energy Seabrook, LLC Compressor 11,119 13,495 11,119 YES NextEra Energy Seabrook, LLC Compressor 11,119 13,495 11,119 YES NextEra Energy Seabrook, LLC Hex Bolt 257 608 257 YES Page458-1 Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset orRioht Name of Affiliate Cost/Orig. Cost Accumulated Depreciation Net Book Value Fair Market Value Title Passed Yes/No Purchase or Sales Price Purs:ha§!!/Iransfers from .!,ffilij!!!!§: (continued! NextEra Energy Seabrook, LLC Sealant NextEra Energy Seabrook, LLC Waming Labels NextEra Energy Seabrook, LLC Diaphragm NextEra Energy Seabrook, LLC Relief Valve 1,431 356 356 YES 359 520 359 YES 80 48 48 YES 25,285 53,601 25,285 YES NextEra Energy Seabrook, LLC Bulkhead Tubing 575 465 465 YES NextEra Energy Seabrook, LLC Flow Indicator 537 522 522 YES NextEra Energy, Inc. Control Instrumentation 957,712 1,511,995 957,712 YES NextEra Energy, Inc. Piping 628,820 988,005 628,820 YES NextEra Energy, Inc. Generator Piping 773,932 1,770,299 773,932 YES NextEra Energy, Inc. Generator Frame Housing 373,266 853,812 373,266 YES NextEra Energy, Inc. Generator Rotor Coils 104,741 239,585 104,741 YES NextEra Energy, Inc. Generator Rotor 498,527 1,140,334 498,527 YES NextEra Energy, Inc. Generator Stator Coils 121,194 391,589 121,194 YES NextEra Energy, Inc. Generator Wedge System 293,806 672,052 293,806 YES NextEra Energy, Inc. Generator Bearing Assembly 89,966 205,787 89,966 YES NextEra Energy, Inc. Generator Coolers 51,917 118,782 51,917 YES NextEra Energy, Inc. Generator Brush Rigging 27,589 63,107 27,589 YES NextEra Energy, Inc. Generator Stator 1,286,315 3,774,957 1,286,315 YES NextEra Energy, Inc. Generator Potential TX 8,623 19,725 8,623 YES YES NextEra Energy, Inc. Transformer 257,952 750,000 257,952 North American Power Systems, LLC Fuel Nozzle 191,848 531,196 191,848 YES Northeast Energy Associates Valve:Quick Release 422 1,233 422 YES Zuni Solar, LLC Solar Panels 1,169,736 905,817 905,817 YES Zuni Solar, LLC Solar Panels 78,670 60,921 60,921 YES Zuni Solar, LLC Solar Panels 37,844 29,304 29,304 YES Zuni Solar, LLC Solar Panels 37,844 29,304 29,304 YES 61,272 YES Zuni Solar, LLC Solar Panels 79,129 61,272 Zuni Solar, LLC Solar Panels 267,434 207,082 207,082 YES Zuni Solar, LLC Solar Panels 663,080 513,474 513,474 YES 7 629 256 Total Page 458-2 Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset or Right Name of Affiliate Accumulated Depreciation Cost/Orig. Cost Net Book Value Title Passed Yes/No Purchase or Sales Price Fair Market Value Sales to Affiliates: AE-FPLE Montezuma Wind, LLC Converter 556 430 556 YES Blue Summit Wind, LLC De,Cnd,Bitd,AI,336-795,W/52-5 Skt,30K#U 650 580 650 YES Blue Summit Wind, LLC Suspension Clamp 268 238 268 YES Blue Summit Wind, LLC Spi,Cnd,Comp,Jm,AI,795ACSR-927AAAC 104 91 104 YES Blue Summit Wind, LLC Vibration Damper 71 63 71 YES Blue Summit Wind, LLC Vibration Damper 653 482 653 YES Blue Summit Wind, LLC Armor Rods 330 294 330 YES 1,195 1,015 1,195 YES 370 363 370 YES Blue Summit Wind, LLC Spi,Cnd,Comp,Ft,AI,795ACSR&TW,927AAAC Blue Summit Wind, LLC Suspension Clamp Blue Summit Wind, LLC Con,Pg,Bitd,AI,.472"-.0PGW,#4SOL OR 41 36 41 YES Blue Summit Wind, LLC CLV, Baii,15/16"0W,2-7/8"L,5/8"D,52-3&5 77 67 77 YES Blue Summit Wind, LLC CLV, Ball, 13/16"0W ,3-15/16"L,30K#D,52-5 189 98 189 YES Blue Summit Wind, LLC THBL,GUY, 1-1/16"0W,2-1/2"TD,1"PIN,60K# 261 280 280 YES Blue Summit Wind, LLC BOLT,MA,GALV, 1"X26",A325,8UNC-2A,HYHXHD 522 272 522 YES Blue Summit Wind, LLC BOLT,MA,GALV,1"X26",A325,8UNC-2A,HYHXHD 12 8 12 YES Blue Summit Wind, LLC Thimble, Eye, GALV,1.06"GD,2.5"D Loop 100 96 100 YES 1,893 1,630 1,893 YES Blue Summit Wind, LLC GRIP, GuyAdj 0-18",3/4",19D,58.3K#HS,GLV Blue Summit Wind, LLC GRIP ,Guy,Bgalv,3/4"EHS,2/3-1/8"LD,Orange 325 298 325 YES Blue Summit Wind, LLC Wire,OPGW/AW ,.472"D,48FBR, 14365# 292 158 292 YES Blue Summit Wind, LLC Link,Chain, GALV, 1/2"X1"X2-1/4",30K# 40 52 52 YES Blue Summit Wind, LLC PLT,Guy,TEE,Crvd,GALV, 1-1/8"Hole,60K# 354 319 354 YES Blue Summit Wind, LLC SHFTAnchor 2,238 1,982 2,238 YES Blue Summit Wind, LLC SHKL Anchor 71 63 71 YES Blue Summit Wind, LLC SHKLAnchor 185 132 185 YES Blue Summit Wind, LLC Washr,Crvd ,SQ,GALV, 1"Bit, 1/4"thk 125 54 125 YES Blue Summit Wind, LLC Washr,Lck,HEL SPRG,Galv, 1"Bit 9 4 9 YES Blue Summit Wind, LLC Assembly Pole Band 204 179 204 YES Blue Summit Wind, LLC Control Board 6,278 5,300 6,278 YES Capricorn Ridge Wind, LLC Wire 71,681 75,496 75,496 YES 107 YES Capricorn Ridge Wind, LLC DE,CND,COMP,1272 107 82 Capricorn Ridge Wind, LLC DE, OPGW, PREF 899 810 899 YES Capricorn Ridge Wind, LLC Suspension Clamp 1,479 1,411 1,479 YES Capricorn Ridge Wind, LLC Converter 661 573 661 YES Page 458-3 Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset or Right Name of Affiliate CosUOrig. Cost Accumulated Depreciation Net Book Value Purchase or Sales Price Fair Market Value Title Passed Yes/No Sales to Affiliates: !continued) 179 318 318 YES 1,749 1,477 1,749 YES 54 46 54 YES 2,593 2,320 2,593 YES SLV,RPR,COMPAL,21" 769 537 769 YES Capricorn Ridge Wind, LLC SPL,CND,Comp,FT Aluminum 749 713 740 YES Capricorn Ridge Wind, LLC Suspension Clamp 924 720 924 YES Capricorn Ridge Wind, LLC CON,PG,BLTD Aluminum 404 361 404 YES Capricorn Ridge Wind, LLC CON,BNZ GRD TX Tank 23 20 23 YES 189 168 189 YES 89 82 89 YES 280 308 308 YES 26 97 97 YES 342 280 342 YES 2,522 2,173 2,522 YES 10,384 6,195 10,384 YES Capricorn Ridge Wind, LLC Vibration Damper/For Optical Ground Wires Capricorn Ridge Wind, LLC Vibration Damper/Conductor Capricorn Ridge Wind, LLC Vibration Damper/Aluminum Conductor for Steel Capricorn Ridge Wind, LLC Armor Rods Capricorn Ridge Wind, LLC Capricorn Ridge Wind, LLC CLV-Y Ball, 52-5, 1.5" Capricorn Ridge Wind, LLC Thimble Capricorn Ridge Wind, LLC Guy Thimble Capricorn Ridge Wind, LLC Wire Capricorn Ridge Wind, LLC Downlead Clamp Capricorn Ridge Wind, LLC Grip Guy Capricorn Ridge Wind, LLC Wire Capricorn Ridge Wind, LLC Bands 535 470 535 YES Capricorn Ridge Wind, LLC Buckle for Banding 185 224 224 YES Capricorn Ridge Wind, LLC Giant Banding Tool 395 336 395 YES Conestoga Wind, LP Diode 57 33 57 YES Conestoga Wind, LP Adapter 124 231 231 YES Conestoga Wind, LP Capacitor 35 13 35 YES Conestoga Wind, LP Relay 87 56 87 YES Ensign Wind, LLC Suspension 488 436 488 YES Ensign Wind, LLC CON, Bolted, #6·1/0 3 3 3 YES Ensign Wind, LLC Vibration Damper 102 95 102 YES Ensign Wind, LLC Armor Rods 520 465 520 YES Ensign Wind, LLC Suspension Clamp 554 432 554 YES Ensign Wind, LLC Wire/Cable 168 146 168 YES Ensign Wind, LLC Converter/Comparator 8 7 8 YES Ensign Wind, LLC Converter/Comparator 100 88 100 YES Ensign Wind, LLC Converter 242 214 242 YES Ensign Wind, LLC CLV, Y-Ball,52·5,1.5" OW 210 187 210 YES Page 458-4 Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset or Right Name of Affiliate Accumulated Depreciation CosUOrig. Cost Net Book Value Title Passed Yes/No Purchase or Sales Price Fair Market Value Sales to Affiliates: (continued) 299 455 455 YES Ensign Wind, LLC Dual Socket Ensign Wind, LLC CLV, Thimble, 35000 LB 138 132 138 YES Ensign Wind, LLC Rods/Threadless, Copper Clad 216 231 231 YES Ensign Wind, LLC Sil Suspension Insulators 230KV 1,736 1,553 1,736 YES Ensign Wind, LLC LPOST Poly Insulators 3,977 3,551 3,977 YES Ensign Wind, LLC Multi HeIix Steel Anchors 123 108 123 YES Ensign Wind, LLC Stud Anchor 487 435 487 YES Ensign Wind, LLC Stud Anchor 1,584 1,389 1,584 YES Ensign Wind, LLC BKT,OHGW, Loop 694 243 694 YES Ensign Wind, LLC Converter 146 140 146 YES Ensign Wind, LLC Converter 529 475 529 YES Ensign Wind, LLC Converter 227 181 227 YES Ensign Wind, LLC Galvanized Rope Thimbles 159 153 159 YES Ensign Wind, LLC Galvanized Rope Thimbles 119 162 162 YES Ensign Wind, LLC Grip Guy 285 264 285 YES Ensign Wind, LLC Wire 2,230 1,980 2,230 YES Ensign Wind, LLC NuULock/Palnut 13 27 27 YES Ensign Wind, LLC NuULock/Palnut 108 94 108 YES 128 YES Ensign Wind, LLC Plt,PLE,Eye, Galvanized 63 128 Ensign Wind, LLC Plated Twisted Eye 5/8" 613 541 613 YES Ensign Wind, LLC Marker, GUY, Yellow, Polyethylene 74 65 74 YES Ensign Wind, LLC SHFT Anchor 106 95 106 YES Ensign Wind, LLC SHFT Anchor 223 198 223 YES Ensign Wind, LLC SHKLAnchor 18 16 18 YES Ensign Wind, LLC Staple 262 230 262 YES 13 20 YES Ensign Wind, LLC Curved Washer 20 Ensign Wind, LLC Curved Washer 7 14 14 YES Ensign Wind, LLC Curved Washer 287 123 287 YES Ensign Wind, LLC Flat Round Washer 14 11 14 YES Ensign Wind, LLC Double Spring Lock Washer 12 3 12 YES 2 1 2 YES Ensign Wind, LLC Bolts Ensign Wind, LLC Spring Washer 96 306 306 YES Ensign Wind, LLC Double Spring Lock Washer 71 63 71 YES Page 458-5 Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset or Right Name of Affiliate Cost/Orig. Cost Accumulated Depreciation Net Book Value Purchase or Sales Price Fair Market Value Title Passed Yes/No Sales to Affiliate§: !continued! FPL Energy Cabazon Wind, LLC Fuse Block 434 397 434 YES FPL Energy Cabazon Wind, LLC Tinned Copper Braid 183 62 183 YES FPL Energy Cabazon Wind, LLC Bronze Ground Connector 11 7 11 YES FPL Energy Cabazon Wind, LLC Cable 110 38 110 YES FPL Energy Cowboy Wind, LLC Vinyl Caps 66 6 66 YES FPL Energy Cowboy Wind, LLC Converter 34 15 34 YES 360 0 360 YES FPL Energy Cowboy Wind, LLC Cable FPL Energy Cowboy Wind, LLC Tie Cable 5-3/4" 14 0 14 YES FPL Energy Cowboy Wind, LLC Tie Cable 2-1/2" 12 0 12 YES FPL Energy Cowboy Wind, LLC Lug Ring 45 0 45 YES FPL Energy Cowboy Wind, LLC Lug Ring 58 0 58 YES FPL Energy Horse Hollow Wind, LLC Relay 44 39 44 YES FPL Energy Horse Hollow Wind, LLC Relay 19 15 19 YES FPL Energy Horse Hollow Wind, LLC Con,Cu,Trm,Comp, Lug,Ring,#12-14,Stud#10 82 60 82 YES FPL Energy Horse Hollow Wind, LLC Tag ID, Fiber, 1-1/4" Dia, 1EA=Bag of 100 24 22 24 YES FPL Energy Horse Hollow Wind, LLC Tie,Cbi,Nylon,Self Locking,S-3/4", Black 58 20 58 YES FPL Energy Horse Hollow Wind, LLC Tie,Cbi,Nylon,Self Locking,2-1/2", Black 40 10 40 YES FPL Energy Horse Hollow Wind, LLC Clv, Y-Eye, 90D,1-3/4"EW, 2-(7-9)/16"L,30K 62 71 71 YES FPL Energy Horse Hollow Wind, LLC Clv, Y-Eye, 90D,2.5"EW, 2-(7-10)/16"L,3/4"P 52 63 63 YES FPL Energy Horse Hollow Wind, LLC Clmp,Susp,Cnd,AI, 954-1431ACSR, W/90D Clvs 262 346 346 YES 279 246 279 YES 648 578 648 YES 46 4,000 4,000 YES FPL Energy Horse Hollow Wind, LLC Rod,Armr,Pref,AI,.365"D, 1OO"L, 1272ACSR FPL Energy Marcus Hook LLC Screw Cap FPL Energy Marcus Hook LLC EOL Srap Parts FPL Energy Marcus Hook, L.P. Cplr,Opticai,Minimum 6ft., USB 584 15 584 YES FPL Energy Marcus Hook, L.P. Modem Fiber Optic Tranceiver Sel 2830M 402 318 402 YES FPL Energy New Mexico Wind, LLC Concealed Vertical Rod 168 165 168 YES FPL Energy New Mexico Wind, LLC Band Clamping Screw FPL Energy Oklahoma Wind, LLC Bkt,Ohgw,Loop,Galv, 16"L,3/4"Bit,6"Thd FPL Energy Oklahoma Wind, LLC Washer, Spring Bolt FPL Energy Oklahoma Wind, LLC 51 19 51 YES 1,665 2,617 2,617 YES 11 7 11 YES Stud,Da, 1"X36",A325/A449,AII Thd 3,116 2,623 3,116 YES FPL Energy Oklahoma Wind, LLC Armor Rods 2,018 1,835 2,018 YES FPL Energy Oklahoma Wind, LLC Suspension Clamp 1,935 1,725 1,935 YES Page458~ Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset or Right Name of Affiliate Cost/Orig. Cost Accumulated Depreciation Net Book Value Purchase or Sales Price Fair Market Value Title Passed Yes/No Sales to Affiliates: !continued) FPL Energy Oklahoma Wind, LLC Clv,Y-Ball,52-5, 1.5"0w,3.25"L,3/4"Bit,30 525 468 525 YES FPL Energy Oklahoma Wind, LLC lns,Lpost,Poly, 138Kv,2.5"X60", 1290#Cant 11,022 9,863 11,022 YES FPL Energy Oklahoma Wind, LLC lns,Lpost,Sil, 138Kv,2.5X80", 180"Lk,900#C 7,062 6,319 7,062 YES FPL Energy Oklahoma Wind, LLC Curved Washer 435 341 435 YES FPL Energy Oklahoma Wind, LLC Flat Round Washer 46 38 46 YES FPL Energy Oklahoma Wind, LLC Con,Cu,Cmpr,H-Type,#S-4 Cu To #2-1/0 Cu 60 53 60 YES FPL Energy Oklahoma Wind, LLC Con,Cu,Cmpr,H-Type,#8-4 Cu To #8-4 Cu 63 55 63 YES FPL Energy Oklahoma Wind, LLC Con,Trm,Bitd,Gv, 15D, 1Hp,#4-2/0Cu-1"Bit 735 657 735 YES 510 461 510 YES FPL Energy Oklahoma Wind, LLC Staple FPL Energy Oklahoma Wind, LLC Wire 2,451 2,599 2,599 YES FPL Energy Oklahoma Wind, LLC Wire/Cable 1,640 1,340 1,640 YES FPL Energy Oklahoma Wind, LLC Rod Guard 499 427 499 YES FPL Energy Oklahoma Wind, LLC Chrg,Cadweld Plus,One Shot, Type Gt 153 138 153 YES FPL Energy Oklahoma Wind, LLC Coating,Preserv,Wd Ple,Cu-Napth Sol,160z 113 194 194 YES FPL Energy Oklahoma Wind, LLC Cap,Wd Pie, Mastic Cloth, 19"D,3/16"Th 484 497 497 YES Slv,Rpr,Comp,AI, 19-1/8"L,795Acsr&Aac,927 241 172 241 YES FPL Energy Oklahoma Wind, LLC Con,Trm,Bitd,Gv, 15D, 1Hp,#4-2/0Cu,3/4"Bit 376 330 376 YES FPL Energy Oklahoma Wind, LLC Tooi,Eiectronic Igniter For Cadweld Plus 112 100 112 YES FPL Energy Oklahoma Wind, LLC Coating, Zinc Rich, Organic 9 8 9 YES FPL Energy Oklahoma Wind, LLC Mrkr,Sw,"1",Yellow On Black 35 29 35 YES FPL Energy Oklahoma Wind, LLC Mrkr,Sw,"2",Yellow On Black 23 19 23 YES FPL Energy Oklahoma Wind, LLC Mrkr,Sw,"3",Yellow On Black 12 10 12 YES FPL Energy Oklahoma Wind, LLC Mrkr,Sw,"4",Yellow On Black 12 10 12 YES Mrkr,Sw,"5",Yellow On Black 12 10 12 YES FPL Energy Oklahoma Wind, LLC Mrkr,Sw,6/9,Yellow On Black 23 19 23 YES FPL Energy Oklahoma Wind, LLC Mrkr,Sw,"7",Yellow On Black 12 10 12 YES FPL Energy Oklahoma Wind, LLC Mrkr,Sw,"8",Yellow On Black 12 10 12 YES FPL Energy Oklahoma Wind, LLC Mrkr,Sw,"O",Yellow On Black 12 10 12 YES FPL Energy Oklahoma Wind, LLC Mrkr,Sw,"A",Yellow On Black FPL Energy Oklahoma Wind, LLC FPL Energy Oklahoma Wind, LLC 6 5 6 YES 341 306 341 YES 5,257 4,613 5,257 YES FPL Energy Oklahoma Wind, LLC Plt,Vert,Piastic,For Switch Num/Let FPL Energy Oklahoma Wind, LLC Con,Trm,Bitd,Gv, 15D, 1Hp,#4-2/0Cu,3/4"Bit FPL Energy Oklahoma Wind, LLC Wire,Tie,#4,198' Spi,Soi,Sdb,Cu 822 665 822 YES FPL Energy Oklahoma Wind, LLC Con,Cu,Cmpr,H-Type,#6-4 Cu To #6-4 Cu 529 462 529 YES Page 458-7 Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset orRi!lht Name of Affiliate Cost/Orig. Cost Accumulated Depreciation Net Book Value Purchase or Sales Price Fair Market Value Title Passed Yes/No Si!II!S to Affili!!t@s: !continued! 17 14 17 YES Suspension Insulator 230KV 85" 2,668 2,408 2,668 YES FPL Energy Oklahoma Wind, LLC Suspension Insulator 230KV 76" 4,825 4,314 4,825 YES FPL Energy Oklahoma Wind, LLC Plated Twisted Eye 5/8" 2,563 2,283 2,563 YES FPL Energy Oklahoma Wind, LLC SHKLAnchor 235 208 235 YES FPL Energy Oklahoma Wind, LLC Dual Socket 345 523 523 YES FPL Energy Oklahoma Wind, LLC Stud Anchor 1,349 1,157 1,349 YES 50 39 50 YES 378 170 378 YES FPL Energy Oklahoma Wind, LLC Mrkr,Sw,"1",Yellow On Black FPL Energy Oklahoma Wind, LLC FPL Energy Oklahoma Wind, LLC Nut, Lock, Palnut, 1" FPL Energy Oklahoma Wind, LLC Curved Washer FPL Energy Oklahoma Wind, LLC Flat Round Washer 22 14 22 YES FPL Energy Oklahoma Wind, LLC Double Spring Lock Washer 85 255 255 YES FPL Energy Oklahoma Wind, LLC Converter/Comparator 112 95 112 YES FPL Energy Oklahoma Wind, LLC Converter 669 593 669 YES 376 YES FPL Energy Oklahoma Wind, LLC Wire/Cable 376 296 FPL Energy Oklahoma Wind, LLC CLV Socket 466 1,112 1,112 YES FPL Energy Oklahoma Wind, LLC Cable 360 0 360 YES FPL Energy Oklahoma Wind, LLC Tie Cable 14 0 14 YES FPL Energy Oklahoma Wind, LLC Tie Cable 12 0 12 YES FPL Energy Oklahoma Wind, LLC Lug Ring 45 0 45 YES FPL Energy Oklahoma Wind, LLC Lug Ring 35 0 35 YES 66 YES FPL Energy Oklahoma Wind, LLC Vinyl Caps 66 6 FPL Energy Oklahoma Wind, LLC Converter 34 15 34 YES FPL Energy Upton Wind I, LP Lubricant,666, Silicone, 13 Oz Spray 112 90 112 YES FPL Energy Upton Wind I, LP Silicone Spray for Insulators 102 172 172 YES FPL Energy Upton Wind I, LP Concealed Vertical Rod 586 551 586 YES FPL Energy Wyman, LLC Sileo Exiter Parts 46 1,000 1,000 YES 1,092 946 1,092 YES FPL Fibernet, LLC Splice Case FPL Fibernet, LLC Ground, 1/10 Cu, Length 6' 835 696 835 YES FPL Fibernet, LLC Ground, 1/10 Cu, Length 10' 533 646 646 YES FPL Fibernet, LLC Ground, 1/10 Cu, Length 20' 420 548 548 YES FPLE Forney, LLC Cable 196 135 196 YES 1,164 1,000 1,164 YES 248 180 248 YES FPLE Forney, LLC Sensor FPLE Forney, LLC Relay Page 458-8 Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset or Right Name of Affiliate Cost/Orig. Cost Accumulated Depreciation Net Book Value Fair Mariket Value Purchase or Sales Price Title Passed Yes/No Sales to Affiliates: (continued) 291 219 291 YES 46 200 200 YES 1,151 1,150 1,151 YES Copper Flat Bus Bar 614 31 614 YES Hawkeye Power Partners, LLC Belleville Washer 182 110 182 YES High Majestic Wind II, LLC BSH, HV, 138KV, 800A 1251nch Creep 9,551 8,666 9,551 YES Javelina Wind Energy, LLC Unit Tunng Band 3,126 2,756 3,126 YES Javelina Wind Energy, LLC Padlock 1,573 61 1,573 YES Lake Benton Power Partners II Ground Cluster Bar FPLE Forney, LLC Relay FPLE Forney, LLC LCI System FPLE Forney, LLC Radiation Exhaust Shield Hawkeye Power Partners, LLC 385 576 576 YES 1,361 YES Lamar Power Partners, LLC Input 8 PT. Snap Track Typ 654 1,361 Lamar Power Partners, LLC Metal Hose 370 316 370 YES Lamar Power Partners, LLC Gas Hose 1,319 668 1,319 YES Lamar Power Partners, LLC Gas Hose 390 334 390 YES Lamar Power Partners, LLC Gas Hose 895 786 895 YES Lamar Power Partners, LLC Gas Hose 1,331 804 1,331 YES Lamar Power Partners, LLC Gas Hose 1,137 671 1,137 YES 46 4,000 4,000 YES Lamar Power Partners, LLC EOL Srap Parts Lamar Power Partners, LLC Radiation Exhaust Shield 1,151 443 1,151 YES Lamar Power Partners, LLC Linear Transducer 3,926 1,663 3,926 YES Lamar Power Partners, LLC Lock Nuts 1,415 1,180 1,415 YES Lamar Power Partners, LLC Bolt 147 242 242 YES Lamar Power Partners, LLC Nut 227 117 227 YES Lamar Power Partners, LLC Hose 4,487 5,302 5,302 YES Lamar Power Partners, LLC Gas Hose 1,350 1,207 1,350 YES Lamar Power Partners, LLC Metal Gas Hose 585 809 809 YES Lamar Power Partners, LLC Metal Gas Hose 553 801 801 YES Lamar Power Partners, LLC Metal Gas Hose 368 328 368 YES Lamar Power Partners, LLC Metal Gas Hose 1,223 328 1,223 YES Lamar Power Partners, LLC Metal Gas Hose 481 429 481 YES Lamar Power Partners, LLC Metal Gas Hose 1,290 839 1,290 YES Lamar Power Partners, LLC Metal Gas Hose 368 328 368 YES Lamar Power Partners, LLC Metal Gas Hose 372 331 372 YES Page 458-9 Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31,2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset or Right Name of Affiliate CosUOrig. Cost Accumulated Depreciation Net Book Value Fair Market Value Purchase or Sales Price Title Passed Yes/No Sale! to Affiliat!!s: (continued) LamarPowerPartners,LLC Metal Gas Hose 372 331 372 YES Lamar Power Partners, LLC Screw 120 81 120 YES Lamar Power Partners, LLC Nut Lock 41 32 41 YES 646 646 YES Lamar Power Partners, LLC Bolt 391 Lamar Power Partners, LLC Nut Lock 532 480 532 YES Lamar Power Partners, LLC Studs 162 222 222 YES Lone Star Transmission, LLC Stud, Da, 1"x36", A325/A449, All Thd 292 247 292 YES Lone Star Transmission, LLC Stud, Da, 1"x32", A325/A449, All Thd 269 238 269 YES Lone Star Transmission, LLC Stud, Da, 1"x40", A325/A449, All Thd 1,694 1,402 1,694 YES Lone Star Transmission, LLC Stud, Da, 1"x44", A325/A449, All Thd 2,114 1,649 2,114 YES Lone Star Transmission, LLC Wsher,Fit, Rnd,Galv,F436,2", 1" Bit 175 112 175 YES Mill Run Windpower, LLC Bsh, Standoff, Loadbreak,25KV 368 257 368 YES Mill Run Windpower, LLC Terminator, Renewal Part, Male Pin SML IN 146 89 146 YES Mill Run Windpower, LLC Electric Lug 6,056 5,342 6,056 YES Mill Run Windpower, LLC Connector 52 46 52 YES Mill Run Windpower, LLC Elbow Arrester Surge 277 207 277 YES NAPS Wind, LLC Relay 11,704 9,400 11,704 YES 941 24 941 YES YES NAPS Wind, LLC DE, OPGW.461-.477" NAPS Wind, LLC Vibration Damper 159 142 159 NAPS Wind, LLC Downlead Clamp 356 433 433 YES NAPS Wind, LLC Downlead Clamp 300 468 468 YES NAPS Wind, LLC Band 330 282 330 YES NAPS Wind, LLC Buckle for Banding 18 15 18 YES NAPS Wind, LLC Wire 1,208 1,190 1,208 YES NAPS Wind, LLC CON,BNZ, GRD TX TANK 347 304 347 YES NAPS Wind, LLC SPL,CND,COMP,FT, Aluminum 667 591 667 YES NAPS Wind, LLC NUT,EYE Galvanized 3/4"D 29 25 29 YES NAPS Wind, LLC SHKLAnchor 112 100 112 YES NAPS Wind, LLC Compressor 2,294 1,631 2,294 YES 2,248 1,749 2,248 YES 52 33 52 YES 119 231 231 YES 30 13 30 YES NAPS Wind, LLC ARR Surge 36KV NAPS Wind, LLC Diode NAPS Wind, LLC Adapter NAPS Wind, LLC Ceramic Disk CPCTR Page 458-10 ~-~---~---- Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset or Right Name of Affiliate Cost/Orig. Cost Accumulated Depreciation Net Book Value Title Passed Yes/No Purchase or Sales Price Fair Market Value Sales to Affiliates: !continued) NAPS Wind, LLC Converter NextEra Energy Duane Arnold, LLC Ball Bearing NextEra Energy Duane Arnold, LLC Sealant NextEra Energy Duane Arnold, LLC Pressure Switch Gasket NextEra Energy Duane Arnold, LLC Circuit Board 76 56 76 YES 523 498 523 YES 1,113 732 1,113 YES 676 600 676 YES 1,840 4,012 4,012 YES NextEra Energy Duane Arnold, LLC Valve 362 123 362 YES NextEra Energy Duane Arnold, LLC Relay 2,558 7,267 7,267 YES NextEra Energy Duane Arnold, LLC Fuse Block 220 376 376 YES NextEra Energy Duane Arnold, LLC Pipe Nipple 49 3 49 YES NextEra Energy Duane Arnold, LLC Plug Cable 9,363 4,665 9,363 YES NextEra Energy Duane Arnold, LLC Nuts 298 159 298 YES NextEra Energy Point Beach, LLC Gasket 142 30 142 YES NextEra Energy Point Beach, LLC Temperature Switch 2,270 3,141 3,141 YES 9,424 YES NextEra Energy Point Beach, LLC Switch 7,299 9,424 NextEra Energy Point Beach, LLC Switch 425 2,500 2,500 YES NextEra Energy Point Beach, LLC Switch 172 505 505 YES NextEra Energy Point Beach, LLC Cable 544 250 544 YES NextEra Energy Point Beach, LLC Grease 2,671 5,666 5,666 YES NextEra Energy Point Beach, LLC Cable 608 490 608 YES NextEra Energy Point Beach, LLC Diode 49 0 49 YES NextEra Energy Point Beach, LLC Diode 97 4 97 YES 314 314 YES NextEra Energy Point Beach, LLC Adaptor 157 NextEra Energy Point Beach, LLC Oil 874 117 874 YES NextEra Energy Point Beach, LLC Paint 3,869 3,423 3,869 YES NextEra Energy Point Beach, LLC Lantern Ring 257 415 415 YES NextEra Energy Point Beach, LLC Sealant 2,050 1,765 2,050 YES 14,410 21,380 21,380 YES 70 25 70 YES 1,290 273 1,290 YES NextEra Energy Point Beach, LLC Pump NextEra Energy Point Beach, LLC 0 Ring NextEra Energy Point Beach, LLC Fire Detector Probe NextEra Energy Point Beach, LLC Detector 91,856 102,657 102,657 YES NextEra Energy Point Beach, LLC Terminal 149 5 149 YES Nextera Energy Resources Relay 248 180 248 YES Nextera Energy Resources Relay 291 219 291 YES NextEra Energy Seabrook, LLC Relay 2,041 416 2,041 YES Page 458-11 Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the right to use assets. Description of Asset or Right Name of Affiliate Cost/Orig. Cost Accumulated Depreciation Net Book Value Purchase or Sales Price Fair Market Value Title Passed Yes/No Sale!! to Affiliates: !continued! NextEra Energy Seabrook, LLC Relay NextEra Energy Seabrook, LLC Motor Connection Kit 1,289 1,149 1,289 YES 920 965 965 YES NextEra Energy Seabrook, LLC Power Module 17,529 48,000 48,000 YES NextEra Energy Seabrook, LLC Power Supply 17,102 15,204 17,102 YES NextEra Energy Seabrook, LLC Monitor Pump 40,404 30,122 40,404 YES NextEra Energy Seabrook, LLC Valve 179 158 179 YES NextEra Energy Seabrook, LLC Filter 3,091 1,996 3,091 YES NextEra Energy Seabrook, LLC Gasket 850 465 850 YES NextEra Energy Seabrook, LLC Tape 2,652 55 2,652 YES NextEra Energy Seabrook, LLC Pump 16,241 12,852 16,241 YES North Jersey Energy Associates, LP Relay 1,117 2,396 2,396 YES Osceola Windpower, LLC Suspension Clamp 421 357 421 YES Osceola Windpower, LLC Armor Rods 507 432 507 YES Peetz Table Wind Energy, LLC Clmp,Jmpr,Bitd,Fxd,Rge 1.00" To 1.4" Dia 5,133 3,926 5,133 YES Peetz Table Wind Energy, LLC Guard,Animal,1.25"x12', Ins Cvr Hose 3,325 2,917 3,325 YES Peetz Table Wind Energy, LLC Cvr,Multi-Rod,Polyethylene,Mini-Xena 2,623 2,753 2,753 YES Peetz Table Wind Energy, LLC Cvr,Angled Multi-Rod, Polyethylene 227 215 227 YES Peetz Table Wind Energy, LLC Gd, Animai,Cid shrink Tape, Gray, 1"X36' 188 168 188 YES Peetz Table Wind Energy, LLC Band Clamping Screw 263 195 263 YES Peetz Table Wind Energy, LLC Suspension Clamp 94 68 94 YES Peetz Table Wind Energy, LLC Vibration Damper 25 16 25 YES Peetz Table Wind Energy, LLC BKT,OHGW, Loop 22" 28 77 77 YES Peetz Table Wind Energy, LLC Round Washer 2 0 2 YES Peetz Table Wind Energy, LLC Armor Rods 177 147 177 YES Peetz Table Wind Energy, LLC Suspension Clamp 114 91 114 YES Peetz Table Wind Energy, LLC CLV, Y-Eye,90D,1-3/4" 107 204 204 YES Peetz Table Wind Energy, LLC Grip Guy 2,762 128 2,762 YES Peetz Table Wind Energy, LLC Clamp 143 9 143 YES Peetz Table Wind Energy, LLC Guy Thimble 179 22 179 YES Peetz Table Wind Energy, LLC Wire 4,180 4 4,180 YES Pennsylvania Windfarms, LLC SW-Phone LN, SWER, Teltone, M-396 2,479 2,200 2,479 YES Page 458-12 Analysis of Diversification Activity Assets or Rights Purchased from or Sold to Affiliates Florida Power & Light Company For the Period Ended December 31, 2015 Provide a summary of affiliated transactions involving asset transfers or the rtght to use assets. Descrtption of Asset or Right Name of Affiliate Cost/Ortg. Cost Accumulated Depreciation Net Book Value Purchase or Sales Prtce Fair Market Value Title Passed Yes/No Sales to Affiliates: !continued) Post Wind Farm, LP SPL,CND, COMP, FT Aluminum 322 254 322 YES Post Wind Farm, LP Suspension Insulator 230KV 76" 336 127 336 YES Post Wind Farm, LP DE,OPGW,Pref .461-.477 2,243 2,003 2,243 YES Post Wind Farm, LP Suspension Clamp 191 181 191 YES Post Wind Farm, LP Plt,PLE,Eye, Galvanized 542 1,123 1,123 YES Post Wind Farm, LP Pit Curved GUY 1,025 956 1,025 YES Post Wind Farm, LP Curved Gain Grtd 100 565 565 YES Post Wind Farm, LP Bolts 70 31 70 YES Post Wind Farm, LP Washer 5 81 81 YES Post Wind Farm, LP BKT, OHGW, Loop 59 8 59 YES Post Wind Farm, LP Curved Washer 48 32 48 YES Post Wind Farm, LP Studs 324 284 324 YES Post Wind Farm, LP Bolts 110 76 110 YES Somerset Windpower LLC Transformer 1,375 1,231 1,375 YES Somerset Windpower, LLC Elbow Arrester Surge 277 207 277 YES Somerset Windpower, LLC Electrtc Lug 4,061 3,562 4,061 YES Total 644 208 Footnotes and General Comments: Note 1: Activity includes Materials and Supplies /Non - Capital Items Page 458-13 Analysis ofDiversification Activity Employee Transfers Florida Power & Light Company For the Year Ended December 31, 2015 List Employees earning more than $30,000 annually transferred from/to the utility from/to an affiliate company. Employee Company Transferred from "C Ill IC ID ~ C1l CD .... I 11784 14351 35689 43133 73422 19199 13346 15188 23940 26495 29153 33308 36028 72801 74509 24510 35424 41443 73854 74970 17249 30124 32181 42849 15764 17526 24853 75111 17112 33754 41575 41655 42264 44208 74303 75589 75601 75614 75628 76650 11565 19713 24936 27054 28472 42026 72550 Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Company Transferred to Old Job Assignment New Job Assignment NextEra Project Mgmt NextEra Operating Srvs NextEra Duane Arnold NextEra Point Beach NextEra Energy Resources, LLC NextEra Energy Resources, LLC FPL Energy Services, Inc NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Project Mgmt NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Project Mgmt FPL Energy Services, Inc NextEra Energy Resources, LLC NextEra Transmission, LLC FPL FiberNet, LLC NextEra Energy Resources, LLC NextEra Duane Arnold NextEra Power Mktg NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Operating Srvs NextEra Energy Pipeline Srvcs NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC FPL Energy Services, Inc NextEra Energy Pipeline Srvcs NextEra Energy Pipeline Srvcs NextEra Energy Pipeline Srvcs NextEra Energy Pipeline Srvcs NextEra Energy Pipeline Srvcs NextEra Energy Seabrook, LLC FPL Energy Services, Inc NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC WindLogics Inc N Planner Scheduler I PGD Central Maintenance Manager N Maintenance Section Supervisor N Operations Site Director PGD Associate Business Analyst PGD Technical Services General Mgr Administrative Technician Sr Director Business Services - PO PGD Technical Services Manager Resource Lead - Dsbn Sr Engineer- TIS N Engineer I Tax Director Sr HR Advisor Sr Communication Specialist Manager - Construction Sr Paralegal Sr. Manager Strategic Initiatives Legal Assistant PGD Engineer Business Analyst II IT Systems Administrator S Sr Manager Regulatory Affairs Accounting Technician Supply Chain Specialist N Engineering Site Manager HR Advisor I Paralegal Manager Supply Chain PWQ Specialist Pipeline Controller IT Database Administrator P Mgr of Auditing Sr Accountant Communication Specialist Associate Pipeline Controller Associate Pipeline Controller Associate Pipeline Controller Pipeline Controller Associate Pipeline Controller N Engineer Principal Field Collector Principal Business Analyst - Dsbn Supply Chain Analyst - NSC IT Business Systems Analyst Principal Executive Administrative Assistant IT ERP Business Solutions Manager PGD Central Maintenance Planner PGD Central Maintenance Manager N Mtn Online/Outage Coordinator N Plant General Manager PGD Associate Business Analyst PGD Technical Services General Mgr Administrative Specialist I VP Business Management PGD Production Assurance General Manager Engineer I System Operations Manager- NEER T/S N Engineer Senior Tax Director Sr Labor Relations Consultant Sr Communication Specialist Sr Project Manager - E&C Sr Regulatory Affairs Analyst Sr. Manager Strategic Initiatives Administrative Technician PGD Engineer Accountant I Infrastructure Specialist Sr Manager Regulatory Affairs Sales Support - FPL FiberNet Sourcing Specialist I N Engineering Site Manager - Design Quantitative Analyst Paralegal Sr Project Manager - E&C PGD Business Services Tech NextEra Pipeline Controller IT Database Administrator P Manager - Portfolio & Business Budget Analyst Sr Communication Specialist Pipeline Controller- NEPS Pipeline Controller - NEPS Pipeline Controller- NEPS Pipeline Controller Associate Pipeline Controller N Planning Section Supervisor Field Technician Quality Program Manager N Engineering Analyst II Principal Project Engineer Administrative Technician Trade Services Supervisor Florida Power & Light Company For the Year Ended December 31,2015 List Employees earning more than $30,000 annually transferred from/to the utility from/to an affiliate company. Employee Com1;1any Transferred from , Ill r.c CD ""' CJI CD N 13492 Florida Power & Light Company 23189 Florida Power & Light Company 29080 Florida Power & Light Company 74420 Florida Power & Light Company 75784 Florida Power & Light Company 25157 Florida Power & Light Company 28421 Florida Power & Light Company 15722 Florida Power & Light Company 20203 Florida Power & Light Company 22184 Florida Power & Light Company 42823 Florida Power & Light Company 72854 Florida Power & Light Company 73077 Florida Power & Light Company 76095 Florida Power & Light Company 19052 Florida Power & Light Company 35669 Florida Power & Light Company 43730 Florida Power & Light Company 28167 Florida Power & Light Company 42520 Florida Power & Light Company 42639 Florida Power & Light Company 43341 Florida Power & Light Company 22139 Florida Power & Light Company 34555 Florida Power & Light Company 35818 Florida Power & Light Company 43723 Florida Power & Light Company 74682 Florida Power & Light Company 74759 Florida Power & Light Company 29835 Florida Power & Light Company 33039 Florida Power & Light Company 34388 Florida Power & Light Company 72708 Florida Power & Light Company 77056 Florida Power & Light Company 29865 Florida Power & Light Company 41864 Florida Power & Light Company 74100 Florida Power & Light Company 18867 Florida Power & Light Company 25808 Florida Power & Light Company 31418 Florida Power & Light Company 42592 Florida Power & Light Company 77066 Florida Power & Light Company 28609 Florida Power & Light Company 30676 Florida Power & Light Company 14345 Florida Power & Light Company 19399 Florida Power & Light Company 24639 Florida Power & Light Company 41891 Florida Power & Light Company 73939 Florida Power & Light Company 76828 Florida Power & Light Company 23549 Florida Power & Light Company 24830 Florida Power & Light Company Com1;1any Transferred to Old Job Assignment New Job Assignment FPL Energy Services, Inc NextEra Project Mgmt NextEra Operating Srvs NextEra Power Mktg NextEra Energy Resources, LLC FPL Energy Services, Inc NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC FPL Energy Services, Inc NextEra Energy Resources, LLC FPL Energy Services, Inc Nex!Era Energy Resources, LLC NextEra Project Mgmt NextEra Energy Resources, LLC NextEra Energy Resources, LLC WindLogics Inc NextEra Energy Resources, LLC NextEra Power Mktg FPL Energy Services, Inc NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC FPL Energy Services, Inc NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Project Mgmt FPL Energy Services, Inc NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Duane Arnold NextEra Energy Resources, LLC NextEra DG Operations, LLC Nex!Era Energy Resources, LLC Nex!Era Energy Resources, LLC FPL FiberNet, LLC FPL Energy Services, Inc Administrative Specialist I Manager Supply Chain Sr PGD Maintenance Specialist Intermediate Internal Auditor Associate Financial Analyst Meter Reader Lead PGD Engineer NEXTeam Project Manager Environmental Services Project Manager Financial Analyst I Accounting Technician Supply Chain Specialist Mgr of Finance Manager Project Development Customer Accounting Representative Supply Chain Specialist IT ERP Business Systems Analyst Prin Sr Accounting Technician Accountant II Principal Financial Analyst Receipt Inspector IT Project Manager S Sr PGD Engineer Sr Tax Analyst Tax Analyst Associate Tax Analyst Assoc Engineer- TIS Administrative Specialist Ill N QC Specialist Principal Infrastructure Specialist Engineer I -TIS Sr Sales Rep-Commercial & Industrial Account Specialist Chemist Central Lab Investor Relations Analyst PGD Plant General Manager Manager Business Services - PD Principal Investor Relations Analyst IT Performance Supervisor Sourcing Specialist II IT Business Systems Analyst S PGD Staff Engineer Reliability Standards & Compliance Manag N Maintenance Section Supervisor Production Manager I Lead Business Spec Sr Internal Auditor N Engineer Associate IT Network Engineer P Sr. Manager ISC Support Services Account Specialist Manager Due Diligence PGD Central Maintenance Leader Principal Derivative Accountant Assoc Business Services Specialist Field Technician N Engineer I Senior Reliability Specialist Environmental Services Project Manager Sr Financial Analyst Accounting Technician Product Manager FPLES Director Business Management Project Manager Development Administrative Technician Sourcing Specialist I Sr Quantitative Analyst Executive Administrative Assistant Accountant I Sr Scheduler Technical Specialist I- TIS Rotational Assignment -NextEra Resources Sr PGD Engineer Sr Tax Analyst Tax Analyst Associate Tax Analyst Assoc Engineer- TIS Administrative Specialist Ill- NextEra N QC Specialist Principal infrastructure Specialist PGD Engineer Director Commercial Lighting Administrative Specialist II Chemist Central Lab - Nextera Associate Project Mgr Wind Regional General Manager Manager New Product Development Rotational Assignment -NextEra Resources Training Mgr Technology Sourcing Specialist II Sr Supply Chain Analyst - Nuclear PGD Staff Engineer Sr Attorney N Project Manager Lead Training Mgr F&S Project Manager Development Principal Financial Analyst N Engineer Associate IP Network Security Engineer Sr Director - Home Services Florida Power & Light Company For the Year Ended December 31, 2015 List Employees earning more than $30,000 annually transferred from/to the utility from/to an affiliate company. Employee Company Transferred from ., Ill ICI CD ""' (11 IQ lJ 29076 42821 15863 34929 32641 43894 7 4178 11217 12694 12951 13543 14533 15159 15700 17220 17652 18130 19595 21333 21674 25465 25605 29774 29775 30259 30686 31569 32970 33215 33412 33491 33664 34129 34629 41459 65760 72755 74069 74459 75161 75167 75171 75228 76075 76645 77829 78297 16883 22839 23033 Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company NextEra Energy Resources, LLC NextEra Energy Seabrook, LLC NextEra Point Beach Company Transferred to Old Job Assignment New Job Assignment NextEra Energy Resources, LLC NextEra Duane Arnold FPL FiberNet, LLC NextEra Energy Resources, LLC FPL FiberNet, LLC NextEra Project Mgmt NextEra Project Mgmt NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Transmission, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Engineering Leader - Dsbn N Maintenance Section Supervisor Associate Revenue Protection Biller PGD Production Assurance Specialist Lead Customer Accounting Representative Executive Administrative Assistant IT Business Systems Analyst S Manager Procurement Engineering Director IT Programs N Engineer Senior Sr Technical Specialist- T/S N QC Specialist Principal Sr Receipt Inspector N Engineer Senior Supply Chain Analyst - NSC Sr Receipt Inspector N QC Specialist Principal Administrative Specialist II Sr Technical Specialist Sr Supply Chain Analyst - Nuclear Manager Technical Services N QC Specialist Principal Wholesale Services Manager- T/S N Engineer Senior Director, ISC Technical Services Sr Supply Chain Analyst - Nuclear N Engineering Supervisor N Engineer Principal N QC Specialist Principal N Engineer Senior N Engineer Senior N Engineer Senior N Engineer Senior Sr Supply Chain Analyst- Nuclear N Engineer Senior Sr Technical Specialist Sr Technical Specialist - T /S N Engineer Principal Supply Chain Analyst - Nuclear N Engineer Principal N QC Specialist Principal N Engineering Analyst Senior N Engineer Senior Inventory Services Specialist N Engineer Senior N Engineer Associate N Engineer Senior IT Programmer Analyst S N Principal Engineer- 1ST N Plant General Manager Manager Project Engineering Manager - Construction Account Specialist - FiberNet Reliability Engineer Account Specialist IT Business Systems Analyst S IT Project Manager P Manager Procurement Engineering Sr Director Business Management N Engineer Senior Sr Technical Specialist- T/S N QC Specialist Principal Sr Receipt Inspector N Engineer Senior Supply Chain Analyst - Nuclear Sr Receipt Inspector N QC Specialist Principal Administrative Specialist II Sr Technical Specialist- T/S Sr Supply Chain Analyst - Nuclear Manager Technical Services N QC Specialist Principal Project Director Development - NextEra N Engineer Senior Director, ISC Technical Services Sr Supply Chain Analyst - Nuclear N Engineering Supervisor N Engineer Principal N QC Specialist Principal N Engineer Senior N Engineer Senior N Engineer Senior N Engineer Senior Senior Sourcing Specialist N Engineer Senior Sr Technical Specialist- T/S Sr Technical Specialist- T/S N Engineer Principal Supply Chain Analyst - Nuclear N Engineer Principal N QC Specialist Principal N Engineering Analyst Senior N Engineer Senior Inventory Services Specialist N Engineer Senior N Engineer Associate N Engineer Senior Senior Compliance Specialist N Principal Engineer - 1ST N GM - Fleet Engineering Florida Power & Light Company For the Year Ended December 31, 2015 List Employees earning more than $30,000 annually transferred from/to the utility from/to an affiliate company. Emelo}!ee Comean}! Transferred from ., ~ IC CD .... Ul 1.1) J,.. 25043 33491 34137 35243 72916 11549 16985 27563 31409 36495 43818 73381 73761 75360 76476 30342 33300 34995 14002 22188 26698 44036 69816 73319 73842 74040 16916 34602 41704 32036 33619 41544 42383 75018 22975 28006 73905 35484 44111 74159 42290 75426 15512 42624 73576 75692 42545 74244 76277 22302 Lone Star Transmission, LLC NextEra Energy Resources, LLC NextEra Operating Srvs NextEra Energy Resources, LLC Lone Star Transmission, LLC NextEra Operating Srvs NextEra Energy Resources, LLC NextEra Duane Arnold NextEra Energy Resources, LLC NextEra Energy Resources, LLC FPL Energy Services, Inc NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Point Beach NextEra Energy Resources, LLC FPL Energy Services, Inc NextEra Energy Resources, LLC NextEra Energy Resources, LLC FPL Energy Services, Inc NextEra Energy Resources, LLC NextEra Operating Srvs NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Point Beach NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Project Mgmt NextEra Duane Arnold NextEra Energy Seabrook, LLC NextEra Energy Resources, LLC NextEra Operating Srvs NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Project Mgmt NextEra Energy Seabrook, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra DG Operations, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Duane Arnold NextEra Energy Resources, LLC Comean}! Transferred to Old Job Assignment New Job Assignment Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Florida Power & Light Company Sr Compliance Specialist System Operator- NEER T/S Wind Technician Leader Executive Administrative Assistant Transmission Field Operations Mgr- LS Rotational Assignment Manager - Portfolio & Business N Security Analyst Senior Engineer I -TIS Executive Administrative Assistant Administrative Specialist II Business Management Analyst N Engineering Analyst II Director of Tax Sourcing Specialist II Administrative Technician N Performance Analyst Senior Sr PGD Engineer Product Manager FPLES Compliance Project Manager Project Controller - NextEra Sr Communication Specialist Associate Accounting Technician PGD Business Services Tech NextEra PGD Engineer Associate Accounting Technician Lead Professional - Construction Land Services Technician Associate FPDC Engineering Operator N Training Mtn!Technical Supervisor Sr PGD Engineer IT Database Administrator P N Director Cost Mgmt & Project Controls N Maintenance Section Supervisor N QA Rotational Assignment Accounting Technician Assoc Engineer- TIS Business Services Specialist II - PD Accounting Technician Lead Professional - Construction IT Nuclear Computer Process Engineer Accounting Technician Sr Supply Chain Specialist Project Manager Development Business Manager Quality Program Manager Senior Business Manager PGD Engineer N Operations Unit Supervisor - Lie Class Principal Financial Analyst Leader Training & Development N Engineer Senior Sr PGD Engineer Sr HR Service Specialist Area Manager - Dsbn PGD Central Maintenance Manager Sr Director Business Services - PD N Security Analyst Senior Sr Engineer- TIS Executive Administrative Assistant Account Specialist Sr Business Analyst N Engineering Supervisor Director of Tax Sourcing Specialist I Administrative Technician N Outage Supervisor PGD Engineering Leader IT Business Systems Analyst S Investor Relations Manager Sr Accountant Sr Communication Specialist Accounting Technician PGD Business Analyst Reliability Engineer Financial Analyst II Principal Project Engineer Operation A Clerk N Engineer II -TIS N Training Fleet Manager Senior Reliability Engineer IT Database Administrator P N Director Strategy, Projects & Controls N Planner Scheduler Senior N Rad Protection Supervisor Accounting Technician Engineer II - TIS Business Analyst I Accounting Technician Sourcing Leader IT Nuclear Technology AnalystS Regulatory Affairs Analyst Sr Supply Chain Specialist Director, Project Development Environmental Services Manager Mgr of Corporate Operations Manager Project Development Reliability Engineer N Operations Unit Supervisor- Lie Class Principal Financial Analyst Florida Power & Light Company For the Year Ended December 31, 2015 List Employees earning more than $30,000 annually transferred from/to the utility from/to an affiliate company. EmDioyee Com1;1any Transferred from '"IJ I» CQ CD .... (11 co b. 27753 30124 32777 33085 35862 73962 76437 77034 20763 30071 31475 36243 72685 72962 73316 74742 75784 15879 43465 76143 77266 15464 34362 43506 75846 44058 69809 15587 35818 43157 76988 13492 13858 35434 75010 75478 15171 16314 17112 26619 36204 43291 78217 NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Power Mktg NextEra Energy Resources, LLC NextEra Power Mktg NextEra Energy Resources, LLC FPL Energy Services, Inc NextEra Project Mgmt NextEra Project Mgmt FPL FiberNet, LLC FPL FiberNet, LLC NextEra Operating Srvs NextEra Energy Resources, LLC NextEra Transmission, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Operating Srvs NextEra Energy Resources, LLC NextEra Operating Srvs NextEra Energy Resources, LLC NextEra Project Mgmt NextEra Energy Resources, LLC Lone Star Transmission, LLC FPL Energy Services, Inc NextEra Energy Resources, LLC NextEra Transmission, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Transmission, LLC NextEra Operating Srvs FPL Energy Services, Inc NextEra Project Mgmt NextEra Energy Resources, LLC NextEra Project Mgmt NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Energy Resources, LLC NextEra Project Mgmt NextEra Energy Resources, LLC NextEra Project Mgmt ComQany Transferred to Old Job Assignment New Job Assignment Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Florida Sr PGD Engineer Infrastructure Specialist Rotational Assignment Sr Trading Risk Analyst Sr Director Business Management Settlement Specialist Associate Chemist Central Lab - Nextera Senior Natural Gas Consultant PGD Plant General Manager Supply Chain Supervisor Financial Analyst I Assoc Supply Chain Specialist Wind Technician Ill Sr Project Engineer Executive Administrative Assistant Sr Project Manager - E&C Assoc Business Services Specialist Production Manager I FPDC Leader Wind Field Service Technician - MCTF Sourcing Specialist II Sr Recruiting & Placement Specialist Sr PGD Engineer Engineer II Control Center Inside Sales Rep Project Controls & Scheduling Specialist VP Development - NEET Principal Financial Analyst Sr Tax Analyst Sr Business Management Analyst PGD Business Analyst Account Specialist Manager Project Management - TIS Senior Business Manager Project Management Consultant- E&C Executive Administrative Assistant Project Manager - E & C Principal Financial Analyst Sr Project Manager - E&C Sr Proj Controls & Scheduling Splst Sr Director, Origination- EMT Tax Project Manager Staff Reservoir Engineer Sr PGD Central Maintenance Specialist Infrastructure Specialist Director of Projects Business Manager Sr Dir Enterprise Financial Proc & Srtgy Financial Analyst II Associate Chemist Central Lab Sales Consultant PGD Plant General Manager Manager Inventory Services & SPOC Principal Accountant Sourcing Specialist II Meter Installer Principal Engineer- TIS Executive Administrative Assistant Sr Project Manager - E&C Associate Financial Analyst PGD Central Maintenance Manager Reliability Specialist Mechanic - N SC Sourcing Specialist II Manager Recruiting PGD Engineering Leader IT Systems Administrator S Associate Communication Specialist Sr Financial Analyst VP Development - FPL Principal Risk Management Analyst Sr Tax Analyst Principal Financial Analyst PGD Business Analyst Administrative Specialist I Smart Grid Program Manager Mgr Process Improvement Project Management Consultant- E&C Executive Administrative Assistant Project Manager - E&C Principal Financial Analyst Sr Project Manager - E&C Sr Project Management Consultant- E&C Sr Director, Origination - EMT Principal Financial Analyst Staff Reservoir Engineer Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Power & Light Company Analysis of Diversification Activity Non-Tariffed Services and Products Provided by the Utility Florida Power & Light Company For the Year Ended December 31, 2015 Provide the following information regarding all non-tariffed services and products provided by the utility. Description of Regulated or Product or Service Account No. Non-regulated Miscellaneous Service Revenues 451.000 Regulated Rent from Electric Utility Pia nt 454.000 Regulated Rent from Electronic Utility Plant- Affiliates 454.020 Regulated Rent from Future Use Property 454.100 Regulated Rent from Leased Plant In Service Property 454.200 Regulated Rent from Cable TV Attachments 454.300 Regulated Rent from Pole Attachments 454.400 Regulated Other Electric Revenues 456.000 Regulated Reclamation and Salvage Revenue 456.000 Regulated Bill Statement Advertising Revenues 456.000 Regulated Revenue Enhancement Contract Fees 456.000 Regulated Development & Construction Performance Contract Revenues 456.000 Regulated JEA Reimbursement- 500 KV Line 456.000 Regulated Regulation Service Revenue 456.145 Regulated Use Charge Recoveries- OUC & FMPA 456.400 Regulated Page460 Analysis of Diversification Activity Non utility Property (Account 121) Florida Power & Light Company For the Year Ended December 31, 2015 1. Give a brief description and state the location of non utility property included in Account 121. 2. Designate with a double asterisk any property which is leased to another company. State name of lessee and whether lessee is an associated company. 3. Furnish particulars (details) concerning sales, punchases, or transfers of nonutility property during the year. 4. List separately all property previously devoted to public service and give date of transfer to Account 121, Nonutility Property. 5. Minor items (5% of the balance at the end of the year, for Account 121 or $100,000, whichever is less) may be grouped by (1) previously devoted to public service, or (2) other property non utility property. Description and Location Purchases, Sales, Balance at beginning of year Balance at end of year Transfers, etc. 1 PROPERTY PREVIOUSLY DEVOTED TO PUBLIC SERVICE: 2 Dade County-Turlf-Way (Transferred 1992) 408,648 408,648 6 Volusia County-Bunnell-St. Johns Right-of-Way (Transferred 1992) 297,010 297,010 7 St Johns County-Bunnell-St. Johns Right-of-Way (Transferred 1992) 101,079 101,079 8 Martin County-Tequesta Substation Site (Transferred 1992) 116,288 116,288 9 Flagler County-Bunnell-Angela Right-of-Way (Transferred 1992) 198,581 198,581 10 Indian River County-Sebastian Service Center (Transferred 1999) 109,082 109,082 11 Flagler County-Substation Site (Transferred 1999) 553,043 12 Brevard County-Wickham Substation (Transferred 2001) 747,944 (468,512) 747,944 203,807 84,531 13 Brevard County-Eaugallie Section (Transferred 2001) 203,807 14 Palm Beach County-Alexander Substation(Transferred 1996) 198,112 198,112 15 Broward County-Harmony Substation Site (Transferred 2005) 1,590,303 1,590,303 16 Palm Beach County- Terminal Substation (Transferred 2005) 224,105 224,105 17 Dade-Farmers Subs (Transferred 2008) 202,879 18 Rinker Substation (Transferred 2013) 131,796 0 131,796 6,351,718 (468,512) 5,883,206 4,943,798 (270,893) 4,672,905 5,069,613 (270,893) 4,798,720 804,313 (10,070) 794,243 TOTALS: 19 202,879 20 21 OTHER NON-UTILITY PROPERTY: 22 Dade County-Dade Davis Transm. Right-<>f-Way at SW 104 St.& 127 Ave. 125,815 23 Flagami Settlement (Transferred 2009) TOTALS: 24 125,815 25 26 MINOR ITEMS PREVIOUSLY DEVOTED TO PUBLIC SERVICE: 27 Classified from Future Use to Non-Utility 12/2008 28 Sales of Land & Land Rights 29 Transfer from 101 to 121 0 0 30 Transfer from 121 to 105 0 0 31 Transfer from 105 to 121 0 TOTALS: 32 804,313 0 (10,070) 794,243 33 111,917 34 MINOR ITEMS -OTHER NONUTILITY PROPERTY: 111,917 35 36 GRAND TOTAL: Page461 12,337,561 [749,475) 11,588,086 Number ofElectric Department Employees FLORIDA POWER & LIGHT COMPANY For the Year Ended December 31, 2015 1. The data on number of employees should be reported for the payroll period ending nearest to October 31, or any payroll period ending 60 days before or after October 31. 2. If the respondent's payroll for the reporting period includes any special construction personnel, include such employees on line 3, and show the number of such special construction employees in a footnote. 3. The number of employees assignable to the electric department from joint functions of combination utilities may be determined by estimate, on the basis of employee equivalents. Show the estimated number of equivalent employees attributed to the electric department from joint functions. 1. Payroll Period Ended (Date) 2. Total Regular Full-Time Employees 3. Total Part-Time and Temporary Employees 4. Total Employees Details 12/3112015 8,683 76 8,759 Note: The above numbers do not include temporary employees to remain consistent with the company's 10-K filing. Page 462 Particulars Concerning Certain Income Deductions and Interest Charges Accounts Florida Power & Light Company For the Year Ended December 31, 2015 Report the information specified below, in the order given, for the respective income deduction and interest charges accounts. Provide a subheading for each account and a total for the account. Additional columns may be added if deemed appropriate with respect to any account. (a) Miscellaneous Amortization (Account 425) -- Describe the nature of items included in this account, the contra account charged, the total of amortization charges for the year, and the period of amortization. (b) Miscellaneous Income Deductions --Report the nature, payee, and amount of other income deductions for the year as required by Accounts 426.1, Donations; 426.2, Life Insurance; 426.3, Penalties; 426.4, Expenditures for Certain Civic, Political and related Activities; and 426.5, Other Deductions, of the Uniform System of Accounts. Amounts ofless than 5% of each account total for the year (or $1,000, whichever is greater) may be grouped by classes within the above accounts. (c) Interest on Debt to Associated Companies (Account 430) - For each associated company to which interest on debt was incurred during the year, indicate the amount and interest rate respectively for (a) advances on notes, (b) advances on open account, (c) notes payable, (d) accounts payable, and (e) other debt, and total interest. Explain the nature of other debt on which interest was incurred during the year. (d) Other Interest Expense (Account 431) - Report particulars (details) including the amount and interest rate for other interest charges incurred during the year. Item Amount (a) Miscellaneous Amortization- Account 425: (b) Miscellaneous Income Deductions- Account 426: Donations - Account 426.1 Miami Dade County 241,975 The Salvation Army 440,015 2,000,000 NextEra Energy Foundation 1,893,581 Miscellaneous 4,575,571 Total Account 426.1 Life Insurance - Account 426.2 54,455 Penalties -Account 426.3 Expenditures for Certain Civic, Political and Related Activities- Account 426.4 11,502,896 Lobbying Expenses Salary and Expenses of FPL Employees in Connection with Civic & Legislative Matters 4,246,192 Executive and Employee Performance Incentives 1,123,108 Professional Services 6,090,067 Total Account 426.4 22,962,262 Other Deductions - Account 426.5 3,676,658 Community Services 18,423,373 Marketing and Communications 1,779,600 Miscellaneous 23,879,631 Total Account 426.5 PAGE463-1 --~·-·--- ·-----------------""-- Particulars Concerning Certain Income Deductions and Interest Charges Accounts Florida Power & Light Company For the Year EndedDecember31, 2015 Report the information specified below, in the order given, for the respective income deduction and interest charges accounts. Provide a subheading for each account and a total for the account. Additional columns may be added if deemed appropriate with respect to any account. (a) Miscellaneous Amortization (Account 425)- Describe the nature of items included in this account, the contra account charged, the total of amortization charges for the year, and the period of amortization. (b) Miscellaneous Income Deductions -- Report the nature, payee, and amount of other income deductions for the year as required by Accounts 426.1, Donations; 426.2, Life Insurance; 426.3, Penalties; 426.4, Expenditures for Certain Civic, Political and related Activities; and 426.5, Other Deductions, of the Uniform System of Accounts. Amounts of less than 5% of each account total for the year (or $1 ,000, whichever is greater) may be grouped by classes within the above accounts. (c) Interest on Debt to Associated Companies (Account 430)- For each associated company to which interest on debt was incurred during the year, indicate the amount and interest rate respectively for (a) advances on notes, (b) advances on open account, (c) notes payable, (d) accounts payable, and (e) other debt, and total interest. Explain the nature of other debt on which interest was incurred during the year. (d) Other Interest Expense (Account 431) - Report particulars (details) including the amount and interest rate for other interest charges incurred during the year. Item Amount (c) Interest on Debt to Associated Companies- Account 430: (d) Other Interest Expense -Account 431: 923,501 Commercial Paper (Various Rates) Credit Line Commitment Fees (Various Rates) 6,363,913 Customer Deposits* 9,472,495 (35,034) FMPAandOUC 87,277 Sales and Use Tax for State of Florida Interest on Customer Overbillings 141 Other Tax Audits (Various Rates) 3,936,858 St. Johns River Power Park- Purchase Power Agreement (Various Rates) Collateral Interest to Counterparties (2,231) 35 1,623 Scherer- Purchase Power Agreement (Various Rates) 20,748,577 Total Account 431 *Non-residential customers with cash deposits who have had 23 months or more of continuous service and have maintained a prompt payment record during the last 12 months are entitled to receive interest at the simple rate of 3% per annum. All other customers with cash deposits receive interest at the simple rate of2% per annum. PAGE463-2 Budgeted and Actual In-Service Costs of Nuclear Power Plant Florida Power & Light Company For the Year Ended December 31, 2015 Report the budged and actual costs as compared to the estimated in-service costs of the proposed power plant as provided in the petition for need determination or revised estimate as necessary. Per Rule 25-6.0423(8)(f) Item Plant Name: Turke Point 6 & 7 Remaining Budgeted Costs To Complete Plant Low Range High Range Actual Costs as of December 31,2015 "tl Site Selection $ 6,118,105 $ Pre-Construction (d) $ 235,389,760 $ Construction $ AFUDC & Carrying Charges (b)(c)(d)(e) $ Total $ $ Total Estimated ln-5ervice Cost High Range Low Range Estimated Cost Provided in the Petition for Need determination Low Range High Range $ 6,118,105 $ 6,118,105 $ 8,000,000 $ 8,000,000 $ 302,305,438 $ 335,146,376 $ 465,000,000 $ 465,000,000 I» IC 66,915,678 $ 99,756,616 $10,119,373,657 $ 14,876,554,988 $10,119,373,657 $14,876,554,988 $ 8,149,000,000 $ 12,124,000,000 40,450,727 $ 3, 198,666,143 $ 4,702,379,255 $ 3,239,116,870 $ 4,742,829,983 $ 3,461 ,000,000 $ 5,160,000,000 281,958,592 $ 13,384,955,478 $ 19,678,690,860 $ 13,666,914,070 $19,960,649,452 $12,083,000,000 $ 17,757,000,000 (1) .... 0) .... )> Notes: a) Actual Sunk costs represent costs incurred on the project as of December 31, 2015. This amount does not include any termination or other cancellation costs that could be incurred in the event of project cancellation or deferral. b) Carrying Charges on over/under recoveries are not included as part of Sunk Costs. c) AFUDC is calculated on the non-incremental costs total company and includes carrying charges. d) Totals may not add due to rounding. e) Actual AFUDC through December 31, 2015 represents the retail jurisdictional portion. - - -