BUREAU OF REVENUE REQUIREMENtS
~· ELECTRIC & GAS ACCOUNTING

;.,i

THIS FILING IS (CHECK ONE BOX FOR EACH ITEM)
Item 1:

IK1

An Initial (Original)
Submission

OR

D

Resubmission No.

Item 2:

D

An Original Signed Fonn

OR

IX!

Contonnecl Copy

Fonn Approved
OMB No. 1902-0021
(Expires 7/31198)

FERC Form No. 1:
ANNUAL REPORT OF MAJOR ELECTRIC
UTILITIES, LICENSEES AND OTHERS

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Th1s report is manda!Dty undef !he Fedaral Power Act, Sections 3. 4(a}. 304 .wid 30a,
and 18 CFR, 41 .1. Failu,. to report may result 1n criminal tinea. civil penalllft &ncl
oltlvr sanction& as provided bV law The federal Energy RegUlatory CommiSSIOn doe$
not COI'I$IdM tN5 N~PGrt 1D be of a confidantial nature.

Exact L.agal Name of Respondent (Company)

Year

FLORIDA POWER & LIGHT COMPANY

Oec 31. 19. 96

Report

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Deloitte &
ToucheLLP
0

Certified Public Accountants

Suite 2500
100 Southeast Second Street
Miami. Florida 33131-2135
Telephone: (305) 358-4141
Facsimile : (305) 372-3160

INDEPENDENT AUDITORS' REPORT
Florida Power & Light Company
We have audited the balance sheet ofFiorida Power & Light Company and its subsidiaries
(collectively referred to herein as the "Company") as ofDecember 31 , 1996, and the related
statements of income, retained earnings, and cash flows for the year then ended, included on
pages 110 through 123 (including the Notes to Consolidated Financial Statements attached
thereto) of the accompanying Federal Energy Regulatory Commission ("FERC") Form 1. These
financial statements are the responsibility of the Company's management. Our responsibility is to
express an opinion on these financial statements based on our audit.
We conducted our audit in accordance with generally accepted auditing standards. Those
standards require that we plan and perform the audit to obtain reasonable assurance about
whether the financial statements are free of material misstatement. An audit includes examining,
on a test basis, evidence supporting the amounts and disclosures in the financial statements. An
audit also includes assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation. We believe that
our audit provides a reasonable basis for our opinion.
As required by the FERC, the Company classifies certain items in its Form 1 Balance Sheet
(primarily the classification of the components of accumulated deferred income taxes and
maturities of preferred stock and long-term debt) in a manner different from that required by
generally accepted accounting principles. If generally accepted accounting principles were
followed, at December 31, 1996, the following financial statement captions would increase
(decrease) by (in thousands):
Deferred Debits
Long-term Debt
Proprietary Capital
Current Liabilities
Deferred Credits

$(1,082,898)
$
(40)
$
(4,000)
$
4,040
$ (1,082,898)

Presenting the total outstanding balances ofPreferred Stock Issued and Bonds as non current
liabilities rather than reclassifying the current portion to a current liability and presenting the
components of deferred income taxes on a gross basis have no effect on net income, retained
earnings, or cash flows .

loitte Touche
Tohmatsu
International

 In our opinion, except for the effects of the balance sheet classifications discussed in the preceding
paragraph, the financial statements referred to above present fairly, in all material respects, the
financial position of the Company at December 31, 1996, and the results of its operations and its
cash flows for the year then ended in conformity with generally accepted accounting principles.
Also, in our opinion, the information presented in the financial statements referred to above is
presented fairly, in all material respects, 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.
DELOITTE & TOUCHE LLP

February 14, 1997

 INSTRUCTIONS FOR FILING THE
FERC FORM NO. 1
GENERAL INFORMATION
I.

Purpose
This form is a regulatory support requirement (18 CFR 141.1). It is designed to collect financial and operational
i nformation from major electric utilities, licensees and others subject to the jurisdiction of the Federal Energy
Regulatory commission. This report is also secondarily considered to be a nonconfidential public use form
supporting a statistical publication (Financial Stat i stics of Selected Electric Utilities), published by the
Energy Information Administration.

II.

Yho 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 CFR 101),
must submit this form.
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) .

III. Yhat and Yhere to Submit
(a) Submit this form on electronic media consisting of two (2) duplicate data diskettes and an original and
six (6) conformed paper copies, properly filed in and attested, to:
Office of the Secretary
Federal Energy Regulatory Commission
888 First Street, NE.
Room 1A-21
Yashington, DC 20426
Retain one copy of this report for your files.

i b)

Include with the original and each conformed paper copy of this form the subscription statement requ i red by
18 C.F.R. 385.2011(c)(5). Paragraph (c)(5) of 18 C.F.R. 385.2011 requires each respondent submitting data
electronically to file a subscription stating that the paper copies contain the same information as contained
on the electronic media, that the signer knows the contents of the paper copies and electronic media, and
that the contents as stated in the copies and on the electronic media are true to the best knowledge and
belief of the signer.
Submit immediately upon publication, four (4) copies of the latest annual report to stockholders and any
annual financial or statistical report regularly prepared and distributed to bondholders, security analysts,
or industry associations. (Do not include monthly and quarterly reports. Indicate by checking the
appropriate box on Page 4, List of Schedules, if the reports to stockholders will be submitted or if no
annual report to stockholders is prepared.) Mail these reports to:
Chief Accountant
Federal Energy Regulatory Commission
888 First Street, NE.
Room 1A-21
Yashington, DC 20426

(c)

For the CPA certification, submit with the original submission, or within 30 days after the filing date
for this form, a letter or report (not applicable to respondents classified as Class Cor Class D pr i or to
January 1, 1984):
(i) Attesting to the conformity, in all material aspects, of the below listed (schedules and)
pages with the Commission's applicable Uniform Systems of Accounts (including applicable notes
relating thereto and the Chief Accountant's published accounting releases), and
(i i ) 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 CFR 41.10-41.12 for specific qualifications.)

FERC FORM NO. 1 (REV.

12-95 )

Page

 GENERAL INFORMATION (Continued)
III.

and ~here to Submit (Continued)
Continued

~hat

(c)

Reference
Pages

Schedules
Comparative Balance Sheet
Statement of Income
Statement of Retained Earnings
Statement of Cash Flows
Notes to Financial Statements

110
114
118
120
122

~hen

accompanying this form, insert the letter or report
submitting after the filing date for this form, send the
at the address indicated at III (a).
Use the following form for the letter or report unless
the letter or report, demand that it be varied. Insert
reported.

-

113
117
119
121
123

immediately following the cover sheet. ~hen
letter or report to the Office of the Secretary
unusual circumstances or conditions, explained in
parenthetical phrases only when exceptions are

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 fo r 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.

(d)

IV.
V.

State in the letter or report, which, if any, of the pages above do not conform to the Commission's
requirements. Describe the discrepancies that exist.
Federal, State and Local Governments and other authorized users may obtain additional blank copies
to meet their requirements free of charge from:
Public Reference and Files Maintenance Branch
Federal Energy Regulatory Commission
888 First Street, NE.
Room 2A-1 ED-12.2
~ashington, DC 20426
(202) 208-2474

to Submit:
Submit this report form on or before April 30th of the year following the year covered by this report.

~hen

to Send Comments on Public Reporting Burden.
The public reporting burden for this collection of information is estimated to average 1,217 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. Send comments regarding this burden
estimate or any aspect of this collection of information, including suggestions for reducing this burden, to the
Federal Energy Regulatory Commission, 888 First Street NE., ~ashington, DC 20426 (Attention: Mr. Michael Miller ,
ED-12.3); and to the Office of Information and Regulatory Affairs, Office of Management and Budget,
~ashington, DC
20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission).
~here

FE RC FORM N0 . 1 (REV.

12-95)

Page ii

 GENERAL INSTRUCTIONS
1.

Prepare this report in conformity with the Uniform System of Accounts (18 CFR 101) (U.S. of A.).
all accounting words and phrases in accordance with the U. S. of A.

Interpret

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
financ i al 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 signi f icance
for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting year,
and use for statement of income accounts the current year's amounts.

111.

Complete each question fully and accurately, even if it has been answered in a previous annual report.
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 collllll'1 (d) on the List of Schedules, pages 2, 3, and 4.

V.

Enter

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). The date of the
resubmission must be reported in the header for all form pages, whether or not they are changed from the
previous filing.

VI.

Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must
be repo r ted 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, two (2) new data diskettes and an original and six (6) conformed paper copies of the
entire form, as well as the appropriate number of copies of the subscription statement indicated at
instruction Ill (a) must be filed. Resubmissions must be numbered sequentially both on the diskettes and on
the cover page of the paper copies of the form. In addition, the cover page of each paper copy must indicate
that the filing is a resubmission. Send the resubmissions to the address indicated at instruction Ill (a) .

VII I.

Do not make references to reports of previous years or to other reports in lieu of required entries, except as
specifically authorized.

IX.

Wherever (schedule) pages refer to figures from a previous year, the figures reported must be based upon those
shown by the annual report of the previous year, or an appropriate explanation given as to why the different
figures were used.
DEFINITIONS

I.

II.

Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any
other Commission. Name the commission whose authorization was obtained and give date of the authorization.
Respondent -- The person, corporation, licensee, agency, authority, or other legal entity or instrumentality
in whose behalf the report is made.

,....
FERC FORM N0.1 (REV . 12-95)

Page ii i

 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 wit:
... (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 on the business of developing, transmitting, utilizing, 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 forebay reservoirs directly connected therewith, the primary line or lines
transmitting power therefrom 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 form in which such reports shall be made, amd 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."
"Sec. 309. The Commission shall have power to perform any and all acts, and to prescribe, issue, make, amend,
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 form or 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 filed .... "
GENERAL PENALTIES
to
of
of
to

"Sec. 315. (a) Any licensee or public utility which willfully fails, within the time prescribed by the Commission,
comply with any order of the Commission, to file any report required under this Act or any rule or regulation
the Commission thereunder, to submit any information of document required by the Commission in the course
an investigation conducted under this Act, .•. shall forfeit to the United States an amount not exceeding $1,000
be fixed by the Commission after notice and opportunity for hearing .... "

FERC FORM N0.1 (ED. 12-91)

Page iv

 FERC FORM NO . 1:
ANNUAL REPORT OF MAJOR ELECTRIC UTILITIES LICENSEES AND OTHER
IDENTIFICATION
02 Year of Report
01 Exact legal Name of Respondent
Florida Power & Light Company
Dec. 31, 1996
03 Previous Name and Date of Change (if name changed during year)
NA
04 Address of Principal Office at End of Year (Street, City, State, Zip Code)
700 UNIVERSE BOULEVARD, P.O. BOX 14000, JUNO BEACH, FLORIDA 33408-0420
06 Title of Contact Person
05 Name of Contact Person
VICE PRESIDENT and CON TROLLER
K. M. DAVIS
07 Address of Contact Person (Street, City, State, Zip Code)
9250 WEST FLAGLER STREET, P.O. BOX 029100, MIAMI, FLORIDA 33102
08 Telephone of Contact Person,
09 This Report is
10 Date of Report
( 1) X An Original
(2)
(Mo, Da, Yr)
including Area Code
A Resubmission
(305) 552-4327
04!30!97
ATTESTATION
The undersigned officer certifies that he/she has examined the accompanying report, that to the best of his I her knowledge
information and belief, all statements of fact contained in the accompanying report are true and the accompanying report is
a correct statement of the business and affairs of the above named respondent in respect to each and every matter set forth
therein during the period from and including January 1 to and including December 31 of the year of the report.
03 Signature
04 Date Signed
01 Name
(Mo, Da, Yr)
K. M. DAVIS
02 Title
Signed
K M Davis
04/15/97
VICE PRESIDENT and CONTROLLER
Title 18, U.S.C. 1001, makes it a crime for any person knowingly and willingly to make to any Agency or Department of the United
States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.

,....

~ ERC

FORM NO. 1 (ED. 12 -91)

Page 1

 l

This Report Is: .
Date of Report
Year of Report
(Mo, Da, Yr)
(1) [XJ An Or1g1nal
Dec. 31, 1996
(2) [ A Resubmission
LIST OF SCHEDULES (Electric Utility)
have been reported for certain pages. Omit pages where the
Enter in column (d) the terms "none," "not applicable,"
respondents are 11 none, 11 11 not applicable," or "NA".
or "NA," as appropriate, where no information or amounts
Reference
Title of Schedule
Date
Remarks
Page No.
Revised
(a)
(b)
(c)
(d)
GENERAL CORPORATE INFORMATION AND
FINANCIAL STATEMENTS
General Information .........................................•.
101
Ed. 12-87
Control Over Respondent
..................................... .
102
Ed. 12-96
Corporations Controlled by Respondent
........ • ...............
Ed. 12-96
103
104
Officers
Ed. 12-96
Directors
Ed. 12-95
105
Security Holders and Voting Powers
106 - 107
Ed. 12-96
108 - 109
Ed. 12-96
Important Changes During the Year
110 - 113
Comparative Balance Sheet
................................... .
Ed. 12-94
114 - 117
Ed. 12-96
Statement of Income for the Year ............................. .
118 - 119
Statement of Retained Earnings for the Year
Ed. 12-96
Statement of Cash Flows
120 - 121
Ed. 12-96
122 - 123
Ed. 12-96
Notes to Financial Statements
N9me of Respondent
Florida Power & L1ght Company

I

I

BALANCE SHEET SUPPORTING SCHEDULES (Assets and Other Debits)
Summary of Utility Plant and Accumulated Provisions for
Depreciation, Amortization, and Depletion ..•..•.•....•.•....
Nuclear Fuel Materials
...............................•....•..
Electric Plant in Service
Electric Plant Leased to Others
Electric Plant Held for Future Use
Construction Work in Progress -- Electric
Construction Overheads -· Electric
General Description of Construction Overhead Procedure
Accumulated Provision for Depreciation of Electric Utility Plant.
Nonut i l i ty Property
...•...•..........•..•....................
Investment in Subsidiary Companies
.......................... .
Materials and Supplies
•....••.••....••.•.•..•..•......•......
Allowances
Extraordinary Property Losses
Unrecovered Plant and Regulatory Study Costs ................. .
Other Regulatory Assets ...•..•. • ..... • •. • .....•...•....•.... • .
Miscellaneous Deferred Debits
Accumulated Deferred Income Taxes (Account 19D)

200 - 201
202 - 203
204 - 207
213
214
216
217
218
219
221
224 - 225
227
228 - 229
230
230
232
233
234

Ed. 12-89
Ed. 12-89
Rev. 12-95
Rev. 12-95
Ed. 12-89
Ed. 12-87
Ed. 12-89
Ed. 12-88
Ed. 12-88
Rev. 12-95
Ed. 12-89
Ed. 12-96
Ed. 12-95
Ed. 12-93
Ed. 12-93
Ed. 12-95
Ed. 12-94
Ed. 12-88

BALANCE SHEET SUPPORTING SCHEDULES (Liabilities and Other
Credits)
Capital Stock
Capital Stock Subscribed, Capital Stock Liability for
Conversion, Premium on Capital Stock, and Installments
Received on Capital Stock ............................•.•....
Other Paid-in Capital
.........................•.•..•.••.•. • ..
Discount on Capital Stock
..................•....•......•.....
Capital Stock Expense
................................•.•.....
Long-Term Debt

FE RC FORM NO . 1 (ED. 12-96)

250 - 251

Ed. 12-91

252
253
254
254
256 - 257

Rev. 12-95
Ed. 12-87
Ed. 12-87
Ed. 12-86
Ed. 12-96

Page 2

not applicable

not applicable
not applicable

 of Respondent
Florida Power & L1ght Company

Date of Report
(Mo, Da, Yr)

N~me

I

I

Year of Report
Dec. 31, 1996

LIST OF SCHEDULES (Electric Utility) (Continued)
Title of Schedule
(a)

Reference
Page No.

Date
Revised

Remarks

(b)

(C)

(d)

BALANCE SHEET SUPPORTING SCHEDULES
(Liabilities and Other Credits) (Continued)
Reconciliation of Reported Net Income with Taxable Income
for Federal Income Taxes
............ . . .
Taxes Accrued, Prepaid and Charged During Year
Accumulated Deferred Investment Tax Credits •........... • ..••..
Other Deferred Credits
..•••.••..•....••..••...•.......•..••..
Accumulated Deferred Income Taxes -- Accelerated Amortization
Property
.......................•...........• • ..........•...
Accumulated Deferred Income Taxes -- Other Property
Accumulated Deferred Income Taxes -- Other
.•.................
Other Regulatory Liabilities
...............••.......... • .....

261
262 - 263
266 - 267
269

Ed.
Ed.
Ed.
Ed.

12-96
12-96
12-89
12-88

272 - 273
274 - 275
276 - 277
278

Ed.
Ed.
Ed.
Ed.

12-96
12-96
12-96
12-94

3DO - 301
304
310 - 311
320 - 323
323
326 - 327
328 - 330
332
335
336 - 337

Ed.
Ed.
Ed.
Ed.
Ed.
Ed.
Ed.
Ed.
Ed.
Ed.

12-96
12-95
12-88
12-95
12-93
12-95
12-90
12-90
12-94
12-95

none

INCOME ACCOUNT SUPPORTING SCHEDULES
Electric Operating Revenues
.................•....... •• .......
Sales of Electricity by Rate Schedules
...................... .
Sales of Resale
Electric Operation and Maintenance Expenses
.......•..... •• ...
Number of Electric Department Employees .......••......••.•....
Purchased Power
Transmission of Electricity for Others
Transmission of Electricity by Others
Miscellaneous General Expenses-- Electric
Depreciation and Amortization of Electric Plant
Particulars Concerning Certain Income Deduction and Interest
Charges Accounts

340

Ed. 12-87

COMMON SECTION
Regulatory Commission Expenses
Research, Development and Demonstration Activities
•..•......•
Distribution of Salaries and Wages
...•••...•.••...••.••.....•
Common Utility Plant and Expenses
..•...•....•..•....•. • ....•.

350 - 351
352 - 353
354 - 355
356

Ed.
Ed.
Ed.
Ed.

12-96
12-87
12-88
12-87

not applicable

ELECTRIC PLANT STATISTICAL DATA
Electric Energy Account
Monthly Peaks and Output
Steam-Electric Generating Plant Statistics (Large Plants)
Hydroelect o c Generating Plant Statistics (large Plants)
Pumped Storage Generating Plant Statistics (Large Plants)
Generating Plant Statistics (Small Plants)

FE RC FORM NO. 1 (ED. 12-96)

401
401
402
406
408
410

Page 3

-

Rev. 12-90
Rev. 12-90
403
407
409
411

Rev. 12-95
Ed. 12-89
Ed. 12-88
Ed. 12 -87

not applicable
not applicable
not applicable

 of Respondent
Florida Power & L1ght Company

N~me

Date of Report
(Mo, Da, Yr)

I

I

Year of Report
Dec. 31, 1996

LIST OF SCHEDULES (Electric Utility) (Continued)
Title of Schedule
(a)

Reference
Page No.

Date
Revised

Remarks

(b)

(C)

(d)

ELECTRIC PLANT STATISTICAL DATA (Continued)
Transmission Line Statistics
Transmission Lines Added During Year
Substations
Electric Distribution Meters and Line Transformers
Environmental Protection Facilities
Environmental Protection Expenses
Footnote Data
Stockholders' Reports

Check appropriate box:

[ J

Four copies will be submitted.

[XJ

No annual report to stockholders is prepared.

FERC FORM NO . 1 (ED. 12-96)

422 - 423
424 - 425
426 - 427
429
430
431
450

Page 4

Ed.
Ed.
Ed.
Ed.
Ed.
Ed.
Ed.

12-87
12-86
12-96
12-88
12-88
12-88
12-87

not applicable

 of Respondent
Florida Power & L1ght Company

Year of Report
Dec. 31, 1996

N~me

I

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 the office where any other corporate
books are kept, if different from that where the general corporate books are kept.
K. M. Davis, Vice President, Accounting, Controller and Chief Accounting Officer
9250 West Flagler Street
Miami, Florida 33174
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.
Florida - December 28, 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 Applicable

4.
State the classes of utility and other services furnished by respondent during the year in each State in which
the respondent operated.
Electric Utility Service is provided in Florida only. The respondent owns 76.36% of Scherer Unit No. 4,
a coal-fired gene rating unit located in central Georgia .

5.
Have you engaged as the principal accountant to audit your financial statements an accountant who is not the
the principal accountant for your previous year's certified financial statements?
Yes ... Enter the date when such independent accountant was initially engaged:
X No

FERC FORM N0 . 1 (ED. 12 -87 )

Page 101

 Date of Report
This Report Is: .
Year of Report
(Mo, Da, Yr)
( 1 ) [XJ An Or 1g1na l
(2) [ A ResuiJmission
Dec. 31, 1996
CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or combination of such organizat i ons jointly held
control over the respondent at end of 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
the main parent company or organization. If control was held by a trustee(s), state
of ownership or control to
name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.

of Respondent
Florida Power & L1ght Company

N~me

I

I

FPL Group, Inc., a holding company, is the sole holder of the common stock of the respondent.

FERC FORM N0.1 (ED. 12-96)

Page 102

I

 of Respondent
Florida Power & L1ght Company

N~me

I

This Report 1~:.
(1) [X] An Or1g1nal
(2) [ l A Resuemission

Date of Report
(Mo, Da, Yr)

l

Year of Report
Dec. 31, 1996

CORPORATIONS CONTROLLED BY RESPONDENT
2. 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 t he other
interests.

1. Report below the names of all corporations,
business trusts, and similar organizations, controlled
directly or indirectly by respondent at any time during
the year. If control ceased prior to end of year, give particulars (details) in a footnote.

DEFINITIONS
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.

1. See the Unifo rm 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.
4. Joint control is that in which neither interest can
effectively control or direct action without the consent
Name of Company Controlled
Line
No.

(a)

1
2
3
4
5
6

,_

c ER ~

Footnote
Ref.

(c)

(d)

Holds real properties used or
to be used by FPL in its
utility operations for the
purpose of increasing
financing options beyond
those permitted by FPL's
Mortgage.

100 N/A

KPB Financial Corp.

Maintenance and management of
intangible assets.

100 N/A

FPL Enersys, Inc.

Investigates and pursues
opportunities for the development or acquisition of
energy systems.

100 N/A

FPL Energy Services, Inc.

Provides conservation
services by analyzing energy
efficient equipment.

100

13

14
15
16
17
18
19
20
21
22
23
24
25
26
27

(b)

Percent Voting
Stock Owned

Land Resources Investment Co.

7

8
9
10
11
12

Kind of Business

t-> L Services

roRM N0.1 <ED. 12 -96)

Marketing, development,
design, installation, construction, financing and
servicing of ener gy conservation projects.

Page 103

*

 of Respondent
Florida Power & L1ght Company

N~me

I

This Report Is:
(1) [XJ An Or1ginal
(2) [ A ResuErnission

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31, 1996

CORPORATIONS CONTROLLED BY RESPONDENT
1. Report below the names of all corporations,
business trusts, and similar organizations, controlled
directly or indirectly by respondent at any time during
the year. If control ceased prior to end of year, give particulars (details) in a footnote.

2. 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.
4. Joint control is that in which neither interest can
effectively control or direct action without the consent

Name of Company Controlled
Line
No.
1
2
3
4
5
6

(a)

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.

Kind of Business

(b)

Percent Voting
Stock Owned

Footnote
Ref.

(c)

(d)

FPL Energy Services II, Inc.

Provides marketing services
for energy conservation
measures.

100 *

FPL Historical Museum, Inc.

A non-profit corporation
formed to permanently care
for and display FPL historical objects and information.

100 N/A

7
8

9

10
11

12
13
14
15

16
17
18

19
20
21
22
23
24
25

26
27

FERC FORM N0.1 CEO. 12-96)

Page 103.1

 <

Page 103 Line 17 Column d

>

Wholly owned subsidiary of FPL Enersys, Inc.

<

Page 103 Line 21 Column d

>

General Partnership between FPL Energy Services,
FPL Energy Services II, Inc.

<

Page 103.1 Line 1 Column d

>

Wholly owned subsidiary of FPL Enersys, Inc .

Page 103 Footnote.1

Inc. and

 of Respondent
Florida Power & L1ght Company

N~me

I

I~~s[~elp~~to~T~inal
(2) [ A Resuomission

I

Date of Report
(Mo, Da, Y)-)

I

Year of Report
Dec. 31, 1996

OFFICERS
1. Report below the name, title and salary for each
who performs similar policymaking functions.
executive officer whose salary is $50,000 or more. An "ex·
2. If a change was made during the year in the inecutive officer" of a respondent includes its president,
cumbent of any position, show name and total remunera·
secretary, treasurer, and vice president in charge of a
tion of the previous incumbent, and the date the change
principal business unit, division or function (such as
in incumbency was made.
sales, administration or finance), and any other person
Line
Title
Salary
Name of Officer
No.
for Year
(b)

(a)

1
2
3

4
5

*See Page 104 Footnote.1 and Footnote.2 for
"Executive Compensation" as f i led with
the Securities and Exchange Commission
in the Company's 1996 Form 10-K.

6
7
8
9

,,

10

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 N0.1 (ED. 12·96)

Page 104

(c)

 <

Page 104 Line 1 Column a >

EXECUTIVE COMPENSATION
The following table sets forth FPL's portion of the compensation
paid during the past three years to FPL's chief executive officer
and the other four most highly-compensated persons who
served as executive officers of FPL at December 31, 1996.
SUMMARY COMPENSATION TABLE
ANNUAL COMPENSATION

Bonus

Salary

Name and Principal Position
--------------------------JAMES L. BROADHEAD (3)
Chairman of the Board and
Chief Executive Officer

Year
1996
1995
1994

$799,800
749,567
692,346

$633,423
637,000
565,500

PAUL J. EVANSON
President

1996
1995
1994

540,000
500,000
261,000

340,200
307,400
130,500

DENNIS P. COYLE
General Counsel and
Secretary

1996
1995
1994

334,800
303,849
280,662

158,193
138,957
125,344

c.o. WOODY
Senior Vice President,
Power Generation

1996
1995
1994

295,000
283,300
273,700

142,500
133,400
123,216

MICHAEL W. YACKIRA
Chief Financial Officer

1996
1995
1994

279,000
239,250
231,200

131,874
110,403
110,000

-----

------

Long-Term
Compensation
Payouts
-----------Other

Year

Long Term

Annual Incentive
Compen- Plan
sat ion Payouts(1)
---------------

All
Other
Compensation(2)
---------

Name and Principal Position
JAMES L. BROADHEAD (3)
Chairman of the Board and
Chief Executive Officer

1996
1995
1994

$10,601
30,342
5,658

$920,892
947,387
780,681

$12,727
15,901
14,131

PAUL J. EVANSON
President

1996
1995

2,925
3, 69 1

197,471
155,513

15,868
12,906

Page 1 04 Footno te.1

 1994

3,254

69,622

10,214

DENNIS P. COYLE
General Counsel and
Secretary

1996
1995
1994

3,756

203,637
223,724
165,351

10,742
11,972
10,784

c.o. WOODY
Senior Vice President,
Power Generation

1996
1995
1994

3,882
3,234
1,458

184,711
207,350
165,288

13,448
15,539
14,391

MICHAEL W. YACKIRA
Chief Financial Officer

1996
1995
1994

3,886
4,526
3,199

145,942
153,294
165,288

9,908
9,092
9,791

(1)
Payouts were made in cash (for payment of income taxes)
and shares of common stock of FPL Group, Inc., valued at
the closing price on the last business day preceding payout.
(2)
Represents employer matching contributions to thrift plans
and employer contributions for life insurance.
Mr.
Mr.
Mr.
Mr.
Mr.

Broadhead
Evanson . . . . . . . . . . . . . . . . . . . .
Coyle . . . . . . . . . . . . . . . . . . . . . .
Woody . . . . . . . . . . . . . . . . . . . . . .
Yackira . . . . . . . . . . . . . . . . . . . .

Thrift Match
$6,626
7,125
.
6,626
.
7,125
.
6,626
.

Life Insurance
$6,101
8,743
4,115
6,323
3,282

(3)
At December 31, 1996, Mr. Broadhead held 96,800 shares
of restricted common stock of FPL Group, Inc. with a value
of $4,452,800. These shares were awarded in 1991 for the purpose
of financing Mr. Broadhead's supplemental retirement plan
and will offset lump sum benefits that would otherwise be
payable to him in cash upon retirement. Dividends at normal
rates are paid on restricted common stock.

Page 104 Footnote.2

 t~;s[~elp~~to~~~inal

Year of Report
Date of Report
(Mo, Da, Yr)
Dec. 31 , 1996
(2) [ A ResuExnission
DIRECTORS
2. Designate members of the Executive Committee
1. Report below the information called for concern by a triple asterisk and the Chairman of the Executive
ing each director of the respondent who held office at
any time during the year. Include in column (a), abCommittee by a double asterisk.
breviated titles of the directors who are officers of the
respondent.
Line
Name (and Title) of Director
Principal Business Address
No.
(a)
(b)
1 James L. Broadhead
P.O. Box 14000
2
Chairman of the Board and Chief Executive Officer
Juno Beach, Florida 33408
Name of Respondent
Florida Power & L1ght Company

I

I

I

3

4 Dennis P. Coyle
5
General Counsel and Secretary

P.O. Box 14000
Juno Beach, Florida

33408

P.O. Box 14000
Juno Beach, Florida

33408

P. 0. Box 14000
Juno Beach, Florida

33408

P. o. Box 14000
Juno Beach, Florida

33408

P. 0. Box 14000
Juno Beach, Florida

33408

P. o. Box 14000
Juno Beach, FLorida

33408

P. 0. Box 14000
Juno Beach, Florida

33408

6

7 Paul J. Evanson
8
President
9

10 Jerome H. Goldberg
11
President, Nuclear Division (until 3/1/96)
12
13 Lawrence J. Kelleher
14
Senior Vice President, Human Resources
15
16 Thomas F. Plunkett
17
President, Nuclear Division (as of 3/1/96)
18
19 C. 0. IJoody
20
Senior Vice President, Power Generation
21
22 Mic ~ ~-· IJ. Yackira
23
S
or Vice President, Finance, and Chief
24
F • ·:ancial Officer
25
26
27
28
29 Note: There was no FPL Executive Committee in 1996.
30
31
32
33

34
35
36
37
38

39
40
41
42
43
44
45
46
47
48
FE RC FORM NO. 1 (ED. 12-95)

Page 105

 Nfme of Respongent
L1ght Company
F orida Power

Thi s Report Is:
Date of Re~ort
Year of Report
(Mo, Da, Y )
~~~ fXj A
An Resu
Or1~nal
ission
Dec. 31, 1996
SECURITY HOLDERS AND VOTING POWERS
1. Give the names and addresses of the 10 security
whereby such security became vested with voting rights and
holders of the respondent who, at the date of the latest closgive other important particulars (details) concerning the
ing of the stock book or compilation of list of stockholders
voting rights of such security. State whether voting rights are
of the respondent, prior to the end of the year had the
actual or contingent; if contingent, describe the contingency.
highest voting powers in the respondent, and state the
3. If any class or issue of security has any special
number of votes wh i ch each would have had the right to cast
privileges i n the election of directors, trustees or manage rs ,
on that date if a meeting were then in order. If any such
or in the determination of corporate action by any method,
holder held in trust, give in a footnote the known particulars
explain briefly in a footnote.
of the trust(whether voting trust, etc.) duration of trust, and
4. Furnish particulars (details) concerning any options ,
principal holders of beneficiary interests in the trust. If the warrants, or rights outstanding at the end of the year for
stock book was not closed or a list of stockholders was not
others to purchase securities of the respondent or any
compiled within one year prior to the end of the year, or if
securities or other assets owned by the respondent, including
since the previous compilation of a list of stockholders, some
prices, expiration dates, and other material information
other class of security has become vested with voting rights,
relating to exercise of the options, warrants, or rights.Specify
then show such 10 security holders as of the close of the
the amount of such securities or assets so entitled to be pur year. Arrange the names of the security holders in the order
chased by any officer, director, associated company, or any
of voting power, commencing with the highest. Show in colof the ten largest security holders. This instruction is inapumn (a) the titles of officers and directors included in such
plicable to convertible securities or to any securities substantially all of which are outstanding in the hands of the general
l i st of 10 security holders.
public where the options, warrants, or rights were issued on a
2. If any security other than stock carries voting
rights, explain in a footnote the circumstances
prorata basis.
1. Give date of the latest closing of the stock
2. State the total number of votes cast at the 3. Give the date
latest general meeting prior to end of year
and place of such
book pr i or to end of year, and state the purpose
for election of directors or the respondent and meeting:
of such closing:
number of such votes cast by proxy
May 13, 1996
N/A
Juno Beach,
Total:
1,000
Florida

I

I

I

By proxy:
Line
No.

4
5
6
7
8
9
10
11
12
13
14
15
16
17
18

Name (Title) and Address of Security
Holder
(a)
TOTAL votes of all voting securities
TOTAL number of security holders
TOTAL votes of Security holders
listed below
FPL Group, Inc .
700 Universe Blvd.
Juno Beach, FL 33408

FERC FORM NO.1 (ED. 12 -96)

, 1~Q~URITIES
Number of votes as of (date): DecemberV0!1NG
Preferred
Total
Common
Stock.
Votes
Stock
(c)
(d)
(b)
1,000
1,000
1
1
1,000
1,000

Page 106

1,000
1,000

Other
(e)

0

0

 I

Date of Report
This Report Is:.
(Mo, Da, Yr)
~1~ fXl An
Or1~nal
ission
A Resu
SECURITY HOLDERS AND VOTING PO~ERS (Continued)
Common
Preferred
Total
Name (Title) and Address of Security Holder
Stock
Stock
Votes
(a)
(b)
(c)
(d)
Not Applicable

Nfme of Respon~ent
L1ght Company
F orida Power

Line
No.
19
20
21
22
23
24
25
26
27
28
29 I
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53

I
I

FE RC FORM N0.1 (ED. 12-96)

Page 107

I

Year of Report
Dec. 31, 1996

Other
(e)

 of Respondent
Florida Power & L1ght Company

N~me

I9ss[~fP~~to~~~inal

J

Date of Report
Year of Report
(Mo, Da, Yt-)
(2) [ l A Resuemission
Dec. 31, 1996
IMPORTANT CHANGES DURING THE YEAR
Give particulars (details) concerning the matters indicated
natural gas company must also state major new continuing
below. Make the statements explicit and precise, and number
sources of gas made available to it from purchases,
them in accordance with the inquiries. Each inquiry should
development,
purchase contract or otherwise,
giving
be answered. Enter "none" "not applicable," or "NA" where
location and approximate total gas volumes available,
applicable. If information which answers an inquiry is
period of contracts,
and other parties to any such
given elsewhere in the report, make a reference to the
arrangements etc.
schedule in which it appears.
6. Obligations incurred as a result of issuance of
1. Changes in and important additions to franchise rights:
securities or assumption of liabilities or guarantees
Describe the actual consideration given therefor and state
including issuance of short-term debt and commercial paper
from whom the franchise rights were acquired. If acquired
having a maturity of one year or less. Give reference to
without the payment of consideration, state that fact.
FERC or State Commission authorization, as appropriate, and
2. Acquisition of ownership
in other companies
by
the amount of obligation or guarantee.
reorganization, merger,
or consolidation with
other
7. Changes in articles of incorporation or amendments to
companies: Give names of companies involved, particulars
charter: Explain the nature and purpose of such changes or
concerning the transactions,
name of the
Commission
amendments.
authorizing the transaction, and reference to Commission
8. State the estimated annual effect and nature of any
authorization.
important wage scale changes during the year.
3. Purchase or sale of an operating unit or system: Give
9. State briefly the status of any materially important
a brief description
of
the property,
and of the
legal proceedings pending at the end of the year, and the
transactions relating thereto, and reference to Commission
results of any such proceedings culminated during the year.
authorization, if any was required. Give date journal
10. Describe briefly any materially important
tranentries called for by the Uniform system of Accounts were
sactions of the respondent not disclosed elsewhere in this
submitted to the Commission.
report in which an officer, director, security holder
4. Important leaseholds ( other than leaseholds
for
reported on page 106, voting trustee, associated company
natural gas lands ) that have been acquired or given,
or known associate of any of these persons was a party or
assigned or surrendered: Give effective dates, lengths of
in which any such person had a material interest.
11. (Reserved.)
terms, names of parties, rents, and other conditions. 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
12. If the important changes during the year relating to
and date operations began or ceased and give reference to
the respondent company appearing in the annual report to
Commission authorization, if any was required. State also
stockholders are applicable in every respect and furnish
the data required by instructions 1 to ·11 above, such notes
the approximate number of customers added or lost and
may be included on this page.
approximate annual revenues of each class of service. Each

I

PAGE 108 INTENTIONALLY LEFT BLANK
SEE PAGE 109 FOR REQUIRED INFORMATION

FERC FORM N0.1 (ED. 12-96)

Page 108

I

 Date of Report Year of Report
Name of Respondent
This Report Is:
(Mo,Da,Yr)
Florida Power & Light Comp (1) [X]An Original
Dec. 31, 1996
any
(2) [ ]A Resubmission
IMPORTANT CHANGES DURING THE YEAR (Continued)

.--

1 .

None.

2.

None.

3.

None .

4.

None.

5 .

None other than the addition of normal transmission and distribution
facilities to serve new customers.

6.

For information on Long-Term Debt issued during 1996, see pages 256 and
257.
During 1996, under FPSC Order Nos. PSC-95-1400-FOF-EI and PSC-95-1400AFOF-EI, FPL issued a total of $913 million in commercial paper, none of
which was outstanding at 12/31/96. The average amount of commercial
paper outstanding during the year ended 12/31/96 was $39 million.

7.

None.

8.

None.

9.

See Item 3. Legal Proceedings in FPL's 1996 Form 10-K which is
filed with this report. Also see Note 9 of the Notes to Consolidated
Financial Statements - Commitments and Contingencies - Litigation.

10. FPL is a member of Nuclear Electric Insurance Limited (NEIL) and Nuclear
Mutual Limited (NML). In 1996, FPL made premium payments to NML of
approximately 5% and to NEIL of approximately 4% of these
carriers' consolidated gross premiums for its last fiscal year.
Mr. Keith Kennedy, Director of Risk Management, is a member
representative of Energy Insurance Mutual Limited (EIM) . EIM
represents Excess Liability and Directors and Officers Insurance.
In 1996, FPL made premium payments of less than 1% of this carrier's
consolidated gross premiums for its last fiscal year.
11. Not applicable.
12. Not applicable.

FERC FORM N0.1

(ED. 12-96)

Page 109

 of Respondent
Florida Power & L1ght Company

N~me

Line
No.

Date of Report
(Mo, Da, Yr)
Ref .
Page No.
(b)

Balance at
Beginning of Year
(C)

Year of Report
Dec. 31, 1996
Balance at
End of Year

 of Report
Da, Yr)

of Respondent
Florida Power & L1ght Company

N~me

Line
No.

Page No.
(b)

(a)

~~~~2.!~el§>and

other Debits (Enter Total of lines 10, 11, 12,

,......

FERC FORM N0.1 (REVISED 12-93)

Page 111

Balance at
Beginning of Year
(c)

$12,773,431,393

Year of Report
Dec. 31, 1996
Balance at
End of Year
(d)

$12,614,171,212

 Name of Respondent
Flor ida Power & Ltght Company

of Report
Oa, Yr)

Line
No.

FERC FORM N0 . 1 (EO. 12-89)

Balance at
of Year

Page 112

Year of Report
Dec. 31, 1996
Balance at
End of Year

 Year of Report
Date of Re~ort
This Report Is: .
(Mo, Da, Y )
~~~ fXl A
An Resu
Or1~nal
Dec. 31, 1996
ission
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS) (Continued)
Balance at
Balance at
Ref.
Title of Account
End of Year
Beginning of Year
Page No.
(d)
(C)
(b)
(a)
DEFERRED CREDITS
$309.120
$f t
CustomerAdVBrlees for Construction (252)
250,641 .108
266:267
281,965,507
AccllllUlatedoeterndlnvestment Tax credits <255)
3,244,136
3,547,903
Deferred Gains from D-isposition of Utility Plant (256)
217,743,077
197,287,094
269
Other D.,;f;; <=u Credits (253)
463,053,466
532,367,430
278
Other Regulatory Liabilities (254)
389,084
649,545
269
Unamortized Gain on Reacquired Debt (257)
1, 966,249,299
272-277
1~,156
AccllllUlated Deferred Income Taxes (281-283)
$2,901,889,751
TOTAL Deferred Credits (Enter Total of Lines 47 thru 53)
$2,945' 732,652

Nfme of Respon~ent
L1ght Company
F orida Power
Line
No.
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63

I

I

I

64

65
66

67
68

!gTAL L~fbilities and Other Credits (Enter Total of Lines 14 22 30
and
)
'
'
'

FERC FORM N0.1 (REVISED 12-93)

Page 113

$12,773,431,393

$12,614,171,212

 of Respondent
Florida Power & L1ght Company

N~me

Date of Report
(Mo, Da, Yrl

1. Report amounts for accounts 412
Expenses from Utility Plant Leased to Others, in another
Utility column (i,k,m,o) in a similar manner to a utility
department. Spread the amount(s) over lines 02 thru 24 as
appropriate. Include these amounts in columns (c) and (d)
totals.
2. Report amounts in account 414, Other Utility Operating
Income, in the same manner as accounts 412 and 413 above.
3. Report data for lines 7,9, and 10 for Natural Gas companies using accounts 404.1, 404.2, 404.3, 407.1 and 407.2.
4. Use pages 122-123 for important notes regarding the
statement of income or any account thereof.
Account

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 a material refund to the
utility with respect to power or gas purchases. State for
each year affected the 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 and gas purchases.
6. Give concise explanations concerning significant
amounts of any refunds made or received duing the year.
(Ref.)
Page No.
Previous Year
(b)

24

Net Utility Operating Income
line 2 less 23) (Carry forward to page 117, line 25)

FE RC FORM N0.1 (ED. 12-96)

Year of Report
Dec. 31, 1996

Page 114

(d)

$858,781,172

$865,306,453

 Nfme of Respon~ent
F orida Power
L1ght Company

I

This Report Is: .
~~~ fXl An
Or1~nal
ission
A Resu

I

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31' 1996

STATEMENT OF INCOME FOR THE YEAR (Continued)

resulting from settlement of any rate proceeding affecting
revenues received or costs incurred for power or gas
purchases, and a summary of the adjustments made to balance
sheet, income, and expense accounts.
7. If any notes appearing in the report to stockholders
are applicable to this Statement of Income, such notes may
be included on pages 122-123.
8. Enter on pages 122-123 a concise explanation of only
those changes in accounting methods made during the year
ELECTRIC

UTILITY

~··;"¥'
( )

, •• ,

GAS
Current Year
(g)

which had an effect on net income, including the basis of
allocations and apportionments from those used in the preceding
year. Also give the approximate dollar effect of such changes.
9. Explain in a footnote if the previous year's figures
are different from that reported in prior reports.
10. If the columns are insufficient for reporting additional utility departments, supply the appropriate account
titles, lines 2 to 23, and report the information in the
blank space on pages 122 - 123 or in a footnote.

UTILITY
Previous Year
(h)

2,538 ,165,958
322;158,603
797,970,216

0
0
47,818,532
0
586,504,601
387,515,268
53,952,541
342 , 954,229
4 ~ ,063,206
(31,324,399)
849,264
12,725
0
0
$5 '127,646,555

0
0
39,777,653
0
547,976,007
395,479,721
64,426,911
209,878,039
301,611,621
(20, 831,922)

0
-$4;664-, 750' 714

$858,781' 172

$865,306,453

FERC FORM N0.1 (ED. 12-96)

(, )

UTILITY
Previous Year
(J)

Line
No.
1
2
3
4
5
6
7
8

. $5 '530 ;o57;167
2,887,550,373
370,591,787
832,702,989
71,261,143
3 019,236

OTHER
Current Year

-68,799,060

2,8o9,828

9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24

25-6-,5798,840 .
0

Page 115

 Nfme of Respon~ent
F orida Power
L1ght Company

Line
No.
1
2
3

OTHER
Current Year

I

UTI Ll TY

NA

4
5

I

'"' '::::C::::'
( )

(k)

This Report Is:.
~~~ fX~ A
An Resu
Or1~nal
ission
STATEMENT OF INCOME FOR THE YEAR (Continued)
OTHER UTI Ll TY
Previous Year
(m)
(n)

6
7
8
9

,

10
12
13
14
15
16
17
18

""19
2o
21
22
23
24

0

FERC FORM N0.1 (ED. 12-96)

Page 116

Date of Re~ort
(Mo, Da, Y )

I
OTHER

Year of Report
Dec. 31, 1996
UTILITY

(p)
'"'''"'(o) '·~

-

 Date of Report
(Mo, Da, Yr)

of Respondent
Florida Power & L1ght Company

N~me

FERC FORM N0.1 (ED . 12-96)

Page 117

Year of Report
Dec. 31, 1996

 N9me of Respondent
Florida Power & L1ght Company

Date of Report
(Me, Da, Yr)

1. Report all changes in appropriated retained earnings,
unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the the year.
2. 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).
3. State the purpose and amount of each reservation or
appropriation of retained earnings.
4. 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.

Line
No.

Item

Year of Report
Dec. 31, 1996

for each clas s and series of
capital stock.
6. Show separately the State and Federal income tax effect
of items shown in account 439, Adjustments to Retained
Earnings.
7. 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 appro priated as well as the totals eventually to
be
accumulated.
8. If any notes appearing in the report to stockholders are
applicable to this statement, include them on pages 122-123.
Cootra
Pr1mary
Ac;c;ount
Amount
Affected
(b)

(C)

 of Report
Da, Yl')

Name of Respondent
Florida Power & L1ght Company
Line
No.

APPROPRIATED RETAINED EARNINGS (Account 215)
State balance and purpose of each appropriated retained earnings amount at end of year and give
accounting entries for any applications of appropriated retained earnings during the year.
39
40
41

42
43

44

,....
APPROPRIATED RETAINED EARNINGS-AMORTIZATION RESERVE,FEDERAL
(Account 215.1)
State below the total amount set aside through appropriations of retained earnings,
of the year, in compliance with the provisions of Federally granted hydroelectric project licenses
held by the respondent. If any reductions or changes other than the normal annual credits hereto have

FERC FORM N0. 1 ( ED. 12-96 )

Page 119

Year of Report
Dec. 31, 1996

 <

Page 118 Line 24 Column c

>

(A) Detail of Dividends Declared - Preferred Stock:
4.50% Series
4.50% Series A
4.50% Series B
4.50% Series c
4.32% Series D
4.35% Series E
7.28% Series F
7.40% Series G
6.84% Series Q
8.625% Series R
$2.00 Series A
6.98% Series s
7.05% Series T
6.75% Series u
TOTAL

Amount
$450,000
225,000
225,000
281,250
216,000
217,500
667,333
452,222
2,872,800
575,000
5,066,376
5,235,000
3,525,000
4,387,500
24,395,981

NOTE: During 1995 the Company changed its accounting for premiums
on preferred stock reacquisitions. In prior years such
premiums were charged directly to retained earnings.
Effective for reporting year 1995 and in accordance with
EITF Topic D-42, such premiums will be treated as dividends
on preferred stock.

Page 118-119 Footnote.1

 Date of Report
(Mo, Da, Yr)

of Respondent
Florida Power & L1ght Company

N~me

r-

Year of Report
Dec. 31, 1996

Under "Other" specify significant amounts and group others.
1. If the notes to the cash flow statement in the respondents
Operating Activities - Other: Include gains and losses perannual stockholders report are applicable to this statement,
taining to operating activities only. Gains and Losses persuch notes should be included in pages 122-123. Informa taining to investing and financing activities should be
tion about noncash investing and financing activities
should be provided on pages 122-123. Provide also on pages
reported in those activities. Show on pages 122-123 the
amount of interest paid ( net of amounts capitalized) and
122-123 a reconciliation between "Cash and Cash Equivalents
income taxes paid.
at End of Year" with related amounts on the balance sheet.
Description (See Instruction No. 5 for Explanation of Codes)
Line
Amounts
(a)
(b)
No.

FERC FORM N0.1 (ED. 12-96)

Page 120

 Name of Respondent
Florida Power & L1ght Company

Date of Report
(Mo, Da, Yr)

Year of Report
Dec. 31, 1996

4 . Investing Activities
5. Codes used:
Include at Other (line 31) net cash outflow to acquire other
(a) Net proceeds or payments.
companies. Provide a reconciliation of assets acquired with
(b) Bonds,debentures and other long term debt .
liabilities assumed on pages 122-123.
(c) Include commercial paper.
Do not include on this statement the dollar amount of leases
(d) Identify separately such items as investments, fixed
capitalized per US of A General Instruction 20; instead
assets, intangibles, etc.
provide a reconciliation of the dollar amount of leases
6. Enter on pages 122-123 clarifications and explanations.
capitalized with the plant cost on pages 122-123.
Line
Description (See Instruction No. 5 for Explanation of Codes)
Amounts
No.
(b)

 <

Page 120 Line 22 Column b

>

Supplemental disclosures of cash flow information:
CASH PAID DURING THE PERIOD FOR:
Interest (net of amount capitalized)
Federal Income Taxes
State Income Taxes

<

Page 120 Line 26 Column b

$ 228,079,246
$ 306,100,000
$ 72,819,000

>

Supplemental schedule of non-cash investing activities:
Additions to capital lease obligations

<

$

86,331,990

Page 120 Line 36 Column b >

Increase in Nuclear Decommissioning and Storm Funds.

<

Page 121 Line 90 Column b

>

Reconciliation between ''Cash and Cash Equivalents at End of Year"
with related amounts on the Balance Sheet:
FOR YEAR ENDED DECEMBER 31, 1996:
Cash and Cash Equivalents at End of Year

$78,417,210

BALANCE SHEET ACCOUNTS:
Cash (131)
Special Deposits (132-134)
Working Fund (135)
Temporary Cash Investments (136)

$27,354,934
100,621
113,600
50,848,055

TOTAL BALANCE SHEET ACCOUNTS

Page 120-1 2 1 Footnot e.1

$78,417,210

 Date of Report
Year of Report
This Report Is:.
(Mo, Da, Yr)
(1) [XJ An Or1g1nal
Dec. 31, 1996
(2) [ A Resuomission
NOTES TO FINANCIAL STATEMENTS
plan of disposition contemplated, giving references to Com1. Use the space below for important notes regarding the
mission orders or other authorizations respecting classificaBalance Sheet, Statement of Income for the year, Statement
tion of amounts as plant adjustment s and requ i rement s as
of Retained Earnings for the year, and Statement of Cash
Flows, or any account thereof. Classify the notes according
to disposition thereof.
to each basic statement, providing a subheading for each
4. ~here Accounts 189, Unamortized loss on Reacquired
s tatement except where a note is applicable to more than
Debt, and 257, Unamortized Gain on Reacquired Debt, are
not used, give an explanation, providing the rate treatment
one statement.
2. Furnish particulars (details) as to any significant contin- given these items. See General Instruction 17 of the Uniform
System of Accounts.
gent assets or liabilities existing at end of year, including a
5. Give a concise explanation of any retained earnings
brief explanation of any action initiated by the Internal
Revenue Service involving possible assessment of additional
restrictions and state the amount of retained earnings affected
income taxes of material amount, or of a claim for refund of
by such restrictions.
6. If the notes to financial statements relating to the
income taxes of a material amount initiated by the utility.Give
respondent company appearing in the annual report to the
also a brief explanation of any dividends in arrears on
stockholders are applicable and furnish the data required by
cumulative preferred stock.
instructions above and on pages 114-121, such notes may
3. For Account 116, Utility Plant Adjustments, explain the
be included herein.
or i gin of such amount, debits and credits during the year, and
N9me of Res pondent
Florida Power & L1ght Company

I

I

PAGE 122 INTENTIONALLY LEFT BLANK
SEE PAGE 123 FOR REQUIRED INFORMATION

FERC FORM N0. 1 (ED. 12-96)

Page 122

I

 Date o f Report Year of Report
Name of Respondent
This Report Is:
(Mo,Da,Yr )
Florida Power & Light Comp (1 ) [X]An Original
Dec . 31 , 1 996
any
(2 ) [ ]A Resubmission
NOTES TO FINANCIAL STATEMENTS

(Continued )

FPL GROUP, INC. AND FLORIDA POWER & LIGHT COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Years Ended December 31, 1996, 1995 and 1994
1.

Summary of Significant Accounting and Reporting Policies

Basis of Presentation - Substantially all of FPL Group, Inc.'s (FPL
Group) revenues are derived from Florida Power & Light Company (FPL)
which supplies electric service to 3.6 million customers throughout
most of the east and lower west coasts of Florida.
Other operations
mainly consist of investments in non - utility energy projects and
agricultural operations.
The consolidated financial statements of FPL Group and FPL include
the accounts of their respective subsidiaries. All significant
intercompany balances and transactions have been eliminated in
consolidation.
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 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.
Regulation - FPL is a public utility subject to 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 practices set forth
1n Statement of Financial Accounting Standard (FAS) 71, "Accounting
for the Effects of Certain Types of Regulation." FAS 71 indicates
that regulators can create assets and impose liabilities that would
not be recorded by non-regulated entities. Regulatory assets and
liabilities represent probable future revenues that will be recovered
from or refunded to customers through the ratemaking process.
Recoverability of regulatory assets is assessed at each reporting
period.
Var1ous states, other than Florida, have either enacted legislation
or are pursuing initiatives designed to deregulate the production and
sale of electricity.
By allowing customers to choose their
ele ctricity supplier, deregulation is expected to result in a shift
fr om cost-based rates to market-based rates for energy production.
Similar initiatives are also being pursued on the federal level.
Although the legislation and initiatives vary substantially, common
areas of focus include when market-based pricing will be available
FERC FORM N0 .1 (ED. 12-96)

Page 123

Next Page is 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
Florida Power & Light Comp ( 1) [X] An Original
(Mo, Da, Yr)
any
(2) [ ]A Resubmission
Dec. 31, 1996
NOTES TO FINANCIAL STATEMENTS

(Continued)

for wholesale and retail customers, what existing prudently incurred
costs in excess of the market-based price will be recoverable and
whether generation assets should be separated from transmission,
distribution and other assets.
In the event that FPL's operations are no longer subject to the
provisions of FAS 71, as a result of market-based pricing due to
regulatory or other changes, existing regulatory assets and
liabilities would be written off unless regulators specify an
alternative means of recovery or refund.
The principal regulatory
assets and liabilities are as follows:
December 31,
---------------------1996
1995
--------- ---------(Thousands of Dollars)
Assets:
Unamortized debt reacquisition costs ..........
Plant-related deferred costs (included
in other assets) . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Nuclear maintenance cumulative effect
adjustment (included in other assets) ........
Deferred Department of Energy (DOE)
assessment (included in other assets) ........
Liabilities:
Deferred regulatory credit - income taxes .....
Unamortized investment tax credits ............
Storm and property insurance reserve ..........

.

$ 282,756

.

$

46,191

.

$

21,311

.

$

52,598

.
.
.

$ 128,638
$ 250,641
$ 222,577

$ 294,844
$

73,906
-

$

56,254

$ 144,351
$ 281,966
$ 177,498

The amounts presented above exclude clause-related regulatory assets
and liabilities that are recovered or refunded over six-month periods.
These amounts are reflected as current assets and liabilities in the
consolidated balance sheets. Additionally, other aspects of the
business, such as generation assets and long-term power purchase
commitments, would need to be reviewed to assess their recoverability
in a changed regulatory environment.
Since there is no deregulation
proposal currently under consideration in Florida, FPL is unable to
predict what impact would result from a change to a more competitive
environment.
FPL has been taking steps to lower its costs of operations.
In 1995,
FPL began amortizing the plant-related deferred costs in the table above
over a period of no more than five years as approved by the FPSC.
In
1996, FPL received final approval from the FPSC of a program started in
1995 to amortize specified nuclear and fossil generating assets, the tax
effect of certain tax basis differences and debt reacquisition costs
(collectively, special amortization).
The program calls for a continuing
FERC FORM N0.1

(ED. 12-96)

Page 123.1

Next Page is 200

 Date o f Report Year o f Repo r t
Name of Respondent
This Report Is:
(Mo,Da,Yr )
Florida Power & Light Comp (1 ) [X]An Original
Dec. 31 , 1 996
any
(2 ) [ ]A Resubmission
NOTES TO FINANCIAL STATEMENTS

(Continued )

special nuclear amortization of $30 million per year plus, through 19 9 7,
an additional amount of amortization based on the level of sales
achieved compared to a forecasted amount.
Under this program, $160
million of special amortization was recorded in 1996 and $126 million in
1995 . The 1996 amount includes, as depreciation and amortization
expense, $20 million of amortization of the tax effects of tax basis
differences.
By the end of 1996, the approved amounts for nuclear and
fossil generating assets had been completely amortized and accelerated
amortization of regulatory assets had begun.

~

~

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. Unbilled base revenues are included in
customer receivables and amounted to approximately $161 million and
$155 million at December 31, 1996 and 1995, respectively.
Revenues include amounts resulting from cost recovery clauses, which
are designed to permit full recovery of certain costs and provide a return
on certain assets utilized by these programs, and franchise fees.
These
revenues generally represent a pass-through of costs and include
substantially all fuel, purchased power and interchange expenses,
conservation- and environmental-related expenses, certain revenue
taxes and franchise fees.
Revenues from cost recovery clauses are
recorded when billed; FPL achieves matching of costs and related
revenues by deferring the net under or over recovery.
Any under
recovered costs or over recovered revenues are collected from or
returned to customers in subsequent periods.
Electric Utility Plant, Depreciation and Amortization - The cost of
additions to units of utility property is added to electric utility plant.
The cost of units of utility property retired, less net salvage, 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, 1996, the generating, transmission,
distribution and general facilities of FPL represented approximately 38%,
14%, 40% and 8%, respectively, of FPL's investment in electric utility
plant in service, net of accumulated depreciation.
Substantially all
electric utility plant is subject to the lien of a mortgage securing FPL's
first mortgage bonds.
Depreciation of utility property is primarily provided on a straight-line
average remaining life basis and includes a provision for fossil plant
d ismantlement and nuclear plant de commissioning.
For substantially all
utility property, depreciation and fossil fuel plant dismantlement studies
are performed at least every four years.
The next studies are scheduled
to be filed in 1997 and would be effective for 1998. The weighted
FERC FORM N0.1

(ED . 12 - 96)

Page 123.2

Next Page i s 20 0

 Name of Respondent
This Report Is:
Date of Report Year of Report
(Mo,Da,Yr)
Florida Power & Light Comp (1) [X]An Original
any
( 2) [ ] A Resubmission
Dec . 31, 19 9 6
NOTES TO FINANCIAL STATEMENTS

(Continued)

annual composite depreciation rate was approximately 4.1% for 1996
and 4.0% for 1995 and 1994, excluding the effects of dismantlement and
decommissioning.
Further, the 1996 and 1995 rates exclude
approximately $188 million and $163 million, respectively, of special and
plant-related deferred costs amortization.
See Regulation.
The 1994
rate excludes $47 million of accelerated write-off of certain accumulated
plant overhaul costs.
Nuclear Fuel - FPL leases nuclear fuel for all four of its nuclear units.
Nuclear fuel lease payments were $94 million, $104 million and $115
million in 1996, 1995 and 1994, respectively.
Included in these
payments was an interest component of $10 million in 1996 and $11
million in both 1995 and 1994. The nuclear fuel lease payments and a
charge for spent nuclear fuel disposal are charged to fuel expense on a
unit of production method.
These costs are recovered through the fuel
and purchased power cost recovery clause (fuel clause). Under certain
circumstances of lease termination, FPL is required to purchase all
nuclear fuel in whatever form at a purchase price designed to allow the
lessor to recover its net investment cost in the fuel, which totaled $182
million at December 31, 1996. For ratemaking, these leases are
classified as operating leases.
For financial reporting, the capital lease
obligation is recorded at the amount due 1n the event of lease
termination.
Decommissioning and Dismantlement of Generating Plant - FPL
accrues nuclear decommissioning costs over the expected service life of
each unit. Nuclear decommissioning studies are performed at least once
every five years for FPL's four nuclear units and are submitted to the
FPSC for approval.
The next studies are scheduled for 1999. These
studies assume prompt dismantlement for the Turkey Point Unit Nos. 3
and 4 with decommissioning activities commencing in 2012 and 2013,
respectively.
St. Lucie Unit No. 1 will be mothballed in 2016 until St.
Lucie Unit No. 2 is ready for decommissioning in 2023. These studies
also assume that FPL will be storing spent fuel on site pending removal
to a U.S. Government facility.
In January 1997, FPL joined a number of
other utilities in a lawsuit against the DOE to suspend payments for
future transportation and storage. Alternatively, the utilities proposed
to hold the funds in escrow until a nuclear waste storage facility is
available. Decommissioning expense accruals, included in depreciation
and amortization expense, were $85 million in both 1996 and 1995 and
$38 million in 1994.
FPL's portion of the ultimate cost of
decommissioning its four units, including dismantlement and reclamation,
expressed in 1996 dollars, is currently estimated to aggregate $1.5
billion. At December 31, 1996 and 1995, the accumulated provision for
nuclear decommissioning totaled $805 million and $666 million,
respectively, and is included in accumulated depreciation.
Similarly, FPL accrues the cost of dismantling its fossil fuel plants over
FERC FORM N0.1 (ED. 12 -96)

Page 123.3

Next Page is 200

 r-

Date o f Report Year o f Repo r t
Na me of Respondent
This Re p o rt Is:
(Mo, Da, Yr )
Florida Power & Light Comp (1 ) [X]An Original
De c . 31, 1 996
(
2
)
[
]
A
Resubmission
any
NOTES TO FINANCIAL STATEMENTS

(Continued )

the expected service life of each unit.
Fossil dismantlement expense
totaled $17 million, $25 million and $11 million in 1996, 1995 and 1994,
respectively, and is included in depreciation and amortization expense .
The ultimate cost of dismantlement for the fossil units, expressed in
1996 dollars, is estimated to be $258 million. At December 31, 1996
and 1995, the accumulated provision for fossil dismantlement totaled
$146 million and $130 million, respectively, and is a component of
accumulated depreciation.
Restricted assets for the payment of future expenditures to
decommission FPL's nuclear units are included in special use funds of
FPL. At December 31, 1996 and 1995, decommissioning fund assets
were $667 million and $534 million, respectively.
Securities held in the
decommissioning fund are carried at market value with market
adjustments resulting in a corresponding adjustment to the accumulated
provision for nuclear decommissioning.
See Note 7.
Contributions to
the funds are based on current period decommissioning expense.
Additionally, fund earnings, net of taxes are reinvested in the funds . The
tax effects of amounts not yet recognized for tax purposes are included
in accumulated deferred income taxes.
~

In 1996, the Financial Accounting Standards Board issued an exposure
draft, "Accounting for Certain Liabilities Related to Closure or Removal of
Long-Lived Assets.'' The primary effect of this exposure draft would be
to change the · way FPL accounts for nuclear decommissioning and fossil
dismantlement costs.
The exposure draft calls for recording the present
value of estimated future cash flows to decommission FPL's nuclear
power plants and dismantle its fossil power plants as an increase to
asset balances and as a liability.
This amount is currently estimated to
be $1.4 billion.
It is anticipated that there will be no effect on cash
flows and, because of the regulatory treatment, there will be no
significant effect on net income.
Accrual for Nuclear Maintenance Costs - In 1996, the FPSC approved a
new method of accounting for costs associated with nuclear refueling
outages. Under this new method, the estimated nuclear refueling and
maintenance costs relating to each unit's next planned outage will be
accrued over the period beginning when the unit resumes operations
t ~ til the end of the next outage.
Any difference between the estimated
and actual costs will be included in O&M expenses when known.
This
approach will result in FPL recognizing costs equivalent to slightly less
than three outages per year based upon the current refueling outage
s c hedule for FPL's four nuclear units.
The cumulative effect of adopting
i s accounting method was $35 million and, in accordance with the
? SC order, was recorded as a regulatory asset which will be amortized
a n d included in O&M expenses over a period not to exceed f ive years.
In 1996, $14 million of the cumulative adjustment was expensed.

"E RC

FORM N0.1

(ED. 12- 9 6)

Page 123. 4

Ne xt Page is 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
Florida Power & Light Comp (1) [X]An Original
(Mo,Da,Yr)
any
(2) [ ]A Resubmission
De c. 31, 1996
NOTES TO FINANCIAL STATEMENTS

(Continued )

Allowance for Funds Used During Construction (AFUDC) - AFUDC is a
noncash item representing the allowed cost of capital, including a return
on common equity, used to finance FPL's construction projects.
In 1996,
the FPSC eliminated the recording of AFUDC except for projects that
cost ln excess of 1/2% of a company's utility plant in service balance
and recharacterized the construction work in progress balance as an
element of rate base. AFUDC amounted to $2 million, $15 million and
$24 million for the years ended December 31, 1996, 1995 and 1994,
respectively, and is included in other - net in the consolidated statements
of income.
Storm and Property Insurance Reserve Fund (storm fund) - The storm
fund provides coverage toward storm damage costs and possible
retrospective premium assessments stemming from a nuclear incident
under the various insurance programs covering FPL's nuclear generating
plants. The storm fund, which totaled $139 million and $113 million at
December 31, 1996 and 1995, respectively, is included in special use
funds of FPL. Securities held in the fund are carried at market value
with market adjustments resulting ln a corresponding adjustment to the
storm and property insurance reserve.
See Note 7 and
Note 9 - Insurance.
Fund earnings, net of taxes, are reinvested in the
fund.
The tax effects of amounts not yet recognized for tax purposes
are included in accumulated deferred income taxes.
Other Investments - Included in other investments in FPL Group's
consolidated balance sheets are non-majority owned interests in
partnerships and joint ventures, essentially all of which are accounted for
under the equity method. Additionally, other investments include FPL
Group's participation in leveraged leases of $157 million and $158
million at December 31, 1996 and 1995, respectively.
Cash Equivalents - Cash equivalents consist of short-term, highly liquid
investments with original maturities of three months or less.
Commercial Paper - The year end weighted-average interest rate on
commercial paper at December 31, 1995 was 5.8%.
Retirement of Long - Term Debt - The excess of FPL's reacquisition cost
over the book value of long-term debt is deferred and amortized to
expense ratably over the remaining life of the original issue, which lS
consistent with its treatment ln the ratemaking process. See Regulation.
FPL Group Capital Inc (FPL Group Capital) expenses this cost in the
period incurred.
Inc ome Taxes - Deferred income taxes are provided on all significant
temporary differences between the financial statement and tax bases of
assets and liabilities.
FPL is included in the consolidated federal lncome
tax return filed by FPL Group.
FPL determines its income tax provision
FERC FORM N0.1

(ED. 12-96)

Page 123.5

Next Page is 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
Florida Power & Light Comp (1) [X]An Original
(Mo, Da, Yr)
any
(2) [ ]A Resubmission
Dec . 3 1 , 19 9 6
NOTES TO FINANCIAL STATEMENTS

(Continued)

on the "separate return method." The deferred regulatory creditincome taxes of FPL represents the revenue equivalent of the difference
in accumulated deferred income taxes computed under FAS 109,
"Accounting for Income Taxes," as compared to prior accounting rules.
This amount is being amortized in accordance with the regulatory
treatment over the estimated lives of the assets or liabilities which
resulted in the initial recognition of the deferred tax amount.
Investment
tax credits (ITC) for FPL are deferred and amortized to income over the
approximate lives of the related property in accordance with the
regulatory treatment.
2.

Jointly-Owned Electric Utility Plant

FPL owns approximately 85% of the St. Lucie Unit No. 2, 20% of the St.
Johns River Power Park units and coal terminal and approximately 76%
of Scherer Unit No. 4. At December 31, 1996, FPL's gross investment in
these units was $1.176 billion, $329 million and $570 million,
respectively; accumulated depreciation was $434 million, $129 million
and $138 million, respectively.
FPL is responsible for its share of the operating costs, as well as
providing its own financing. At December 31, 1996, there was no
significant balance of construction work in progress on these facilities.
3.

Employee Retirement Benefits

Pension Benefits - Substantially all employees of FPL Group and its
subsidiaries are covered by a noncontributory defined benefit pension
plan.
Plan benefits are generally based on employees' years of service
and compensation during the last years of employment.
Participants are
vested after five years of service. All costs of the FPL Group pension
plan are allocated to participating subsidiaries on a pro rata basis.
For 1996, 1995 and 1994 the components of pension cost are as
follows:

FERC FORM N0.1

(ED. 12-96)

Page 123.6

Next Page is 200

 Date of Report Year of Report
Name of Respondent
This Report Is:
(Mo, Da, Yr)
Florida Power & Light Comp ( 1) [X] An Original
Dec. 31, 1996
(2)
[
]A
Resubmission
any
NOTES TO FINANCIAL STATEMENTS

(Continued)

Years Ended December 31,
----------- -------------------1994
1995
1996
(Thousands of Dollars)
Service cost . . . . . . . . . . . . . . . . . . . . . . . . . .
Interest cost on projected benefit
obligation . . . . . . . . . . . . . . . . . . . . . . . . . . .
Actual return on plan assets ..........
Net amortization and deferral .........

38,302

$

31,782

$

37,423

.

$

.
.
.

80,466
87,871
(11,293)
(350,237)
(118,770)
211,523
--------- --------(12,174)
(19,061)
5,338
--------- --------- --------$ (18,529) $ (13,723) $ (12,174)

Negative pension cost . . . . . . . . . . . . . . . . . .
Effect of special retirement programs ..
FPL Group's pension cost . . . . . . . . . . . . . . .
Pension cost allocated to FPL ......... .

90,716
(123,278)
(24,269)
--------(18,529)

=========

=========

$ (13,432)

$ (11,966)

=========

=========

=========

$ (18,285)

=========

FPL Group and its subsidiaries fund the pension cost calculated under
the entry age normal level percentage of pay actuarial cost method,
provided that this amount satisfies the minimum funding standards of the
Employee Retirement Income Security Act of 1974, as amended, and is
not greater than the maximum tax deductible amount for the year. No
contributions to the plan were required for 1996, 1995 or 1994.
A reconciliation of the funded status of the plan to the amounts
recognized in FPL Group's consolidated balance sheets is presented
below:

FERC FORM N0.1

(ED. 12-96)

Page 123.7

Next Page is 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
Florida Power & Light Comp (1) [X]An Original
(Mo,Da,Yr)
any
(2) [ ]A Resubmission
Dec . 3 1 , 19 9 6
NOTES TO FINANCIAL STATEMENTS

(Continued)

September 30, December 31,
1996
1995
(Thousands of Dollars)
Plan assets at fair value, primarily
listed stocks and bonds . . . . . . . . . . . . . . . . . . . . . . . .

$1,996,405

$1,910,986

Actuarial present value of benefits for
se l vices rendered to date:
Accumulated benefits based on salaries to
date, including vested benefits of $898
million and $924 million . . . . . . . . . . . . . . . . . . . . .
Additional benefits based on estimated
future salary levels . . . . . . . . . . . . . . . . . . . . . . . . .

950,865

982,159

311,294

447, 1 20

Projected benefit obligation . . . . . . . . . . . . . . . . . . . .

1,262,159

1,429,279

.

734,246

481,707

.

174,740

187,463

.
.

(186,847)
(674,950)

(210,203)
(430,307)

Plan assets in excess of projected
benefit obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Prior service costs not recognized in net
periodic pension cost . . . . . . . . . . . . . . . . . . . . . . . . .
Unrecognized net asset at January 1, 1986,
being amortized over 19 years - net of
accumulated amortization . . . . . . . . . . . . . . . . . . . . . .
Unrecognized net gain . . . . . . . . . . . . . . . . . . . . . . . . . .

Prepaid pension cost of FPL Group . . . . . . . . . . . . . . .

$

47,189

==========
Prepaid pension cost allocated to FPL .......... .

$

43,354

$

28,660

==========
$

25,069

The weighted-average discount rate used in determining the actuarial
present value of the projected benefit obligation was 7.00% and 6.75%
for 1996 and 1995, respectively. The assumed rate of increase in future
compensation levels was 5.5% for both years.
The expected long-term
rate of return on plan assets used in determining pension cost was
7.75% for 1996, 1995 and 1994.
In 1996, FPL Group elected to change
the measurement date for pension obligations and plan assets from
December 31 to September 30. The effect of this accounting change is
not material.
Other Postretirement Benefits - FPL Group and its subsidiaries have
defined benefit postretirement plans for health care and life insurance
benefits that cover substantially all employees. All costs of the FPL
Group plans are allocated to participating subsidiaries on a pro rata
basis.
Eligibility for health care benefits lS based upon age plus years
FERC FORM N0.1

(ED . 12-9 6 )

Page 123.8

Next Page is 200

 Date of Report Year of Report
Name of Respondent
This Report Is:
(Mo,Da, Yr)
Florida Power & Light Comp ( 1) [X] An Original
Dec. 31, 19 9 6
any
( 2) [ ] A Resubmission
NOTES TO FINANCIAL STATEMENTS

(Continued)

of serv1ce at retirement.
The plans are contributory and contain
cost-sharing features such as deductibles and coinsurance.
FPL Group
has capped company contributions for postretirement health care at a
defined level which, depending on actual claims experience, may be
reached by the year 2004.
Generally, life insurance benefits for retirees
are capped at $50,000.
FPL Group's policy is to fund postretirement
benefits in amounts determined at the discretion of management.
For 1996, 1995 and 1994, the components of net periodic postretirement
benefit cost are as follows:
Years Ended December 31,
1996

1995

1994

(Thousands of Dollars)
Service cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Interest cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Actual return on plan assets . . . . . . . . . . . . . . .
Amortization of transition obligation ......
Net amortization and deferral . . . . . . . . . . . . . .

.
.
.
.
.

FPL Group's postretirement benefit cost .....
Postretirement benefit cost allocated
to FPL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

$ 4,921
18,138
(4, 621)
3,485
(2,324

$

-------

--------

-------

$19,599

$ 18,557

- ======

========

$18,633
=======

4,216
18,119
(23,742)
3,485
16,479

$ 4,717
17,336
(749)
3,485
(6 156)
1

$19,464

$ 18,326

$18,436

=======

========

=======

A reconciliation of the funded status of the plan to the amounts
recognized 1n FPL Group's consolidated balance sheets is presented
below:

FERC FORM N0.1

(ED. 12-96)

Page 123.9

Next Page is 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
(Mo,Da,Yr)
Florida Power & Light Comp (1) [X]An Original
Dec. 31, 1996
any
( 2) [ ] A Resubmission
NOTES TO FINANCIAL STATEMENTS

(Continued)

September 30, December 31,
1996
1995
(Thousands of Dollars)
Plan assets at fair value, primarily
listed stocks and bonds . . . . . . . . . . . . . . . . . . . . . . . . . .
Accumulated postretirement benefit obligation:
Retirees . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Fully eligible active plan participants ........ .
Other active plan participants . . . . . . . . . . . . . . . . . .
Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accumulated postretirement benefit obligation
in excess of plan assets . . . . . . . . . . . . . . . . . . . . . . . . .
Unrecognized net transition obligation
(amortized over 20 years) . . . . . . . . . . . . . . . . . . . . . . . .
Unrecognized net loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accrued postretirement benefit liability of
FPL Group . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Accrued postretirement benefit liability
allocated to FPL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

$ 107,334

$ 110,435

188,618
3,327
81,604
--------273,549

172,572
3,194
94,128
--------269,894

--------(166,215)
55,762
10,002
---------

--------(159,459)
59,247
18,269
---------

$(100,451) $ (81,943)

=========

=========

$ (99,568) $ (81,194)

=========

=========

The weighted-average annual assumed rate of increase ln the per capita
cost of covered benefits (i.e., health care cost trend rate) for 1996 is
7.5% for retirees under age 65 and 6.5% for retirees over age 65.
These rates are assumed to decrease gradually to 5.0% by 2003. The
cap on FPL Group's contributions mitigates the potential significant
increase in costs resulting from an increase in the health care cost trend
rate.
Increasing the assumed health care cost trend rate by one
percentage point would increase the plan's accumulated postretirement
benefit obligation as of September 30, 1996 by $8 million, and the
aggregate of the service and interest cost components of net periodic
pc .
~ tirement benefit cost of the plan for 1996 by approximately $1
milL n.

FERC FORM N0.1 (ED. 12-96)

Page 123.10

Next Page is 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
(Mo,Da,Yr)
Florida Power & Light Comp (1) [X]An Original
any
(2) [ ]A Resubmission
Dec. 31, 1996
NOTES TO FINANCIAL STATEMENTS

(Continued)

The weighted-average discount rate used in determining the
accumulated postretirement benefit obligation was 7.00% and 6.75% for
1996 and 1995, respectively.
The expected long-term rate of return on
plan assets used in determining postretirement benefit cost was 7.75%
for 1996, 1995 and 1994.
In 1996, FPL Group elected to change the
measurement date for benefit obligations and plan assets from
December 31 to September 30.
The effect of this accounting change is
not material.
4.

Common Shareholders' Equity

FPL Group - The changes ln FPL Group's common shareholders' equity
accounts are as follows:

FERC FORM N0.1

(ED. 12-96)

Page 123.11

Next Page is 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
Florida Power & Light Comp ( 1) [X] An Original
(Mo,Da,Yr)
Dec . 3 1 , 1 9 9 6
any
( 2) [ ] A Resubmission
NOTES TO FINANCIAL STATEMENTS

(Continued)

Common Stock (1)

Shares

,.....

Aggre - Additional Unearned
gate Par Paid-In
CompenValue
Capital
sation

Common
Shareholders'
Equity

Retained
Earnings

Balances,
(In Thousands)
12/31/93 ........ 190,065
$1,901 $3,589,994 $(321,121)$ 829,833
Net income....
518,711
Issuance of common stock ....
16,680
506
5
Repurchase of com(40)
mon stock....
(4, 000)
(123,693)
Dividends on common stock ....
(334,751)
Earned compensation under
ESOP ........ .
1,964
16,900
Other ........ .
852
Balances,
(304,221) 1,013,793
12/31/94 ........ 186,571(2) 1,866 3,485,797
Net income ....
Repurchase of common stock....
(1, 878)
Dividends on common stock ....
Earned compensation under
ESOP ........ .
Other ........ .

(19)
-

Balances,
12/31/95 ........ 184,693(2) 1,847
Net income ....
Repurchase of common stock....
(1,861)
Dividends on common stock ....
Earned compensation under
ESOP ........ .
(17)
Other ........ .

(69,375)
5,030
(1,832)
3,419,620

-

553,311

-

-

16,741
-

(308,582)
-

(287,480) 1,258,522 $4,392,509
579,450

( 19)

(81,636)
(320,253)
7,991
(842)

14,932

Balances,
12/31/96 ........ 182,815(2)$1,828 $3,345,133 $(272,548)$1,517,719 $4,592,132

====== ========== ========= ========== ==========
FERC FORM N0.1

(ED. 12-96)

Page 123.12

Next

Pa o~

i s 20 0

 Date of Report Year of Report
Name of Respondent
This Report Is:
(Mo,Da,Yr)
Florida Power & Light Comp (1 ) [X]An Original
Dec. 31, 1996
any
(2) [ ]A Resubmission
NOTES TO FINANCIAL STATEMENTS

(Continued)

(1) $.01 par value, authorized- 300,000,000 shares; outstanding 182,815,135
and 184,692,985 at December 31, 1996 and 1995, respectively.
(2) Outstanding and unallocated shares held by the ESOP Trust totaled 9.3
million, 9.8 million and 10.4 million at December 31, 1996, 1995 and
1994, respectively.
Common Stock Dividend Restrictions - FPL Group's charter does not
limit the dividends that may be paid on its common stock. As a practical
matter, the ability of FPL Group to pay dividends on its common stock is
dependent upon dividends paid to it by its subsidiaries, primarily FPL.
FPL's charter and a mortgage securing FPL's first mortgage bonds
contain provisions that, under certain conditions, restrict the payment of
dividends and other distributions to FPL Group.
These restrictions do
not currently limit FPL's ability to pay dividends to FPL Group.
In 1996,
1995 and 1994, FPL paid, as dividends to FPL Group, its net income
available to FPL Group on a one-month lag basis.
Employee Stock Ownership Plan (ESOP) - The employee thrift plans of
FPL Group include a leveraged ESOP feature.
Shares of common stock
held by the Trust for the thrift 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 the ESOP loan held by FPL Group Capital.
Dividends on shares allocated to employee accounts and used by the
Trust for debt service are replaced with an equivalent amount of shares
of common stock at prevailing market prices.
ESOP-related compensation expense of approximately $23 million in
1996 and $18 million in both 1995 and 1994 was recognized 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
shareholders' equity at December 31, 1996 was approximately $269
million, representing 9.3 million unallocated shares at the original issue
price of $29 per share. The fair value of the ESOP-related unearned
compensation account using the closing price of FPL Group stock as of
December 31, 1996 was approximately $427 million.
Long-Term Incentive Plan - In 1994, FPL Group's board of directors and
its shareholders approved FPL Group's current long-term incentive plan.
Under this plan, 9 million shares of common stock are reserved and
available for awards to officers and employees of FPL Group and its
subsidiaries as of December 31, 1996. Total compensation charged
against earnings under the incentive plan, and the effect on earnings per
share, were not material in any year.
The changes in share awards
under the incentive plan are as follows:

FERC FORM N0.1 (ED. 12-96)

Page 123.13

Next Page is 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
Florida Power & Light Comp (1) [X]An Original
(Mo,Da,Yr )
any
(2) [ ]A Resubmission
Dec . 31, 19 9 6
NOTES TO FINANCIAL STATEMENTS

(Continued)

Perf ormance
Shares
Balances, December 31, 1993 . . . . . . . . . . . . .
Granted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Exercised at $30 7/8 . . . . . . . . . . . . . . . . . .
Pa ~ j/released . . . . . . . . . . . . . . . . . . . . . . . . .
Fe ""· eited . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

.
.
.
.
.

Balances, December 31, 1994 . . . . . . . . . . . . .
Granted ( 1) . . . . . . . . . . . . . . . . . . . . . . . . . . .
~ s rcised at $30 7/8 . . . . . . . . . . . . . . . . .
..... _djreleased . . . . . . . . . . . . . . . . . . . . . . . . .
Forfeited . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

.
.
.
.
.

Balances, December 31, 1995 . . . . . . . . . . . . .
Granted ( 1) . . . . . . . . . . . . . . . . . . . . . . . . . . .
Exercised at $30 7/8 . . . . . . . . . . . . . . . . . .
Paid/released . . . . . . . . . . . . . . . . . . . . . . . . .
Forfeited . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

.
.
.
.
.

--------

-------

--- ·----

280,059
102,720

166,323
29,000

5 C,076

-

-

(51 589)

-

( 81

-

(6,223)
(1, 350)

941)
-

(2, 748)

--------

-------

-------

377,190
97,786

187,750
13,500

38,387

-

(123,328)
(31,312)

-

-

(23,136)

(3,000)
(4,050)

-

(4, 066)

--------

-------

-------

320,336
90,772

194,200
23,000

11,185

-

-

(60,359)
(39,222)
--------

Balances, December 31, 1996 . . . . . . . . . . . . . .

Restricted
Stock

Nonqualified
Option
Shares

-

(10,935)

(34,250)
(16,650)
-------

-

(250)
-------

311,527(2) 166,300(3)

========

=======

=======

(1) The average grant date fair value of equity instruments issued under
the incentive plan was $5 million in 1996 and $4 million in 1995.
(2) Payment of performance shares is based on the market price of FPL
Group's common stock when the related performance goal is achieved.
(3) Shares of restricted stock were issued at market value at the da t e
of the grant.
The requirements of FAS 123, "Accounting for Stock-Based
Compensation," became effective in 1996. The statement encourages,
but does not require, a fair value-based method of accounting for
stock-based compensation.
FPL Group elected to continue the use of
the intrinsic value-based method of accounting; however,
implementation of FAS 123 would not have a material effect on FPL
Group's results of operations or earnings per share.
Other - Each share of common stock has been granted a Preferred Share
Purchase Right (Right), which is exercisable in the event of certain
attempted business combinations.
The Rights will cause substantial
dilution to a person or group attempting to acquire FPL Group on
terms not approved by FPL Group's board of directors.
FERC FORM N0.1

(ED.

- 96 )

Page 123.14

Ne x t Pag e is 2 00

 Date of Report Year of Report
Name of Respondent
This Report Is:
(Mo,Da, Yr )
Florida Power & Light Comp ( 1) [X] An Original
Dec. 31, 1996
any
( 2) [ ] A Resubmission
NOTES TO FINANCIAL STATEMENTS

(Continued)

FPL - The changes in FPL's common shareholder's equity accounts are
as follows:
AddiCommon
tional
SharePaid-In
Retained
holder's
Common
Stock (1)
Capital
Earnings
Equity
(Thousands of Dollars)
Balances, 12/31/93 ........
Contributions from
FPL Group . . . . . . . . . . . . . .
Net income available to
FPL Group . . . . . . . . . . . . . .
Dividends to FPL Group ..
Other . . . . . . . . . . . . . . . . . . .
Balances, 12/31/94 ........

.

$1,373,069

$1,741,436

$ 864,920

.

-

205,000

-

.
.
.
.

-

-

-

-

1,373,069

100
1,946,536

528,515
(527,454)
-

865,981

----------

----------

---------

.

-

280,000

-

.
.
.

-

-

-

Balances, 12/31/95 ........ .

---------1,373,069

Contributions from
FPL Group . . . . . . . . . . . . . .
Net income available to
FPL Group . . . . . . . . . . . . . .
Dividends to FPL Group ..
Other . . . . . . . . . . . . . . . . . . .

Contributions from
FPL Group . . . . . . . . . . . . . .
Net income available to
FPL Group . . . . . . . . . . . . . .
Dividends to FPL Group ..
Other . . . . . . . . . . . . . . . . . . .

-

2,057
---------2,228,593

567,972
(557,923)
(3, 984)

---------

872,046

$4,473,708

==========
.

-

.
.
.

-

-

-

-

Balances, 12/31/96 ........ .

195,000

-

-

166

---------$1,373,069

----------

$2,423,759

591,162
(592,815)
(280)
--------$ 870,113 $4,666,941

==========

==========

=========

==========

(1) Common stock, no par value, 1,000 shares authorized, issued and
outstanding.
5.

Preferred Stock

FPL Group's charter authorizes the issuance of 100 million shares of
serial preferred stock, $.01 par value.
None of these shares is
outstanding.
FPL Group has reserved 3 million shares for issuance
upon exercise of preferred share purchase rights which expire in June
2006.
Preferred stock of FPL consists of the following: (1)
====================PLEASE NOTE: THE NEXT PAGE IS 123.17====================
FERC FORM N0.1

(ED. 12-96)

Page 123.15

Next Page is 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
Florida Power & Light Comp ( 1) [X] An OriginC< l
(Mo,Da,Yr)
Dec. 31, 1996
any
(2) [ ]A Resubmission
NOTES TO FINANCIAL STATEMENTS

(Continued)

December 31, 1996
Redemption
Price

Outstanding

December 31,
1996

1995

(Thousands of $)
Cumulative, No Par Value, authorized
10,000,000 shares at December 31,
1996 and 1995; without sinking fund
requirements - $2.00 No Par Value,
Series A (Involuntary Liquidation
Value $25 Per Share) (2) . . . . . . . . . . .
Cumulative, $100 Par Value, authorized
15,822,500 shares at December 31,
1996 and 1995:
Without sinking fund requirements:
4 1/2% Series . . . . . . . . . . . . . . . . . .
4 1/2% Series A . . . . . . . . . . . . . . . .
4 1/2% Series B . . . . . . . . . . . . . . . .
4 1/2% Series C . . . . . . . . . . . . . . . .
4. 32% Series D . . . . . . . . . . . . . . . . .
4. 35% Series E . . . . . . . . . . . . . . . . .
7. 28% Series F . . . . . . . . . . . . . . . . .
7.40% Series G . . . . . . . . . . . . . . . . .
6.98% Series S . . . . . . . . . . . . . . . . .
7. 05% Series T . . . . . . . . . . . . . . . . .
6. 75% Series U . . . . . . . . . . . . . . . . .
Total preferred stock of FPL
without sinking fund requirements . . . . . . . . . . . . . . . . .
Less current maturities ..
Total preferred stock of FPL
without sinking fund requirements, excluding
current maturities ........ .

FERC FORM N0.1

(ED. 12- 9 6 )

2,533,188 $ 27.00

100,000
50,000
50,000
62,500
50,000
50,000
-

750,000
500,000
650,000

4,795,688

4,795,688

Page 123.17

$ 63,330 $ 63,330

$101.00
$101.00
$101.00
$103.00
$103.50
$102.00

10,000
5,000
5,000
6,250
5,000
5,000

-

-

- ( 3)
- ( 3)
- (3)

75,000
50,000
65,000

10,000
5,000
5,000
6,250
5,000
5,000
60,000
40,000
75,000
50,000
65,000

289,580
-

389,580
100,000

$289,580 $289,580

Next Pag e is 20 0

 Name of Respondent
This Report Is:
Date of Repo rt Year o f Repo r t
(Mo,Da,Yr )
Florida Power & Light Comp ( 1 ) [X] An Original
any
( 2 ) [ ] A Resubmission
Dec. 31, 1 996
NOTES TO FINANCIAL STATEMENTS

(Continued )

December 31, 1996
Outstanding

Redemption
Price

December 31,
1996

1995

(Thousands of $)
With sinking fund requirements(4):
6.84% Series Q (5) ............ .
8.625% Series R (6) . . .... . .... .

410,000 $102.28
50,000 $104.60

Total preferred stock of FPL
with sinking fund requirements . . . . . . . . . . . . . . . . .
Less current maturities ..

460,000
40,000

Total preferred stock of FPL
with sinking fund requirements, excluding current
maturities . . . . . . . . . . . . . . . . . .

420,000

$ 41,000 $ 44,000
5,000
10,000

46,000
4,000

54,000
4,000

$ 42,000 $ 50,000

======== ========
(1) FPL's charter authorizes the issuance of 5 million shares of
subordinated preferred stock, no par value.
None of these shares is
outstanding. There were no issuances of preferred stock in 1996, 1995
and 1994.
In 1996, FPL redeemed 600,000 shares of its 7.28% Preferred
Stock, Series F, $100 Par Value and 400,000 shares of its 7.40%
Preferred Stock, Series G, $100 Par Value.
(2) In 1995, 2,466,812 shares were tendered, accepted for exchange and
retired by FPL pursuant to its offer to exchange each such share for
$25 in principal amount of 8.75% Quarterly Income Debt Securities
(Subordinated Deferrable Interest Debentures).
In February 1997,
FPL issued notices to redeem all of the outstanding shares in
March 1997.
(3) Not redeemable prior to 2003.
(4) Minimum annual sinking fund requirements on preferred stock are $4
million for 1997 and 1998 and approximately $2 million per year for
1999 through 2001.
In the event that FPL should be in arrears on
its sinking fund obligations, FPL may not pay dividends on common stock.
(5) Entitled to a sinking fund to retire a minimum of 15,000 shares and
a maximum of 30,000 shares annually from 1997 through 2024 at $100 per
share plus accrued dividends.
FPL redeemed and retired 45,000 shares
in 1994, satisfying the 1994 and 1995 minimum annual sinking fund
requirement.
In 1996, FPL redeemed and retired 30,000 shares.
In February 1997, FPL issued notices to redeem and retire 30,000
shares on April 1, 1997.
(6) FPL redeemed and retired 400,000 shares in 1995.
In 1996, FPL
redeemed and retired 50,000 shares.
In February 1997, FPL issued
FERC FORM N0.1

(ED. 12-96)

Page 123.18

Nex t Page is 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
(Mo, Da, Yr )
Florida Power & Light Comp ( 1) [X] An Original
Dec . 31, 1996
any
( 2) [ ] A Resubmission
NOTES TO FINANCIAL STATEMENTS

(Continued)

notices to redeem and retire the remaining 50,000 shares on April 1,
1997.
6.

Long-Term Debt (1) (2)

Long-term debt consists of the following:
December 31,
1996

1995

(Thousands of Dollars)
FPL
First mortgage bonds:
Maturing through 2000 - 5 3/8% to 5 1/2% ....... .
Maturing 2001 through 2015 - 6 5/8% to 7 7/8% .. .
Maturing 2016 through 2026 - 7% to 8 1/2% ...... .
Medium-term notes:
Maturing through 2000 - 5.50% to 6.20% ....... .
Maturing 2001 through 2015 - 5.79% to 8.20% .. .
Maturing 2016 through 2022 - 8% . . . . . . . . . . . . . . .
Pollution control and industrial development
series -Maturing 2020 through 2027 - 6.7%
to 7.5% . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Pollution control, solid waste disposal and industrial development revenue bonds - Maturing 2021
through 2029 - variable, 3.6% and 4.3% average
annual interest rate, respectively . . . . . . . . . . . . . .
Installment purchase and security contracts maturing 2007 - 5. 9% . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Quarterly Income Debt Securities (Subordinated
Deferrable Interest Debentures) - maturing
2025 - 8.75% (3) · . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Unamortized discount - net . . . . . . . . . . . . . . . . . . . . . . . .

$

355,000 $ 355,000
659,738
661,838
910,452 1,024,702
180,300
106,500
98,610

280,300
106,500
98,610

150,135

150,135

483,735

483,735

2,000

2,000

61,670
(26,839)

61,670
(30,440)

Total long-term debt of FPL . . . . . . . . . . . . . . . . . . . . .
Less current maturities . . . . . . . . . . . . . . . . . . . . . . .

2,981,301
40

3,194,050
100,000

Long-term debt of FPL, excluding current
maturities .... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

2,981,261

3,094,050

F=RC FORM N0 .1

(ED. 12-96)

Page 123.19

Next Page i s 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
(Mo, Da, Yr)
Florida Power & Light Camp ( 1) [X] An Original
any
( 2) [ ] A Resubmission
Dec. 31, 1996
NOTES TO FINANCIAL STATEMENTS

(Continued)
December 31,
1996

1995

(Thousands of Dollars)
FPL Group Capital
Debentures:
Maturing 1997 - 6 1/2% . . . . . . . . . . . . . . . . . . . . . . . . .
Maturing 2013 - 7 5/8% . . . . . . . . . . . . . . . . . . . . . . . . .
Other long-term debt - 6.5% to 8.44% due various
dates to 2013 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Unamortized discount . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

.
.
.
.

150,000
125,000

150,000
125,000

40,740
(2 128)

17,655
(2 1190)

1

Total long-term debt of FPL Group Capital ...... .
Less current maturities . . . . . . . . . . . . . . . . . . . . . . .

313,612
150,560

290,465
7,902

Long-term debt of FPL Group Capital, excluding
current maturities . . . . . . . . . . . . . . . . . . . . . . . . . .

163,052

282,563

Total long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . .

$3,144,313 $3,376,613

(1) Minimum annual maturities and sinking fund requirements of long-term
debt for FPL Group for 1997-2001 are approximately $151 million, $180
million, $261 million, $125 million and $40 thousand, respectively.
The respective amounts for FPL are $40 thousand, $180 million, $230
million, $125 million and $40 thousand.
(2) Available lines of credit aggregated approximately $1.3 billion at
December 31, 1996, all of which were based on firm commitments.
(3) In February 1997, FPL issued notices to redeem all of the outstanding
Quarterly Income Debt Securities (Subordinated Deferrable Interest
Debentures) .
7.

Financial Instruments

The carrying amounts of cash equivalents and commercial paper
approximate their fair values.
Certain investments of FPL Group,
included in other investments, are carried at estimated fair value
which was $66 million and $84 million at December 31, 1996 and 1995,
respectively.
The following estimates of the fair value of financial
instruments have been made using available market information and
other valuation methodologies. However, the use of different market
assumptions or methods of valuation could result in different
estimated fair values.

FERC FORM N0.1

(ED. 12-96)

Page 123.20

Next Page is 200

 ,......

Name of Respondent
This Report Is:
Date of Report Year of Report
Florida Power & Light Comp ( 1) [X] An Original
(Mo, Da, Yr)
any
(2) [ ]A Resubmission
Dec. 31, 1996
NOTES TO FINANCIAL STATEMENTS

(Continued)

December 31,
1996
Carrying
Amount

1995

Estimated
Fair
Value(l)

Carrying
Amount

Estimated
Fair
Value(l)

(Thousands of Dollars)
Preferred stock of FPL with
sinking fund requirements (2) ............... .
Long-term debt
of FPL (2) .............. .
Long-term debt of
FPL Group (2) ........... .

$

46,000

$

46,979

$

54,000

$

55,520

$2,981,301

$3,001,265

$3,194,050

$3,285,925

$3,294,913

$3,318,588

$3,484,515

$3,588,835

(1) Based on quoted market prices for these or similar issues.
(2) Includes current maturities.
Special Use Funds - Securities held in the special use funds are
carried at estimated fair value. Approximately two-thirds of the
nuclear decommissioning fund consists of municipal and corporate debt
securities with a weighted-average maturity of 9 years.
The
remaining balance consists of equity securities. The storm fund
primarily consists of municipal debt securities with a
weighted-average maturity of 5 years.
The cost of securities sold 1s
determined on the specific identification method.
The funds had
realized gains of $8 million and realized losses of $9 million in
1996, $13 million and $4 million in 1995 and $6 million and $8
million in 1994, respectively.
The funds had unrealized gains of $55
million and $33 million at December 31, 1996 and 1995, respectively;
there were no significant unrealized losses at those periods. The
proceeds from the sale of securities in 1996, 1995 and 1994 were
$1.05 billion, $950 million and $650 million, respectively. A shift
in the asset mix of the decommissioning fund occurred in recent years
due to certain tax law changes.

FERC FORM N0.1

(ED. 12-96)

Page 123.21

Next Page is 200

 Date of Report Year o f Report
Name of Respondent
This Report Is:
(Mo, Da, Yr )
Florida Power & Light Comp ( 1 ) [X] An Original
any
( 2) [ ] A Resubmission
Dec. 3 1, 1 996
NOTES TO FINANCIAL STATEMENTS
8.

(Continued )

Income Taxes

The components of income taxes are as follows:
FPL Group

FPL

Years Ended December 31,
1996

1994

1995

Years Ended December 31,
1996

1995

1994

(Thousands of Dollars)
Federal:
Current ....... .
Deferred ....... .
ITC - net ...... .

$355,091 $380,792 $203,407
(76,692) (78,467)
83,135
(31,442) (20,957) (21,205)
--------

Total
federal ...
State:
Current . . . . . . . . .
Deferred ...... .
Total state.

--------

--------

-- --- --- --------

--------

246,957

281,368

265,337

275,528

290,018

271,837

--------

--------

--------

--------

--------

--------

63,180
(16,275)

58,426
(11,200)

32,020
9,925

53,953
(447)

64,427
(7' 104)

46,152
4,446

--------

--------

--------

--------

--------

46,905

47,226

41,945

53,506

57,323

50,598

--------

--------

--------

329,034

347,341

322,435

Income taxes
charged to
operations-FPL ..
Credited to other
income (deductions)-FPL ..... .
Total income
taxes . . . . . . . . . .

$387,514 $395,480 $314,956
(80,662) (84,630) (22,125)
(31,324) (20,832) (20,994)

(7,448)
$293,862 $328,594 $307,282

(5,047)

--------

(3,026)

$321,586 $342,294 $319,409

======== ======== ========

FERC FORM N0.1

(ED. 12-96)

Page 123.22

Next Page is 2 0 0

 Name of Respondent
This Report Is:
Date of Report Year of Report
Florida Power & Light Camp (1) [X]An Original
(Mo, Da, Yr)
any
(2) [ ]A Resubmission
Dec. 31, 1996
NOTES TO FINANCIAL STATEMENTS

(Continued)

A reconciliation between the effective income tax rates and the
applicable statutory rates is as follows:
FPL Group

FPL

Years Ended
December 31,
1996

,.....

Statutory federal income
tax rate... . . . . . . . . . . . . . . . . . . . . . . . 35.0%
Increases (reductions) resulting from:
State income taxes - net of
federal income tax benefit ... .
3.5
(3 6)
Amortization of ITC . . . . . . . . . . . . .
Preferred stock dividends-FPL .. .
1.0
(2 3)
Other - net . . . . . . . . . . . . . . . . . . . . .
0

0

Effective income tax rate .........

FERC FORM N0.1

(ED. 1 2-96)

33.6%

Years Ended
December 31,

1995

1994

1996

1995

1994

35.0%

35.0%

35.0%

35.0%

35.0%

3.5
( 2 4)
1.7
5)

3.3
(2 6)
1.7
2)

3.7
(3 3)

3.9
(2 2)

3.7
(2 4)

0

0

0

0

-

0

-

( 1 1)

-

3)

----

----

----

8)
----

37.3%

37.2%

34.3%

35.9%

36.0%

----

----

----

----

----

(

Page 123.23

0

(

0

0

(

0

(

0

----

Next Page i s 200

 Name of Respondent
This Report Is:
Date of Report Year of Report
Florida Power & Light Comp (1) [X]An Original
(Mo, Da, Yr )
Dec. 31, 1996
any
( 2) [ ] A Resubmission
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 Group
December 31,
1996

1995

FPL
December 31,
1996

1995

(Thousands of Dollars)
Deferred tax liabilities:
Property-related .......... .
Investment-related ........ .
Unamortized debt reacquisition costs and other ...
Total deferred tax
liabilities ........... .
Deferred tax assets and
valuation allowance:
Asset writedowns and
capital loss
carryforward ............ .
Unamortized ITC and deferred regulatory
credit - income taxes ....
Storm and decommissioning
reserves . . . . . . . . . . . . . . . . .
Other . . . . . . . . . . . . . . . . . . . . . .
Valuation allowance ....... .
Net deferred tax assets ..
Accumulated deferred income
taxes . . . . . . . . . . . . . . . . . . . . . . . .

$1,707,705 $1,704,643
384,023
371,298

$1,676,497 $1,670,242

342,274

222,279

188,499

145,180

2,434,002

2,298,220

1,864,996

1,815,422

154,864

263,149

-

146,825

164,451

146,825

164,451

200,890
289,885
(207,604)

223,694
347,797

200,890
245,766

-

-

223,694
442,151
(64,070)
---------903,464

-

----------

710,771
----------

---------- ---------718,316
611,107
---------- ----------

$1,530,538 $1,587,449

$1,146,680 $1,204,315

========== ==========

========== ==========

----------

Certain deferred tax assets and the related valuation allowance
decreased during 1996. These accounts primarily relate to a capital loss
carryforward from the disposition of an FPL Group Capital subsidiary in a
prior year.
The amount of the deductible loss from this disposition was
limited by Internal Revenue Service (IRS) rules.
The carryforward period
expired at the end of 1996.
FPL Group is challenging the IRS loss
limitations and the IRS 1s disputing certain positions taken by FPL
Group.
Tax benefits, if any, associated with these matters will be
reported in future periods when resolved.

FERC FORM N0.1 (ED. 12-96)

Page 123.24

Next Page is 200

 Name of Respondent
This Repo r t Is:
Date o f Report Year o f Re p ort
(Mo ,Da, Yr )
Fl o rida Power & Light Comp (1 ) [X] An Or igi n al
any
(2 ) [ ] A Resubmi ssion
De c. 3 1, 1996
NOTES TO FINANCIAL STATEMENTS
9.

(Cont i nued )

Commitments and Contingencies

Comn itments - FPL has made commitments in connection with a portion
of its projected capital expenditures.
Capital expenditures for the
construction or acquisition of additional facilities and equipment to meet
customer demand are estimated to be approximately $1.6 billion for
1997 through 1999 .
Included in this three-year forecast are capital
expend i tures for 1997 of approximately $590 million.
FPL Group Capital
and i t s subsidiaries, primarily ESI Energy, Inc., have guaranteed
approximately $120 million of lease obligations, debt service payments
and other payments subject to certain contingencies.
I nsurance - Liability for accidents at nuclear power plants is governed by
the Price-Anderson Act, which limits the liability of nuclear reactor
owners to the amount of the lnsurance available from private sources
and under an industry retrospective payment plan.
In accordance with
this Act, FPL maintains $200 million of private liability insurance, which
is the maximum obtainable, and participates ln a secondary financial
protection system under which it is subject to retrospective assessments
of up to $327 million per incident at any nuclear utility reactor in the
United States, payable at a rate not to exceed $40 million per incident
per year.
FPL participates in nuclear insurance mutual companies that provide
$2.75 billion of limited insurance coverage for property damage,
decontamination and premature decommissioning risks at its nuclear
plants.
The proceeds from such insurance, however, must first be used
for reactor stabilization and site decontamination before they can be
used for plant repair.
FPL also participates in an insurance program that
provides limited coverage for replacement power costs if a plant is out of
service because of an accident.
In the event of an accident at one of
FPL's or another participating insured's nuclear plants, FPL could be
assessed up to $70 million in retrospective premiums.
FPL also participates in a program that provides $200 million of tort
liability coverage for nuclear worker claims.
In the event of a tort claim
by an FPL or another insured's nuclear worker, FPL could be assessed
up to $12 million in retrospective premiums per incident.
In the event of a catastrophic loss at one of FPL's nuclear plants, the
amount of insurance available may not be adequate to cover property
damage and other expenses incurred. Uninsured losses, to the extent
not recovered through rates, would be borne by FPL and could have a
ma t e ria l adverse effect on FPL Group's and FPL's financial condition.
FPL sel f -insures certain of its transmission and distribution (T&D )
property due to the high cost and limited coverage available from
third-party insurers.
FPL maintains a funded storm and property
FERC FORM N0 . 1 (ED . 12-96)

Page 123 . 2 5

Ne xt Page is 20 0

 Name of Respondent
This Report Is:
Date of Report Year o f Report
Florida Power & Light Comp ( 1 ) [X] An Original
(Mo, Da, Yr )
any
(2) [ ]A Resubmission
Dec . 31, 1 996
(Continued )

NOTES TO FINANCIAL STATEMENTS

insurance reserve, which totaled approximately $223 million at
December 31, 1996, for T&D property storm damage or assessments
under the nuclear insurance program.
Recovery from customers of any
losses in excess of the storm and property insurance reserve will require
the approval of the FPSC.
FPL's available lines of credit include $300
million to provide additional liquidity in the event of a T&D property loss.
Contracts - FPL has entered into certain long-term purchased power and
fuel contracts. Take-or-pay purchased power contracts with the
Jacksonville Electric Authority (JEA) and with subsidiaries of the
Southern Company (Southern Companies) provide approximately 1,300
megawatts (mw) of power through mid-2010 and 374 mw through 2022.
FPL also has various firm pay-for-performance contracts to purchase
approximately 1,000 mw from certain cogenerators and small power
producers (qualifying facilities) with expiration dates ranging from 2002
through 2026.
The purchased power contracts provide for capacity and
energy payments.
Energy payments are based on the actual power
taken under these contracts.
Capacity payments for the
pay-for-performance contracts are subject to the qualifying facilities
meeting certain contract conditions.
The fuel contracts provide for the
transportation and supply of natural gas and coal and the supply and
use of Orimulsion.
Orimulsion is a new fuel which FPL expected to
begin using in 1998. The contract and related use of this fuel lS subject
to regulatory approvals.
In 1996, Florida's Power Plant Siting Board
denied FPL's request to burn Orimulsion at the Manatee power plant.
FPL has appealed the denial to the First District Court of Appeal of the
State of Florida.
The required capacity and minimum payments through 2001 under these
contracts are estimated to be as follows:
1997

1998

1999

2000

2001

----

----

----

----

----

(Millions of Dollars)
Capacity payments:
JEA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Southern Companies . . . . . . . . . . . . . . . . . . . . . . .
Qualifying facilities . . . . . . . . . . . . . . . . . . . .
Minimum payments, at projected prices:
Natural gas, including transportation ....
Orimulsion ( 1) .... . . . . . . . . . . . . . . . ...... . .
Coal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

.
.
.

$ 80
$130
$330

$ 80
$130
$340

$ 80
$120
$350

$ 80
$130
$360

$ 90
$130
$370

.
.
.

$210

$200

-

-

$ 50

$ 50

$210
$140
$ 40

$210
$140
$ 40

$210
$140
$ 30

(1) All of FPL's Orimulsion-related contract obligations are subject to
obtaining the required regulatory approvals.

FERC FORM N0.1

(ED. 12-96)

Page 123.26

Next Page i s 2 0 0

 Name of Respondent
This Report Is:
Date of Report Year of Report
Florida Power & Light Comp ( 1) [X] An Original
(Mo, Da, Yr )
any
(2) [ ]A Resubmission
Dec. 31, 1996
NOTES TO FINANCIAL STATEMENTS

(Continued)

Capacity, energy and fuel charges under these contracts were as
follows:
1996 Charges

1995 Charges

1994 Charges

Energy/
Capacity Fuel(l)

Energy/
Capacity Fuel(l)

Energy/
Capacity Fuel(l)

(Millions of Dollars)

,.....

JEA . . . . . . . . . . . . . . . . . . . .
Southern Companies .... .
Qualifying facilities ..
Natural gas ............
Coal . . . . . . . . . . . . . . . . . . .

$ 77 ( 2)
$115(3)
$279(3)
-

$ 49
$ 99
$125
$422
$ 49

$ 83 (2)
$130(3)
$158(3)
-

$ 47
$ 94
$ 92
$361
$ 37

$ 82 (2)
$186(3)
$137(3)
-

$ 48
$124
$ 68
$232
$ 33

(1) Recovered through the fuel clause.
(2) Recovered through base rates and the capacity cost recovery clause
(capacity clause) .
(3) Recovered through the capacity clause.

,......

,....

Litigation - The Florida Municipal Power Agency (FMPA), an organization
comprised of municipal electric utilities, has sued FPL for allegedly
breaching a "contract" to provide transmission service to the FMPA and
its members and for breaching antitrust laws by monopolizing or
attempting to monopolize the provision, coordination and transmission of
electric power in refusing to provide transmission service, or to permit
the FMPA to invest in and use FPL's transmission system, on the
FMPA's proposed terms.
The FMPA seeks $140 million in damages,
before trebling for the antitrust claim, and court orders requiring FPL to
permit the FMPA to invest in and use FPL's transmission system on
"reasonable terms and conditions" and on a basis equal to FPL.
In
1995, the Court of Appeals vacated the District Court's summary
judgment in favor of FPL and remanded the matter to the District Court
for further proceedings.
In 1996, the District Court ordered the FMPA to
seek a declaratory ruling from the FERC regarding certain issues in the
case. All other action in the case has been stayed pending the PERC's
ruling.
A former cable installation contractor for Telesat Cablevision, Inc.
(Telesat), a wholly-owned subsidiary of FPL Group Capital, sued FPL
Group, FPL Group Capital and Telesat for breach of contract, fraud,
violation of racketeering statutes and several other claims.
The trial
court entered a judgment in favo r o f FPL Group and Telesat on nine of
twelve counts, including all of the racketeering and fraud claims, and in
favor of FPL Group Capital on all counts.
It also denied all parties'
claims for attorneys' fees.
However, the jury in the case awarded the
FERC FORM N0.1 (ED. 12-96)

Page 123.27

Next Page is 2 0 0

 Date of Report Year o f Report
Name of Respondent
This Report Is:
(Mo,Da,Yr)
Florida Power & Light Comp (1) [X)An Original
Dec. 31, 19 96
any
(2) [ ]A Resubmission
NOTES TO FINANCIAL STATEMENTS

(Continued)

contractor damages totaling approximately $6 million against FPL Group
and Telesat for breach of contract and tortious interference. All parties
have appealed.
FPL Group and FPL believe that they have meritorious defenses to the
litigation described above and are vigorously defending these suits.
Accordingly, the liabilities, if any, arising from these proceedings are
not anticipated to have a material adverse effect on their financial
statements.
10. Summarized Financial Information of FPL Group Capital
(Unaudited)
FPL Group Capital's debentures are guaranteed by FPL Group.
Operating revenues of FPL Group Capital for the three years ended
December 31, 1996, 1995 and 1994 were $50 million, $62 million and
$80 million, respectively.
For the same periods, operating expenses
were $65 million, $77 million and $84 million, respectively. Net income
for 1996, 1995 and 1994 was $11 million, $2 million and $7 million,
respectively.
At December 31, 1996, FPL Group Capital had $144 million of current
assets, $857 million of noncurrent assets, $182 million of current
liabilities and $595 million of noncurrent liabilities. At December 31,
1995, FPL Group Capital had current assets of $89 million, noncurrent
assets of $934 million, current liabilities of $24 million and noncurrent
liabilities of $787 million.
11.

Quarterly Data (Unaudited)

Condensed consolidated quarterly financial information for 1996 and
1995 is as follows:

FERC FORM N0.1 (ED. 12-96)

Page 123.28

Next Page is 200

 Date of Report Year o f Repo rt
Name of Respondent
This Report Is:
(Mo , Da, Yr )
Florida Power & Light Comp ( 1 ) [X] An Or i ginal
De c. 31 , 1 996
any
( 2 ) [ ]A Resubmissi o n
NOTES TO FINANCIAL STATEMENTS
March 31 (1)

June 30

(1)

(Continued )

September 30

(1 ) December 31

(1 )

(In thousands, except per share amounts)
r-

FPL Group:
1996
-----------Operating
revenues ... $ 1,357,707
Operating
223,374
income ..... $
93,712
Net income .. $
Earnings per
share ...... $
0.54
Dividends per
share ...... $
0.46
High-low
trading
prices ..... $48 - 42 1/8

$

1,474,086 $

1,769,599 $

1,435,386

$
$

299,288 $
150,313 $

459,133 $
250,116 $

189,026
85,309

$

0.86 $

1.44 $

0.49

$

0.46 $

0.46 $

0.46

$46 1/4 - 41 1/2 $46 5/8 - 42 5/8 $48 1/8 - 43 1/8

1995
Operating
revenues ...
Operating
income .....
Net income ..
Earnings per
share ..... .
Dividends
per share ..
High-low
trading
prices .....

$

1,177,366 $

1,466,724 $

1,587,037 $

1,361,358

$
$

248,797 $
99,840 $

312,191 $
138,302 $

447,935 $
240,449 $

188,183
74,720

$

0.57 $

0.79 $

1.37 $

0.43

$

0.44 $

0.44 $

0.44 $

0.44

$37 1/4 - 34 $39 1/4 - 36 1/8 $

41 1/8

-

37 $46 1/2 - 40 1/4

'

FERC FORM N0.1

(ED. 12-9 6)

Pa g e 1 23.29

Next

P a~e

i s 2 00

 Name of Respondent
This Report Is:
Date of Report Year of Report
(Mo ,Da,Yr )
Florida Power & Light Comp ( 1 ) [X] An Original
any
( 2 ) [ ] A Resubmission
Dec. 31 , 1996
NOTES TO FINANCIAL STATEMENTS
March 31 (1)

June 30 (1)

(Continued )

September 30

(1 ) December 31 (1 )

(In thousands, except per share amounts )
FPL:
1996
Operating
revenues ... $
Operating
income ..... $
Net income .. $
Net income
available to
FPL Group .. $

1,340,742 $

1,454,997 $

1,760,939 $

1,429,750

166,805 $
107,153 $

218,757 $
158,357 $

316,926 $
253,027 $

156,293
96,357

100,719 $

152,591 $

247,260 $

90,592

1,156,269 $

1,446,203 $

1,579,549 $

1,348,036

185,616 $
119,442 $

219,554 $
153,804 $

306,782 $
245,747 $

153,354
92,381

144,765 $

236,757 $

79,161

1995
Operating
revenues . .. $
Operating
income ..... $
Net income .. $
Net income
available to
FPL Group .. $
(1)

In the opinion of FPL Group and FPL, all adjustments, which consist of
normal recurring accruals necessary to present a fair statement of such
amounts for such periods, have been made.
Results of operations for an
interim period may not give a true indication of results for the
calendar year.
The change in the method of accounting for the cost of
nuclear refueling outages described in Note 1 did not have a material
effect on the operating results of any quarter.

============================================================================
The preceding "NOTES TO CONSOLIDATED FINANCIAL STATEMENTS" appear in Florida
Power & Light Company's Annual Report on Form 10-K for the fiscal year ended
December 31, 1996. The notes fulfill the requirements of item 6 on page 122.
The accompanying Consolidated Financial Statements on pages 110 through 121
conform with the requirements of the FERC Form 1 which differ ln some
respects from those presented in the Company's Annual Report on Form 10 -K.

FERC FORM N0.1 (ED. 12-96)

Page 123.30

Next Page is 200

 Name of Respondent
This Report Is:
Date c~ Report Year of Report
Florida Power & Light Comp (1) [X]An Original
(Mo,Da,Yr)
any
(2) [ ]A Resubmission
Dec. 31, 1996
NOTES TO FINANCIAL STATEMENTS

(Continued)

In accordance with the Commission's Order in Docket No. RM93-18-000 the
following information concerning special assessments levied under the Atomic
Energy Act to establish a fund for the decontamination and decommissioning
of the Department of Energy's uranium enrichment plants is provided:
(1)

Expenses associated with special assessments recorded in account
518 during 1996 totaled $5,274,155.

(2)

Payments associated with special assessments made during 1996
totaled $5,258,733.

(3)

No refunds of special assessments were received during 1996.

FERC FORM N0.1

(ED. 12-96 )

Page 123.31

Next Paoe

s 20 0

 of Respondent
Flor i da Power & L1ght Company

N~me

(b)

(a)

TOTAL Accumvlated _ Provi~ions <Should agree with line 14 above)
(Enter Total of l1nes 2l,26,30,31 and 32)

FERC FORM N0.1 (ED. 12-89)

Year of Repo r t
Dec. 31, 1996

Total

Item

Li ne
No .

33

Date of Report
This Report I$:.
(Mo, Da, Yt)
(1) [XJ An Or1g1nal
(2) [ A Resuemission
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS
FOR DEPRECIATION, AMORTIZATION AND DEPLETION

Page 200

$7,610,785,812 *

Electric
(c)

$7,610,785,812

 Date of Report
Thi s Report Is: .
(Mo, Da, Yr)
(1) [XJ An Or1g1nal
(2) [ A Resuemission
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS
FOR DEPRECIATION . AMORTIZATION AND DEPLETION
Other( Specify)
Other( Specify)
Other( Specify)

of Respondent
Florida Power & L1ght Company

N~me

Gas

Year of Report
Dec. 31, 1996

Common

Line
No.

33

FERC FORM N0 . 1 (ED. 12-89)

Page 201

 <

Page 200 Line 14 Column c

>

Includes nuclear decommissioning reserve and earnings on the
nuclear decommissioning fund of $805,159,735.

<

Page 200 Line 33 Column c >

See note on line 14.

Page 200-201 Footnote.1

 Year of Report
Dec. 31, 1996

of Respondent
Florida Power & L1ght Company

N~me

1. Report below the costs
for nuclear fuel materials in process of
fabrication, on hand, in reactor, and in
cooling; owned by the respondent.
Line
No.

tained under leasing arrangements, attach a statement showing the amount of
nuclear fuel leased, the quantity used

quantity on hand, and the costs
incurred under such leasing arrangements.

Description of item

Balance
Beginning of Year

Additions

(a)

(b)

(c)

Nuclear fuel in process of Refinement,
Convers1on, Enr1chment & Fabr1cat1on (120.1)

~Lefs> Ace~.

Prov_ for A~~rt~zation of
uc ear Fue Assembl1es ( 0. )

14
15
16
17

TOTAL
<Entyr1neTof~l)
1nes ~uc\aar
,
, 11Fuel
, andSt~~k less
Estimate? net ~<Jlva~e Value of Nuclear
Mater1a s 1n 1ne
Estimate? net ~~(,~a~l Value of Nuclear
Mater1a s 1n
Estimate? net Salv<Jge Value of Nuclear
Mater1a s 1n Chem1cal Processing

$179,100,119

TOTAL Nucle~r Materials held for Sale
Enter Total of l1nes 19, 20, and 21

FERC FORM N0.1 (ED. 12-89)

Page 202

 Year of Report
Dec. 31, 1996

Name of Respondent
Florida Power & L1ght Company

Amortization

(Explain in a footnote)

Line
No.

Balance
End of Year
. (f)

(e)

0

$182,162,630

14

15

16
17

FERC FORM N0.1 (ED. 12-89)

Page 203

 <

Page 202 Line 3 Column c

>

Transfer from Account 120.2

<

Page 203 Line 3 Column e

>

Sale to FPL Fuels, Inc.

<

Page 203 Line 8 Column e

>

Transfer to Account 120.1

<

Page 203 Line 12 Column f

>

The Respondent has a nuclear fuel leasing arrangement for
the St. Lucie and Turkey Point nuclear units:
Nuclear Fuel Leased
Nuclear Fuel Used
Nuclear Fuel on Hand
Costs Incurred

$182,162,630
$ 83,353,127
$182,162,630
$ 86,433,876

Page 202-203 Footnote.1

 Year of Report
Dec . 31, 1996

N9me of Respondent
Florida Power & L1ght Company
1. Report below the original cost of electric plant in service according to the prescribed accounts.
2. In addition to Account 101, Electric Plant in Service
Classified ), this page and the next include Account 102,
Electric Plant Purchased or Sold; Account 103, Experimental
Electric Plant Unclassified; and Account 106, Completed
Construction Not Classified-Electric.
3. Include in column (c) or (d), as appropriate, corrections
of additions and retirements for the current or preceding year.
4. Enclose in parentheses credit
adjustments of plant
accounts to indicate the negative effect of such accounts.
5. Classify Account 106 according to
prescribed ac-

FE RC FORM NO.1 (REV. 12-95)

counts,
on an estimated basis if necessary, and include the
entries in column (c). Also to be included in column (c)
are
entries for reversals of tentative distributions of prior
year reported in column (b). Likewise, if the respondent has
a significant amount of plant retirements which have not
been classified to primary accounts at the end of the year,
include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra
entry to the account for accumulated depreciation provision.
Include also in column(d) reversals of tentative distributions
of prior year of unclassified retirements. Show in a
footnote the account distributions of these tentative
classifications in columns (c) and (d), including the

Page 204

 Year 0 1 RP.port
Dec. 31 1996

of Respondent
Florida Power & L1ght Company

N~me

-- -------~

reversals of the pr i or years tentative account distributions of
these amounts. Careful observance of the above instructions
and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent's plant actually
in service at end of year.
6. Show i n column (f) reclassifications or transfers within
utility plant accounts. Include also in column(f) the additions
or reductions of primary account classifications ar1s1ng from
distribution of amounts initially recorded in Account 102. In
showing the clearance of Account 102, include in column (e)
the amounts with respect to
accumulated
provision
for
depreciation, acquisition adjustments, etc., and show in colAdjustments
(e)

FE Rt FORM N0.1 ( ED. 12 -88)

umn (f) only the offset to the deb i t s or credit s d is~rlDUted in
column (f) to primary account classifications.
7. For Account 399,state the nature and use of plant included
in this account and if substantial in amount submit a supple such
mentary statement showing subaccount classificati o ~
plant conforming to the requirements of these pages.
8. For each amount compr1s1ng the reported balance and
changes in Account 102, state the property purchased or sold,
name of vendor or purchaser, and date of transaction. If proposed journal entries have been filed with the Commission
as required by the Uniform System of Accounts, give also
date of such filing.
Transfers
(f)

Page 205

Balance at
End of Year
(g)

 of Respondent
Florida Power & L1ght Company

N~me

Yea r of Report
Dec. 31 , 1996

line
No.

Additions
(c)

FERC FORM NO.1 (ED . 12-94)

Page 206

 Year of Report
Dec. 31, 1996

of Respondent
Florida Power & L1ght Company

N~me

Retirements
(d)

FERC FORM N0.1 (ED. 12-88)

Adjustments
(e)

Tran!>fers
(f)

Page 207

Bqlal')ce at
End of year
(g)

Line
No .

NeAt Pagt i s

2~3

 N9me of Respondent
Florida Power & L1ght Company

I

t~~s[~elp~~to~r~inal
(2) [

A Resu~ission

I

Date of Re~ort
(Mo, Da, Y )

Year of Report
Dec. 31, 1996

ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
future use, give in column (a), in addition to other required
1. Report separately each property held for future use at
information, the date that utility use of such property was
end of the year having an original cost of $250,000 or more.
discontinued, and the date the original cost was transferred
Group other items of property held for future use.
2. For property having an original cost of $ 250,000 or
to Account 105.
more previously used in utility operations, now held for
Descri~tion and Location
Date Expected
Date oriainally
Bala~ce at
ot Property
En of
Line
to ~e Used 1n
IRclude in
(a}
Uti 1ty Service
No.
T 1s ~ccount
Ye~r
(

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

Land and Rights:
DeSoto Plant Site
* South Dade Plant Site
General Office - Additional Property
Central Service Center (Relocation)
Overtown Substation Site
Arch Creek Substation Site
Conservation Substation Site
Alexander Substation Site
Challenger Substation Site
Chester Substation Site
Cullum Substation Site
Eureka Substation Site
Fulford Substation Site
Windover Substation Site
Hampton Substation Site
Jennings Substation Site
O'Neil Substation Site
Rinker Substation Site
Rolf Substation Site
Other Property:

)

09/30/1974
02/29/1972
03/31/1974
12/31/1989
02/28/1987
12/31/1993
03/31!1989
11/30/1989
11/30/1994
01/31/1994
11/30/1991
03/31/1989
01/31/1994
02/28/1990
04/30!1990
04/30/1994
04/30/1990
03/31/1994
04/30/1994

(C)

12/31/2010
12/31/1999
12/31/1998
12/31/2001
06/30/2002
06/30/2001
02/28/1997
02/28/1997
06/30/2002
12/31/2008
06/30/1997
06/30/1999
12/31/2000
11/30/1997
06/30/2005
06!30!2002
06/30/1998
06/30/1999
06/30/1998

(

)

$9,566,898
11,872,653
524,013
5,152,179
705.182
682,809
1,686, 738
1,452,293
251,661
374,695
1,057,877
715,636
300,063
1,299,435
300,810
761,721
417,392
601,808
506,527

44

45
46

~4~7TO_TfJA_
L----------------~~--------------.rr========~
_
FERC FORM N0.1 (ED. 12-89)

Page 214

Next Page is 216

 N9me of Respondent
Florida Power & L1ght Company

I

t~~s[~elp~~t 0 ~~~inal
(2) [

A Resuemission

I

Date of Re~ort
(Mo, Da, y )

Year of Report
Dec. 31, 1996

ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
future use, give in column (a), in addition to other required
1. Report separately each property held for future use at
information, the date that utility use of such property was
end of the year having an original cost of $250,000 or more.
discontinued, and the date the original cost was transferred
Group other items of property held for future use.
2. For property having an original cost of $ 250,000 or
to Account 105.
more previously used in utility operations, now held for
DescriRtion and Location
Date Expected
Date Originally
Bal~ce at
ot Property
E of
Line
Includea in
to ~ Used 1n
(a)
Uti 1ty Service
No.
Th1s Account
Ye~r
( )
(b)
(c)
1 Land and Rights:
$317,180
2 Notre Dame II Substation Site
06/30/2004
08/31/1984
478,506
3
Sistrunk Substation Site (Expansion)
12/31/1994
06/30/1999
01/31/1984
06/30/2001
276,589
4 Apollo Substation Site
06/30/2005
354,747
08/31/1994
5 Steeplechase Substation Site
507,373
6
Terminal Substation Site
08/31/1994
06/30/2001
528,672
02/28/1994
06/30/1999
7 Vanderbilt Substation Site
366,741
8
Woods Substation Site
04/30/1994
06/30/2000
9 DeSoto-Orange River Right-of-Way
07/31/1978
06/30/2006
900,792
363,908
10
Rotonda-Myaka Right-of-Way
10!31!1979
02!28!2001
851.985
11
Rima 240 KV Site
10!31!1988
12!31!2010
2,654,400
12
Turkey Point-Levee Right-of-Way
11/30/1976
12/31/2006
13
Coconut Grove-Olympia Heights Right-of-Way
1,046,840
08/31/1994
12/31/2004
14
Edgewater-Scottsmoor Right-of-Way
06/30/2000
585.188
11/30/1994
341,829
15
Notre Dame-Punta Gorda Right-of-Way
06/30/2003
04/30/1994
486,711
06/30/1998
12/31/1995
16
Portsaid Substation Site
06/30/2003
17 Celery-Geneva-Osteen 115KV Right-Of-Way
937,133
04/30/1995
18 Conservation-Levee 500KV Line
12!31!1999
5,475' 9(:: l
04/30/1995
377,051
19
Plaza Substation Site
06/30/2005
10/31/1988
1,838,657
06/30/2006
20
Manatee-Ringling Right-of-Way
06/30/1996
21
Other Property:
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45

...

-

F~~ -

"0RM

~J .

1 CEO. 12-89)

Page 214.1

Next Page is

 Year of Report
Date of Report
This Report Is:
(Mo, Da, Yr)
(1) [Xl An Or1ginal
Dec. 31, 1996
(2) [ A Resuomission
ELECTRIC PLANT HELD FOR FUTURE USE (Account 1D5)
1. Report separately each property held for future use at
future use, give in column (a), in addition to other required
end of the year having an original cost of $250,000 or more.
information, the date that utility use of such property was
Group other items of property held for future use.
discontinued, and the date the original cost was transferred
2. For property having an original cost of $ 250,000 or
to Account 105.
more previously used in utility operations, now held for
DescriQtion and Location
Balance at
Date Expected
Date Ori§inally
ot Property
Line
End of
!~elude
in
to ~e Used 1n
(a)
No.
Uti 1ty Service
Ye~r
T 1s ~ccount
( )
(d)
(c)
1 Land and Rights:
2 Coast Substation Site
06/30/1996
$1,327,188
12!31!2010
3
Flamingo Substation Site
12/31/1995
10!31!1997
695' 191
4 Hammock Substation Site
11!30!1991
12/31/1999
553,042
5 Levee Substation Site
06/30/2004
01/31/1996
789,030
6
Items with Balances Under $250,000:
7 Power Plant Sites
147,788
8 General Plant Sites
119,970
9 Substation Sites
3,018,464
633,071
10
Transmission Rights-of-Way
of Respondent
Florida Power & L1ght Company

N~me

I

I

,,

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
47

Other Property:
* Riviera Plant - Unit #2

12/31/1991

4,204,526

$68,408,943

TOTAL

FERC FORM N0.1 (ED. 12-89)

12/31/1997

Page 214.2

Next Page is 216

 <

Page 214 Line 3 Column a

>

Additional property of $3,351,359 was transferred from Account
101 - Electric Plant In Service, to Account 105 - Electric Plant
Held for Future Use, in February 1996.

<

Page 214.2 Line 22 Column a

>

Property was transferred from Account 101 - Electric Plant In
Service, to Account 105 - Electric Plant Held For Future Use,
in December 1991.

Page 214 Footnote.1

 mfXl AAnResu
Or15ri,nal
ission
IIN PROGRESS--ELECTRIC
I
(Account 107)
This Report Is: .

Nfme of Respongent
F orida Power
L1ght Company

CONSTRUCTION IIORK
1. Report below descriptions and balances at end of year
of projects in process of construction (107).
2. Show items relating to "research, development, and
demonstration" projects last, under a caption Research,
Description of Project

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
35
36
37
38
39
40
41
42
43

(a)

Date of Re~ort
(Mo, Da, Y )

I

Year of Report
Dec. 31, 1996

Development, and Demonstration ( see Account 107 of the
Uniform System of Accounts).
3. Minor projects (5% of the Balance End of the Year fo r
Account 107 or $100,000, whichever is less) may be grouped.
Construction llork
in Progress-Ele~tric
(Account 1Of)
(b)

INTANGIBLE PLANT
Development and Implementation of Cash Management Module
Financial Accounting On-Line Inquiry System
Power Billing System
Messaging Foundation Deployment Project Development - Lotus Notes
Foundation Infrastructure to Provide Software, Print and File Server Management
Services and Products - System Infrastructure Development
Call Centers System Development
Infrastructure for Information Storehouse to Support Distributed Processing
Build Information Storehouse
PRODUCTION PLANT
MANATEE - Convert Plant to Orimulsion
MARTIN - Low Pressure Turbine Rotor Replacements Unit #2
PT. EVERGLADES - 400MII Turbine Modification Unit #4
ST. LUCIE UNIT #1 - Preliminary Engineering for Steam Generator Replacement
- Procure Two New Steam Generators
- Replace Drawer in Reactor Protection System
- Upgrade of Incore Instrumentation Flange/Incore Detector
ST. LUCIE UNIT #2- Upgrade of Incore Instrumentation Flange/Incore Detector
ST. LUCIE COMMON - Improvements to the North Service Building
TURKEY POINT UNIT #3 - Replacement of High Pressure Turbine Ring

2,204,054
1,478,374
3,274,712
1,838,888
2, 928,213
1,213,434
1,683,547
1,277, 710
1,644,365

19,294,621
6,186,575
4,176,517
15,632,891
51,165,701
1,657,089
1,242,715
1,547,736
1,017,916
1, 722,292

TRANSMISSION PLANT
Brevard - Rockledge Transmission Line; Acquire Right-Of-llay
Cape Norris-Barna Phase II; Acquire Right-Of-llay
EauGallie-Malabar #2 Extension to llickham; Acquire Right-of-llay
Conservation; Construct 500-230KV Substation
Conservation Substation; Purchase One SOOKV Autotransformer
Indian Creek - Lemon City 138KV Line; Repair Lagorce Canal
Bass Creek-Pennsucco Transmission Line; Acquire Right-of-llay

1,728,020
1,376,459
2,143,886
3,591,254
2,047,502
1,348,929
1,700,684

GENERAL PLANT
Ft. Myers-Pompano; Install Fiber
Call Center System Hardware
llest Palm Central Service Center
Install Automated Teller Machine
Sonet-Ringling #1; Install Fiber

2,215,720
2,223,289
1,460,544
1,348,691
3,225,901

Optic
Improvements
Backbone Ring Network
Optic

*TOTAL PROJECTS IIITH BALANCES UNDER $1,000,000

74,538,429

$220,136,658

TOTAL

FERC FORM NO.1 (ED. 12-87)

Page 216

 <

Page 216 Line 40 Column a

>

A $1,000,000 reporting threshold was approved for FPL effective
with the 1993 reporting year by the Chief Accountant, Federal
Energy Regulatory Commission in a letter to the Company dated
September 24, 1993.

Page 216 Footnote.1

 Date of Report
Year of Report
This Report I~: .
(Mo, Da, Yl")
(1) [XJ An Or1g1nal
Dec. 31, 1996
(2) [ A Resuemission
CONSTRUCTION OVERHEADS-ELECTRIC
1. List in column (a) the kinds of overheads according to
lain on page 218 the accounting procedures, . employeo and the
the t1tles useo by tne respondent. Charges for outs1de proamounts .of eng1neer1ng, superv1s1on and adm1n1strat1ve costs,
fesslona\ serv1ces tor eng1neer1ng fees and management or
etc. wh1ch are dlrectry charged to construct1on.
supervis1on fees cap1tal1zed shoula be shown as separate items.
2. On page 218 furnish information concerning construction
4. Enter on this page engineering, supervision, adminisoverheads.
trative, and allowance for funds used during construction,
3. A respondent should not report "none" to the page if no
etc., which are first assigned to a blanket work order and
overhead apportionments are made, but rather should expthen prorated to construction jobs.
Tot;ll Amount
Line
Description of Overhead
Cha~ged
No .
for t e Year
of Respondent
Florida Power & L1ght Company

N~me

I

I

(a)

1 Engineering, Administrative & Construction
2 Engineering Charges for Specific Projects
3 Payroll Taxes and Insurance
4
Pension & Welfare (Funded)
5 Pension & Welfare (Unfunded)
Stores Expense Overhead
6
7 Workman's Compensation Allocation
8 Allowance for Funds Used During Construction:
9 Amount Credited to Interest Charges
10 Amount Credited to Other Income
11
12
13
14
15
16
NOTE:
17 Charges for outside professional services for engineering and management or supervision fees
18
capitalized are included on Lines 1, 2 and 6 above and are not shown as separate items as required
19
by instruction #1 since to do so would cause an undue reporting burden.
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
FER C FORM N0.1 (ED. 12-89)
Page 217

(

)

$80,178,362
321 '181
8,017,491
9,645,350
555,879
13,191,854
(117, 101)
816,911
1,089,231

$113,699,158

 of Respondent
Florida Power & L1ght Company

N~me

~~~s[~fp~~t 0 ~~~inal
(2) [ l A Resuemission

Date of Re~ort
(Mo, Da, Y )

Year of Report
Dec. 31, 1996

GENERAL DESCRIPTION OF CONSTRUCTION OVERHEAD PROCEDURE
overhead explain: (a) the nature
2. Show below the computation of allowance for fund s
and extent of work, etc. the overhead charges are intended
used during construction rates, in accordance with the
to cover, (b) the general procedure for determining the
provisions of Electric Plant Instructions 3(17) of the
amount capitalized, (c) the method of distribution to construc U.S. of A.
tion jobs, (d) whether different rates are applied to different
3. ~here a net-of - tax rate for borrowed funds is used,
types of construction,(e) basis of differentiation in rates for
show the appropriate tax effect adjustment to the computadifferent types of construction, and (f) whether the overhead
tions below in a manner that clearly indicates the amount
is directly or indirectly assigned.
of reduction in the gross rate for tax effects.
1. For each construction

* Engineering and Construction Overheads
(Allocation to Blanket Expenditure Requisitions)
a) Includes 1) time and expenses of company employees devoting a portion of their time to the design,
planning and supervision of construction jobs, and 2) fees paid engineering and/or construction companies,
consultants, etc. for services rendered in connection with design of construction jobs. These costs are
accumulated in a construction clearing account.
b) The amount capitalized is based on the ratio of overhead charges to construction expenditures.
c) Overhead rates are applied to construction expenditures through a work order system.
d) Separate rates are established for different types of construction to reflect the different
levels of construction expenditures and related overhead costs for these activities.
e) Overhead costs are recorded in separate clearing accounts; construction expenditures are accumulated
in individual work orders. The separation of costs and expenditures is made to provide
a basis for determining the different rates.
f) Overheads are indirectly assigned.

COMPUTATION OF ALLO~ANCE FOR FUNDS USED DURING CONSTRUCTION RATES
For line 1(5), column (d) below, enter the rate granted in the last rate proceeding. If such is not available, use the average
rate earned during the preceding three years.
1. Components of Formula (Derived from actual book balances and actual cost rates):
Capitalization
Amount
Ratlo(Percent)
(b)

2. Gross Rate for Borrowed Funds

s

S(-)
~

3. Rate for Other Funds
[ 1

+ d(

- ws l [ p<D+P+C> +
p

D
)(1
D+P+C

(c)

s

- -w'

c

6.14%

C(--)

D+P+C
4. ~eighted Average Rate Actually Used for the Year:
a. Rate for Borrowed Funds - 3.57"1.
b. Rate for Other Funds - 4.69%

FERC fO M NO.1 (ED. 12-88)

3. 17"1.

Page 218

 <

Page 218

>

Engineering and Construction Overheads (Continued )
(Allocation to Specific Expenditure Requisitions )
a)

b)
c)

d)
e)

f)

Includes 1) the actual time and expenses of company
employees involved in the design, planning and supervision
of specific construction jobs, and 2) fees paid engineering
and/or construction companies, consultants, etc. for
services rendered in connection with design of those
specific construction jobs.
These costs are accumulated ln
specific engineering orders and are later transferred to
the applicable work orders.
The amount capitalized is based on the ratio of overhead
charges to construction expenditures.
Overhead rates are applied to construction expenditures
through a work order system.
They are applied to all
primary accounts (construction) except for land.
No
engineering is applied to maintenance accounts.
Separate rates are established for different types of
construction to reflect the different levels of
construction expenditures and related overhead costs.
Overhead costs are recorded in separate clearing accounts;
construction expenditures are accumulated in individual
work orders. The separation of costs and expenditures is
made to provide a basis for determining the different
rates.
Overheads are directly assigned.

Stores Expense Overhead
a)
Includes 1) all payroll, vehicle, freight, transfer costs
and miscellaneous expenses associated with the operations
and maintenance of storeroom activities. Additionally,
all costs associated with managing, inventorying and
operating storerooms are captured in a clearing account;
and 2) a portion of Purchasing Department's payroll
associated with purchasing material & supplies, a portion
of Computer Operation's expense associated with the
Inventory Management System's reports, microfiche and other
related expenses are captured in this account.
These costs
are accumulated in undistributed stores expense (a clearing
account). Undistributed stores expenses are cleared out by
applying the overhead rate to the materials issued and
returned from/to the storeroom.
b)
The amount capitalized is based on the ratio of overhead
charges to material & supplies issued and returned during
the year.
c)
Overhead rates are applied to construction expenditures
through a work order system.
d-e)Substation Reserve Equipment delivered directly to a construction site and not directly handled by the storeroom
is applied a lesser rate than materials handled and
delivered from a storeroom.
f)
Overheads are indirectly assigned.

Page 218 Footnote.1

 Labor Overheads
a)
Includes payroll taxes, insurance, pension and welfare
expenses associated with payroll charged to construction
projects.
b)
The amount of overhead charges capitalized is based on the
ratio of construction payroll to total payroll.
c)
Overhead rates are applied to construction payroll through
a work order system.
d-e)The Company develops individual rates to capitalize: l)payroll taxes & insurance costs, and 2) pension & welfare expenses.
The individual rates are applied to all types
of construction payroll.
f)
Overheads are indirectly assigned.

Page 2 18 Footnote.2

 Year of Report
Dec. 31, 1996

of Respondent
Florida Power & L1ght Company

N~me

1. Explain

in

a

footnote

any important

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 (d), excluding retirements of nondepreciable 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.

amount of plant retired
at year end which has not been recorded and I 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.
4. Show separately interest credits under a sinking fund
or similar method of depreciation accounting.

Electric Pl;mt
Leased to Others
(e)

FERC FORM NO

(ED. 12-88)

Page 219

Next Page is 221

 <

Page 219 Line 7 Column c >

Includes the following:
SJRPP Coal Cars Depreciation, Account 501-Fuel Expense $2,186,493
Martin Pipeline Depreciation, Account 547-Fuel Expense 1,288,057
Decommissioning Earnings Accounts . . . . . . . . . . . . . . . . . . . 29,839,591
Decommissioning Fund SFAS 115 Accounts . . . . . . . . . . . . . . 24,449,000
Total Page 219, Line 7, Column (c)

<

$57,763,141

Page 219 Line 11 Column c >

Reconciliation of Book Cost of Plant Retired as required
by instruction #2:
Plant Retired - Page 219, Line 11, Column (c)
Book Cost of Amortizable Plant Retired

$154,644,207
43,691,281

Electric Plant in Service Retirements Page 207, Line 88, Column (d)

$198,335,488

<

Page 219 Line 15 Column c

>

Transfers.

Page 2 19 Footnote.1

 of Respondent
Florida Power & Light Company

N~me

I

I

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31, 1996

NONUTILITY PROPERTY (Account 121)
4. List separately all property previously devoted to
1. Give a brief description and state the location of nonpublic service and give date of transfer to Account 121,
utility property included in Account 121.
Nonutility Property.
2. Designate with a double asterisk any property which is
5. Minor Items ( 5% of the Balance at the End of the
leased to another company. State name of lessee and whether
Year), for Account 121 or $100,000, whichever is less)
lessee is an associated company.
may be grouped by (1) previously devoted to public ser3. Furnish particulars (details ) concerning sales, purchases, or transfers of Nonutility Property during the year.
vice(line 44), or(2) other nonutility property (line 45).
Balance at End
Balance of Beginning
Purchases, Sales,
Line
Description and Location
ot Year
Transfers, etc.
of Year
(a)
(b)
(C)
(d)
No.
1 PROPERTY PREVIOUSLY DEVOTED TO PUBLIC SERVICE
2 Dade County-Turkey Point Transmission Right-of-Way
3
(Transferred 1972)
451,553
451,553
4 Dade County-Miami Riverside Center (Transferred 1994)
13,982
( 13, 982)
0
*
5 Broward County-Andytown Switching Station
658,345
658,345
6
(Transferred 1995)
7 Manatee County-Bradenton U.S. 41 and Buckeye Road
414,462
414,462
8
(Transferred 1986)
9 Duval/Bradford Counties-Bradford-Duval #2 Right-of-Way
408,648
408,648
10
(Transferred 1992)
11
Volusia County-Bunnell-St Johns Right-of-Way
359,070
359,070
12
(Transferred 1992)
13
St Johns County-Bunnell-St Johns Right-of-Way
359,069
359,069
14
(Transferred 1992)
15
Martin County-Tequesta Sub Site (Transferred 1992)
116,288
116,288
16
Flagler County-Bunnell-Angela Right-of-Way
326,182
326,182
17
(Transferred 1992)
18
19
PROPERTY NOT PREVIOUSLY DEVOTED TO PUBLIC SERVICE
20
Dade County-Dade Davis Transmission Right-of-Way at
125,815
125,815
21
S. W. 104 St. and 127 Ave.
22
Dade County-Lot 4, Block 3, LeBlond Subdivision
179,381
179,381
23
Dade County-Vacant Land adjacent to Miami Central
600,450
0
*
600,450
24
Service Center
25
26
PROPERTY FOR NON-REGULATED ACTIVITES OF FPL ENERGY
27
SERVICES, INC. (located in the State of Florida)
28
* Energy Management Systems
323,679
323,679
29
Office Furniture & Equipment
111,894
0 *
111,894
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
Minor Item Previously Devoted to Public Service
233,256
780,500
1,013,756
*
45 I Mi nor Items-Other Nonutility Property
815,795
(700,402)
115,393
*
46
TOTAL
$4,785,525
$778,460
$5,563,985
FERC FORM NO.1 (ED. 12-95)
Page 221
Next Page 1s 224

 -

<

Page 221 Line 4 Column c

>

Additional expenses for sale of land, building and parking
garage.

<

Page 221 Line 23 Column c

>

Purchase of 1.047 acres.

<

Page 221 Line 28 Column a

>

Systems are leased to two companies: (1) Byron Hall, and
(2) VHS Realty/5600 Collins Bldg. These companies are
not associated companies of Florida Power & Light Company.

<

Page 221 Line 29 Column c >

,....
Purchase of office furniture and equipment.

<

Page 221 Line 44 Column c

>

During 1996, $700,402 of property previously reported on line 45"Minor Items-Other Nonutility Property" was reclassified to
"Minor Items-Previously Devoted to Public Service" (line 44).

<

Page 221 Line 45 Column c

>

See Footnote for line 44.

-

Page 221 Fc J t note.1

 of Respondent
Florida Power & L1ght Company

N~me

I

(~~s[~eJp~~to~T~inal
(2) [ A Resubmission

l

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31, 1996

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
separately
the
Report
(b) Investment
Advances
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.

1. Report below investments in Accounts 123.1, Investments in Subsidiary Companies.
2. Provide a subheading for each company and List
thereunder 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 .

Line
No.

Description of Investment

Date
Acqu1red

(a)

(b)

Date Qf
Matur1ty
(c)

Amount of Investment at
Beg1nn(~~ ot Year

1

2
3
4

5
6

7

FPL Services-General Partnership
Equity in Undistributed
Subsidiary Earnings

10/29/1993

(98,515)

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

!TOTAL Cost of Account 123.1

FERC FORM N0.1 (ED. 12-89)

$

0

Page 224

TOTAL

($98,5 15)

 I

I

Year of Report
This Report I$·
Date of Report
(1) [X] An Or1ginal
(Mo, Da, Yr)
Dec . 31, 1996
(2) [ l A ResuElmission
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)(Continued)
7. In column (h) report for each investment disposed
4. For any securities, notes, or accounts that were pledged,
of during the year, the gain or loss represented by
designate such securities, notes, or accounts in a footnote,
the difference between cost of the investment ( or the
and state the name of pledgee and purpose of the pledge.
other amount at which carried in the books of account
5. If Commission approval was required for any advance
if difference from cost) and the selling price thereof,
made or security acquired, designate such fact in a footnote
not including interest adjustment includible in col and give name of Commission, date of authorization, and case
or docket number.
umn <fl.
8. Report on Line 42, column (a) the total cost of
6. Report column (f) interest and dividend revenues from
Account 123.1.
investments, including such revenues from securities disposed
of during the year.
Gain or Loss
EquitY. in
Amount of
Line
SLJbslCiijry
Investment at
frorn Investment
Revenues
No.
D1sposed ot
End ot Year
Earn1ngs tor Year
For Year

Name of Respondent
Florida Power & L1ght Company

(e)

I

,

(h)

(g)

(f)

2
3
4

237,387

0

*

0

0

5
6
7

8
9

,,
10

12
13

14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
20
31
32
33
34
35
36
37
38
39
40

~----------~-----------+------------r-----------~1
$237,387
FER C FORM N0 .1 (ED. 12-89)

0

0

Page 225

0

Next Page is 22

 <

Page 225 Line 7 Column g

>

In November 1996, FPL Energy Services, Inc. (a wholly-owned
subsidiary of FPL) became the sole owner of FPL Services. At
year-end 1996, FPL Services and FPL Energy Services transactions
were 100% consolidated in the Florida Power & Light Company
Consolidated Financial Statements.

Page 224-225 Footnote.1

 Year of Report
Date of Report
This Report Is:.
(Mo, Da, Yr)
~~~ fXl A
An Resu
Or1~nal
ission
Dec. 31. 1996
MATERIALS AND SUPPLIES
For Account 154, report the amount of plant materials
2. Give an explanation of important inventory adjustand operating supplies
under the primary functional
ments during the year (in a footnote) showing general
classifications as indicated in column(a); estimates of
classes of material and supplies and the various
amounts by function are acceptable. In column(d), desigaccounts ( operating expenses, clearing accounts, plant,
nate the department or departments which use the class of
etc.) affected- debited or credited. Show separately
material.
debit or credits to stores expense-clearing, if applicable.
Sal;;mce
De~artment or
Bal?nce
Line
End o Year
Account
Beg1nmng of
Depar ments ~hlch
No.
Year
Use Mater1a
(a)
(b)
(c)
(d)
Fuel Stock (Account 151)
1
$65,361,395
$95,942,112 ELECTRIC
2
Fuel Stock Expenses Undistributed (Account 152)
Residuals and Extracted Products (Account 153)
3
4
Plant Materials and Operating Supplies (Account 154)
Assigned to - Construction (Estimated )
5
105,969,122 ELECTRIC
120,626,161
6
Assigned to - Operations and Maintenance
7
Production Plant (Estimated)
32,023,653
31,976,861 ELECTRIC
8
Transmission Plant (Estimated)
2,749,093
2,634,878 ELECTRIC
Distribution Plant (Estimated)
9,519,793
10,594,900 ELECTRIC
9
Assigned to - Other
10
475,063
478,914 ELECTRIC
TOTAL Account 154 (Enter Total of lines 5 thru 10)
$165,393,763
$151,654,675
11
Merchandise (Account 155)
12
13
Other Materials and Supplies (Account 156)
14
Nuclefr Mgferials Held.for.Sale <Account 157) (Not
app 1ca e to Gas Ut1 1t1es)
Stores Expense Undistributed (Account 163)
15
(202,629)
0 ELECTRIC
16
17
18
19
$247,596,787
TOTAL Materials and Supplies (Per Balance Sheet)
20
$230,552,529
Nfme of Respongent
L1ght Company
F orida Power

I

I

,_

fERC FORM N0. 1 (ED. 12-96)

Page 227

I

 m

This Report Is:
Year of Report
Date of Re~ort
(Mo, Da, Y )
fXl A
An Resu
Or1~nal
ission
Dec. 31, 1996
Allowances (Accounts 158.1 and 158.2)
4. Report the allowances transactions by the period they are
1. Report below the particulars (details) called for
first eligble for use: the current year's allowances in columns
concerning allowances.
(b)-(c), allowances for the three succeeding years in columns
2. Report all acquisitions of allowances at cost.
(d)-(i), starting with the following year, and allowances for
3. Report allowances in accordance with a weighted average
the remaining succeeding years in columns (j)-(k).
cost allocation method and other accounting as prescribed by
General Instruction No. 21 in the Uniform System of Accounts.
5. Report on line 4 the Environmental Protection Agency (EPA)
Nfme of Respongent
L1ght Company
F orida Power

Line
No.
01

~~
05

~~
09
10
11
12
13
14
15

~~
19
20

~1
23
24
25
26
27
28
29

~~
33
34
35
36
37
38
39
40

~~
44
45
46

Allowances Inventory
(Account 158.1)
(a)
Balance··Beginning of Year

j

I

Current Year
No.
(b)

Purchases/Transfers:

Total
Relinguished Durin~ ;aer:
Charges to Accoun
Other;
Cost of Sales/Transfers:

Total
Balance-End of Year

0

Sales:
Net Sales Proceeds <Assoc. Co.)
Net Sales
v""'"'""' (Other)
Gains
Losses

FER C FORM NO. (ED. 12-95)

1997
Amt.
(c)

Acquired Durina Ye~r·
Issued (Less ith e[d Allow.)
Returned by EPA

Sales:
Net Sales Proceeds (Assoc. Co.)
Net Sales Proceeds (Other)
Gains
Losses
Allowances ¥~~h~eld
(Account
. )
Balance·Beginning of Year
Add: Withheld by EPA
Deduct Returned by EPA
Cost of Sales
Balance·End of Year

I

Page 228

No.
(d)

Amt.
(e)

 of Respondent
Florida Power & L1ght Company

N~me

I

I

Date of Report
(Mo, Da, Yr)

Year of Report
Dec. 31, 1996

I

Allowances (Accounts 158.1 and 158.2) (Continued)
issued allowances. Report withheld portions lines 36-40
System of Accounts).
6. Report on lines 5 allowances returned by the EPA. Report on
8. Report on lines 22- 27 the name of purchasers/transferees !
I line 39 the EPA's sales of the withheld allowances. Report on
of allowances disposed of and identify associated companies.
I lines 43-46 the net sales proceeds and gains/losses resulting
9. Report the net costs and benefits of hedging transactions !
!from the EPA's sale or auction of the withheld allowances.
on a separate line under purchases/transfers and sales/transfers !
I 7. Report on lines 8-14 the names of vendors/transferors of
10. Report on lines 32-35 & 43-46 the net sales proceeds and I
!allowances acquired and identify associated companies (See
gains or losses from allowance sales.
I
"associated company" under "Definitions" in the Uniform
1998
1999
Future Years
Totals
Line
Amt.
No.
Amt.
NQ.
Amt.
No.
(j)
~~)
(g)
(h)
( 1)
(m)
~~5·
~?>
3,322,370.00
3,322,370.00
0 01
0
501,296.00

0

501,296.00

0

~~
05

~~

0
0

0
0

0

0

09
10
11
12

0

14
15

13

0

u
19
20

~~

3,823,666.00

0

3,823,666.00

23
24
25
26
27
28
0 29

u
33
34
35

I*

89.519.00
14,490.00
0
2,386.00
101,623.00

0
0
0
0
0

89.519.00
14,490.00
0
2,386.00
101,623.00

0
0
0
0,
0

36
37
38
39
40

~~

180, 164
180, 164

FE'<C FORM N0.1 (ED . 12-95)

Page

229

0
180,164 44
180,164 45
·46 '

 <

Page 229 Line 39 Column j

>

The number of allowances sold by the EPA is estimated.

Page 228-229 Footnote.l

 ,....

,......

T~h~,~- sfXRelpAort
Is:. l
n 0 r1g1na

Date of Report
Year of Report
(Mo, Oa, Yr)
Dec. 31, 1996
A Resuemission
OTHER REGULATORY ASSETS (Account 182:3)
3. Minor items ( 5% of the Balance at End of Year for Account
1. Report below the particulars (details) called for
182.3 or amounts less than $50,000, whichever is less) may be grouped
concerning other regulatory assets which are created
through the ratemaking actions of regulatory agencies
by classes.
(and not includable in other accounts).
2. For regulatory assets being amortized, show
period of amortization in column (a).
CREDITS
Description ~nd Purpose of
Line
Other Regulatory Assets
Balan<;e at
Debits
Account
Amount
No.
End of Year
Charged
of Respondent
Florida Power & L1ght Company

N~me

(a)

1 Special Assessment for Decontamination
and Decommissioning Fund (wholesale portion of
2
annual assessment is amortized over 12 months.)
3

I

(b)

I

I

(C)

$1,618,089 518

(e ;

(d)

$5,274,155

$52 ,5~

681,645
1,106,936
1,372,487

1' 135,975
1,844,891
2,287,478

4

5 *Martin Plant Reservoir
- Deferred Depreciation
- Deferred Cost of Capital - Debt
- Deferred Cost of Capital - Equity
8

0 407.3
0 407.3
0 407.3

6
7

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

\'-\ \

u3 °

* Turkey Point Unit No. 3 Steam Generator Repairs
- Deferred Depreciation
- Deferred Cost of Capital - Debt
- Deferred Cost of Capital - Equity

0 407.3
0 407.3
0 407.3

3,092,496
5,099,480
6,550,697

10,917,828

* Turkey Point Unit No. 4 Steam Generator Repairs
- Deferred Depreciation
- Deferred Cost of Capital - Debt
- Deferred Cost of Capital - Equity

0 407.3
0 407.3
0 407.3

2,162,214
3,310,847
4,337,939

3,603,690
5,518,080
7,229,898

)

1

(

"

. ' (,0

s, 49S., u3c.

~

Underrecovered Fuel Clause Costs - FPSC

Underrecovered Fuel Clause Costs - FERC

122,221,294 456
557

12,408
91,764,072

4,158,895 557

4,015,860

111 '1 58' 135

./~

,__q.
144,236

J

l,

Underrecovered Environmental Cost Recovery
Clause Costs
Underrecovered Energy Conservation Cost Recovery
Clause Costs

2,364,618

885,049

0

14,858,408

561,236 106
108
421.2

634
447,242
182,242

472,689

90,151,791 108
282
283
407.3

456,271
56,792,441
35,952,285
30,259,158

263,328,825

35,662,000 528

14,350,778

21,311,222

0

8,261,297

2,512,782 557

14,858,408

* Deferred Loss on Sale of Land

Regulatory Assets-Deferred Income Taxes

* Nuclear Maintenance Reserve
* Turkey Point Nuclear Plant Thermal Uprate

8,261,297

L4~
4 ~ T~
OTrA~IL_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _~------~~~------~--------~
FE RC FORM N0.1 (EO. 12-94)

-------------- ---

Page 232

 Name of Respondent
Florida Power & L1ght Company

I

I

Date of Report
(Mo, Da, Yl")

I

Year of Report
Dec. 31, 1996

OTHER REGULATORY ASSETS (Account 182.3)
1. Report bel ·ow the particulars (details) called for
3. Minor items ( 5% of the Balance at End of Year for Account
concerning other regulatory assets which are created
182.3 or amounts less than $50,000, whichever is less) may be grouped
through the ratemaking actions of regulatory agencies
by classes.
(and not includable in other accounts).
2. For regulatory assets being amortized, show
period of amortization in column (a).
CREDITS
Line
Deschi~tion fnd Pur~ose of
Ot e Regu atory ssets
Debits
Account
Amount
Balance at
End of Year
No.
Char~ed
(d)
(e)
(a)
(b)
(c
$1,149,248 Various
1 Minor Items
0
$1 '179,659
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 TOTAL

FERC FORM NO.1 (ED. 12-94)

$281,155,040

Page 232.1

$270,766' 564

$519,208,776

 <

Page 232 Line 5 Column a

>

Amortized over a period not to exceed 5 years beginning 1 / 1 / 95.

<

Page 232 Line 10 Column a

>

Amortized over a period not to exceed 5 years beginning 1/1/95.

<

Page 232 Line 15 Column a

>

Amortized over a period not to exceed 5 years beginning 1/1/95.

<

Page 232 Line 31 Column a

>

5 year amortization - various periods

<

Page 232 Line 40 Column a

>

Amortized over a period not to exceed 5 years beginning 1/1/96.

<

Page 232 Line 42 Column a

>

Amortized over 2 years beginning 1/1/97.

Page 232 Footnote.1

 1. Report below the P,articulars (details) called for
concern1hg miscellaneous aeferred deb1ts.
2. For any deferred debit being amortized, show period
of amort1zat1on 1n column (a).
Balance at
Description of Miscellaneous
Line
Deferred Debits
Beginning of Year
No.
(a)

2 St. Johns River Power Park
3
Renewal and Replacement Fund
4
5 Deferred Pension Cost

Year of Report
Dec. 31, 1996

Date of Report
(Mo, Da, Yn

of Respondent
Florida Power & L1ght Company

N~me

(b)

33,732,507
26,033,145

3. Minor items ( 1% of the Balance at End of Year for
Account 186 or amounts less than $50,000, whichever is less)
may be grouped by classes.
Balance at
Debits
Account
Amount
End of Year
Charged
(f)
(c)
(d)
(e)

6,844,309 143
18,493,211 *

6,844,309

33,732,507

224,419

44,301,937

6

330,045

0 931

123,099

206,946

2,238,614

427,710 512

2,666,324

D

Estimated Workers
Compensation Payment

590,205

0 228

590,205

0

Insurance Claim

500,000

0

0

500,000

ASEA Brown Boveri Claim

312,820

0

0

312,820

10,950,836

1,224,265

0

948,296

3,975,009

309.529

0

107,019

34,516,251

271,975

7 Bradenton Office 8 * Leasehold Improvements
9

10

Port Everglades Plant Fire

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

Miscellaneous Fuel Sales

(634)

FPL Energy Services, Inc.

0

Storm Maintenance

0

Nuclear Decommissioning Study
Minor Items

FERC FORM N0.1 (ED . 12-94)

107,019
2,216,576

12,175,735 *
948,296
4,284,538 228
0

32,571,650 Various

 <

Page 233 Line 5 Column d >

Accounts Charged:
926
228

$208,300
16,119
$224,419

<

Page 233 Line 8 Column a >

Amortization period: October 1994 - September 1999.

<

Page 233 Line 19 Column d >

Accounts Charged:
143
151

$10,395,163
555,673
$10,950,836

===========

.....

Page 233 Footnote.1

 Date of Report
(Mo, Da, Yr)

of Respondent
Florida Power & L1ght Company

N~me

Year of Report
Dec. 31, 1996

At Other (Specify), include deferrals relating to
other income and deductions.
Balance at
End of Year

1. Report
concerning
respondent's accounting for deferred income taxes.
Line
No.
Account Subdivisions

(c)

(a)

NOTES

FERC FORM N0.1 (ED. 12-88)

Page 234

Next Page 250

 <

Page 234 Line 7 Column b

>

Balance at
Beginning o f
Year
(b )

Balance at
End of Ye ar
(c)

Line 7 - Other:
Deferred Revenue - Capacity
Cost Recovery Clause
Unbilled Revenues - Clauses
Bad Debts
Deferred Compensation
Vacation Pay Accrual
Dormant Materials
Restructuring Charges
ITC Deferred Taxes
Regulatory Liabilities
Unfunded Pension and Postretirement Benefits
Nuclear Maintenance Reserve
Miscellaneous Other

26,851,946
38,183,791
5,418,105
6,774,799
11,970,795
20,449,258
6,732,290
108,768,193
170,111,231

23,319,022
43,459,444
5,304,474
8,529,612
11,970,795
11,677,357
7,864,558
96,684,807
150,876,002

32,572,091
44,204,686

44,307,719
13,153,552
64,204,766

472,037,185

481,352,108

0

Subtotal
Line 17 - Other:
Other Income and Deductions:
JEA Acquisition Adjustment
Gains/Losses on Disposition
of Property
Subtotal

<

,....

Page 234 Line 17 Column a

56,951

33,412

366,904

989,594

423,855

1,023,006

>

See Note for line 7.

Page 2 3 4 Foo tnot e. 1

 N9me of Respondent
Florida Power & L1ght Company

l

This Report Is: . l
(1) [Xl An Or1g1na
(2) [ f>. Resuomission
CAPITAL STOCK (Accounts 201 and 204)

I

1. Report below the particulars ( details ) called for con·
cerning
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 10-K Report Form filing,
Class and Serie~ of Stock and
Name of Stock Exchange

Line
No .

(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
36
37
38
39
40
41
42

Cumulative, No Par Value
* $2.00 Preferred Series A

Year of Report
Dec. 31, 1996

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 10-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.
N~ber

of S ares
Authorized
By Charter
(b)
10,000,000

Par
or Stated
Value
Per Share

Cc;1ll
Pr1c;e at
End of Year

(c)

(d)

*

Cumulative, $100 Par Value
4.50% Preferred, Series
4.50% Preferred, Series A
4.50% Preferred, Series B
4.50% Preferred, Series c
4.32% Preferred, Series D
4.35% Preferred, Series E
6.84% Preferred, Series Q
8.625% Preferred, Series R
6.98% Preferred, Series s
7.05% Preferred, Series T
6.75% Preferred, Series u

$27.00

15,822,500
$100.00
$100.00
$100.00
$100.00
$100.00
$100.00
$100.00
$100.00
$100.00
$100.00
$100.00

* TOTAL_PRE

25,822,500

* Common Stock

1,000

TOTAL_COM

1,000

FERC FORM NO.1 (ED. 12-91)

Date of Report
(Mo, Da, Yt")

Page 250

*

$101.00
$101.00
$101.00
$103.00
$103.50
$102.00
$102.28
$104.60

*
*
*

 of Respondent
Florida Power & L1ght Company

N~me

,.....

Date of Report
T~~h~isfRXelpAort
1s: . l
n 0 r1g1na
(Mo, Da, Y)')
A Resuemission
CAPITAL STOCK (Account 201 and 204 )(Continued)

I

I

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 noncumulative.

I

Year of Report
Dec. 31, 1996

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.

HELD BY RESPONDENT
OUTSTANDING PER BALANCE SHEET
(Tota ~mount outstanding Wlthout
AS REACQUIRED STOCK
IN SINKING AND
reduct1on tor ~mounts held by
respondent.)
(Account 217)
OTHER FUNDS
Line
~--------~~~~~--------------~----~--~~~~~~~----------~----~~-------r----~--~----~ No.
Shares
AmQunt
Shares
Co:;t
Sh<;~res
Amovnt
(e)

(t)

(g)

(h)

(1

>

(J)

1

2,533,188

-

2

63,329,700

100,000
50,000
50,000
62,500
50,000
50,000
410,000
50,000
750,000
500,000
650,000

10,000,000
5,000,000
5,000,000
6,250,000
5,000,000
5,000,000
41,000,000
5,000,000
75,000,000
50,000,000
65,000,000

5,255,688

335,579,700

1,000

1 ,373, 068,515

1,000

1, 373,068,515

3
4
5
6
7
8
9

10
11

12
13

0

0

0

0

0

0

,......

FE RC FORM N0.1 ( ED. 12-88)

Page 251

14
15
16
0 17
18
19
20
0 21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42

 <

Page 250 Line 2 Column a

>

New York Stock Exchange.

<

Page 250 Line 2 Column c

>

No Par Value.

<

Page 250 Line 13 Column d >

Not redeemable prior to 2003.

<

Page 250 Line 14 Column d >

Not redeemable prior to 2003.

<

Page 250 Line 15 Column d

>

Not redeemable prior to 2003.

<

Page 250 Line 17 Column a >

FPL's Charter also authorizes the issuance of 5 million shares of
subordinated preferred stock, no par value. None of these shares
is outstanding.

<

Page 250 Line 19 Column a

>

All shares are held by FPL Group,

<

Page 250 Line 19 Column c

Inc.

>

No Par Value.

Page 250-251 Footnote.1

 of Respondent
Florida Power & L1ght Company

N~me

Date of Report
This Report Is:
Year of Report
(1) [XJ An Or1ginal
(Mo, Da, Yr)
(2) [ J A Resuemission
Dec. 31, 1996
CAPITAL STOCK SUBSCRIBED CAPITAL STOCK LIABILITY FOR CONVERSION
PREMIUM ON CAPITAL STOCK, A~D INSTALLMENTS RECEIVED
CAPITAL STOtK
(Accounts 202 and 205, 203 and 206, 2 7, 212)
1. Show for each of the above accounts the amounts
Common Stock Liability for Conversion, or Account 206,
applying to each class and series of capital stock.
Preferred Stock Liability for Conversion, at the end of the
2. For Account 202, Common Stock Subscribed, and Acyear.
ccount 205, Preferred Stock Subscribed, show the subscription
4. For Premium on Account 207, Capital Stock, designate
price and the balance due on each class at the end of year.
with a double asterisk any amounts representing the excess
of consideration received over stated values of stocks
3. Describe in a footnote the agreement and transactions
without par value.
under which a conversion liability existed under Account 203,
Number of Shares
Amount
Name of Account and Description of Item
Line
(C)
(b)
(a)
No.
Premium
on
Capital
Stock
Account
207
1
2
3
112,500
50,000
4.50% Preferred Stock, Series A
4
5,950
50,000
4.32% Preferred Stock, Series D
5

I

I

8N

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

100,000
L4~5~-------------------------------------------i--------10c~ot-----~4~6~~T~O~T~A~L--~-=~~~~------------------------------p;.~~,---------~--------------~--~--------- -

FERC FORM NO. 1 (ED. 12-95)

Page 252

,a, 1, 50

j

 Year of Report
Date of Report
I s:. l
T~h~~i s fXRlepAort
(Mo, Da, Yr)
n 0 r1g1na
Dec. 31, 1996
A Resu!Smission
OTHER PAID-IN CAPITAL (Accounts 208-211, inc.)
capital change which gave rise to amounts reported under
Report below the balance at the end of the year and the
this caption including identification with the class and series
information specified below for the respective other paid-in
of
stock to which related.
capital accounts. Provide a subheading for each account and
(c) Gain on Resale or Cancellation of Reacquired Capital
show a total for the account, as well as total of all accounts
Stock (Account 210)--Report balance at beginning of year,
for reconciliation with balance sheet, page 112. Add more
credits, debits, and balance at end of year with a designacolumns for any account if deemed necessary. Explain
tion of the nature of each credit and debt identified by the
changes made in any account during the year and give the
class and series of stock to which related.
accounting entries effecting such change.
(d) Miscellaneous Paid-In Capital (Account 211)--Classify
(a) Donations Received from Stockholders (Account
amounts included in this account according to captions
208)--State amount and give brief explanation of the origin
which, together with brief explanations, disclose the general
and purpose of each donation.
(b) Reduction in Par or Stated Value of Capital Stock (Acnature of the transactions which gave rise to the reported
count 209)--State amount and give brief explanation of the
amounts.
Line
Item
Amount
No.
(a)
(b)
1
Donations Received from Stockholders (Account 208)
0
2
of Respondent
Florida Power & L1ght Company

N~me

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

I

I

Reduction in Par or Stated Value of Capital Stock (Account 209)

0

Gain on Resale or Cancellation of Reacquired Capital Stock (Account 210)

0

Miscellaneous Paid-In Capital (Account 211):
Contributions from FPL Group, Inc.
Balance at December 31, 1995

2,237,000,000

Contributions During the Year

195,000,000

Subtotal-Balance at December 31, 1996

2,432,000,000

33

34
35
36
37
38
39
40 !TOT AL
FERC FORM N0.1 (ED. 12-87)

$2,432 ,000 , 000
Page 253

 Year of Report
Date of Re~ort
Th is Report Is:. ·
(Mo, Da, Y )
~~~ fXl A
An Resu
Or1~nal
Dec . 31' 1996
ission
DISCOUNT ON CAPITAL STOCK (Account 213)
wi th respect to any class or s eries of stock, attach a s tatement
1. Report the balance at end of the year of d i scount on
gi ving particulars (details) of the change. State the rea son for
capital stock for each class and series of capital stock.
any charge-off during the year and specify the amount charged.
2. If any change occurred during the year in the balance
Balance at End of Year
Class and Series of Stock
Line
(b)
(a)
No.
Nfme of Respongent
L1ght Company
F orida Power

I

I

I

1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

18
19
20
21

TOTAL

0
CAPITAL STOCK EXPENSE (Account 214)
giving particulars (details) of the change. State the reason
1. Report the balance at end of the year of capital stock expenses for each class and series of capital stock.
for any charge- off of capital stock expense and specify the
account charged.
2. If any change occurred during the year in the balance wi th
respect to any class or series of stock, attach a statement
Balance at End of Year
Class and Series of Stock
Line
(b)
(a)
No.
$4,527,245
1 * Prefer r ed Stock
2
3,741,472
3 Conmon Stock
4
90,423
5 * Capital Stock Expense- Unallocated
6
7
8
9
10
11
12
13

14
15
16
17
18
19
20
21
22 TOT AL
FERC FORM N0.1 (ED. 12·87)

Page 254

___

\ 59 ,1 40_.I
age is 256

 <

Page 254 Line 1 Column a

>

Preferred Stock (a) :
4.50%
4.50% Series A
4.50% Series B
4.50% Series c
4.32% Series D
4.35% Series E
(b) 6.84% Series Q
(c) 8.625% Series R
6.98% Series s
7.05% Series T
6.75% Series u
(d) $2.00 Series A - No Par Value
Total Preferred Stock

323,367
14,211
21,474
31,981
20,331
30,824
385,498
50,653
738,148
514,917
635,764
1,760,077
4,527,245

(a)

The 7.28% Series F Preferred Stock and 7.40% Series G
Preferred Stock were redeemed during 1996; $97,846 and
$86,516, respectively, of Capital Stock Expenses were
written-off to account 439 - Adjustments to Retained
Earnings.

(b)

Redemption of 30,000 shares; $37,420 was written-off to
account 439 - Adjustments to Retained Earnings.

(c)

Redemption of 50,000 shares; $63,908 was written-off to
account 439 - Adjustments to Retained Earnings.

(d)

$85,885 of Capital Stock Expense related to the 1995
exchange offer for 2,466,812 shares of $2 No Par Series A
Preferred Stock was written-off to account 439 Adjustments to Retained Earnings.

<

Page 254 Line 5 Column a

>

Capital Stock Expense - Unallocated:
Increase of $311 is the result of additional expenses
unclassified.

Page 254 Footnote.1

 Year of Report
Dec. 31, 1996

of Respondent
Florida Power & L1ght Company

N~me

LONG-TERM DEBT (Accounts 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.

Class and Series of Obligation, Coupon Rate
(For new issue, give Comm1ssion Author1zat1on numbers and dates)

Line
No.
1
2
3

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.
Principal
Amount of
Debt issued
(b)

(a)

Total expense,
Prem1utn or
D1scount
(c)

ACCOUNT 221:
1st MORTGAGE BONDS:

4

5
6
7

5.500% DUE 1999

230,000,000

5_375% DUE 2000

125,000,000

6.625% DUE 2003

100,000,000

6_875%

DUE 2004

125,000,000

7.875% DUE 2007

75,000,000

7.875% DUE 2012

150,000,000

* 7.875% DUE 2013

250,000,000 *

7.300% DUE 2016

225,000,000

* 8.500% DUE 2022

100,000,000 *

* 8.500% DUE 2022

150,000,000 *

* 7.750% DUE 2023

150,000,000 *

7.625% DUE 2024

175,000,000

7.000% DUE 2025

125,000,000

7.050% DUE 2026

135,000,000

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

TOTAL

rE RC FORM N0.1 (ED. 12-96)

Page 256

1,092,890
3,673,100
603,554
375,000
533,400
2,473,000
652,482
1,518,750
370,189
646,500
771,414
3,280,500
1,329,512
5,037,500
1 '079 ,311
5,379,750
490,885
875,000
800,724
1 '987' 500
712,877
2,847,000
831,994
3,934,000
617,687
482,500
689,503
2,671,650

D
D
D
D
D
0
D
D
D
D
D
D
D
D

 of Respondent
Florida Power & L1ght Company

Year of Report
Dec. 31, 1996

N~me

LONG-TERM DEBT (Account s 221, 222,223, and 224) (Continued)

10. Identify separate und i sposed amounts applicab l e to
issues which were redeemed in prior years.
11 . Explain any debits and credits other than amortization debited to Account 428, Amortization of Debt Di scount
and Expense, or credited to Account 429, Amortization of
Premium on Debt - Cred i t.
12. In a footnote,
give explanatory
particulars
(details)
for Accounts 223 and 224 of net changes
during the year. With respect to long-term advances, show
for each company: (a) principal advanced during year, (b)
i nterest added to principal amount, and (c) principal repaid
during year. Gi ve Commission authorization numbers and dates.
13. If the respondent has pledged any of its long - term debt

Nom~nal

o

,.....

,.....

Date
Issue
(d)

Date of
Matur1 ty
(e)

AMORTIZATION PERIOD
Date From
Date To
(f)
(g)

securities gi ve 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 outstan ding 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 (i) . Explain in a
footnote any difference between the total of co l umn (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 .

(

Outstanding
Tot~l amou?t ovtst?nding
w1t out he ~ct1on or
amounts e c~) respondent )

Interest for Year
Amount
( 1)

07!01!1993

07!01!1999

07!01!1993

07!01!1999

230,000,000

12,650,000

09!01!1993

04/01/2000

09/01/1993

04/01/2000

125,000,000

6,718,750

02/01/1993

02!01!2003

02!01!1993

02!01!2003

100,000 , 000

6,625,000

04/01/1993

04/01/2004

04/01/1993

04/01/2004

125,000,000

8,593, 750

01/01/1992

01/01/2007

01/01/1992

01/01/2007

75,000,000

5,906,250

12/01/1992

12!01!2012

12!01!1992

12!01!2012

125,779,000

9,905,096

01!01!1993

01/01/2013

01!01!1993

01 !01!2013

233,959,000

18,501,950

04/01/1993

04/01/2016

04/01/1993

04/01/2016

225,000,000

16,425,000

01/01/1992

01/01/2022

01/01/1992

01!01!2022

0

4,991,625

07/01/1992

07/01/2022

07/01/1992

07/01/2022

125,897,000

10,875,082

02/01/1993

02!01!2023

02/01/1993

02!01!2023

124,555,000

10,703,568

06!01!1993

06/01/2024

06!01!1993

06/01/2024

175,000,000

13,343,750

09!01!1993

09/01/2025

09!01!1993

09/01/2025

125,000,000

8 , 750,000

12/01/1993

12!01!2026

12!01!1993

12/01/2026

135,000,000

9,517,500

~
FERC FORM N0. 1 (ED. 12-96)

Line
No.

,

2
3
4
5
6
7
8
9
10

,,
12
13
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17
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20
21
22
23
24
25
26
27
28
29
30
31
32
}_:,

Page 257

::

Next Page ?b 1

 N9me of Respondent
Florida Power & L1ght Company

Date of Report
T~h~~~- sfXRJepAort
1s: . l
(Mo, Da, Yr)
n 0 r1g1na
A Resuemission
LONG-TERM DEBT (Accounts 221, 222,223, and 224)

I

I

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 authoriza tion 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.
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

I

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 di s count wi th
respect to the amount of bonds or other long-term debt origi nally issued.
B. 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 (0). 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 i n
a footnote the date of the Commission's authorization of
treatment other than as specified by the Uniform System of
Accounts.

Class and Series of Obligation, Cou~ Rate
(For new issue, give Comm1ssion Author1zat1on n ers and dates)
(a)
POLLUTION CONTROL BONDS
7.300% DUE 2020

Princi pa ~
A~unt o
De t issued
(b)
$76,300,000

POLLUTION CONTROL BONDS

7.500% DUE 2020

9,835,000

POLLUTION CONTROL BONDS

7.150% DUE 2023

15,000,000

POLLUTION CONTROL BONDS

7.150% DUE 2023

32,985,000

POLLUTION CONTROL BONDS

7.150% DUE 2023

4,000,000

POLLUTION CONTROL BONDS

6.700% DUE 2027

12,015,000

QUARTERLY INCOME DEBT SECURITIES 8.750% DUE 2025

61,670,300

* MEDIUM TERM NOTE 4_900% DUE 1996

60,000,000

* MEDIUM TERM NOTE 4.850% DUE 1996

40,000,000

MEDIUM TERM NOTE

6.200% DUE 1998

36,300,000

MEDIUM TERM NOTE

6.200% DUE 1998

23,700,000

MEDIUM TERM NOTE

5.700% DUE 1998

55,000,000

MEDIUM TERM NOTE

5.500% DUE 1998

65,300,000

MEDIUM TERM NOTE

8.100% DUE 2002

5,000,000

MEDIUM TERM NOTE

8.000% DUE 2002

5,000,000

MEDIUM TERM NOTE

5.790% DUE 2003

70,000,000

TOTAL

r-

FE RC FORM N0.1 CEO. 12-96)

Year of Report
Dec. 31, 1996

Page 256.1

Total e~ense,
Prem1
or
D1scount
(c)
$1,585,306
460,089
237,034
39,340
440,317
242,550
294,736
533,367
155,796
64,680
231,420
215,068
146,282
(2,158,461)
274,482
192,500
182,988
134,500
161,124
174,250
120,181
102,000
253,588
270,000
301,059
301,200
22,194
31,250
22,194
31,250
320,230
564,500

D
D
D
D
D
D
p

D
D
0
D
D
D
D
D
D

 ....
of Respondent
Florida Power & L1ght Company

N~me

I

This Report Is:
Date of Report
(1) fXl An Or1ginal
(Mo, Da, Yt)
(2)
J A Resuemission
LONG ·TERM DEBT (Accounts 221 222,223, and 224) (Continued)

I

10. Identify separate undisposed amounts applicable to
issues which were redeemed in prior years.
11. Explain any debits and credits other than amortiza·
tion debited to Account 428, Amortization of Debt Discount
and Expense, or credited to Account 429, Amortization of
Premium on Debt · Credit.
12. In a footnote,
give explanatory
particulars
(details)
for Accounts 223 and 224 of net changes
during the year. With respect to long·term advances, show
for each company: (a) principal advanced during year, (b)
interest added to principal amount, and (c) principal repaid
during year. Give Commission authorization numbers and dates.
13. If the respondent has pledged any of its long-term debt

AMORTIZATION PERIOD
Date From
Date To
(f)
(g)
07/01/1990
07/01/2020

Nom}nal Date
o Issue
(d)
06/15/1990

Date of
Matur1ty
(e)
07/01/2020

06!15/1990

07/01/2020

07/01/1990

08/01/1991

02/01/2023

08/01/1991

I

Year of Report
Dec. 31, 1996

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 outstan·
ding 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 (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.

(

Outstanding
Tot~l amou?t ovtst~nding
w1t out e ct1on or
amounts he ~<~) respondent )

*

76,300,000

Interest for Year
Amount
( 1)
5,664,900

07/01/2020

*

9,835,000

749,625

08/01/1991

02/01/2023

*

15,000,000

1,087,500

02/01/2023

08/01/1991

02/01/2023

*

32,985,000

2,358,428

08/01!1991

02/01/2023

08/01/1991

02/01/2023

*

4,000,000

286,000

05/01/1992

05/01/2027

05/01/1992

05/01/2027

*

12,015,000

805,005

11/07/1995

11/01/2025

12/01/1995

11/01/2025

61,670,300

5,396,151

06/04/1993

06/04/1996

06/15/1993

06/15/1996

0

1,261,500

06/22!1993

06/24!1996

06/15/1993

06/15/1996

0

940,278

02/02/1993

02/02/1998

02/15!1993

02/15/1998

36,300,000

2,250,600

02/02/1993

02/02/1998

02/15/1993

02/15/1998

23,700,000

1,469,400

03/05/1993

03/05/1998

03/15/1993

03/15/1998

55,000,000

3,135,000

03/11/1993

03!11/1998

03/15/1993

03/15/1998

65,300,000

3,591,500

04!13/1992

04/15/2002

04/15/1992

04/15/2002

5,000,000

405,000

05/19/1992

05/20/2002

05/15/1992

05/15/2002

5,000,000

400,000

09/15/1993

09/15/2003

70,000,000

4,053,000

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

•

09/14/1993

-

09/15/2003

FERC FORM N0.1 (ED. 12·96)

25
26
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28
29
30
31
32
-3.,.

-

Page 257.1

Next Page 261

 of Respondent
Florida Power & L1ght Company

N~me

I

I

Year of Report
Dec. 31, 1996

LONG-TERM DEBT (Accounts 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.
Line
No.
1
2

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.

Class and Series of Obligation, Cou~ Rate
(For new issue, give Comm1ssion Author1zat1on n ers and dates)
(a)
MEDIUM TERM NOTE 8.200% DUE 2007

Principa}
A~ount o
De t issued
(b)
$5,000,000

3
4

MEDIUM TERM NOTE

8.2DO% DUE 20D7

10,000,00D

5
6
7

MEDIUM TERM NOTE

8.100% DUE 2007

12,000,000

MEDIUM TERM NOTE

8.00D% DUE 2D12

5,000,000

MEDIUM TERM NOTE

8.000% DUE 2022

100,000,000

8
9

1D
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33

MANATEE COUNTY INDUSTRIAL DEVELOPMENT
REVENUE BONDS, 5.900% SERIES A DUE 2007

1,000,000

PUTNAM COUNTY INDUSTRIAL DEVELOPMENT
REVENUE BONDS, 5.900% SERIES A DUE 2007

1,000,000

Total e~ense,
Prem1
or
D1scount
(C)

$22,194
31,250 D
44,386
62,500 D
53,264
74,250 D
22,193
30,000 D
504,624
2,588,000 D
72,417
20,039 D
72,417
20,039 D

CITY OF JACKSONVILLE POLLUTION CONTROL REVENUE
REFUNDING BONDS, VARIABLE RATE SERIES 1992 DUE 2027

28,300,000

377,136

ST. LUCIE COUNTY POLLUTION CONTROL REVENUE
REFUNDING BONDS, VARIABLE RATE SERIES 1992 DUE 2027

49,325,000

418,684

ST. LUCIE COUNTY POLLUTION CONTROL REVENUE
REFUNDING BONDS, VARIABLE RATE SERIES 1993 DUE 2026

56,390,000

477,903

ST. LUCIE COUNTY SOLID WASTE DISPOSAL REVENUE
BONDS, VARIABLE RATE SERIES 1993 DUE 2027

16,500,000

197,527

MARTIN COUNTY SOLID WASTE DISPOSAL REVENUE
BONDS, VARIABLE RATE SERIES 1993 DUE 2027

4,050,000

133,307

TOTAL

FERC FORM NO.1 (ED. 12 -96)

Page 256.2

 r/

of Respondent
Florida Power & L1ght Company

N~me

t~~s[~lep~~to~~~inal
(2) [

LONG·TERM DEBT (AcCoiJrits 221

10. Identify separate undisposed amounts applicable to
issues which were redeemed in prior years.
11. Explain any debits and credits other than amortiza·
tion debited to Account 428, Amortization of Debt Discount
and Expense, or credited to Account 429, Amortization of
Premium on Debt - Credit.
12. In a footnote,
give explanatory
particulars
(details)
for Accounts 223 and 224 of net changes
during the year. With respect to long-term advances, show
for each company: (a) principal advanced during year, (b)
interest added to principal amount, and (c) principa l repaid
during year. Give Commission authorization numbers and dates.
13. If the respondent has pledged any of its long-term debt

AMORTIZATION PERIOD
Date From
Date To
(g)
(f)
04/15/1992
04/15/2007

Date
Issue
(d)
04/14/1992

Date of
Matun ty
(e)
04/16/2007

04!21!1992

04/23/2007

04/15/1992

05/26/1992

05/30/2007

08/14/1992

Nom~nal

A Resu~ission

I

Date of Re~ort
(Mo, Da, y )

222,223, and 224) (Continued)

I

Year of Report
Dec. 31, 1996

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 outstan·
ding 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 (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.

(

Outstanding
w1t out e ct1on or
amounts he ~c~) respondent )
Tot~l amou~t ovtst~nding

5,000,000

Interest for Year
Amount
( 1)
410,000

04/15/2007

10,000,000

820,000

05/15/1992

05/15/2007

6,500,000

526,500

08/14/2012

08/15/1992

08/15/2012

5,000,000

400,000

08!27!1992

08/25/2022

08!15!1992

08/15/2022

98,610,000

7,889,883

09!01!1977

09!01!2007

09!01!1977

09!01/2007

*

1,000,000

59,000

59,000

o

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13

09!01!1977

09!01!2007

09!01!1977

09!01!2007

*

1,000,000

05/28/1992

05/01/2027

05/01/1992

05/01/2027

*

28,300,000

1,061,611

05/28/1992

05/01/2027

05!01!1992

05/01/2027

*

49,325,000

1 ,842, 757

07!01!1993

01/01/2026

07!01!1993

01/01/2026

*

56,390,000

2,026,915

07!01!1993

01!01!2027

07!01!1993

01!01!2027

*

16,500,000

591,380

07!01!1993

01!01!2027

07!01!1993

01!01!2027

*

4,050,000

154,562

~
FER: FORM N0.1 (ED. 12-96)

Page 257.2

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15
16
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18
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20
21
22
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3;

Next Page 2f •

 N9me of Respondent
Florida Power & L1ght Company

l

I

LONG-TERM DEBT (Accounts 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 certifi cates were issued.

1
2
3
4
5

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 origi nally 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.

Class and Series of Obligation Coupon Rate
(For new issue, give Commission Authorization numbers and dates)

Line
No.

Year of Report
Dec. 31, 1996

(a)

DADE COUNTY INDUSTRIAL DEVELOPMENT AUTHORITY REVENUE
REFUNDING BONDS, VARIABLE RATE SERIES 1993 DUE 2D21

Principa~

A~ount o
De t issued
(b)
$45,750,000

Total ex~ense,
Prem1u or
Discount
(C)

$706,067

CITY OF JACKSONVILLE POLLUTION CONTROL REVENUE REFUNDING
BONDS, VARIABLE RATE SERIES 1994 DUE 2D24

45,960,000

396,859

MANATEE COUNTY POLLUTION CONTROL REVENUE REFUNDING
BONDS, VARIABLE RATE SERIES 1994 DUE 2D24

16,510,000

132,450

MARTIN COUNTY POLLUTION CONTROL REVENUE REFUNDING
BONDS, VARIABLE RATE SERIES 1994 DUE 2024

19,400,000

140,106

4,480,000

81,599

ST. LUCIE COUNTY POLLUTION CONTROL REVENUE REFUNDING
BONDS, VARIABLE RATE SERIES 1994A DUE 2029

57,500,000

371,793

ST. LUCIE COUNTY POLLUTION CONTROL REVENUE REFUNDING
BONDS, VARIABLE RATE SERIES 1994B DUE 2029

29,000,000

191,529

ST. LUCIE COUNTY POLLUTION CONTROL REVENUE REFUNDING BONDS,
VARIABLE RATE, SERIES 1995, DUE 2027

49,995,000

318,256

DADE COUNTY INDUSTRIAL DEVELOPMENT AUTHORITY POLLUTION CONTROL
REVENUE REFUNDING BONDS, SERIES 1995 VARIABLE RATE DUE 2020

8,635,000

179,918

CITY OF JACKSONVILLE POLLUTION CONTROL REVENUE REFUNDING BONDS,
VARIABLE RATE, SERIES 1995, DUE 2029

51,940,000

342,347

$3,304,840,300

$59,788,240

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

PUTNAM COUNTY DEVELOPMENT AUTHORITY POLLUTION CONTROL REVENUE
REFUNDING BONDS, VARIABLE RATE SERIES 1994 DUE 2024

TOTAL

FERC FORM NO.1 (ED. 12-96)

Page 256.3

 of Respondent
Florida Power & L1ght Company

N~me

Year of Report
Dec. 31, 1996

10. Identify separate undisposed amounts applicable to
issues which were redeemed in prior years.
11. Explain any debits and credits other than amortization debited to Account 428, Amortization of Debt Discount
and Expense, or credited to Account 429, Amortization of
Premium on Debt - Credit.
12. In a footnote,
give explanatory
particulars
(details)
for Accounts 223 and 224 of net changes
during the year. With respect to long-term advances, show
for each company: (a) principal advanced during year, (b)
interest added to principal amount, and (c) principal repaid
during year. Give Commission authorization numbers and dates.
13. If the respondent has pledged any of its long-term debt

FERC FORM N0.1 (ED. 12-96)

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 (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.

Page 257.3

Next Page 26n

 <

Page 256 Line 17 Column a

>

FPL redeemed $2,100,000 of its 7.875% Series due January 1, 2013
during 1996.

<

Page 256 Line 17 Column c

>

The applicable balance of unamortized debt expense, premium or
discount of the original issue and the redemption premium or
discount were recorded in "Unamortized Loss on Reacquired Debt"
(account 189) or "Unamortized Gain on Reacquired Debt"
(account 257), and are being amortized over the remaining life
of the retired issue.

<

Page 256 Line 21 Column a

>

FPL redeemed the remaining $87,000,000 of its 8.500% Series due
January 1, 2022 during 1996.

<

Page 256 Line 21 Column c

>

See Note for Page 256, Line 17 Column c.

<

Page 256 Line 23 Column a >

FPL redeemed $7,250,000 of its 8.500% Series due July 1, 2022
during 1996.

<

Page 256 Line 23 Column c >

See Note for Page 256, Line 17, column c.

<

Page 256 Line 25 Column a

>

FPL redeemed $20,000,000 of its 7.750% Series due February 1,
2023 during 1996.

<

Page 256 Line 25 Column c

>

See Note for Page 256, Line 17, Column c.

Page 256-257 Footnote.1

 <

Page 256.1 Line 15 Column a

>

FPL redeemed all $60,000,000 of its 4.9% Series Medium Term
Note due June 4, 1996 in June 1996.

<

Page 256.1 Line 17 Column a

>

FPL redeemed all $40,000,000 of its 4.85% Series Medium Term Note
due June 24, 1996 in June 1996.

<

Page 257.1 Line 1 Column h >

First Union National Bank of Florida (Trustee) is in possession
of FPL's First Mortgage Bonds issued as pledged security for
pollution control and industrial development bonds.

<

Page 257.1 Line 3 Column h >

See Note for Page 257.1, Line 1, Column h.

<

Page 257.1 Line 5 Column h >

See Note for Page 257.1, Line 1, Column h.

<

Page 257.1 Line 7 Column h >

See Note for Page 257.1, Line 1, Column h.

<

Page 257.1 Line 9 Column h >

See Note for Page 257.1, Line 1, Column h.

<

Page 257.1 Line 11 Column h >

See Note for Page 257.1, Line 1, Column h.

<

Page 257.2 Line 11 Column h >

See Note for page 257.1, Line 1, Column h.

Page 256-257 Footnote.2

 <

Page 257.2 Line 14 Column h

>

See Note for page 257.1, Line 1, Column h.

<

Page 257.2 Line 17 Column h >

See Note for Page 257.1, Line 1, Column h.

<

Page 257.2 Line 20 Column h >

See Note for Page 257.1, Line 1, Column h.

<

Page 257.2 Line 23 Column h

>

See Note for Page 257.1, Line 1, Column h.

<

Page 257.1 Line 3 Column h >

See Note for Page 257.1, Line 1, Column h.

<

Page 257.2 Line 29 Column h >

See Note for page 257.1, Line 1, Column h.

<

Page 257.3 Line 1 Column h >

See Note for Page 257.1, Line 1, Column h.

<

Page 257.3 Line 4 Column h

>

See Note for Page 257.1, Line 1, Column h.

<

Page 257.3 Line 7 Column h >

See Note for Page 257.1, Line 1, Column h.

Page 256-257 Footnote.3

 <

Page 257.3 Line 10 Column h

>

See Note for Page 257.1, Line 1, Column h.

<

Page 257.3 Line 13 Column h

>

See Note for Page 257.1, Line 1, Column h.

<

Page 257.3 Line 16 Column h

>

See Note for Page 257.1, Line 1, Column h.

<

Page 257.3 Line 19 Column h >

See Note for Page 257.1, Line 1, Column h.

<

Page 257.3 Line 22 Column h

>

See Note for Page 257.1, Line 1, Column h.

<

Page 257.3 Line 25 Column h >

See Note for Page 257.1, Line 1, Column h.

<

Page 257.3 Line 28 Column h

>

See Note for Page 257.1, Line 1, Column h.

Page 256-257 Footnote. 4

 Year of Report
This Report Is:
Date of Report
(1 l [Xl An Or1ginal
(Mo, Da, Yrl
(2) [ A Resuomission
Dec . 31, 1996
RECONCI LIATION OF REPORTED NET INCOME ~ITH TAXABLE INCOME
FOR FEDERAL INCOME TAXES
1. Report the reconciliation of reported net income for the
f/· led, indic~ting, however, intercompany amount s to be
year w1th taxab e income used in computing Federal 1ncome
e 1m1nated 1n such a consol1dated return. State names 0 f
tax accruals and show computation of such tax accruals. Ingroup members, tax ass igned to each group member, and
elude in the reconciliation, as far as practicable, the same
basis of allocation, assignment, or shar i ng of the
detail as furnished on Schedule M-1 of the tax return for the
consolidated tax among the group members.
year. Submit a reconciliation even though there i s no taxable
3. A substitute page, designed to meet a particular
income for the year. Indicate clearly the nature of each reconneed of a company, may be used as long as the data i s
ciling amount.
consistent and meets the requirements of the above
2. If the utility is a member of a group which files a coninstructions. For electronic reporting purposes complete
solidated Federal . tax returQ, reconcile reported net income
line 27 and provide the substitute page in the context
w1th taxable net 1ncome as 1f a separate return were to be
of a footnote.
Line
Particulars (Details)
Amount
No.
(a)
(b)
of Respondent
Florida Power & L1ght Company

N~me

28
Show Computation of Tax:
29
Federal Income Tax @ 35%
30
Prior period adjustment
31
32
33
34
35
Total Accrual
36
37 *
38
39
40
41
42
43
I
44
FE RC FORM NO.1 (ED. 12-96)

416,736,208
(25, 107,700)

391,628,508

Page 261

 <

Page 261 Line 5 Column a

(A)

>

Taxable Income Not Reported on Books:

Contributions in aid of construction
Gain on Sale of Environmental Credits
Gain/(Loss) on Dispositions -Net
Unbilled Revenues - Net
TOTAL:

<

$ 29,923,329
178,127,347
958,660
13,676,537
$222,685,873

Page 261 Line 10 Column a >

,.....
(B) Deductions Recorded on Books Not Deducted on Return:
Federal Income Taxes (A/C 409.1 - 409.3)
Excess Book Over Tax Deprciation/Amortization
Construction period interest
Deferred compensation and interest - Net
Post-retirement benefits - Net
Amortization of loss on reacquired debt
Business meals
Fund reserve expense - Net
Property Taxes
Cost Reduction Costs - Net
Nuclear Maintenance Reserve - Net
Legal expense
Non-deductible penalties/lobbying expenses
Environmental liability
Bad debt expense - Net
Intercdnnection - Homestead

,.....

,.....

391,628,508
118,668,624
7,838,397
2,514,860
17,706,087
12,348,954
1,789,708
70,967,119
10,918,000
1,043,288
34,098,644
181,379
2,417,273
28,530,278
11,585
40,272
700,702,976

TOTAL:

<

Page 261 Line 15 Column a

(C)

>

Income Recorded on Books Not Included in Return:

Provision for Deferred Income Taxes - Net
Investment Tax Credit Adjustment
St Johns River Power Park Costs - Net
Deferred clause revenues - Net
Tax exempt fund income
Pension
Interest on Tax Refund/Deficiency - Net
Prior Years State Tax Adjustment
TOTAL:

Page 261 Footnote.1

$ (93,907,368)
(31,324,399)
(632,596)
(10,469,630)
(15,588,152)
(18,841,625)
(153,240)
(12,987,691)
$(183,904,701)

 <

Page 261 Line 20 Column a

(D)

>

Deductions on Return Not Charged Against Book Income:

Allowance for funds used during construction
Nuclear Thermal Uprate - Net
Dormant Materials - Net
Computer Software Capitalized
Medical Contributions - Net
Removal cost
Injuries and Damages Reserve - Net
Early Capacity Payment - Net
Capitalized Interest - Nuclear Fuel
Repair allowance
Repair projects
Cable injection
Lease Cancellations
Deferred Costs - Clauses - Net
TOTAL:

<

$

(1,906,140)
(8,261,296)
(8,701,550)
(23,785,645)
(14,784,552)
(24,799,782)
(4,548,245)
(316,538)
(2, 7471 797)
(12,000,000)
(13,892,414)
(1,129,685)
(1,235,841)
(45,594,419)

$(163,703,904)

Page 261 Line 37 Column a >

NOTE:

The following information concerning the consolidation
is furnished in accordance with the instructions
on page 261:

(a)
The Company is a member of a consolidated group, FPL Group,
Inc. and Subsidiaries, which will file a consolidated Federal
Income Tax Return for 1996.
(b)
Basis of allocation to the consolidated tax group members:
The consolidated income tax has been allocated to Florida
Power & Light Company and its subsidiaries in accordance with the
IRC section 1552 (a) (2) Reg.1.1502-33 (d) (2) (ii) and a tax sharing
agreement with members of the consolidated group. Under this tax
sharing agreement, Florida Power & Light Company and its
subsidiaries are allocated income taxes on a separate return
basis. The income taxes allocated to Florida Power & Light
Company and its subsidiaries in 1996 are as follows:

Tax

Name
Florida Power & Light Company
Land Resources Investment Co.
FPL Enersys, Inc.
KPB Financial Corp.

390,422,153
355,288
568,834
282,233

TOTAL

391,628,508

Page 261 Footnote.2

 Year of Report
Date of Report
This Report 1$:
(Mo, Da, Y'r)
(1) [Xl An Original
Dec. 31, 1996
( 2 > [ A Resuomi ss ion
TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR
Enter the amounts in both columns (d) and (e). The balancing of
1. Give particulars (details) of the combined prepaid and
this page is not affected by the inclusion of these taxes.
accrued tax accounts and show the total taxes charged to
3. Include in column (d) taxes charged during the year, taxes
operations and other accounts during the year. Do not include
charged to operations and other accounts through (a) accruals
gasoline and other sales taxes which have been charged to the
credited to taxes accrued,(b)amounts credited to proportions of
accounts to which the taxed material was charged. If the actual
prepaid taxes chargeable to current year, and(c) taxes paid and
or estimated amounts of such taxes are know, show the
charged direct to operations or accounts other than accrued and
amounts in a footnote and designate whether estimated or actual
amounts.
prepaid tax accounts.
4. List the aggregate of each kind of tax in such manner that
2. Include on this page, taxes paid during the year and charged
direct to final accounts,(not charged to prepaid or accrued taxes).the total tax for each State and subdivision can readily be
ascertained.
BALANCE AT BEGINNING OF YEAR
Taxes
Taxes
Adjust·
Charged
Line
Kind of T~x
Taxes
PrepQid T~xes
Paid
(See Instruct1on 5)
(Include 1n
Dur1ng
Dur1ng
Accrued
No.
ments
Account 165)
(Account 236)
Ye&r
Year
NQme of Respondent
Florida Power & L1ght Company

(a)

1

FEDERAL

2

-------

3

INCOME TAXES

I

(b)

I

I

(d)

(C)

19,393,204

(f)

(e)

391,628,508

304,902,643

41,939,570

1,820,235
41,447,586

55
672,798

18,329
663,439

679

8,008
1,253,794

7,329
1,197,356

679

435,502,733

350,056,917

26,959,743

55,190,113

59,642,820

4,534,249

(835,242)
10,951,120

3,699,007
72,961

141,816,124

32,982,586
108,932,349

3,048

3,048

811,402

816,741

(74,242)
4,939,949

2,381,896
2,261,226

4

5
6
7

FICA:
YEAR 1995
YEAR 1996

1,820,235

8

9 UNEMPLOYMENT:
1D
YEAR 1995
11
YEAR 1996
12
13 MOTOR VEHICLE
14 SUPERFUND TAX
15
16 SUBTOTAL
17
18 STATE
19
----2D
INCOME TAXES
21
22
UNEMPLOYMENT:
23
YEAR 1995
24
YEAR 1996
25
26 GROSS RECEIPTS:
27 YEAR 1995
28
YEAR 1996
29
3D
INTANGIBLE
31
32 MOTOR VEHICLES
33
34
PUBLIC SERVICE COMMISSION FEE
35
YEAR 1995
36 YEAR 1996
37
38 SALES TAX-CHARGED TO a/c 408
39
40
SUBTOTAL
41 TOT AL
FERC FORM N0.1 (ED. 12-96)

18,274

(219,202)
21,012,511

32,982,586

636,355

2,456,138

740,774 '*
66,932,716

636,355
Page 262

213,543,046

740,774
211,533 , 408

 of Respondent
Florida Power & L1ght Company

N~me

,......

Date of Report
(Mo, Da, Yr)

I

I

Year of Report
Dec. 31, 1996

TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR (Continued)
5. If any tax (exclude Federal and State income taxes)
8. Report in columns (i) through (l) how the taxes were
covers more than one year, show the required information
distributed. Report in column (i) only the amounts charged to
separately for each tax year,identifying the year in column(a). Accounts 408.1 and 409.1 pertaining to electric operations.
6. Enter all adjustments of the accrued and prepaid tax
Report in column (l) the amounts charged to Accounts 408.1 and
accounts in column (f) and explain each adjustment in a foot 409.1 perta1n1ng to other utility departments and amounts
note. Designate debit adjustments by parentheses.
charged to Accounts 408.2 and 409.2. Also show in column (l)
7. Do not include on this page entries with respect to dethe taxes charged to utility plant or other balance sheet
ferred income taxes or taxes collected through payroll deducaccounts.
tions or otherwise pending transmittal of such taxes to the
9. For any tax apportioned to more than one utility departtaxing authority.
ment or account, state in a footnote the basis (necessity) of
apportioning such tax.
BALANCE AT END OF YEAR
DISTRIBUTION OF TAXES CHARGED
Prepaid Texes
Extraordinary
Adjustment to
(Taxes Aq;rved
Electri~;
Line
Other
(Account 4!36)
Items
Ret. Earn1ogs
Oncl. 1n
(Acco~B~-~08.1,
No.
(Account 409.3)
(Account 4.59)
Account 165)
( 1)

(h)

(g)

(J)

(l)

(k)

1

2
387,515,268

106,119,069

*

4,113,240

3
4

5
0

491,984

31,659,691

0

55
550,815

*

10,279,879

.....

-

6
7
8
9

9,359
0

*

121,983

*

8,008

(162,764)

1,253,794

106,457,648

420,979,623

22,507,036

53,952,541

*

1, 237,572

0

(835,242)
10,940,944

*

10,176

*

2,996

10,878,159

14,523,110

0

141,816,124

32,883,775

.....

52

*

641,694

(74, 242)
4,939,949

0

2,678,723

740,774
68 , 947 , 693
FER C FORM N0 . 1 (ED. 12 -96)

64 1,694

211,480 , 900
Page 263

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
2, 062,146 40
41
Next Page 1s 266
811 ,402

 Year of Report
Date of Report
This Report Is:
(Mo, Da, Yr)
(1) [Xl An Or1ginal
Dec. 31, 1996
(2) [ A Resuemission
TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR
Enter the amounts in both columns (d) and (e). The balancing of
1. Give particulars (details) of the combined prepaid and
this page is not affected by the inclusion of these taxes.
accrued tax accounts and show the total taxes charged to
3. Include in column (d) taxes charged during the year, taxes
operations and other accounts during the year. Do not include
charged to operations and other accounts through (a) accruals
gasoline and other sales taxes which have been charged to the
credited to taxes accrued,(b)amounts credited to proportions of
accounts to which the taxed material was charged. If the actual
prepaid taxes chargeable to current year, and(c) taxes paid and
or estimated amounts of such taxes are know, show the
direct to operations or accounts other than accrued and
charged
amounts in a footnote and designate whether estimated or actual
amounts.
prepaid tax accounts.
2. Include on this page, taxes paid during the year and charged
4. List the aggregate of each kind of tax in such manner that
direct to final accounts,(not charged to prepaid or accrued taxes).the total tax for each State and subdivision can readily be
ascertained.
BALANCE AT BEGINNING OF YEAR
Taxes
Taxes
AdjustPaid
Charged
Prep9id T/ilxes
Taxes
Kind of T/i!X
Line
ments
Durmg
Dur1ng
(Include
1
n
Accrued
5)
(See
Instruct1on
No.
Year
Yee~r
Account 165)
(Account 236)
(f)
(e)
(d)
(c)
(b)
(a)
1 LOCAL
2 -- --28,461,958
23,353,422
10,622,443
FRANCHISE PREPAID
3
N9me of Respondent
Florida Power & L1ght Company

4
5 FRANCHISE ACCRUED:
6 YEAR 1995
7 YEAR 1996
8
9 OCCUPATIONAL LICENSES
10
11 REAL & PERSONAL PROPERTY TAX:
12
YEAR 1995
YEAR 1996
13
14
SUBTOTAL
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 40
41 TOTAL
FERC FORM N0.1 (ED. 12·96)

I

I

I

193,971,875

44,074,375
152,038,316

46,966

46,051

69,341
177,871,108

69,341
166,965,360

44,074,375

, ,575

44,074,375

10,624,018

395,312,712

391,655,401

$132,019,602

$11,261,052
Page 262.1

$1,044,358,491

$953,245,726

0

 of Respondent
Florida Power & L1ght Company

N~me

I

I

Date of Report
(Mo, Da, Y'r)

I

Year of Report
Dec. 31, 1996

TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR (Continued)
8. Report in columns (i) through (l) how the taxes were
5. If any tax (exclude Federal and State income taxes)
distributed. Report in column (i) only the amounts charged to
covers more than one year, show the required information
separately for each tax year,identifying the year in column(a). Accounts 408.1 and 409.1 pertaining to electric operations.
Report in column (l) the amounts charged to Accounts 408.1 and
6. Enter all adjustments of the accrued and prepaid tax
409.1
perta1n1ng to other utility departments and amounts
accounts in column (f) and explain each adjustment in a footcharged
to Accounts 408.2 and 409.2. Also show in column (l)
note. Designate debit adjustments by parentheses.
the taxes charged to utility plant or other balance sheet
7. Do not include on this page entries with respect to deaccounts.
ferred income taxes or taxes collected through payroll deduc9. For any tax apportioned to more than one utility departtions or otherwise pending transmittal of such taxes to the
ment or account, state in a footnote the basis (necessity) of
taxing authority.
apportioning such tax.
BALANCE AT END OF YEAR
DISTRIBUTION OF TAXES CHARGED
(Taxes Actrued
Prepaid T~xes
Extraordinary
Electrit
Adjustment to
(Account 256)
(lncl. 1n
Items
Ret. Earn10gs
Other
Line
<Acco~8~.toa.1,
Account 165)
(Account 409.3)
(Account 459)
No.
(g)

(h)

( 1)

(I<)

( J)

( l)

1

15,730,979

2
3

23,353,422

4
5
0

41,933,559

194,861,993
660

*

(890,118)

46,966

6
7
8
9

10
11
0

291,915
176,957,590

10,905,748
52,839,307

I
$228,244,648
FER C FORM NO. 1 ED. 12-96

15,731,639

$16,373,333

*
*

395,511,886

(222,574)
913,518
(199,174)

$1,027 ,972,409

0

Page 263 . 1

0

I

$16,386,082
Next Page 1s 266

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

 <

Page 262 Line 38 Column e

>

Sales and Use Taxes accrued on energy consumed by the Company and
other taxable internal consumption are credited to account 241 Tax Collections Payable.

<

Page 263 Line 3 Column 1 >

Account 409.2 - $4,113,240

<

Page 263 Line 7 Column 1 >

Accounts 107 & 108 - $ 7,329,385
3,067,852
Account 186
(148,736)
Account 234
31,378
Other Accounts
Total Other

<

$10,279,879

Page 263 Line 11 Column 1 >

Accounts 107 & 108 - $121,983

<

Page 263 Line 13 Column 1 >

Transportation Expenses Clearing, Account 703 - $8,008

<

Page 263 Line 20 Column 1 >

Account 409.2 - $1,237,572

<

Page 263 Line 24 Column 1 >

Accounts 107 & 108 - $

<

10,176

Page 263 Line 30 Column 1 >

Account 408.2 - $2,996

Page 262-263 Footnote.1

 <

Page 263 Line 32 Column l

Account 703 - $811,402

<

>

(Transportation Expenses Clearing Account )

Page 263.1 Line 7 Column l

>

Account 182 - $(878,514)
Account 254 ( 11, 604)
Total Other

$(890,118)

,.....
<

Page 263.1 Line 12 Column l

>

Account 143 - $(222,574)

<

Page 263.1 Line 13 Column l

Account 408.2
- $
Account 143
Other Accounts Total Other

>

309,910
600,768
2,840
$913,518

Page 262-263 Footno te.2

 of Respondent
Florida Power & L1ght Company

N~me

Year of Report
Dec. 31, 1996

Report below information applicable to Account 255.
Where appropriate,segregate the balances and transactions by utility and nonutility operations.Explain by
Line

Account

Deferred
Account No.

Bal<Jnce at
Beg1 nm ng
of Year
(b)

(c)

footnote any correction adjustments to the account balance shown in
column(g).Include in column(i) the average period over wh i ch the tax
credits are amortized.
Allocations to
for Year
Current Year's Income
Adjustments
Amo1..1nt
Account No.
(d)

(e)

0

13,888,579

411.4

0

203,056,138

411.4

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

47
48

FERC FORM N0.1 (ED. 12-89)

Page 266

(g)

 Year of Report
Dec. 31, 1996

Bala~ce

En
of Year

at

Averf~e

Peri ad
of A ocat1on
to Income
( i)

(h)

Line
No.
1
2
3
4
5

0
10,862,112 22 Years
0
180,821,429 22 Years
58,957,56 22 Years

~

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
47
48

0
0

r-

FERC FORM NO.1 (ED. 12-89)

Page 267

Next Page is 269

  Page 266 Line 7 Column 

8% Investment Tax Credits

Page 266-267 Footnote.l

T~h~ll.sfXRJepAort
Is: . l
n 0 r1g1na

Date of Report
Year of Report
(Mo, Da, Yr)
Dec. 31, 1996
A Resuemission
OTHER DEFERRED CREDITS (Account 253)
1. Report below the particulars (details) called for
3. Minor items (5% of the Balance End of Year for Acconcerning other deferred credits.
count 253 or amounts less than $10,000, whichever is
2. For any deferred credit being amortized, show the
greater) may be grouped by classes.
period of amortization.
Line
Bal9nce at
DEBITS
Description of Other
Beg1 nm ng
Credits
Balanc;e at
No.
Deferred Cred1ts
of Year
End of Year
Contra
Amount
Account
of Respondent
Florida Power & L1ght Company

N~me

I

(a)

(b)

1 LONG TERM WORKERS COMPENSATION
2 ll AB Ill TY FPL Employees
3

(C)

I

I

(f)

(e)

(d)

21,516,734

*

3,719,464

77,235,511

555

2,128,824

26,699,405

*

5,438,617

29,000,000

232

11,865,918

*

2,611,781

20,409,051

409,338

75,516,025

4
5

6 ST. JOHNS RIVER POWER PARK7 * Deferred Interest Payment
.)<> Qd _J_..
~

:.)

8

9

1 c

10 ENVIRONMENTAL CLAIMS
11
12
13 LEGAL EXPENSES
14 lt:>T.L;'1 IV ..><-<- IT-> "~ r
15
...
16 INTERCONNECTION PROJECTS
17
18
19 MINOR ITEMS
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43

,

W.d e.J.
45·,968,895

55,229,683

11,876,000

12,057,379

29,181,379

17,797,178

7,032,062

1,100,802

74,315,336

79,651,947

36,306,137

0 '(""' !"

4.s
30,969,526

44

45
46
47
"ER

TOTAL
'ORM N0. 1 (ED. 12-88)

$1 97_._ 287,094 -~-$;'1_115_:_,2___:_75,4_
11'9..1....__$_113_.:_5.',_73>_.:.
1,____.1.
402 _ _$2117.:._
_ , 74_3'.:._
, '077__J
Page 269

Next Page i s 272

 <

Page 269 Line 3 Column c >
228.2
242
253
925

1,766,063
690,900
301,607
960,894
3,719,464

< Page 269 Line 7 Column a

>

The Deferred Interest Payments are being amortized over the original life of the St. Johns River Power Park Bonds (1987-2020).

< Page 269 Line 10 Column c

108
154
184
186
232

>

80
73,594
36,477
170,756
5,157,710
5,438,617

< Page 269 Line 16 Column c

107
108
143
184
232
253
421
451
456
571
583
584
593
596
935

>

11,191,468
532,649
152,581
100,942
1,157,614
2,673,908
97,547
1,253,428
96,798
503,353
160
2
29,091
2,902
4,735

----------

17,797,178

Page 269 Footnote.1

 Year of Report
Dec. 31, 1996

Name of Respondent
Florida Power & L1ght Company

to property not subject to accelerated amortization.
2. For Other (Specify),include deferrals relating to other

1. Report the information
concerning the
respondent's accounting for deferred income taxes relating
Line
No.

Account

Bal<tnce at
Beg1nn1ng
of Year

Subdivisions

(b)

FERC FORM N0.1 (ED. 12-96)

Page 274

Amounts
Deb1 ted t
Account 41 . 1
(C)

8

 of Respondent
Florida Power & L1ght Company

Year of Report
Dec. 31, 1996

N~me

income and deductions.
3. Use footnotes as required .
Amol,lnts
Deb1ted to
Account 410.2

Amounts
Cred1ted tQ
Account 411.Z

(e)

(f)

Balance at
End of Year

ACCOI,lnt
Cred1ted
(g)

(k)

NOTES( Continued)

FERC FROM N0.1 (ED. 12-96)

Page 275

Line
No.

 <

Page 275 Line 2 Column i

Account
Debited

Amount

--- - ---

------

2.54
282

$

8,595,215
331,219

$

8,926,434

>

Page 274-275 Footnote.1

 of Report
Da, vn

of Respondent
Florida Power & L1ght Company

N~me

1. Report the information called for below concerning the
respondent's accounting for deferred income taxes relating

Line
No.

FERC FORM NO . 1 (ED. 12-96)

Year of Report
Dec. 31, 1996

to amounts recorded in Account 283.
2. For Other (Specify), include deferrals relating to other

Account Subdivisions

Page 276

 Name of Respondent
Florida Power & L1ght Company

Year of Report
Dec. 31, 1996

income and deductions.
3. Provide in the space below explanations for page 276

to insignificant items
listed under Other.
4. Use footnotes as

required.
BalanGe at
End of Year

NOTES (Continued)

FERC FORM NO . 1 (ED. 12- 96 )

Page 277

Line
No.

 <

Page 276 Line 7 Column a

>

Balance at
Beginning
of Year

Account Subdivisions

810,616
Interconnection Homestead
643,407
Involuntary Conversions
33
Deferred Conservation Costs
0
Pension SFAS 87
0
FPSC Rev Int Sec 1341 Adj
0
Excess Deferred Taxes Sec 1341
0
Nuclear Thermal Uprate
(137,803)
Interest on Audit Adjustments
1,086,103
Other
2,402,356

Page 277 Line 7 Column g

Amounts
Credited to
a / c 411.1
(d )

(c )

(b)

(a)

<

Amounts
Debited to
a / c 410.1
0

1 9 ,623

0

0

5,731,630
8,495,389

836,674

0

0

0
0
0
0

70,524,427

70,442,650

91,148,516

71,298,947

0

3,210,275
3,186,795

>

See Note for Page 277, Line 7, Column k.

<

Page 277 Line 7 Column i

>

See Note for Page 277, Line 7, Column k.

<

Page 277 Line 7 Column k

Amounts
Debited
a/c 410.2
(e)

(1)

Amounts
Debits
Credits
Credited Account
Amount Account Amount
a/c 411.2 Credited
Debited
(j )
(f)
(g)
(h)
( i)

0
0
0
0
0
0
0
0
252,637

0
0
0
0
0
0
0
0
70,977

252,637

70,977

190
254

>

254
( 1)
254

190

526,929
16,490
32
0
0
0
0
0
564,994
1,108,445

(2)
190
190
( 3)
254

Balance at
End of
Year
(k)

0
264,064
0
626,917
0 5,731,631
3,271,583 10,930,298
9,523,445 9,523,445
2,953,169 6,163,444
0 3,186,795
137,804
1
695,131 1,479,677
16,581,132 37,906,272

16,133
357

Page 276-277 Footnote.1

 (2)

(3)

190
254

190
254

3,246,410
25,173

132,524
5,280

 

Page 276?277 Footnote.2

 

of Respondent
Florida Power & L1ght Company

N~me

l

n~s[~elp~~to~~~inal_
(2) [ A Resucmiss1on

OTHER REGULATORY LIABILITIES
1. Reporting below the particulars (details) called for
3.
concerning other regulatory liabilities which are
created through the ratemaking actions of regulatory
agencies (and not includable in other amounts).
2. For regulatory liabilities being amortized, show
period of amortization in column (a).
Line
No.

Year of Report
Dec. 31, 1996

(Account 254)
Minor items ( 5% of the Balance at End of Year for Account
254 or amounts less than $50,000, whichever is less) may be
grouped by classes.

Accovnt
Cred1 ted

(a)

I

Date of Report
(Mo, Da, Yr)

DEBITS

De~cription and Purpos~ of
Other Regulatory Liab1 lit1es

1 Deferred Interest Income - Tax Refunds
2 (5 year amortization - various periods)

1

(b)

Credits

Amount
(c)

Balance at
End of Year

(d)

(e)

419

$153,244

0

$298,261

926

3,908,400

0

3,908,426

106
421.1

382
707,629

1'763,872

2,565,343

182.3
408.1

38,830
2,731,153

3,660,100

2,948,283

3

4 Deferred Pension Credit
5 (5 year amortization Jan. 1993 to Dec. 1997)
6

7 Deferred Gains on Sale of land
8 (5 year amortization - various periods)
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

Overrecovered Franchise Fees

Overrecovered Capacity Clause Revenues

456

35,469,942

26,318,990

60,400,772

Deferred Regulatory Assessment Fees

456

40,627

25,352

50,354

0

180' 164

914,665

190
282
283

31,211,964
16,279,057
1,529,952

0

391,967,314

Various

13,282,666

4,091,404

48

Deferred Gain on Sale of Emission Allowances
Regulatory Liabilities-Deferred Income Taxes

Minor Items

~4_>1~1T_~T_
AL ___________________~~----~~--$S1_05>,~,35~3>,~846_ _ _$~36,,0~39,88~2~$~4~>,0=S~~~~

FERC FORM N0.1 (ED. 12-94)

Page 278

Next Page is 300

 Date of Report
(Mo, Da, Yr)

of Respondent
Florida Power & L1ght Company

N~me

1. Report below operating revenues for each prescribed
account, and manufactured gas revenues in total.
2. Report number of customers, columns (f) 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

Line
No.

FERC FORM N0.1 (ED. 12-96)

Year of Report
Dec. 31, 1996

for each group of meters added. The average number of
customers means the average of twelve figures at the close
of each month.
3. If increases or decreases from previous year (columns
(c),(e), and (g)), are not derived from previously reported
figures, explain any inconsistencies in a footnote.

Title of Account

Amount for
(b)

Page 300

Year

 of Respondent
Florida Power & L1ght Company

N~me

of Report
Da, Yr)

4. Commercial and Industrial Sales,
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 Uniform System of Accounts. Explain basis of classification in a footnote.)

Line 12, Column (b) includes$
Line 12, Column (d) includes

ERC FORM N0.1 (ED. 12-96)

Year of Report
Dec. 31, 1996

During Year, for
important new territory added and important rate increases
or decreases.
6. For lines 2,4,5,and 6, see page 304 for amounts relating to unbilled revenue by accounts.
7. Include unmetered sales. Provide details of such sales
in a footnote.

0 of unbilled revenues.
0 MWH relating to unbilled revenues.

Page 301

Next Page i s 304

 <

Page 300 Line 21 Column b

>

Includes $5,385,909 net change in unbilled revenues for 1996.

<

Page 300 Line 21 Column c

>

Includes $38,704,740 net change in unbilled revenues for 1995.

<

Page 301 Line 14 Column d

>

Does not include the increase in energy delivered to customers
but not billed of 92,120 MWH for 1996.

<

Page 301 Line 14 Column e

>

Does not include the increase in energy delivered to customers
but not billed of 832,218 MWH for 1995.

Page 300-301 Footnote.1

 of Respondent
Florida Power & L1ght Company

N~me

This Report Is:

Date of Report
(Mo, Da, Yr)

(1)
fXJ An
Or1ginal
( 2)
A ResuExni ss ion
I
I
SALES OF ELECTRICITY BY RATE SCHEDULES

I

Year of Report
Dec. 31, 1996

1. Report below for each rate schedule in effect during
tion (such as a general residential schedule and an off
the year the M~h of electricity sold, revenue, average
peak water heating schedule), the entries in column (d) for
number of customers, average K~h per customer, and average
the special schedule should denote the duplication in
revenue per K~h, excluding data for Sales for Resale which
number of reported customers.
is reported on pages 310-311.
4 . The average number of customers should be the number
2. Provide a subheading and total for each prescribed
of bills rendered during the year divided by the number of
operating revenue account in the sequence followed in
billing periods during the year (12 if all billings are
"Electric Operating Revenues," pages 300-301. If the sales
made monthly).
under any rate schedule are classified in more than one
5. For any rate schedule having a fuel adjustment
revenue account, list the rate schedule and sales data under
clause state in a footnote the estimated additional revenue
each applicable revenue account subheading.
billed pursuant thereto.
3. ~here the same customers are served under more than
6. Report amount of unbilled revenue as of end of year
for each applicable revenue account subheading.
one rate schedule in the same revenue account classificaK~h of Sales
Revenue P,er
Line
Average Number
No. Number and Title of Rate Schedule
M~h Sold
of Customers
per Customer
K~h SolCl
Revenue
(a)

,......

RESIDENTIAL
5 11
6 44
7 45
8 TOTAL

(b)

(C)

(f)

(e)

(d)

40,900
41,251,744
8,886
41,301,530

7,300,323 *
3,315,859,892
643,628
3,323,803,843

4,906
3,147,428
292
3,152,626

8,336
13,106
30,431
13,100

17.8492¢
8.0381¢
7.2431¢
8.0476¢

64,167
4,693,836
3,624
16,802,870
171,451
4,676,683
1,776,561
215,326
608,318
88,925
71,630
55,543
1,372
1,765,851
16,532
18,124
462
13,922
27,847
30,960
651
65
4, 730
39,695
37,418
30

7,844,462 *
399,635,392
277,469
1,135,525,566
13,339,576
289,700' 711
99,792,022
13,508,156
34,188,528
5,701 '938
4,136,054
3,008,240
70,799
91,798,721
986,774
1,047,312
27,614
769,124
1,487,805
1 ,699,161
214,543
6,904
308,434
2,553,051
7,392,338
2,151

2,573
300,091
186
71,235
1 '177
1,511
360
17
37
29

6

24,938
15,641
19,483
235,879
145,667
3,095,091
4,934,891
12,666,235
16,441,027
3,066,379
17,907,500
5,554,300
1,372,000
5,383,692
5,510,666
4,531,000
462,000
13,922,000
13,923,500
30,960,000
325,500
65,000
4,730,000
39,695,000
11,404
5,000

12.2250¢
8.5140¢
7.6564¢
6.7579¢
7.7804¢
6.1945¢
5.6171¢
6.2733¢
5.6201¢
6.4120¢
5.7741¢
5.4160¢
5.1602¢
5.1985¢
5.9688¢
5.7785¢
5.9770¢
5.5245¢
5.3427¢
5.4882¢
32.9559¢
10.6215¢
6.5208¢
6.4316¢
19.7561¢
7.1700¢

31,2~t:He

2. ,Jd8~:~rg

380,86~

81,948

~J~~~~

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

COMMERCIAL
11
68

69
72
70
62
64
63
65
73
71
74
75
54-56
570
571
572
574
575
577
85
851
852
853
87
86

~~ ~gTAL
41 Total Billed
4
To tal Unbilled Rev .(See Ins tr. 6)
' ..
TOTAL
FERC FO Rt~ N0.1 (ED. 12-95)

Page 304

4

10
1

328
3
4

1
1
2

1
2

1

1
1

3,281

Next Page 1s 310

 Year of Report
Date of Report
This Report Is: .
(Mo, Da, Yt-l
( 1 ) [XJ An Or 1g1na l
Dec. 31, 1996
(2) [ A Resubmission
SALES OF ELECTRICITY BY RATE SCHEDULES
tion (such as a general residential schedule and an off
1. Report below for each rate schedule in effect during
peak water heating schedule), the entries in column (d) for
the year the M~h of electricity sold, revenue, average
the special schedule should denote the duplication in
number of customers, average K~h per customer, and average
number of reported customers.
revenue per K~h. excluding data for Sales for Resale which
4. The average number of customers should be the number
is reported on pages 310-311.
of bills rendered during the year divided by the number of
2. Provide a subheading and total for each prescribed
billing periods during the year (12 if all billings are
operating revenue account in the sequence followed in
made monthly).
"Electric Operating Revenues," pages 300-301. If the sales
5. For any rate schedule having a fuel adjustment
under any rate schedule are classified in more than one
clause state in a footnote the estimated additional revenue
revenue account, list the rate schedule and sales data under
billed pursuant thereto.
each applicable revenue account subheading.
3. ~here the same customers are served under more than
6. Report amount of unbilled revenue as of end of year
for each applicable revenue account subheading.
one rate schedule in the same revenue account classificaAverage Number
Line
K~h of Sales
Revenue P,er
of Customers
per Customer
Revenue
No. Number and Title of Rate Schedule
M~h Sold
K~h SolCl
of Respondent
Florida Power & L1ght Company

N~me

(a)

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

41
42
i 43
FERC

INDUSTRIAL
11
68
69
72
70
62
64
63
65
91
73

71
74
75
52
54
55

56
570
571
575
579
85
852
853
TOTAL

PUBLIC STREET & HIGHWAY LIGHTING
87
86
TOTAL

Total Billed
Total Unbilled Rev.(See lnstr. 6)
TOTAL
FORM N0.1 (ED. 12-95)

I

(c)

(b)

I

I

559
80,431
230
474,765
12,354
290,086
176,138
69,557
268,019
17,099
42,157
19,740
12,704
21,990
619
934,713
1,146,592
34,681
12,888
12,938
40,235
25.170
88,119
2,390
7,762
3,791,936

62,281
7,563,268
20,435
34,379,182
1,205,456
18,520,949
9,916,113
4,225,117
14,821,285
1, 298,110
2,752,595
1,066,633
696,343
1,203,978
70,130
46,335,587
45,968,529
2,039,763
758,906
685,521
1,875,118
1,197,327
5,917,658
192,537
420,346
203,193,167

295,802
72,296
368,098

42,742,661
5,089,425
47,832,086

Page 304.1

(e)

(d)

*

(f)

14,781

69,875
6,549
6,571
239,417
87,617
3, 153,108
5,681,870
9,936,714
19,144,214
17,099,000
2,342,055
19,740,000
3,176,000
10,995,000
619,000
8,902,028
81,899,428
1,651,476
4,296,000
6,469,000
10,058,750
25,170,000
8,811,900
2,390,000
7,762,000
256,541

11.1415¢
9.4034¢
8.8847¢
7.2413¢
9.7576¢
6.3846¢
5.6297¢
6.0743¢
5.5299¢
7.5917¢
6.5293¢
5.4034¢
5.4812¢
5.4751¢
11.3295¢
4.9571¢
4.0091¢
5.8814¢
5.8884¢
5.2985¢
4.6604¢
4.7569¢
6.7155¢
8.0559¢
5.4154¢
5.3585¢

1,638
522
2,160

180,587
138,498
170,415

14.4497¢
7.0397¢
12.9943¢

8

12,281
35
1,983
141
92
31
7

14
1
18
1
4
2
1

105
14
21
3
2
4
1

10
1
1

Next Page 1s 310

 m

Year of Report
of Report
This Report Is:
(Mo, Da, Yr)
-1 Date
fXl A
An Resu
On~nal
Dec. 31, 1996
ission
SALES OF ELECTRICITY BY RATE SCHEDULES
1. Report below for each rate schedule in effect during
tion (such as a general residential schedule and an off
the year the MWh of electricity sold, revenue, average
peak water heating schedule), the entries in column (d) for
number of customers, average KWh per customer, and average
the special schedule should denote the duplication in
revenue per KWh, excluding data for Sales for Resale which
number of reported customers.
4. The average number of customers should be the number
is reported on pages 310-311.
of bills rendered during the year divided by the number of
2. Provide a subheading and total for each prescribed
billing periods during the year (12 if all billings are
operating revenue account in the sequence followed in
made monthly).
"Electric Operating Revenues," pages 300-301. If the sales
5. For any rate schedule having a fuel adjustment
under any rate schedule are classified in more than one
clause state in a footnote the estimated additional revenue
revenue account, list the rate schedule and sales data under
billed pursuant thereto.
each applicable revenue account subheading.
6. Report amount of unbilled revenue as of end of year
3. Where the same customers are served under more than
for each applicable revenue account subheading.
one rate schedule in the same revenue account classificaRevenue P,er
KWh of Sales
Average Nl.fllber
Line
KWh Soll:l
per Customer
of Customers
Revenue
MWh Sold
No. Number and Title of Rate Schedule
(f)
Name of Respondent
Florida Power & L1ght Company

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

,..-

OTHER SALES TO PUBLIC AUTHORITIES
19
90
TOTAL

RAILROADS AND RAILWAYS
80
TOTAL

I

(C)

(b)

(a)

~

I

(e)

(d)

289

74,092
69,582,250
1,998,193

9.8676¢
4.8710¢
5.0512¢

23
23

3,611,086
3,611,086

6.5843¢
6.5843¢

20,820
556,658
577,478

2,054,440
27,115,226
29,169,666

281

83,055
83,055

5,468,656
5,468,656

8

MEMO: TOTAL FUEL ADJUSTMENT
REVENUE-$ 1,598,278,173

u
41

Tot al Billed
Total Unbill e~

lnstr. 6) *

*
77,333,226
$5,725,754,733
3,550,742
21,779
7.4040¢
FERc-~ =~-o-_-1_(_E_D____1_2--9-5~)------------~------~~~~~--~P~a~g~e~30~4~.~2~---L--------~--~--L-----------~--~N~e~x~t~Pa~g~e~l~s~3~10
I

~2

TOT~ ,

~ .(See

 <

Page 304 Line 5 Column d

>

Average class code 11 users - 61,972

<

Page 304 Line 11 Column d

>

Average class code 11 users - 22,458

<

Page 304.1 Line 5 Column d

>

Average class code 11 users - 99

<

Page 304.2 Line 42 Column b >

Includes -0- MWH of Unbilled Revenues.

<

Page 304.2 Line 42 Column c >

Includes $-0- of Unbilled Revenues.

Page 304 Footnote.1

 Nfme of Respon~ent
L1ght Company
F orida Power

I

This Report Is:.
~~~ fXl An
Or1~nal
A Resu
ission

l

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31, 1996

SALES FOR RESALE (Account 447)

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 tong-term firm service which meet s the
definition of RQ service. For all transactions ident i f i ed
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 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 tong-term service from a designated generating
unit. "Long-term" means five years or longer. The ava i lability and reliability of service, aside from transmission
constraints, must match the availability and reliability of
designated unit.
IU - for intermediate-term service from a desgnated
generating unit. The same as LU service except that
"intermediate-term" means longer than one year but less
than five years .

1. Report all sales for resale <i.e. • sales to purchas ers
other than ultimate consumers) transacted on a settlement
basis other than power exchanges during the year. Do not
( i e.
transactions
report exchanges of electricity
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 affi t iation 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 add i tion, the
ret iabi l ity of requirements service must be the same as, or
second only to, the supplier's service to its own ultimate
consumers.
LF - for long-term service. "Long-term" means five years
that service cannot be
or longer and "firm" means
a

Line
No.
1
2
3
4
5
6
7
8

9
10
11
12
13

14

Name of Co~anA or _Public Authority
[Footno e ff1 1at1onsl
(a)
Florida Keys Electric Cooperative
Florida Keys Electric Cooperative
* Florida Municipal Power Agency
* Florida Municipal Power Agency
* Florida Municipal Power Agency
* Florida Municipal Power Agency
* Florida Municipal Power Agency
* Florida Municipal Power Agency
Ft. Pierce Utilities Authority
City of Homestead
City of Homestead
Utility Board City of Key West
Utility Board City of Key \.lest
City of New Smyrna Beach

FERC FORM N0 . 1 (REVISED. 12-90)

I

Stat~s-

t1ca
Ctasslficat1on
(b)
RQ
AD
RQ
AD
RQ
AD
RQ
AD
AD
RQ
AD
RQ
AD
AD

Rate
Sc ~1ule or
Tari
Number
(c)
130
130
PR3
PR3
PR3
PR3
PR3
PR3
PR3
PR3
PR3
F~RC

138
138

PR3

Page 310

Mont ~veragr
ty B1 t ing
Demand (Mil)
(d)
93
N/A
2.5
N/A
10.5
N/A
2.5
N/A
N/A
N/A
*
N/A
45
N/A
N/A

Actual Demand(MII)
Avera~e

*

Month y
NCP Demand
(e)
95
N/A
2.5
N/A
10.5
N/A
2.5
N/A
N/A
N/A
N/A
45
N/A
N/A

Avera~e

Month y
CP D~mand
(

*

)

93
N/A
2.5
N/A
10.5
N/A
2.5
N/A
N/A
N/A
N/A
45
N/A
N/A

 Nfme of Respon~ent
L1ght Company
F orida Power

This Report I~:
Date of Re~ort
Year of Report
(Mo, Da, Y )
~~~ fXl A
An Resu
Or1~nal
ission
Dec. 31, 1996
SALES FOR RESALE (Account 447) (Continued)
OS - for other service. Use this category only for those
demand in column (f). For all other types of service,
services
which cannot be placed in the above-defined
enter NA in columns (d), (e) and (f). Monthly NCP demand is
categories, such as all non-firm service regardless of the
the maximum metered hourly (60-minute integration) demand
length of the contract and service from designated units of
in a month. Monthly CP demand is the metered demand
less than one year. Describe the nature of the service in a
during the hour (60-minute integration) in which the
footnote.
supplier's system reaches its monthly peak. Demand reported
AD - for out-of-period adjustment. Use this code for any
in columns( e) and (f) must be in megawatts. Footnote any
accounting adjustments or "true-ups" for service provided
demand not stated on a megawatt basis and explain.
in prior reporting years. Provide an explanation in a
7. Report in column (g) the megawatthours shown on bills
footnote for each adjustment.
rendered to the purchaser.
4. Group requirements RQ sales together and report them
8. Report demand charges in column (h), energy charges in
starting at line m.mber one. After listing all RQ sales,
column (i), and the total of any other types of charges,
enter "Subtotal - RQ" in collllll"l (a). The remaining sales
including out-of-period adjustments, in column (j). Explain
may then be listed in any order. Enter "Subtotal-Non-RQ"
in a footnote all components of the amount shown in column
in column (a) after this listing. Enter "Total" in column
( j). Report in column (k) the total charge shown on bills
(a) as the last line of the schedule. Report subtotals and
rendered to the purchaser.
total for columns (g) through (k).
9. The data in column (g) through (k) must be subtotalled
5. In collllll"l (c), identify the FERC Rate Schedule or
based on the RQ/Non-RQ grouping (see instruction 4), and
Tariff Nunber. On separate lines, list all FERC rate
then totalled on the last line of the schedule. The
schedules or tariffs under which service, as identified in
"Subtotal - RQ" amount in column (g) must be reported as
collllll'l (b), is provided.
Requirements Sales For Resale on page 401, line 23. The
6. For requirements RQ sales and any type of service
"Subtotal - Non-RQ" amount in column (g) must be reported
involving demand charges imposed on a monthly (or longer)
as Non-Requirements Sales For Resale on page 401,line 24.
basis, enter the average monthly billing demand in collllll"l
10. Footnote entries as required and provide exptanations
(d). the average monthly non-coincident peak (NCP) demand
following all required data.
in colunn (e), and the average monthly coincident peak (CP)
REVENUE
Line
Megawafthours
Other Charges
Tot~l ($)
No.
Demand iharges
Energf'~harges
So d
<h+l+
(g)
(k
~h~
$11 •821 • 036
0 *
$14,673,599
$26,494,635
609,258
1
0
0
36,361
36,361
2
0 *
17,041
441,630
30,573
346,708
818,911
3
*
(2,218)
(2,218)
4
0
0
0 *
3,378,432
71,136
1,854.180
127,550 *
1,396,702
5
(11,910)
(11,910)
0
0
0 *
6
346,708
818,911
7
17,041
441,630
30,573
*
( 1 ,706)
( 1 ,706)
8
0
0
0 *
0
0 *
90
90
9
0
0
0
0 *
961
961
10
0
0
0 *
109
109
11
7,536,310
12,895,360
5,359,050
0 *
12
311,025
(183,824)
( 183 ,824)
0
0 *
13
0
0 *
385
14
0
0
385

I

I

I

m

FERC FORM N0.1 (ED. 12-91)

Page 311

p

Next Page is 320

 m

This Report Is:.
fXl A
An Resu
Or1~nal
ission
SALES FOR RESALE (Account 447)

Nfme of Respongent
F orida Power
L1ght Company

I

1
2
3
4
5
6
7
8
9
10
11

12
13

14

Name of C~anA O[ .Public Authority
[Footno e ff1 1at1onsJ
(a)
City of Starke
City of Starke
City of Vera Beach
* Seminole Electric Cooperative, Inc.
* Seminole Electric Cooperative, Inc.
* Seminole Electric Cooperative, Inc.
* Seminole Electric Cooperative, Inc.
* Seminole Electric Cooperative, Inc.
* Seminole Electric Cooperative, Inc.
SUBTOTAL-RQ
Florida Municipal Power Agency
Florida Municipal Power Agency
Florida Power Corporation
Ft. Pierce Utilities Authority

FE RC FORM N0.1 (REVISED. 12-90)

Stat~s-

cflea
ass1fi·
cat1on
(b)
RQ
AD
AD
RQ
AD
RQ
AD
RQ
AD
* OS
AD
OS
OS

I

Year of Report
Dec. 31, 1996

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 wh i ch 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 seller 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 f i ve years or longer . The availability and reliability of service, aside from transmission
constraints, must match the availabi lity and reliability of
designated unit.
desgnated
IU- for intermediate-term service from a
generating unit. The same as LU service except that
"intermediate-term" means longer than one year but l ess
than five years.

1. Report all sales for resale (i.e., sales to purchasers
other than ult i mate consumers) transacted on a settlement
basis other than power exchanges during the year. Do not
( i.e.,
transactions
report exchanges of electricity
involving a balancing of debits and credits for energy,
capacity,etc.) and any settlements for i mbalanced 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 ult i mate
consumers.
LF - for long-term service. "Long-term" means five years
or longer and "firm" means
that service cannot be

Line
No.

I

Date of Re~ort
(Mo, Da, Y )

FR2
FR2
FR2
FR2

Mont ~yeragf
y B1 ling
Demand (Mil)
(d)
1
N/A
N/A
258
N/A
.8
N/A
1.8
N/A

87
87
81
49

N/A
N/A
N/A
N/A

F~RC Rate
Sc 11ule or
Tari
Nl..mber

(C)

PR3
PR3
PR3
77
77

Page 310.1

Actual Demand( Mil)
Aver~~e

Mont y
NCP Demand
(e)

Aver~~e
Mont
y
CP Dr,and
(

)

N/A
N/A
258
N/A
.8
N/A
1.8
N/A

1
N/A
N/A
240
N/A
.4
N/A
1.6
N/A

N/A
N/A
N/A
N/A

N/A
N/A
N/A
N/A

1

 Nrme of Respon~ent
L1ght Company
F orida Power

This Report Is:

Or1~nal
ission
I ~~~ fXj AAnResu
I
SALES FOR RESALE (Account 447) (Continued)

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 "Subtotal-Non-RQ"
in col~.mn (a) after this listing. Enter "Total" in column
(a) as the last line of the schedule. Report subtotals and
total for columns (g) through (k).
5. In collllYl (c), identify the FERC Rate Schedule or
Tariff Nl.lllber. On separate lines, list all FERC rate
schedules or tariffs under which service, as identified in
collllYl (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 coll.llll1
(d), the average monthly non-coincident peak (NCP) demand
in column (e), and the average monthly coincident peak (CP)

,.....

Date of Re~ort
(Mo, Da, Y )

I

Year of Report
Dec. 31, 1996

demand in co l umn (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 megawatthours 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 (j). 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 subtotalled
based on the RQ/Non-RQ grouping (see instruction 4), and
then totalled on the last line of the schedule. The
"Subtotal - RQ" amount in col~.mn (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 exptanations
following all required data.
REVENUE

Megawafthours
So d
(g)

l.
I

7,460
0
0
305,067
0
161
0
6,936
0
1,345.125
14,249
0
245,905
574

FE RC FORM N0.1 (ED . 12-91)

Demand

~harges

~h~

$176,430
0
0
45,833,778
0
12,325
0
363,781
0
66,303,840
0
0
0
0

Other Charges

Energh~harges

$13,372
0
0
545,947
0
327
0
12,696
0
761,038
404,279
0
8,879,136
13,332

Page 311 . 1

g~

*
*
*
*
*
*
*
*
*
*

$160,429
80
30
6,807,972
94,384
3,489
79
142,719
334
31,347,791
0
125
0
0

Toti,ll ($)
(h+l+
(k
$350,231
80
30
53,187,697
94,384
16,141
79
519,196
334
98,412,669
404,279
125
8,879,136
13,332

p

Line
No.
1
2
3
4
5
6
7

8
9
10
11
12
13
14

Next Page is 320

 This Report Is:.
~~~ [Xj A
An Resu
Or1~nal
ission
SALES FOR RESALE (Account 447)

Nfme of Respon~ent
F orida Power
L1ght Company

I

1. Repo r t 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
( i.e.,
transactions
report exchanges of electricity
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 long-term service. "Long - term" means five years
that service cannot be
or longer and "firm" means

Line
No.
1
2
3
4
5

6
7
8
9
10
11
12
13
14

Name of C~anA Of . Public Authority
[Footno e ff1 1at1onsJ
(a)
City of Gainesville
City of Homestead
*Jacksonville Electric Authority
Utility Board City of Key llest
City of Lake llorth Utilities
City of Lakeland
City of New Smyrna Beach
*Orlando Utilities Commission
Orlando Utilities Commission
Reedy Creek Improvement District
Seminole Electric Cooperative, Inc.
Southern Company Services, Inc.
City of Starke
City of Tallahassee

FERC FORM N0 .1 (REVISED. 12-90)

Stat~s-

Cflea
ass1ficat1on
(b)
* OS
OS
OS
OS
OS
OS
OS
OS
AD
OS
OS
OS
OS
OS

I

Date of Re~ort
(Mo, Da, Y )

I

Year of Report
Dec . 31, 1996

interrupted for economic reasons and i s 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 seller 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 avail ability and reliability of service, aside from transmission
constraints, must match the availability and reliability of
designated unit.
IU - for intermediate- term service from a desgnated
generating unit. The same as LU service except that
"intermediate-term" means longer than one year but less
than five years.

F~RC Rate
Sc ~1ule or
Tari
Nl.lllber
(c)
27
22
31
9D
7
43
20
33
33
112
80
36
76
98

Page 310.2

Mont ~yeragf
y B1 ling
Demand (Mil)
(d)
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A

Actual Demand( Mil)
Aver~~e
Mont
y
NCP Demand
(e)
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A

Aver~~e
Mont
y
CP D~mand
(

)

N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A

 Nfme of Respon~ent
F orida Power
L1ght Company

This Report Is:

Or1~nal
j
ission
I ~~~ fXl AAn Resu
SALES FOR RESALE (Account 447) (Continued)

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 "Subtotal-Non-RQ"
in coll.ITln (a) after this listing. Enter "Total" in column
(a) as the last line of the schedule. Report subtotals and
total for columns (g) 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
coll1111'1 (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 co ll.ITln (e), and the average monthly coincident peak (CP)

Date of Re~ort
(Mo, Da, Y )

l

Year of Report
Dec. 31, 1996

demand i n column (f). For all other types of serv i ce ,
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 megawatthours 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 (j). 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 subtotalled
based on the RQ/Non-RQ grouping (see instruction 4), and
then totalled on the last line of the schedule. The
"Subtotal - RQ" amount in coll1111'1 (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 exptanations
following all required data.
REVENUE

Mega~g[ahours

(g)

*

24,457
10,850
28,403
3,979
11,095
1,505
1,166
80,352
8
679
43,394
448,649
465
4,104

FERC FORM N0.1 (ED. 12-91)

Demand iharges

Other Charges

EnergrT~harges

~h~

0
0
0
0
0
0
0
0
0
0
0
0
0
0

$699,295
318,662
752,921
86,471
328,595
37,776
50,320
2,305,345
0
15,336
1,376,008
15,682,024
17,097
122,251

Page 311.2

a~

*

0
0
0
0
0
0
0
0
84
0
0
0
0
0

Tot<tl ($)
(h+l+~)
(k
$699,295
318,662
752,921
86,471
328,595
37,776
50,320
2,305,345
84
15,336
1,376,008
15,682,024
17,097
122,251

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13

14

Next Page i s 320

 m

This Report I$: .
fXl A
An Resu
Or1Elri,nal
ission
SALES FOR RESALE (Account 447)

Nfme of Respon~ent
F orida Power
L1ght Company

I

cons~ners.

Line
No.
1
2
3
4
5
6
7
8

9
10

,,

12
13
14

LF - for long-term service. "Long-term" means five years
that service
longer and 11 firm 11 means
cannot be

Name of c~anA O[.Public Authority
[Footno e ff1 1at1onsl
(a)
Tampa Electric Company
City of Vero Beach
Cat ex Vitol Electric, L.L.C.
Coral Power, L.L.C.
Delhi Energy Services, Inc.
Electric Clearinghouse, Inc.
Enron Power Marketing, Inc.
Florida Power Corporation
Ft. Pierce Utilities Authority
City of Gainesville
Heartland Energy Services, Inc.
City of Homestead
ICN Marketing, Inc.
Koch Power Services, Inc.

FE RC FORM N0.1 (REVISED. 12-90)

is-

Stat
Cf1ca
a$Slficat1on
(b)
* OS
OS
* OS
OS
OS
OS
OS
OS
OS
OS
OS
OS
OS
OS

I

Year of Report
Dec. 31, 1996

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 seller 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 desgnated
generating unit. The same as LU service except that
"intermediate-term" means longer than one year but less
than five years.

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
( i ~e.,
transactions
report exchanges of electricity
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

or

I

Date of Report
(Mo, Da, Yr)

F~RC Rate
Sc ?~ule
or
Tari
Nll!lber
(c)
23
44
151

*
171
150
162
143
126
147
149
127
166
148

Page 310.3

Mont ~yeragf
y 81 ling
Demand (Mil)
(d)
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A

Actual Demand(MII)
Aver~~e

Mont y
NCP Demand
(e)
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A

Avera~e

Month y
CP D?mand
(

)

N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A

 mfXJ AAnResu
Orl&:,nal
ission
I
I
SALES FOR RESALE (Account 447) (Continued)

Nfme of Respongent
F orida Power
L1ght Company

This Report Is:

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 "Subtotal-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 (g) 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)

Date of Re~ort
(Mo, Da, Y )

I

Year of Report
Dec. 31, 1996

demand in column (f). For all other types of s ervice,
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 megawatthours 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 (j). 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 subtotalled
based on the RQ/Non-RQ grouping (see instruction 4), and
then totalled 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 exptanations
following all required data.
REVENUE

Megawa[thours
So d
(g)
33,419
5,286
350
2,065
3,050
1,630
235,306
91,643
5,019
10,735
350
2,588
2,305
10,892

-

:RC

FORM N0. 1 (ED.12-91)

Demand

~harges

Energf charges

~~

~h~

0
0
0
0
0
0
0
0
0
0
0
0
0
0

$1,307,240
153,909
8,550
56,383
221,850
61,050
5,653,767
3,690,243
171,502
356,691
20,600
69,649
98,779
334,551

Page 311.3

Other Charges

g~

0
0
0
0
0
0
0
0
0
0
0
0
0
0

Tot<J l ($)
(h+l+~)
(k
$1,307,240
153,909
8,550
56,383
221,850
61,050
5,653,767
3,690,243
171,502
356,691
20,600
69,649
98,779
334,551

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14

Next Page i s 320

 m

This Report I$: .
fXl A
An Resu
Or1~nal
ission
SALES FOR RESALE (Account 447)

Nfme of Respon~ent
F orida Power
L1ght Company

I

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
( i.e.,
transactions
report exchanges of electricity
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 long-term service. "Long-term" means five years
or longer and 11 flrm 11 means
that service cannot be

Line
No.
1
2
3
4
5
6
7
8
9
10
,1
12
13
14

Name of C~anx O[.Public Authority
[Footno e ff1 1at1onsl
(a)
Utility Board City of Key llest
City of Lake llorth Utilities
LG&E Power Marketing Inc.
Louis Dreyfus Electric Power, Inc.
City of New Smyrna Beach
Oglethorpe Power Corporation
Orlando Utilities Commission
Rainbow Energy Marketing Corporation
Sonat Power Marketing Inc.
Tampa Electric Company
Tennessee Valley Authority
Tennessee Power Company
Valero Power Service Company
City of Vero Beach

rERC FORM N0.1 (REVISED. 12-90)

Stat~s-

Cflea
a$Slficat1on
(b)
* OS
OS
OS
OS
OS
OS
OS
OS
OS
OS
OS
OS
OS
OS

1

Date of Re~ort
(Mo, Da, Y )

I

Year of Report
Dec. 31, 1996

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 seller 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 ret iabi l ity of
designated unit.
desgnated
IU- for intermediate-term service from a
generating unit. The same as LU service except that
"intermediate-term" means longer than one year but less
than five years.

F~RC Rate
Sc 1~ule or
Tari
Nll!lber
(c)
129
131
159
152
132
125
128
156
158
114
153
155
168
134

Page 310.4

Mont ~yeragf
y B1 ling
Demand (Mil)
(d)
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A

Actual Demand( Mil)
Aver~~e

Mont y
NCP Demand
(e)
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A

Aver~~e
Mont
y
CP D1mand
(

)

N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A

 mfXl AAn Resu
Or1rx:,nal
ission
I
I
SALES FOR RESALE (Account 447) (Continued)

Nyme of Respon~ent
F orida Power
L1ght Company

This Report Is:

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 colUIIV1 (a). The remaining sales
may then be listed in any order. Enter "Subtotal-Non-RQ"
in coll.m'l (a) after this listing. Enter "Total" in collllln
(a) as the last line of the schedule. Report subtotals and
total for colllllns (g) through (le).
50 In coll.m'l (c), identify the FERC Rate Schedule or
Tariff Nunber. On separate lines, list all FERC rate
schedules or tariffs under which service, as identified in
collllln (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 coll.m'l
(d)' the average monthly non-coincident peale (NCP) demand
in collllln (e), and the average monthly coincident peale (CP)

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31, 1996

demand in column (f) 0 For all other types of service,
enter NA in columns (d), (e) and (f). Monthly NCP demand is
the maximum metered hourly (6D-minute integrat i on) 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 peal<. 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 megawatthours 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 (j). Explain
in a footnote all components of the amount shown in column
( j) 0 Report in column (le) the total charge shown on bills
rendered to the purchaser.
9. The data in column (g) through (le) must be subtotalled
based on the RQ/Non-RQ grouping (see instruction 4), and
then totalled on the last line of the schedule. The
"Subtotal - RQ" amount in collllln (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 exptanations
following all required data.
REVENUE

Megawafthours
So d
(g)
70,457
10,136
3, 700
108,632
5,369
82,113
14,436
300
4
36,898
25,888
10,172
100
6,335

FERC FORM N0.1 (ED. 12-91)

Demand iharges

Energr,~harges

~h~

0
0
0
0
0
0
0
0
0
0
0
0
0
0

$2,048,053
322,332
118,223
3,212,600
221,268
2,798,452
469,554
10,062
98
1 ,687, 777
986,352
661 '180
2,425
227,410

Page 311 .4

Other Charges

l ($)
(h+l+p
(le
$2,048,053
322,332
118,223
3,212,600
221,268
2,798,452
469,554
10,062
98
1 ,687, 777
986,352
661,180
2,425
227,410

Tot~

g~

0
0
0
0
0
0
0
0
0
0
0
0
0
0

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14

Next Page is 320

 Nfme of Respongent
F orida Power
L1ght Company

m

This Report Is:
fXl A
An Resu
Or1~nal
ission
SALES FOR RESALE (Account 447)

I

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
( i.e.,
report exchanges of electricity
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 aff i l i at ion 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
conslJTlers.
LF - for long-term service. "Long-term" means five years
or longer and 11 firm 11 means
that service
cannot be

Line
No.
1
2
3
4
5
6

7
8
9
10
11
12
13
14

Name of C~anx or.Public Authority
[Footno e ff1 1at1onsl
(a)
lies tern Gas Resources Power Marketing
City of New Smyrna Beach
Florida Municipal Power Agency
Florida Municipal Power Agency
Orlando Utilities Commission
Orlando Utilities Commission
Seminole Electric Cooperative, Inc.
Seminole Electric Cooperative, Inc.
Dade County Resource Recovery
Dade County Resource Recovery
Florida Keys Electric Cooperative
Florida Keys Electric Cooperative
Florida Municipal Power Agency
Florida Municipal Power Agency

FERC FORM N0.1 (REVISED. 12-90)

I

Date of Re~ort
(Mo, Da, Y J

I

Year of Report
Dec. 31, 1996

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 seller 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 desgnated
generating unit. The same as LU service except that
"intermediate-term" means longer than one year but less
than five years.

FSRC Rate
Stat~sSc ~~ule or
c(lea
asslfi Tar1
Number
cat1on
(C)
(b)
164
* OS
20
* IF
LU
72
AD
72
LU
72
AD
72
77
* LF
AD
77
124
* LF
AD
124
130
* OS
AD
13D
92,93
* AD *
72
* LF

Page 310.5

Mont ~yeragf
y 81 ling
Demand (Mil)
(d)
N/A
10
N/A
N/A
N/A
N/A
N/A
N/A
1.4
N/A
N/A
N/A
N/A
N/A

Actual Demand( Mil)
Avera~e

Month y
NCP Demand
(e)
N/A
10
N/A
N/A
N/A
N/A
N/A
N/A
1.3
N/A
N/A
N/A
N/A
N/A

Aver~~e
Mont y
CP D~mand
(

)

N/A
10
N/A
N/A
N/A
N/A
N/A
N/A
.8
N/A
N/A
N/A
N/A
N/A

 m

Year of Report
This Report Is:
Date of Report
(Mo, Da, Yr)
fXl A
An Resu
Or1&\,nal
Dec . 31, 1996
ission
SALES FOR RESALE (Account 447) (Continued)
OS - for other service. Use this category only for , those
demand i n column (f). For all other types of serv i ce,
wh i cr cannot be placed in the above-defined
services
enter NA in columns (d), (e) and (f). Monthly NCP demand i s
categories, SU '
; all non-firm service regardless of the
the maximum metered hourly (60-minute integrat i on) demand
length of the c o r ract and service from designated units of
in a month. Monthly CP demand is the metered demand
less than one year. Describe the nature of the service in a
during the hour (60 -minute integration) i n which the
footnote.
supplier's system reaches its monthly peak. Demand reported
AD - for out-of-period adjustment. Use this code for any
in columns( e) and (f) must be in megawatts. Footnote any
accounting adjustments or "true-ups" for service provided
demand not stated on a megawatt basis and explain.
in prior reporting years. Provide an explanation in a
7. Report in column (g) the megawatthours shown on bills
footnote for each adjustment.
rendered to the purchaser.
4. Group requirements RQ sales together and report them
8. Report demand charges in column (h), energy charges in
starting at line number one. After listing all RQ sales,
column (i), and the total of any other types of charges,
enter "Subtotal - RQ" in column (a). The remaining sales
including out-of - period adjustments, in column (j). Explain
may then be listed in any order. Enter "Subtotal-Non-RQ"
in a footnote all components of the amount shown in column
in collllln (a) after this listing. Enter "Total" in column
( j). Report in column (k) the total charge shown on bills
(a) as the last line of the schedule. Report subtotals and
rendered to the purchaser.
tot a for columns (g) through (k).
9. The data in column (g) through (k) must be subtotalled
5. l n column (c), identify the FERC Rate Schedule or
based on the RQ/Non-RQ grouping (see instruction 4), and
Tariff Number. On separate lines, list all FERC rate
then totalled on the last line of the schedule. The
schedules or tariffs under which service, as identified in
"Subtotal - RQ" amount in column (g) must be reported as
column (b), is provided.
Requirements Sales For Resale on page 401, line 23. The
6. For requirements RQ sales and any type of service
"Subtotal - Non-RQ" amount in column (g) must be reported
involving demand charges imposed on a monthly (or longer)
as Non-Requirements Sales For Resale on page 401,line 24.
basis, enter the average monthly billing demand in colL1!11'1
10. Footnote entries as required and provide exptanations
(d), the average monthly non-coincident peak (NCP) demand
following all required data.
in column (e), and the average monthly coincident peak (CP)
REVENUE
Line
Tot<;~l ($)
Other Charges
Megawafthours
Demand ~harges
No.
Energf charges
So d
<h+l+
(g)
g~
(k
~h~
2,000
0
$88,120
$88,120
0
1
282,000
4,812
136,736
0
418,736
2
231,849
0
1,455,634
0
1,455,634
3
0
(298)
(298)
4
0
0 *
160,327
0
1,049,687
0
1,049,687
5
0
(59,712)
(59,712)
0
0 *
6
354
172,502
7
2,854
0
172,148 *
(9,837)
(9,837)
(435)
0
8
0 *
*
7,507
171,948
13,436 *
143,822
329,206
9
(10,551)
(10,551)
0
0
0 *
10
0
522,957
0
10,715
522,957
11
0
0
767
767
12
20
*
*
0
0 *
345
0
345
13
0
0 *
410
0
14
410
Nfme of Respon~ent
F orida Power
L1ght Company

I

I

p

'~

FERC FORM N0. 1 (EO . 12 -91)

I

Page 311.5

Next Page is 320

 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
( i.e.,
transactions
report exchanges of electricity
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
consiJllers.
LF - for long-term service. "Long-term" means five years
that service
cannot be
or longer and "firm" means

Line
No.
1
2
3
4
5

6
7
8
9
10
11
12
13
14

Name of C~anA Of_Public Authority
[Footno e ff1 1at1onsl
(a)
Florida Municipal Power Agency
Orlando Utilities Commission
Florida Power Corporation
City of Tallahassee
SUBTOTAL-NON-RQ
TOTAL

FERC FORM N0.1 (REVISED. 12-90)

l

I

This Report Is:.
~1~ fXl A
An Resu
Or1~nal
ission
SALES FOR RESALE (Account 447)

Nfme of Respon~ent
L1ght Company
F orida Power

Stat ist1ca
Class1ficat1on
(b)
AD
* AD
* OS
OS

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31, 1996

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 meet s 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 seller 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 avail ability and reliability of service, aside from transmission
constraints, must match the availability and reliability of
designated unit.
IU - for intermediate-term service from a desgnated
generating unit. The same as LU service except that
"intermediate-term" means longer than one year but less
than five years.

F~RC Rate
Sc ~1ule or
Tari
NIJllber
(c)
72
69
81
98

Page 310.6

Mont ~yeragr
y B1 ling
Demand (MU)
(d)
N/A
N/A
61
8

Actual Demand(MU)
Avera~e

Month y
NCP Demand
(e)
N/A
N/A
61
8

Aver~~e
Mont
y
CP D~mand
(

)

N/A
N/A
61
8

 Year of Report
This Report Is: .
Date of Re~ort
(Mo, Da, Y )
a~ fXl A
An Resu
Or1~nal
Dec. 31, 1996
ission
SALES FOR RESALE (Account 447) (Continued)
OS - for other service. Use this category only for those
demand in column (f). For all other types of service,
enter NA in columns (d), (e) and (f). Monthly NCP demand is
services
which cannot be placed in the above -defined
categories, such as all non-firm service regardless of the
the maximum metered hourly (60-minute integration) demand
length of the contract and service from designated units of
in a month. Monthly CP demand is the metered demand
less than one year. Describe the nature of the service in a
during the hour (60-minute integration) in which the
footnote.
supplier's system reaches its monthly peak. Demand reported
AD - for out-of-period adjustment. Use this code for any
in columns( e) and (f) must be in megawatts. Footnote any
accounting adjustments or "true-ups" for service provided
demand not stated on a megawatt basis and explain.
in prior reporting years. Provide an explanation in a
7. Report in column (g) the megawatthours shown on bills
footnote for each adjustment.
rendered to the purchaser.
4. Group requirements RQ sales together and report them
8. Report demand charges in column (h), energy charges in
starting at line number one. After listing all RQ sales,
column (i), and the total of any other types of charges,
including out-of-period adjustments, in column (j). Explain
enter "Subtotal - RQ" in colliTln (a). The remaining sales
may then be listed in any order . Enter "Subtotal -Non-RQ"
in a footnote all components of the amount shown in column
( j). Report in column (k) the total charge shown on bills
in coll.ITY1 (a) after this listing. Enter "Total" in column
(a) as the last line of the schedule. Report subtotals and
rendered to the purchaser.
total for columns (g) through (k).
9. The data in colliTln (g) through (k) must be subtotalled
based on the RQ/Non-RQ grouping (see instruction 4), and
5. In coll..rnfl (c), identify the FERC Rate Schedule or
then totalled on the last line of the schedule . The
Tariff Nl.mber. On separate lines, list all FERC rate
"Subtotal . RQ" amount in colliTln (g) must be reported as
schedules or tariffs under which service, as identified in
coll.ITY1 (b), is provided.
Requirements Sales For Resale on page 401, line 23. The
6. For requirements RQ sales and any type of service
"Subtotal - Non-RQ" amount in column (g) must be reported
involving demand charges imposed on a monthly (or longer)
as Non-Requirements Sales For Resale on page 401,line 24.
basis, enter the average monthly billing demand in column
10. Footnote entries as required and provide exptanations
(d), the average monthly non-coincident peak (NCP) demand
following all required data.
in colliTln (e), and the average monthly coincident peak (CP)
REVENUE
Line
Tot;;~ l ($)
No.
Other Charges
Demand iharges
Energf charges
Mega~~fahours
(h+l+~)
(g)
(k
~h~
$79
$79
1
0
0
0 *
27
27
2
0
0
0 *
0
36,639
3
120
22,997
13,642
41,801
4
20,735
21,066
0
237
60,096,119
5
497,680
65,615
2,119,018
59,532,824
158,508,788
6
60,293,862
31,413,406
3,464,143
66,801,520
0
7
0
8
0
9
0 10
0 11
0 12
0 13
0 14

Nfme of Respon~ent
L1ght Company
F orida Power

I

I

m

'~

0

ERC FORM N0.1 (ED. 12-91)

I

Page 311.6

Next Page is 320

 <

Page 310 Line 3 Column a

>

Florida Municipal Power Agency for the City of Green Cove Springs
THE FOLLOWING PORTION OF THIS NOTE APPLIES TO ALL OCCURANCES OF
"FLORIDA MUNICIPAL POWER AGENCY" ON PAGES 310 THROUGH 310.6:
St. Lucie Unit No. 2 is jointly owned by Florida Power & Light
Company (85.10449%), Florida Municipal Power Agency (8.806%)
and Orlando Utilities Commission (6.08951%).
1

<

Page 310 Line 4 Column a

>

Florida Municipal Power Agency for the City of Green Cove Springs

<

Page 310 Line 5 Column a

>

Florida Municipal Power Agency for the City of Jacksonville Beach

<

Page 310 Line 6 Column a

>

Florida Municipal Power Agency for the City of Jacksonville Beach

<

Page 310 Line 7 Column a

>

Florida Municipal Power Agency for the City of Clewiston

<

Page 310 Line 8 Column a

>

Florida Municipal Power Agency for the City of Clewiston

<

Page 310 Line 10 Column d

>

Columns (d)
(e) and (f) are not applicable because service was
terminated in 1995. Amounts billed in 1996 were for the 1995 FERC
Assessment Charge.
1

<

Page 310 Line 10 Column e

>

See footnote for page 3101 line 10, column (d).

Page 310-311 Footnote.1

 <

Page 310 Line 10 Column f

>

See footnote for page 310, line 10, column (d ) .

<

Page 310.1 Line 4 Column a

>

Seminole Electric Cooperative, Inc.
Partial Requirement Sale Agreement

<

Page 310.1 Line 5 Column a

- Aggregated Billing

>

Seminole Electric Cooperative, Inc. - Aggregated Billing
Partial Requirement Sale Agreement

<

Page 310.1 Line 6 Column a

>

Seminole Electric Cooperative, Inc. - Arcadia
Terminated as FR on January 2, 1996.

<

Page 310.1 Line 7 Column a

>

Seminole Electric Cooperative, Inc. - Arcadia
Terminated as FR on January 2, 1996.

<

Page 310.1 Line 8 Column a

>

Seminole Electric Cooperative, Inc. - Ft. Winder

<

Page 310.1 Line 9 Column a

>

Seminole Electric Cooperative, Inc. - Ft. Winder

<

Page 310.1 Line 11 Column b

>

THIS FOOTNOTE APPLIES TO LINES 11 - 14, COLUMN (b), PAGE 310.1:
Schedule CF Economy Energy Sales

<

Page 310.2 Line 1 Column b

TH I ~

>

lOTNOTE APPLIES TO LINES 1 - 14, COLUMN (b), PAGE 310.2:
Page 310-311 Footnote.2

 Schedule CF Economy Energy Sales

<

Page 310.2 Line 3 Column a >

Florida Power & Light Company and Jacksonville Electric Authority
are co-owners of St. Johns River Power Park, Scherer Unit No. 4,
and the Duval-Hatch and Duval-Thalmann 500KV transmission lines .

<

Page 310.2 Line 8 Column a

>

THIS FOOTNOTE APPLIES TO ALL OCCURANCES OF "ORLANDO UTILITIES
COMMISSION" ON PAGES 310 THROUGH 310.6:
St. Lucie Unit No. 2 is jointly owned by Florida Power & Light
Company (85.10449%), Florida Municipal Power Agency (8.806%),
and Orlando Utilities Commission (6.08951%).

<

Page 310.3 Line 1 Column b

>

THIS FOOTNOTE APPLIES TO LINES 1 - 2, COLUMN (b), PAGE 310.3:
Schedule CF Economy Energy Sales

<

Page 310.3 Line 3 Column b >

THIS FOOTNOTE APPLIES TO LINES 3 - 14, COLUMN {b), PAGE 310.3:
Opportunity Sales Contract

<

Page 310.3 Line 4 Column c >

No Rate Schedule Number Assigned, Contract Pending at FERC.

<

Page 310.4 Line 1 Column b

>

THIS FOOTNOTE APPLIES TO LINES 1 - 14, COLUMN {b), PAGE 310.4:
Opportunity Sales Contract

<

Page 310.5 Line 1 Column b

>

Opportunity Sales Contract
Page 310-311 Footnote.3

 <

Page 310.5 Line 2 Column b

>

Agreement terminated on May 31, 1996.

<

Page 310.5 Line 7 Column b

>

Contract expires May 21, 2004 or upon written notice to the other
party at least seven years in advance of the proposed date of
termination.

<

Page 310.5 Line 9 Column b

>

Contract expires October 31, 2013 or upon written notice of one
year.

<

Page 310.5 Line 11 Column b

>

Alternate economic energy. Florida Keys Electric Cooperative may
request Florida Power & Light Company to provide economic energy
to displace energy which would have been provided by Florida Keys
Electric Cooperative resources.

<

Page 310.5 Line 13 Column b

>

Services shall be provided until the earlier of the retirement of
Stanton Unit No. 1 or December 31, 2022.
Florida Power & Light Company was supplying generation to make up
for the transmission losses being billed for under the firm
transmission tariffs. This service was terminated on March 31,
1995.

<

Page 310.5 Line 13 Column c

>

Billing program does not provide a separation of rate schedules
for the losses portion of the bill.

<

Page 310.5 Line 14 Column b

>

Contract expires when St. Lucie Unit No.2 is decommissioned.
Florida Power & Light Company was supplying generation to make up
for the transmission losses being billed for under the firm
transmission tariffs. This service was terminated on March 31,
1995.
Page 3 10-311 Footnot e.4

 <

Page 310.6 Line 2 Column b

>

Contract expires when St. Lucie Unit No. 2 is decommissioned.

<

Page 310 . 6 Line 3 Column b

>

THIS FOOTNOTE APPLIES TO LINES 3 - 4, COLUMN (b), PAGE 310.6:
Schedule AF Emergency Energy Sales

<

Page 311 Line 1 Column j >

"Other charges" - customer charge, fuel adjustment, fuel
adjustment true-up, as applicable, relating to 1996 transactions.

<

Page 311 Line 2 Column j

>

"Other charges" - fuel adjustment true-up, demand charge true-up,
variable O&M true-up, as applicable, relating to 1995
transactions.

<

Page 311 Line 3 Column j >

"Other charges" - customer charge, fuel adjustment, fuel
adjustment true-up, as applicable, relating to 1996 transactions
and 1995 FERC Assessment Charge.

<

Page 311 Line 4 Column j >

"Other charges'' - fuel adjustment true-up, demand charge true-up,
variable O&M true-up, as applicable, relating to 1995
transactions and 1994 FERC Assessment Charge Adjustment.

<

Page 311 Line 5 Column j

>

"Other charges" - customer charge, fuel adjustment, fuel
adjustment true-up, as applicable, relating to 1996 transactions
and 1995 FERC Assessment Charge.

<

Page 311 Line 6 Column j >

"Other charges" - fuel adjustment true-up, demand charge true-up,
variable O&M true-up, as applicable, relating to 1995
Page 310-311 Footnote.5

 transactions and 1994 FERC Assessment Charge Adjustment.

<

Page 311 Line 7 Column j

>

"Other charges" - customer charge, fuel adjustment, fuel
adjustment true-up, as applicable, relating to 1996 transactions
and 1995 FERC Assessment Charge.

<

Page 311 Line 8 Column j

>

"Other charges" - fuel adjustment true-up, demand charge true-up,
variable O&M true-up, as applicable, relating to 1995
transactions and 1994 FERC Assessment Charge Adjustment.

<

Page 311 Line 9 Column j

>

THIS FOOTNOTE APPLIES TO THE FOLLOWING THREE REFERENCES
Page 311-line 9- col. j - 1994 FERC Assessment Charge Adjustment
Page 311-line 10- col. j - 1995 FERC Assessment Charge
Page 311.2-line 9- col. j - Billing Adjustment for December 1995

<

Page 311 Line 9 Column j

>

THIS FOOTNOTE APPLIES TO THE FOLLOWING THREE REFERENCES
Page 311-line 9- col. j - 1994 FERC Assessment Charge Adjustment
Page 311-line 10- col. j - 1995 FERC Assessment Charge
Page 311.2-line 9- col. j - Billing Adjustment for December 1995

<

Page 311 Line 11 Column j

>

"Other charges" - fuel adjustment true-up, demand charge true-up,
variable O&M true-up, as applicable, relating to 1995
transactions and 1994 FERC Assessment Charge Adjustment.

<

Page 311 Line 12 Column j

>

"Other charges" - customer charge, fuel adjustment, fuel
adjustment true-up, as applicable, relating to 1996 transactions.

Page 310-311 Footnote.6

 <

Page 311 Line 13 Column j

>

"Other charges" - fuel adjustment true-up, demand charge true-up,
variable O&M true-up, as applicable, relating to 1995
transactions.

<

Page 311 Line 14 Column j

>

"Other Charges" - 1994 FERC Assessment Charge Adjustment.

<

Page 311.1 Line 1 Column j

>

"Other charges" - customer charge, fuel adjustment, fuel
adjustment true-up, as applicable, relating to 1996 transactions
and 1995 FERC Assessment Charge.

<

Page 311.1 Line 2 Column j >

"Other charges" - fuel adjustment true-up, demand charge true-up,
variable O&M true-up, as applicable, relating to 1995
transactions and 1994 FERC Assessment Charge Adjustment.

<

Page 311.1 Line 3 Column j

>

"Other Charges'' - 1994 FERC Assessment Charge Adjustment

<

Page 311.1 Line 4 Column j >

"Other charges'' - customer charge, fuel adjustment, fuel
adjustment true-up, as applicable, relating to 1996 transactions
and 1995 FERC Assessment Charge.

<

Page 311.1 Line 5 Column j

>

"Other charges" ~ fuel adjustment true-up, demand charge true-up,
variable O&M true-up, as applicable, relating to 1995
transactions and 1994 FERC Assessment Charge Adjustment.

<

Page 311.1 Line 6 Column j

>

"Other charges'' - customer charge, fuel adjustment, fuel
adjustment true-up, as applicable, relating to 1996 transactions
and 1995 FERC Assessment Charge.
Page 310-311 Footnote.?

 <

Page 311.1 Line 7 Column j >

"Other charges" - fuel adjustment true-up, demand charge true-up,
variable O&M true-up, as applicable, relating to 1995
transactions and 1994 FERC Assessment Charge Adjustment.

<

Page 311.1 Line 8 Column j >

"Other charges" - customer charge, fuel adjustment, fuel
adjustment true-up, as applicable, relating to 1996 transactions
and 1995 FERC Assessment Charge.

<

Page 311.1 Line 9 Column j >

"Other charges'' - fuel adjustment true-up, demand charge true-up,
variable O&M true-up, as applicable, relating to 1995
transactions and 1994 FERC Assessment Charge Adjustment.

<

Page 311.1 Line 12 Column j >

"Other charges" - billing adjustment for December 1995.

<

Page 311.2 Line 9 Column g >

Billing Adjustment for December 1995.

<

Page 311 Line 9 Column j

>

THIS FOOTNOTE APPLIES TO THE FOLLOWING THREE REFERENCES
Page 311-line 9- col. j - 1994 FERC Assessment Charge Adjustment
Page 311-line 10- col. j - 1995 FERC Assessment Charge
Page 311.2-line 9- col. j - Billing Adjustment for December 1995

<

Page 311.5 Line 4 Column j

>

"Other charges" - billing adjustment for December 1995

<

Page 311.5 Line 6 Column j >

"Other charges'' - billing adjustment for December 1995
Page 310-311 Footnote.B

 <

Page 311.5 Line 7 Column j

>

"Other Charges" - 1995 FERC Assessment Charge.

<

Page 311.5 Line 8 Column g >

Billing adjustment for December 1995

<

Page 311.5 Line 8 Column j >

"Other charges" - billing adjustment for December 1995

<

Page 311.5 Line 9 Column j >

"Other charges" - customer charge, fuel adjustment, fuel
adjustment true-up, as applicable, relating to 1996 transactions
and 1995 FERC Assessment Charge.

<

Page 311.5 Line 10 Column j

>

"Other charges" - fuel adjustment true-up, demand charge true-up,
variable O&M true-up, as applicable, relating to 1995
transactions and 1994 FERC Assessment Charge Adjustment.

<

Page 311.5 Line 12 Column g >

Billing adjustment for December 1995

<

Page 311.5 Line 12 Column j >

"Other Charges" - Billing Adjustment for December 1995.

<

Page 311.5 Line 13 Column j

>

"Other charges" - Demand Charge True-up, losses O&M True-up
as applicable, relating to 1995 transactions and 1994 FERC
Assessment Charge Adjustment.

Page 310-311 Footnote.9

 <

Page 311.5 Line 14 Column j

>

"Other charges" - 1995 FERC Assessment Charge

<

Page 311.6 Line 1 Column j

>

"Other charges" - losses demand charge true-up and
losses O&M true-up relating to 1995 transactions and 1994
FERC Assessment Charge Adjustment.

<

Page 311.6 Line 2 Column j

>

"Other Charges" - 1994 FERC Assessment Charge Adjustment.

Page 310-311 Footnote.10

 Date of Report
(Mo, Da, Yt')

N9me of Respondent
Florida Power & L1ght Company

Year of Report
Dec. 31, 1996

Amount for
Previous Year
(c)

FERC FORM N0.1 (REVISED. 12-93)

PAGE 320

 Name of Respondent
Florida Power & L1ght Company

of Report
Da, Yl")

Line
No.

Amount for
Current Year

,.....

-

--

r-

FERC FORM N0 . 1 (REVISED. 12 -93)

PAGE 321

Year of Report
Dec. 31, 1996

(b)

Amount fo r
Prev i ous Year (c)

 Date of Report
(Mo, Da, Yr)

Name of Respondent
Florida Power & L1ght Company

Amount for
Current Year
(b)

FERC FORM N0.1 (REVISED. 12-93)

PAGE 322

Year of Report
Dec. 31, 1996
Amovnt For
Prev1ous Year
(c)

 Name of Respondent
Florida Power & L1ght Company

Date of Report
(Mo, Da, Yl")

Year of Report
Dec. 31, 1996
Amovnt for
PreVlOUS Year
(C)

169

TOTAL Admin/· stratjve and General Expenses
(Enter tota of l1nes 165 thru 167)
TOTAL Electric Operation and Maintenance Ex~enses
(Enter tota of l1nes 80,100,126,134,141,148 and 168)

$259,621 '513

$290,089,412

$3,258,142,160

$2,860,324,561

NUMBER OF ELECTRIC DEPARTMENT EMPLOYEES
construction employees in a footnote.
1. The data on number of employees should be reported for
3. The number of employees assignable to the electric
the payroll period ending nearest to October 31, or any
department from joint functions of combination utilities may
payroll period ending 60 days before or after October 31.
be dete mined by estimate, on the basis of employee equi 2. If the respondent's payroll for the reporting period
valents. Show the estimated number of equivalent employees
includes any special construction personel, include such
attributed to the electric department from joint functions.
employees on line 3, and show the number of such special
12/31/96
1. Payroll Period Ended (Date)
9,909
2. Total Regular Full-Time Employees
326
3. Total Part-Time and Temporary Employees
10,235
4. Total Employees

FERC FORM N0.1 (ED.

12 -95)

PAGE 323

Next Page is 326

 Nfme of Respongent
F orida Power
L1ght Company

I

I~~st~ip~~to~~:inal
A Resu&;,ission

1

Date of Report
(Mo, Da, Yr)

-,

Year of Report
Dec. 31, 1996

PURCHASaQ PO~ER (Account 555)
(lnclu 1ng power exchanges)
long-term firm service which meets the definition
the
year. lso
1. Report all power purchases made during
RQ service. For all transactions identified
of
transactions
electricity
(i.e.
report exchanges of
as
LF, provide in a footnote the termination date
credits
for
and
debits
of
balancing
involving a
of the contract defined as the earliest date that
energy, capacity, etc.) and any settlements for
either buyer or seller can unilaterally get out
imbalanced exchanges.
of the contract.
2. Enter the name of the seller or other party in an
exchange transaction in column (a). Do not abbreviate
IF - for intermediate-term firm service. The same as
or truncate the name or use acronyms. Explain in a
expect that "intermediate-term" means
service
LF
affiliation
the
footnote any ownership interest or
one
year but less than five years.
longer
than
the
seller.
respondent has with
Code
Classification
Statistical
In
column(b),
enter
a
3.
SF - for short-term service. Use this category for
contractual terms and
original
the
based on
all firm services, where the duration of each period
conditions of the service as follows:
of commitment for service is one year or less.
RQ - for requirements service. Requirements service
from
a designated
LU - for long-term service
is service which the supplier plans to provide on an
years or
means
five
generating unit. "Long-term"
ongoing basis(i.e., the supplier includes projected
reliability
of
service,
The
availability
and
longer.
in
its system resource
load for this service
match
the
constraints,
must
aside
from
transmission
rel
iabl
i
l
ity
of
the
planning).
In addition,
availability and reliability of the designated unit.
requirement service must be the same as, or second
only to, the supplier's service to its own ultimate
IU - for intermediate-term service from a designated
consumers.
generating unit. The same as LU service expect that
"intermediate-term" means longer than one year but
LF - for long-term firm service. "Long-term" means five
years or longer and "firm" means that service cannot
less than five years.
be interrupted for economic reasons and is intended
EX - For exchanges of electricity. Use this category
to remain reliable even under adverse conditions
for transactions involving a balancing of debits and
(e.g.' the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of
credits for energy,capacity, etc. and any settlements
for imbalanced exchanges.
LF service). This category should not be used for
Actual Demand(M~)
~trtistiAver~~e
Line
F~RC Rate
Mon[ y
NamePubor icCjr~y
or
t Qrity
cfassifiNo.
Bll ~g
Sc ?1ule or
Aver~~e
Ave~rge
(Footnote A~ 1l1at1ons)
Mont y
Mont
y
cat1on
Tari
Number
Dema
NCP Demand
CP Demand
(b)
(a)
(c)
(d)
(e)
(f)
* OS
1 Enron Power Marketing, Inc.
162
N/A
N/A
N/A
OS
81
N/A
N/A
N/A
2 Florida Power Corporation
Ft. Pierce Utilities Authority
OS
49
N/A
N/A
3
N/A
OS
27
N/A
N/A
4 City of Gainsville
N/A
OS
N/A
N/A
5 City of Homestead
22
N/A
OS
31
N/A
N/A
N/A
6 *Jacksonville Electric Authority
Utility Board of The City of Key ~est
7
OS
90
N/A
N/A
N/A
OS
7
N/A
8 City of Lake ~orth Utilities
N/A
N/A
OS
20
N/A
N/A
9 City of New Smyrna Beach
N/A
OS
33
N/A
N/A
10 *Orlando Utilities Commission
N/A
OS
*
N/A
PECO Energy Company
N/A
N/A
N/A
N/A
N/A
Reedy Creek Improvement District
OS
112
12
OS
80
N/A
N/A
N/A
13
Seminole Electric Cooperative, Inc.
OS
36
N/A
N/A
14 Southern Company Services, Inc.
N/A

,,

FERC FORM N0.1 (REVISED 12-90)

PAGE 326

 Nrme of Respon~ent
L1ght Company
F orida Power

This Report Is:
An Resu
Or1~nal
A
ission
PURCHASED P?WE~
55~) (Continued)
(Inc ud1ng power exc anges)
~~~ fXj
I(Account

OS - for other service. Use this category only for those
services which cannot be placed in the above-defined
categories, such as all nonfirm 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.

6.

7.

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
4. footnote for each adjustment.
In column (c), identify the FERC Rate Schedule Number or
Tariff, or, for nonFERC 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 colunn (b), is
50 provided.
For requirements RQ purchases and any type of services
involving demand charges imposed on a monthly ( or longer)
basis, enter the monthly average billing demand in column
(d). the average monthly non- coincident peale (NCP) demand
in colunn (e), and the average monthly coincident peale (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
peale. Demand reported in

8.

9.

POWER EXCHANGES
Megawgtthours
Pure ased
(g)
15
179,999

ece1ved
(h)

84

34,875
25
38,108
99
5,290
42
49,533
3,950
101
205,107
10,689

FERC FORM N0.1 (REVISED 12-90)

Demand Charges
($)
(j)

MeBar~ttho~rs

Me~awatthours

e 1vere
( i)

0
0
0
0
0
0
0
0
0
0
0
0
0
0

0
0
0
0
0
0
0
0
0
0
0
0
0
0

I

Date of Re~ort
(Mo, Da, Y )

I

columns (e) and ( f) must be in megawatts. Footnote any
demand not stated on a megawatt basis and explain.
Report in column (g) the megawatthours shown on bills
rendered to the respondent. Report in column < h) and (i)
the megawatthours of power exchanges received and delivered,
used as the basis for settlement.Do not report net exchange.
Report demand charges in column (j), energy charges in
column ( le). and the total of any other types of charges,
including out-of-period adjustments, in column (l), Exp l ain
in a footnote all components of the amount shown in column
( l) 0 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
(1) include credits or charges other than incremental
generation expenses, or (2) excludes certain credits or
charges covered by the agreement, provide an explanatory
footnote.
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.
Footnote entries as required and provide explanations
following all required data.
COST/SETTLEMENT OF POWER
Other Charges
($)
(le)
(l)
$260
3,487,895
1,852
680,603
1,068
900,610
2,373
116,836
1,268
1,132,503
86,970
2,152
3,485,181
283,407

Ener~t)Charges

0
0
0
0
0
0
0
0
0
0
0
0
0
0

PAGE 327

Year of Report
Dec. 31, 1996

0
0
0
0
0
0
0
0
0
0
0
0
0
0

Total (j+le+l)
of Settlement ($) Line
No.
(m)
$260
1
3,487,895
2
1,852 3
680,603
4
1,068 5
900,610
6
2,373
7
116,836 8
1,268 9
1,132,503 10
86,970
2,152 12
3,485,181 13
283,407 14

,,

 Year of Report
Date of Report
(Mo, Da, Yr)
Dec . 31, 1996
A Resu~iss1on
PURCHASaO PO~ER (Account 555)
(Inclu 1ng power exchanges)
long-term firm service which meets the definition
1. Report all power purchases made during the year. lso
RQ service. For all transactions identified
of
transactions
report exchanges of electricity (i.e.
LF, provide in a footnote the termination date
as
for
credits
and
debits
involving a balancing of
of the contract defined as the earliest date that
energy, capacity, etc.) and any settlements for
either buyer or seller can unilaterally get out
imbalanced exchanges.
of the contract.
2. Enter the name of the seller or other party in an
exchange transaction in column (a). Do not abbreviate
IF - for intermediate - term firm service. The same as
or truncate the name or use acronyms. Explain in a
expect that "intermediate-term" means
service
LF
footnote any ownership interest or affiliation the
one
year but less than five years.
longer
than
respondent has with the seller.
Code
3. In column(b), enter a Statistical Classification
SF - for short-term service. Use this category for
contractual terms and
original
the
based on
all firm services, where the duration of each period
follows:
as
of
the
service
conditions
of commitment for service is one year or less.

Nfme of Respon~ent
F orida Power
L1ght Company

I

T~~sr~fP~~to~~:inal .
~

RQ - for requirements service. Requirements service
is service which the supplier plans to provide on an
ongoing basis(i.e., the supplier includes projected
its system resource
in
load for this service
rel iabl i l ity of
the
planning).
In addition,
requirement service IIXJSt be the same as, or second
only to, the supplier's service to its own ultimate
consiJllers.

1
2
3
4
5
6
7
8
9
10
11
12
13
14

NamePubol icCjr~y
or
t ority
(Footnote A~ 1l1at1ons)
(a)
City of Tallahassee
Tampa Electric Company
City of Vero Beach
Duke Power Company
* Entergy Services, Inc.
Carolina Power & Light Company
Calpine Power Services Company
Catex-Vitol Electric, LLC
Coastal Electrc Services Company
Coral Power, L. L.C.
Delhi Energy Services, Inc.
Enron Power Marketing, Inc.
Electric Clearinghouse, Inc.
Florida Power Corporation

FERC FORM NO.1 (REVISED 12-90)

I

a designated
from
LU - for long-term service
years or
five
generating unit. "Long-term" means
reliability
of
service,
The
availability
and
longer.
aside from transmission constraints, must match the
availability and reliability of the designated unit.

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 IIXJSt attempt to buy emergency
energy from third parties to maintain deliveries of
LF service). This category should not be used for
Line
No.

I

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 involv i ng a balancing of debits and
credits for energy,capacity, etc. and any settlements
for imbalanced exchanges.
Actual Demand(M~)
~trtistiAver~~e
F~RC Rate
Monf y
cfa~sifiBll ~g
Sc ~?ule or
Aver~~e
Avehfge
Mont
y
Mont
y
cat1on
Tari
Nunber
Dema
NCP Demand
CP Demand
(f)
(b)
(C)
(d)
(e)
98
N/A
N/A
N/A
* OS
OS
23
N/A
N/A
N/A
OS
128
N/A
N/A
N/A
285
N/A
N/A
N/A
* OS
N/A
N/A
N/A
OS
113
N/A
N/A
N/A
* OS *
OS
170
N/A
N/A
N/A
151
N/A
N/A
OS
N/A
175
N/A
N/A
N/A
OS
N/A
N/A
OS *
N/A
N/A
171
N/A
N/A
OS
162
N/A
N/A
N/A
OS
N/A
N/A
N/A
OS
150
143
N/A
N/A
N/A
OS

PAGE 326.1

 Nfme of Respon~ent
F orida Power
L1ght Company

I

This Report Is:
~~~ fX~ A
An Resu
Or1~nal
ission

PURCHASED P?W~~ (Account 55~) (Continued)
(Inc u 1ng power exc anges)
OS - for other service. Use this category only for those
services which cannot be placed in the above-defined
categories, such as all nonfirm 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.

6.

7.
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
4. footnote for each adjustment.
In column (c), identify the FERC Rate Schedule Number or
Tariff, or, for nonFERC 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
5. provided.
For requirements RQ purchases and any type of services
involving demand charges imposed on a monthly ( 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

8.

9.

POWER EXCHANGES
Megaw~tthours

Pure ased
(g)
1,836
853,065
5, 744
2,060
213
200
20,800
37,091
1,068
7,823
200
688,809
157,607
2,100

ece1ved
(h)

FERC FORM N0.1 (REVISED 12-90)

Demand Charges
($)

MeBar<:~ttho~rs

Me~awatthours

e 1vere
( i)

0
0
0
0
0
0
0
0
0
0
0
0
0
0

0
0
0
0
0
0
0
0
0
0
0
0
0
0

0
0
0
0
0
0
0
0
0
0
0
0
0
0

PAGE 327.1

Date of Re~ort
(Mo, Da, Y )

I

Year of Report
Dec. 31' 1996

columns (e) and ( f) must be in megawatts. Footnote any
demand not stated on a megawatt basis and explain.
Report in column (g) the megawatthours shown on bil l s
rendered to the respondent. Report in column ( h) and ( i)
the megawatthours of power exchanges received and delivered,
used as the basis for settlement.Do not report net exchange.
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 (l), Explain
in a footnote all components of the amount shown in column
(l). 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
(1) include credits or charges other than incremental
generation expenses, or (2) excludes certain credits or
charges covered by the agreement, provide an explanatory
footnote.
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.
Footnote entries as required and provide explanations
following all required data.
COST/SETTLEMENT OF POWER
Other Charges
($)
(l)
(k)
$38,931
0
14,921,556
0
147,797
0
47,380
0
7,420
0
4,070
0
453,280
0
200,061
483,032 *
21,627
0
(1 ,600)
186,788 *
14,300
0
( 130, 033)
15,668,650 *
4,456,150 *
(90,696)
34,650
0

Ener~~)Charges

(j)

I

Total (j+k+l)
of Settlement ($)
(m)
$38,931
14,921,556
147,797
47,380
7,420
4,070
453,280
683,093
21,627
185' 188
14,300
15,538,617
4,365,454
34,650

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14

 Yea r of Report
Date of Report
Thi s Report Is: . l
(Mo , Da, Yr )
fX~ A
An Resu
Orl ~na
.
Dec.
31' 1996
iss1on
PURCHASaO POWER (Account 555)
(Inclu 1ng power exchanges)
long-term firm service which meet s the def i nition
the
yea r . lso
Report
all
power
purchases
made
during
1.
of RQ service. For all transactions identified
report exchanges of electricity (i.e. transactions
as LF, provide in a footnote the termination date
i nvolving a balancing of debit s and credits for
of the contract defined as the earliest date that
energy, capacity, etc . ) and any settlements for
either buyer or seller can unilaterally get out
imbalanced exchanges.
of the contract.
other
party
in
an
2. Enter the name of the seller or
Do
not
abbreviate
exchange transaction in column (a).
IF - for intermediate-term firm serv i ce. The same as
or truncate the name or use acronyms. Explain in a
expect that "intermediate-term" means
LF service
footnote any ownership interest or affiliation the
longer than one year but less than five years.
respondent has with the seller.

Nfme of Respon~ent
F orida Power
L1ght Company

I m

3. In colunn(b), enter a Statistical Classification Code
contractual terms and
original
the
based on
conditions of the service as follows:

a designated
from
LU - for long-term service
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.

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

1
2
3
4
5
6
7
8
9
10

,,
12
13

14

Name
or Pubor icCj¥a~y
t ority
(Footnote A~ 1l1at1ons)
(a)
City of Gainesville
Heartland Energy Services, Inc.
City of Homestead
Koch Power Services, Inc.
* L G & E Power Marketing, Inc .
Louis Dreyfus Electric Power, Inc.
* Municipal Electric Authority of GA
Oglethorpe Power Corporation
Oglethorpe Power Corporation
*Orlando Utilities Commission
Pan Energy
PECO Energy Co.
Sonat Power Marketing Inc.
Tampa Electric Company

FERC FORM N0.1 (REVISED 12-90)

I

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.

RQ - for requirements service. Requirements service
is service which the supplier plans to provide on an
ongoing basis(i.e., the supplier includes projected
its system resource
in
load for this service
reliablility of
the
In addition,
planning).
requirement service must be the same as, or second
only to, the supplier's service to its own ultimate
consumers.

Line
No.

I

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.
Actual Demand(MW)
~tftistiAver~~e
F~RC Rate
Monf y
cfassifi81 L 1~g
Sc ?~ule or
Aver~~e
Avehfge
Deman
Mont y
Mont
y
cat1on
Tari
Number
NCP Demand
CP Demand
(C)
(d)
(e)
(b)
(f)
* OS
N/A
N/A
147
N/A
OS
149
N/A
N/A
N/A
OS
127
N/A
N/A
N/A
OS
148
N/A
N/A
N/A
OS
N/A
N/A
159
N/A
N/A
N/A
OS
152
N/A
OS *
N/A
N/A
N/A
OS
125
N/A
N/A
N/A
AD
125
N/A
N/A
N/A
OS
128
N/A
N/A
N/A
N/A
OS
178
N/A
N/A
*
N/A
N/A
OS
N/A
N/A
OS
158
N/A
N/A
N/A
OS
114
N/A
N/A

PAGE 326.2

 Nfme of Respon~ent
F orida Power
L1ght Company

I

This Report Is:
~~~ fX~ A
An Resu
Or1~nal
ission

PURCHASED P?~E~ (Account 55~) (Continued)
(Inc ud1ng power exc anges)
OS - for other service. Use this category only for those
services which cannot be placed in the above-defined
categories, such as all nonfirm 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.

I

6.

7.

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
4. footnote for each adjustment.
In column (c), identify the FERC Rate Schedule Number or
Tariff, or, for nonFERC 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
5. provided.
For requirements RQ purchases and any type of services
involving demand charges imposed on a monthly ( or longer)
basis, enter the monthly average billing demand in column
(d), the average monthly non- coincident peale (NCP) demand
in coll1111'1 (e), and the average monthly coincident peale (CP)
demand in column (f). For all other types of service, enter
NA in columns (d), (e) and (f). Monthly NCP demand is the
maxillllll1 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
peale. Demand reported in

8.

9.

Pure ased
(g)
4,168
2,679
20
230,857
53,723
335,788
803
338,616
0
7,375
8,000
103,029
25,357
54,709

FE~

• D e~

ecelVed
(h)

N0.1 (REVISED 12-90)

Demand Charges
($)
(j)

MeBar;,~ttho~rs

Me~awatthours

e 1vere
( i)

0
0
0
0
0
0
0
0
0
0
0
0
0
0

0
0
0
0
0
0
0
0
0
0
0
0
0
0

1

Year of Report
Dec. 31, 1996

columns (e) and ( f) must be in megawatts. Footnote any
demand not stated on a megawatt basis and explain.
Report in column (g) the megawatthours shown on bills
rendered to the respondent. Report in column ( h) and Ci)
the megawatthours of power exchanges received and delivered,
used as the basis for settlement.Do not report net exchange.
Report demand charges in column (j), energy charges in
column ( le)' and the total of any other types of charges,
including out-of-period adjustments, in column (l), Explain
in a footnote all components of the amount shown in column
( l) 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
(1) include credits or charges other than incremental
generation expenses, or (2) excludes certain credits or
charges covered by the agreement, provide an explanatory
footnote.
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.
Footnote entries as required and provide explanations
following all required data.
0

POIIER EXCHANGES
Megaw~tthours

I

Date of Report
(Mo, Da, Yr)

COST/SETTLEMENT OF PO~ER
Other Charges
($)
(le)
( l)
$148,042
0
80,886
0
1,230
0
(236,548)
5,078,344 *
1,072,034
0
7,214,612
0
16,150
0
6,813,084
0
4,410
0 *
0
288,395
(17,920)
272,211 *
0
2,450,491
(56,920)
764,813 *
0
1,058,859

Ener~$)Charges

0
0
0
0
0
0
0
0
0
0
0
0
0
0

PAGE 327.2

Total (j+le+l)
of Settlement ($) Line
No.
(m)
$148,042
1
80,886
2
1,230 3
4,841,796 4
1,072,034
5
7,214,612 6
16,150 7
6,813,084 8
4,410 9
288,395 10
254,291 11
2,450,491 12
707,893 13
1,058,859 14

 Nfme of Respon~ent
F orida Power
L1ght Company

I

T~isf~ep~~to~~:inal .

I

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31, 1996

~ ~ ~ A Resu~iss1on
PURCHASaO POWER (Account 555)
(Inclu 1ng power exchanges)
long-term firm service which meets the definition
the
year. lso
Report
all
power
purchases
made
during
1.
of RQ service. For all transactions identified
report exchanges of electricity (i.e. transactions
LF, provide in a footnote the termination date
as
involving a balancing of debits and credits for
the
contract defined as the earliest date that
of
for
energy, capacity, etc.) and any settlements
buyer or seller can uni laterally get out
either
imbalanced exchanges.
contract.
the
of
other
party
in
an
seller
or
2. Enter the name of the
Do
not
abbreviate
exchange transaction in column (a).
IF - for intermediate-term firm service. The same as
or truncate the name or use acronyms. Explain in a
expect that "intermediate-term" means
LF service
footnote any ownership interest or affiliation the
longer than one year but less than five years.
respondent has with the seller.
3. In col~..mn(b), enter a Statistical Classification Code
contractual terms and
original
the
based on
conditions of the service as follows:

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.

RQ - for requirements service. Requirements service
is service which the supplier plans to provide on an
ongoing basis(i.e., the supplier includes projected
its system resource
in
load for this service
rel iabl i l ity of
the
planning).
In addition,
requirement service must be the same as, or second
only to, the supplier's service to its own ultimate
consl.lllers.

from
a designated
LU - for long-term service
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.

LF - for long-term firm service. "Long-term" means five
years or longer and 11 flrm 11 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
Line
No.
1
2
3
4
5
6
7

8
9
10
11
12
13
14

NamePubof icCj¥a~y
or
t ority
(Footnote A~ 1l1at1ons)
(a)
Seminole Electric Cooperative, Inc.
* Florida Municipal Power Agency
*Orlando Utilities Commission
* Seminole Electric Cooperative, Inc.
Seminole Electric Cooperative, Inc.
* Southern Company Services, Inc.
Southern Company Services, Inc.
*Jacksonville Electric Authority
*Jacksonville Electric Authority
Bio-Energy Partners, Inc.
Bio-Energy Partners, Inc.
* Broward County Resource Recovery
* Broward County Resource Recovery
* Broward County Resource Recovery

FERC FORM N0.1 (REVISED 12-90)

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.
Actual Demand(MW)
~tftistiAver~~e
FijRC Rate
Monf y
cfassifiSc f1ule or
B1l ~g
Aver~~e
Avehfge
Mont y
Mont
y
cat1on
Tar1
Number
Dema
NCP Demand
CP Demand
(C)
(b)
(d)
(e)
(f)
EX
N/A
N/A
77
N/A
N/A
N/A
LU
72
N/A
LU
72
N/A
N/A
N/A
LF
77
N/A
N/A
N/A
N/A
AD
77
N/A
N/A
920
920
LF
36
886
AD
36
N/A
N/A
N/A
LU *
374
391
362
*
N/A
N/A
AD
N/A
LU
COG-2
8
9
8
N/A
AD
COG-2
N/A
N/A
COG-2
49
LU
58
52
N/A
N/A
AD
COG-2
N/A
LU
COG-2
49
59
45

PAGE 326.3

 Nfme.of Respon~ent
F or1da Power
L1ght Company

This Report Is:
~~~ fX~ A
An Resu
Or1~nal
ission

I(Account

PURCHASED P?~~~
55~) (Continued)
(Inc u 1ng power exc anges)
OS - for other service. Use this category only for those
services which cannot be placed in the above-defined
categories, such as all nonfirm 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.

6.

7.
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
4. footnote for each adjustment.
In column (c), identify the FERC Rate Schedule Number or
Tariff, or, for nonFERC 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
50 provided.
For requirements RQ purchases and any type of services
involving demand charges imposed on a monthly ( 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
maxi111llll 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
P~ER

Megaw~tthours

Pure ased
(g)

0
303,349
209,745
4,006

*

*
*

(73)

5,464,993
0
2,937,577
0
72,545
758
438,306
3,832
429,716

8.

9.

EXCHANGES

Me~awatthours

ece1ved
(h)
4,455
0
0
0
0
0
0
0
0
0
0
0
0
0

FERC FORM NO.1 (REVISED 12-90)

MeBa~_.ttho~rs

e 1vere
(i)

Demand Charges
($)

(j)
758
0
0
0
0
0
0
0
0
0
0
0
0
0

I

PAGE 327.3

j

Year of Report
Dec. 31' 1996

columns (e) and ( f) must be in megawatts. Footnote any
demand not stated on a megawatt basis and explain.
Report in column (g) the megawatthours shown on bills
rendered to the respondent. Report in column ( h) and (i)
the megawatthours of power exchanges received and delivered,
used as the basis for settlement.Do not report net exchange.
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 (l), Explain
in a footnote all components of the amount shown in column
(l). 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
(1) include credits or charges other than
incremental
generation expenses, or (2) excludes certain credits or
charges covered by the agreement, provide an explanatory
footnote.
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.
Footnote entries as required and provide explanations
following all required data.

COST/SETTLEMENT OF PO~ER
Other Charges
Ener~t)Charges
($)

(k)

0
0
0
0
0
114,627,333
0
77,135,218
0
1,321,920
0
13,556,874
0
12,930,037

Date of Re~ort
(Mo, Da, Y )

0
1,655,281
1,061,234
80,666
0
98,862,435
0
49,070,948
0
1,422,518
0
9,150,688
0
8,884,526

( l)

*

0
0
0
0
(1,341)

*

106,794

*

(727, 106)
0
(12,035)
0
(68,443)
0

*
*

Total (j+k+ll
of Settlement $)
(m)
0
1,655,281
1 '061 '234
80,666
( 1,341)
213,489,768
106,794
126,206,166
(727, 106)
2,744,438
(12,035)
22,707,562
(68,443)
21,814,563

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14

 Year of Report
Date of Re~ort
(Mo, Da, Y )
rlis ~fP~~to~~=inal
Dec. 31, 1996
~ ~ f A Resu~ission
PURCHASaO POWER (Account 555)
(Inclu 1ng power exchanges)
long-term firm service which meets the definition
the
year. lso
1. Report all power purchases made during
of RQ service. For all transactions identified
report exchanges of electricity (i.e. transactions
as LF, provide in a footnote the termination date
involving a balancing of debits and credits for
of the contract defined as the earliest date that
energy, capacity, etc.) and any settlements for
either buyer or seller can unilaterally get out
imbalanced exchanges.
of the contract.
2. Enter the name of the seller or other party in an
exchange transaction in column (a). Do not abbreviate
IF - for intermediate-term firm service. The same as
or truncate the name or use acronyms. Explain in a
service expect that "intermediate-term" means
LF
affiliation
the
or
footnote any ownership interest
longer
than one year but less than five years.
the
seller.
has
with
respondent
Code
Classification
enter
a
Statistical
In
column(b),
3.
SF - for short-term service. Use this category for
contractual terms and
original
the
based on
all firm services, where the duration of each period
conditions of the service as follows:
of commitment for service is one year or less.
RQ - for requirements service. Requirements service
from
a designated
LU - for long-term service
is service which the supplier plans to provide on an
years or
five
"Long-term"
means
generating
unit.
includes
projected
ongoing basis(i.e., the supplier
reliability
of
service,
The
availability
and
longer.
system
resource
its
service
in
load for this
aside from transmission constraints, must match the
reliablility of
addition,
the
planning).
In
availability and reliability of the designated unit.
requirement service must be the same as, or second
only to, the supplier's service to its own ultimate
IU - for intermediate-term service from a designated
consLmers.
generating unit. The same as LU service expect that
"intermediate-term" means longer than one year but
LF - for long-term firm service. "Long-term" means five
less than five years.
years or longer and "firm" means that service cannot
be interrupted for economic reasons and is intended
EX - For exchanges of electricity. Use this category
to remain reliable even under adverse conditions
for transactions involving a balancing of debits and
(e.g.' the supplier must attempt to buy emergency
credits for energy,capacity, etc. and any settlements
energy from third parties to maintain deliveries of
for imbalanced exchanges.
LF service). This category should not be used for
Actual Demand(MW)
~tftistiAver~~e
Line
F~RC Rate
Monf y
NamePubol icCj¥a~y
cfassifiNo.
or
t ority
Bll ~g
Sc·?1ule or
Avehfge
Aver~~e
Mont y
Mont
y
(Footnote A~ 1 l1at1ons)
cat1on
Tan
Nl.nlber
Dema
NCP Demand
CP Demand
(f)
(b)
(c)
(d)
(e)
(a)
AD
COG-2
N/A
N/A
N/A
1 * Broward County Resource Recovery
COG-2
202
258
LU
213
2 Cedar Bay Generating Company
AD
COG-2
N/A
N/A
N/A
3 Cedar Bay Generating Company
AD
N/A
N/A
N/A
4 Cypress Energy Company
*
COG-2
106
131
LU
120
Florida Crushed Stone
5
COG-2
N/A
N/A
N/A
AD
Florida Crushed Stone
6
COG-1
N/A
N/A
N/A
7 Georgia Pacific Corporation
LU
COG-1
N/A
N/A
AD
N/A
8 Georgia Pacific Corporation
LU
COG-2
210
338
270
9 * Indiantown Cogeneration L.P.
AD
COG-2
N/A
N/A
N/A
10 * Indiantown Cogeneration L.P.
COG-1
N/A
N/A
LU
N/A
11
* Lee County Resource Recovery
COG-1
N/A
N/A
N/A
AD
12 * Lee County Resource Recovery
COG-1
N/A
N/A
LU
N/A
13 Okeelanta Power Limited Partnership
AD
COG-1
N/A
N/A
N/A
14
Okeelanta Power Limited Partnership
Nfme of Respon~ent
F orida Power
L1ght Company

F~RC

FORM N0.1 (REVISED 12-9D)

I

I

PAGE 326.4

l

 ,....
Nfme of Respon~ent
L1ght Company
F orida Power

I

This Report Is:
~~~ fXl A
An Resu
Or1~nal
ission

PURCHASED P?W§~ (Account 55~) (Continued)
(Inc u 1ng power exc anges)
OS - for other service. Use this category only for those
services which cannot be placed in the above-defined
categories, such as all nonfirm service regardless of the
length of the contract and service from designated units
of less than one year. Describe the nature of the service
l"J a footnote for each adjustment.

6.

7.
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
4. footnote for each adjustment.
In column (c), identify the FERC Rate Schedule Number or
Tariff, or, for nonFERC 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 colunn (b), is
5. provided.
For requirements RQ purchases and any type of services
involving demand charges imposed on a monthly ( or longer)
basis, enter the monthly average billing demand in column
(d). the average monthly non- coincident peak (NCP) demand
. . , c:olumn (e), and the average monthly coincident peak (CP)
aemand 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
its monthly
reaches
peak. Demand reported in

8.

9.

POWER EXCHANGES
Megawatthours
Purchased
(g)
2,620
*
1, 786,903
(17,074)
*
0
941,259
0
2,090
270
*
1,861,752
(47. 998)
*
194,448
448
*
156,098
14,214
*

ece1ved
(h)

FERC FORM N0. 1 (R EV,Rr

e 1vere
(i)

0
0
0
0
0
0
0
0
0
0
0
0
0
0

12-90)

Demand Charges
($)
(j)

MeBa~Cilttho~rs

Me~awatthours

0
0
0
0
0
0
0
0
0
0
0
0
0
0

0
82,994,441
0
0
39,100,032
0
0
0
114,552,781
0
0
0
0
0

PAGE 327.4

I

Date of Re~ort
CMo, Da, Y )

I

Year of Report
Dec. 31, 1996

columns (e) and C f) must be in megawatts. Footnote any
demand not stated on a megawatt basis and explain.
Report in column (g) the megawatthours shown on bills
rendered to the respondent. Report in column ( h) and (i)
the megawatthours of power exchanges received and delivered,
used as the basis for settlement.Do not report net exchange.
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 (l), Explain
in a footnote all components of the amount shown in column
(l). 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
(1) include credits or charges other
than incremental
generation expenses, or (2) excludes certain credits or
charges covered by the agreement, provide an explanatory
footnote.
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.
Footnote entries as required and provide explanations
following all required data.
COST/SETTLEMENT OF POWER
Other Charges
($)
( l)
(k)
($93,304)
0 *
0
29,216,253
511,938
0 *
11,876,000
0 *
15,861,141
0
13,931
0 *
45,232
0
5,338
0 *
43,788,628
0
(488,314)
0 *
4,396,785
0
16,905
0 *
3,671,546
0
291,798
0 *

Ener~t)Charges

Total (j+k+l)
of Settlement ($)
(m)
($93,304)
112,210,694
511,938
11,876,000
54,961,173
13,931
45,232
5,338
158,341,409
(488,314)
4,396,785
16,905
3,671,546
291,798

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14

 Nfme of Respon~ent
F orida Power
L1ght Company

I

f~lst~ip~~to~~:inal
A ResugJ,ission

I

Date of Re~ort
(Mo, Da, Y )

I

Year of Report
Dec. 31, 1996

PURCHASaO PO~ER (Account 555)
(lnclu 1ng power exchanges)
long-term firm service which meets the definition
1. Report all power purchases made during the year. lso
of RQ service. For all transactions identified
report exchanges of electricity (i.e. transactions
as LF, provide in a footnote the termination date
involving a balancing of debits and credits for
of the contract defined as the earliest date that
for
settlements
energy, capacity, etc.) and any
buyer or seller can uni laterally get out
either
imbalanced exchanges.
contract.
of
the
other
party
in
an
seller
or
of
the
name
2. Enter the
exchange transaction in column (a). Do not abbreviate
IF - for intermediate-term firm service. The same as
or truncate the name or use acronyms. Explain in a
expect that "intermediate-term" means
LF service
footnote any ownership interest or affiliation the
longer than one year but less than five years.
respondent has with the seller.
3. In column(b), enter a Statistical Classification Code
S"F - for short-term service. Use this category for
contractual terms and
original
the
on
based
all firm services, where the duration of each period
conditions of the service as follows:
of commitment for service is one year or less.
RQ - for requirements service. Requirements service
a designated
from
LU - for long-term service
is service which the supplier plans to provide on an
generating unit. "Long-term" means five years or
ongoing basis(i.e., the supplier includes projected
longer. The availability and reliability of service,
its system resource
in
load for this service
rel iabl i l ity of
aside from transmission constraints, must match the
planning).
In addition,
the
availability and reliability of the designated unit.
requirement service must be the same as, or second
only to, the supplier's service to its own ultimate
IU - for intermediate-term service from a designated
consumers.
generating unit. The same as LU service expect that
LF - for long-term firm service. "Long-term" means five
"intermediate-term" means longer than one year but
years or longer and "firm" means that service cannot
less than five years.
be interrupted for economic reasons and is intended
to remain reliable even under adverse conditions
EX - For exchanges of electricity. Use this category
for transactions involving a balancing of debits and
(e.g.' the supplier must attempt to buy emergency
energy from third parties to maintain deliveries of
credits for energy,capacity, etc. and any settlements
LF service). This category should not be used for
for imbalanced exchanges.
Actual Demand(M~)
~trtistiAver~~e
Line
FSRC Rate
Mont y
NamePubor icCj¥a~y
No.
or
t Qrity
cfassifiB1l
~g
Sc
f1ule
or
Aver~~e
Avehfge
(Footnote A? 1l1at1ons)
cat1on
Tar1
NlJilber
Mont y
Dema
Mont
y
NCP Demand
CP Demand
(a)
(b)
(C)
(d)
(f)
(e)
1 Osceola Power Limited Partnership
COG-1
LU
N/A
N/A
N/A
AD
COG-1
2 Osceola Power Limited Partnership
N/A
N/A
N/A
LU
COG-2
3 Royster CO!Il>any
7
11
8
4 Royster CO!Il>any
AD
COG-2
N/A
N/A
N/A
LU
COG-2
39
5 Solid ~aste Authority of Palm Beach
50
39
AD
COG-2
6 Solid ~aste Authority of Palm Beach
N/A
N/A
N/A
7
Tropicana Products, Inc.
LU
COG-1
N/A
N/A
N/A
Tropicana Products, Inc.
COG-1
8
AD
N/A
N/A
N/A
LU
COG-1
9 u. s. Sugar Corporation - Bryant
N/A
N/A
N/A
10 u. s. Sugar Corporation - Bryant
AD
COG-1
N/A
N/A
N/A
11
u. s. Sugar Corporation - Clewiston
LU
COG-1
N/A
N/A
N/A
AD
COG-1
N/A
12 u. s. Sugar Corporation - Clewiston
N/A
N/A
13
TOTAL
14

FERC FORM N0.1 (REVISED 12-90)

PAGE 326.5

 Nfme of Respon~ent
F orida Power
L1ght Company

This Report Is:
~~~ fXl A
An Resu
Or1~nal
ission
PURCHASED P?Wa~ (Account 55~) (Continued)
(Inc u 1ng power exc anges)

I

OS - for other service. Use this category only for those
services which cannot be placed in the above-defined
categories, such as all nonfirm 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.

6.

7.
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
4. footnote for each adjustment.
In coll.m'l (c), identify the FERC Rate Schedule Number or
Tariff, or, for nonFERC 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 coliATln (b), is
5. provided.
For requirements RQ purchases and any type of services
involving demand charges imposed on a monthly ( 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 coll.m'l (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
its monthly
peak. Demand reported in
reaches

,.......

8.

9.

POWER EXCHANGES
Megaw~tthours

*

*
*
*

Pure ased
(g)
84,500
467
65.113
0
336,559
1,623
9,473
(608)
20,120
1,379
882
0
18,750,949

Me~awatthours

ecelVed
(h)

0
0
0
0
0
0
0
0
0
0
D
0
4,455

FE RC fORM NO.1 (REVISED 12-90)

MeBar<;~ttho~rs

e 1vere
( i)

0
0
0
0
0
0
0
0
0
0
0
0
758

Demand Charges
($)
(j)
0
0
2,308,924
0
11,691,540
0
0
0
0
0
0
0
470,219,100

PAGE 327.5

l

Date of Re~ort
(Mo, Da, Y )

I

Year of Report
Dec. 31, 1996

columns (e) and ( f) must be in megawatts. Footnote any
demand not stated on a megawatt basis and explain.
Report in column (g) the megawatthours shown on bills
rendered to the respondent. Report in column ( h) and (i)
the megawatthours of power exchanges received and delivered,
used as the basis for settlement.Do not report net exchange.
Report demand charges in column (j), energy charges in
column (I<). and the total of any other types of charges,
including out-of-period adjustments, in column (l), Explain
in a footnote all components of the amount shown in column
( l). 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
( 1) include credits or charges other than incremental
generation expenses, or ( 2) excludes certain credits or
charges covered by the agreement, provide an explanatory
footnote.
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.
Footnote entries as required and provide explanations
following all required data.
COST/SETTLEMENT OF POWER
Other Charges
Total (j+i<+l)
Ener~~)Charges
($)
of Settlement ($)
(I<)
( l)
(m)
$1,945,005
0
$1,945,005
9,896
9,896
0 *
3,320,166
1,011,242
0
(72,280)
(72,280)
0 *
5,231,986
0
16,923,526
61.199
61.199
0 *
230,570
0
230,570
(8,312)
(8,312)
0 *
451,017
0
451,017
31,628
31,628
0 *
19,440
0
19,440
142
142
0 *
347,984,901
829,329,189
11,125.188 *

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14

 <

Page 326 Line 1 Column b

>

THIS FOOTNOTE APPLIES TO LINES 1 - 14, COLUMN (b ) , PAGE 326 :
Schedule C Economy Energy Purchases.

<

Page 326 Line 6 Column a

>

Florida Power & Light Company and Jacksonville Electric
Authority are co-owners of St. Johns River Power Park,
Scherer Unit No. 4, and the Duval-Hatch and Duval-Thalmann
500KV transmission lines.

<

Page 326 Line 10 Column a

>

St. Luice Unit No. 2 is jointly owned by Florida Power &
Light Company (85.10449%), Florida Municipal Power Agency
(8.806%) and Orlando Utilities Commission (6.08951%).

<

Page 326 Line 11 Column c

>

FERC electric tariff of PECO Energy Company.

<

Page 326.1 Line 1 Column b

>

THIS FOOTNOTE APPLIES TO LINES 1 - 3, COLUMN (b), PAGE 326.1:
Schedule C Economy Energy Purchases.

<

Page 326.1 Line 4 Column b

>

THIS FOOTNOTE APPLIES TO LINES 4 & 5, COLUMN (b), PAGE 326.1:
Schedule EP

<

Page 326.1 Line 5 Column a

>

Entergy Services, Inc. for Arkansas Power & Light.

<

Page 326.1 Line 6 Column b

>

THIS FOOTNOTE APPLIES TO LINES 6 - 14, COLUMN (b), PAGE 326 .1:
Page 326-327 Footnote.1

 Opportunity Purchase Contract

<

Page 326.1 Line 6 Column c >

Tariff No. 1 for Sales of Capacity and Energy by Carolina Power &
Light Company.

<

Page 326.1 Line 10 Column c

>

No rate schedule assigned, contract is pending at FERC.

<

Page 326.2 Line 1 Column b >

THIS FOOTNOTE APPLIES TO LINES 1 - 14, COLUMN (b), PAGE 326.2:
Opportunity purchase contract.

<

Page 326.2 Line 5 Column a >

Complete name: Louisville Gas & Electric Power Marketing, Inc.

<

Page 326.2 Line 7 Column a

>

Complete name: Municipal Electric Authority of Georgia.

<

Page 326.2 Line 7 Column c >

Municipal Electric Authority of Georgia is a non-FERC
jurisdictional seller.

<

Page 326.2 Line 10 Column a >

St. Lucie Unit . No. 2 is jointly owned by Florida Power &
Light Company (85.10449%), Florida Municipal Power Agency
(8.806%) and Orlando Utilities Commission (6.08951%).

<

Page 326.2 Line 12 Column c >

FERC electric tariff of PECO Energy Company.

Page 326-327 Footnote.2

 <

Page 326.3 Line 2 Column a >

St. Lucie Unit No. 2 is jointly owned by Florida Power &
Light Company ( 85.10449% ) , Florida Municipal Power Agency
(8.806%) and Orlando Utilities Commission (6.08951% ) .

<

Page 326.3 Line 3 Column a >

St. Lucie Unit No. 2 is jointly owned by Florida Power &
Light Company (85.10449%), Florida Municipal Power Agency
(8.806%) and Orlando Utilities Commission (6.08951%).

<

Page 326.3 Line 4 Column a >

Contract expires May 21, 2004 or upon written notice to
the other party at least seven years in advance of the
proposed date of termination.

<

Page 326.3 Line 6 Column a>

Contract expires May 31, 2010.

<

Page 326.3 Line 8 Column a >

Florida Power & Light Company and Jacksonville Electric
Authority are co-owners of St. Johns River Power Park,
Scherer Unit No. 4, and the Duval-Hatch and Duval-Thalmann
500KV transmission lines.

<

Page 326.3 Line 8 Column c >

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 & Light Company.

<

Page 326.3 Line 9 Column a>

Florida Power & Light Company and Jacksonville Electric
Authority are co-owners of St. Johns River Power Park,
Scherer Unit No. 4, and the Duval-Hatch and Duval-Thalmann
500KV transmission lines.
Page 326-327 Footnote.3

 <

Page 326.3 Line 9 Column c >

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 & Light Company.

<

Page 326.3 Line 12 Column a >

Complete name: Broward County Resource Recovery - North.

<

Page 326.3 Line 13 Column a >

Complete name: Broward County Resource Recovery - North.

<

Page 326.3 Line 14 Column a >

Complete name: Broward County Resource Recovery - South.

<

Page 326.4 Line 1 Column a>

Complete name: Broward County Resource Recovery - South.

<

Page 326.4 Line 4 Column c >

On July 9, 1996 the Florida Public Service Commission (FPSC)
approved Florida Power & Light Company's petition for approval of
an agreement to buy out the Cypress Energy Company Standard Offer
Contract in Order No. PSC-96-0889-FOF-EU, Docket No. 940546-EU.
The FPSC also ordered that FPL recover the costs associated with
the buy out by assigning 58 percent of the costs to the Capacity
Cost Recovery Clause and 42 percent of the costs to the Fuel and
Purchased Power Cost Recovery Clause.

<

Page 326.4 Line 9 Column a >

Complete name: Indiantown Cogeneration Limited Partnership.

Page 3 26-327 Footnote.4

 <

Page 326.4 Line 10 Column a

Complete name:

<

>

Indiantown Cogeneration Limited Partnership.

Page 326.4 Line 11 Column a

>

Complete name: Lee County Solid Waste Resource Recovery.

<

Page 326.4 Line 12 Column a

>

Complete name: Lee County Solid Waste Resource Recovery.

<

Page 327.1 Line 8 Column l >

"Other charges" represents a negotiated adder.

<

Page 327.1 Line 10 Column l >

"Other Charges" - Tolling Fee

<

Page 327.1 Line 12 Column l

>

"Other Charges" - Tolling Fee

<

Page 327.1 Line 13 Column l >

"Other Charges" - Tolling Fee

<

Page 327.2 Line 4 Column l >

"Other Charges" - Tolling Fee

<

Page 327.2 Line 9 Column l

>

"Other Charges'' - Billing Adjustment for October and
December 1995.

Page 326-327 Footnote.S

 <

Page 3 27.2 Line 11 Column 1

"Other Charges 11

<

-

>

Tolling Fe e

Page 3 2 7. 2 Line 13 Column 1

>

"Other Charges" - Tolling Fee

<

Page 327.3 Line 5 Column g

>

Billing Adjustment for December 1995.

<

Page 327.3 Line 5 Column 1

>

"Other charges" represents billing adjustment for December 1995.

<

Page 327.3 Line 7 Column 1

>

"Other charges" represents billing adjustment for December 1995 .

<

Page 327.3 Line 9 Column 1

>

"Other charges" represents billing adjustment for
December 1995

<

Page 327.3 Line 11 Column g

>

Billing Adjustment for December 1995.

<

Page 327.3 Line 11 Column 1

>

"Other charges" represents billing adjustment for December 1995.

<

Page 327.3 Line 13 Column g

>

Billing Adjustment for De c ember 1995.

Page 326-3 2 7 Footno t e .6

 <

Page 327.3 Line 13 Column l

>

"Other charges" represents billing adjustment for December 1995.

<

Page 327.4 Line 1 Column g

>

Billing Adjustment for December 1995.

<

Page 327.4 Line 1 Column l

>

"Other charges" represents billing adjustment for December 1995.

<

Page 327.4 Line 3 Column g >

Billing Adjustment for December 1995.

<

Page 327.4 Line 3 Column l >

"Other charges" represents billing adjustment for December 1995.

<

Page 327.4 Line 4 Column l

>

Contract buy out payments. See the footnote for page 326.4,
line 4, column c.

<

Page 327.4 Line 6 Column l >

"Other charges" represents billing adjustment for December 1995.

<

Page 327.4 Line 8 Column g

>

Billing Adjustment for December 1995.

<

Page 327.4 Line 8 Column l >

"Other charges" represents billing adjustment for December 1995.

Page 326-327 Footnote.?

 <

Page 327.4 Line 10 Column g

>

Billing Adjustment for December 1995.

<

Page 327.4 Line 10 Column 1 >

"Other charges" represents billing adjustment for December 1995.

<

Page 327.4 Line 12 Column g >

Billing Adjustment for December 1995.

<

Page 327.4 Line 12 Column 1

>

"Other charges" represents billing adjustment for December 1995.

<

Page 327.4 Line 14 Column g >

Billing Adjustment for December 1995.

<

Page 327.4 Line 14 Column 1 >

"Other charges'' represents billing adjustment for December 1995.

<

Page 327.5 Line 2 Column g >

Billing adjustment for December 1995.

<

Page 327.5 Line 2 Column 1 >

"Other charges'' represents billing adjustments for December 1995.

<

Page 327.5 Line 4 Column 1 >

"Other charges" represents billing adjustment for December 1995.

<

Page 327.5 Line 6 Column g

>

Billing adjustment for December 1995.
Page 326-327 Footnote.B

 <

Page 327.5 Line 6 Column l >

"Other charges" represents billing adjustment for December 1995.

<

Page 327.5 Line 8 Column g

>

Billing adjustment for December 1995.

<

Page 327.5 Line 8 Column l >

"Other charges" represents billing adjustment for December 1995.

<

Page 327.5 Line 10 Column g

>

Billing adjustment for December 1995.

<

Page 327.5 Line 10 Column l >

"Other charges" represents billing adjustment for December 1995.

<

Page 327.5 Line 12 Column l

>

"Other charges" represents billing adjustment for December 1995.

<

Page 327.5 Line 13 Column m >

Total does not include $30,077 for Florida Electric Power
Coordinating Group brokerage expenses charged to Account 555,
nor ($36,811) erroneously credited to Account 555.

Page 326-327 Footnote.9

 Nfme of Respon~ent
F orida Power
L1ght Company

I

I~~sf~fp~~to~~:inal
A ResuE,ri,ission

I

Date of Re~ort
(Mo, Da, Y l

I

Year of Report
Dec. 31' 1996

TRANSMITSION OF ELECTRICITY F?R OT~ERS (Account 456~
(Inc ud1ng transact1ons re erre to as "wheel1ng')
4. In column(d) enter a Statistical Classification code
i. e. wheeling,
electricity,
of
transmission
1. Report all
based on the original contractual terms and conditions
provided for other electric utilities, cooperatives,
of the s·e rvice as follows:
public authorities, qualifying
municipalities, other
and
suppliers
utility
facilities, non-traditional
LF - for long-term firm transmission service. "Long-term"
ultimate customers.
means
one year or longer and "firm" means that service
distinct
type
of
2. Use a separate line of data for each
be interrupted for economic reasons and is
cannot
listed
in
involving
the
entities
transmission service
intended
to remain reliable even under adverse con(b)
and
(c).
column (a),
ditions. For all transactions identified as LF, provide
3. Report in column (a) the company or public authority
in a footnote the termination date of the contract
in
that paid for the transmission service. Report
defined as the earliest date that either buyer or
column(b) the company or public authority that the
seller can unilaterally get out of the contract.
energy was received from and in column (c) the company

Line
No.
1
2
3
4
5
6
7

8
9
10
11
12
13

14
15
16
17

or public authority that the energy was delivered to.
SF - for short-term firm transmission service. Use this
Provide the full name of each company or public
category for all firm services, where the duration
authority. Do not abbreviate or truncate name or use
service is less than
of each period of commitment for
interest
footnote
any
ownership
acronyms. Explain in a
one year.
in or affiliation the respondent has with the entities
listed in col1.11111s (a), (b) or (c).
Energy Delive~ed To
Sfatis~ic
Pa~nt Sy
Energy Receired Fro~
(Co~ant or Pu~ ly.Authority) c ass 1 1(Co~ant or Pu~ ly .Aut ority)
(Com~ant or Pu~~ly.Authority)
cat1on
[ oo note A 1 1at1onsl
[ oo note A 1 1at1onsl
[ oo note A 1 1at1onsl
(C)
(d)
(b)
(a)
* OS
City of Gainsville
En ron Power Marketing, Inc.
En ron Power Marketing, Inc.
OS
City of Homestead
En ron Power Marketing, Inc.
En ron Power Marketing, Inc.
OS
City of Key West
En ron Power Marketing, Inc.
En ron Power Marketing, Inc.
OS
Ft. Pierce Utilities Authority
Florida Power Corporation
En ron Power Marketing, Inc.
City of Key !.lest
OS
Florida Power Corporation
En ron Power Marketing, Inc.
City of Vero Beach
OS
Florida Power Corporation
En ron Power Marketing, Inc.
City of New Smyrna Beach
City of Gainesville
OS
En ron Power Marketing, Inc.
City of Gainesville
Southern Company Services, Inc.
OS
En ron Power Marketing, Inc.
*Jacksonville Electric Authority Ft. Pierce Utilities Authority
OS
En ron Power Marketing, Inc.
Jacksonville Electric Authority
City of Gainesville
OS
En ron Power Marketing, Inc.
En ron Power Marketing, Inc.
Jacksonville Electric Authority City of Homestead
OS
City of Key West
Jacksonville Electric Authority
OS
En ron Power Marketing, Inc.
En ron Power Marketing, Inc.
Jacksonville Electric Authority City of Lakeland
OS
Jacksonville Electric Authority *Orlando Utilities Commission
En ron Power Marketing, Inc.
OS
Jacksonville Electric Authority City of Vero Beach
OS
En ron Power Marketing, Inc.
Orlando Utilities Commission
Southern Company Services, Inc.
OS
En ron Power Marketing, Inc.
Southern Company Services, Inc.
Ft. Pierce Utilities Authority
OS
En ron Power Marketing, Inc.

FERC FORM NO.1 (REVISED 12-90)

PAGE 328

 Nfme
of Respon~ent
F orida
Power
Light Company

I

~lisf~fP~~to~~:inal

I

Date of Re~ort
(Mo, Da, Y )

I

Year of Report
Dec. 31' 1996

~
A Resu~ission
(Account 45?)(Continued)
TRANSMISSI?N OF ELECTRICITY FOR ~THERS to
as "whee 1ng")
(Inc ud1ng transactions re erred
as
identified in column (d)' is provided.
OS - for other transmission service. Use this category
Report
receipt and deli very locations for all single
6.
be
placed
in
which
cannot
only for those services
contract path, "point to point" transmission service.
the above-defined categories, such as all nonfirm tran In column (f), report the designation for the substasmission service, regardless of the length of the
tion, or other appropriate identification for where
contract. Describe the nature of the service in a
energy was received as specified in the contract. In
footnote.
column (g) report the designation for the substation,
or other appropriate identification for where energy
AD - for out-of-period adjustment. Use this code for
was delivered as specified in the contract.
any accounting adjustments or "true-ups" for service
Report in column(h) the number of megawatts of billing
7.
provided in prior reporting years. Provide an explanathat is specified in the firm transmission
demand
tion in a footnote for each adjustment.
service
contract.
Demand reported in column (h) must
or
Schedule
FERC
Rate
identify
the
5. In column (e),
be in megawatts. Footnote any demand not stated on a
Tariff Number. On separate lines, list all FERC rate
megawatts basis and explain.
schedules or contract designations under which service,

FE~C

6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6

Rfte
Sc ~?u Nlnlber
e of
Tari
(e)
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6

Point of ReceiBt
(Substation or ther
De~1gnat1on)

(

)

System
System
System
System
System
System
Deerhaven Substation
Deerhaven Substation
System
System
System
System
System
System
System
System
System

>ERC FORM N0.1 (REVISED 12-90)

Point of Delivehy
Ot er
Des1gnat1on)
(g)
Deerhaven Substation
Lucy Substation
Marathon Substation
Hartman Substation
Marathon Substation
System
Smyrna Substation
System
Hartman Substation
Deerhaven Substation
Lucy Substation
Marathon Substation
System
System
System
System
Hartman Substation
(Subst~tlon.or

PAGE 329

Bill~g

Dema

(~~~

TRANSFER OF ENERGY
Megftthours
De 1yered
Receive
( 1)
( J)
7,910
8,128
531
545
118
124
1,297
1,328
79
77
1 '156
1 '130
116
120
2,400
2,400
1,411
1,355
23,949
23,315
10,319
9,944
551
486
29,948
28,567
35,077
33,463
1,847
1 '753
12,010
12,010
171
163

Megattho~rs

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

 Nfme of Respon~ent
L1ght Company
F or ida Power

This Report Is:
Date of Re~ort
Year of Report
CMo, Da, Y )
~~~ fXj A
An Resu
Or1~nal
ission
Dec. 31, 1996
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions referred to as "wheeling")
8. Report in column (i) and (j) the total megawatthours
shown on bills rendered to the entity listed in column
received and delivered.
(a). If no monetary settlement was made, enter zero
9 . In column (k) through (n), report the revenue amounts
C"D"> in column(n). Provide a footnote expla i ning the
as shown on bills or vouchers. In column (k), prov ide
nature of the nonmonetary settlement, including the
revenues from demand charges related to the bill i ng
amount and type of energy or service rendered.
demand reported in column (h). In column Cl). provide
10. Provide total amounts in column (i) through (n) as the
revenues from energy charges related to the amount of
last line. Enter "TOTAL" in column (a) as the last
energy transferred. In column (m), provide the total
line. The total amounts in columns (i) and (j) must be
revenues from all other charges on bills or vouchers
reported as Transmission Received and Delivered on page
rendered, including out of period adjustments. Explain
401' lines 16 and 17, respectively.
in a footnote all components of the amount shown in
11. Footnote entries and provide explanations following
column (m). Report in column (n) the
total charge
all required data.

Demand

I

I

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energff~harges

~harges

h~

~~~

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

FERC FORM N0.1 (REVISED 12-90)

$16,256
1,090
248
2,656
158
2,312
240
4,800
2,822
47,898
20,638
1,102
59,896
70,154
3,694
24,020
342

*
*

*
*
*

*

PAGE 330

0
(1,068)
0
(2,656)
0
(1,864)
0
0
( 1,706)
0
( 16,678)
0
0
0
(1,240)
0
0

I

Total ryvenues($)
(k+ +m)
(n)
$16,256
22
248
0
158
448
240
4,800
1,116
47,898
3,960
1,102
59,896
70,154
2,454
24,020
342

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

Next Page is 332

 Year of Report
Date of Re~ort
Thi s Report Is : .
(Mo, Da, Y )
~B fX~ A
An Resu
Or1~nal
Dec. 311 1996
ission
TRANSMitSIQN OF ELECTRICITY F~R OT~ERS (Account 456?,
(Inc ud1ng transactions re erre to as "wheeling')
4. In column(d) enter a Statistical Clas sification code
1. Report all transmission of electricity, i. e. wheel i ng,
based on the original contractual terms and conditions
provided for other electric utilities, cooperatives ,
the service as follows:
of
authorities,
qualifying
public
muni ci pal it i es, other
and
utility
suppliers
f ac i l i t i es, non-traditional
LF - for long-term firm transmission service. "Long-term"
ultimate customers.
means one year or longe r and "firm" means that service
2. Use a separate line of data for each distinct type of
cannot be interrupted for economic reasons and is
transmission service involving the entities listed in
intended to remain reliable even under adverse concolumn (a), (b) and (c).
ditions. For all transact i ons identified as LF, provide
3. Report in column (a) the company or public author i ty
in
in a footnote the termination date of the contract
that paid for the transmission service. Report
defined as the earliest date that either buyer or
colliTln(b) the company or public authority that the
company
seller can unilaterally get out of the contract.
energy was received from and in column (c) the
authority
that
the
energy
was
delivered
to.
or public
SF - for short - term firm transmission service. Use this
Provide the full name of each company or publ i c
category for all firm services, where the duration
authority. Do not abbreviate or truncate name or use
service is less than
acronyms. Explain in a footnote any ownership interest
of each period of commitment for
one year.
in or affiliation the respondent has with the entit i es
listed i n columns (a), (b) or (c).
Pa~nt Sy
Energy Delive~ed To
Energy Receired Fr~
Sfatisiic
Line
(C~ant or Pu~}lf.Authority)
(Comrant or Pu~ lf .Aut ority)
(C~ant or Pu~ lf .Authority) c ass 1 1[ oo note A 1 1at1onsl
[ oo note A 1 1at1onsl
[ oo note A 1 1at1onsl
cat1on
No.
(a)
(b)
(C)
(d)
1 En ron Power Marketing, Inc.
Southern Company Services, Inc.
City of Gainesville
OS
City of Key West
2 En ron Power Marketing, Inc.
OS
Southern Company Services, Inc.
3 En ron Power Marketing, Inc.
City of Lakeland
OS
Southern Company Services, Inc.
4 En ron Power Marketing, Inc.
Orlando Ut i lities Commission
OS
Southern Company Services, Inc.
City of Gainesville
5 En ron Power Marketing, Inc.
OS
Seminole Electric Cooperative
Seminole Electric Cooperative
City of Key West
6 En ron Power Marketing, Inc.
OS
City of Key West
7
En ron Power Marketing, Inc.
Florida Power Corporation
OS
City of Key West
Orlando Utilities Commission
8 En ron Power Marketing, Inc.
OS
9 * Florida Municipal Power Agency
Ft. Pierce Utilities Authority
Florida Municipal Power Agency
OS
Florida Municipal Power Agency
10
City of Vero Beach
Florida Municipal Power Agency
OS
11 FLorida Power Corporation
Ft. Pierce Utilities Authority
Florida Power Corporation
OS
City of Homestead
12
Florida Power Corporation
Florida Power Corporation
OS
13
Florida Power Corporation
City of Key West
Florida Power Corporation
OS
Florida Power Corporation
14
City of Lake Worth Utilities
Florida Power Corporation
OS
15
Florida Power Corporation
City of Vero Beach
Florida Power Corporation
OS
16
Florida Power Corporation
N/A
N/A
AD
17
Ft. Pierce Utilities Authority
Florida Power Corporation
Ft. Pierce Utilities Authority
OS
Nfme of Respongent
F orida Power
L1ght Company

FERC

NO. 1 (REV ISED 12-90)

I

I

PAGE 328 . 1

I

 I mfXl

Nfme of Respon~ent
F orida Power
L1ght Company

5.

This Report 1~:
Year of Report
Date of Re~ort
(Mo, Da, Y )
An Resu
Or1~nal
A
ission
Dec. 31, 1996
TRANSMISSI?N OF ELECTRICITY FOR ~THERS (Account 45?)(Continued)
(Inc ud1ng transact1ons re erred to as "whee 1ng 11 )
OS · for other transmission service. Use this category
as identified in column (d)' is provided.
only for those services which cannot be placed in
6. Report receipt and deli very locations for all single
the above -defined categories, such as all nonfirm trancontract path, "point to point" transmission service.
smission service, regardless of the length of the
In column (f), report the designation for the substa contract. Describe the nature of the service in a
tion, or other appropriate identification for where
footnote.
energy was received as specified in the contract. In
column (g) report the designation for the substation,
AD - for out-of-period adjustment. Use this code for
or other appropriate identification for where energy
any accounting adjustments or "true-ups" for service
was delivered as specified in the contract.
provided in prior reporting years. Provide an explana7. Report in column(h) the number of megawatts of billing
tion in a footnote for each adjustment.
demand that is specified in the firm transmission
In colLm'l (e), identify the FERC Rate Schedule or
service contract. Demand reported in column (h) must
Tariff Number. On separate lines, list all FERC rate
be in megawatts. Footnote any demand not stated on a
schedules or contract designations under which service,
megawatts basis and explain.

FE~C Rfte
Sc f~u NLmber
e of
Tari
(e)
6 of T-6
6 of T-6
6 of T-6
6 of T-6
6 of T-6
6 of T-6
6 of T-6
6 of T-6
72 of T-6
72 of T-6
24 of T-6
24 of T-6
24 of T-6
24 of T-6
24 of T-6
T-3
16 of T-6

Point of Receigt
(SubstatJon or ther
System
System
System
System
System
System
System
System
Hartman Substation
System
Hartman Substation
Lucy Substation
Marathon Substation
Hypoluxo Substation
System

Point of Delivehy
Ot er
Des1gnat1on)
(g)
Deerhaven Substation
Marathon Substation
System
System
Deerhaven Substation
Marathon Substation
Marathon Substation
Marathon Substation
System
System
System
System
System
System
System

N/A

N/A

System

Hartman Substation

De~1gnat1on)

(

)

FE RC FORM N0.1 (REVISED 12 -90)

I

Bill i~g
Deman

(Subst~tlon_or

(~~~

*
*

PAGE 329.1

TRANSFER OF ENERGY
Megrtthours
De 1yered
Rece1ve
( 1)
(J)
1, 778
1'735
16,273
15,528
2,978
2,873
364
352
1,493
1,478
298
270
1,080
1,050
7,920
7,590
6
6
1
1
29
29
474
446
625
660
2,113
2,202
2,914
3,002
0
0
134
133

Megattho~rs

15
15

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

 Nfme of Respon~ent
L1ght Company
F orida Power

I

l~~ s f~fp~~to~~~oa
l.
A Resu 1SS1

I

Date of Re~ort
(Me, Da, Y )

I

Year of Report
Dec. 31, 1996

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 4 ~ o l (Continued)
(Including transactions referred to as "wheeling")
shown on bills rendered to the entity listed in column
8. Report in column ( i ) and (j) the total megawatthours
(a). If no monetary settlement was made, enter zero
received and delivered.
("D") in column(n). Provide a footnote explaining the
amounts
the
revenue
report
In
column
(k)
through
(n),
9.
nature of the nonmonetary settlement, including the
as shown on bills or vouchers. In column ( k). provide
amount and type of energy or service rendered.
revenues from demand charges related to the billing
10. Provide total amounts in column (i) through (n) as th e
demand reported in column (h). In column ( l). provide
last line. Enter "TOTAL" in column (a) as the last
revenues from energy charges related to the amount of
line. The total amounts in columns (i) and (j) must be
the
total
energy transferred. In column (m), provide
reported
as Transmission Received and Delivered on page
vouchers
on
bills
or
revenues from all other charges
lines
16 and 17, respectively.
401,
out
of
period
adjustments.
Explain
including
rendered,
11 . Footnote entries and provide explanations following
in a footnote all components of the amount shown in
all required data.
total charge
column (m). Report in column (n) the

Demand iharges

~d

.

-

F:O RC

FO R ~

0
0
0
0
0
0
20,220
9,000
0
0
0
0
0
0
0
0
0

RE VISED 12 -90)

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energ{f~harges

~~~

$3,556
33,531
5,956
728
2,986
596
21
155
28
6
107
2,642
3,654
11.909
16,473
0
597

*

*

PAGE 33 0.1

0
(70)
0
0
0
0
0
0
0
0
0
0
0
0
0
(4, 181)
0

Total ryvenues($)
Ck+ +m)
(n)
$3,556
33,461
5,956
728
2,986
596
20,241
9.155
28
6
107
2,642
3,654
11,909
16,473
(4,181)
597

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13

14
15
16
17

Nex t Page is 332

 Nfme of Respongent
L1ght Company
F orida Power

This Report Is:
Date of Re~ort
Year of Report
(Mo, Da, Y )
~~~ fXJ A
An Resu
Or1~nal
ission
Dec. 31, 1996
TRANSMI~SIQN OF ELECTRICITY F~R OT~ERS (Account 456?,
(Inc ud1ng transact1ons re erre to as "wheel1ng 1 )
1. Report all transmission of electricity, i. e. wheeling,
4. In column(d) enter a Statistical Classification code
provided for other electric utilities, cooperatives,
based on the original contractual terms and conditions
municipalities, other
public authorities, qualifying
of the service as follows:
facilities, non-traditional
utility
suppliers
and
ultimate customers.
LF - for long-term firm transmission service. "Long-term"
2. Use a separate line of data for each distinct type of
means one year or longer and "firm" means that service
transmission service involving the entities listed in
cannot be interrupted for economic reasons and is
column (a), (b) and (c).
intended to remain reliable even under adverse con3. Report in column (a) the company or public authority
ditions. For all transactions identified as LF, provide
that paid for the transmission service. Report
in
in a footnote the termination date of the contract
column(b) the company or public authority that the
defined as the earliest date that either buyer or
energy was received from and in column (c) the company
seller can unilaterally get out of the contract.
or public authority that the energy was delivered to.
Provide the full name of each company or public
SF - for short-term firm transmission service. Use this
authority. Do not abbreviate or truncate name or use
category for all firm services, where the duration
acronyms. Explain in a footnote any ownership interest
of each period of commitment for
service is less than
in or affiliation the respondent has with the entities
one year.
listed in columns (a), (b) or (c).
Pa~nt ijy
Energy Delive~ed To
Energy Receired Fr~
sratisiic
Line
(Com~ant or Pu~ lf_Aut ority)
(C~ant or Pu~~lf.Authority)
(Com~ant or Pu~ lf.Authority) C ass 1 1No.
[ oo note A 1 1at1onsJ
[ oo note A 1 1at1onsJ
[ oo note A 1 1at1onsJ
cat1on
(a)
(b)
(c)
(d)
1 Ft. Pierce Utilities Authority
City of Gainesville
Ft. Pierce Utilities Authority
OS
2
Ft. Pierce Utilities Authority
Jacksonville Electric Authority
Ft. Pierce Utilities Authority
OS
3
Ft. Pierce Utilities Authority
City of Lake Worth Utilities
Ft. Pierce Utilities Authority
OS
Ft. Pierce Utilities Authority
4
Orlando Utilities Commission
Ft. Pierce Utilities Authority
OS
Ft. Pierce Utilities Authority
5
Seminole Electric Cooperative
Ft. Pierce Utilities Authority
OS
6
Ft. Pierce Utilities Authority
Tampa Electric Company
Ft. Pierce Utilities Authority
OS
7
Ft. Pierce Utilities Authority
N/A
N/A
AD
Ft. Pierce Utilities Authority
City of Gainesville
OS
8 City of Gainesivlle
City of Homestead
City of Gainesville
9 City of Gainesville
OS
City of Gainesville
City of Gainesville
City of Lake Worth Utilities
OS
10
City of Vera Beach
City of Gainesville
OS
11 City of Gainesville
City of Gainesville
N/A
N/A
AD
12
City of Homestead
Florida Power Corporation
OS
City of Homestead
13
Ft. Pierce Utilities Authority
City of Homestead
City of Homestead
OS
14
City of Gainesville
City of Homestead
City of Homestead
OS
15
City of Homestead
Jacksonville Electric Authority City of Homestead
OS
16
City of Key West
City of Homestead
OS
17 City of Homestead

' ERC FORM N0.1 (REVISED 12-90)

I

I

PAGE 328.2

l

 Year of Report
Date of Report
This Report Is: .
(Mo, Da, Yr)
a~ fXl A
An Resu
Or1~nal
Dec.
31, 1996
ission
1
TRANSMISSI?N OF ELECTRICITY FOR ~THERS (Account 45?)(Continued)
(Inc ud1ng transact1ons re erred to as "whee 1ng")
as identified in column (d). is provided.
: her transmission service. Use this category
OS ·
Report receipt and delivery locations for all single
in
6.
be
placed
which
cannot
those services
onl ·
contract path, "point to point" transmission service.
such
as
all
nonfirm
trandefined
categories,
the a •.
In column (f), report the designation for the substasmission service, regardless of the length of the
tion, or other appropriate identification for where
contract. Describe the nature of the service in a
energy was received as specified in the contract. In
footnote.
column (g) report the designation for the substation,
or other appropriate identification for where energy
AD - for out-of-period adjustment. Use this code for
was delivered as specified in the contract.
any accounting adjustments or "true-ups" for service
7. Report in column(h) the number of megawatts of billing
provided in prior reporting years. Provide an explana demand that is specified in the firm transmission
· ion in a footnote for each adjustment.
service contract. Demand reported in column (h) must
: olumn (e), identify the FERC Rate Schedule or
·< f Number. On separate lines, list all FERC rate
be in megawatts. Footnote any demand not stated on a
megawatts basis and explain.
J ules or contract designations under which service,

Nfme of Respongent
F orida Power
L1ght Company

5.

FERC Rfte
Schf1u e of
Number
Tari
(e)
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6

16
16
16
16
16
16
T-3
26 of
26 of
26 of
26 of
T-3
30 of
30 of
30 of
30 of
30 of

T-6
T-6
T-6
T-6
T-6
T-6
T-6
T-6
T-6

Point ~f ReceiBt
(Substatlon Qr ther
De~1gnat1on)

(

)

Deerhaven Substation
System
Hypoluxo Substation
System
System
System
N/A
Hartman Substation
Lucy Substation
Hypoluxo Substation
System
N/A
System
Hartman Substation
Deerhaven Substation
System
Marathon Substation

FER ' FORM N0. 1 (REVISED 12- 90)

I

I

Point Qf Delivery
or Other
Des1gnation)
(g)
Hartman Substation
Hartman Substation
Hartman Substation
Hartman Substation
Hartman Substation
Hartman Substation
N/A
Deerhaven Substation
Deerhaven Substation
Deerhaven Substation
Deerhaven Substation
N/A
Lucy Substation
Lucy Substation
Lucy Substation
Lucy Substation
Lucy Substation
(Subst~tlon

PAGE 329 .2

Bill igg
Deman

(~~~

TRANSFER OF ENERGY
Megrtthours
De 1yered
Rece1ve
(j)
( 1)
49
51
831
807
9
10
13,379
13,115
857
845
15,293
15,094
0
0
9
9
6
6
156
171
203
213
0
0
1,186
1,135
2
2
2,377
2,181
6,441
5,931
59
59

Megattho~rs

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

 Nrme of Respon~ent
F orida Power
L1ght Company

This Report 1$:
Year of Report
Date of Re~ort
(Mo, Da, Y )
~~~ fXj A
An Resu
Or1~nal
ission
Dec. 31, 1996
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions referred to as "wheeling")
B. Report in column (i) and (j) the total megawatthours
shown on bills rendered to the entity listed in column
received and delivered.
(a). If no monetary settlement was made, enter zero
9. In column (k) through (n), report the revenue amounts
("0") in column(n). Provide a footnote explaining the
as shown on bills or vouchers. In column ( k)' provide
nature of the nonmonetary settlement, including the
revenues from demand charges related to the billing
amount and type of energy or service rendered.
demand reported in column (h). In column ( l)' provide
10. Provide total amounts in column (i) through (n) as the
revenues from energy charges related to the amount of
last line. Enter "TOTAL" in column (a) as the last
energy transferred. In column (m), provide the total
line. The total amounts in columns (i) and (j) must be
revenues from all other charges on bills or vouchers
reported as Transmission Received and Delivered on page
rendered, including out of period adjustments. Explain
401, lines 16 and 17, respectively.
in a footnote all components of the amount shown in
11. Footnote entries and provide explanations following
column (m). Report in column (n) the
total charge
all required data.

I

I

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energff~harges

Demand iharges

~~~

~d

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

FERC FORM N0.1 (REVISED 12-90)

$149
1,760
44
26,963
4,351
71,617
0
21
34
869
961
0
4,609
7
7,577
29' 171
234

*
*
*
*
*
*

*
*
*
*

PAGE 330.2

($25)
(1,500)
0
(576)
(3,822)
(64,493)
(606)
0
0
0
0
( 190)
(249)
0
(322)
(23, 109)
0

I

Total rtvenues($)
(k+ +m)
(n)
$124
260
44
26,387
529
7,124
(606)
21
34
869
961
( 190)
4,360
7
7,255
6,062
234

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13

14
15
16
17

Next Page is 332

 Year of Report
Date of Re~ort
This Report Is: .
(Mo, Da, Y )
~~~ fXl A
An Resu
Or1~nal
Dec. 31, 1996
ission
TRANSMI~SIQN OF ELECTRICITY F~R OT~ERS (Account 456~
(Inc ud1ng transact1ons re erre to as "wheel1ng')
4. In column(d) enter a Statistical Classification code
1. Report all transmission of electricity, i. e. wheeling,
based on the original contractual terms and conditions
provided for other electric utilities, cooperatives,
of the service as follows:
public authorities, qualifying
municipalities, other
and
utility
suppliers
facilities, non-traditional
LF - for long-term firm transmission service. "Long-term"
ultimate customers.
means
one year or longer and "firm" means that service
distinct
type
of
for
each
line
of
data
a
separate
Use
2.
cannot be interrupted for economic reasons and is
transmission service involving the entities listed in
intended to remain reliable even under adverse concolumn (a), (b) and (c).
ditions. For all transactions identified as LF, provide
3. Report in column (a) the company or public authority
in
in a footnote the termination date of the contract
that paid for the transmission service. Report
defined as the earliest date that either buyer or
column(b) the company or public authority that the
seller can unilaterally get out of the contract.
energy was received from and in column (c) the company
or public authority that the energy was delivered to.
SF - for short-term firm transmission service. Use this
Provide the full name of each company or public
category for all firm services, where the duration
authority. Do not abbreviate or truncate name or use
service is less than
of each period of commitment for
acronyms. Explain in a footnote any ownership interest
one year.
in or affiliation the respondent has with the entities
listed in columns (a), (b) or (c).
Pa}'ll1!1nt Sy
Energy Delive~ed To
Energy Receired Fr~
Sfatis~ic
Line
ccoTFant or Pu~ ly_Authority) Cass11·
CComFant or Pu~ ly _Aut ority)
cc~ant or Pu~~ly.Authority)
[ oo note A 1 1at1onsl
cat1on
[ oo note A 1 1at1onsl
[ oo note A 1 1at1onsl
No.
(C)
(d)
(a)
(b)
City of Lake Worth Utilities
City of Homestead
OS
1 City of Homestead
City of New Smyrna Beach
City of Homestead
OS
2 :-ity of Homestead
City of Homestead
OS
3 City of Homestead
Orlando Utilities Commission
City of Homestead
OS
Seminole Electric Cooperative
4 City of Homestead
City of Tallahassee
City of Homestead
OS
5 City of Homestead
Tampa Electric Company
City of Homestead
OS
6 City of Homestead
City of Vero Beach
City of Homestead
OS
City of Homestead
7
AD
N/A
N/A
8 City of Homestead
City of Gainesville
Jacksonville Electric Authority
OS
Jacksonville Electric Authority
9
City of Homestead
Jacksonville Electric Authority
OS
Jacksonville Electric Authority
10
City of Lake Worth Utilities
Jacksonville Electric Authority
OS
11 Jacksonville Electric Authority
City of New Smyrna Beach
Jacksonville Electric Authority
Jacksonville Electric Authority
OS
12
Jacksonville Electric Authority
Orlando Utilities Commission
Jacksonville Electric Authority
OS
13
Jacksonville Electric Authority
Southern Company Services Inc
Jacksonville Electric Authority
OS
14
City of Tallahassee
15
Jacksonville Electric Authority
Jacksonville Electric Authority
OS
Tampa Electric Company
Jacksonville Electric Authority
Jacksonville Electric Authority
OS
16
City of Vero Beach
Jacksonville Electric Authority
OS
17 Jacksonville Electric Authority
Nfme of Respon~ent
F orida Power
L1ght Company

-

-

FERC FORM N0.1 (REVISED 12-90)

l

I

PAGE 328.3

I

 Nfme of Respon~ent
F orida Power
L1ght Company

5.

This Report Is:.
Date of Report
Year of Report
(Mo, Da, Yr)
An Resu
Or1g.:,nal
A
ission
Dec. 31' 1996
TRANSMISSI?N OF ELECTRICITY FOR ~THERS (Account 45?)(Continued)
(Inc ud1ng transact1ons re erred to as "whee 1ng 11 )
OS - for other transmission service. Use this category
as identified in column (d), is provided.
only for those services which cannot be placed in
6. Report receipt and delivery locations for all single
the above-defined categories, such as all nonfirm trancontract path, "point to point" transmission service.
smission service, regardless of the length of the
In column (f), report the designation for the substacontract. Describe the nature of the service in a
tion, or other appropriate identification for where
footnote.
energy was received as specified in the contract. In
column (g) report the designation for the substation,
AD - for out-of-period adjustment. Use this code for
or other appropriate identification for where energy
any accounting adjustments or "true-ups" for service
was delivered as specified in the contract.
provided in prior reporting years. Provide an explana7. Report in column(h) the number of megawatts of billing
tion in a footnote for each adjustment.
demand that is specified in the firm transmission
In column (e), identify the FERC Rate Schedule or
service contract. Demand reported in column (h) must
Tariff Number. On separate lines, list all FERC rate
be in megawatts. Footnote any demand not stated on a
schedules or contract designations under which service,
megawatts basis and explain.

FE~C Rfte
Sc f1u Number
e of
Tari
(e)
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6

30
30
30
30
30
30
30
T-3
36 of
36 of
36 of
36 of
36 of
36 of
36 of
36 of
36 of

I mfXJ

T-6
T-6
T-6
T-6
T-6
T-6
T-6
T-6
T-6

Point of Receigt
(Substatlon or ther
De~1gnat1on)

(

)

Hypoluxo Substation
Smyrna Substation
System
System
System
System
System
N/A
Deerhaven Substation
Lucy Substation
Hypoluxo Substation
Smyrna Substation
System
System
System
System
System

FERC FORM N0.1 (REVISED 12-90)

Point of Delivehy
Ot er
Des1gnat1on)
(g)
Lucy Substation
Lucy Substation
Lucy Substation
Lucy Substation
Lucy Substation
Lucy Substation
Lucy Substation
N/A
System
System
System
System
System
System
System
System
System
csubst~t1on . or

PAGE 329.3

I

Bill~g

Dema

(~~~

TRANSFER OF ENERGY
Megftthours
Rece1ve
De 1yered
( 1)
( J)
1,223
1,234
15
15
856
799
5,281
5,005
184
171
22,915
21,858
980
953
0
0
979
987
95
101
181
192
22
23
2,134
2,158
542
536
59
60
15,842
16,058
283
294

Megattho~rs

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

 Nfme of Respongent
F orida Power
L1ght Company

This Report Is:

Date of

Re~ort

(Mo, Da, Y )
fXl A
An Resu ission
I
I
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
a~

Or1~nal

I

Year of Report
Dec. 31' 1996

(Including transactions referred to as "wheeling")
8. Report in column (i) and (j) the total megawatthours
shown on bills rendered to the entity listed in column
received and delivered.
(a). If no monetary settlement was made, enter zero
("D") in column(n). Provide a footnote explaining the
9. In column (k) through (n), report the revenue amounts
as shown on bills or vouchers. In column ( k)' provide
nature of the nonmonetary settlement, including the
revenues from demand charges related to the billing
amount and type of energy or service rendered.
demand reported in column (h). In column ( l)' provide
10. Provide total amounts in column (i) through (n) as the
revenues from energy charges related to the amount of
last line. Enter "TOTAL" in column (a) as the last
energy transferred. In column (m), provide the total
line. The total amounts in columns (i) and (j) must be
revenues from all other charges on bills or vouchers
reported as Transmission Received and Delivered on page
rendered, including out of period adjustments. Explain
401, lines 16 and 17, respectively.
in a footnote all components of the amount shown in
11. Footnote entries and provide explanations following
column (m). Report in column (n) the
total charge
all required data.

Demand

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energrf~harges

~harges

~~~

~d

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

0

ERC FORM N0.1 (REVISED 12-90)

$4,660
70
3,038
22,135
688
111,559
3,042
0
4,452
552
725
130
9,495
1,084
302
62,685
1,505

*
*
*
*
*
*
*

PAGE 330.3

($82)
0
(352)
(3,055)
(37)
(5,336)
( 133)
(480)
0
0
0
0
0
0
0
0
0

Total ryvenues($)
(k+ +m)
(n)
$4,578
70
2,686
19,080
651
106,223
2,909
(480)
4,452
552
725
130
9,495
1,084
302
62,685
1,505

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

Next Page is 332

 Year of Report
This Report Is: .
Date of Re~ort
(Mo, Da, Y )
~~~ fXJ A
An Resu
Or1~nal
Dec. 31' 1996
ission
TRANSMitSIQN OF ELECTRICITY F~R OT~ERS (Account 456?,
(Inc ud1ng transact1ons re erre to as "wheel1ng ')
1. Report all transmission of electricity, i. e. wheeling,
4. In column(d) enter a Statistical Classification code
based on the original contractual terms and conditions
provided for other electric utilities, cooperatives,
public authorities, qualifying
of the service as follows:
municipalities, other
utility
suppliers
and
facilities, non-traditional
ultimate customers.
LF - for long-term firm transmission service. "long-term"
means one year or longer and "firm" means that service
2. Use a separate line of data for each distinct type of
cannot be interrupted for economic reasons and is
transmission service involving the entities listed in
column (a), (b) and (c).
intended to remain reliable even under adverse conditions. For all transactions identified as LF, provide
3. Report in column (a) the company or public authority
that paid for the transmission service. Report
in
in a footnote the termination date of the contract
column(b) the company or public authority that the
defined as the earliest date that either buyer or
energy was received from and in column (c) the company
seller can unilaterally get out of the contract.
or public authority that the energy was delivered to.
Provide the full name of each company or public
SF - for short-term firm transmission service. Use this
category for all firm services, where the duration
authority. Do not abbreviate or truncate name or use
of each period of commitment for
acronyms. Explain in a footnote any ownership interest
service is less than
one year.
in or affiliation the respondent has with the entities
listed in col~.nns (a), (b) or (c).
Payment 6Y
Energy Delive}ed To
Energy Recei!ed Fr~
S[atislic
Line
(C~ant or Pu~ lt_Aut ority)
(C~ant or Pu~ lt_Authority) c ass 1 1(C~ant or Pu~ilt _ Authority)
No.
[ oo note A 1 1at1onsJ
[ oo note A 1 1at1onsJ
[ oo note A 1 1at1onsJ
cat1on
(a)
(b)
(c)
(d)
1 Jacksonville Electric Authority
N/A
N/A
AD
Florida Power Corporation
Utility Board City of Key West
2 Utility Board City of Key West
OS
City of Gainesville
Utility Board City of Key West
3 Utility Board City of Key West
OS
Utility Board City of Key West
City of Homestead
Utility Board City of Key West
4
OS
5 Utility Board City of Key West
Jacksonville Electric Authority Utility Board City of Key West
OS
Utility Board City of Key West
City of lake Worth Utilities
Utility Board City of Key West
6
OS
Utility Board City of Key West
7 Utility Board City of Key West
Orlando Utilities Commission
OS
Utility Board City of Key West
8
Seminole Electric Cooperative Inc Utility Board City of Key West
OS
City of Tallahassee
Utility Board City of Key West
9 Utility Board City of Key West
OS
Tampa Electric Company
Utility Board City of Key West
10 Utility Board City of Key West
OS
Utility Board City of Key West
11 Utility Board City of Key West
City of Vero Beach
OS
12
Utility Board City of Key West
N/A
N/A
AD
Kissimmee Utility Authority
13
N/A
N/A
AD
City of lake Worth Utilities
14
City of Lake Worth Utilities
Florida Power Corporation
OS
City of lake Worth Utilities
Ft. Pierce Utilities Authority
City of lake Worth Utilities
OS
15
City of Lake Worth Utilities
City of Gainesville
City of Lake Worth Utilities
16
OS
City of Homestead
City of Lake Worth Utilities
17 City of Lake Worth Utilities
OS
Nfme of Respon~ent
F orida Power
L1ght Company

FERC FORM N0.1 (REVISED 12-90)

I

I

PAGE 328.4

I

 I m

Year of Report
Date of Report
Thi s Report Is: .
(Mo, Da, Yr)
fXJ A
An Resu
Or1Elri,nal
ission
Dec. 31' 1996
TRANSMISSI?N OF ELECTRICITY FOR ~THERS (Account 45?)(Continued)
(Inc ud1ng transact1ons re erred to as "whee 1ng")
OS - for other transmission service. Use this category
as identified in column (d), is provided.
only for those services which cannot be placed in
6. Report receipt and delivery locations for all s ingle
the above-defined categories, such as all nonf i rm trancontract path, "point to point" transmission service.
In column (f), report the designation for the substasmission service, regardless of the length of the
tion, or other appropriate identification for where
contract. Describe the nature of the service in a
energy was received as specified in the contract. In
footnote.
column (g) report the designation for the substation,
AD - for out-of-period adjustment. Use this code for
or other appropriate identification for where energy
was delivered as specified in the contract.
any accounting adjustments or "true-ups" for service
provided in prior reporting years. Provide an explana7. Report in column(h) the number of megawatts of billing
tion in a footnote for each adjustment.
demand that is specified in the firm transmission
In column (e), identify the FERC Rate Schedule or
service contract. Demand reported in column (h) must
be in megawatts. Footnote any demand not stated on a
Tariff Number . On separate lines, list all FERC rate
megawatts basis and explain.
schedules or contract designations under which service,

Nfme of Respongent
L1ght Company
F orida Power

5.

FE~C Rfte
Sc ?1u e of
Tar1
Nl.lllber
(e)

T-3
22 of
22 of
22 of
22 of
22 of
22 of
22 of
22 of
22 of
22 of
T-3
T-3
34 of
34 of
34 of
34 of

De~1gnat1on)

(

)

N/A
System
Deerhaven Substation
Lucy Substation
System
Hypoluxo Substation
System
System
System
System
System
N/A
N/A
System
Hartman Substation
Deerhaven Substation
Lucy Substation

T-6
T-6
T-6
T-6
T-6
T-6
T-6
T-6
T-6
T-6

T-6
T-6
T-6
T-6

ERC FORM

Point of Receigt
(Substatlon or ther

~0. 1

(REVISED 12 - 90)

Point of Delivehy
or Ot er
Des1gnation)
(g)

(Subst~t1on

N/A
Marathon
Marathon
Marathon
Marathon
Marathon
Marathon
Marathon
Marathon
Marathon
Marathon
N/A
N/A
Hypoluxo
Hypoluxo
Hypoluxo
Hypoluxo

Substation
Substation
Substation
Substation
Substation
Substation
Substation
Substation
Substation
Substation

Substation
Substation
Substation
Substation

PAGE 329.4

I

Bill~g

Dema

(~~~

I

TRANSFER OF ENERGY
Megftthours
De 1yered
Rece1ve
( 1)
( J)
0
0
500
462
225
207
271
270
1, 750
1,595
59
59
11,814
11,156
3,032
2,851
15
14
6,212
5,949
1,324
1,366
0
0
0
0
23
23
10
10
2,000
2,150
57
57

Megattho~rs

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

 m

Year of Report
This Report Is:.
Date of Re~ort
(Mo, Da, Y )
fXl A
An Resu
Or1~nal
Dec. 31' 1996
ission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions referred to as "wheeling")
shown on bills rendered to the entity listed in column
8. Report in column (i) and (j) the total megawatthours
(a). If no monetary settlement was made, enter zero
received and delivered.
("0") in column(n). Provide a footnote explaining the
9. In column (k) through (n), report the revenue amounts
nature of the nonmonetary settlement, including the
as shown on bills or vouchers. In column (k), provide
amount and type of energy or service rendered.
revenues from demand charges related to the billing
demand reported in column (h). In column (l)' provide
1D. Provide total amounts in column (i) through (n) as the
revenues from energy charges related to the amount of
last line. Enter "TOTAL" in column (a) as the last
energy transferred. In column (m), provide the total
line. The total amounts in columns (i) and (j) must be
revenues from all other charges on bills or vouchers
reported as Transmission Received and Delivered on page
rendered, including out of period adjustments. Explain
401, lines 16 and 17, respectively.
11. Footnote entries and provide explanations following
in a footnote all components of the amount shown in
column (m). Report in column (n) the
total charge
all required data.

Nfme of Respongent
F orida Power
L1ght Company

I

I

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energff~harges

Demand iharges

~~~

~d

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

FERC FORM N0.1 (REVISED 12-90)

0
2,796
706
1,509
9,702
223
40,011
7,958
61
16,197
7,660
0
0
87
48
10,163
299

*
*

*
*

*
*
*
*
*
*

PAGE 330.4

($1,512)
(50)
0
0
(9,548)
0
( 1'046)
0
0
(7,074)
0
(931)
(934)
(49)
0
(2,714)
(5)

I

Total ryvenues($)
{k+ +m)
(n)
($1,512)
2,746
706
1,509
154
223
38,965
7,958
61
9,123
7,660
(931)
(934)
38
48
7,449
294

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

Next Page is 332

 Year of Report
This Report Is: .
Date of Re~ort
(Mo, Da, Y )
~~~ fXJ A
An Resu
Or1~nal
Dec. 31, 1996
ission
TRANSMITSION OF ELECTRICITY F~R OT~ERS (Account 456?,
(Inc ud1ng transact1ons re erre to as "wheel1ng')
1. Report all transmission of electricity, i. e. wheeling,
4. In column(d) enter a Statistical Classification code
provided for other electric utilities, cooperatives,
based on the original contractual terms and conditions
municipalities, other
public authorities, qualifying
of the service as follows:
utility
facilities, non-traditional
suppliers
and
ultimate customers.
LF - for long-term firm transmission service. "Long - term"
means one year or longer and "firm" means that service
2. Use a separate line of data for each distinct type of
transmission service involving the entities listed in
cannot be interrupted for economic reasons and is
column (a), (b) and (c).
intended to remain reliable even under adverse con3. Report in column (a) the company or public author i ty
ditions. For all transactions identified as LF, provide
that paid for the transmission service. Report
in
in a footnote the termination date of the contract
coll11111(b) the company or public authority that the
defined as the earliest date that either buyer or
seller can unilaterally get out of the contract.
energy was received from and in coll11111 (c) the company
or public authority that the energy was delivered to.
Provide the full name of each company or public
SF - for short-term firm transmission service. Use this
authority. Do not abbreviate or truncate name or use
category for all firm services, where the duration
acronyms. Explain in a footnote any ownership interest
of each period of commitment for
service is less than
in or affiliation the respondent has with the entit i es
one year .
lis ted in columns (a), (b) or (c).
Payment 8Y
Energy Delive~ed To
Energy Receired Fr~
Sfatis~ic
Line
(Co~ant or Pu~ lt _Aut ority)
(C~ant or Pu~ lt _Authority) c ass 1 1(C~ant or Pu~}lt _ Authority)
[ oo note A 1 1at1ons]
[ oo note A 1 1at1ons]
[ oo note A 1 1at1ons]
cat1on
No.
(d)
(a)
(b)
(c)
1 City of Lake Worth Utilities
Jacksonville Electric Authority
City of Lake Worth Utilities
OS
City of Lake Worth Utilities
2 City of Lake Worth Utilities
City of Key West
OS
City of New Smyrna Beach
City of Lake Worth Utilities
OS
3 City of Lake Worth Utilities
Orlando Utilities Commission
City of Lake Worth Utilities
OS
4 City of Lake Worth Utilities
OS
5 City of Lake Worth Utilities
Seminole Electric Cooperative Inc City of Lake Worth Utilities
City of Lake Worth Utilities
City of Tallahassee
OS
6 City of Lake Worth Utilities
City of Lake Worth Utilities
Tampa Electric Company
OS
7 City of Lake Worth Utilities
City of Vera Beach
City of Lake Worth Utilities
OS
8 City of Lake Worth Utilities
N/A
AD
N/A
9 City of Lake Worth Utilities
City of Gainesville
Jacksonville Electric Authority
OS
10
Louisville Power Marketing
Marketing
Orlando
Uti
l
ities
Commission
City of Gainesville
OS
Power
11
Louisville
Southern Company Services, Inc.
OS
Orlando Utilities Commission
12
Louisville Power Marketing
City of Key West
Southern Company Services, Inc.
OS
13
Louisville Power Marketing
City of Homestead
City of New Smyrna Beach
OS
City of New Smyrna Beach
14
City of New Smyrna Beach
City of Lake llorth Utilities
OS
City of New Smyrna Beach
15
City of Vera Beach
City of New Smyrna Beach
OS
16 City of New Smyrna Beach
N/A
AD
N/A
17 City of New Smyrna Beach
Nfme of Respon~ent
L1ght Company
F orida Power

,...
,...

I

I

,....
ERC FORM N0.1 (REVISED 12 -90)

PAGE 328 . 5

I

 Year of Report
This Report I$:.
Date of Re~ort
(Mo, Da, Y )
~~~ fXJ A
An Resu
Or1~nal
Dec. 31, 1996
ission
TRANSMISSI?N OF ELECTRICITY FOR ~THERS (Account 45~)(Continued)
(Inc ud1ng transact1ons re erred to as "whee 1ng")
OS - for other transmission service. Use this category
as identified in column (d), is provided.
6. Report receipt and delivery locations for all single
only for those services which cannot be placed in
the above-defined categories, such as all nonfirm trancontract path, "point to point" transmission service.
In column (f), report the designation for the substasmission service, regardless of the length of the
contract. Describe the nature of the service in a
tion, or other appropriate identification for where
energy was received as specified in the contract. In
footnote.
column (g) report the designation for the substation,
AD - for out-of-period adjustment. Use this code for
or other appropriate identification for where energy
any accounting adjustments or "true-ups" for service
was delivered as specified in the contract.
provided in prior reporting years. Provide an explana7. Report in column(h) the number of megawatts of billing
tion in a footnote for each adjustment.
demand that is specified in the firm transmission
In column (e), identify the FERC Rate Schedule or
service contract. Demand reported in column (h) must
be in megawatts. Footnote any demand not stated on a
Tariff Number. On separate lines, list all FERC rate
schedules or contract designations under which service,
megawatts basis and explain.

Nfme of Respongent
L1ght Company
F orida Power

5.

FE~C Rfte
Sc i~u Number
e of
Tar1
(e)
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6

34
34
34
34
34
34
34
34
T-3
12 of
12 of
12 of
12 of
84 of
84 of
84 of
T-3

T-6
T-6
T-6
T-6
T-6
T-6
T-6

Point of Receigt
(SubstatJon or ther
De~1gnat1on)

(

)

System
Marathon Substation
Smyrna Substation
System
System
System
System
System
N/A
System
System
System
System
Lucy Substation
Hypoluxo Substation
System
N/A

FERC FORM N0.1 (REVISED 12-90)

I

I

I

Point of Delivehy
Ot er
Des1gnat1on)
(g)
Hypoluxo Substation
Hypoluxo Substation
Hypoluxo Substation
Hypoluxo Substation
Hypoluxo Substation
Hypoluxo Substation
Hypoluxo Substation
Hypoluxo Substation
N/A
Deerhaven Substation
Deerhaven Substation
System
Marathon Substation
Smyrna Substaiton
Smyrna Substation
Smyrna Substation
N/A
(Subst~t1on . or

PAGE 329.5

Bill~g

Dema

(~~~

TRANSFER OF ENERGY
Megrtthours
De 1yered
Rece1ve
( 1)
( J)
792
720
47
47
34
32
7,631
7,247
19,277
18,062
756
694
3,269
3,105
812
783
0
0
4,247
4,163
3,610
3,671
1,688
1,688
3,633
3,473
68
70
381
390
590
600
0
0

Megattho~rs

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13

14
15
16
17

 Year of Report
This Report Is:
Date of Re~ort
(Mo, Da, Y )
~~~
An Resu
Or1~nal
Dec. 31, 1996
ission
A
·TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions referred to as "wheeling")
- ·-··
shown on bills rendered to the entity listed in column
8. Repc· •. in column (i) and (j) the total megawatthours
recel\,.
and delivered.
(a). If no monetary settlement was made, enter zero
("0") in column(n). Provide a footnote explaining t ne
9. In col .r:- (I<) through (n), report the revenue amounts
as shown on bills or vouchers. In column (i<), provide
nature of the nonmonetary settlement, including the
revenues from demand charges related to the billing
amount and type of energy or service rendered.
demand reported in column (h). In column (l)' provide
10. Provide total amounts in column (i) through (n) as the
revenues from energy charges related to the amount of
last line. Enter "TOTAL" in column (a) as the last
line. The total amounts in columns (i) and (j) must be
energy transferred. In column (m), provide the total
revenues from all other charges on bills or vouchers
reported as Transmission Received and Delivered on page
rendered, including out of period adjustments. Explain
401, lines 16 and 17, respectively.
in a footnote all components of the amount shown in
11. Footnote entries and provide explanations following
column (m). Report in column (n) the
total charge
all required data.

Nfme of Respongent
L1ght Compa
F orida Power

$3,052
212
148
16,923
58,830
3,539
16,976
3,783
0
8,494
7,796
3,520
7,266
381
2,183
3,381
0

0

FORM

~J . 1

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

(REVISED

I

~~~

~I<~

FcP. C

txl

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energrt~harges

Demand iharges

-

I

J)

*
*
*
*
*
*
*

*

PAGE 330 .5

($928)
0
0
(949)
(20,275)
(1,346)
(5,606)
(840)
(542)
0
0
0
0
0
0
0
(342)

I

Total ryvenues($)
(I<+ +m)
(n)
$2,124
212
148
15,974
38,555
2,193
11,370
2,943
(542)
8,494
7,796
3,520
7,266
381
2,183
3,381
(342)

Line
No.
1
2
3
4
5
6
7
8

9
10
11
12
13
14
15
16
17

Next Page i s 332

 Year of Report
This Report Is:.
Date of Report
(Mo, Da, Yr)
~~~ fXl A
An Resu
Or1~nal
ission
Dec. 31, 1996
TRANSMI~SIQN OF ELECTRICITY F~R OT~ERS (Account 456?,
(Inc ud1ng transact1ons re erre to as "wheel1ng')
4. In column(d) enter a Statistical Classification code
1. Report all transmission of electricity, i. e. wheeling,
based on the original contractual terms and conditions
provided for other electric utilities, cooperatives,
public authorities, qualifying
of the service as follows:
municipalities, other
utility suppliers
and
f ac i l it i es, non-traditional
LF - for long-term firm transmission service. "Long-term"
ultimate customers.
means one year or longer and "firm" means that service
2. Use a separate line of data for each distinct type of
transmission service involving the entities listed in
cannot be interrupted for economic reasons and is
column (a), (b) and (c).
intended to remain reliable even under adverse conditions. For all transactions identified as LF, provide
3. Report in colunn (a) the company or public authority
that paid for the transmission service. Report
in
in a footnote the termination date of the contract
column(b) the company or public authority that the
defined as the earliest date that either buyer or
energy was received from and in colunn (c) the company
seller can unilaterally get out of the contract.
or public authority that the energy was delivered to.
Provide the full name of each company or public
SF - for short-term firm transmission service. Use this
authority. Do not abbreviate or truncate name or use
category for all firm services, where the duration
acronyms. Explain in a footnote any ownership interest
of each period of commitment for
service is less than
in or affiliation the respondent has with the entities
one year.
listed in col~.nns (a), (b) or (c).
Pa~nt 6Y
Energy Delive~ed To
Energy Recei}ed Fr~
Line
cSfatisiic
ass 1 1(Com~anr or Pu~ ly_Aut ority)
(Co~anr or Pu~ ly _Authority)
(C~anr or Pu~}ly.Authority)
[ oo note A 1 1at1onsl
No.
[ oo note A 1 1at1onsl
[ oo note A 1 1at1onsl
cat1on
(a)
(b)
(c)
(d)
Jacksonville Electric Authority
City of Key \olest
1 No rAm Energy Services
OS
2 No rAm Energy Services
Seminole Electric Cooperative
City of Key IJest
OS
3 Orlando Utilities Conmission
Ft. Pierce Utilities Authority
Orlando Utilities Commission
OS
4 Orlando Utilities Commission
City of Homestead
Orlando Utilities Commission
OS
City of Lake \olorth Utilities
5 Orlando Utilities Conmission
Orlando Utilities Commission
OS
City of Vero Beach
6
Orlando Utilities Commission
Orlando Utilities Commission
OS
7 Reedy Creek Improvement District
City of Lake \olorth Utilities
Reedy Creek Improvement District
OS
8 Seminole Electric Cooperative, Inc.
Florida Power Corporation
Seminole Electric Cooperative
OS
9 Seminole Electric Cooperative, Inc.
Ft. Pierce Utilities Authority
Seminole Electric Cooperative
OS
City of Gainesville
10 Seminole Electric Cooperative, Inc.
Seminole Electric Cooperative
OS
City of Homestead
11
Seminole Electric Cooperative, Inc.
Seminole Electric Cooperative
OS
City of Key \olest
12 Seminole Electric Cooperative, Inc.
Seminole Electric Cooperative
OS
City of Lake IJorth Utilities
13
Seminole Electric Cooperative, Inc.
Seminole Electric Cooperative
OS
14 Seminole Electric Cooperative, Inc.
Orlando Utilities Conmission
Seminole Electric Cooperative
OS
Seminole Electric Cooperative, Inc.
Tampa Electric Company
15
Seminole Electric Cooperative
OS
City of Vero Beach
16 Seminole Electric Cooperative, Inc.
Seminole Electric Cooperative
OS
17 Seminole Electric Cooperative, Inc.
N/A
N/A
AD
NTme of Respongent
L1ght Company
F orida Power

FERC FORM NO.1 (REVISED 12-90)

I

I

PAGE 328.6

I

 50

48
48
40
40
40
40
32
38
38
38
38
38
38
38
38
38
T-3

m

Year of Report
This Report Is: .
Date of Re~ort
(Mo, Da, Y )
fXJ A
An Resu
Or1~nal
ission
Dec. 31' 1996
TRANSMISSI?N OF ELECTRICITY FOR ~THERS (Account 45t)(Continued)
(Inc ud1ng transact1ons re erred to as "whee 1ng 11 )
as identified in column (d)' is provided.
OS - for other transmission service. Use this category
only for those services which cannot be placed in
6. Report receipt and delivery locations for all si ngle
the above-defined categories, such as all nonfirm trancontract path, "point to point" transmission service.
smission service, regardless of the length of the
In column (f), report the designation for the substacontract. Describe the nature of the service in a
ti on, or other appropriate identification for where
energy was received as specified in the contract . In
footnote.
column (g) report the designation for the substation,
AD - for out-of-period adjustment. Use this code for
or other appropriate identification for where energy
was delivered as specified in the contract.
any accounting adjustments or "true-ups" for service
provided in prior reporting years. Provide an explana7. Report in column(h) the number of megawatts of billing
tion in a footnote for each adjustment.
demand that is specified in the firm transmission
In column (e), identify the FERC Rate Schedule or
service contract. Demand reported in column (h) must
be in megawatts. Footnote any demand not stated on a
Tariff Number. On separate lines, list all FERC rate
schedules or contract designations under which service,
megawatts basis and explain.

Nfme of Respo~ent
F orida Power
L1ght Company

FE~C Rfte
Sc rru e of
Tari
NlJllber
(e)
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6

Point of Receigt
(Substatlon or ther
De11gnat1on)
(

)

System
System
Hartman Substation
Lucy Substation
Hypoluxo Substation
System
Hypoluxo Substation
System
Hartman Substation
Deerhaven Substation
Lucy Substation
Marathon Substation
Hypoluxo Substation
System
System
System
N/A

FERC FORM N0.1 (RE V!SED 12-90)

I

Point of Delive~y
Ot er
Des1gnat1on)
(g)
Marathon Substation
Marathon Substation
System
System
System
System
System
System
System
System
System
System
System
System
System
System
N/A
(Subst~tlon_or

PAGE 329.6

I

Bill i~g
Deman

(~~~

I

TRANSFER OF ENERGY
Megftthours
De 1yered
Rece1ve
( 1)
( J)
5,106
5,611
4,899
4,626
10
10
58
56
67
69
52
52
17
17
20
20
78
78
396
396
104
106
455
451
1' 107
1' 148
169
169
38,524
38,524
2,539
2,446
0
0

Megattho~rs

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13

14
15
16
17

 I m

Year of Report
This Report Is:
Date of Re~ort
[Xl A
An Resu
Or1~nal
j (Mo, Da, Y )
Dec. 31, 1996
ission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions referred to as "wheeling")
shown on bills rendered to the entity listed in column
8. Report in column (i) and (j) the total megawatthours
(a). If no monetary settlement was made, enter zero
received and delivered.
("0") in column(n). Provide a footnote explaining the
9. In column (k) through (n), report the revenue amounts
nature of the nonmonetary settlement, including the
as shown on bills or vouchers. In column (k), provide
amount and type of energy or service rendered.
revenues from demand charges related to the billing
demand reported in column (h). In column ( l). provide
10. Provide total amounts in column (i) through (n) as the
revenues from energy charges related to the amount of
last line. Enter "TOTAL" in column (a) as the last
energy transferred. In column (m), provide the total
line. The total amounts in columns (i) and (j) must be
revenues from all other charges on bills or vouchers
reported as Transmission Received and Delivered on page
rendered, including out of period adjustments. Explain
401, lines 16 and 17, respectively.
in a footnote all components of the amount shown in
11 . Footnote entries and provide explanations following
column (m). Report in column (n) the
total charge
all required data.

Nfme of Respon~ent
L1ght Company
F orida Power

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energff~harges

Demand iharges

~~~

~k~

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

F~RC

I

FORM NO.1 (REVISED 12-90)

$28,013
18,185
29
297
277
164
34
59
243
1,228
495
2,254
5,014
401
173,767
11,428
0

*
*

*
*
*
*
*
*
*
*
*
*

PAGE 330.6

($25,989)
(14,255)
0
0
0
0
0
(59)
( 144)
(1,228)
(161)
(1,880)
(2,281)
(401)
(173,767)
(1,455)
(1,031)

Total ryvenues($)
(k+ +m)
(n)
$2,024
3,930
29
297
277
164
34
0
99
0
334
374
2,733
0
0
9,973
(1 ,031)

Line
No.
1
2
3
4
5
6
7

8
9
10
11
12
13
14
15
16
17

Next Page is 332

 Nrme of Respon~ent
L1ght Company
F orida Power

This Report I~:
Date of Re~ort
Year of Report
(Mo, Da, Y )
~~~ fXJ A
An Resu
Or1~nal
ission
Dec. 31' 1996
TRANSMI~SION OF ELECTRICITY F~R OT~ERS (Account 456~
(Inc ud1ng transact1ons re erre to as "wheel1ng ')
1. Report all transmission of electricity, i. e. wheeling,
4. In column(d) enter a Statistical Classification code
provided for other electric utilities, cooperatives,
based on the original contractual terms and conditions
municipalities, other
public authorities, qualifying
of the service as follows:
facil i ties, non - traditional
utility suppliers
and
ultimate customers.
LF - for long-term firm transmission service. "Long-term"
2. Use a separate line of data for each distinct type of
means one year or longer and "firm" means that service
transmission service involving the entities listed in
cannot be interrupted for economic reasons and is
column (a), (b) and (c).
intended to remain reliable even under adverse con3. Report in column (a) the company or public authority
ditions. For all transactions identified as LF, provide
that paid for the transmission service. Report
in
in a footnote the termination date of the contract
column(b) the company or public authority that the
defined as the earliest date that either buyer or
energy was received from and in column (c) the company
seller can unilaterally get out of the contract.
or public authority that the energy was delivered to.
Provide the full name of each company or public
SF - for short-term firm transmission service. Use this
authority. Do not abbreviate or truncate name or use
category for all firm services, where the duration
acronyms. Explain in a footnote any ownership interest
of each period of commitment for
service is less than
in or affiliation the respondent has with the entities
one year.
listed in co ll.1111'1s (a) , (b) or (c).
Pa~nt 6Y
Energy Delive~ed To
Energy Receired Fr~ .
S[ati~~ic
Line
(Com~ant or Pu~~lt.Authority)
(C~ant or Pu~ 1t.Aut or1ty)
(C~ant or Pu~ lt .Authority) C a~s 1 1No.
[ oo note A 1 1at1ons]
[ oo note A 1 1at1onsJ
[ oo note A 1 1at1ons]
cat1on
(a)
(b)
(C)
(d)
1 Sonat Power Marketing
Jacksonville Electric Authority
City of Lake Worth Utilities
OS
Tampa Electric Company
Southern Company Services, Inc.
2 Southern Company Services, Inc.
OS
City of Starke
3
Florida Power Corporation
City of Starke
OS
City of Starke
4 City of Starke
City of Gainesville
OS
City of Homestead
City of Starke
OS
5 City of Starke
City of Starke
OS
Jacksonville Electic Authority
6 City of Starke
City of Key West
City of Starke
OS
7 City of Starke
City of Lake Worth Utilities
City of Starke
OS
City of Starke
8
City of Starke
OS
City of New Smyrna Beach
9 City of Starke
City of Starke
OS
Orlando Utilities Commission
City of Starke
10
City of Starke
OS
Semi nole Electric Cooperative
City of Starke
11
City of Starke
OS
Tampa Electric Company
City of Starke
12
City of Starke
OS
City of Vero Beach
City of Starke
13
AD
N/A
N/A
City of Starke
14
City of Tallahassee
OS
City of Lake Worth Utilities
City of Tallahassee
15
City of Tallahassee
OS
City of Vero Beach
16 City of Tallahassee
AD
N/A
N/A
Tallahassee
17 City of

F~R C

FORM N0.1 (REVISED 12-90)

I

I

PAGE 328 . 7

I

 Year of Report
Date of Report
This Report Is: .
(Mo, Da, Yr)
~~~ fXJ A
An Resu
Or1~nal
31, 1996
Dec.
ission
(Account
45~)(Continued)
TRANSMISSI?N OF ELECTRICITY FOR ~THERS to as "whee 1ng")
(Inc ud1ng transact1ons re erred
as identified i n column (d), i s provided.
OS - for other transm i s s ion service. Use this category
6. Report receipt and delivery locations for all s ingle
only for those serv i ces wh i ch cannot be placed in
contract path, "point to point" transmission service .
the above-defined categories, such as all nonfirm tran·
In column (f), report the designation for the substa·
smission service, regardless of the length of the
or other appropriate identificat i on for where
tion,
contract. Describe the nature of the service in a
was received as specified in the contract. In
energy
footnote.
column (g) report the designation for the substation,
or other appropriate identification for where energy
AD - for out-of - period adjustment. Use this code for
was delivered as specified in the contract.
any accounting adjustments or "true-ups" for service
7. Report in column(h) the number of megawatts of billing
provided in prior reporting years. Provide an explanademand that is specified in the firm transmission
tion in a footnote for each adjustment.
service contract. Demand reported in column (h) must
In column (e), identify the FERC Rate Schedule or
be in megawatts . Footnote any demand not stated on a
Tariff Number. On separate lines, list all FERC rate
megawatts basis and explain.
schedules or contract designations under which service,

Nfme of Respon~ent
F orida Power
L1ght Company

5.

FE~C Rfte
Sc ~1u Number
e of
Tari
(e)
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6

58
63
82
82
82
82
82
82
82
82
82
82
82
T-3
28 of T-6
28 of T-6
T-3

Point of ReceiBt
(Substatlon or ther
De~1gnat1on)

(

)

System
System
System
Deerhaven Substation
Lucy Substation
System
Marathon Substation
Hypoluxo Substation
Smyrna Substation
System
System
System
System
N/A
Hypoluxo Substation
System
N/A

FERC FORM N0. 1 (REVISED 12-90)

I

I

I

Point of Delivehy
or Ot er
Des1gnation)
(g)
Hypoluxo Substation
System
Starke Substation
Starke Substation
Starke Substation
Starke Substation
Starke Substat i on
Starke Substation
Starke Substation
Starke Substation
Starke Substation
Starke Substation
Starke Substation
N/A
System
System
N/A
(Subst~tlon

PAGE 329 . 7

Bill~g

Dema

(~~~

TRANSFER OF ENERGY
Megftthours
De 1yered
Rece1ve
( 1)
( J)
42
48
1,421
1,420
6
6
47
46
8
8
20
20
7
7
40
41
9
9
10
10
10,649
10,361
457
458
12
12
0
0
40
40
148
150
0
0

Megattho~rs

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13

14
15
16
17

 Nrme of Respon~ent
L1ght Company
F orida Power

This Report Is:
Year of Report
Date of Re~ort
(Mo, Da, Y )
~~~ fXJ A
An Resu
Or1~nal
ission
Dec. 31' 1996
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions referred to as "wheeling")
8. Report in column (i) and (j) the total megawatthours
shown on bills rendered to the entity listed in column
received and delivered.
(a). If no monetary settlement was made, enter zero
9. In column (k) through (n), report the revenue amounts
("0") in column(n). Provide a footnote explaining the
as shown on bills or vouchers. In column (k), provide
nature of the nonmonetary settlement, including the
revenues from demand charges related to the billing
amount and type of energy or service rendered.
demand reported in column (h). In column ( l)' provide
10. Provide total amounts in column (i) through (n) as the
revenues from energy charges related to the amount of
last line. Enter "TOTAL" in column (a) as the last
energy transferred. In column (m), provide the total
line. The total amounts in columns (i) and (j) must be
revenues from all other charges on bills or vouchers
reported as Transmission Received and Delivered on page
rendered, including out of period adjustments. Explain
401' lines 16 and 17, respectively.
in a footnote all components of the amount shown in
11. Footnote entries and provide explanations following
column (m). Report in column (n) the
total charge
all required data.

Demand

I

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energff~harges

~harges

~~~

~k~

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

~ RC

I

FORM ~· , (REVISED 12-90)

$271
5,989
34
260
41
113
39
231
51
56
58,329
2,590

*

*

68

0
222
837
0

*

*

PAGE 330.7

($271)
0
0
0
0
0
0
0
0
0
(8,771)
0
0
(8,480)
0
0
(24)

I

Total ryvenues($)
(k+ +m)
(n)
0
5,989
34
260
41
113
39
231
51
56
49,558
2,590
68
(8,480)
222
837
(24)

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

Next Page is 332

 m

Year of Report
Date of Report
Th i s Report Is:.
(Mo , Da, Yr)
fXl A
An Resu
Or15ri,nal
Dec. 31 , 1996
ission
TRANSMlySIQN OF ELECTRICITY F~R OT~ERS (Account 456~
(Inc ud1ng transact1ons re erre to as "wheel1ng ')
4. In column(d) enter a Stat i stica l Classification code
1. Report all transmission of electr i city, i. e. wheeling,
based on the orig i nal cont ractual terms and cond i t i ons
cooperatives
,
utilities,
provided for other electric
of the service as follows:
authorities,
qualifying
public
other
municipalities,
and
suppliers
utility
facilities, non-traditional
LF - for long-term firm transmission service. "Long-term"
ultimate customers.
means one year or longer and "firm" means that service
2. Use a separate line of data for each distinct type of
cannot be interrupted for economic reasons and is
transmission service involving the entities listed in
intended to remain reliable even under adverse concolumn (a), (b) and (c).
authority
ditions
. For all transactions identified as LF, prov i de
3. Report in column (a) the company or public
footnote
the termination date of the contract
Report
in
a
in
service.
transmission
that paid for the
defined as the earliest date that either buyer or
column(b) the company or public authority that the
seller can unilaterally get out of the contract.
energy was received from and in column (c) the company
or public authority that the energy was delivered to.
SF - for short-term firm transmission service. Use this
Provide the full name of each company or public
category for all firm services, where the duration
authority. Do not abbreviate or truncate name or use
service is less than
of each period of commitment for
acronyms. Explain in a footnote any ownership interest
one year.
in or affiliation the respondent has with the entities
listed in columns (a), (b) or (c).
Stat i s~ic
Energy Delive~ed To
Pa~nt Sy
Energy Recei!ed Fro~
(ComFant or Pu~ ly.Authority) Class1 1Line
(ComFant or Pu~ ly.Aut ority)
(C~ant or Pu~~ly . Authority)
cat1on
[ oo note A 1 1at1onsl
[ oo note A 1 1at1onsl
[ oo note A 1 1at1onsl
No.
(C)
(d)
(b)
(a)
OS
City of Homestead
Tampa Electric Company
1 Tampa Electric Company
OS
City of Key llest
Tampa Electric Company
2 Tampa Electric Company
OS
Tampa Electric Company
City of La lee llorth Utilities
3 Tampa Electric Company
OS
City of Vero Beach
Tampa Electric Company
4 Tampa Electric Company
N/A
AD
N/A
5 Tampa Electric Company
City of Vero Beach
OS
Florida Power Corporation
6 City of Vero Beach
City of Gainesville
City of Vero Beach
OS
7 City of Vero Beach
Jacksonville Electric Authority City of Vero Beach
OS
8 City of Vero Beach
City of Lalc:e llorth Utilities
City of Vero Beach
9 City of Vero Beach
OS
City of Vero Beach
City of Vero Beach
10
Orlando Utilities Commission
OS
, 1 City of Vero Beach
City of Vero Beach
Seminole Electric Cooperative
OS
City of Vero Beach
City of Vero Beach
Southern Company Services, Inc.
12
OS
City of Vero Beach
Tampa Electric Company
City of Vero Beach
13
OS
City of Vero Beach
N/A
N/A
14
AD
Jacksonville Electric Authority City of Homestead
15
lies tern Power Services
OS
Florida Municipal Power Agency
Orlando Utilities Commission
Ft. Pierce Utilities Authority
16
* LF
Orlando Utilities Commission
17
Florida Municipal Power Agency
Ft. Pierce Utilities Authority
AD
Nfme of Re s pon~ent
L1ght Company
F orida Power

FE RC FORM N0.1 (REVISED 12-90)

I

PAGE 328.8

I

I

 ,.....

Nfme of Respon~ent
L1ght Company
F orida Power

5.

,......

This Report 1~:
Year of Report
Date of Re~ort
(Mo, Da, Y >
~~~ fXl A
An Resu
Or1~nal
ission
Dec. 31' 1996
TRANSMISSI?N OF ELECTRICITY FOR ~THERS (Account 45~)(Continued)
(Inc ud1ng transactions re erred to as "whee 1ng")
OS - for other transmission service. Use this category
as identified in column (d)' is provided.
only for those services which cannot be placed in
6. Report receipt and delivery locations for all single
the above-defined categories, such as all nonfirm trancontract path, "point to point" transmission service.
smission service, regardless of the length of the
In column (f), report the designation for the substacontract. Describe the nature of the service in a
ti on, or other appropriate identification for where
footnote.
energy was received as specified in the contract. In
column (g) report the designation for the substation,
AD - for out-of-period adjustment. Use this code for
or other appropriate identification for where energy
any accounting adjustments or "true-ups" for service
was delivered as specified in the contract.
provided in prior reporting years. Provide an explana7. Report in column(h) the number of megawatts of billing
tion in a footnote for each adjustment.
demand that is specified in the firm transmission
In column (e), identify the FERC Rate Schedule or
service contract. Demand reported in column (h) must
Tariff Number. On separate lines, list all FERC rate
be in megawatts. Footnote any demand not stated on a
schedules or contract designations under which service,
megawatts basis and explain.

FE@C Rfte
Sc f?u Number
e of
Tar1
(e)
of T-6
of T-6
of T-6
of T-6

65
65
65
65
T-3
10 of
10 of
10 of
10 of
10 of
10 of
10 of
10 of
T-3
68 of
92
92

~C

T-6
T-6
T-6
T-6
T-6
T-6
T-6
T-6
T-6

Point of Receigt
(Substation or ther
De~1gnat1on)

(

)

Lucy Substation
Marathon Substation
Hypoluxo Substation
System
N/A
System
Deerhaven Substation
System
Hypoluxo Substation
System
System
System
System
N/A
System
System
System

FORM N0.1 (REVISED 12-90)

I

l

I

Point of Delivehy
Ot er
Des1gnat1on)
(g)
System
System
System
System
N/A
System
System
System
System
System
System
System
System
N/A
Lucy Substation
Hartman Substation
Hartman Substation
(Subst~tlon.or

PAGE 329.8

Bill~g

Dema

TRANSFER OF ENERGY
Megftthours
Rece1ve
De 1yered
( 1)
(J)
123
124
244
257
759
785
1,853
1 '918
0
0
126
122
341
326
1,342
1,277
77
79
86
83
1,456
1,530
140
136
18,179
17,939
0
0
27
21
100,582
98,192
0
0

Megattho~rs

(~~~

15
0

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

 m

l

Year of Report
This Report I~: .
Date of Re~ort
(Mo, Da, Y )
fXl A
An Resu
Or1rx;,nal
Dec. 31, 1996
ission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions referred to as "wheeling")
shown on bills rendered to the entity listed in column
8. Report in column (i) and (j) the total megawatthours
(a). If no monetary settlement was made, enter zero
received and delivered.
( 11 011 )
in column(n). Provide a footnote explaining the
amounts
9. In column (k) through (n), report the revenue
nature of the nonmonetary settlement, including the
as shown on bills or vouchers. In column (k), provide
amount and type of energy or service rendered.
revenues from demand charges related to the billing
10. Provide total amounts in column (i) through (n) as the
demand reported in column (h). In column ( l)' provide
last line. Enter "TOTAL" in column (a) as the last
revenues from energy charges related to the amount of
line. The total amounts in columns (i) and (j) must be
energy transferred. In column (m), provide the total
reported as Transmission Received and Delivered on page
revenues from all other charges on bills or vouchers
401, lines 16 and 17, respectively.
rendered, including out of period adjustments. Explain
11. Footnote entries and provide explanations following
in a footnote all components of the amount shown in
all required data.
column (m). Report in column (n) the
total charge

Nfme of Respon~ent
F orida Power
L1ght Company

Demand

~harges

~d

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
308,178
0

FERC FORM N0.1 (REVISED 12-90)

I

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energrf~harges

~~~

$656
1,444
4,271
10,603
0
476
, , 129
3,615
313
329
5,941
790
93,632
0
54
, ,257
0

*
*
*
*
*
*
*
*

PAGE 330.8

0
0
0
0
(997)
(102)
0
(,, 743)
0
0
(2,514)
(790)
(4,, 922)
(, ,862)
0
0
(29,984)

I

Total ryvenues($)
<k+ +m)
(n)
$656
1,444
4,271
10,603
(997)
374
1,129
1,872
313
329
3,427
0
51,710
(1,862)
54
309,435
(29,984)

Line
No.
1
2
3
4
5
6
7
8
9
10

,,
12
13
14
15
16
17

Next Page is 332

 Nfme of Respon~ent
L1ght Company
F orida Power

This Report Is:
Date of Re~ort
Year of Report
(Mo, Da, Y )
~~~ fXj A
An Resu
Or1~nal
ission
Dec. 31, 1996
TRANSMitSIQN OF ELECTRICITY F~R OT~ERS (Account 456?,1
(Inc ud1ng transact1ons re erre to as "wheel1ng )
1. Report all transmission of electricity, i. e. wheeling,
4. In column(d) enter a Statistical Classification code
provided for other electric utilities, cooperatives,
based on the original contractual terms and conditions
municipalities, other
public authorities, qualifying
of the service as follows:
f aci l i t i es, non-traditional
utility
suppliers
and
ultimate customers.
LF - for long-term firm transmission service. "Long-term"
2. Use a separate line of data for each distinct type of
means one year or longer and "firm" means that service
transmission service involving the entities listed in
cannot be interrupted for economic reasons and is
column (a), (b) and (c).
intended to remain reliable even under adverse con3. Report in column (a) the company or public authority
ditions. For all transactions identified as LF, provide
that paid for the transmission service. Report
in
in a footnote the termination date of the contract
column( b) the company or public authority that the
defined as the earliest date that either buyer or
energy was received from and in column (c) the company
seller can unilaterally get out of the contract.
or public authority that the energy was delivered to.
Provide the full name of each company or public
SF - for short-term firm transmission service. Use this
authority. Do not abbreviate or truncate name or use
category for all firm services, where the duration
acronyms. Explain in a footnote any ownership interest
of each period of corrmitment for
service is less than
in or affiliation the respondent has with the entities
one year.
listed in columns (a), (b) or (c).
Pa~nt 8Y
Energy Receired Fr~
Energy Delive~ed To
Sfatisiic
Line
c ass 1 1(Comrant or Pu~}lf.Authority)
ccomrant or Pu~ lf.Aut ority)
(C~ant or Pu~ lf.Authority)
No.
[ oo note A 1 1at1onsJ
[ oo note A 1 1at1onsJ
[ oo note A 1 1at1onsJ
cat1on
(a)
(b)
(c)
(d)
1 Florida Municipal Power Agency
Orlando Utilities Corrmission
Ft. Pierce Utilities Authority
* LF
2
Florida Municipal Power Agency
Orlando Utilities Corrmission
Ft. Pierce Utilities Authority
AD
3
Florida Municipal Power Agency
Orlando Utilities Corrmission
* LF
Ft. Pierce Utilities Authority
4
Florida Municipal Power Agency
Orlando Utilities Corrmission
City of Homestead
* LF
5
Florida Municipal Power Agency
Orlando Utilities Corrmission
City of Homestead
AD
6
Florida Municipal Power Agency
Orlando Utilities Corrmission
City of Homestead
* LF
7
Florida Municipal Power Agency
Orlando Utilities Corrmisison
City of Homestead
AD
* LF
Florida Municipal Power Agency
City of Homestead
Orlando Utilities Corrmission
8
* LF
Florida Municipal Power Agency
Utility Board City of Key West
Orlando Utilities Corrmission
9
Florida Municipal Power Agency
Orlando Utilities Corrmission
Utility Board City of Key West
AD
10
* LF
Utility Board City of Key West
11
FLorida Municipal Power Agency
Orlando Utilities Corrmission
City of Lake Worth Utilities
* LF
Florida Municipal Power Agency
Orlando Utilities Corrmission
12
City of Lake Worth Utilities
AD
Orlando Utilities Corrmission
13
Florida Municipal Power Agency
* LF
City of Starke
Orlando Utilities Corrmission
Florida Municipal Power Agency
14
City of Starke
AD
Orlando Utilities Corrmission
Florida Municipal Power Agency
15
* LF
City of Starke
Orlando Utilities Corrmission
Florida Municipal Power Agency
16
* LF
City of Vero Beach
Orlando Utilities Corrmission
Florida Municipal Power Agency
17

cRC FORM NO. 1 (REVISED 12-90)

l

I

PAGE 328.9

I

 Nfme of Respon~ent
F orida Power
L1ght Company

5.

Date of Re~o r t
(Mo, Da, Y )

I

I

Year of Report
Dec. 31, 1996

45~)(Continued)
TRANSMISSI?N OF ELECTRICITY FOR ~THERS (Account
(Inc ud1ng transactions re erred to as "whee 1ng")
as identified in column (d)' is provided.
OS - for other transmission service. Use this category
Report receipt and delivery locations for all single
6.
be
placed
in
which
cannot
services
only for those
contract path, "point to point" transmission service .
the above-defined categor i es, such as all nonfirm tranIn column (f), report the designation for the substasmission service, regardless of the length of the
tion, or other appropriate identification for where
contract. Describe the nature of the service in a
energy was received as specified in the contract. In
footnote.
column (g) report the des i gnat i on for the substation,
or other appropriate identification for where energy
AD - for out-of-period adjustment. Use this code for
was delivered as specified in the contract .
for
service
any accounting adjustments or "true-ups"
7. Report in column(h) the number of megawatts of billing
provided in prior reporting years. Provide an explanademand that is specified in the firm transm i ssion
tion in a footnote for each adjustment.
service contract. Demand reported in column (h) must
In column (e), identify the FERC Rate Schedule or
be in megawatts. Footnote any demand not stated on a
Tariff Number. On separate lines, list all FERC rate
megawatts basis and explain.
schedules or contract des i gnations under which service,

FE~C Rfte
Sc ~1u e of

Number
Tari
(e)
93
93
4 of
92
92
93
93
4 of
93
93
4 of
92
92
92
92
4 of
92

I

I~lst~ip~~to~~:inal
A Resu~i ssion

T-6

T-6

T-6

T-6

Point of Receigt
(Substation or ther
De~1gnat1on)

(

)

System
System
System
System
System
System
System
System
System
System
System
System
System
System
System
System
System

FE RC FORM N0 . 1 (REVISED 12 -90)

Point of Delivehy
(Substet1on.or Ot er
Des1gnat1on)
(g)
Hartman Substation
Hartman Substation
Hartman Substation
Lucy Substation
Lucy Substation
Lucy Substation
Lucy Substation
Lucy Substation
Marathon Substation
Marathon Substation
Marathon Substation
Hypoluxo Substation
Hypoluxo Substation
Starke Substation
Starke Substation
Starke Substation
System

PAGE 329.9

Bill i~g
Deman

TRANSFER OF ENERGY
Megftthours
De 1yered
Rece1ve
( 1)
( J)
33,527
32,731
0
0
71,619
69,893
83,219
85,230
0
0
28,410
27,740
0
0
37,708
36,799
86,909
89' 013
0
0
47,083
45,953
61,657
60,133
0
0
, , ,068
10,815
0
0
5,879
5,751
, 17,362
, 14,608

Megattho~rs

(~~~

5
0
16
10
0
3
0
8
12
0
10
10
0
2
0

,

21

Line
No.

,

2
3
4
5
6
7
8
9
10

,,
12
13
14
15
16
17

 Nfme of Respon~ent
F orida Power
L1ght Company

,_.

(Me, Da,
~~~ fXJ An
Or1~nal
A Resu
ission I
I
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
This Report Is:

Date of

Re~ort

Y)

I

Year of Report
Dec. 31, 1996

(IncLuding transactions referred to as "wheeling")
8. Report in column (i) and (j) the total megawatthours
shown on biLLs rendered to the entity Listed in column
received and delivered.
(a). If no monetary settlement was made, enter zero
11 11
9. In column (k) through (n), report the revenue amounts
(
0 ) in column(n). Provide a footnote explaining the
as shown on bills or vouchers. In column (k), provide
nature of the nonmonetary settlement, including the
revenues from demand charges related to the biLLing
amount and type of energy or service rendered.
demand rep "ted in column (h). In column ( L)' provide
10. Provide total amounts in column (i) through (n) as the
revenues · · " n energy charges related to the amount of
Last line. Enter "TOTAL" in column (a) as the Last
energy tr ans ferred. In column (m), provide the total
Line. The total amounts in columns (i) and (j) must be
revenues from all other charges on bills or vouchers
reported as Transmission Received and Delivered on page
rendered, including out of period adjustments. Explain
401, Lines 16 and 17, respectively.
in a footnote alL components of the amount shown in
11. Footnote entries and provide explanations following
column (m). Report in column (n) the
total charge
all required data.

Demand

~harges

~d

,_.

..

F!:RC FOR" N0.1

( k.

$102,735
0
181,261
227,297
0
102,733
0
92,045
246,372
0
108,757
205.574
0
30,827
0
13,589
410,633

.,ED 12-90)

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energrt~harges

~~~

$419
0
927
1,615
0
717
0
488
1,519
0
598
1,5 18
0
6,309
0
74
1,324

*
*
*

*
*
*

PAGE 330.9

0
(11,828)
0
0
(33,520)
0
(11,182)
0
0
(26,310)
0
0
(23, 756)
0
(3,618)
0
0

Total ryvenues($)
( k+ +m)
(n)
$103,154
(11,828)
182,188
228,912
(33,520)
103,450
(11, 182)
92,533
247,891
(26,310)
109,355
207,092
(23,756)
37,136
(3,618)
13,663
411,957

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

Next Page is 332

 Year of Report
Date of Re~ort
This Report I~:.
(Mo, Da, Y )
-1 Dec. 31, 1996
fXl A
An Resu
Or1f!,ri,nal
.
iss1on
TRANSMlySIQN OF ELECTRICITY F~R OT~ERS (Account 456?,
(Inc ud1ng transact1ons re erre to as "wheel1ng ')
4. In column(d) enter a Stat i stical Classification code
1. Report all transmission of electricity, i. e. wheeling,
based on the original contractual terms and conditions
cooperatives,
utilities,
provided for other electric
the service as follows:
of
authorities,
qualifying
public
municipalities, other
and
utility suppliers
facilities, non-traditional
LF - for long-term firm transmission service. "Long-term"
ultimate customers.
means one year or longer and "firm" means that service
2. Use a separate line of data for each distinct type of
cannot be interrupted for economic reasons and is
transmission service involving the entities listed in
intended to remain reliable even under adverse concolumn (a), (b) and (c).
For all transactions identified as LF, provide
ditions.
3. Report in column (a) the company or public authority
footnote
the termination date of the contract
in
in
a
service.
Report
that paid for the transmission
defined as the earliest date that either buyer or
colunn(b) the company or public authority that the
seller can unilaterally get out of the contract.
energy was received from and in column (c) the company
or public authority that the energy was delivered to.
SF - for short-term firm transmission service. Use this
Provide the full name of each company or public
category for all firm services, where the duration
authority. Do not abbreviate or truncate name or use
service is less than
of each period of commitment for
acronyms. Explain in a footnote any ownership interest
one year.
in or affiliation the respondent has with the entities
listed in coll.m"ls (a), (b) or (c).
Energy Deliveted To
Payment Sy
Energy Receired Fr~
Sfatis~ic
Line
cco~ant or Pu~ IT.Authority) Cass11·
ccom~ant or Pu~ 1T .Aut ority)
(Com~ant or Pu~~IT.Authority)
cat1on
[ oo note A 1 1at1onsl
[ oo note A 1 1at1ons]
[ oo note A 1 1at1onsl
No.
(d)
(b)
(c)
(a)
City of Vera Beach
AD
Orlando Utilities Conmission
Florida Municipal Power Agency
* LF
City of Vera Beach
Florida Municipal Power Agency
Orlando Utilities Conmission
2
* LF
N/A
N/A
Florida Municipal Power Agency
3
N/A
* LF
4
Florida Municipal Power Agency
N/A
N/A
N/A
* LF
5
Florida Municipal Power Agency
*
City of Clewiston
* LF
6
Florida Municipal Power Agency
*
City of Clewiston
7
Florida Municipal Power Agency
AD
*
Florida Municipal Power Agency
City of Green Cove Springs
* LF
8
Florida Municipal Power Agency
*
City of Green Cove Springs
9
AD
*
10
Florida Municipal Power Agency
City of Jacksonville Beach
* LF
Florida Municipal Power Agency
*
City of Jacksonville Beach
AD
12
Florida Municipal Power Agency
N/A
N/A
* LF
13
Florida Municipal Power Agency
*
*
* LF
14
Florida Municipal Power Agency
Florida Power & Light Company
Florida Municipal Power Agency
* LF
15
Florida Municipal Power Agency
Florida Power & Light Company
Florida Municipal Power Agency
* LF
16
Florida Municipal Power Agency
Florida Power & Light Company
Florida Municipal Power Agency
AD
17
Florida Municipal Power Agency
Florida Power & Light Company
Orlando Utilities Conmission
* LF
Nfme of Respon~ent
F orida Power
L1ght Company

I Hl

,

,,

FERC FORM N0.1 (REVISED 12-90)

PAGE 328.10

I

 Nfme of Respongent
L1ght Company
F orida Power

5.

This Report Is:
Date of Re~ort
Year of Report
(Mo, Da, Y )
~~~ fX~ A
An Resu
Or1~nal
ission
Dec. 31' 1996
TRANSMISSI?N OF ELECTRICITY FOR ~THERS (Account 45~)(Continued)
(Inc ud1ng transact1ons re erred to as "whee 1ng")
OS - for other transmission service. Use this category
as identified in column (d), is provided.
only for those services which cannot be placed in
6. Report receipt and delivery locations for all single
the above-defined categories, such as all nonfirm trancontract path, "point to point" transmission service.
smission service, regardless of the length of the
In column (f), report the designation for the substacontract. Describe the nature of the service in a
tion, or other appropriate identification for where
footnote.
energy was received as specified in the contract. In
column (g) report the designation for the substation,
AD - for out-of-period adjustment. Use this code for
or other appropriate identification for where energy
any accounting adjustments or "true-ups" for service
was delivered as specified in the contract.
provided in prior reporting years. Provide an explana7. Report in column(h) the number of megawatts of billing
tion in a footnote for each adjustment.
demand that is specified in the firm transmission
In column (e), identify the FERC Rate Schedule or
service contract. Demand reported in column (h) must
Tariff Number. On separate lines, list all FERC rate
be in megawatts. Footnote any demand not stated on a
schedules or contract designations under which service,
megawatts basis and explain.

FE~C Rfte
Sc f1u e of
Tari
NlMilber
(e)

92
4 of T-6
92
93
4 of T-6
84
84
84
84
84
84

84
80 of T-6
72
72
--72
- -·
69

Point of Receigt
(Substatlon or ther
De~1gnat1on)

(

)

System
System
N/A
N/A
N/A
System
System
System
System
System
System
N/A
System
St. Lucie
St. Lucie
St. Lucie
St. Lucie

FERC FORM N0.1 (REVISED 12-90)

Plant
Plant
Plant
Plant

I

I

Point of Delivehy
(Substijtlon.or Ot er
Des1gnat1on)
(g)
System
System
N/A
N/A
N/A
Hendry Substaiton
Hendry Substation
Green Cove Springs
Green Cove Springs
Sampson Substation
Sampson Substation
N/A
System
Smyrna Substation
Smyrna Substaiton
Smyrna Substation
Smyrna Substation

Bill~g

Dema

*
*

*

PAGE 329.10

TRANSFER OF ENERGY
Megftthours
Recr:1ve
De 1yered
( 1)
( J)
0
0
57,709
56,297
0
0
0
0
0
0
21,339
20,847
0
0
26,880
27' 514
0
0
109,340
106,173
0
0
0
0
654,798
639' 166
147,659
144,175
386,930
377,698
0
0
369,679
360,885

Megattho~rs

(~~~

*

I

0
16
0
0
0
15
0
19
0
115
0
0
0
75
64

0
52

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

 Year of Report
Date of Report
(Mo, Da, Yr)
Dec. 31' 1996
A Resuf,ri,i ss ion
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions referred to as "wheeling")
shown on bills rendered to the entity listed in column
8. Report in column (i) and (j) the total megawatthours
(a). If no monetary settlement was made, enter zero
received and delivered.
("0") in column(n). Provide a footnote explaining the
9. In column (k) through (n), report the revenue amounts
nature of the nonmonetary settlement, including the
as shown on bills or vouchers. In column (k), provide
amount
and type of energy or service rendered.
billing
revenues from demand charges related to the
10. Provide total amounts in column (i) through (n) as the
demand reported in column (h). In column ( l)' provide
last line. Enter "TOTAL" in column (a) as the last
revenues from energy charges related to the amount of
line. The total amounts in columns (i) and (j) must be
energy transferred. In column (m), provide the total
reported as Transmission Received and Delivered on page
revenues from all other charges on bills or vouchers
401, l i nes 16 and 17, respectively.
rendered, including out of period adjustments. Explain
11. Footnote entries and provide explanations following
in a footnote all components of the amount shown in
column (m). Report in column (n) the
all required data.
total charge

Nfme of Respon~ent
F orida Power
L1ght Company

Demand iharges

~kl

0
181,261
0
0
0
82,027
0
96,180
0
760,462
0
0
2, 124,718
355,108
994,748
0
, ,005,996

FER C FORM N0 . 1 (REVISED 12-90)

I

T~isf~ep~~to~~:inal

~ l

l

I

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energrf~harges

~~l

0
702
0
0
0
0
0
0
0
0
0
0
12,506
178
2,429
0
259

*
*
*
*
*
*
*
*
*
*
*
*
*

PAGE 330.10

($47,370)
0
7,800
7,800
4,550
0
(33,527)
0
(32,825)
0
(201,349)
, ,950
2,500
, ,950
5,850
(154,026)
7,800

I

Total rivenues($)
(k+ +m)
(n)
($47,370)
181,963
7,800
7,800
4,550
82,027
(33,527)
96,180
(32,825)
760,462
(201,349)
, ,950
2,139,724
357,236
1,003,027
(154,026)
1,014,055

Line
No.
1
2
3
4
5
6
7
8
9
10

,,
12
13
14
15
16
17

Next Page is 332

 Nrme of Respon~ent
L1ght Company
F orida Power

This Report Is:
Date of Re~ort
Year of Report
(Mo, Da , Y )
~~~ fX~ A
An Resu
Or1~nal
ission
Dec. 31, 1996
TRANSMifSION OF ELECTRICITY F~R OT~ERS (Account
456~
(Inc ud1ng transact1ons re erre to as 11 wheel1ng ')
1. Report all transmission of electricity, i. e. wheeling,
4. In column(d) enter a Statistical Classification code
provided for other electric utilities, cooperatives,
based on the original contractual terms and conditions
municipalities, other
public authorities, qualifying
of the service as follows:
facilities, non-traditional
utility suppliers
and
ultimate customers.
LF - for long-term firm transmission service. "Long-term"
2. Use a separate line of data for each distinct type of
means one year or longer and "firm" means that service
transmission service involving the entities listed in
cannot be interrupted for economic reasons and is
column (a), (b) and (c).
intended to remain reliable even under adverse con3. Report in column (a) the company or public authority
ditions. For all transactions identified as LF, provide
that paid for the transmission service. Report
in
in a footnote the termination date of the contract
column(b) the company or public authority that the
defined as the earliest date that either buyer or
energy was received from and in column (c) the company
seller can unilaterally get out of the contract.
or public authority that the energy was delivered to.
Provide the full name of each company or public
SF - for short-term firm transmission service. Use this
authority. Do not abbreviate or truncate name or use
category for all firm services, where the duration
acronyms. Explain in a footnote any ownership interest
of each period of commitment for
service is less than
in or affiliation the respondent has with the entities
one year.
listed in columns (a), (b) or (c).
Pa~nt 8Y
Energy Recei}ed Fro~
Energy Delive~ed To
sratis~ic
Line
C
a$S1 1·
cc~ant or Pu~~lt . Authority)
(ComFant or Pu~ !{ _Aut ority)
(C~ant or Pu~ !{ _Authority)
No.
[ oo note A 1 1at1onsl
[ oo note A 1 1at1ons]
cat1on
[ oo note A 1 1at1ons]
(a)
(b)
(c)
(d)
1 Florida Municipal Power Agency
Florida Power & Light Company
Orlando Utilities Commission
AD
2 City of New Smyrna Beach
Florida Power Corporation
City of New Smyrna Beach
* LF
3 City of New Smyrna Beach
Florida Power Corporation
City of New Smyrna Beach
AD
4 City of Starke
City of Gainesville
City of Starke
* LF
5 City of Starke
City of Gainesville
City of Starke
AD
6 Seminole Electric Cooperative, Inc.
Seminole Electric Cooperative
Florida Power & Light Company
* LF
7 Seminole Electric Cooperative, Inc.
Seminole Electric Cooperative
FLorida Power & Light Company
AD
Dade County Resource Recovery
Florida Power Corporation
8 Dade County Resource Recovery
* LF
Dade County Resource Recovery
Florida Power Corporation
AD
9 Dade County Resource Recovery
Coral Power, LLC
N/A
N/A
SF
10
SF
N/A
Duke/Louis Dreyfus
N/A
11
SF
N/A
N/A
Enron Power Marketing, Inc.
12
SF
N/A
Florida Municipal Power Agency
N/A
13
SF
N/A
N/A
Florida Power Corporation
14
AD
N/A
N/A
Florida Power Corporation
15
SF
N/A
N/A
Ft. Pierce Utilities Authority
16
SF
N/A
N/A
17 City of Gainesville

· ERC FORM NO.1 (REVISED 12-90)

I

I

PAGE 328.11

I

 Nfme of Respon~ent
F orida Power
L1ght Company

5.

I

This Report Is:.
~~~ fX~ A
An Resu
Or1~nal
ission

I

Date of Re~ort
(Mo, Da, Y )

I

Year of Report
Dec. 31' 1996

(Account 45~)(Continued)
TRANSMISSI?N OF ELECTRICITY FOR ~THERS to
as "whee 1ng")
(Inc ud1ng transact1ons re erred
as identified in column (d), is provided.
OS - for other transmission service. Use this category
6. Report receipt and delivery locations for all single
only for those services which cannot be placed in
contract path, "point to point" transmission service.
the above-defined categories, such as all nonfirm tran·
In column (f), report the designation for the substasmission service, regardless of the length of the
ti
on, or other appropriate identification for where
in
a
the
service
contract. Describe the nature of
was received as specified in the contract. In
energy
footnote.
column (g) report the designation for the substation,
or other appropriate identification for where energy
AD - for out-of-period adjustment. Use this code for
was delivered as specified in the contract.
any accounting adjustments or "true-ups" for service
7. Report in column(h) the number of megawatts of billing
provided in prior reporting years. Provide an explanademand that is specified in the firm transmission
tion in a footnote for each adjustment.
service contract. Demand reported in column (h) must
In column (e), identify the FERC Rate Schedule or
be in megawatts. Footnote any demand not stated on a
Tariff Number. On separate lines, list all FERC rate
megawatts
basis and explain.
schedules or contract designations under which service,

FE~C Rfte
Sc ~1u e of
Number
Tari
(e)

69
88
88
3 of T-6
T-1
78
78
124
124
88 of T-6
13 of T-6
5 of T-6
71 of T-6
23 of T-6
T-2
15 of T-6
25 of T-6

Point of Receigt
(Substatlon Qr ther
De~1gnat1on)

(

)

St. Lucie Plant
System
System
Deerhaven Substation
Deerhaven Substation
Seminole Plant
Seminole Plant
Doral Substation
Doral Substation
N/A
N/A
N/A
N/A

N/A
N/A
N/A
N/A

FERC FORM N0.1 (REVISED 12-90)

Point Qf Delivehy
or Ot er
Des1gnation)
(g)
Smyrna Substation
Smyrna Substation
Smyrna Substation
Starke Substation
Starke Substation
System
System
System
System
(Subst~tlon

N/A
N/A
N/A
N/A
N/A
N/A

N/A
N/A

PAGE 329.11

Bill~g

TRANSFER OF ENERGY
Megftthours
De 1yered
ReCfi!lVe
( 1)
( J)
0
0
230
228
0
0
19,986
20,482
0
0
3,360,614
3,281,098
0
0
313,557
306,097
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

Megattho~rs

Dema

(~~~
0
52
0
3
0
472
0
60
0
0
0
0
0
0
0
0
0

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

 Nfme of Respon~ent
F orida Power
L1ght Company

This Report Is:
Year of Report
Date of Re~ort
(Mo, Da, Y )
~B fXJ A
An Resu
Or1~nal
ission
Dec. 31, 1996
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions referred to as "wheeling")
8. Report in column (i) and (j) the total megawatthours
shown on bills rendered to the entity listed in column
received and delivered.
(a). If no monetary settlement was made, enter zero
9. In column (k) through (n), report the revenue amounts
("D") in column(n) . Provide a footnote explaining the
as shown on bills or vouchers. In column (k), provide
nature of the nonmonetary settlement, including the
revenues from demand charges related to the billing
amount and type of energy or service rendered.
demand reported in column (h). In column (l)' provide
1D. Provide total amounts in column (i) through (n) as the
revenues from energy charges related to the amount of
last line. Enter "TOTAL" in column (a) as the last
energy transferred. In column (m), provide the total
line. The total amounts in columns (i) and (j) must be
revenues from all other charges on bills or vouchers
reported as Transmission Received and Delivered on page
rendered, including out of period adjustments. Explain
401, lines 16 and 17, respectively.
in a footnote all components of the amount shown in
11. Footnote entries and provide explanations following
column (m). Report in column (n) the
total charge
all required data.

Demand iharges

~k~

0
154,381
0
63,219
0
9,909,510
0
1,218,981
0
0
0
0
0
0
0
0
0

ERC FORI-'

1 (REVISED 12-90)

I

I

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energrf~harges

~~~

0
8,316
0
182
0
0
0
997
0
0
0
0
0
0
0
0
0

*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*

PAGE 330.11

($107,416)
0
(37,029)
7,800
(405)
7,800
(971,992)
7,800
(136,492)
2,600
3,439
3, 732
3,732
3, 732
(2,304)
3, 732
650

I

Total rTvenues($)
(k+ +m)
(n)
($107,416)
162,697
(37,029)
71,201
(405)
9,917,310
(971,992)
1,227,778
(136,492)
2,600
3,439
3,732
3,732
3,732
(2,304)
3,732
650

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

Next Page is 33c

 m

l

Year of Report
Date of Re~ort
This Report Is:
(Mo, Da, Y )
fXl An
Or1~nal
Dec. 31, 1996
A Resu
ission
TRANSMI~SIQN OF ELECTRICITY F~R OT~ERS (Account 456?,
(Inc ud1ng transact1ons re erre to as "wheel1ng ')
4. In column(d) enter a Statistical Classification code
1. Report all transmission of electricity, i. e. wheeling,
based on the original contractual terms and conditions
provided for other electric utilities, cooperatives,
of the service as follows:
public authorities, qualifying
municipalities, other
utility suppliers
and
facilities, non-traditional
LF - for long-term firm transmission service. "Long-term"
ultimate customers.
means
one year or longer and "firm" means that service
distinct
type
of
a
separate
line
of
data
for
each
2. Use
cannot be interrupted for economic reasons and is
transmission service involving the entities listed in
intended to remain reliable even under adverse concolumn (a), (b) and (c).
ditions. For all transactions identified as LF, provide
3. Report in column (a) the company or public authority
in
in a footnote the termination date of the contract
that paid for the transmission service. Report
column(b) the company or public authority that the
defined as the earliest date that either buyer or
seller can unilaterally get out of the contract.
energy was received from and in column (c) the company
or public authority that the energy was delivered to.
SF - for short-term firm transmission service. Use this
Provide the full name of each company or public
category for all firm services, where the duration
authority. Do not abbreviate or truncate name or use
of each period of commitment for
service is less than
acronyms. Explain in a footnote any ownership interest
one year.
in or affiliation the respondent has with the entities
listed in colL.mns (a), (b) or (c).
Pa~nt 6Y
Energy Delive~ed To
Energy Receired Fro~
Sfatis~ic
Line
(Com~ant or Pu~ lf .Authority) c ass1 1(Com~ant or Pu~ Iy .Aut ority)
(C~ant or Pu~~ly.Authority)
[ oo note A 1 1at1onsl
cat1on
[ oo note A 1 1at1onsl
[ oo note A 1 1at1onsl
No.
(a)
(b)
(c)
(d)
SF
1 Heartland Energy Services, Inc.
N/A
N/A
2 City of Homestead
N/A
N/A
SF
N/A
N/A
SF
3 Jacksonville Electric Authority
4 City of Key West
N/A
N/A
SF
5 Koch Power Services, Inc.
N/A
N/A
SF
N/A
N/A
6 City of Lake Worth Utilities
SF
N/A
7 City of Lakeland
N/A
AD
N/A
N/A
8 MidCon Power Services Corp.
SF
N/A
N/A
9 City of New Smyrna Beach
SF
NorAm Energy Services
City of Key West
10
Seminole Electric Cooperative
SF
City of Key West
11 NorAm Energy Services
Seminole Electric Cooperative
SF
12
NorAm Energy Services
N/A
N/A
SF
PanEnergy Power Services, Inc.
N/A
N/A
13
SF
Rainbow Energy Marketing Corp.
14
N/A
N/A
SF
Seminole Electric Cooperative, Inc.
N/A
N/A
15
SF
16 Sonat Power Marketing, Inc.
N/A
N/A
SF
Tampa Electric Company
17 Southern Company Services, Inc.
Southern Company Services, Inc.
SF
Nfme of Respon~ent
F orida Power
L1ght Company

FERC FORM N0.1 (REVISED 12-90)

I

PAGE 328.12

I

 Nfme of Respon~ent
Light Company
F orida Power

5.

This Report Is:
Date of Report
Year of Report
(Mo, Da, Yr)
~~~ fXl A
An Resu
Or1~nal
ission
Dec. 31' 1996
TRANSM!SS!?N OF ELECTRICITY FOR ~THERS (Account 45?)(Continued)
(Inc ud1ng transactions re erred to as "whee 1ng")
OS - for other transmission service. Use this category
as identified in column (d)' is provided.
only for those services which cannot be placed in
6. Report receipt and delivery locations for all single
the above-defined categories, such as all nonfirm trancontract path, "point to point" transmission service.
smission service, regardless of the length of the
In column (f), report the designation for the substacontract. Describe the nature of the service in a
tion, or other appropriate identification for where
footnote.
energy was received as specified in the contract. In
column (g) report the designation for the substation,
AD - for out-of-period adjustment. Use this code for
or other appropriate identification for where energy
any accounting adjustments or "true-ups" for service
was delivered as specified in the contract.
provided in prior reporting years. Provide an explana:
7. Report in column(h) the number of megawatts of billing
tion in a footnote for each adjustment.
demand that is specified in the firm transmission
In colLmn (e), identify the FERC Rate Schedule or
service contract. Demand reported in column (h) must
Tariff Number. On separate lines, list all FERC rate
be in megawatts. Footnote any demand not stated on a
schedules or contract designations under which service,
megawatts basis and explain.

FE~C Rfte
Sc
of
Tar1
Number
(e)
of T-6
of T-6
of T-6
of T-6
of T-6
of T-6

11u e

66
29
35
21
51
33
T-2
77 of T-6
83 of T-6
47 of T-6
47 of T-6
47 of T-6
85 of T-6
7 of T-6
37 of T-6
57 of T-6
62 of T-6

Point of Receigt
(Substation Qr ther
De~1gnat1on)

(

)

N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
System
System
N/A
N/A
N/A
N/A
N/A
N/A

FERC FORM NO.1 (REVISED 12-90)

I

I

Point Qf Delivehy
(Substot1on . or Ot er
Des1gnat1on)
(g)
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
Marathon Substation
Marathon Substation
N/A
N/A
N/A
N/A
N/A
N/A

PAGE 329.12

Bill~g

Dema

I

TRANSFER OF ENERGY
Megrtthours
Rece1ve
De 1Vered
( 1)
( J)
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
35,640
35,010
4,960
4,837
0
0
0
0
0
0
0
0
0
0
949
927

Megattho~rs

(~~~
0
0
0
0
0
0
0
0
0
15
10
0
0
0
0
0
154

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13

14
15
16
17

 m

Year of Report
Date of Re~ort
This Report Is:.
(Mo, Da, Y )
fXl A
An Resu
Or1~nal
Dec. 31. 1996
ission
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)
(Including transactions referred to as "wheeling")
shown on bills rendered to the ent i ty listed in column
and
(
j)
the
total megawatthours
8. Report in column (i)
(a). If no monetary settlement was made, enter ze r o
received and delivered.
("0") in column(n). Provide a footnote explaining the
9. In column (k) through (n), report the revenue amounts
nature of the nonmonetary settlement, including the
as shown on bills or vouchers. In column ( k). provide
amount and type of energy or service rendered.
revenues from demand charges related to the billing
10. Provide total amounts in column (i) through (n) as the
demand reported in column (h). In column ( l). provide
last line. Enter "TOTAL" in column (a) as the last
revenues from energy charges related to the amount of
line. The total amounts in columns (i) and (j) must be
energy transferred. In column (m), provide the total
reported
as Transmission Received and Delivered on page
vouchers
revenues from all other charges on bills or
lines
16 and 17, respectively.
out
of
period
adjustments
.
Explain
401,
including
rendered,
11. Footnote entries and provide explanations following
in a footnote all components of the amount shown in
all required data.
total charge
column (m). Report in column (n) the

Nfme of Respon~ent
F orida Power
L1ght Company

Demand iharges

~d

0
0
0
0
0
0
0
0
0
116,850
19,433
0
0
0
0
0
169,388

FERC FORM N0.1 (REVISED 12-90)

I

I

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energff~harges

~~~

0
0
0
0
0
0
0
0
0
13,832
97
0
0
0
0
0
55

*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*

PAGE 330.12

$3,732
3,732
3,732
3,732
3,732
3,732
(60)
1,132
3,732
1. 782
650
1,300
2,600
1,132
650
3, 732
1,132

I

Total ryvenues($)
( k+ +m)
(n)
$3,732
3, 732
3, 732
3, 732
3,732
3, 732
(60)
1,132
3,732
132,464
20,180
1,300
2,600
1,132
650
3, 732
170,575

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

Next Page i s 332

 Nfme of Respon~ent
L1ght Company
F orida Power

-

This Report Is:
Date of Re~ort
Year of Report
(Mo, Da, Y )
~~~ fXl A
An Resu
Or1~nal
ission
Dec. 31, 1996
TRANSMitSIQN OF ELECTRICITY F?R OT~ERS (Account 456~
(Inc ud1ng transact1ons re erre to as "wheel1ng ')
1. Report at t transmission of electricity, i. e. wheeling,
4. In cotumn(d) enter a Statistical Classification code
provided for other electric uti t ities, cooperatives,
based on the original contractual terms and conditions
mun i c i pa t i t i es, other
public authorities, qualifying
of the service as follows:
facilities, non-traditional
uti t i ty
suppliers
and
ultimate customers.
LF - for long-term firm transmission service. "Long-term"
2. Use a separate line of data for each distinct type of
means one year or longer and "firm" means that service
transmission service involving the entities t isted in
cannot be interrupted for economic reasons and is
column (a), (b) and (c).
intended to remain reliable even under adverse con3. Report in column (a) the company or public authority
ditions. For all transactions identified as LF, provide
that paid for the transmission service. Report
in
in a footnote the termination date of the contract
coll.1111'1(b) the company or public authority that the
defined as the earliest date that either buyer or
energy was received from and in column (c) the company
seller can unilaterally get out of the contract.
or pubt ic authority that the energy was delivered to.
Provide the fut t name of each company or public
SF - for short-term firm transmission service. Use this
authority. Do not abbreviate or truncate name or use
category for at t firm services, where the duration
acronyms. Explain in a footnote any ownership interest
of each period of commitment for
service is less than
in or affiliation the respondent has with the entities
one year.
t isted in columns (a), (b) or (c).
Pa~nt 6Y
.
Energy Recei}ed Fro~
Energy Delive}ed To
S[atislic
Line
c ass1 1(C~ant or Pu~~lt.Author1ty)
(Com~ant or Pu~ ly.Aut ority)
(Com~ant or Pu~ Iy.Authority)
No.
[ oo note A 1 1at1onsJ
[ oo note A 1 1at1onsJ
[ oo note A 1 1at1onsJ
cat1on
(a)
(b)
(c)
(d)
1 Southern Company Services, Inc.
N/A
N/A
SF
2 City of Starke
N/A
N/A
SF
3 Tampa Electric Company
N/A
N/A
SF
4 Valero Power Services Company
N/A
N/A
SF
N/A
N/A
5 City of Vera Beach
SF
N/A
6 City of Vera Beach
N/A
AD
7 Ft. Pierce Uti t ities Authority
Southern Company Services, Inc.
Ft. Pierce Utilities Authority
OS
8 TOTAL
9
10
11
12
13
14
15
16
17

"ERC FORM NO.1 (REVISED 12-90)

I

I

PAGE 328.13

I

 5.

m

Year of Report
Date of Re~ort
This Report Is:.
(Mo, Da, Y )
fXl A
An Resu
Or1~nal
Dec. 31, 1996
ission
TRANSMISSI?N OF ELECTRICITY FOR OTHERS (Account 45?)(Continued)
(Inc ud1ng transact1ons referred to as "whee 1ng")
as identified in column (d). is provided.
OS - for other transmission service. Use this category
6. Report receipt and delivery locations for all single
only for those services which cannot be placed in
contract path, "point to point" transmission service.
the above-defined categories, such as all nonfirm tranIn column (f), report the designation for the substasmission service, regardless of the length of the
tion, or other appropriate identification for where
contract. Describe the nature of the service in a
energy was received as specified in the contract. In
footnote.
column (g) report the designation for the substation,
or other appropriate identification for where energy
AD - for out-of-period adjustment. Use this code for
was delivered as specified in the contract.
any accounting adjustments or "true-ups" for service
7.
Report in column(h) the number of megawatts of billing
provided in prior reporting years. Provide an explanademand that is specified in the firm transmission
tion in a footnote for each adjustment.
service contract. Demand reported in column (h) must
In column (e), identify the FERC Rate Schedule or
be in megawatts. Footnote any demand not stated on a
Tariff Number. On separate lines, list all FERC rate
megawatts basis and explain.
schedules or contract designations under which service,

Nfme of Respon~ent
L1ght Company
F orida Power

FE~C Rfte
Sc ~?u NI.Milber
e of
Tari
(e)
62 of T-6
81 of T-6
64 of T-6
69 of T-6
9 of T-6
T-2
16 of T-6

Point of ReceiBt
(Substatlon or ther
De~1gnat1on)

(

)

N/A
N/A
N/A
N/A
N/A
N/A
System

FE RC FORM N0.1 (REVISED 12-90)

I

Point of Delivehy
Ot er
Des1gnat1on)
(g)

(Subst~tlon.or

N/A
N/A
N/A
N/A
N/A
N/A
Hartman Substation

PAGE 329 . 13

I

I

Bill i~g
Deman

TRANSFER OF ENERGY
Line
Megrtthours
De 1yered
Rece1ve
No.
( 1)
( J)
0
0 1
0
0 2
0
0 3
0
0 4
0
0 5
0
0 6
70
69 7
6,626,748
6,466,453 8
9
10
11
12
13
14
15
16
17

Megattho~rs

(~~~

0
0
0
0
0
0
0

 Nfme of Respon~ent
L1ght Company
F orida Power

This Report Is:

Date of

(Mo, Da,
~~~ fXl A
An Resu
Or1~nal
ission
I
I
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456)(Continued)

Re~ort

Y)

I

Year of Report
Dec. 31, 1996

(Including transactions referred to as "wheeling")
8. Report in column (i) and (j) the total megawatthours
shown on bills rendered to the entity listed in column
rece 1.- ~-i and delivered.
(a). If no monetary settlement was made, enter zero
9. In co
(k) through (n), report the revenue amounts
("0") in column(n). Provide a footnote explaining the
as sho ~ Jn bills or vouchers. In column (k), provide
nature of the nonmonetary settlement, including the
revenues from demand charges related to the billing
amount and type of energy or service rendered.
demand reported in column (h). In column ( l), provide
10. Provide total amounts in column (i) through (n) as the
revenues from energy charges related to the amount of
last line. Enter "TOTAL" in column (a) as the last
energy transferred. In column (m), provide the total
line. The total amounts in columns (i) and (j) must be
revenues from all other charges on bills or vouchers
reported as Transmission Received and Delivered on page
rendered, including out of period adjustments. Explain
401, lines 16 and 17, respectively.
. Footnote entries and provide explanations following
in a footnote all components of the amount shown in
column (m). Report in column (n) the
total charge
all required data.

,,

Demand iharges
- ···

-

~k~

0
0
0
0
0
0
0
19,311,483

>ERC FORM N0.1 (REVISED 12-90)

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Other Charges
Energff~harges

~~~

0
0
0
0
0
0
140
, ,440,394

*
*
*
*
*
*
*

PAGE 330.13

$2,600
3,732
3,732
, , 782
3, 732
(377)
( 140)
(2,203,129)

Total ryvenues($)
(k+ +m)
(n)
$2,600
3, 732
3,732
, , 782
3, 732
(377)
0
18,548,748

Line
No.

,

2
3
4
5
6
7
8
9
10
1,
12
13
14
15
16
17

Next Page is

~JL

 <

Page 328 Line 1 Column d

>

THIS FOOTNOTE APPLIES TO ALL OCCURRENCES OF "OS" CLASSIFICATIONS ON PAGES 328 THROUGH 328.13:
"OS" classifications are hour-by-hour transmission service
transactions.

<

Page 328 Line 9 Column b

>

THIS FOOTNOTE APPLIES TO ALL OCCURRENCES OF "JACKSONVILLE
ELECTRIC AUTHORITY" ON PAGES 328 THROUGH 330.12:
Florida Power & Light Company and Jacksonville Electric
Authority are co-owners of St. Johns River Power Park,
Scherer Unit No. 4, and the Duval-Hatch and Duval-Thalmann
500 KV transmission lines.

<

Page 328 Line 14 Column c

>

THIS FOOTNOTE APPLIES TO ALL OCCURRENCES OF "ORLANDO
UTILITIES COMMISSION" ON PAGES 328 THROUGH 330.11:
St. Lucie Unit No. 2 is jointly owned by Florida Power &
Light Company (85.10449%), Florida Municipal Power Agency
(8.806%) and Orlando Utilities Commission (6.08951%).

<

Page 328.1 Line 9 Column a

>

THIS FOOTNOTE APPLIES TO ALL OCCURANCES OF "FLORIDA MUNICIPAL
POWER AGENCY" ON PAGES 328.1 THOUGH 330.11:
St. Lucie Unit No. 2 is jointly owned by Florida Power & Light
Company (85.10449%), Florida Municipal Power Agency (8.806%),
and Orlando Utilities Commission (6.08951%).

<

Page 328.8 Line 16 Column d

>

Service shall be provided until the earlier of the retirement of
Stanton No. 1 or December 31, 2022.

<

Page 328.9 Line 1 Column d

>

Service shall be provided until the earlier of the retirement of
Stanton No. 1 or December 31, 2022.

Page 328-330 Footnote.1

 <

Page 328.9 Line 3 Column d

>

Service shall be provided until the earlier of the retirement of Stanton No. 2 or December 31, 2032.

<

Page 328.9 Line 4 Column d

>

Service shall be provided until the earlier of the retirement of
Stanton No. 1 or December 31, 2022.

<

Page 328.9 Line 6 Column d

>

Service shall be provided until the earlier of the retirement of
Stanton No. 1 or December 31, 2022.

<

Page 328.9 Line 8 Column d

>

Service shall be provided until the earlier of the retirement of Stanton No. 2 or December 31, 2032.

<

Page 328.9 Line 9 Column d

>

Service shall be provided until the earlier of the retirement of
Stanton No. 1 or December 31, 2022.

<

Page 328.9 Line 11 Column d

>

Service shall be provided until the earlier of the retirement of Stanton No. 2 or December 31, 2032.

<

Page 328.9 Line 12 Column d

>

Service shall be provided until the earlier of the retirement of
Stanton No. 1 or December 31, 2022.

<

Page 328.9 Line 14 Column d

>

Service shall be provided until the earlier of the retirement of
Stanton No. 1 or December 31, 2022.

Page 328- 330 Foo t n o te .2

 <

Page 328.9 Line 16 Column d

>

Service shall be provided until the earlier of the retirement of Stanton No. 2 or December 31, 2032.

<

Page 328.9 Line 17 Column d >

Service shall be provided until the earlier of the retirement of
Stanton No. 1 or December 31, 2022.

<

Page 328.10 Line 2 Column d >

Service shall be provided until the earlier of the retirement of Stanton No. 2 or December 31, 2032.

<

Page 328.10 Line 3 Column d

>

Service shall be provided until the earlier of retirement of Stanton No. 1 or December 31, 2022.

<

Page 328.10 Line 4 Column d >

Service shall be provided until the earlier of retirement of Stanton No. 1 or December 31, 2022.

<

Page 328.10 Line 5 Column d >

Service shall be provided until the earlier of retirement of Stanton No. 2 or December 31, 2032.

<

Page 328.10 Line 6 Column b >

Energy delivered to the City of Clewiston is received
from Florida Power & Light Company's St. Lucie Plant,
Orlando Utilities Commission's Indian River Plant, City
of Homestead's Lucy Substation and Tampa Electric
Company's multiple interconnections with Florida Power
& Light Company; namely, the Manatee and Johnson 230 KV
Substations.

<

Page 328.10 Line 6 Column d

>

Contract superseded by Network Agreement on April 1, 1996.
Page 328-330 Footnote.3

 <

Page 328.10 Line 7 Column b

>

Same footnote as Page 328.10, Line 6, Column b.

<

Page 328.10 Line 8 Column b

>

Energy delivered to the City of Green Cove Springs is
received from Florida Power & Light Company's St. Lucie
Plant, City of Lake Worth Utilities' Hypoluxo Substation,
City of Gainesville's Deerhaven Substation, Orlando Utilities Commission's Indian River Plant and Tampa Electric
Company's multiple interconnections with Florida Power &
Light Company; namely, the Manatee and Johnson 230 KV
Substations.

<

Page 328.10 Line 8 Column d

>

Contract superseded by Network Agreement on April 1, 1996.

<

Page 328.10 Line 9 Column b

>

Same footnote as Page 328.10, Line 8, Column b.

<

Page 328.10 Line 10 Column b

>

Energy delivered to the City of Jacksonville Beach is
received from Florida Power & Light Company's St. Lucie
Plant, City of Lake Worth Utilities' Hypoluxo Substation,
City of Gainesville's Deerhaven Substation, Orlando Utilities Commission's Indian River Plant and Tampa Electric
Company's multiple interconnections with Florida Power &
Light Company; namely, the Mantee and Johnson 230 KV
Substations.

<

Page 328.10 Line 10 Column d

>

Contract superseded by Network Agreement on April 1, 1996.

<

Page 328.10 Line 11 Column b

>

Same footnote as Line 328.10, Line 10, Column b.

Page 328-330 Foo tnote.4

 <

Page 328.10 Line 12 Column d >

Contract superseded by Network Agreement on April 1, 1996.

<

Page 328.10 Line 13 Column b >

Energy is received from Florida Power & Light Company's
St. Lucie Plant, City of Lake Worth Utilities' Hypoluxo
Substation, City of Gainesville's Deerhaven Substation,
Orlando Utilities Commission's Indian River Plant, City
of Homestead's Lucy Substation and Tampa Electric Company's multiple interconnections with Florida Power &
Light Company; namely, the Manatee and Johnson 230 KV
Substations.

<

Page 328.10 Line 13 Column c

>

Energy delivered to the City of Clewiston, City of Green
Cove Springs and the City of Jacksonville Beach.

<

Page 328.10 Line 13 Column d

>

Contract expires on April 1, 2026.

<

Page 328.10 Line 14 Column d

>

Contract expires when St. Lucie No. 2 is decommissioned.

<

Page 328.10 Line 15 Column d

>

Contract expires when St. Lucie No. 2 is decommissioned.

<

Page 328.10 Line 17 Column d

>

Contract expires when St. Lucie No. 2 is decommissioned.

<

Page 328.11 Line 2 Column d >

Contract shall continue so long as the "Revised Agreement"
remains in effect.

Page 328-330 Footnote.5

 <

Page 328.11 Line 4 Column d

>

Agreement shall terminate on December 31, 2004.

<

Page 328.11 Line 6 Column d

>

Contract requires five years notice for termination.

<

Page 328.11 Line 8 Column d

>

Contract expires October 31, 2013.

<

Page 329.1 Line 7 Column h

>

Transaction was on a daily basis instead of hourly.

<

Page 329.1 Line 8 Column h

>

Transaction was on a daily basis instead of hourly.

<

Page 329.10 Line 6 Column h

>

Average billing demand.

<

Page 329.10 Line 8 Column h

>

Average billing demand.

<

Page 329.10 Line 10 Column h

>

Average billing demand.

<

Page 329.10 Line 13 Column h

>

The billing demand is based on the ratio using a 12-month
running average, dividing Florida Power & Light Company's
monthly peak hour load by Florida Municipal Power Agency's
monthly peak hour load.

Page 328-330 Footnote.6

 <

Page 330 Line 2 Column m

>

"Other charges" - Flexible Point to Point transmission
replacement credit.

<

Page 330 Line 4 Column m >

"Other charges" - Flexible Point to Point transmission
replacement credit.

<

Page 330 Line 6 Column m >

"Other charges" - Flexible Point to Point transmission
replacement credit.

<

Page 330 Line 9 Column m >

"Other charges" - Flexible Point to Point transmission
replacement credit.

<

Page 330 Line 11 Column m >

"Other charges'' - Flexible Point to Point transmission
replacement credit.

<

Page 330 Line 15 Column m >

"Other charges" - Flexible Point to Point transmission
replacement credit.

<

Page 330.1 Line 2 Column m >

"Other charges" - Flexible Point to Point transmission
replacement credit.

<

Page 330.1 Line 16 Column m >

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

Page 328-330 Footnote.?

 <

Page 330.2 Line 1 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and / or Flexible
Point to Point transmission replacement credit.

<

Page 330.2 Line 2 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.2 Line 4 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.2 Line 5 Column m

>

"Other charges'' - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.2 Line 6 Column m

>

"Other charges'' - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.2 Line 7 Column m

>

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

<

Page 330.2 Line 12 Column m

>

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

<

Page 330.2 Line 13 Column m >

"Other charges'' - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and / or Flexible
Poi n t to Point tra n smission replacement credit.
Page 328-330 Footnote.8

 <

Page 330.2 Line 15 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and /o r Flexible
Point to Point transmission replacement credit.

<

Page 330.2 Line 16 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.3 Line 1 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.3 Line 3 Column m >

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.3 Line 4 Column m >

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.3 Line 5 Column m >

"Other charges" - · stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.3 Line 6 Column m >

"Other charges'' - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

Page 328-330 Footnote.9

 <

Page 33 0 .3 Line 7 Column m

>

"Other charges" - Stanton transmissi o n repla c eme nt credit,
St. Lucie transmission replacement credit and / or Flexible
Point to Point transmission replacement credit.

<

Page 330.3 Line 8 Column m >

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

<

Page 330.4 Line 1 Column m

>

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

<

Page 330.4 Line 2 Column m

>

"Other charges'' - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and / or Flexible
Point to Point transmission replacement credit.

<

Page 330.4 Line 5 Column m >

"Other charges" - Stanton transmission replacement credit,
St . Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit .

<

Page 330.4 Line 7 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.4 Line 10 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and / or Flexible
Point to Point transmission replacement credit.

<

Page 330.4 Line 12 Column m >

"Ot h e r charges" - 1995 True-up of the T-3 Alternate Rate.

Page 328 - 330 Foo t n ote . 10

 <

Page 330.4 Line 13 Column m

>

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

<

Page 330.4 Line 14 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and /o r Flexible
Point to Point transmission replacement credit.

<

Page 330.4 Line 16 Column m >

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.4 Line 17 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.5 Line 1 Column m >

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.5 Line 4 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.5 Line 5 Column m >

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

Page 328-330 Footnote.11

 <

"(
S,
Pc

<

Page 330.5 Line 6 Column m

>

er charges" - Stanton transmission replacement credit,
Lucie transmission replacement credit and/or Flexible
1t to Point transmission replacement credit.

Page 330. 5 Line 7 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.5 Line 8 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.5 Line 9 Column m

>

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

? age 330.5 Line 17 Column m

>

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

<

Page 330.6 Line 1 Column m

>

"Other charges" - Flexible Point to Point transmission
replacement credit.

<

Page 330.6 Line 2 Column m

>

"Other charges" - Flexible Point to Point transmission
replacement credit.

<

Page 330.6 Line 8 Column m

>

''Jther charges" - transmission service credit for Seminole
=ctric Cooperative, Inc.'s load which is in Florida
wer & Light Company's territory.

~

Page 328-330 Footnote.12

 <

Page 330.6 Line 9 Column m

>

"Other Charges" - transmission service credit for Seminole
Electric Cooperative, Inc.'s load which is in Florida
Power & Light Company's territory.

<

Page 330.6 Line 10 Column m

>

"Other Charges" - transmission service credit for Seminole
Electric Cooperative, Inc.'s load which is in Florida
Power & Light Company's territory.

<

Page 330.6 Line 11 Column m >

"Other charges" - transmission service credit for Seminole
Electric Cooperative, Inc.'s load which is in Florida
Power & Light Company's territory.

<

Page 330.6 Line 12 Column m >

"Other charges" - transmission service credit for Seminole
Electric Cooperative, Inc.'s load which is in Florida
Power & Light Company's territory.

<

Page 330.6 Line 13 Column m >

"Other Charges" - transmission service credit for Seminole
Electric Cooperative, Inc.'s load which is in Florida
Power & Light Company's territory.

<

Page 330.6 Line 14 Column m >

"Other Charges" - transmission service credit for Seminole
Electric Cooperative, Inc.'s load which is in Florida
Power & Light Company's territory.

<

Page 330.6 Line 15 Column m

>

"Other Charges" - transmission service credit for Seminole
Electric Cooperative, Inc.'s load which is in Florida
Power & Light Company's territory.

Page 328-330 Footnote.13

 <

Page 330.6 Line 16 Column m

>

"Other Charges" - transmission service credit for Seminole
Electric Cooperative, Inc.'s load which is in Florida
Power & Light Company's territory.

<

Page 330.6 Line 17 Column m

>

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

<

Page 330.7 Line 1 Column m

>

"Other charges" - Flexible Point to Point transmission
replacement credit.

<

Page 330.7 Line 11 Column m >

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.7 Line 14 Column m >

"Other charges'' - 1995 True-up of the T-3 Alternate Rate.

<

Page 330.7 Line 17 Column m

>

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

<

Page 330.8 Line 5 Column m >

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

<

Page 330.8 Line 6 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

Page 328-330 Footnote.14

 <

Page 330.8 Line 8 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and / or Flexible
Point to Point transmission replacement credit.

<

Page 330.8 Line 11 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.8 Line 12 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.8 Line 13 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

<

Page 330.8 Line 14 Column m

>

"Other charges" - 1995 True-up of the T-3 Alternate Rate.

<

Page 330.8 Line 17 Column m

>

"Other charges'' - Adjustment for December 1995, 1995
Demand Charge true-up and 1995 FERC Assessment Charge.

<

Page 330.9 Line 2 Column m >

"Other charges" - Adjustment for December 1995, 1995
Demand Charge true-up and 1995 FERC Assessment Charge.

<

Page 330.9 Line 5 Column m

>

"Other charges" - Adjustment for December 1995, 1995
Demand Charge true-up and 1995 FERC Assessment Charge.
Page 328-330 Footnote.15

 <

Page 330.9 Line 7 Column m

>

"Other charges" - Adjustment for December 1995, 1995
Demand Charge true-up and 1995 FERC Assessment Charge.

<

Page 330.9 Line 10 Column m >

"Other charges" - Adjustment for December 1995, 1995
Demand Charge true-up and 1995 FERC Assessment Charge.

<

Page 330.9 Line 13 Column m >

"Other charges" - Adjustment for December 1995, 1995
Demand Charge true-up and 1995 FERC Assessment Charge.

<

Page 330.9 Line 15 Column m >

"Other charges" - Adjustment for December 1995, 1995
Demand Charge true-up and 1995 FERC Assessment Charge.

<

Page 330.10 Line 1 Column m >

"Other charges" - Adjustment for December 1995, 1995
Demand Charge true-up and 1995 FERC Assessment Charge.

<

Page 330.10 Line 3 Column m >

"Other charges" - Customer Charge.

<

Page 330.10 Line 4 Column m >

"Other charges" - Customer Charge.

<

Page 330.10 Line 5 Column m >

"Other charges" - Customer Charge.

Page 328-330 Footnote.16

 <

Page 330.10 Line 7 Column m

>

"Other charges" - 1995 Demand Charge true-up and 1995 FERC
Assessment Charge.

<

Page 330.10 Line 9 Column m

>

"Other charges" - 1995 Demand Charge true-up and 1995 FERC
Assessment Charge.

<

Page 330.10 Line 11 Column m >

"Other charges" - 1995 Demand Charge true-up and 1995 FERC
Assessment Charge.

<

Page 330.10 Line 12 Column m

>

"Other charges" - Customer Charge.

<

Page 330.10 Line 13 Column m

>

"Other charges" - Network Study Cost.

<

Page 330.10 Line 14 Column m >

"Other charges" - Customer Charge.

<

Page 330.10 Line 15 Column m >

"Other charges" - Customer Charge.

<

Page 330.10 Line 16 Column m

>

"Other charges" - 1995 Demand Charge true-up and 1995 FERC
Assessment Charge.

<

Page 330.10 Line 17 Column m

>

"Other charges" - Customer Charge.

Page 328-330 Footnote.17

 <

Page 330.11 Line 1 Column m

>

"Other charges" - 1995 Demand Charge true-up and 1995 FERC
Assessment Charge.

<

Page 330.11 Line 3 Column m

>

"Other charges" - 1994 and 1995 Demand Charge true-up.

<

Page 330.11 Line 4 Column m >

"Other charges" - Customer Charge.

<

Page 330.11 Line 5 Column m >

"Other charges'' - 1995 Demand Charge true-up, 1995
FERC Assessment Charge and 1995 Customer Charges.

<

Page 330.11 Line 6 Column m >

"Other charges" - Customer Charge.

<

Page 330.11 Line 7 Column m

>

"Other charges" - 1995 Demand Charge true-up and 1995 FERC
Assessment Charge.

<

Page 330.11 Line 8 Column m

>

"Other charges" - Customer Charge.

<

Page 330.11 Line 9 Column m

>

"Other charges'' - 1995 Demand Charge true-up, 1994 and
1995 FERC Assessment Charge.

<

Page 330.11 Line 10 Column m

>

"Other charges" - Customer Charge.
Page 328-330 Footnote.18

 <

Page 330.11 Line 11 Column m >

"Other charges" - Customer Charge.

<

Page 330.11 Line 12 Column m >

"Other charges" - Customer Charge.

<

Page 330.11 Line 13 Column m >

"Other charges" - Customer Charge.

<

Page 330.11 Line 14 Column m >

"Other charges" - Customer Charge.

<

Page 330.11 Line 15 Column m >

"Other charges" - 1995 Demand Charge true-up.

<

Page 330.11 Line 16 Column m >

"Other charges" - Customer Charge.

<

Page 330.11 Line 17 Column m >

"Other charges" - Customer Charge.

<

Page 330.12 Line 1 Column m

>

"Other charges" - Customer Charge.

<

Page 330.12 Line 2 Column m

>

"Other charges" - Customer Charge.

Page 328-330 Footnote.19

 <

Page 330.12 Line 3 Column m

>

"Other charges" - Customer Charge.

<

Page 330.12 Line 4 Column m

>

"Other charges" - Customer Charge.

<

Page 330.12 Line 5 Column m

>

"Other charges" - Customer Charge.

<

Page 330.12 Line 6 Column m >

"Other charges" - Customer Charge.

<

Page 330.12 Line 7 Column m

>

"Other charges" - 1995 Demand Charge true-up and 1995 FERC
Assessment Charge.

<

Page 330.12 Line 8 Column m >

"Other charges" - Customer Charge.

<

Page 330.12 Line 9 Column m

>

"Other charges" - Customer Charge.

<

Page 330.12 Line 10 Column m >

"Other charges" - Customer Charge.

<

Page 330.12 Line 11 Column m

>

"Other charges" - Customer Charge.

Page 328-330 Footnote.20

 <

Page 330.12 Line 12 Column m

>

"Other charges" - Customer Charge.

<

Page 330.12 Line 13 Column m

>

"Other charges" - Customer Charge.

<

Page 330.12 Line 14 Column m

>

"Other charges" - Customer Charge.

<

Page 330.12 Line 15 Column m

>

"Other charges" - Customer Charge.

<

Page 330.12 Line 16 Column m >

"Other charges" - Customer Charge.

<

Page 330.12 Line 17 Column m >

"Other charges" - Customer Charge.

<

Page 330.13 Line 1 Column m >

"Other charges" - Customer Charge.

<

Page 330.13 Line 2 Column m

>

"Other charges" - Customer Charge.

<

Page 330.13 Line 3 Column m

>

"Other charges" - Customer Charge.

<

Page 330.13 Line 4 Column m

>

"Other charges" - Customer Charge.
Page 328-330 Footnote.21

 <

Page 330.13 Line 5 Column m

>

"Other charges" - Customer Charge.

<

Page 330.13 Line 6 Column m

>

"Other charges" - 1995 Demand Charge true-up and 1995 FERC
Assessment Charge.

<

Page 330.13 Line 7 Column m

>

"Other charges" - Stanton transmission replacement credit,
St. Lucie transmission replacement credit and/or Flexible
Point to Point transmission replacement credit.

Page 328-330 Footnote.22

 m

Year of Repo r t
Date of Report
This Report Is:.
(Mo, Da, Yr)
fXJ A
An Resu
Or1~nal
Dec . 31, 1996
ission
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
(Including transactions referred to as "wheeling")
column (f), provide the total of all other charges on
1. Report all transmission, i.e., wheeling, of elecbills or vouchers rendered to the respondent, including
tricity provided to respondent by other electric utiliany out of period adjustments. Explain in a footnote all
municipalities, or other public
cooperatives,
ties,
components of the amount shown in column (f). Report in
authorities during the year.
column (g) the total charge shown on bills rendered to the
company
or
public
authoreport
each
2. In column (a)
respondent. If no monetary settlement was made, enter zero
rity that provided transmission service. Provide the full
("0") in column (g). Provide a footnote explaining the
name of the company; abbreviate if necessary, but do not
nature of the nonmonetary settlement, including the amount
truncate name or use acronyms. Explain in a footnote any
and type of energy or service rendered .
ownership interest in or affiliation with the transmiss ion
6. Enter "TOTAL" in column (a) as the last line. Provide
service provider.
a total amount in columns (b) through (g) as the last l i ne.
3. Provide in column (a) subheadings and classify transEnergy provided by the respondent for the wheeler's
mission service purchased from other utilities as: "Deli transmission losses should be reported on the Electric
vered Power to IJheeler" or "Received Power from IJheeler."
Energy
Account, page 401 . If the respondent received power
total
megawatthours
4. Report in columns (b) and (c) the
from the wheeler, energy provided to account for losses
received and delivered by the provider of the transmission
should be reported on line 19. Transmission By Others
service.
Losses, on page 401. Otherwise, losses should be reported
5. In columns (d) through (g), report expenses as shown
on line 27, Total Energy Losses, page 401.
on bills or vouchers rendered to the respondent. In column
7. Footnote entries and prov ide explanations following
(d), provide demand charges. In column (e), provide energy
all required data.
charges related to the amount of energy transferred. In
TRANSFER OF ENERGY
EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line Na~y . of Co~paot or
Other
Total Cost of
Pu 1c Aut r y
Demand
No.
~egawatt~egawattE~ergy
[Footnote A ~illations]
ours
Transm$ss1on
charrs
charrs
c arrs
Rece1ved
Deo~rs
ivered
(b)
(C)
(a)
~~
~~
~g~
~~
1 "Received Power from
2 IJheeler"
(77)
3 * Florida Power Corp
1,884
1,839
0
4,174 *
4,097
4,219,424
4,219,382
34,656
239,225
0
4 *Jacksonville Elec Aut
273,881
0
0
0
0 *
500
500
5 * Tennessee Valley Auth
6
7 SUBTOTAL
4,221,308
4,221,221
34,656
243,399
423
278,478
8
9 "Delivered Power to
10 IJheeler"
11 * Southern Co Services
4,094,094
4,094,052
11,156,733
27,237 *
(650,251)
10,533,719
12
4,094,094
4,094,052
11,156,733
(650,251)
13 SUBTOTAL
27,237
10,533,719
* 8,315,402 * 8,315,273
14 TOTAL
(649,828)
270,636
11 '191 ,389
10,812,197
15
16
Nfme of Respon~ent
L1ght Company
F orida Power

FERC FORM NO. 1 (REVISED. 12-90)

l

Page 332

I

I

Next Page is 335

 <

Page 332 Line 3 Column a

>

Complete name: Florida Power Corpo a tion

<

Page 332 Line 3 Column f >

"Other charges" - 1995 true-up adjustment.

<

Page 332 Line 4 Column a

>

Complete name: Jacksonville Electric Authority
Florida Power and Light Company and Jacksonville Electric
Authority are co-owners of St. Johns River Power Park, Scherer
Unit No.4, and the Duval-Hatch and Duval-Thalmann 500KV
transmission lines.

<

Page 332 Line 5 Column a >

Complete name: Tennessee Valley Authority

<

Page 332 Line 5 Column f >

"Other charges'' - Non-refundable request fee.

<

Page 332 Line 11 Column a >

Comt, lete name: Southern Company Services, Inc.

<

Page 332 Line 11 Column f >

"Other charges" - 1995 true-up adjustment.

<

Page 332 Line 14 Column b

>

Total MWh's received - 4,221,308

<

Page 332 Line 14 Column c >

Total MWh's delive red - 4,221,221
Page 332 Footno te.1

 Nfme of Respon~ent
F orida Power
L1ght Company
Line
No.

,

2
3
4
5
6
7
8
9
10

,,

12
13
14
15
16

m

Date of Report
This Report Is:
(Mo, Da, Yr)
fXJ An
Or1~nal
A Resu
ission
MISCELLANEOUS GENERAL EXPENSES (Account 930.2)(ELECTRIC)

I

I

I

Descri~tion

(a

Industry Association Dues
Nuclear Power Research Expenses
Other Experimental and General Research Expenses
Publishing an~ Distributing Information and R?ports _tQ Stockholders; Trustee, Registhar~ and Transfer
Agent Fees an Expenses, and Other Expenses o Serv1c1ng Outstand1ng Secur1t1es of t e espondent
Ot~er Expenses (~ist
items of $5,000 or mor? in this ci~~n s~owing the (~) ~ur~ose, (2) reci~ient
an (3) emou~t o such 1tems. Group amounts o ess that
, 00 y classes 1 t e umber of 1te s so
grouped 1s s own)

Year of Report
Dec. 31, 1996
Amount
(b)
$2,883,571
0
468,991
371,727

Membership Fees

305,926

Directors Fees and Expenses

879,265

Management and Employee Development Expenses

289,199

SJRPP Special Voluntary Severance Program

62,351

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

Legal Expenses and Settlements

(2,818,621)

Environmental Expenses

33,050,000

Strategic Business Unit Review

10,094,000

Dormant Material Write-Off

(35 ,747)

FPL Historical Museum

231,412

Reddy Communications

40,543

Electric Transportation Program

12,707

Benchmarking Project

16,936

Various Other Items less than $5,000

13,814

TOTAL

FE RC FORM N0.1 (ED. 12-94)

$45,866,074

Page 335

 Nfme of Respon~ent
F orida Power
L1ght Company

This Report I:,:
Year of Report
Date of Re~ort
(Mo, Da , Y )
~~~ fXl A
An Resu
Or1~nal
Dec. 31, 1996
ission
DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Accounts 403, 404, 405)
(Except amortization of acquisition adjustments)
1. Report in Section A for the year the amounts for:
classifications and showing a composite total. Indicate
(a) Depreciation Expense (Account 403); (b) Amortization
at the bottom of section c the manner in which column
of Limited-Term Electric Plant (Account 404); and (c)
balances are obtained. If average balances, state the
Amortization of Other Electric Plant (Account 405).
method of averaging used.
2. Report in section B the rates used to compute amorti For columns (c), (d). and (e) report available informazation charges for electric plant (Accounts 404 and
tion for each plant subaccount, account or functional
405). State the basis used to compute charges and
classification listed in column (a). If plant mortality
whether any changes have been made in the basis or
studies are prepared to assist in estimating average
rates used from the preceding report year.
service lives, show in column (f) the type mortality
3. Report all available information called for in section
curve selected as most appropriate for the account
section C every fifth year beginning with report year 1971,
and in column (g), if available, the weighted average
reporting annually only changes to columns (C) through
average remaining life of surviving plant.
(g) from the complete report of the preceding year.
If composite depreciation accounting is used, report
Unless composite depreciation accounting for total depreavai table information called for in columns (b) through
ciable plant is followed, list numerically in column (a)
(g) on this basis.
each plant subaccount, account or
functional classifi4. If provisions for depreciation were made during
cation, as appropriate, to which a rate is applied.
the year in addition to depreciation provided by applica Identify at the bottom of section c the type of plant
tion of reported rates, state at the bottom of
included in any subaccounts used.
section c the amounts and nature of the provisions
In column (b) report all depreciable plant balances to
and the plant items to which related.
which ~ ates are applied showing subtotals by functional
A. Summary of Depreciation and Amortization Charges
De~reciation
Amortizftion of
Amortiaation rf
xpense
Line
Functional Classification
Total
L1m1tf
-Term E a~-)
O[her E ec! 0 ~c
No.
(Account 403)
tr1cP ant(Acc
P ant~~~c
)
(a)
(b)
(c)
(e)
Intangible Plant
$2,676,888
$25,996,933
$28,673,821
1
191,145,114
2,324,682
193,469,796
2 Steam Product Plant
*
Nuclear Production Plant
3
316,076,632
7,077,426
323,154,058
*
Hydraulic Production Plant--Conventional
0
4
0
5 Hydraulic Production Plant--Pumped Storage
79,300,337
77,978,479
1,321,858
6 Other Production Plant
40,459,612
Transmission Plant
40,459,612
7
184,829,352
184,829,352
8 Distribution Plant
54,077,156
19,536,912
34,540,244
9 General Plant
10
Conmon Plant--Electric
$71,261,143
$903 964 132
$832,702,989
TOTAL
11
B. Basis for Amortization Charges
Account 404 represents applicable annual amounts of leasehold improvements, short-t ived production property,

l

I

1

1

selected general plant property and miscellaneous intangible plant costs amortized over their respective lives or
lives assigned by the Florida Public Service Commission CFPSC) in Rule 25-6.0142 of the Florida Administrative Code.

FER :: FORM N0.1 (ED. 12 -uo)

PAGE 336

1

 This Report Is:
( 1) [X] An Original
(2) [ l A Resubmission

Name of Respondent
Florida Power & Light Company

Date of Report
(Mo, Da, Yr)

Year of Report
Dec. 31, 1996

DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)

c. Factors Used in Estimating Depreciation Charges

Line
No.

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
47
48
49
50

Depreciable
Plant Base
(In Thousands)
(b)

Account
No.
(a)
Cape Canaveral
Cutler
Ft. Myers
Manatee
Martin
Martin Pipet ine
Pt. Everglades
Riviera 3 & 4
Sanford
Scherer Coal Cars
Scherer Excl. Coal Cars
St. Johns River Power
Parle Coal Cars
St. Johns River Power
Parle Excl. Coal Cars
Turkey Point
316.3
*
316.5
*
316.7
*
Subtotal - Steam
St. Lucie
Turkey Point
325.3
325.5
325.7
Subtotal - Nuclear

*
*
*

Ft. Myers GTs
Lauderdale GTs
Lauderdale Units 4 & 5
Martin Pipeline
Martin Units 3 & 4
Pt. Everglades GTs
Putnam
346.3
*
346.5
*
346.7
*
Subtotal - Other

FERC FORM NO.1 (ED. 12-95)

Estimated
Avg. Service
Life
(C)

Net
Salvage
(Percent)
(d)

Applied
Depr. Rates
(Percent)
(e)

Mortality
Curve
Type
(f)

Average
Remaining
Life
(g)

152,767
45,287
80,326
383,992
703,896
371
246,813
89,391
150,809
24,026
543,132

27.DO
22.00
31.00
27.00
29.00
11 .30
28.00
30.00
31.00
15.00
31.00

(10.00%)
0
(8.00%)
(8.00%)
(8.00%)
(13.00%)
(10.00%)
(9.00%)
(8.00%)
(20.00%)
(12.20%)

4.40%
4.70%
3.20%
4.70%
4.00%
10.40%
4.60%
3.30%
3.40%
8.00%
3.70%

17.40
8.40
12.90
13.00
17.10
10.60
12.80
15.30
13.90
15.00
26.00

2,842

15.00

(20.00%)

9.30%

8.50

323,879
145,796
429
5,345
7,645
2,906,746

29.00
25.00

(13.00%)
(11.00%)

3.60%
4.00%

23.00
17.50

2,170,843
1,200,146
598
7,896
35,024
3,414,507

34.00
21.00

(6.00%)
(5.00%)

3.30%
5.50%

23.00
12.70

58,169
81,064
516,495
13,293
468,535
43,561
155,133
136
2,214
5,957
1,344,557

28.00
30.00
16.60
11.30
16.80
31.00
21.00

(2.00%)
(2.00%)
(2.00%)
(2.00%)
(2.00%)
(2.00%)
(2.00%)

2.10%
1.90%
6.60%
9.40%
6.10%
1.00%
5.10%

9.50
9.50
13.90
10.60
15.30
9.10
11.10

PAGE 337

Next Page i s 340

 Name of Respondent
Florida Power & Light Company

This Report Is:
( 1) [X] An Original
(2) [ l A Resubmission

Date of Report
(Mo, Da, Yr)

Year of Report
Dec. 31, 1996

DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)

c. Factors Used in Estimating Depreciation Charges

-

Line
No.

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
47
48
49
50

rEK:

Depreciable
Plant Base
(In Thousands)
(b)

Account
No.
(a)

Estimated
Avg. Service
Life
(c)

Net
Salvage
(Percent)
(d)

Applied
Depr. Rates
(Percent)
(e)

350.2
352
353
354
355
356
357
358
359
Subtotal - Transmission

129,952
40,431
727,788
272,029
338,855
409,789
30,103
33,726
71,043
2,053,716

65.00
47.00
40.00
45.00
40.00
37.00
46.00
35.00
65.00

0
(15.00%)
20.00%
(15.00%)
(35.00%)
(20.00%)
0
0
0

361
362
362 LMS
364
365
366.6
366.7
367.6
367.7
367.8
367.9
368
369.1
369.7
370
370 LMS
371
371 LMS
373
Subtotal - Distribution

45.00
37.00

(5.00%)
(5.00%)

36.00
34.00
54.00
35.00
34.00
29.00

*
*

62,120
725,738
14,195
451,528
706,381
411,345
21,885
538,959
324,865
13,602
3,362
975,321
104,815
314,323
310,348
478
45,847
93,801
207,176
5,326,089

390
390 LRIC
391.1
391.2
391.3
391.4
391.5

*
*
*
*
*
*
*

145,461
180,976
17,620
3,712
997
3,612
120,691

FORM N0.1 (ED. 12 -95 )

*

*
*

(f)

Average
Remaining
Life
(g)

S4.0
S4.0
R2.0
R5.0
R2.0
R2.5
S3.0
S3.0
SQ

49.00
36.00
30.00
30.00
29.00
26.00
27.00
17.50
52.00

2.30% L3.0
2.80% R1.5

35.00
29.00

(30.00%)
(35.00%)
0
0
10.00%
0

3.10%
3.60%
1.80%
3.00%
2.50%
2.80%

LO.O
L1.0
S2.0
S3.0
S0.5
R3.0

30.00
27.00
44.00
25.00
27.00
17.80

30.00
36.00
34.00
30.00

(15.00%)
(60.00%)
(10.00%)
5.00%

3.70%
4.20%
3.10%
2.90%

S1.0
R1.0
R2.0
S3.0

22.00
27.00
27.00
18.50

15.00

(20.00%)

7.90% L1.0

10.70

25.00

(20.00%)

4.30%

so.o

18.10

47.00
47.00

0
0

2.20% S1.5
2.00% S1.5

39.00
39.00

PAGE 337.1

1.70%
2.50%
1.80%
2.80%
3.20%
3.00%
2.20%
2.80%
1.50%

Mortality
Curve
Type

Next Page is 340

 This Report Is:
( 1) [X] An Original
(2) [ J A Resubmission

Name of Respondent
Florida Power & Light Company

Date of Report
(Mo, Da, Yr)

Year of Report
Dec. 31, 1996

DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)

c. Factors Used in Estimating Depreciation Charges

Line
No.

Depreciable
Plant Base
(In Thousands)
(b)

Account
No.
(a)

12 391 .6 LMS
13 391.7 LMS
14 391.8 LMS
15 391.9
16 392.0 Fixed Wing
17 392.0 Rotary Wing
18 392.0 Jet
19 392.1
20 392.2
21 392.3
22 392.7
23 392.9
24 393.1
25 393.2
26 393.3
27 394.1
28 394.2
29 395.1
30 395.2
31 395.6 LMS
32 395.8 ECCR
33 396.1
34 396.8
35 397.1
36 397.3
37 397.4 LMS
38 397.6 LMS
39 397.8
40 398
41 398.6 LMS
42 Subtotal - General
43
44 390.1 (Leaseholds)
45
46 Total
47
48 * Nuclear and Steam
Amortization
49
50

FERC FORM N0 .1 (ED . 12-95)

*
*
*
*
*

*
*
*
*
*
*
*

*
*
*
*
*

2,173
326
1,410
10,194
0
2,108
19,984
820
16,418
145,912
37
11,408
9,129
1,204
579
14,732
10,086
21,093
12,015
793
2,559
6,033
223
37,033
18,379
753
63
33,433
7,720
1
859,687

Estimated
Avg. Service
Life
(C)

Mortality
Curve
Type
(f)

Applied
Depr. Rates
(Percent)
(e)

Net
Salvage
(Percent)
(d)

Average
Remaining
Life
(g)

SQ
SQ
SQ
R3.0
S3.0
S2.0

3.10
6.50
6.50
2.10
3.50
6.80

20.00%
10.00%

3.90% S2.0
3.50% R2.0

10.50
19.90

28.00

(10.00%)

3.80% R0.5

24.00

35.00

0

2.80% L0.5

30.00

9.00
9.00
17.00
8.00

20.00%
20.00%
0
0

10.00

5.00%

10.00
7.00
10.00
6.00
8.00
12.00

50.00%
50.00%
50.00%
10.00%
15.00%
15.00%

17.00
26.00

0.30%
6.40%
5.20%
26.40%
11 .30%
6.80%

5.50%
1.50%
5.50%
14.20%

LO.O
LO.O
R3.0
R3.0

6. 00
5.10
12.90
5.10

9.50% R2.0

7.80

3,946
15,909,248

PAGE 337.2

Next Page is 340

 <

Page 336 Line 2 Column b

>

Includes $60,338,330 of additional amortization on steam
production facilities.

<

Page 336 Line 3 Column b

>

Includes nuclear decommissioning expense of $84,652,456 and
$79,180,163 of additional nuclear amortization.

<

Page 337 Line 28 Column b

>

3-Year Amortizable property.

<

Page 337 Line 29 Column b

>

5-Year amortizable property.

<

Page 337 Line 30 Column b

>

7-Year Amortizable property.

<

Page 337 Line 35 Column b

>

3-Year Amortizable property.

<

Page 337 Line 36 Column b

>

5-Year Amortizable property.

<

Page 337 Line 37 Column b >

7-Year Amortizable property.

<

Page 337 Line 47 Column b

>

3-Year Amortizable property.

Page 336-337 Footnote.1

 <

Page 337 Line 48 Column b

>

5-Year Amortizable property.

<

Page 337 Line 49 Column b

>

7-Year Amortizable property.

<

Page 337.1 Line 25 Column b

>

Capital Recovery of Load Management System (LMS) equipment
is through the ECCR clause.

<

Page 337.1 Line 32 Column b

>

Account represents Cable Injection investment amortized
over 10 years.

<

Page 337.1 Line 33 Column b

>

Account represents Cable Injection investment amortized
over 10 years.

<

Page 337.1 Line 38 Column b

>

Capital recovery of Load Management System (LMS) equipment
is through the ECCR clause.

<

Page 337.1 Line 40 Column b

>

Capital recovery of Load Management System (LMS) equipment
is through the ECCR clause.

<

Page 337.1 Line 44 Column b

FPL Only.

<

>

Excludes Leaseholds.

Page 337.1 Line 45 Column b

>

Land Resources Investment Company (LRIC) .
Page 336-337 Footnote.2

 <

Page 337.1 Line 46 Column b

>

7-Year Amortizable property.

<

Page 337.1 Line 47 Column b

>

5-Year Amortizable property.

<

Page 337.1 Line 48 Column b

>

7-Year Amortizable property.

<

Page 337.1 Line 49 Column b

>

7-Year Amortizable property.

<

Page 337.1 Line 50 Column b

>

5-Year Amortizable property.

<

Page 337.2 Line 12 Column b

>

Capital recovery of Load Management System (LMS) equipment
is through the ECCR clause.

<

Page 337.2 Line 13 Column b

>

Capital recovery of Load Management System (LMS) equipment
is through the ECCR clause.

<

Page 337.2 Line 14 Column b

>

Capital recovery of Load Management System (LMS) equipment
is through the ECCR clause.

<

Page 337.2 Line 15 Column b >

3-Year Amortizable property.
Page 3 36 -337 Footnote.3

 <

Page 337.2 Line 16 Column b

>

Fixed Wing (Non-Jet) Aircraft.

<

Page 337.2 Line 22 Column b

>

5-Year Amortizable property.

<

Page 337.2 Line 25 Column b

>

7-Year Amortizable property.

<

Page 337.2 Line 26 Column b

>

7-Year Amortizable property.

<

Page 337.2 Line 28 Column b

>

7-Year Amortizable property.

<

Page 337.2 Line 30 Column b

>

7-Year Amortizable property.

<

Page 337.2 Line 31 Column b

>

Capital recovery of Load Management System (LMS) equipment
is through the ECCR clause.

<

Page 337.2 Line 32 Column b

>

Capital recovery is through an Energy Conservation Cost
Recovery (ECCR) clause.

<

Page 337.2 Line 37 Column b

>

Capital recovery of Load Management System (LMS) equipment
is through the ECCR clause.
Page 336-337 Footnote.4

 <

Page 337.2 Line 38 Column b

>

Capital recovery of Load Management System (LMS) equipment
is through the ECCR clause.

<

Page 337.2 Line 40 Column b

>

7-Year Amortizable property.

<

Page 337.2 Line 41 Column b

>

Capital recovery of Load Management System (LMS) equipment
is through the ECCR clause.

<

Page 337.2 Line 44 Column b

>

Leaseholds are amortized over the life of each lease agreement.

<

Page 337.2 Line 48 Column a

>

The Florida Public Service Commission has approved amortization
of FPL's nuclear units of $30 million per year plus an
additional amount based on the level of sales achieved for
years 1995 through 1997 to be applied to reserve deficiencies
that exist in nuclear production and steam production
facilities.
As a result, nuclear depreciation expense for
1996 includes $79,180,163 of additional nuclear amortization
and $60,338,330 of additional amortization on steam production.

Page 336-337 Footnote.5

 N9me of Respondent
Florida Power & L1ght Company

Date of Report
Year of Report
(Mo, Da, Yt")
(2) [ A Resucmission
Dec. 31, 1996
PARTICULARS CONCERNING CERTAIN INCOME DEDUCTIONS AND INTEREST CHARGES ACCOUNTS
RepQrt the information_specified below, in tbe order
Accounts. Amounts 9f Less thijn 5% of . each account total
given, tor the respect1ve 1ncome deduct1on and 1nterest
for the year (or $1,000, wh1chever 1s greater) may be
charges accounts. Provide a subheading for each account
grouped by classes within the above accounts.
and a total for the account. Additional columns may be
(c) Interest on Debt to Associated Companies (Account
added if deemed appropriate with respect to any account.
430) -- For each associated company to which interest on
(a) Miscellaneous Amortization (Account 425) -- Desdebt was incurred during the year, indicate the amount
cribe the nature of items included in this account, the
and interest rate respectively for (a) advances on notes,
contra account charged, the total of amortization charges
(b) advances
on
open account, (c) notes payable,(d)
for the year, and the period of amortization.
accounts payable, and (e) other debt, and total interest.
(b) Miscellaneous
Income Deductions -- Report the
Explain the nature of other debt on which interest was
nature, payee, and amount of other income deductions for
incurred during the year.
(d) Other Interest
Expense (Account 431) -- Report
the year as required by Accounts 426.1, Donations; 426.2,
particulars (details) including the amount and interest
Life Insurance; 426.3, Penalties; 426.4, Expenditures for
rate for other interest charges incurred during the year.
Certain
Civic, Political and Related Activities; and
426.5, Other Deduct1ons, of
the Un1form
System
of
Item
Line
Amount
(b)
(a)
No.
3

I

I~isr~elp~~to~T~inal

(a) Miscellaneous Amortization- Account 425

I

I

0

4
5

6

7
8
9

(b) Miscellaneous Income Deductions:
Donations- Account 426.1
FPL Group Foundation, Inc.
Miscellaneous

10
11
12
13

14
15
16
17
18
19
20
21
22
23
24
25
26

1

27
28
29
30
31
32
33
34
35
36
37
38
39

2,430,000
327,011
2, 757,011

TOTAL -426.1
Life Insurance - Account 426.2

0

Penalties - Account 426.3
Nuclear Regulatory Commission

400,000

TOTAL-426.3

400,000

Expenditures for Certain Civic, Political and
Related Activities - Account 426.4
Salary and expenses of FPL employees in
connection with legislative matters
Lobbying Expenses
Edison Electric Institute Dues
Nuclear Energy Institute Dues
Miscellaneous

100,342
1,512,390
222,101
136,277

82,841
2,053,951

TOTAL-426.4
Other Deductions - Account 426.5
Legislative and Political Counsel
Miscellaneous

83,855
512,796
596,651

TOTAL-426.5

(c) Interest on Debt to Associated Companies Account 430

0

d9
FERC FORM NO.1 (ED. 12-87)

PAGE 340

Next Page 1s 350

 of Respondent
Florida Power & L1ght Company

Date of Report
(Mo, Da, Y'r)

N~me

I

I

Year of Report
Dec. 31, 1996

PARTICULARS CONCERNING CERTAIN INCOME DEDUCTIONS AND INTEREST CHARGES ACCOUNTS
Accounts. Amounts of less th~n 5% of _each account total
Report the information_specified be~ow, in tbe order
for the year (or $1,000, whichever IS greater) may be
given, tor the respective Income deduction and Interest
grouped by classes within the above accounts.
charges accounts. Provide a subheading for each account
(c) Interest on Debt to Associated Companies (Account
and a total for the account. Additional columns may be
430) -- For each associated company to which interest on
added if deemed appropriate with respect to any account.
debt was incurred during the year, indicate the amount
(a) Miscellaneous Amortization (Account 425) -- Desand interest rate respectively for (a) advances on notes,
cribe the nature of items included in this account, the
(b) advances
on
open account, (c) notes payable,(d)
contra account charged, the total of amortization charges
for the yea~, and the period of amortization.
accounts payable, and (e) other debt, and total interest.
(b) Miscellaneous
Income Deductions -- Report the
Explain the nature of other debt on which interest was
nature, pay e~ , and amount of other income deductions for
incurred during the year.
(d) Other Interest
Expense (Account 431) -- Report
the year as required by Accounts 426.1, Donations; 426-2,
particulars (details) including the amount and interest
Life Insurance; 426.3, Penalties; 426.4, Expenditures for
Certain
Civic, Political and Related Activities; and
rate for other interest charges incurred during the year.
4Z6.5, Other Deductions, of
the Un1form System of
Line
Item
Amount
No.
(a)
(b)
3 (d) Other Interest Expense - Account 431
Customer Deposits
4 *
5
Commercial Paper (Various Rates)
6
Wholesale Rate Refund (Various Rates)
7
Compensating Balances (Various Rates)
8
Misce l aneous (Various Rates)

14,700,494
2,332,386
489,836
205,876
197,881

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

·ER:::

TOTAL-431

~1 RM

N0 .1 (EC. 12 -87)

17,926,473

PAGE 340 .1

Next Page 1s 350

 <

Page 340.1 Line 4 Column a

>

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 7% per annum. All other customers
with cash deposits receive interest at the simple rate of 6% per
annum.

Page 340 Footnote.l

 of Respondent
Florida Power & L1ght Company

N~me

This Report Is: .
(1) (Xl An Or1g1nal
(2) ( A ResuDrl1ission
REGULATORY COMMISSION EXPENSES

Description
(Furnish name of regulatory commission or bQdy
the docket or case number, and a descr1pt1on
of the case.)
(a)

1
2
3
4
5
6
7

Date of Report
(Mo, Da, Yr)

I

1. Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous
years, if being amortized) relating to formal cases before a
regulatory body, or cases in which such a body was a party.
Line
No.

I

I

Year of Report
Dec. 31, 1996

2. Report in columns (b) and (c), only the current year's
expenses that are not deferred and the current year's
amortization of amounts deferred in previous years.

Asses$ed by
Regu~atQry
Comm1ss1on
(b)

Expetses
ut? ity

Total
Ex~enses for
Cu rent Year
( ) + (c)

(c)

(d)

.Deferred
1n Ac3ount
182, ;;It
Be~1 nmng
o year
(e)

Before the Florida Public Service Commission:
Review of Cogeneration Rules 25-17.080 25-17.091 for Possible Amendment to Ensure
Consistency with "Bidding" Rule 25-22.082,
F.A.C. - Dkt 931186-EC

8 Petition to Resolve Territorial Dispute with
9
Florida Power & Light in St. Johns County
- Dkt 950307-EU
10
11
12
Petition to Establish an Amortization Schedule
13
for Florida Power & light Company's Nuclear
14
Generating Units to Address the Potential for
15
Stranded Investment - Dkt 950359-EI
16
17 Proposed Revisions to Rule 25-6.D141, F.A.C.,
18 Allowance for Funds Used During Construction 19 Dkt 951535-EI
20
21
Fuel and Purchased Power Cost Recovery Clause
22
and Generating Performance Factors 23
Dkt 960001-EI
24
25
Petition of Florida Power & Light Company for
26 Approval of Agreement to Buy Out the Cypress
27 Energy Standard Offer Contract - Dkt 960182-EQ
28
29
Petition to Further Extend BuildSmart Pilot
30
Program by FPL - Dkts 951536, 951537,
31
960255-EQ
32
33
Lee County Self Service ~heeling - Undocketed
34
35
Electric Prepayment Tariffs - Undocketed
36
37
Investigation into the Relationship Between
FPL and FPL Energy Services, Inc . - Undocketed
38
39
40
Development of an FPSC Complaint System 41
Undocketed
42
43
44
45
46
TOTAL
FERC FORM N0.1 (ED. 12-96)

27,699

27,699

65,697

65,697

151,288

151,288

0

0

41,819

41,819

116,054

116,054
0

56,211

56,211
0

116,257

116,257

68,788

68,788

26,056

26,056

0
0

67,710

0
67,710

33,875

33,875
0

0
Page 350

 Year of Report
Dec. 31, 1996

of Respondent
Flor i da Power & L1ght Company

N~me

REGULATORY COMMISSION EXPENSES (Continued)
4. List in column (f), (g), and (h) expenses i ncur r ed dur i ng
3. Show in column (k) any expens es incurred in prior year s
year which were charged currently to i ncome, p l ant , or oth er
which are being amort i zed . Li st in column (a) the period of
accounts.
amortizat i on.
5. Minor items (less than $25,000) may be grouped.
EXPENSES INCURRED DURING YEAR
CHARGED CURRENTLY TO
Amount
Account
Department
No.
(g)

(f)

(h)

AMORT I ZED DURING YEAR
Deferred tQ
Account 182.3

Contra
Account

( i)

( j)

Amount
(k)

Deferred in
Account 182.3,
End of Year
( l)

Line
No.
1
2

3
4

5

Electric

928

6

27,699

7
8
9

Electric

928

10

65,697

11

Electric

928

151,288

Electric

928

41,819

Electric

928

116,054

Electric

928

56,211

Electric

928

116,257

Electric

928

68,788

Electric

928

26,D56

Electric

928

67,710

El ectric

928

33,875

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 N0.1 (ED. 12 -96)

Page 351

45

:..~..-_ _ _ _ _ _ _ _J..__ _ _ _ _ _ _ ____l_.:......J

46

 N9me of Respondent
Florida Po~er & L1ght Company

I

Iq~sf~elp~~to~~~inal
(2)
A Resubmission

Date of Report
(Mo, Da , Yr )

I

REGULATORY COMMISSION EXPENSES
1. Report particulars (details) of regulatory commission ex penses incurred during the current year (or incurred in previous
years , if being amortized) relating to formal cases before a
regulatory body, or cases in ~hich such a body ~as a party .
Line
No .

Description
(Furnish name of regulatory commission or body
the docket or ca~e number, and a descr1pt1on
ot the case.)
(a)

1
2
3
4
5

I

Year of Report
Dec. 31, 1996

2. Report in columns (b) and (c), only the current year' s
expenses that are not deferred and the current yea r's
amortization of amounts deferred in previous years .

Assesfed by
Regu atory
Comm1ss1on

Expefses
ut? ity

(b)

(C)

Total
Ex~enses for
Cu rent Year
(b) + (C)
(d)

Deferred
in Ac§ount
182, i;lt
Be~1 nmng
o year
(e)

Before the Federal Energy Regulatory Comm:
Wholesale Rate Case - Restructure Wholesale
Rates and Transmission Tariff s Dkt ER93-465-00

418,020

418,020

FMPA Wheeling Complaint - DKT EL93-51/TX93-4

76,142

76,142

Promoting Wholesale Competition through Open
Access Non-Discriminatory Transmission
Services by Public Utilities. Recovery
of Stranded Costs/Realtime Information
Net~orks - Dkts 94-7/95-8/95-9

296,665

296,665

Various FPSC Dockets
Various FERC Dockets

317,752
70,699

317,752
70,699

$1,950,732

$1,950,732

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
TOTAL
46
FE RC FORM N0-1 CEO. 12-96)

0

Page 350.1

0

 Name of Respondent
Florida Power & L1ght Company

I

I

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31 , 1996

REGULATORY COMMISSION EXPENSES (Continued)
4. List i n column (f), (g), and (h) expenses incurred during
3. Show in column (k) any expenses incurred in pr i or years
year which were charged currently to income, plant, or other
which are being amortized. List in column (a) the period of
accounts.
amortization.
5. Minor items (less than $25,000) may be grouped.
EXPENSES INCURRED DURING YEAR
CHARGED CURRENTLY TO
Department
Account
Amount
No.
(f)

(g)

(h)

AMORTIZED DURING YEAR
Deferred tQ
Account 182.5

Contra
Account

( i)

(j)

Deferred in
Account 182.3,
End of Year

Amount
(k)

( l)

Line
No.
1

2
3

Electric

928

418,020

Electric

928

76,142

4
5
6
7
8
9

10
11

Electric

928

296,665

Electric
Electric

928
928

317,752
70,699

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

$1,950,732
FERC FORM N0. 1 (E D. 12-96)

0

Page 351. 1

0

0

45
46

 of Respondent
Florida Power & L1ght Company

N~me

Date of Report
Da, Yr)

(Mo,
I
I
DEVELOPMENT, AND DEMONSTRATION ACTIVITIES

RESEARCH,
1. Describe and show below costs i ncurred and account s
charged during the year for technological research, develop·
ment, 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 car ried 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
11. Other hydroelectr1c
Line
No.

I

Year of Report
Dec. 31, 1996

b. Fossil-fuel steam
c. Internal combustion or gas turbine
d. Nuclea r
e. Unconventional generation
f. Siting and heat rejection
(2) System Planning, Engineering and Operation
(3) Transmission
a. Overhead
b. Underground
(4) Distribution
(5) Environment (other than equipment)
(6) Other (Classify and include items in excess of $5,000.)
(7) Total Cost Incurred
B. Electric, R, D & D Performed Externally
(1) Research Support to tbe Electrical Research
Counc1L or the Electr1c Power Research Institute

Classification

Description

(a)

(b)

3

A( 1 )c

4

A( 1 )d

5

11

A(1)e
A(3)a
A(3)a
A(3)b
A(4)
A(4)
A(4)

12

A( 5)

FOSSIL STEAM GENERATION:PLANT OPERATIONS IMPROVEMENT PROJECTS
FOSSIL STEAM GENERATION:REDUCTION AND CONTROL OF PLANT EMISSIONS PROJECTS
GAS TURBINE GENERATION:PLANT OPERATIONS IMPROVEMENT PROJECTS
NUCLEAR GENERATION:PLANT DESIGN AND OPERATIONS IMPROVEMENT PROJECTS
OTHER GENERATION:PHOTOVOLTAIC GRID COMPATIBILITY PROJECT
OVERHEAD TRANSMISSION:SYSTEM RELIABILITY PROJECTS
OVERHEAD TRANSMISSION:STSTEM MONITORING PROJECT
UNDERGROUND TRANSMISSION:SYSTEM RELIABILITY PROJECTS
DISTRIBUTION:SYSTEM RELIABILITY PROJECTS
DISTRIBUTION:SYSTEM MONITORING PROJECT
DISTRIBUTION:PHOTOVOLTAIC GRID COMPATIBILITY PROJECT
ENVIRONMENTAL:EMISSIONS MEASUREMENT, REDUCTION AND CONTROL PROJECTS

A(6)
A(6)

OTHER:ELECTRIC VEHICLE PROJECT
OTHER:COMMERCIAL AND INDUSTRIAL END-USE PROJECTS

B(1)

ELECTRIC POWER RESEARCH INSTITUTE REIMBURSEMENT
FROM PRIOR YEARS' MEMBERSHIP
DEPARTMENT OF ENERGY-EDISON ELECTRIC INSTITUTE COFUNDING OF INDUSTRY
ISSUES
DEPARTMENT OF DEFENSE-ADVANCED RESEARCH PROJECTS AGENCY ELECTRIC
VEHICLE RESEARCH
GERALD L. GUNTER ENDOWMENT
PUBLIC UTILITY RESEARCH CENTER SUPPORT

1

A(1)b

2

A( 1 )b

6
7
8
9
10

13
14

15
16
17
18
19
20
21
22

23
24
25
26
27
28
29
30
31
32

B(2)
B(4)

B(4)
B(4)

33

34
35
36
TOTAL
FERC FORM N0.1 (ED. 12·87)

Page 352

 Year of Report
Date of Report
T~h~,~-stRxelpAort
I$:. l
(Mo, Da, Yr)
n 0 r1g1na
Dec. 31, 1996
A Resuemission
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES (Continued)
with expenses during the year or the account to which
(2) Research Support to Edison Electric
amounts
were capitalized during the year, listing Account
Institute
107, Construction ~ork in Progress, first. Show in col(3) Research Support to Nuclear Power
umn (f) the amounts related to the account charged in
Groups
column (e).
(4) Research Support to Others (Classify)
5. Show in column (g) the total unamortized ac(5) Total Cost Incurred
cumulation of costs of projects. This total must equal the
3. Include in column (c) all R, 0 & 0 items performed
balance in Account 188, Research, Development, and
internally and in column (d) those items performed
outside the company costing $5,000 or more, briefly
Demonstration Expenditures , Outstanding at the end of
describing the specific area of R, 0 & 0 (such as
the year.
safety, corrosion control, pollution, automation, measure6. If costs have not been segregated for R, 0 & 0
activities or projects, submit estimates for columns
ment, insulation, type of appliance, etc.). Group items
(c), (d), and (f) with such amounts identified by
under $5,000 by classifications and indicate the number
of items grouped. Under Other, (A.(6) and 8.(4)) classify
"Est."
7, ~eport se~arately research aad related testing
itzms ~y ty~e ol R, 0 & 0 activity.
. S ow 1 co umn (e) the account number charged
fac1l1t1es ope ated by the respon ent.
AMOUNTS CHARGED IN CURRENT YEAR
Costs Incurred Internally Costs Incurred Externally
Line
Unamorfized
Current Year
Current Year
Account
Accumu at1on
No.
Amo~nt
(C)
(d)
( )
(e)
(g)
$701,603
506
$701,603
1
9,384
506
9,384
2
305,272
549
305,272
3
488,931
524
488,931
4
342
549
342
5
183,549
566
183,549
6
1,251
930.2
7
1 '251
92,080
566
92,080
8
161,504
588
161,504
9
50,000
588
10
50,000
60
588
60
11
815,899
506
203,338
12
930.2
612,561
13
588
14
115' 101
115' 101
8,474
930.2
8,474
15
16
of Respondent
Florida Power & L1ght Company

N~me

r-

J

I

I

17

(606,395)

r-

86,756

2,933,450
FER C FORM N0.1 (EO. 12-87)

18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36

(606,395)

930.2

86,756

566

400,000

930.2

400,000

8,000
45,100

930.2
930.2

8,000
45,100

2,866 ,911

(66, 539 )
Page 353

0

~~

 of Respondent
Florida Power & L1ght Company

N~me

Date of Report
(Mo, Da, Yt)

Report below the distribution of total salaries and wages
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.

Classification

Total

(a)

FERC FORM NO.1 (ED. 12-88)

Year of Report
Dec. 31, 1996

Page 354

 of Respondent
Power & L1ght Company

N 9 ~n
F l u~ i da

,....

Line
No.

of Report
Da, Yr)

Year of Report
Dec. 31, 1996

Classification

Total

....

r

75
76
77

Other Accounts (Specify):
Accounts Receivable - various (143)

955,603

0

955,603

Accounts Receivable from Associated Companies (146)

332,131

934,538

1,266,669

Temporary Facilities (185)

889,340

49,329

938,669

(164,957)

73,631

(91,326)

78
79

r

r-

r-

8o
81
82
83
84
85
86
87
88
89
90
91
92
93
94

Various

FERC FORM N0. 1 (ED. 12-88)

0
0
D

0

Page 355

 Year of Report
Date of Report
This Report I$: .
(Mo, Da, Yr)
(1) [XJ An Or1g1nal
Dec. 31, 1996
(2) [ A ResuExnission
STEAM-ELECTRIC GENERATING PLANT STATISTICS (large Plants)
assignable to each plant.
.
1 Report data for plant in Service only.
.
6. If gas 1s used and purchased on a therm bijs1s,report the
Large ~lants are stea~ ~lants w1th 1nstalled capac1ty
Btu content of the gas and the quant1ty of tuel burned
<~erne
late rat1ng) ot z5,0VO Kw or more. Repo[t on
converted to Mc;f.
.
t 1~
ege gas-turbine ana 1nternal combustion p ants
7. Quentit1es of fuel bu[oed <g1ne 37) and averege cost per
o ]0, 00 Kw or more and nuclear plants.
un1t of fuel burned ( 1ne 4 ) must be cons1$tent w1th
3. Ind1cate by _ ~_footnofe any plant leased or operated as
gha[~~~ fg_expense acco~nts 01 a~d 547 (l1ne 41) as show
a J01nt fac1l1tx.
.
.
4. If net pea~ aemand tor 60 minutes . 1s not .ava1 lable,
8. I~ more then one fuel 1S burned 1n a plant, furnish only
1ve data wh1ch 1s ava1lable, spec1ty1ng per1od.
the compos1te heat rate for all fuels burnea.
5. t any employees attend more than one plaht 1 report on
1ne 11 the approx1mate average number or employees

of Respondent
Florida Power & L1ght Company

N~me

I

I

2:

T

Item

Line
No.

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

Kind of Plant (Steam, Internal Combustion, Gas
Turbine or Nuc[ear)
Ty~:>e of Plant Construction(Conventional, Outdoor
so·1 ler, Full Outdoor, Etc.)
Year Originally Constructed
Year Last Unit was Installed
Total {nstalled . Capacjty (Maximum Generator
Name P ate Rat1ngs 1n MW)
Net Peak Demand on Plant -- MW (60 minutes)
Plant Hours Connected to Load
Net Continuous Plant Capability (Megawatts)
When Not Limited by Condenser Water
When Limited by Condenser Water
Average Number of Employees
Net Generation,Exclusive of Plant Use --KWh
Cost of Plant: Land and Land Rights
Structures and Improvements
Equipment Costs
Total Cost
Cost per KW of Installed Capacity (line 5)
Production Expenses: Oper. Supv. & Engr.
Fuel
Coolants and Water (Nuclear Plants Only)
Steam Expenses
Steam From Other Sources
Steam Transferred (Cr.)
Electric Expenses
Misc. Steam (or Nuclear) Power Expenses
Rents
Allowances
Maintenance Supervision and Engineering
Maintenance of Structures
Maintenance of Boiler (Or Reactor) Plant
Maintenance of Electric Plant
Maintenance Misc. Steam (or Nuclear) Plant
Total Production Expenses
Expenses per Net KWh
Fuel: Kind (Coal,Gas,Oil,or Nuclear)
Uoit~ (Coal-tons of 2(000 lb.) (Oil-barrels
of 4~ gals.) (Gas-Mcf,(Nuclear-1nd1cate)
Quantity (Units) of Fuel Burned
Avg[ Heat Cont. of . Fuel Burned CBty per lb. of
coe per_ga~, of 01 l, or per Mcf of gas)
(G1ve un1t 1r nuclear)
Average Cost of Fuel per Unit, as Delivered
f.o.b. Plant During Year
Average Cost of Fuel per Unit Burned
Avg. Cost of Fuel Burned per Million Btu
Avg. Cost of Fuel Burned per KWh Net Gen
Average Btu per KWh Net Generation

FERC FORM NO. 1 (REV. 12-95)

Plant Name: Cutler

Plant Name: CaP.e Canaveral

(c)

(b)

(a)

Steam

Steam

Full Outdoor

Full Outdoor
1965
1969

1948
1971

804.10
873
8,071

236.50

800
794
86
3,312,902,000
804,071
13,531,668
140,611,070
$154,946,809
192.6959
818,773
97,413,091

217
215
19
205,121,000
71,255
7,102,264
38,882,240
$46,055,759
194.7389
101,341
7,934,736

217

646

0

0

9,125

210,293

0

0

0

0

0

2,913,846

356,530
496,027

0

0

0

0

604,031
99,981
1,261,098
763,408
563,082
$104,446,435
$0.0315
Gas
Oil

94,220
22,983
620,243
117,758
82,584
$10,036,715
$0.0489
Gas

Mcf
Barrels
14,731,302
2,862,371

Page 402

-

-

Mcf
2,669,254

1,000,000

151 '167

1,000,000

$3.07Q
$3.070
$3.070

$17.500
$17.500
$2.756
$0.029
9,931.000

$2 . 980
$2.980
$2.980
$0.039
13,013.000

 This Report Is:
Year of Report
Date of Re~ort
(Mo, Da, Y )
~1~ fXl A
An Resu
Or1~nal
ission
Dec. 31, 1996
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued)
9. lte~s under Cost of Plant are ?ased on ~.S. of A.accounts.
-tu~bine unit
funttions in ~ combined c~cle operation
WJt a conventiona steam un1t,1nc ude t e gas- turb1ne
Pro ucrion expe~ses do not inc ~de hurc ased Power, Sy~te~
Contro and Loa D1fyatch1ng,an Ot er Expenses c ass1 1e
w}t the fteam plant.
12. I ~ nuc ear ~ower generatin~ plan1, briefly exgtain
as Other Power !u~~
Expenses.
10. For I~ ~nd ~T ~ ~ s, repor~ Oper!ting_Expenses, Account
by ootnote <f
account1ng me hod
or co5t of
ower
generated 1~c u?ing any excess co~ts attr1 uted to reNos. 4 an
on l 1~5
4
ectr/c; Ex~ynses," and
Ma 1nte~ante Acc;ounf Nos. 3 ~nd 5 on 1~e
"~a i ntensearch ~nd eve o~ent;(~)1ypts o cost un1ts used for
th var1ous compo ents o ue cost; an ( ) anY, o he
fnce o E ectr1c P ant." Ind1cate Plfnts esig8ed or peak
1n1or~at1ve data concern10~ pant type,~uet useQ, lue[
oad syrv1ce. Qes1~nate auto~~t1c~ y o~erate p~ants.
11. For a~ ant e~u1~Ye w1tb com 1nat1onf o . foss1l uel ste~m,
enh1c ment.ty~e a~d quant1 y or the report per1o?,and
stea ,
dro, 1nternal com ust1on or gas:lurb1ne
ot er phys1ca an operat1ng character1st1cs of p ant.
nuclea
equ1pment,report each as a separate pant. However,1 a gas
Plant Name: Fort Myers
Plant Name: Fort Myers
Plant Name: La~derdale
Line
(d)
( )
(e)
No.
1
Steam
Gas Turbines
Combined Cycle
2
Full Outdoor
Conventional
Conventional
1958
1974
1926
3
1969
1974
1993
4
5
558.30
744.00
1,042.50
554
672
908
6
6,388
505
7,650
7
8
9D4
536
636
9
532
564
860
10
85
91
11
*
1 ,594, 781,000
14,065,000
12
6,521,391,000
$1,466,348
$499,879
0
13
15,588,149
3,648,581
79,152,637
14
65,464,606
15
54,588,355
440,037,242
$82,519,103
$58,236,936
$519,689,758
16
147.8042
17
78.2754
498.5033
775,107
18
60,787
1,944,040
43,466,467
1,143,448
159,926,190
19
0
0
0
20
330,124
21
0
0
0
0
0
22
0
23
0
0
444,867
663, 1D1
24
128,054
1, 715,594
25
0
0
0
0
26
0
0
0
0
27
682,489
103,938
613,316
28
8,357
74,631
512,258
29
0
11,360,102
0
30
157,215
2,347,332
31
2,392,153
32
0
0
962,021
$1,601,799
S165,568,61D
$62,641,182
33
$0.1138
$0.0253
34
SD.0392
Gas
35
Oil
Oil
36
Barrels
Mcf
Barrels
50,452,582 37
37,950
2,513,592

Nfme of Respon~ent
F orida Power
L1ght Company

I

I

"5

,....

FERC FORM NO. 1 (REV. 12-95)

151,738

138,786

1,000,000

$16.670
$16.670
$2.616
$0.027
10,032.000

$30.130
$30.130
$5.169
$0.081
15,754.000

$3.160
$3.160
$3.160
$0.025
7,736.000

Page 403

38
39
40
41
42
43

Next Page i s 406

 m

Year of Report
Date of Re~ort
This Report Is:.
(Mo, Da, Y )
fXl A
An Resu
Or15ri,nal
Dec. 31, 1996
ission
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)
Report rata for plant in Servic~ only.
a'signable to each clant.
.
~: Large~ ants ar~ steam ~5anOB w1th 1nstalled capacity
6. I gas 1s use~ and
urchased on a th~rm b~s1¥,rrport the
Btu content o ihe gas and the quant1ty o
ue
burned
<~erne
ate rat1ng6 of
,0
Kw ?r more. Repo[t on
convert~d to
Me .
.
t ,~
aBe gas-tur ine aga 1nterna combustion P ants
Kw or more an nuTlear plants.
7. Quentii11s ?f fuel bu[~ed i~1ne 37) ~nd averege cost peh
o 0,
3. Ind1cate by _f_footnofe any pant leased or operated as
u~1t o
ue
burned ( 1ne
must
Tons1ftent w1t
a JOlnt fac1 1tx.
c arges t~ expense accounts
1 and 5
( lne
) as show
4. If net pe~~ o~mand f?r ?O minute¥ . is not_available,
o? 1ne
.
8. I more t en o~e fuel i¥ burnfd in a glant, furnish only
1Ch lS ava1 abe, ~peel y1nf ~er10d.
rlVe data
the compos1te eat rate or al fuels urnea.
5. f an, em~ oyees attend more t an one g a tf rec?rt on
1ne 1 t e approx1mate average num er o em oyees

Nfme of Respon~ent
F or ida Power
L1ght Company

I

I

6

7

r

Line
Item
(a)
No.
1 Kind of Plant fSteam, Internal Combustion, Gas
Turbine or Nuc ear)
2 Typf of Plfnt cogstruction~Conventional, Outdoor
Bo1 er, Fu l Out oor, Etc.
3 Year Originally Constructed
4 Year Last Unit was Installed
5 Total [nstalled_Capacjty (Maximum Generator
Name P ate Rat1ngs 1n MW)
6 Net Peak Demand on Plant -- MW (60 minutes)
7 Plant Hours Connected to Load
Net Continuous Plant Capability (Megawatts)
8
When Not Limited by Condenser Water
9
10
When Limited by Condenser Water
11
Average Number of Employees
12
Net Generation,Exclusive of Plant Use --KWh
13
Cost of Plant: Land and Land Rights
14
Structures and Improvements
15
Equipment Costs
16
Total Cost
17 Cost per KW of Installed Capacity (line 5)
18 Production Expenses: Oper. Supv. & Engr.
19
Fuel
Coolants and Water (Nuclear Plants Only)
20
21
Steam Expenses
Steam From Other Sources
22
Steam Transferred (Cr.)
23
24
Electric Expenses
25
Misc. Steam (or Nuclear) Power Expenses
26
Rents
27
Allowances
Maintenance Supervision and Engineering
28
29
Maintenance of Structures
Maintenance of Boiler (Or Reactor) Plant
30
31
Maintenance of Electric Plant
32
Maintenance Misc. Steam (or Nuclear) Plant
Total Production Expenses
33
Expenses per Net KWh
34
Fuel: Kind (Coal,Gas,Oil,or Nuclear)
35
36
U~i!~ (C?al-tons of ~~000 fb.) (Oil-barrels
o
gas.) (Gas-Me (Nuc ear-lndlcate)
Quantity (Units) of Fuel Burned
37
38
Avg[ Heat c~nt. of . ruel Burned ~Bt¥ per lb. of
coe per.~a t of ?1 , or per Me o gas)
(Glve un1 1 nuc ear)
39
~vergge yost of fuel per Unit, as Delivered
.o •. P ant Dur1ng Year
Average Cost of Fuel per Unit Burned
40
Avg. Cost of Fuel Burned per Mill ion Btu
41
Avg. Cost of Fuel Burned per KWh Net Gen
42
Average Btu per KWh Net Generation
43
FERC FORM NO. 1 (REV. 12-95)

Plant Name: Lauderdale
(b)

Plant Name: Manatee
(c)

Gas Turbines

Steam

Conventional

Full Outdoor
1970
1972

1976
1977

821.50
783
1,901

1,726.60
1,694
7,406

792
720

1,610
1,596
97
3,089,568,000
5,718,886
91,923,045
293,294,336
$390,936,267
226.4197
1,123,580
90,813,186
0
849,949
0
0
849,947
2,391,460
0
0
153,714
1,539,965
3,347,953
1,641,465
1,289,850
$104,001,069
$0.0336
Oil

*
41,033,000
216,447
5,857,506
75,224.720
$81,298,673
98.9636
1,922
2,500,915
0
0
0
0
(714)
0
0
0
2,010
0
0
5,717
0
$2,509,850
$0.0611
Gas
Oil
Mcf

Page 402.1

621,060

Barrels
16,854

Barrels
5,128,831

1,000,000

135,595

151,881

$3.270
$3.270
$3.270

$27.890
$27.890
$4.897
$0.061
17,475.000

$17.610
$17.610
$2.761
$0.029
10,572.000

 This Report Is:.
Year of Report
Date of Re~ort
(Mo, Da, Y )
~~~ fXJ A
An Resu
Or1~nal
ission
Dec. 31, 1996
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued)
9. Ite~s under Cost of Plant are ~ased on U.S. of A.accounts.
-tu~bine unit
funytions in e combined c~cle operation
WJt a conventiona steam un1t,1nc ude t e gas-turb1ne
Pro uction expe~se$ do not inc ~de hurchased Powe[, Sy1te~
Centro and Loa D1f~atch1ng,an Ot er Expenses c ass1 1e
w1t the fteam plant.
12. If ~ nuc ear ~ower generatin~ plan~, briefly ex~lain
as Other Power !u~~
Expenses.
10. For I§ ~nd ~T ~ ~ s, repor~ Oper!ting_Expenses, Account
by ootnote <r
account1ng me hod
or cost of
ower
gener~ted 1~c u?ing any excess co1ts attr1buted to reNos. 4 an
on l1 ~5
4
ect r /';: Ex~ynses," and
Ma 1nte~anye Account Nos. 3 end 5 on 1~e
"~a i ntensearc end eve o~ent;(~)~YPfS o cost un1ts used for
fnce o E ectr1c Plant." Ind1cate Plfnts esigged or peak
th~ var1ous compo ents o
ue cost; and <y> anx o~he[
1n or~at1ve data concern10~ p~ant type,fue useQ, ue
cad sfrv1ce. Qes1~nate auto~et1ce y o~erate p~anfs.
11. For a~ ant e~u1~~e w1tb com 1nat1on~ o .foss1l ue steem,
enh1c ment _ ty~e a~d quant1 y or the report per1o?,and
nuclea
stea ,
dro, 1nternal com ust1on or gas:~urb1ne
ot er phys1ca an operat1ng character1st1cs of p ant.
equ1pment,report each as a separate pant. However,1 a gas
Plant Name: Martin
Plant Name: Martin
Plant Name: Port Everglades
Line
(d)
(e)
(f)
No.
1
Steam
Combined Cycle
Steam
2
Full Outdoor
Conventional
Full Outdoor
1980
1993
1960
3
1981
1994
1965
4
5
1,726.60
1,224.00
1,254.60
1,648
1,016
6
1,209
5,840
8,656
6,016
7
8
1,626
920
1,202
9
1,596
10
860
1 '198
85
64
159
11
4,433,249,000
7,069,403,000
3,106,840,000
12
$9,486,668
$2,075,941
13
$305' 750
246,336,857
14
43,879,881
23,627,722
460,710,248
442,423,905
15
225,132,585
$716,533,773
$488,379,727
$249,066,057
16
414.9969
399.0030
198.5222
17
826,697
586,387
1,036,209
18
136,056,217
164,392,014
95,080,805
19
0
0
0
20
386,988
0
2,045,932
21
0
0
22
0
0
0
23
0
357,708
2,340,164
0
24
1, 780,251
0
3,906,312
25
0
0
26
0
0
0
0
27
292,571
216,441
28
297,119
1,166,003
145,950
1,692,266
29
0
2,755,124
5,287,318
30
2,025,111
1,618,275
4,040,183
31
0
1, 765,142
858,592
32
$148,630,620
$171,721,139
$110,604,020
33
$0.0242
$0.0356
$0.0335
34
Gas
Oil
Oil
Gas
35
Gas
36
Mcf
Mcf
Barrels
Mcf
Barrels
51,088,509
15,526,665
24,292,430
3,379,994
2, 768,121 37

Nfme of Respongent
F orida Power
L1ght Company

I

I

"5

,......

1,000,000

151,786

1,000,000

1,000,000

152,476

$3.030
$3.030
$3.030

$18.290
$18.290
$2.869
$0.031
10,334.000

$3.200
$3.200
$3.200
$0.023
7,227.000

$2.890
$2.890
$2.890

$18.050
$18.050
$2.819
$0.031
10,704.000

FERC FORM NO. 1 (REV. 12-95)

Page 403.1

38
39
40
41
42
43

Next Page is 406

 m

Year of Report
Date of Re~ort
This Report 1&: .
(Mo, Da, Y )
fXl A
An Resu
Or1~nal
Dec. 31, 1996
ission
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)
a~signable to each ~lant.
Re~ort ?ata for plant in Service only.
6. I gas 1s used and
urchased on a therm b~si~,rfport the
La ge ~ants are steam ~~anOB w1th 1nstalled capacity
Btu content of ~he gas and the quant1ty o
ue
burned
(~arne
late rat1ng6 of
,0
Kw ?r more. Repo[t on
converted
to
Me
.
aBe gas-tur ine a~a 1nferna combustion pants
t 1~
7. auantii1~s ?f fuel bu[oed 4~ine 37) and average cost per
o o,
Kw or more an nuT ear plands.
3. Ind1cate by_f_footnote any pant lease or operated as
u~1t o
ue
burned ( 1ne
must
Tons1~fent w1th
a J01nt fac1 ltY..
c arges f~ expense accounts
1 and 5
( 1ne
) as show
4. If net pea~ aemand f?r ?D minute~ . is not.available,
o~
1ne
.
8. I more t an o~e fuel i~ burnrd in a gtant, furnish only
f1ve data ~h1ch 1s ava1 ab e, spec1 y1n~ ~er1od.
the compos1te eat rate or at fuels urnea.
5. f an1 em~ oyees attend more than one g a t~ re~?rt on
1ne 1 t e approx1mate average num er o em oyees

Nfme of Respon~ent
L1ght Company
F orida Power

I

I

I

1:

d

Item
Line
(a)
No.
1 Kind of Plant {Steam, Internal Combustion, Gas
Turbine or Nuc ear)
2 Typr of Ptrnt co~struction(Conventional, Outdoor
Bo1 er, Fu l Out oar, Etc.)
Year Originally Constructed
3
Year Last Unit was Installed
4
5 Total [nstalled.Capacjty (Maximum Generator
Name P ate Rat1ngs 1n MW)
Net Peak Demand on Plant -- MW (60 minutes)
6
7
Plant Hours Connected to Load
8
Net Continuous Plant Capability (Megawatts)
9
When Not Limited by Condenser Water
10
When Limited by Condenser Water
11
Average Number of Employees
12
Net Generation,Exclusive of Plant Use --KWh
Cost of Plant: Land and Land Rights
13
14
Structures and Improvements
Equipment Costs
15
Total Cost
16
17
Cost per KW of Installed Capacity Cline 5)
18
Production Expenses: Oper. Supv. & Engr.
19
Fuel
Coolants and Water (Nuclear Plants Only)
20
21
Steam Expenses
Steam From Other Sources
22
Steam Transferred (Cr.)
23
Electric Expenses
24
Misc. Steam (or Nuclear) Power Expenses
25
Rents
26
Allowances
27
Maintenance Supervision and Engineering
28
29
Maintenance of Structures
30
Maintenance of Boiler (Or Reactor) Plant
31
Maintenance of Electric Plant
Maintenance Misc. Steam (or Nuclear) Plant
32
Total Production Expenses
33
34
Expenses per Net KWh
Fuel: Kind (Coal,Gas,Oil,or Nuclear)
35
36
U~i!~ (C?al-tons of ~~000 fb.) (Oil-barrels
o
gas.) (Gas-Me (Nuc ear·1nd1cate)
Quantity (Units) of Fuel Burned
37
38
Avg[ Heat c?nt. of . ruel Burned ~Bt¥ per lb. of
coa per . ~a ~of y1 , or per Me o gas)
(G1ve un1 1 nuc ear)
39
~vergge fast of Fuel per Unit, as Delivered
.o . . P ant During Year
Average Cost of Fuel per Unit Burned
40
Avg. Cost of Fuel Burned per Million Btu
41
Avg. Cost of Fuel Burned per KWh Net Gen
42
Average Btu per KWh Net Generation
43
FERC FORM NO. 1 (REV. 12-95)

Plant Name: Port Everglades
(b)

Plant Name: Putnam
(C)

Combined Cycle

Gas Turbines
Conventional

Full Outdoor
1971
1971

1977
1978

410.80
264
1,284

580.00
555
6,850

393
364

500
478
82
2,474,904,000
37,989
11,233,464
144,680,623
$155,952,076
268.8828
353,513
71,786,618
0
0
0
0
2,542,632
0
0
0
1,131,970
51,049
0
2,470,394
0
$78,336,176
$0.0316
Gas
Oil

*
29,467,000
0
3,608,668
40,221,670
$43,830,338
106.6950
1,005,632
1,873,754
0
0
0
0
1,424,849
0
0
0
440,987
231,204
0
3,377,870
0
$8,354,296
$0.2835
Gas
Oil
Mcf

Page 402.2

f7

Barrels

Mcf
Barrels
23,346,693

503,664

281

1,000,000

138,190

1,000,000

136,762

$3.300
$3.300
$3.300

$26.840
$26.840
$4.624
$0.064
17,148.000

$3.050
$3.050
$3.050

$40.060
$40.060
$6.974
$0.029
9,434.000

185

 .....

,.....

Year of Report
Date of Re~ort
This Report Is:
(Mo, Da, Y )
~~~ fXJ A
An Resu
Or1~nal
Dec. 31, 1996
ission
STEAM· ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued)
9. Ite~s under Cost of Plant are rased on U.S. of A.accounts.
-turbine unit funTtions in ~ combined c~cle operation
Wit~ a conventiona
steam un1t,1nclude t e gas-turblne
Pro uc[ion expe~ses do not inc ~de hurchased Power, Sy~te~
Contro and Loa D1fyatch1ng,an Ot er Expenses c ass1 1e
wft the fteam plant.
12 . I ~ nuc ear ~ower generatin~ planl' briefly exglain
Expenses.
as Other Power !u~~
10. For I~ gnd ~T ~
by ootnote <r
account1ng me hod
or cost of
ower
s, repor~ Oper!ting_Expenses, Account
generated 1~c u?ing any excess co~ts attr1buted to reNos. 4 an
on l1~5
4
ectrlr; Ex~lnses," and
search ~nd eve o~ent;(¥)lYPfS o cost un1ts used for
Ma1nte~anTe Acr;oun{ Nos.
3 ~nd 5
on 1~e
"~aintenfnce o E ectnc P ant." Ind1cate Plfnts esig8ed or peak
thl var1ous compo ents o ue cost; an1 <y> anY. olhel
1n or~at1ve data concern10~ P}ant type, ue useo, ue
oad sTrv1ce. Oesl~nate auto~~t1c~ y o~erate p}anfs.
11. For a~ ant e~u1~Ye w1tb com 1nat1o~ o .foss1 l ue ste~m,
enh1c ment.ty~e a~d quanti y or the report per1o?,and
nuclea
stea ,
dro, 1nternal co ust1on or gas:lurb1ne
ot er phys1ca an operat1ng character1st1cs of p ant.
equ1pment,report each as a separate pant. However,1 a gas
Line
Plant Name: Riviera
Plant Name: Sanford
Plant Name: * ~cherer Unit No. 4
( )
(d)
(e)
No.
1
Steam
Steam
Steam
2
Full Outdoor
Full Outdoor
Conventional
1953
1926
1989
3
1963
1973
1989
4
5
620.84
1,028.45
680.40
631
6
615
1,004
7,310
7
7,647
6,324
8
9
633
584
935
10
633
580
925
11
103
84
98
12
2,234,172,000
2,463,244,000
4,073,384,000
$4,274,718
$2,047,673
$2,490,853
13
14
8,944,981
32,853,947
94,010,068
81,477,168
119,445,003
473,147,862
15
$569,648,783
$94,696,867
$154,346,623
16
17
837.2263
152.5302
150.0769
991,241
454,072
1,498,254
18
19
70,583,615
60,851,066
76,808,561
0
20
0
0
870,141
21
334,784
92,230
22
0
0
0
0
23
0
0
24
418,767
57,198
537,554
1,286,154
2,802,942
1 ,596, 118
25
26
72
0
0
0
27
0
0
1,743,466
28
722,115
566,288
317,682
29
38,086
675,049
30
5,589,216
2,269,594
2,079,996
2,382,614
31
273,991
505,585
615,509
1,550,530
32
747,777
$85,734,169
$85,516,756
33
$68,009,342
$0.0210
$0.0347
34
$0.0304
Oil
Oil
Coal
35
Oil
Gas
Gas
36
Barrels
Barrels
Tons
Met
Barrels
Mcf
5,094
8,500,503
2,801,404
2,454,798 37
3,030,738
3,500,178

Nfme of Respongent
L1ght Company
F orida Power

e

I

I

"5

1,000,000

152,667

1,000,000

150,333

138,500

8,589

$3.020
$3.020
$3.020

$16.590
$16.590
$2.587
$0.027
10,265.000

$2.980
$2.980
$2.980

$16.840
$16.840
$2.667
$0.031
10,629.000

$29.210
$29.210
$5.578

$28.690
$28.690
$1.670
$0.017
10,103.000

FERC FORM NO. 1 (REV. 12-95)

Page 403.2

38
39
40
41
42
43

Next Page is 406

 m

Year of Report
This Report Is:.
Date of Report
(Mo, Da, Yr)
fXJ A
An Resu
Or15ri,nal
ission
Dec. 31, 1996
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)
Re~ort rata for plant in Servic~ only.
a~signable to
each ~lant.
6. I gas 1s use1 and
~: La ge ~ants ar~ steam ~~anOB w1th 1nstalled capacity
urchased on a th~rm b1si~,rlport the
Btu content o fhe gas and the quant1ty o
ue
burned
(~~me
ate rat1ng6 of
,0
Kw ?r more. Repo[t on
convert~d to M1 .
t 1l
BBe gas-tur ine age 1nferna combustion p ants
Kw or more an nuT ear plants.
7. Qu~ntifl~s ?f
o 0,
uel bu[Qed £~ine 37~ and aver~ge cost peh
3. Ind1cate bY.f . footnote any pant leased or operated as
u~1t o
ue
burned ( 1ne
O mus ~7 Tons1~fent w1t
a JOlnt fac1 1tx.
c arges f~ expense accounts
1 and 5
( lne
) as show
4. If net pe~~ a~mand f?r
minut~~ . is not_available,
o~
1ne
.
B. I more t ~n o~e fuel i~ burnld in a glant, furnish only
rlVe data t lCh lS ava1 abe, spec1 y1n~ ger1od.
the compos1te eat rate oral fuels urnea.
5. f an1 emg oyees attend more than one g a tf re~?rt on
1ne 1 t e approx1mate average num er o em oyees

Nfme of Respon~ent
L1ght Company
F orida Power

I

I

I

?O

Line
Item
(a)
No.
1 Kind of Plant fSteam, Internal Combustion, Gas
Turbine or Nuc ear)
2 Typl of Plfnt cogstruction(Conventional, Outdoor
Bo1 er, Fu l Out oor, Etc.)
3 Year Originally Constructed
4 Year Last Unit was Installed
5 Total lnstalled _Capacjty (Maximum Generator
Name P ate Rat1ngs 1n M~)
6 Net Peak Demand on Plant -- MW (60 minutes)
7 Plant Hours Connected to Load
Net Continuous Plant Capability (Megawa.tts)
8
9
When Not Limited by Condenser Water
10
When Limited by Condenser Water
11
Average Number of Employees
12
Net Generation,Exclusive of Plant Use --KWh
13
Cost of Plant: Land and Land Rights
14
Structures and Improvements
15
Equipment Costs
16
Total Cost
Cost per KW of Installed Capacity (line 5)
17
Production Expenses: Oper. Supv. & Engr.
18
19
Fuel
Coolants and Water (Nuclear Plants Only)
20
21
Steam Expenses
22
Steam From Other Sources
Steam Transferred (Cr.)
23
24
Electric Expenses
Misc. Steam (or Nuclear) Power Expenses
25
26
Rents
27
Allowances
Maintenance Supervision and Engineering
28
29
Maintenance of Structures
30
Maintenance of Boiler (Or Reactor) Plant
Maintenance of Electric Plant
31
Maintenance Misc. Steam (or Nuclear) Plant
32
Total Production Expenses
33
34
Expenses per Net KWh
Fuel: Kind (Coal,Gas,Oil,or Nuclear)
35
36
U~i!~ (C?al-tons of ~~000 [b.) (Oil-barrels
o
gas.) (Gas-Me (Nuc ear-1nd1cate)
Quantity (Units) of Fuel Burned
37
38
Avg[ Heat c~nt. of . ruel Burned ~Bt¥ per lb. of
co~
per_~a ~of?, , or per Me
o gas)
(G1ve un1 1 nuc ear)
39
~vergge Tost of fuel per Unit, as Delivered
.o •. P ant Dur1ng Year
Average Cost of Fuel per Unit Burned
40
Avg. Cost of Fuel Burned per Million Btu
41
Avg. Cost of Fuel Burned per KWh Net Gen
42
Average Btu per KWh Net Generation
43
FERC FORM NO. 1 (REV. 12-95)

Plant Name: * St. Johns River
(b)

Plant Name: * St. Lucie
(C)

* Nuclear

Steam
Outdoor Boiler

Conventional
1987
1988

1976
1983

271.84
257
5,066

1, 700.00
1,775
6,528

250
250
406
1 • 953. 528. 000
1, 546,128
52,835,179
274,846,637
$329,227,944
1, 211.1092
382,151
32,361,341
0
971,527
0
0
182,076
1 ,942,178
7,413
0
384,010
446,916
3,004,740
444,265
264.575
$40,391,192
$0.0206
Coal
Oil
Tons

Page 402.3

1,579
1,553
758
11,110,136,000
2,444,839
689,142,382
1,505,989,551
$2,197,576,772
1,292.6922
48,607,844
65,139,947
1,532,382
5,344,087
0
0
(4,050)
21,323,844
0
0
36,407,148
1,790,751
23,303,985
12,166,456
2,825,756
$218,438,150
$0.0196
Nuclear

Barrels
747,794

6,995

12,307

138,720

$43.030
$43.030
$1.748

$26.630
$26.630
$4.571
$0.017
9,444.000

MMbtu
121,934,439

$0.530
$0.530
$0.530
$0.006
10,977.000

 This Report Is:
Year of Report
Date of Re~ort
(Mo, Da, Y )
~1~ fX] A
An Resu
Or1~nal
Dec. 31, 1996
ission
STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued)
9. Ite~s under Cost of Plant are rased on U.S. of A.accounts.
-tu~bine unit
funTtions in e combined c~cle operation
Wit a conventiona steam un1t,1nc ude t e gas - turbJne
Pro uction expegses do not inc ~de hurchased Power, Sy~te~
Control and Loa D1~Vatch1ng,an Ot er Expenses c ass1 1e
w1t the ~team plant.
12. If ~ nuc ear ~ower generatin~ plan~, briefly ex~lain
Expenses.
as Other Power !u~~
10. For I~ gnd ~T ~
by ootnote <r
account1ng me hod
or cost of
ower
s, repor~ Oper!ting_Expenses, Account
generated 1gc u?ing any excess co~ts attr1buted to reNos. 4 an
on l1~5
4
ectrlc; Ex~ynses," and
Ma1nte~anTe Acc;ounf Nos.
3 end 5 on 1ge
"~aintensearch end eve o~ent;<¥>~YPfS o cost un1ts used for
fnce o E ectr1c P ant." Ind1cate plfnts esig8ed or peak
th~ var1ous compo ents o
ue cost; and <r> anv. o~hef
oad sfrv1ce. Qesl§nate auto~et1cel y o~erate p~ants.
1n or~at1ve data concern1o~ p~ant type,fue useo, ue
11. For a~ ant e~u1~Ve w1tb com 1nat1ons o .foss1 l uel steem,
enh1c ment _ ty~e agd quanti y or the report per1o?,and
nuclea
stea •
dro, lnternal comrustJon or gas:~urblne
ot er phys1ca an operat1ng character1st1cs of pant.
equ1pment,report each as a separate pant. However,1 a gas
Plant Name: Turkey Point
Plant Name: Turkey Point
Plant Name: * Turkey Point
Line
(d)
(e)
(f)
No.
1
Steam/Fossil
* Nuclear
* Internal Combust.
2
Full Outdoor
Conventional
Conventional
1967
1972
1968
3
1968
1973
1968
4
5
804.10
1,519.94
13.75
796
1,486
6
4,975
5,295
104
7
8
809
1,434
12
9
803
1,386
12
10
64
710
11
3,201,961,000
10,914,223,000
12
$2,186,686
$10,145,724
13
12,443,352
314,181,371
14
134,539,931
15
905,194,074
$149,169,969
$1,229,521,169
16
185.5117
17
808.9274
400,872
23,842,662
18
97,917,771
19
54,478,762
0
672,514
20
426,025
2,356,625
21
0
22
0
0
0
23
781,044
24
0
1,724,246
38,084,821
25
0
0
26
0
27
0
912,338
36,356,692
28
480,979
1,006,221
29
30
998,821
11,963,015
4,392,640
31
744,937
273,859
12,048,940
32
$185,202,892
$104,660,892
33
$0.0169
$0.0326
34
Oil
Nuclear
35
Gas
36
Barrels
MMbtu
Mcf
1,635,092
120,627,326
37
21,952,913

Nfme of Respongent
L1ght Company
F orida Power

e

I

"5

1,000,000

151,238

$3.020
$3.020
$3.020

$18.140
$18.140
$2.856
$0.031
10,097.000

FERC FORM NO. 1 (REV. 12-95)

I

38
$0.450
$0.450
$0.450
$0.005
11,057.000
Page 403.3

39
40
41
42
43
Next Page is 406

 <

Page 402.1 Line 11 Column b

>

Employees are included in Lauderdale Combined Cycle Plant .

<

Page 402.2 Line 11 Column b

>

Employees are included in the Port Everglades Steam Plant.

<

Page 402.3 Line 0 Column b >

Complete Name: St. Johns River Power Park
FPL owns 20% of St. Johns River Power Park. The data shown in
this column relates to FPL's ownership portion only. The
remaining 80% is owned by Jacksonville Electric Authority.

<

Page 402.3 Line 0 Column c

>

FPL owns 100% of St. Lucie Unit No. 1 and 85.10449% of St. Lucie
Unit No. 2. The other co-owners of Unit No. 2 and their ownership
percentages are Florida Municipal Power Agency - 8.806%, and
Orlando Utilities Commission - 6.08951%. The data shown in this
column relates to FPL's ownership portion only.

<

Page 402.3 Line 1 Column c >

The St. Lucie Nuclear Units have pressurized 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. Under the Nuclear Waste Policy Act of 1982, the U. S.
Department of Energy (DOE) is responsible for the ultimate
storage and disposal of spent nuclear fuel removed from nuclear
reactors. Additional information on FPL's nuclear fuel lease
program and nuclear decommissioning is detailed in the Notes to
Consolidated Financial Statements.

Page 402 Footnote.1

 <

Page 403 Line 11 Column e

>

Employees are included in the Ft. Myers Steam Plant.

<

Page 403.2 Line 0 Column f

>

FPL owns 76.36% of Scherer Unit No. 4. The data shown in this
column relates to FPL's ownership portion only. The other
co-owner of Scherer Unit No. 4 is Jacksonville Electric
Authority.

<

Page 403.3 Line 0 Column f

>

All operating data and costs for lines 11 through 43 related to
these diesel units are included in the Turkey Point Fossil Plant
amounts.

<

Page 403.3 Line 1 Column e

>

The Turkey Point Nuclear Units have pressurized water reactors.
The nuclear fuel assemblies in the reactors contain enriched
uranium. The cost of the nuclear fuel is amortized to fuel
expense based on the quantity of heat produced 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 disposal of spent nuclear fuel removed from
nuclear reactors. Additional information on FPL's nuclear fuel
lease program and nuclear decommissioning is detailed in the
Notes to Consolidated Financial Statements.

<

Page 403.3 Line 1 Column f

>

Kind of Plant - Internal Combustion
This installation consists of 5 diesel-driven generators each
having a nameplate rating of 2.75 MW. They are used occasionally
for peaking and emergency situations. These units operate semiautomatically inasmuch as an operator is required to start the
first unit while the others follow automatically.

Page 403 Footnote.1

 ~~Js[~elp~~to~~~inal

Year of Report
Date of Report
j
(Mo, Da, Yrl
Dec. 31, 1996
(2) [ A Resutxnission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support 1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
having nominal voltage of 132 kilovolts or greater. Report
by the use of brackets and extra lines. Minor portions of a
transmission lines below these voltages in group totals only
transmission line of a different type of construction need not
for each voltage.
be distinguished from the remainder of the line.
2. Transmission lines include all lines covered by the
6. Report in columns (f)and(g) the total pole miles of each
definition of transmission system plant as given in the Unitransmission line. Show in column (f) the pole miles of line
form System of Accounts. Do not report substation costs and
on structures the cost of which is reported for the line desiexpenses on this page.
gnated; conversely, show in column (g) the pole miles of line
3. Report data by individual lines for all voltages if so
on structures the cost of which is reported for another line.
required by a State commission.
Report pole miles of line on leased or partly owned stru4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
plant costs are included in Account 121, Nonutility Property.
such occupancy and state whether expenses with respect to
5.Indicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
ed in column<e> is:(1) single pole,wood or steel;<2> H-frame,
line designated.
wood, or steel poles; (3) tower; or (4) underground construeVOLTAGE (KV)
LENGTH (Pole miles)
DESIGNATION
(lnd1cate wliere
Type of
(In the case 9f
Number
undergrovnd ~1nes
other fhao
60 eye e,3 phase)
Supporting
report c1rcu1t ml(es)
of
Liner-----------------------.------------------------t----~--T-~~~
Operating Designed Structure
0~ Structure 0~ Structures Circuits
No.
From
To
of llne
of.Another
Des1~?~ted
L1ne(g)
(a)
(b)
(C)
(d)
(e)
(h)
of Respondent
Florida Power & L1ght Company

N~me

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

~~

ANDYTOIJN
ANDYTOIJN
CONSERVATION
ANDYTOIJN
ANDYTOIJN
CORBETT
CORBETT
ANDYTOIJN
CORBETT
CORBETT
CORBETT
ANDYTOIJN
MIDIJAY
MARTIN
MARTIN
MARTIN
* DUVAL
* DUVAL
POINSETT
DUVAL
DUVAL
FLORIDA CITY
FLORIDA CITY
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI

36
FERC FORM NO. 1 (ED. 12-87)

I

LEVEE NO 1
LEVEE NO 2
CORBETT
MARTIN PLANT NO 1
MARTIN PLANT NO 1
MARTIN NO 2
MARTIN NO 2
CORBETT
MIDIJAY
MARTIN
MARTIN
ORANGE RIVER
POINSETT
MIDWAY
MIDIJAY
POINSETT
<GAP>
HATCH
<GAP>
THALMANN
RICE
RICE
POINSETT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT

I

~88:88

~88:88 ~

500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00
23D.OO
230.00
230.00
230.00
230.00

500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
500.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00

~~8:88

~~8:88 ~p

8

H
H
H
H
H
H
H
H
H
H
H
H
H
H
H
H
H
H
H
SP
SP
H
H
H
H
H
H
H
H
H

56.66
82.11
1.51
30.73
1.83
51.05
56.17
1.80
34.13
106.78
92.72
1.76
28.84
109.24
37.53
37.53
126.53
45.92
172.47
7.54
0.75
16.87
1.46
0.13
0

H

1

0

1

0

1
1

0

0

0

1
1
1
1
1
1
1
1
1
1
1
1
1
1

0

1

0
0
0

0
0
0

0
0

0
0
0
0

0

1

0
0
0

2

0

18.18

1

2
1
2

0.17

0

1

0

18.20

2

0.41
0.50

0

1

0

0

0

1
1

9.96

0

1

8
TOTAL

Page 422

0

 N9me of Respondent
Florida Power & L1ght Company

This Report
(1)

7. Do not report the same transmission line structure twice.
Report lower voltage lines and higher voltage lines as one
li ne. Designate in a footnote if you do not include lower
vo ltage 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)_
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 other than a leased line, or portion thereof, for
which the respondent is not the sole owner but which the

Siz.e of
Conductor
and Mater1al
(i)

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

I~:

[XJ An Or1ginal
(2) [ J A Resuomission
I
TRANSMISSION LINE STATISTICS (Continued)

(k)

I

Date of Report
(Mo, Da, Y'r)

I

Year of Report
Dec. 31, 1996

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 line, name of co - owner, basis of sharing
ex penses of the line,and how the expenses borne by the respondent are accounted for, and accounts affected.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 (j) to
(l) on the book cost at end of year.

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

(l)

Total
Expenses

Line
No.

(p)

~-~H~
ACSRAZ
ACSRA\.1

~

3-1435 AAAC
3-1127 AAAC
3-1272 ACSRA\.1
3-1127 AAAC
3-1272 ACSRA\.1
3-1127 AAAC
3-1272 ACSRA\.1
3-1127 AAAC
3-1272 ACSRA\.1
3-1127 AAAC
3-1272 ACSRA\.1
3-1127 AAAC
3-1272 ACSRA\.1
3-1272 ACSRA\.1
3-1113 ACSR
3-1113 ACSR
3-1272 ACSRA\.1
3-1272 ACSRA\.1
3-1272 ACSRA\.1
954 ACSRA\.1
954 ACSRA\.1
1691 AAAC
1691 AAAC
1691 AAAC
1691 AAAC
1691 AAAC
1691 AAAC
1431 ACSRAZ
1431 ACSRA\.1
1691 AAAC
2- 5568 ACSRAZ

3
4
5
b
T
4

t!

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

~~

1t~ 1 A
ACSRAZ
CSRAZ

36
FERC FORM NO. 1 (ED. 12-87)

Page 423

 Year of Report
Date of Report
This Report Is:
(Mo, Da, Y)')
<1 l [Xl Ar. Or1ginal.
Dec. 31, 1996
(2) [ A ResuElmlSSlon
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support·
1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
having nominal voltage of 132 kilovolts or greater. Report
by the use of brackets and extra lines. Minor portions of a
transmission line of a different type of construction need not
transmission lines below these voltages in group totals only
be distinguished from the remainder of the line.
for each voltage.
6. Report in columns (f)and(g) the total pole miles of each
2. Transmission lines include all lines covered by the
definition of transmission system plant as given in the Unitransmission line. Show in column (f) the pole miles of line
form System of Accounts. Do not report substation costs and
on structures the cost of which is reported for the line desi·
expenses on this page.
gnated; conversely, show in column (g) the pole miles of line
3. Report data by individual lines for all voltages if so
on structures the cost of which is reported for another line.
required by a State commission.
Report pole miles of line on leased or partly owned stru4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
plant costs are included in Account 121, Nonutility Property.
such occupancy and state whether expenses with respect to
5.Indicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
ed in column(~) is:(1) single pole,wood or steel;(2) H-frame,
line designated.
wood, or steel poles; (3) tower; or (4) underground construeVOLTAGE (KV)
LENGTH (Pole miles)
(!nd1cate wliere
Type of
Number
DESIGNATION
(In the case 9f
undergrovnd Llnes
other [hao
Supporting
60 eye e,5 phase)
report c1 rcult mdes)
of
Line~----------------------.------------------------+----~--r-~--~
Operating Designed
Structure
0?
Structure 0? Structures Circuits
No.
From
To
0
8esi~~~ted Li~~~:~er
(h)
(a)
(b)
(C)
(d)
(e)
of Respondent
Florida Power & L1ght Company

N~me

1
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

FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
LEVEE
LEVEE
LEVEE
LEVEE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DORAL
DORAL
DORAL
DORAL
DORAL
DORAL
DADE
DADE
DADE
DADE
DORAL
DAVIS
DAVIS
DAVIS
DAVIS
FLAGAMI
FLAGAMI

36
FERC FORM NO. 1 (ED. 12-87)

I

I

TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
LEVEE NO 1
LEVEE NO 1
LEVEE NO 1
LEVEE NO 1
LEVEE NO 2
LEVEE NO 2
LEVEE NO 2
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
TURKEY POINT
DORAL
DORAL
DORAL
DORAL
RES RCVRY DADE<RRDC>
LEVEE NO 3
LEVEE NO 3
LEVEE NO 3
LEVEE NO 3
MIAMI NO 1
MIAMI NO 1

I

~~8:88

~~8:88 ~

1sJg

8

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
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

0.17
0.15
10.02
2.69
18.20
0.13
1. 10
12.57
18.24
0.03
0.09
0.01
6. 75
0.21

0

~~8:88

~~8:88 ~~

H
H
H
H
H
H
H
H
H
H
H
SP
H
H
SP
H
H
H
SP
SP
H
H
H
H
SP
H
SP
H
SP
H
SP

1
1

0

1

0

2

0

2

0

0

1
1
2
2
1
1
1

1.97

2

0

0
0
0

0
0

1.13

0

1
1

7.48
0.13
6.08
0.10
0.15

0

2

0

1
1

0
0

0
0

1

0

1

17.22
18.24

2
2
1
1
1
2

0.17
0.98
0.16

0
0

0

0

2.01

0. 76
0.14
21.33

0
0

1
1
1

0

0.96

2

1. 79

0

2

D

8
TOTAL

Page 422.1

0

 Date of Report
Year of Report
This Report Is: .
(Mo, Da, Yr>
(1) [Xl An Or1g1nal
Dec. 31, 1996
(2) [ A Resub"nission
TRANSMISSION LINE STATISTICS (Continued)
respondent operates or shares in the operation of, furnish a
7. Do not report the same transmission line structure twice.
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
particulars (details) of such matters as percent ownership by
line. Designate in a footnote if you do not include lower
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
expenses of the line,and how the expenses borne by the responmission line structures support lines of the same voltage,
report the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g) .
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9_ Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company_
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
(l) on the book cost at end of year.
which the respondent is not the sole owner but which the

N9me of Respondent
Florida Power & L1ght Company

S~e

of
Co uctor
and Material
(i)
AAAC
ACSRAZ
1691 AAAC
1431 ACSRAZ
2-5568 ACSRAZ
1431 ACSRAZ
1691 AAAC
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1691 AAAC
1431 ACSRAIJ
1431 ACSRAZ
1431 ACSRAIJ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
795 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1691 AAAC
1431 ACSRAZ
2-5568 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
954 ACSRAZ
954 ACSRAIJ
954 ACSRAIJ
954 ACSRAIJ
954 ACSRAII

I

COST OF Ll NE (Include in column (j) land,
land rights, and clearing right-of-way)
Construction and
Total Cost
Land
Other Costs
(j)

(k)

(l)

I

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
EXpenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

~*~~

Total
Expenses

Line
No_

(p)

~
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17

18
19
2D
21
22
23
24
25
26
27
28
29
30
31
32
33

~~

~~88 §~

36
FERC FORM NO. 1 (ED. 12-87)

Page 423.1

 Date of Report
Year of Report
This Report Is:
(Mo, Da, Yr)
(1) [Xl An Or1ginal
Dec. 31, 1996
(2) [ A Resuemission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construct i on
lines, and expenses for year. List each transmission line
by the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission lines below these voltages in group totals only
transmission line of a different type of construction need not
be distinguished from the remainder of the line.
for each voltage.
6. Report in columns (f)and(g) the total pole miles of each
2. Transmission lines include all lines covered by the
definition of transmission system plant as given in the Unitransmission line. Show in column (f) the pole miles of line
form System of Accounts. Do not report substation costs and
on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line
expenses on this page.
3. Report data by individual lines for all voltages if so
on structures the cost of which is reported for another line.
required by a State commission.
Report pole miles of line on leased or partly owned stru4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
such occupancy and state whether expenses with respect to
plant costs are included in Account 121, Nonutility Property.
5.Indicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
line designated.
ed in column(~) is:(1) single pole,wood or steel;(2) H-frame,
wood, or steel poles; (3) tower; or (4) underground construeLENGTH (Pole miles)
VOLTAGE (KV)
(lnd1cate where
Type of
DESIGNATION
(In the case 9f
Number
undergrovnd ~1nes
other thao
60 cycle,5 phase)
Supporting
report c1rcu1t m1!es)
of
Line
Operating Designed Structure
On Structure On Structures Circuits
No.
From
To
at L1ne
ot.Another
Des1~?~ted
L1ne(g)
(h)
(a)
(b)
(c)
(d)
(e)
of Respondent
Florida Power & L1ght Company

N~me

3
4
5
6
7
8
9
10
11
12
13

FLAGAMI
FLAGAMI
FLAGAMI
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE

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)

I

MIAMI NO 1
MIAMI NO 2
MIAMI NO 2
LEVEE NO 1
LEVEE NO 1
LEVEE NO 1
LEVEE NO 2
LEVEE NO 2
LEVEE NO 2
LEVEE
LEVEE
LEVEE
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDY TOWN
ANDYTOWN
ANDYTOWN
ANDY TOWN
ANDYTOWN
ANDYTOWN
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
MIAMI SHORES

PLT
PLT
PLT
PLT
PLT

I

I

~~8:88

~~8:88 0~

~j~

8

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
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

UG
H
H
H
H
H
H
H
SP
H
H
H
H
SP
SP
H
H
H
UG
H
H
H
H
SP
H
H
UG
H
H
H
SP

1.05

0

0.13

0

0

~~8:88

~~8:88 ~p

1.12

0

2

0.13

0

1

12.32

0

2

0

1.12

2

0.59
4.71
1.12
14.63
4.76
4. 71
4.20
0.06
0.22
6.51
6.44
0.25
0.17
0.04
20.66
0.98
0.10
0.26
0.57
0.25
21.43
3.02
4.63
1.40

0

1

0

1

6.75

2
1
1

0
0
0
0
0

1
1
1

0.40

2
2
2

0

2

0

0

1
1
1
1
1

0
0

0
0
0
0

2

10.96

2

0

2

0

1

0
0

1
1

0

1

8
TOTAL

Page 422.2

12.32

1
1
2

 Year of Report
Date of Report
This Report Is:.
(Mo, Da, Yr)
( 1) [XJ An Or 1g 1na l
Dec. 31, 1996
(2) [ A Resuemission
TRANSMISSION LINE STATISTICS (Continued)
respondent operates or shares in the operation of, furnish a
7. Do not report the same transmission line structure twice.
succinct statement explaining the arrangement and giving
Report lower voltage lines and higher voltage lines as one
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the respondent are accounted for, and accounts affected.Specify whether
report the pole miles of the primary structure in column (f)
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
9. Designate any transmission line leased to another company
8. Designate any transmission line or portion thereof for
and give name of lessee, date and terms of lease, annual rent
which the respondent is not the sole owner. If such property
for year, and how determined. Specify whether lessee is an
is leased from another company, give name of lessor, date and
terms of lease, and amount of rent for year. For any transmiassociated company.
10. Base the plant cost figures called for in columns (j) to
ssion line other than a leased line, or portion thereof, for
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

of Respondent
Florida Power & L1ght Company

N~me

S~e of
Co uctor
and Mater1al

r-

( i)
ACSRAZ
~3~6 AL
3750 AL
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
2-5568 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
2-5568 ACSRAZ
954 ACSRAII
1431 ACSRAII
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
2-3750P AL
1431 ACSRAZ
1431 ACSRAII
1431 ACSRAZ
2-5568 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
2-3750P AL
1431 ACSRAZ
900 CUHT
1431 ACSRAZ
1431 ACSRAZ
ACSRAZ
ACSRAZ

I

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Construction and
Total Cost
Land
Other Costs
(j)

(k)

(l)

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

Total
Expenses

Line
No.

(p)

~
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

~~

1H1

36
FERC FORM NO. 1 (ED. 12-87)

Page 423.2

 of Respondent
Florida Power & L1ght Company

N~me

l~isr~elp~~to~I~inal

I (2) (
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 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 construe-

A Resuemission

(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
36
FERC

DADE
GREYNOLOS
GREYNOLDS
LAUDANIA
LAUOANIA
LAUDANIA
PORT EVERGLADES
PORT EVERGLADES
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANOYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANOYTOWN
ANOYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN
ANDYTOWN

(! nd1

(b)

MIAMI SHORES
LAUDANIA
LAUDANIA
LAUDERDALE PLANT
LAUDERDALE PLANT
PORT EVERGLADES
SISTRUNK
SISTRUNK
PORT EVERGLADES NO
PORT EVERGLADES NO
PORT EVERGLADES NO
PORT EVERGLADES NO
163U5
163U5
163U5
LAUDERDALE PLANT
LAUDERDALE PLANT
ANOYTOWN
ANDY TOWN
ANDYTOWN
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION

(c)

1
1
3
3

Type of
Supporting
Structure
(e)

(d)

~j8:88

~j8:88 ~G

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
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

I

Year of Report
Dec. 31, 1996

~j8:88

~j8:88 ~p

Page 422.3

LENGTH (Pole miles)
(In the case of
Number
undergrovnd 11nes
report c1rcu1t m1les)
of
On Structure On Structures Circuits
of l1ne
of Another
Des1gnated
Line
(g)

{t)

(h)

8

UG
H
H
H
UG
UG
H
H
H
H
H
SP
H
H
H
SP
H

1.25
0.68
4.26
2.70
3.44
1.03
3.39
4.26
3.39
4.26
1. 72
0.01

0
0

0

1
1
1

0

1
1

0

1

0

0

0

1
1
1
1
1
1

0

0.12

2

0.04
10.99
0.17

0

0.12
16.73

1
2
1
2
2

0

1

0

H

0

H
SP
H
H
H
H
SP
SP
SP
H
H
H
H

0.11
0.07
0.12
12.06
4.85
0.32
22.56
1.16
0.03
0.12

0
0
0
0

6.00
0

0

1

0

2

0

2

0

2

0

1

0

1

0

2
1

0

0

0

0.17
11.94
1.93

8

8:H

0

4.85

TOTAL
FORM NO. 1 (EO. 12-87)

Date of Re~ort
(Mo, Da, Y )

tion. 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.

VOLTAGE (KV)
cate wtiere
other fhao
60 eye e,3 phase)
Line~----------------------,----------------------~----~--T-~~~
Operating Designed
No.
From
To
DESIGNATION

I

2
2
2
2

 of Respondent
Florida Power & L1ght Company

I9;
s [~elp~~to~T~inal
(2) [ A Resuemission

N~me

I

I

Date of Report
(Mo, Da, Yt"l

I

Year of Report
Dec. 31, 1996

TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furn i sh a
Report lower voltage lines and higher voltage Lines as one
succinct statement explaining the arrangement and gi ving
Line. Designate in a footnote if you do not include Lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the Line, name of co -owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other Line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8 . Designate any transmission line or portion thereof for
9. Designate any transmission Line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
associated company .
terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

S~e of
Co uctor
and Material

,....-

( i)
ACSRAZ
~3o6 AL
3750 AL
900 CUHT
1431 ACSRAZ
900 CUHT
3000 AL
3750 AL
900 CUHT
1431 ACSRAZ
900 CUHT
1431 ACSRAZ
1431 ACSRAW
1431 ACSRAW
1431 ACSRAW
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAW
1431 ACSRAW
1431 ACSRAW
1431 ACSRAW
1431 ACSRAZ
1431 ACSRAW
1431 ACSRAZ
1431 ACSRAW
ACSRAZ
~ H ~ ACSRAW

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of - way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

(l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

Total
Expenses

Line
No.

(p)

~
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

~~
36

FERC FORM NO . 1 (ED. 12-87)

Page 423.3

 Date of Report
Year of Report
(Mo, Da, Yr>
(2) [ A Resubmission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS
1. Report information concerning transmission lines,cost of
tion. If a transmission line has more than one type of supportlines, and expenses for year. List each transmission line
ing structure, indicate the mileage of each type of construction
having nominal voltage of 132 kilovolts or greater. Report
by the use of brackets and extra lines. Minor portions of a
transmission lines below these voltages in group totals only
transmission line of a different type of construction need not
for each voltage.
be distinguished from the remainder of the line.
2. Transmi ss ion lines include all lines covered by the
6. Report in columns <f>and(g) the total pole miles of each
definition of transmission system plant as given in the Unitransmission line. Show in column (f) the pole miles of line
form System of Accounts. Do not report substation costs and
on structures the cost of which is reported for the line desiexpenses on this page.
gnated; conversely, show in column (g) the pole miles of line
3. Report data by individual lines for all voltages if so
on structures the cost of which is reported for another line.
required by a State commission.
Report pole miles of line on leased or partly owned stru4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
plant costs are included in Account 121, Nonutility Property.
such occupancy and state whether expenses with respect to
5.1ndicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
ed in column<e> is:(1) single pole,wood or steel;(2) H-frame,
line designated.
wood, or steel poles; (3) tower; or (4) underground construeVOLTAGE (KV)
LENGTH (Pole miles)
DESIGNATION
(I nd1 cate wnere
Type of
(In the case 9f
Number
undergrovnd ~1nes
other fhao
Supporting
bO eye e,5 phase)
report c1rcu1t ml(es)
of
Line~----------------------,------------------------+~--~--~~~~
Operating Designed Structure
OQ Structure OQ Structures Circuits
No.
From
To
of Llne
of Another
DeslgQated
Line
N9me of Respondent
Florida Power & L1ght Company

(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
36
FERC

ANDYTOIIN
ANDYTOIIN
ANDYTOIIN
ANDYTOIIN
ANDYTOIIN
ANDYTOIIN
ANDYTOIIN
ANDYTOIIN
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
BRDIIARD
BRDIIARD
BRDIIARD
BROIIARD
BRDIIARD
BRDIIARD
BRDIIARD
BRDIIARD
BROIIARD
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
BROIIARD

I

(b)

CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
CONSERVATION
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
RANCH
RANCH
YAMATO
YAMATO
YAMATO
YAMATO
YAMATO NO 1

NO
NO
NO
NO
NO
NO
NO
NO
NO

t~~s[~elp~~to~T~inal

(C)

1
1
1
1
1
2
2
2
2

(e)

(d)

(g)

(f)

(h)

~~8:88

~~8:88 ~~

8:8~

8

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
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
H
H
H
H
H
H
SP
SP
SP
SP
H
H
H
H
SP
SP
H
H
SP
H
H
H
SP
H
H
H
H
H
H
SP

0.06
0.34

0

2

0

2

0

0.12

11.86
1.93
0.45
0.39
10.23
2.43
0. 15

0

~~8:88

~~8:88

Hp

0

Page 422.4

0

2
2
2
2
1
1
1
1
2
1
2
2
2
2
1
2

0

2

0

2

0

1
1

0

4.85
0
0
0
0

1.16

0.06

0

0

0.38
10.08
1.96
0.20

0
0
0

0.65
0.38
12.04
0.20
0.02
29.83
2.32
0.64
1. 15
6.25
9.12
0

0.13

0

0.03
7.78

0

1
1
1

0

0

0
0

1
1

0

2

0
0

2
1

6.25

2

0

8
TOTAL

FORM NO. 1 (ED. 12-87)

I

I

 Date of Report
Year of Report
This Report 1$:
(Mo, Da, Yr)
( 1 ) [XJ An Or 1gina l
Dec. 31, 1996
(2) [ A Resuemission
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property
and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmi associated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

N9me of Respondent
Florida Power & L1ght Company

Siz.e of
Conductor
and Material

~B~
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431
1431

iHl

( i)
ACSRAZ
ACSRAII
ACSRAZ
ACSRAII
ACSRAZ
ACSRAZ
ACSRAII
ACSRAZ
ACSRAZ
ACSRAZ
ACSRAZ
ACSRAZ
ACSRAII
ACSRAZ
ACSRAZ
ACSRAZ
ACSRAZ
ACSRAIJ
ACSRAZ
ACSRAZ
ACSRAZ
ACSRAIJ
ACSRAZ
ACSRAZ
ACSRAZ
ACSRAIJ
ACSRAZ
ACSRAZ
ACSRAZ
ACSRAZ
ACSRAIJ
ACSRAZ
ACSRAIJ
ACSRAZ
ACSRA Z

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

I

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

Total
Expenses

Line
No.

(p)

~
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

~~
36

FERC FORM NO. 1 (ED. 12-87)

Page 423.4

 Year of Report
Dec. 31, 1996

N9me of Respondent
Florida Power & L1ght Company
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. Transmi ss ion 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(~) is:(1) single pole,wood or steel;<2> H-frame,
wood, or steel poles; (5) tower; or (4) underground construe-

tion. 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.

VOLTAGE (KV)
cate where
other thao
60 cycle,5 phase)
Line~----------------------.------------------------+--------.-~--~
Operating Designed
No.
From
To
(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
36
FERC

BROWARD
BROWARD
BROWARD
BROWARD
BROWARD
BROWARD
BROWARD
BROIIARD
BROWARD
BROWARD
BROIIARD
BROWARD
BROIIARD
BROIIARD
BROIIARD
BROIIARD
BROWARD
CORBETT
CORBETT
CORBETT
CORBETT
CORBETT
CORBETT
CORBETT
RANCH
RANCH
RANCH
RANCH
PRATT & WHITNEY
INDIANTOWN
MARTIN
MARTIN
MARTIN
MARTIN
MARTIN

Type of
Supporting
Structure

(I nd1

DESIGNATION

(b)

YAMATO NO 1
YAMATO NO 1
YAMATO NO 1
YAMATO NO 1
RANCH
RANCH
RANCH
RANCH
CORBETT
CORBETT
CORBETT
CORBETT
CORBETT
CORBETT
CORBETT
CORBETT
CORBETT
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
RANCH NO 1
RANCH NO 2
MIDWAY
MIDWAY
MIDWAY
MIDWAY
RANCH
PRATT & WHITNEY
SHERMAN
SHERMAN
SHERMAN
SHERMAN
WARFIELD

(C)

(e)

(d)

~~8:88

~~8:88 ~p

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
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

~~8:88

~~8:88 ~~

Page 422.5

(g)

{f)

(h)

8

SP
SP
SP
H
H
H
H
H
SP
SP
SP
SP
H
H
H
SP
SP
H
SP
SP
H
H
H
H
H
SP
H
H
H
H
H

0.87
2.64
0.23
0.13
0.05
31.58
0.13
0.13
0.29
0.10
0.02
0.06
0
0

11.90
4.40
10.76

0
0
0
0
0
0
0
0
0
0

1
1
1

2
2
2
1
1
1
1

0

1

0

1

0.05
31.32
0

2

2
2

0

1

0

1

11.90
0.17

2

0.58
11.90

0

2

0

2

0

11.90

2

1.54
30.98
20.74
0.40
20.74
8.45
0.13
0.13
3.85

0

1
1

0
0

1~:~~
TOTAL

FORM NO. 1 (ED. 12-87)

LENGTH (Pole miles)
(In the case ot
Number
underground 11nes
report c1rcu1t m1les)
of
Oo Structure Oo Structures Circuits
ot ~1ne
ot Another
Des1goated
Line

0

2

0

1

0

1

0

1

0

1
1
1
1

0
0
0

8

 of Respondent
Florida Power & Llght Company

This Report 1$:
Date of Report
Year of Report
(1) [X] An Or1ginal
(Mo, Da, Yi")
(2) [ l A Resuemission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
respondent operates or shares in the operation of, furnish a
7. Do not report the same transmission line structure twice.
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the respon report the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

N~me

Siz.e of
Conductor
and Mater1al

,......

,......

......

( i)
ACSRAZ
u~~ ACSRAZ
1431 ACSRAW
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAW
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRTW
1431 ACSRAW
1431 ACSRTW
1431 ACSRTW
1431 ACSRAW
1431 ACSRTW
1431 ACSRTW
1431 ACSRTW
2-7958 ACSRAZ
2-7958 ACSRAZ
2-9548 ACSRAZ
1431 ACSRAW
2-9548 ACSRAZ
2-9548 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ

J

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

(l)

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

Total
Expenses

Line
No.

(p)

~
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

~~

~5~ ~CSRAZ

- 9 B ACSRAW

36
FERC FORM NO. 1 ( ED. 12-87)

Page 423 .5

 Year of Report
Date of Report
This Report 1~: .
(Mo, Da, Yr)
(1) (Xl An Or1g1nal
Dec . 31, 1996
(2) ( A ResuElmission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
by the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission lines below these voltages in group totals only
transmission line of a different type of construction need not
for each voltage.
be distinguished from the remainder of the line.
2. Transmission lines include all lines covered by the
6. Report in columns (f)and(g) the total pole miles of each
definition of transmission system plant as given in the Unitransmission line. Show in column (f) the pole miles of line
form System of Accounts. Do not report substation costs and
on structures the cost of which is reported for the line desiexpenses on this page.
gnated; conversely, show in column (g) the pole miles of line
3. Report data by individual lines for all voltages if so
on structures the cost of which is reported for another line.
required by a State commission.
Report pole miles of line on leased or partly owned stru4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
plant costs are included in Account 121, Nonutility Property.
such occupancy and state whether expenses with respect to
5.1ndicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
line designated.
ed in column<e> is:(1) single pole,wood or steel;(2) H- frame,
wood, or steel poles; (5) tower; or (4) underground construeVOLTAGE (KV)
LENGTH (Pole miles)
(lnd1cate wliere
DESIGNATION
Type of
(In the case of
Number
other thao
undergro~nd ~1nes
60 cycle,5 phase)
report c1rcu1t m1les)
Supporting
of
Liner-----------------------,------------------------+~--~--~~--~
Operating Designed Structure
Oo Structure Oo Structures Circuits
No.
From
To
of ~1ne
of Another
Des1goated
Line
N9me of Respondent
Florida Power & L1ght Company

(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
36
FERC

MARTIN
MIDIIAY
MIDIIAY
INDIANTDIIN
I NO I AN TOliN
INDIANTOIIN
INDIANTOIIN Sll STA
INDIANTOIIN Sll STA
SANDPIPER
SANDPIPER
SANDPIPER
MIDIIAY
BRIDGE
INDIANTDIIN
BRIDGE
BRIDGE
BRIDGE
BRIDGE
BRIDGE
BRIDGE
MIDIIAY
MIDIIAY
MIDIIAY
MIDIIAY
MIDIIAY
MIDIIAY
ST LUCIE PLANT
EMERSON
EMERSON
EMERSON
EMERSON
EMERSON
MALABAR
MALABAR
MALABAR

I

(b)

IIARFIELD
SHERMAN
SHERMAN
MARTIN
MARTIN
MARTIN
MIDIIAY
MIDIIAY
TURNPIKE
TURNPIKE
TURNPIKE
TURNPIKE
TURNPIKE
liAR FIELD
HOBE
HOBE
INDIANTOIIN
INDIANTOIIN
PLUMOSUS
PLUMOSUS
ST LUCIE
ST LUCIE
ST LUCIE
ST LUCIE
ST LUCIE
ST LUCIE
HUTCHINSON ISL RDIAL
MIDIIAY
MIDIIAY
MIDIIAY
MALABAR
MALABAR
MIDIIAY
MIDIIAY
MIDIIAY

(C)

(d)

~~8:88

~~8:88 ~

11.2~

0.1g

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
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

15.54
1.97
9.69
0.18
1.54
22.58
4.14
0.31
1.68
9.85
17.23
8.56
0.01
6.23
0.02
9.98
24.98
3.04
9.49
2.13
9.64
2.13
9.64
2.11
0.04
11.96
0.01
3.00
38.42

0

0
0
0
0
0
0

0

3.00

0.01

0

~~8:88

H8:88 ~p

5~:b1

8

(e)

H
H
SP
H
H
H
SP
SP
SP
SP
SP
SP
H
H
H

H
SP
SP
H
H
H
H
H
H
H
H
SP
H
H
H
H
TOTAL

FORM NO. 1 (ED. 12-87)

I

I

Page 422.6

(g)

(f)

(h)

0

1
1
1

0

2

0

1
1
1

0

0

0
0
0
0
0

0

1
2
1
1
1

0
0

1

0

1
1

0

1

0

1
1

0

1

0

1

0

0

1

0

1

0

1
1
1
1
1
2
1

2
1

 of Respondent
Florida Power & L1ght Company

This Report Is: .
Date of Report
Year of Report
(Mo, Da, Y'r)
(1) [Xl An Or1g1nal
Dec. 31, 1996
(2) [ A ResuExnission
TRANSMISSION LINE STATISTICS (Continued)
respondent operates or shares in the operation of, furnish a
7. Do not report the same transmission line structure twice.
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the ar rangement and gi ving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
associated company.
terms of lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

N~me

SMJe of
Co uctor
and Mater1al
( i)
ACSRAW
4 1 ACSRAZ
1431 ACSRAZ
2-7958 ACSRAW
2-7958 ACSRAW
2- 7958 ACSRAW
2-9548 ACSRAZ
2-9548 ACSRAZ
1431 ACSRAW
1431 ACSRAW
1431 ACSRAW
1431 ACSRAW
1431 ACSRAW
2-7958 ACSRAW
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAW
1431 ACSRAW
2-1691 AAAC
3400 ACSRAW
2-1691 AAAC
3400 ACSRAW
2- 1691 AAAC
3400 ACSRAW
927.2 AAAC
795 ACSRAZ
795 ACSRAZ
954 ACSRAW
795 ACSRAZ
954 ACSRAW
795 ACSRAZ
~g~ ACSRAZ
ACSRAZ

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

~ - ~958

,....-

,...--

,......

,...--

I

I

Total
Expenses

Line
No.

(p)

~
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

~~
36

FE RC FORM NO. 1 (EO. 12-87)

Page 423.6

 of Respondent
Florida Power & L1ght Company

Date of Report
(Mo, Da, Yr)

N~me

I

I

Year of Report
Dec. 31, 1996

TRANSMISSION LINE STATISTICS
1. Report information concerning transmission lines,cost of
tion. If a transmission line has more than one type of support ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
having nominal voltage of 132 kilovolts or greater. Report
by the use of brackets and extra lines. Minor portions of a
transmission lines below these voltages in group totals only
transmission line of a different type of construction need not
for each voltage.
be distinguished from the remainder of the line.
2. Transmission lines include all lines covered by the
6. Report in columns (f)and(g) the total pole miles of each
definition of transmission system plant as given in the Unitransmission line. Show in column (f) the pole miles of line
form System of Accounts. Do not report substation costs and
on structures the cost of which is reported for the line desiexpenses on this page.
gnated; conversely, show in column (g) the pole miles of line
3. Report data by individual lines for all voltages if so
on structures the cost of which is reported for another line.
required by a State commission.
Report pole miles of line on leased or partly owned stru4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
plant costs are included in Account 121, Nonutility Property.
such occupancy and state whether expenses with respect to
S.Indicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
ed in column(e) is:(1) single pole,wood or steel;(2) H-frame,
line designated.
wood, or steel poles; (5) tower; or (4) underground construeVOLTAGE (KV)
LENGTH (Pole miles)
DESIGNATION
(lnd1cate wliere
Type of
(In the case ot
Number
other thao
undergrovnd 11nes
60 cycle,5 phase)
report c1rcu1t m1les)
Supporting
of
Line~----------------------,------------------------+----~--r-~--~
Operating Designed Structure
0~ Structure 0~ Structures Circuits
No.
From
To
of ~1ne
of Another
Des1g~ated
Line
(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
~4

MALABAR
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
POINSETT
POINSETT
POINSETT
POINSETT
POINSETT
POINSETT
POINSETT
POINSETT
POINSETT
POINSETT
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
CAPE CANAVERAL PLT
CAPE CANAVERAL PLT
CAPE CANAVERAL
CAPE CANAVERAL
CAPE CANAVERAL
CAPE CANAVERAL
CAPE CANAVERAL
NORRIS

55
36
FERC FORM NO. 1 (ED. 12-87)

(b)

MIDWAY
MALABAR NO 1
MALABAR NO 1
MALABAR NO 2
POINSETT NO 1
POINSETT NO 1
POINSETT NO 1
POINSETT NO 1
POINSETT NO 2
POINSETT NO 2
WEST LAKE WALES<FPC>
WEST LAKE WALES<FPC>
SANFORD
SANFORD
SANFORD
SANFORD
SANFORD
SANFORD
SANFORD
SANFORD
CAPE CANAVERAL PLT
CAPE CANAVERAL PLT
CAPE CANAVERAL PLT
CAPE CANAVERAL PLT
CAPE CANAVERAL PLT
CAPE CANAVERAL
CAPE CANAVERAL
INDIAN RVR PLT <OUC>
INDIAN RVR PLT <OUC>
BARNA
BARNA
BARNA
BARNA
BARNA
VOLUSIA

(c)

(e)

(d)

(g)

(f)

(h)

~~8:88

~~8:88 ~p

2gj~

8

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
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

0.32
26.39
0.12
4.86
2.11
4.31
7.63
0.19
0.12

0

~~8:88

~~8:88 ~p

SP
H
H
H
H
H
H
H
H
H
H
H
SP
SP
SP
H
SP
SP
H
H
SP
H
H
H

H
H
H
H
H
H
SP

Page 422.7

1
1

0

1

0

0

1
1
2
1
2
1

0
0
0
0

0

4.31

2

4.77

0

39.90
0.06
0.36
0.02
0.19
0.02
12.10
0.68
7.75
0.04
0.69
7.75
0. 71
7.73
1.56
0.71
0.30
10. 11

0

1
1

0

2.55

4~:~~
TOTAL

0

0
0

1

0

1
1
2
2
2

0

1

0
0

0.02

0

1

0

1
1
1

0
0

0

1

0
0

1
1

0

2

0

1

0

1

0. 73
0

2

8

2

 Name of Respondent
Florida Power & L1ght Company

Date of Report
Year of Report
Thi s Report Is:
(Mo, Da, Yr)
(1) fXJ An Or1ginal
Dec. 31, 1996
(2)
A ResuElm i ssion
TRANSMISSION LINE STATISTICS (Continued)
respondent operates or shares in the operat i on of , furn ish a
7. Do not report the same transmission line structure twice.
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and g1v1ng
line. Des i gnate in a footnote i f you do not include lower
particulars (details) of s uch matters as percent owner shi p by
voltage lines with higher voltage lines. If two or more trans respondent in the line, name of co-owner, bas i s of s haring
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Spec i fy whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an assoc i ated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property
and give name of lessee, date and terms of lease, annual rent
i s leased from another company, give name of lessor, date and
for year, and how determined. Spec i fy whether lessee is an
terms of lease, and amount of rent for year. For any transmi associated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

Siz.e of
Conductor
and Mater1al
( i)

I

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right - of -way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
EXpenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

ACSRAII
ACSRAZ
1431 ACSRAII
795 ACSRAZ
954 ACSRAII
954 ACSRAZ
954 ACSRAZ
954 ACSRAII
2-7958 ACSRAZ
1431 ACSRAZ
954 ACSRAII
954 ACSRAII
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
954 ACSRAII
954 ACSRAZ
954 ACSRAII
1431 ACSRTII
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAII
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
954 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
954 ACSRAII
954 ACSRAII
954 ACSRAZ

Total
Expenses

Line
No.

(p)

1
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

~~
36

FERC FORM NO . 1 (ED. 12-87)

Page 423.7

 I

Year of Report
Date of Report
(Mo, Da, Yr)
Dec. 31, 1996
(2) [ A ResuiJmission
TRANSMISSION LINE STATISTICS
1. Report information concerning transmission lines,cost of
tion. If a transmission line has more than one type of support lines, and expenses for year. List each transmission line
ing structure, indicate the mileage of each type of construction
having nominal voltage of 132 kilovolts or greater. Report
by the use of brackets and extra lines. Minor portions of a
transmission lines below these voltages in group totals only
transmission line of a different type of construction need not
for each voltage.
be distinguished from the remainder of the line.
2. Transmission lines include all lines covered by the
6. Report in columns (f)and(g) the total pole miles of each
definition of transmission system plant as given in the Unitransmission line. Show in column (f) the pole miles of line
form System of Accounts. Do not report substation costs and
on structures the cost of which is reported for the line desiexpenses on this page.
gnated; conversely, show in column (g) the pole miles of line
3. Report data by individual lines for all voltages if so
on structures the cost of which is reported for another line.
required by a State commission.
Report pole miles of line on leased or partly owned stru4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
plant costs are included in Account 121, Nonutility Property.
such occupancy and state whether expenses with respect to
5.1ndicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
ed in column(~) is:(1) single pole,wood or steel;(2) H-frame,
line designated.
wood, or steel poles; (3) tower; or (4) underground construeVOLTAGE (KV)
LENGTH (Pole miles)
(I nd1 cate where
Type of
DESIGNATION
(In the case of
Number
undergrovnd \lnes
other fhao
60 eye e,3 phase)
Supporting
report c1rcu1t m1!es)
of
Line~-----------------------.-----------------------+----~--~~--~
Operating Designed Structure
0~ Structure 0~ Structures Circuits
No.
From
To
of ~1ne
ot Another
Des1g~ated
Line
N9me of Respondent
Florida Power & L1ght Company

(a)

1
2
3
4
5
6
7
8
9
10
11
12
13

NORRIS
BARNA
BARNA
BARNA
SANFORD
SANFORD
SANFORD
SANFORD
SANFORD
SANFORD
SANFORD
SANFORD
SANFORD
SANFORD
SANFORD
BUNNELL
BUNNELL
PUTNAM
PUTNAM
PUTNAM
PUTNAM
BRADFORD
DUVAL
DUVAL
DUVAL
DUVAL
DUVAL
DUVAL
PUTNAM
PUTNAM
PUTNAM
MILLCREEK
MILLCREEK
MILLCREEK
MILLCREEK

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)

I

(b)

VOLUSIA
NORRIS
NORRIS
NORRIS
NORTH LONGWOOD
NORTH LONGWOOD
NORTH LONGWOOD
NORTH LONGWOOD
VOLUSIA NO 1
VOLUSIA NO 1
VOLUSIA NO 1
VOLUSIA NO 1
VOLUSIA NO 2
VOLUSIA NO 2
VOLUSIA NO 2
VOLUSIA
PUTNAM
VOLUSIA
VOLUSIA
VOLUSIA
VOLUSIA
DUVAL
KINGSLAND
KINGSLAND
KINGSLAND
KINGSLAND
KINGSLAND
KINGSLAND
TOCOI
TOCOI
TOCOI
TOCOI
TOCOI
TOCOI
SAMPSON

t~~s[~elp~~to~~~inal

(c)

<FPC>
<FPC>
<FPC>
<FPC>

<GAP>
<GAP>
<GAP>
<GAP>
<GAP>
<GAP>

<JBH>

(d)

(e)

~~8:88

~~8:88 ~p

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
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

~~8:88

~~8:88 ~p

(g)

(f)

(h)

8

SP
SP
H
H
H
SP
H
H
H
SP
H
H
H
H
H
H
H
SP
SP
H
H
H
H
H
SP
SP
H
H
SP
H
H

0
0

2.55
0.65

2

1.01
0.19
6.70
0.06
0.10
0.20
33.01
2.49
0.10
0.20
33.01
23.39
26.74
0.20
49.78
0.10
0.20
27.18
0.09
0.38
13.00
15.06
0.35
20.54
0.07
16.29
1.95
0.09
8.05

0

1

0

1
1
1

8:8~
TOTAL

Page 422.8

I

0
0

2

0

1

0

1

0
0

1
1

0

1

0
0

1

0

1

0

1

0

1
1

0

1

0

1

0

1

0

0
0
0

1
1
1
1

0

1

0

1

0

1

0
0

1
1

0

1

0

1

0

1

8

 Year of Report
Date of Report
This Report Is:
1
(Mo, Da, Yt")
(1) [XJ An Or1ginal
Dec. 31, 1996
(2) [ A ResuDinission
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property
and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
associated company.
terms of lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

Name of Respondent
Florida Power & L1ght Company

Siz;e of
Conductor
and Material
( i)

I

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
EXpenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

ACSRAZ
ACSRAZ
954 ACSRAiol
954 ACSRAiol
954 ACSRAZ
2-954 ACSRAiol
954 ACSRAZ
954 ACSRAiol
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAiol
954 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
2-9548 ACSRAZ
1431 ACSRAiol
1431 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
ACSRAII
ACSRAZ

Total
Expenses

Line
No.

(p)

1
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

~~
36

FERC FORM NO. 1 (ED. 12-87)

Page 423.8

 Year of Report
Date of Report
(Mo, Da, Y)')
Dec. 31, 1996
(2) [ A Resuemission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
by the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission lines below these voltages in group totals only
transmission line of a different type of construction need not
be distinguished from the remainder of the line.
for each voltage.
6. Report in columns (f)and(g) the total pole miles of each
2. Transmission lines include all lines covered by the
definition of transmission system plant as given in the Uni·
transmission line. Show in column (f) the pole miles of line
on structures the cost of which is reported for the line desiform System of Accounts. Do not report substation costs and
expenses on this page.
gnated; conversely, show in column (g) the pole miles of line
3. Report data by individual lines for all voltages if so
on structures the cost of which is reported for another line.
required by a State commission.
Report pole miles of line on leased or partly owned stru4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
plant costs are included in Account 121, Nonutility Property.
such occupancy and state whether expenses with respect to
5.Indicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
line designated.
ed in column(e) is:(1) single pole,wood or steel;(2) H-frame,
wood, or steel poles; (3) tower; or (4) underground construeVOLTAGE (KV)
LENGTH (Pole miles)
Type of
DESIGNATION
(lnd1cate wliere
(In the case 9f
Number
underground llnes
other than
Supporting
60 cycle,3 phase)
report c1rcu1t m1!es)
of
Liner-----------------------,------------------------+----~--r-~---4
Operating Designed Structure
0~ Structure 0~ Structures Circuits
No.
From
To
of ~1ne
ot .Another
Des1{?~ted
L1ne(g)
(a)
(b)
(c)
(d)
(e)
(h)
of Respondent
Florida Power & L1ght Company

N~me

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
FERC

MILLCREEK
MILLCREEK
GREENLAND
GREENLAND
ST JOHNS
BALDWIN
BALDWIN
BALDWIN
BALDWIN
PUTNAM
PUTNAM
PUTNAM
PUTNAM
PUTNAM
PUTNAM
DUVAL
DUVAL
DUVAL
DUVAL
BRADFORD
BRADFORD
BRADFORD
PUTNAM
PUTNAM
PUTNAM
RICE
RICE
COLLIER
COLLIER
COLLIER
ALI CO
ALICO
ALICO
ALICO
ALICO

<JEA>
<JEA>

I

SAMPSON
SAMPSON
SAMPSON
SAMPSON
TOCOI
DUVAL
DUVAL
DUVAL
DUVAL
SEMINOLE
SEMINOLE
SEMINOLE
SEMINOLE
SEMINOLE
SEMINOLE
SEMINOLE
SEMINOLE
SEMINOLE
SEMINOLE
RICE
RICE
RICE
RICE
RICE
RICE
SEMINOLE NO 1
SEMINOLE NO 2
ORANGE RIVER
ORANGE RIVER
ORANGE RIVER
ORANGE RIVER
ORANGE RIVER
ORANGE RIVER
ORANGE RIVER
ORANGE RIVER

<JBH>
<JBH>
<JBH>
<JBH>

<SEC>
<SEC>
<SEC>
<SEC>
<SEC>
<SEC>
<SEC>
<SEC>
<SEC>
<SEC>

<SEC>
<SEC>

I~is[~elp~~to~~~inal

I

~~8:88

H8:88 ~p

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

138.00
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
138.00
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

~~8:88

~~8:88 ~p

8

H
H
SP
H
H
SP
SP
H
H
SP
SP
H
H
H
H
H
SP
H
H
SP
H
SP
H
H
H
H
H
H
H
H
H

Page 422.9

0.15
0.03
11.20
0.06
1.83
0.76
0.47
6.92
3.85
0.67
2.59
0.26

0

2

0

1.50

2

0

1
1

0.26
35.31
10.20
2.24
3.87
24.03
0.48
12.87
0.12
1.50
0.01
0.01
7.56
22.48
6.46
0.06
0.04
7.53

0

1

0

0

1
1

0

1

0

1

0

1

0

1

0

1
1

0
0
0

0
0
0
0

1
1

1
1
1

0

1

0

1

0

1

0

1

0

2

0

0

1
1
1

0

2

0

2

0

1
1
1

0

0
0

8
TOTAL

FORM NO. 1 (ED. 12-87)

I

 N9me of Respondent
Florida Power & L1ght Company

This Report Is:
Date of Report
Year of Report
(Mo, Oa, Yr)
(1) [Xl An Or1ginal
( 2) [ A Resuemi ss ion
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more trans respondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

Siz.e of
Conductor
and Material
( i)
ACSRAZ
~~~ ACSRAIJ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAIJ
1431 ACSRAZ
2-5568 ACSRAZ
1431 ACSRAIJ
1431 ACSRAZ
1431 ACSRAIJ
1431 ACSRAZ
1431 ACSRAIJ
1431 ACSRAZ
2-5568 ACSRAZ
1431 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
2-1780 ACSRSD
2-1780 ACSRSD
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAIJ
1431 ACSRAZ
1431 ACSRAZ
ACS RAZ
ACSRAIJ

I

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

(l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

Total
Expenses

Line
No.

(p)

~
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

~~

1H1

FERC FORM NO. 1 (EO . 12-87)

I

36
Page 423.9

 Year of Report
Date of Report
This Report Is:.
(Mo, Da, Yr)
( 1) [Xl An Or 1g 1na l
Dec. 31, 1996
(2) [ A Resuemission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support·
1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
by the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission line of a different type of construction need not
transmission lines below these voltages in group totals only
be distinguished from the remainder of the line.
for each voltage.
6. Report in columns (f)and(g) the total pole miles of each
2. Transmission lines include all lines covered by the
transmission line. Show in column (f) the pole miles of line
definition of transmission system plant as given in the Union structures the cost of which is reported for the line desiform System of Accounts. Do not report substation costs and
gnated; conversely, show in column (g) the pole miles of line
expenses on this page.
on structures the cost of which is reported for another line.
3. Report data by individual lines for all voltages if so
Report pole miles of line on leased or partly owned strurequired by a State commission.
ctures in column (g). In a footnote, explain the basis of
4. Exclude from this page any transmission lines for which
plant costs are included in Account 121, Nonutility Property.
such occupancy and state whether expenses with respect to
5.Indicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
ed in column(e) is:(1) single pole,wood or steel;(2) H-frame,
line designated.
wood, or steel poles; (3) tower; or (4) underground construeLENGTH (Pole miles)
VOLTAGE (KV)
(I nd1 cate wliere
Type of
DES! GNAT! ON
(In the case 9f
Number
undergrovnd ~1nes
other than
Supporting
60 cycle,3 phase)
report c1rcu1t m1!es)
of
Liner-----------------------,------------------------+----~--.-~--~
Operating Designed Structure
0~ Structure 0~ Structures Circuits
ot ~1ne
ot Another
No.
From
To
Des1g~ated
Line
N9me of Respondent
Florida Power & L1ght Company

(a)

1
2
3
4
5
6
7
8
9
10
11
12
13

ALICO
CORBETT
CORBETT
CORBETT
CORBETT
CORBETT
CORBETT
ALICO
ALICO
ALICO
CHARLOTTE
CALUSA
CALUSA
CALUSA
CALUSA
CALUSA
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
FM PLANT STRING BUS
FM PLANT STRING BUS
LAURELWOOD

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)

I

I

(b)

ORANGE RIVER
ORANGE RIVER
ORANGE RIVER
ORANGE RIVER
ORANGE RIVER
ORANGE RIVER
ORANGE RIVER
COLLIER
COLLIER
COLLIER
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
CHARLOTTE
CHARLOTTE
RINGLING
RINGLING
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
LAUREL WOOD
LAUREL WOOD
LAUREL WOOD
LAUREL WOOD
LAUREL WOOD
LAURELWOOD
WHIDDEN
WHIDDEN
WHIDDEN
WHIDDEN
FM GT SITE
FM GT SITE
MYAKKA

NO 1

NO
NO
NO
NO

2
2
2
2

(C)

(d)

~~8:88

~~8:88 ~

230.00
230.00
230.00
230.00
230.00
230.00
23D.OD
23D.OO
230.00
230.0D
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.DO
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00
230.00

230.00
230.DO
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

~~8:88

~~8:88 ~~

(e)

H
H
H
H
SP
SP
H
H
H
H
H
H
H
H
H
H
H
H
SP
SP
H
H
H
H
SP
SP
H
H
H
SP
SP

(h)

85.3~

6.56

~

0.91

0

0

0
0

0.24
1.98
2.50

2.40
0.31

0

1
2
2
2
2
1
2
2
1
1
1
1

0
0

0

4.82
22.48

22.21
0.07
0.16
1.35
0.07
20.63
40.68
4.95
2.47
20.18
0.05
0.03
0.07
0.06
1.36
30.71
0.10
0.03

0

22.13

0

5.26
1.05
0.08
0.32

0
0
0
0

0
0
0
0
0
0
0

1
1
1
2

1
1
1

0

1

0

1
1

0

0

0
0

1
1
1
1
1

0

1

0

1
1
1

0
0

8
TOTAL

Page 422.10

(g)

(f)

 of Respondent
Florida Power & L1ght Company

N~me

This Report Il>:.
Date of Report
Year of Report
(Mo, Da, Yr)
(1) (Xl An Or1g1nal
(2) ( A ResufJmission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
respondent operates or shares in the operation of, furnish a
7. Do not report the same transmission line structure twice.
succinct statement explaining the arrangement and giving
Report lower voltage lines and higher voltage lines as one
particulars (details) of such matters as percent ownership by
line. Designate in a footnote if you do not include lower
respondent in the line, name of co-owner, basis of sharing
voltage lines with higher voltage lines. If two or more transexpenses of the line,and how the expenses borne by the responmission line structures support lines of the same voltage,
dent are accounted for, and accounts affected.Specify whether
report the pole miles of the primary structure in column (f)
lessor, co-owner, or other party is an associated company.
and the pole miles of the other line(s) in column (g).
9. Designate any transmission line leased to another company
B. Designate any transmission line or portion thereof for
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
for year, and how determined. Specify whether lessee is an
is leased from another company, give name of lessor, date and
associated company.
terms of lease, and amount of rent for year. For any transmi10. Base the plant cost figures called for in columns (j) to
ssion line other than a leased line, or portion thereof, for
(l) on the book cost at end of year.
which the respondent is not the sole owner but which the

Siz.e of
Conductor
and Mater1 a l
(i)

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

I

I

(k)

(l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
EXpenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

Total
Expenses

Line
No.

(p)

1

~~~1

ACSRAZ
ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
1431 ACSRTW
954 ACSRAZ
1431 ACSRAW
1431 ACSRAW
1431 ACSRAZ
954 ACSRAZ
2-5568 ACSRAZ
2-556B ACSRAZ
2-5568 ACSRAZ
2-5568 ACSRAZ
2-5568 ACSRAZ
954 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAW
1431 ACSRAZ
1431 ACSRAZ
795 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
2-1431 ACSRAZ
1431 ACSRAW
FERC FORM NO. 1 (ED. 12-87)

I

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

~~
36
Page 423.10

 N~me

of Respondent
Florida Power & L1ght Company

Date of Report
(Mo, Da, Yr)

I

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 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.
S.lndicate 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 construe-

Type of
Supporting
Structure

Line~----------------------,------------------------+~~c~y~c~e~,~ph~a~s~e~)
No.

From

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
FERC

LAURELIIOOO
LAURELIIOOD
LAURELIIOOD
LAURELIIOOD
LAURELIIOOD
HOIIARD
HOIIARD
HOIIARD
HOIIARD
HOIIARD
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
HOIIARD
HOIIARD
HOIIARD
HOIIARD
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
KEENTOIIN
KEENTOIIN
JOHNSON
JOHNSON
JOHNSON
MANATEE
MANATEE
MANATEE
MANATEE
MANATEE
MANATEE
MANATEE

(a)

To

Operating Designed
(C)

(b)

MYAKKA
RINGLING NO 1
RINGLING NO 1
RINGLING NO 2
RINGLING NO 2
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
ORANGE RIVER NO
ORANGE RIVER NO
ORANGE RIVER NO
ORANGE RIVER NO
ORANGE RIVER NO
LAURELIIOOO
LAURELIIOOD
LAURELIIOOO
LAURELIIOOO
ORANGE RIVER NO
ORANGE RIVER NO
ORANGE RIVER NO
ORANGE RIVER NO
MANATEE
IIH lODEN
MANATEE PLANT
MANATEE PLANT
MANATEE PLANT
RINGLING NO 2
RINGLING NO 2
RINGLING NO 2
RINGLING NO 3
RINGLING NO 3
RINGLING NO 3
RINGLING NO 3

1
1
1
1
1

2
2
2
2

(e)

(d)

~~8:88

~~8:88 ~p

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
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

~~8:88

~~8:88 ~p

Page 422.11

LENGTH (Pole miles)
Number
(In the case of
undergrovnd ~1nes
report c 1rcu1 t md es)
of
Oo Structure Oo Structures Circuits
of ~1ne
ot Another
Des1~~~ted
Line(g)
(h)

8

SP
SP
H
H
H
SP
SP
SP
H
H
H
H
H
H
SP
H
SP
H
H
H
SP
H
H
H
H
H
H
H
H
H
H

0

1.35

1
1
2

0.11
0.01
4.31
3.09
0.58
0.04
0.16
0.15
0.24
1.98
0.39
10.22
3.58
0.32
0.10
0.29
2.11
0.15
19.25
37.34
16.92

0

1

0

0.10
0.80

2

24.01
0.03
1.62
0.04
1.59

0
0

1
1

0

2

0

1
1

22:8~

8

0.06
19.78

0

0

TOTAL
FORM NO . 1 (ED. 12-87)

Year of Report
Dec. 31, 1996

tion. 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.

VOLTAGE (KV)
(lnd1cate wliere
Zbher tha~

DESIGNATION

I

0

0

1

0

1

0

1

0

2

0

1
1

0

0

1
2
2
1
1

0

2

0

2

0

1
1

0
0
0
0

0
0

1

0

1

0

1

0

1
1

0

0

2

 N~me of Respondent
Florida Power & L1ght Company

This Report Is:
Date of Report
Year of Report
(1) [Xl An Or1ginal
(Mo, Da, Yr)
(2) [ A Resuflmission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage l ines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

Siae of
Con uctor l
and Mater1a
( i)
ACSRAZ
ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAII
1431 ACSRTII
1431 ACSRAII
1431 ACSRTII
1431 ACSRTII
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
1431 ACSRTII
1431 ACSRTII
1431 ACSRAII
1431 ACSRTII
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2- 1431 ACSRAZ
ACSRAZ
~=1z~ 1 ACSRAZ

I

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Construction and
Total Cost
Land
Other Costs
(j)

(k)

(l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

FERC FORM NO. 1 (ED. 12-87)

Total
Expenses

Line
No.

(p)

1

1H1

,_.

I

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

~~
36
Page 423. 11

 Name of Respondent
Florida Power & L1ght Company

I

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 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; (5) tower; or (4) underground construeDESIGNATION
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
35
36
FERC

From

To

(a)

(b)

MANATEE PLANT
MANATEE PLANT
MANATEE PLANT
MANATEE PLANT
MANATEE PLANT
MANATEE PLANT
MANATEE PLANT
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
FLORIDA CITY
FLORIDA CITY
FLORIDA CITY
FLORIDA CITY
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER

BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
JOHNSON
JOHNSON
JOHNSON
JOHNSON
JOHNSON
JOHNSON
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
BIG BEND PLANT <TEC>
JEWFISH CK NO 1<FKE>
JEWFISH CK NO 1<FKE>
JEWFISH CK NO 1<FKE>
JEWFISH CK NO 1<FKE>
DAVIS NO 1
DAVIS NO 1
DAVIS NO 1
DAVIS NO 1
DAVIS NO 1
DAVIS NO 1
DAVIS NO 2

tion. If a transmission line has more than one type of support ing structure, indicate the mileage of each type of cons truction
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 stru ctures 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.

VOLTAGE (KV)
(lnd1cate wnere
other thao
60 cycle,5 phase)
Operating Designed
(c)

Type of
Supporting
Structure
(e)

(d)

~~8:88

~~8:88 ~

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
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00

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
138.00
138.00
138.00
230.00
138.00
138.00
138.00
230.00
230.00

(h)

(g)

(f)

0.20
0.18
12.97
0.12
9.86

0
0
0

8.73

0

0.04
0.10
0.07
0.80
0.04
0.44
0.01
0.54
0.21
6.25
16.48
0.15
8.43
0.47
0.12
3.81
0.02
0.06
12.86

HB:88 HR:88 ~
Page 422 . 12

LENGTH (Pole miles)
Number
(In the case 9f
underground ~1nes
of
report c1rcu1t m1les)
On Structure On Structures Circuits
of llne
of Another
Des1gnated
Line

8

H
H
H
H
SP
H
H
SP
H
H
SP
H
H
H
H
H
H
SP
SP
SP
SP
SP
H
H
SP
SP
H
H
SP
H
H
TOTAL

FORM NO. 1 (ED. 12-87)

Year of Report
Dec. 31, 1996

Date of Re~ort
(Mo, Da, Y )

0

0
0

0
0
0
0
0

0
0

0
0
0
0
0
0

0
0
0
0

1
1
1
1
1
1
1

1
2
2
2
1
1
1
1
1
1
1

1
1
1

0

1
1
1
1

0

0.75

2

3.57
0.25
0.08
0.38
0.03

0

1

0
0

1
1

0

1

0

1

3.58

2.6g

 N~me

of Respondent
Florida Power & L1ght Company

I

This Report Is:
~~~ fXi ~nR~~~~n~!i on

I

Dat e of Report
(Mo, Da, Yr)

I

Year of Report

-----L----------------~----D_e_c_.__3_1~,__
19_9_6______~
TRANSMISSION LINE STATISTICS (Cont i • ed)
7. Do not report the same transmission line structure twice.
responden operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
Jccinct
1tement explaining the arrangement and giving
line. Desi gnate in a footnote if you do not include lower
particula r , details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more trans ·
responden t in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
for year, and how determined. Specify whether lessee is an
is leased from another company, give name of lessor, date and
associated company.
terms of lease, and amount of rent for year. For any transmi10. Base the plant cost figures called for in columns (j) to
ssion line other than a leased line, or portion thereof, for
(l) on the book cost at end of year.
which the respondent is not the sole owner but which the

Siae of
Con uctor
and Material

~

( i)
ACSRAZ
~=~~~ ACSRAZ
2-795 ACSRAZ
2-795 ACSRAZ
2-795 ACSRAZ
2-1431 ACSRAZ
2-795 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-1431 ACSRAZ
2-795 ACSRA\.1
954 ACSRA\.1
2-3368 ACSRAZ
954 ACSRAZ
2-3368 ACSRAZ
954 ACSRAZ
2-3368 ACSRAZ
954 ACSRAZ
954 ACSRA\.1
954 ACSRAZ
1431 ACSRAZ
2-3368 ACSRAZ
1127 AAAC
1127 AAAC
1127 AAAC
1127 AAAC
350 CUHT
556.5 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
~~~1

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Total Cost
Construction and
Land
Other Costs
(j)

(k)

(l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(o)

Line
No.

(p)

~
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

~~

ACSRAZ
CUHT

FERC FORM NO. 1 (ED. 12-87)

Total
Expenses

36
Page 423.12

 N9me of Respondent
Florida Power & L1ght Company

I

I

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 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 construe-

<a>
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
FLORIDA CITY
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER
CUTLER

Type of
Supporting
Structure

g0

(c)

(b)

DAVIS NO 2
DAVIS NO 2
DAVIS NO 2
DAVIS NO 4
DAVIS NO 4
DAVIS NO 4
DAVIS NO 4
DAVIS NO 4
DAVIS NO 4
DAVIS NO 4
DAVIS NO 4
PERRINE RADIAL
PERRINE RADIAL
PERRINE RADIAL
PERRINE RADIAL
PERRINE RADIAL
PERRINE RADIAL
PERRINE RADIAL
PERRINE RADIAL
PERRINE RADIAL
PERRINE RADIAL
PERRINE RADIAL
TAVERNIER
SOUTH MIAMI NO
SOUTH MIAMI NO
SOUTH MIAMI NO
SOUTH MIAMI NO
SOUTH MIAMI NO
SOUTH MIAMI NO
SOUTH MIAMI NO
SOUTH MIAMI NO
SOUTH MIAMI NO
SOUTH MIAMI NO
SOUTH MIAMI NO
SOUTH MIAMI NO

(e)

(d)

HB:88 HS:88

<FKE>
1
1
1
2
2
2
2
2
2
2
2
2

H
SP
SP
SP
SP
SP
SP
H
H
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
SP
SP
UG
SP
SP
SP
SP
SP
SP
SP
SP
SP

HB:88 HB:88

~~

Page 422.13

LENGTH (Pole miles)
Number
(In the case llf
undergrovnd ~1nes
of
report c1rcu1t m1les)
OQ Structure OQ Structures Circuits
of Llne
of Another
DeslgQated
Line
(h)

(g)

(f)

8

~

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
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
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

0

2. 71

0.13
0.05
0.22
0.19
4.33
2.01
1.09

0

0

0.38
0.66
0.16
1.07
3.22
0.73
0.60
2.18
0.78
0.15
0.80
15.70
0.78
1.44
6.09
0.15
3.84
0.33
1.00
0.04
0. 12
7.30

8:5~
TOTAL

FORM NO. 1 (ED. 12-87)

I

line designated.

VOLTAGE (KV)
wliere
her fha~
Line~----------------------.------------------------+----c~y_c__e~·~p_h~a~s_e~)
No.
From
To
Operating Designed
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
FERC

Year of Report
Dec. 31, 1996

tion. 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

(I nd1 cate

DESIGNATION

Date of Report
(Mo, Da, Yr)

0

2
1
1
1

0

1

0

0

1

0

1

0
0.17

0

2
3
1
1
1
1
1
1
1
1
1
2

0

2

0
0
0
0
0
0

0
0

0

0

1

0

1
1

0
0

1

0

1

0

1
1
1

0
0
0

1

0

1

0

1

8

 N~me of Respondent
Florida Power & L1ght Company

l

Year of Report
This Report Is: .
Date of Report
(Mo, Da, Yr)
(1) [Xl An Or1g1nal
Dec . 31, 1996
(2) [ A Resuflmission
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
succinct statement explaining the arrangement and giving
Report lower voltage lines and higher voltage lines as one
particulars (details) of such matters as percent ownership by
line. Designate in a footnote if you do not include lower
respondent in the line, name of co-owner, basis of sharing
voltage lines with higher voltage lines. If two or more transexpenses of the line,and how the expenses borne by the responmission line structures support lines of the same voltage,
dent are accounted for, and accounts affected.Specify whether
report the pole miles of the primary structure in column (f)
lessor, co-owner, or other party is an associated company.
and the pole miles of the other line(s) in column (g).
9. Designate any transmission line leased to another company
8. Designate any transmission line or portion thereof for
and give name of lessee, date and terms of lease, annual rent
which the respondent is not the sole owner. If such property
for year, and how determined. Specify whether lessee is an
is leased from another company, give name of lessor, date and
associated
company.
terms of lease, and amount of rent for year. For any transmi10.
Base
the
plant cost figures called for in columns (j) to
ssion line other than a leased line, or portion thereof, for
(l) on the book cost at end of year.
which the respondent is not the sole owner but which the

Siz.e of
Conductor
and Mater1al
( i)

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
EXpenses

Maintenance
Expenses

Rents

(m)

(n)

(o)

Line
No.

(p)

~

n~l5 ACSRAZ

ACSRAZ
1431 ACSRAZ
600 CUHT
954 ACSRAZ
954 ACSRA'ol
600 CUHT
795 AA
954 ACSRAZ
954 ACSRAZ
600 CUHT
336.4 ACSRAZ
795 ACSRA'ol
954 ACSRAZ
954 ACSRAZ
336.4 ACSRAZ
556.5 ACSRA'ol
795 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRA'ol
2000 cu
954 ACSRAZ
954 ACSRAZ
600 CUHT
954 ACSRAZ
954 ACSRA'ol
954 ACSRAZ
954 ACSRA'ol
600 CUHT
954 ACSRAZ
ACSRAZ
¢~z ACSRA'ol
FERC FORM NO. 1 (ED. 12-87)

Total
Expenses

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

~~
36
Page 423.13

 N~me

of Respondent
Florida Power & L1ght Company

I

I

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 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 construe-

Type of
Supporting
Structure

g0

Line~----------------------,------------------------+~~c~y~c~e~,~~ph~a~se~)~
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
36
FERC

CUTLER
CUTLER
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
COCONUT GROVE
COCONUT GROVE
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS

To
(b)

SOUTH MIAMI NO 2
SOUTH MIAMI NO 2
SOUTH MIAMI
SOUTH MIAMI
SOUTH MIAMI
SOUTH MIAMI
SOUTH MIAMI
SOUTH MIAMI
SOUTH MIAMI
SOUTH MIAMI
FLORIDA CITY NO 1
FLORIDA CITY NO 1
FLORIDA CITY NO 1
FLORIDA CITY NO 1
FLORIDA CITY NO 1
FLORIDA CITY NO 1
FLORIDA CITY NO 1
FLORIDA CITY NO 1
FLORIDA CITY NO 1
FLORIDA CITY NO 1
FLORIDA CITY NO 1
FLORIDA CITY NO 1
AVOCADO RADIAL
AVOCADO .RADIAL
AVOCADO RADIAL
LUCY ST
<HST>
LUCY ST
<HST>
LUCY ST
<HST>
<HST>
LUCY ST
<HST>
LUCY ST
<HST>
LUCY ST
<HST>
LUCY ST
<HST>
LUCY ST
<HST>
LUCY ST
<HST>
LUCY ST

Operating Designed
(c)

(d)

(e)

LENGTH (Pole miles)
Number
(In the case 9f
undergrovnd 11nes
report c1rcu1t m1les>
of
Oo Structure Oo Structures Circuits
of ~1ne
ot .Another
Des1~?~ted
L1ne(g)
(h)

H~:88

HS:88

~p

B:lr

8

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
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
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

SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
SP
SP
SP
UG
SP
SP
H
SP
SP
SP
SP
SP
SP
SP

0.89
0.09
5.29

0

0

0.44
0.03
1.42

H~:88

~~8:88 ~

0

0.08
1.49
1.51
0.09
0.41
12.95
1.23
1.79
8.89
0.99
0.04

Page 422.14

0
0

1
1
1
2
2
2

0

1

0

1
1
1
1
1

0

0
0
0
0

1

0

1
1

0

0

1
2

0

0.15
0.80

0.67

0

2

0

TOTAL
FORM NO. 1 (ED. 12-87)

Year of Report
Dec. 31, 1996

I

tion. 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 stru ctures 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.

VOLTAGE (KV)
(lnd1cate wliere
her fha~

DESIGNATION

Date of Report
(Mo, Da, Yr)

2

0

0.66

2

0.30
12.03

0
0

1
1

0

1. 79

2

0.16
0.09
1.79
0.11
4.71
0.03
3.77
4.05

0

1
1
1

0.1~

o.58

0
0
0

1

0

0

1
1

0

1

0

1

 N9me of Respondent
Florida Power & L1ght Company

.---

r-

This Report Is:
Date of Report
Year of Report
(1) [XJ An Or1ginal
(Mo, Da, Yr>
(2) [
A Resuemission
Dec.
31, 1996
1
1
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
9. Designate any transmission line leased to another company
8. Designate any transmission line or portion thereof for
which the respondent is not the sole owner_ If such property and give name of lessee, date and terms of lease, annual rent
for year, and how determined. Specify whether lessee is an
is leased from another company, give name of lessor, date and
associated company.
terms of lease, and amount of rent for year. For any transmi10. Base the plant cost figures called for in columns (j) to
ssion line other than a leased line, or portion thereof, for
(l) on the book cost at end of year.
which the respondent is not the sole owner but which the

Siz.e of
Conductor
and Material
( i)

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
EXpenses

Maintenance
Expenses

Rents

(m)

(n)

(o)

Line
No.

(p)

~

600 CUHT
954 ACSRAII
954 ACSRAZ
954 ACSRAII
954 ACSRAZ
954 ACSRAZ
954 ACSRAII
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
336.4 ACSRAZ
795 AA
954 ACSRAZ
954 ACSRAII
954 ACSRAZ
336.4 ACSRAZ
795 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
336.4 ACSRAZ
795 ACSRAZ
2500 cu
954 ACSRAII
954 ACSRAII
954 ACSRAII
795 ACSRAZ
954 ACSRAZ
954 ACSRAII
795 AA
795 ACSRAZ
795 ACSRAII
954 ACSRAZ
ACSRAII
ACSRAIJ
FERC FORM NO. 1 (ED. 12-87)

Total
Expenses

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

~~
36
Page 423.14

 Year of Report
Date of Report
This Report Is: .
(Mo, Da, Yr)
(1) [X] An Or1g1nal
Dec
. 31, 1996
(2) [ l A Resucmission
\
\
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
by
the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission
line of a different type of construction need not
transmission lines below these voltages in group totals only
be
distinguished
from the remainder of the line.
for each voltage.
6.
Report
in
columns
(f)and(g) the total pole miles of each
2. Transmission lines include all lines covered by the
transmission line. Show in column (f) the pole miles of line
definition of transmission system plant as given in the Union structures the cost of which is reported for the line desiform System of Accounts. Do not report substation costs and
gnated; conversely, show in column (g) the pole miles of line
expenses on this page.
on structures the cost of which is reported for another line.
3. Report data by individual lines for all voltages if so
Report pole miles of line on leased or partly owned strurequired by a State commission.
ctures
in column (g). In a footnote, explain the basis of
4. Exclude from this page any transmission lines for which
such
occupancy
and state whether expenses with respect to
plant costs are included in Account 121, Nonutility Property.
such
structures
are
included in the expenses reported for the
5.Indicate whether the type of supporting structure reportline designated.
ed in column(e) is:(1) single pole,wood or steel;(2) H-frame,
wood, or steel poles; (3) tower; or (4) underground construeLENGTH (Pole miles)
VOLTAGE (KV)
Number
(In the case 9t
Type of
(!nd1cate wtiere
DESIGNATION
undergrovnd ~1nes
Qther thao
of
report c1rcu1t m1!es)
Supporting
Line------------------------.------------------------+~b~O~c~y~c~le~·~3~p~h~as~e~)~
On Structure On Structures Circuits
Structure
No.
From
·
To
Operating Designed
of ~1ne
of Another
Des1gnated
Line
of Respondent
Florida Power & L1ght Company

N~me

(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

FLORIDA
FLORIDA
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
DAVIS
COCONUT
COCONUT
COCONUT
COCONUT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
AIRPORT
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI

CITY
CITY

GROVE
GROVE
GROVE
GROVE

36
FERC FORM NO. 1 (ED. 12-87)

I

(C)

(b)

LUCY ST
LUCY ST
FLAGAMI NO 3
FLAGAMI NO 3
FLAGAMI NO 3
FLAGAMI NO 3
FLAGAMI NO 3
FLAGAMI NO 3
FLAGAMI NO 3
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
RIVERSIDE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
RIVERSIDE NO
RIVERSIDE NO
RIVERSIDE NO
RIVERSIDE NO
RIVERSIDE NO

<HST>
<HST>

1
1
1
1
1

(e)

(d)

~~g:88

~~g:88 ~~

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
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
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

8
1.94
2.60
0.02
1.13
7.08
0
0.18
3.95
2.04
0.04
0.04
0.07
2.54
0.04
1.36
0.37

SP
SP
SP
SP
SP
H
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
SP

0

0.22
0.07
0.05
1.38
0.34
0.64
0.29
0.77
0
0
0

0.94
0.10
2.80

Hg:88 HS:88 ~~

0

1
1
1
1
1
2
2
1
1
1

0.04

2

0

1
1

0

0
0
0
0

1.09
0.18
0
0

0
0

1

0

1
1
2

0

0.14
0

1
1

0

1

0

1

0

0

1

0

1

0

1

0

1

0.15
0.30
0.11

2

2
2

0

1
1

0

1

0

8
TOTAL

Page 422.15

(h)

(g)

(f)

 of Respondent
Florida Power & L1ght Company

Date of Report
Year of Repo r t
This Report Is: .
(Mo, Da, Yr)
(1) [Xl An Or1g1nal
Dec. 31, 1996
(2) [ A ResuDinission
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and g1v1ng
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the respondent are accounted for, and accounts affected.Specify whether
report the pole miles of the primary structure in column (f)
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

N~me

SMJe of
Co uctor
and Mater1al

,.._
( i)
ACSRAZ
t~~ AA
954 ACSRAZ
954 ACSRA\.1
795 AA
795 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
795 ACSRAZ
795 ACSRAZ
954 ACSRAZ
795 ACSRAZ
954 ACSRAZ
954 ACSRAZ
350 CUHT
556.5 ACSRAZ
954 ACSRAZ
556.5 ACSRAZ
795 AA
556.5 ACSRAZ
954 ACSRAZ
556.5 ACSRAZ
600 CUHT
795 AA
795 ACSRAZ
954 ACSRAZ
795 AA
795 AA
795 ACSRAZ
954 ACSRAZ
954 ACSRA\.1
954 ACSRAZ
954 ACSRAZ
95 4 ACSRAZ

j

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

i

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

<m>

(n)

(o)

Total
Expenses

Line
No.

(p)

~
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
3D
31
32
33

~~
36

FERC FORM NO. 1 (ED. 12-87)

Page 423.15

 Date of Report
Year of Report
This Report Is:
(Mo, Da, Yr)
(1) [XJ An Or1ginal
Dec. 31, 1996
(2) [ A ResuElmission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support 1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
by the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission line of a different type of construction need not
transmission lines below these voltages in group totals only
be distinguished from the remainder of the line.
for each voltage.
6. Report in columns (f)and(g) the total pole miles of each
2. Transmission lines include all lines covered by the
definition of transmission system plant as given in the Uni·
transmission line. Show in column (f) the pole miles of line
on structures the cost of which is reported for the line desiform System of Accounts. Do not report substation costs and
gnated; conversely, show in column (g) the pole miles of line
expenses on this page.
3. Report data by individual lines for all voltages if so
on structures the cost of which is reported for another line.
required by a State commission.
Report pole miles of line on leased or partly owned stru4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
plant costs are included in Account 121, Nonutility Property.
such occupancy and state whether expenses with respect to
5.Indicate whether the type of supporting structure report such structures are included in the expenses reported for the
ed in column(~) is:(1) single pole,wood or steel;(2) H-frame,
line designated.
wood, or steel poles; (3) tower; or (4) underground construeVOLTAGE (KV)
LENGTH (Pole miles)
(lnd1cate where
Type of
DESIGNATION
(In the case 9t
Number
undergrovnd 11nes
other than
6D cycle,3 phase)
Supporting
report c1rcu1t m1les)
of
Line
Operating Designed Structure
0~ Structure 0~ Structures Circuits
No.
From
To
of l1ne
of Another
Des1g~ated
Line
Name of Respondent
Florida Power & L1ght Company

(a)

(b)

FLAGAMI
FLAGAMI
FLAGAMI
MIAMI
MIAMI
MIAMI
COCONUT GROVE
MIAMI
MIAMI
MIAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
FLAGAMI
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE

RIVERSIDE NO 2
RIVERSIDE NO 2
RIVERSIDE NO 2
RIVERSIDE
RIVERSIDE
RIVERSIDE
MIAMI PLANT
MIAMI BEACH
MIAMI BEACH
MIAMI BEACH
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
GRATIGNY NO 1
GRATIGNY NO 1
GRATIGNY NO 1
GRATIGNY NO 1
GRATIGNY NO 1
GRATIGNY NO 2
GRATIGNY NO 2
GRATIGNY NO 2
GRATIGNY NO 2
GRA TI GNY NO 2
GRATIGNY NO 2
GRATIGNY NO 2
GRATIGNY NO 2
GRATIGNY NO 2
LITTLE RIVER

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
FERC FORM NO. 1 (EO. 12-87)

l

I

(c)

(e)

(d)

H~:88

H~:88 ~~

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
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
230.00
230.00
138.00
138.00
138.00
230.00
230.00
138.00
138.00
138.00
138.00
138.00
138. DO
138. DO
230.00

SP
UG
SP
SP
UG
UG
UG
UG
H
UG
SP
SP
SP
SP
SP
SP
H
H
H
SP
SP
SP
H
SP
SP
SP
SP
SP
SP
SP
SP

H~:88

Hg:88

~

(f)

(g)

(h)

8
1.42
2.65
3.21
0.06
4.97
0.25
5.16
5. 75
0.51
0.38
0.64
2.89
0.40
0.06
2.08
0.23
0.01
0.04
0.92
2.09
0.03
0.29

0.08

2

0
0

1
1

0

2

0

1
1

0

0.43

0.85
4.25

0

2. 73

0

2.13
0.76
0.15
0.26
0.71

0

0.1g
TOTAL

Page 422.16

I

0

0

1
1
1
1
1

0

1

0

1
1
1

0
0
0
0

0
0
0
0
0

0

2
1
1
1

0

1

0

1
1

0

0

2
1
1
1

0

1
1
1

0.26

2

0

1

0

0.4~

 Year of Report
Date of Report
This Report Is:
(Mo, Da, Yr)
(1) [Xl An Or1ginal .
Dec.
31, 1996
(2) [ A ResuOmiSSlOn
I
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and g1v1ng
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
B. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property
and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

N9me of Respondent
Florida Power & L1ght Company

Siz.e of
Conductor
and Material

,......

( i)
ACSRAZ
g~~ ACSRAZ
954 ACSRAZ
2000 cu
954 ACSRAZ
954 ACSRAZ
700 cu
1250 cu
1500 cu
2000 cu
954 ACSRAZ
2000 cu
795 ACSRAZ
954 ACSRAZ
954 ACSRAI.I
954 ACSRAI.I
795 ACSRAZ
954 ACSRAI.I
795 ACSRAZ
1431 ACSRAZ
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
600 CUHT
954 ACSRAZ
954 ACSRAZ
600 CUHT
795 AA
795 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
600 CUHT

I

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

Total
Expenses

Line
No.

(p)

1
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

~~
36

FERC FORM NO. 1 (ED. 12-87)

Page 423.16

 I

I

Year of Report
This Report Is:.
Date of Report
(Mo, Da, Yr)
( 1) [XJ An Or 1g1na l
Dec. 31, 1996
(2) [ A Resuomission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
having nominal voltage of 132 kilovolts or greater. Report
by the use of brackets and extra lines. Minor portions of a
transmission lines below these voltages in group totals only
transmission line of a different type of construction need not
for each voltage.
be distinguished from the remainder of the line.
2. Transmission lines include all lines covered by the
6. Report in columns (f)and(g) the total pole miles of each
transmission line. Show in column (f) the pole miles of line
definition of transmission system plant as given in the Union structures the cost of which is reported for the line desiform System of Accounts. Do not report substation costs and
gnated; conversely, show in column (g) the pole miles of line
expenses on this page.
on structures the cost of which is reported for another line.
3. Report data by individual lines for all voltages if so
Report pole miles of line on leased or partly owned strurequired by a State commission.
ctures in column (g). In a footnote, explain the basis of
4. Exclude from this page any transmission lines for which
such occupancy and state whether expenses with respect to
plant costs are included in Account 121, Nonutility Property.
5.Indicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
line designated.
ed in column(e) is:(1) single pole,wood or steel;(2) H-frame,
wood, or steel poles; (5) tower; or (4) underground construeVOLTAGE (KV)
LENGTH (Pole miles)
(Ind1cate wliere
Type of
DESIGNATION
(In the case 9f
Number
undergrovnd 11nes
other fhao
60 eye e,5 phase)
report c1rcu1t m1les)
of
Supporting
Line~----------------------.------------------------+~--~--~~--~
Operating Designed Structure
OQ Structure OQ Structures Circuits
No.
From
To
of l1ne
of Another
Des1gQated
Line
of Respondent
Florida Power & L1ght Company

N~me

(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
36
FERC

DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
DADE
LITTLE
LITTLE
LITTLE
LITTLE
LITTLE
LITTLE
LITTLE
MARKET
MARKET
MARKET
MARKET
MIAMI
MIAMI

RIVER
RIVER
RIVER
RIVER
RIVER
RIVER
RIVER

I

(b)

LITTLE RIVER
Ll TTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
Ll TTLE RIVER
LITTLE RIVER
Ll TTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
MARKET
MARKET
MARKET
MARKET
MARKET
MARKET
MARKET
RAILIJAY
RAI LIJAY
RAILIJAY
RAILIJAY
RAILIJAY NO 1
RAI LIJAY NO 2

NO
NO
NO
NO
NO
NO
NO
NO
NO
NO

(C)

3
3
3
3
3
3
3
3
3
3

(e)

(d)

(h)

HR:88 HR:88

~p

8:8s

8

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
138.00
138.00
138.00
138.00
138.00
138.00
138.00

SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
H
H
SP
SP
SP
SP
SP
SP
SP
H
SP
SP
UG
SP
SP
SP

0.48
0.67
0.13
0.02
4.89
0.90
2.73
0.13

0

1

0

1

0

1

0

1
1

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
138.00
138.00
138.00
138.00
138.00
138.00
138.00

0

0.11
0.05
0.76
0.20
4.49
2.88
0.22
0.15
0.27
0.27
0.41
0.14
0.13
2.99
0.53
0

0
0

0.72
0.02
2.11
0.70

HR:88 HR:88 ug

1J8
TOTAL

FORM NO. 1 (ED. 12-87)

(g)

(f)

Page 422.17

0
0

1

0

1

0

1

0.12

2

0

2

0

1

0

1

0

1
1
1

0

0

0

2
2
2

0
0

2

0

1

0

1

0
0

2

0

1

0

1

0.22
0.27
0.27

2

2
2

0

1

0

1

0

1

0

1

8

 Year of Report
Date of Report
This Report Is:
(Mo, Da, Yr)
(1) [XJ An Or1ginal
(2) [
A Resuflmission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
respondent operates or shares in the operation of, furnish a
7. Do not report the same transmission line structure twice.
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

of Respondent
Florida Power & L1ght Company

N~me

Siz.e of
Conductor
and Material
( i)

I

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

(l)

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(o)

Total
Expenses

Line
No.

(p)

t~s A~~~~oz

~

4/0 cu
266 cu
336.4 ACSRAZ
350 CUHT
600 CUHT
795 AA
795 ACSRAZ
954 ACSRAZ
4/0 cu
795 ACSRAZ
1431 ACSRAZ
4/0 cu
600 CUHT
795 AA
795 ACSRAZ
795 AA
795 ACSRAZ
795 AA
795 AA
795 ACSRAZ
795 AA
954 ACSRAZ
795 AA
795 ACSRAZ
795 AA
795 AA
795 AA
2000 cu
795 ACSRAZ
954 ACSRAZ
954 ACSRAZ

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

1

~~

2888 ~~

36
FERC FORM NO. 1 (ED. 12-87)

Page 423.17

 of Respondent
Florida Power & L1ght Company

N~me

I

I~~s[~elp~~to~~~inal
(2) [ A Resucmission

I

Date of Report
(Mo, Da, Yi')

I

Year of Report
Dec. 31, 1996

TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support 1. Report information concerning transmission lines,cost of
lines, and expenses for year. List each transmission line
ing structure, indicate the mileage of each type of construction
having nominal voltage of 132 kilovolts or greater. Report
by the use of brackets and extra lines. Minor portions of a
transmission lines below these voltages in group totals only
transmission line of a different type of construction need not
for each voltage.
be distinguished from the remainder of the line.
2. Transmission lines include all lines covered by the
6. Report in columns (f)and(g) the total pole miles of each
definition of transmission system plant as given in the Unitransmission line. Show in column (f) the pole miles of line
on structures the cost of which is reported for the line desiform System of Accounts. Do not report substation costs and
gnated; conversely, show in column (g) the pole miles of line
expenses on this page.
3. Report data by individual lines for all voltages if so
on structures the cost of which is reported for another line.
required by a State commission.
Report pole miles of line on leased or partly owned stru4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
plant costs are included in Account 121, Nonutility Property.
such occupancy and state whether expenses with respect to
5.Indicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
ed in column(~) is:(1) single pole,wood or steel;(2) H-frame,
line designated.
wood, or steel poles; (5) tower; or (4) underground construeVOLTAGE CKV)
LENGTH (Pole miles)
(lnd1cate wnere
Type of
DESIGNATION
(In the case 9t
Number
undergrovnd ~1nes
other than
60 cycle,5 phase)
Supporting
report c1 rcu1t mdes)
of
Line
Operating Designed Structure
0~ Structure 0~ Structures Circuits
No.
From
To
0
8esr~~~ted Li~~~:~er
<h>
(a)
(b)
(c)
(d)
(e)

3
4
5
6
7

INDIAN CREEK
INDIAN CREEK
40TH STREET
40TH STREET
GRATIGNY
GRATIGNY
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
ARCH CREEK
ARCH CREEK
ARCH CREEK
ARCH CREEK

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
FERC FORM NO. 1 (ED. 12-87)

LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LITTLE RIVER
LAUDERDALE PLANT
LAUDERDALE PLANT
MIAMI SHORES
MIAMI SHORES
MIAMI SHORES
MIAMI SHORES
MIAMI SHORES
MIAMI SHORES
MIAMI SHORES
MIAMI SHORES
MIAMI SHORES
MIAMI SHORES
MIAMI SHORES
MIAMI SHORES
MIAMI SHORES
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
NORMANDY CABLE
NORMANDY CABLE
GREYNOLDS
GREYNOLDS

8
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
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
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
230.00
230.00
138.00
138.00

UG
UG
H
H
SP
SP
SP
H
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
H
UG
UG

0

0.73

0

0.99
0.26
2.06
1.37
7.44
0.27
0.02
3.00
15.91
2.23
1.91

0

2.73

0.38
0.49
0.49
0.02
0.02

H~:88 ~~

0
0
0
0

0
0
0
0
0

0
0

0
0
0

0

1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
2
1

0

1

0
0
0
0
0

1
1

1
1

0

0.83

1
1
1
2
1
2

1.45
2.34

0

1

0

1

0
0

0.02
0

8
TOTAL

Page 422.18

3.63
2.47
0.03
18.76
0.09
0.67
0. 71
0.80
2.41
0.18

 of Respondent
Florida Power & L1ght Company

N~me

I

This Report 1$:
Date of Report
Year of Report
(1) fXl An Or1ginal
(Mo, Da, Yr)
( 2)
J A Resucmi ss ion
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and g1v1ng
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property
and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

Siz.e of
Conductor
and Material
( i)

~2~~

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
EXpenses

Maintenance
Expenses

Rents

(m)

(n)

(o)

cu

Total
Expenses

Line
No.

(p)

~

ACSRAZ
1250 cu
2000 cu
600 CUHT
795 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
2-3508 CUHT
2-5568 AA
1431 ACSRAZ
1431 ACSRAZ
2-3508 CUHT
2-5568 AA
350 CUHT
1431 ACSRAZ
2-3508 CUHT
2-5568 AA
1431 ACSRAZ
954 ACSRAZ
795 ACSRAZ
954 ACSRAZ
954 ACSRAZ
556.5 AA
556.5 ACSRAZ
795 AA
795 ACSRAZ
954 ACSRAZ
1431 ACSRA Z
1431 ACSRAZ
1431 ACSRAZ
1500 cu
2000 cu

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

~~

~g2oA~~RAZ

36
FERC FORM NO. 1 (ED. 12-87)

Page 423.18

 of Respondent
Florida Power & L1ght Company

N~me

Date of Report
(Mo, Da, Yr)

I

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 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 construe-

Line
No.

To

From

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
FERC

ARCH CREEK
ARCH CREEK
ARCH CREEK
ARCH CREEK
ARCH CREEK
ARCH CREEK
ARCH CREEK
ARCH CREEK
ARCH CREEK
ARCH CREEK
ARCH CREEK
ARCH CREEK
ARCH CREEK
HAULOVER
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS

(C)

(b)

(a)

GREYNOLDS
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
NORMANDY
HAUL OVER
HAUL OVER
HAUL OVER
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE
LAUDERDALE

tion. If a transmission line has more than one type of support·
ing 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.

VOLTAGE (KV)
(lnd1cate where
other thao
bO cycle,3 phase)
Operating Designed

DESIGNATION

Type of
Supporting
Structure
(e)

(d)

H~:88 ~

NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO

1
1
1
1
1
1
1
1
1
2
2
2
2
2
2
2
2
2

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
138.00
138.00
138.0D
138.0D
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
138.00
138.00
230.00
138.00
138.00
138.00
138.0D
138.00
138.00
138.00

H~:88 ~~
Page 422.19

LENGTH (Pole miles)
Number
(In the case ot
undergrovnd ~1nes
of
report c1rcu1t m1les)
On Structure On Structures Circuits
of ~1ne
of Another
Des1gnated
Line
(g)

(f)

2.68
1.02
1.27
2.83
0.34
0.01
0.22
0. 04
0.12
4.13
1.69
1.38
2.00
1.44
0.23
2.38
0.13
0.19
7.07
3.87

UG
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
UG
SP
SP
SP
H
H
SP
SP
SP
H
H
SP
H
UG
SP
SP
SP
SP
SP
SP

(h)

o.os
0

1

0

1

0

1

0

1

0

1

0
0

1
1
1

0

1

0

0

1

1. 70

2

0
0

1
1

0

1

0

1
1

0
0

1
1

0

1

0

1.31

0

1

0.06
1.79
0.14
0.03
1. 76
1.12
0.22
3.26
1.32
0.04
0.41

0

2

0

2

0.15

2

0

1

0

1
1

0

0
0
0
0
0

8
TOTAL

FORM NO. 1 (ED. 12-87)

I

Year of Report
Dec. 31, 1996

1

1

1
1
1

 N~me

of Respondent
Florida Power & L1ght Company

I

This Report Is:
Date of Report
Year of Report
(1) [XJ An Or1ginal
(Mo, Da, Yr)
(2) [ J A ResuDrl1ission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. U such. property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

Siz.e of
Conductor
and Material
( i)

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

(l)

1

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(o)

~~~ 5 ~~s~z

Total
Expenses

Line
No.

(p)

j

2000 cu
954 ACSRAZ
1431 ACSRAZ
1431 ACSRAIJ
1431 ACSRAZ
1431 ACSRAZ
2-5568 AA
1431 ACSRAIJ
954 ACSRAZ
2-5568 AA
1431 ACSRAZ
2000 cu
350 CUHT
556.5 ACSRAIJ
350 CUHT
954 ACSRAZ
1431 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
9DO CUHT
2DOO cu
35D CUHT
795 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAIJ
954 ACSRAZ

14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
3D
31
32
33

~~8 ~~~t

~~

3
4
5
6
7
8
9
10
11
12
13

36
FERC FORM NO. 1 (ED. 12-87)

Page 423.19

 Year of Report
Date of Report
This Report Is: . l
(Mo, Da, Yr)
( 1 ) [Xl An Or 1g1na
Dec.
31, 1996
(2) [ A ResuExnission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
by
the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission
line of a different type of construction need not
transmission lines below these voltages in group totals only
be
distinguished
from the remainder of the line.
for each voltage.
6.
Report
in
columns
(f)and(g) the total pole miles of each
2. Transmission lines include all lines covered by the
transmission line. Show in column (f) the pole miles of line
definition of transmission system plant as given in the Union structures the cost of which is reported for the line desiform System of Accounts. Do not report substation costs and
gnated; conversely, show in column (g) the pole miles of line
expenses on this page.
on structures the cost of which is reported for another line.
3. Report data by individual lines for all voltages if so
Report pole miles of line on leased or partly owned strurequired by a State commission.
ctures in column (g). In a footnote, explain the basis of
4. Exclude from this page any transmission lines for which
such
occupancy and state whether expenses with respect to
plant costs are included in Account 121, Nonutility Property.
such
structures
are included in the expenses reported for the
5.Indicate whether the type of supporting structure reportline
designated.
ed in column(e) is:(1) single pole,wood or steel;(2) H-frame,
wood, or steel poles; (3) tower; or (4) underground construeLENGTH (Pole miles)
VOLTAGE (KV)
Number
Type of
(In the case 9f
(lnd1cate wliere
DESIGNATION
undergrovnd Llnes
g her thao
of
report c1rcu1t m1!es)
Supporting
Liner-----------------------.-----------------------~~~c~y~c~l~e~,5~p~h~a~s~e~)
OQ Structure OQ Structures Circuits
Operating Designed Structure
of ~1ne
of Another
To
From
No.
DeslgQated
Line
of Respondent
Florida Power & L1ght Company

N~me

l

I

I

0

(b)

(a)

1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21

GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
GREYNOLDS
ASHMONT
HOLLYWOOD
HOLLYWOOD
HOLL YWOOO
HOLLYWOOD
HOLLYWOOD
HOLLYWOOD
HOLLYIJOOO
HOLLYWOOD
HOLLYIJOOO
HOLLYWOOD
PORT
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
OAKLAND PARK
OAKLAND PARK
OAKLAND PARK
OAKLAND PARK
OAKLAND PARK
OAKLAND PARK
OAKLAND PARK

PLT
PLT
PLT
PLT
PLT
PLT
PLT
PLT
PLT

22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
FERC FORM NO. 1 (ED. 12-87)

LAUDERDALE NO 2
LAUDERDALE NO 2
LAUDERDALE NO 2
LAUDERDALE NO 2
LAUDERDALE NO 2
LAUDERDALE NO 2
LAUDERDALE NO 2
LAUDERDALE
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
PORT EVERGLADES
SISTRUNK
SISTRUNK
SISTRUNK
SISTRUNK
SISTRUNK
SISTRUNK
SISTRUNK
SISTRUNK
SISTRUNK
BROWARD
BROWARD
BROIJARD
BROWARD
BROWARD
BROWARD
BROWARD

PLT
PLT
PLT
PLT
PLT
PLT
PLT
PLT
PLT
PLT

(e)

(g)

(t)

(h)

(c)

(d)

HR:88

~~

6JS

8

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
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
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

SP
SP
H
SP
SP
SP
H
SP
SP
SP
SP
SP
SP
H
SP
SP
UG
H
SP
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
SP
SP

0.66
0.09
2.95
1.76
0.41
0.36
0.05
0.54
0.16
0.80
0.06
0.20
3.71
0.11

0

HR:88

2

0

2

0

2
1

0

0
0
0
0
0
0
0
0

1
1
1
1
1
1

1
2
2
2

0

1. 70
0

0.17

0

, .86
0.16
0.92
1.12
0.12

0

,

0

1

0

0.11
0.01

2

0
0

1
1
1

0

1

0

1

2.32
0.04
0.18
5.29
0.54

0
0

1
1
1

0

1

0

1
1

0

0

o.og
TOTAL

Page 422.20

1

0

0.01
0.15
0.08

0

~~

1

0

2

 Name of Respondent
Florida Power & L1ght Company

Date of Report
(Mo, Da, Yr)

I

I

Year of Report
Dec. 31, 1996

TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage Lines with higher voltage Lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

Si:z:e of
Conductor
and Mater1al
( i)

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(o)

Total
Expenses

Line
No.

(p)

~

1~g-5 ACSRAZ

ACSRAZ
954 ACSRAZ
954 ACSRAII
795 ACSRAZ
795 ACSRAZ
350 CUHT
556.5 ACSRAII
795 AA
795 ACSRAZ
900 CUHT
954 ACSRAZ
795 AA
795 ACSRAZ
795 AA
900 CUHT
795 ACSRAZ
795 ACSRAII
2000 cu
1431 ACSRAII
900 CUHT
1431 ACSRAZ
1431 ACSRAZ
1691 AAAC
1431 ACSRAZ
1691 AAAC
900 CUHT
795 ACSRAII
954 ACSRAZ
954 ACSRAII
1431 ACSRAZ
954 ACSRAZ
2-5568 AA
954 ACSRAZ
1431 ACSRAZ

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

~~
36

FERC FORM NO. 1 (ED. 12-87)

Page 423.20

 l

Year of Report
Date of Report
This Report Is:. l
(Mo, Da, Yr>
(1) [XJ An Or1g1na .
Dec.
31, 1996
(2) [ A Resuemiss1on
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support 1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year . List each transmission line
by
the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission
line of a different type of construction need not
transmission lines below these voltages in group totals only
be
distinguished
from the remainder of the line.
for each voltage.
6.
Report
in
columns
(f)and(g) the total pole miles of each
2. Transmission lines include all lines covered by the
transmission
line.
Show
in column (f) the pole miles of line
definition of transmission system plant as given in the Union
structures
the
cost
of
which is reported for the line desiform System of Accounts. Do not report substation costs and
gnated;
conversely,
show
in column (g) the pole miles of line
expenses on this page.
on structures the cost of which is reported for another line.
3. Report data by individual lines for all voltages if so
Report pole miles of line on leased or partly owned strurequired by a State commission.
ctures in column (g). In a footnote, explain the basis of
4. Exclude from this page any transmission lines for which
such occupancy and state whether expenses with respect to
plant costs are included in Account 121, Nonutility Property.
such structures are included in the expenses reported for the
5.Indicate whether the type of supporting structure reportline designated.
ed in column(e) is:(1) single pole,wood or steel;(2) H-frame,
wood, or steel poles; (3) tower; or (4) underground construeLENGTH (Pole miles)
VOLTAGE (KV)
Number
(In the case 1>f
Type of
(I nd1 cate wtiere
DESIGNATION
undergrovnd ~1nes
other than
of
report c1rcu1t ml[es)
Supporting
60 cycle,5 phase)
Liner-----------------------.------------------------+----~~~~~~
0~ Structure 0~ Structures Circuits
Structure
No.
From
To
Operating Designed
ot L1ne
of Another
Des1g~ated
Line
N9me of Respondent
Florida Power & L1ght Company

(a)

1 SISTRUNK
2 SISTRUNK
3 SISTRUNK
4 OAKLAND PARK
5 OAKLAND PARK
6 OAKLAND PARK
7 OAKLAND PARK
8 BROWARD
9 BROWARD
10 BROWARD
11 BROWARD
12 BROWARD
13 BROWARD
14 BROWARD
15 BROWARD
16 BROWARD
17 HOLLYWOOD
18 HOLLYWOOD
19 HOLLYWOOD
20 HOLLYIIOOO
21 HOLLYWOOD
22 HOLLYWOOD
23 HOLLYWOOD
24 HOLLYWOOD
25 LAUDERDALE PLANT
26 LAUDERDALE PLANT
27 LAUDERDALE PLANT
28 LAUDERDALE PLANT
29 LAUDERDALE PLANT
30 LAUDERDALE PLANT
31 LAUDERDALE PLANT
32 LAUDERDALE PLANT
33 CALDWELL (DEERFIELD)

~~

~~BB~~BL <DEERFIELD)

36
FERC FORM NO. 1 CEO. 12-87)

I

I

(b)

OAKLAND PARK
OAKLAND PARK
OAKLAND PARK
SISTRUNK NO 2
SISTRUNK NO 2
SISTRUNK NO 2
SISTRUNK NO 2
OAKLAND PARK NO 2
OAKLAND PARK NO 2
OAKLAND PARK NO 2
OAKLAND PARK NO 2
OAKLAND PARK NO 2
OAKLAND PARK NO 2
OAKLAND PARK NO 2
OAKLAND PARK NO 2
TRADEWINDS
<BCRR>
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
SISTRUNK
SISTRUNK
SISTRUNK
SISTRUNK
SISTRUNK
SISTRUNK
SISTRUNK
SISTRUNK
YAMATO (NO 2)
YAMATO CNO 2>
LAUDERDALE NO 1

(C)

(e)

(d)

H~:88

H~:88 ~~

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
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
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

H~:88

8

SP
SP
SP
SP
SP
H
H
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
SP
H
H
SP
SP
H
SP
SP
SP
SP
SP
SP
SP
SP

0

0.85

2.63
0.94
0.28
1.37
0.01
0.08
3.22
0.23
0.58
1.69
7.03

0

0

0.52

0.99
1.23
1.38
0.47
1.92
0
0
0

0

0.51
1.44
0.68
1 .52
1.83
0.31
1.94
0.75
3.15

H~:88 ~p

0. 1g
TOTAL

Page 422.21

(h)

(g)

{f)

0
0
0

0
0
0
0
0

0
0
0

0
0

0
0

2
1
1
1
1
1
1
1
1
1
1
1
2
1
1
1
1
1

2.19
1.50
0.27
0.25

2

0

1
1

0
0

0
0

2
2
2

1
1
1

0

1

0

1

0

1

0

1

1.08

 N~me

of Respondent
Florida Power & L1ght Company

This Report 1$:
Date of Report
Year of Report
(1) [X] An Or1ginal
(Mo, Da, Yr)
(2) [ l A Resu5mission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

Si7,e of
Conductor l
and Materia
( i)
ACSRAZ
1~~1 ACSRAZ
1431 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
954 ACSRAII
954 ACSRAZ
954 ACSRAZ
954 ACSRAII
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
556.5 ACSRAII
795 AA
954 ACSRAZ
1431 ACSRAII
795 AA
795 AA
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
2-5568 ACSR AZ
1431 ACSRAZ
1431 ACSRAII
1431 ACSRAZ
2-5568 AA
1431 ACSRAII
1431 ACSRAZ
2-5568 ACS RAZ
954 ACSRAII
g~~

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

l

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

Total
Expenses

Line
No.

(p)

~
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

~~

ACSRAII
ACSRAZ

36
FERC FORM NO. 1 (ED. 12-87)

Page 423.21

 Name of Respondent
Florida Power & L1ght Company

I

I

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 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 construe-

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
35
36
FERC

From

To

(a)

(b)

BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROio/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROir/ARD
BROio/ARD
DEERFIELD
DEERFIELD
DEERFIELD
DEERFIELD
DEERFIELD

LAUDERDALE NO 1
LAUDERDALE NO 1
LAUDERDALE NO 1
LAUDERDALE NO 1
LAUDERDALE NO 1
LAUDERDALE NO 1
LAUDERDALE NO 1
LAUDERDALE NO 1
LAUDERDALE NO 1
DEERFIELD NO 1
DEERFIELD NO 1
DEERFIELD NO 1
DEERFIELD NO 1
LAUDERDALE NO 2
LAUDERDALE NO 2
LAUDERDALE NO 2
LAUDERDALE NO 2
LAUDERDALE NO 2
RANCH
RANCH
RANCH
RANCH
RANCH
DEERFIELD NO 2
DEERFIELD NO 2
DEERFIELD NO 2
DEERFIELD NO 2
DEERFIELD NO 2
DEERFIELD NO 2
DEERFIELD NO 2
YAMATO
YAMATO
YAMATO
YAMATO
YAMATO

(c)

Type of
Supporting
Structure
(e)

(d)

H~:88

H~:88 ~

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
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
230.00
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
138.00

H~:88

H~:88 ~

Page 422.22

LENGTH (Pole miles)
Number
(In the case of
undergrovnd (lnes
of
report c1rcu1t ml(es)
On Structure On Structures Circuits
of ~1ne
ot Another
Des1gnated
Line
(g)

(f)

(h)

8

H
H
SP
SP
SP
SP
H
SP
SP
SP
SP
H
SP
SP
SP
SP
H
H
H
SP
H
H
SP
SP
SP
SP
SP
H
SP
SP
SP
TOTAL

FORM NO. 1 (ED. 12-87)

Year of Report
Dec. 31, 1996

I

tion. 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.

VOLTAGE (KV)
(lnd1cate where
other fhao
bO eye e,5 phase)

DESIGNATION

Date of Report
(Mo, Da, Y)")

9.73

0

1

3.80
0.05
0.05
0.06
0.64

0

1
1

0

1

0

1.15

2

3. 74

0

0.34
0.63
0.07
2.17
4. 75
0.08
0.32
15.09
4.28
0.11
27.18
0.20
4.50
0.07
3.86
0.12
0.12
0.44
2.58
0.52
0.63
0.15
12.10

0

1
1

0

0
0

0
0
0

1
1

1
1
1

0

1
1
1
1

0

1

0

1

0

1

0
0
0

0

1

4.50

2

0

1

0

1

0
0

1
1

0

1

0

1

0

2

0

1

0

1

0

1

 N~me

of Respondent
Florida Power & L1ght Company

I

This Report Is:
Date of Report
Year of Report
(1) fXl An Or1ginal
(Mo, Da, Yt")
(2)
J A Resuemission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
B. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property
and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

S~e

of
Co uctor
and Material
( i)

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(o)

rl~ ACSRAZ

-

J

Total
Expenses

Line
No.

(p)

~

1 ACSRAZ
2-3368 ACSRAZ
2-3368 ACSRAZ
954 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
1431 ACSRAW
954 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
1431 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
2-3368 ACSRAZ
2-3368 ACSRAZ
1431 ACSRAZ
954 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
2-5568 AA
954 ACSRAZ
2-5568 AA
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
ACSRAZ
ACSRAZ

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

~~
36

FERC FORM NO. 1 CEO. 12-87)

Page 423.22

 of Respondent
Florida Power & L1ght Company

N~me

I

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 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; (5) tower; or (4) underground construe-

Type of
Supporting
Structure

g

0
Line~-----------------------.-----------------------+~~c~y~c~e~·~p~h~a~s~e~)
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
36
FERC

DEERFIELD
DEERFIELD
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
RANCH
RANCH
RANCH
RANCH
RANCH
RANCH
CEDAR
CEDAR
CEDAR
RANCH
RANCH
RANCH
RANCH
RANCH
RANCH
RANCH
RANCH
RANCH
RANCH
RANCH
RANCH

To
(b)

YAMATO
YAMATO
YAMATO
YAMATO
YAMATO
YAMATO
YAMATO
YAMATO
YAMATO
HYPOLUXO
HYPOLUXO
HYPOLUXO
HYPOLUXO
HYPOLUXO
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
HYPOLUXO
HYPOLUXO
HYPOLUXO
RIVIERA NO 1
RIVIERA NO 1
RIVIERA NO 1
RIVIERA NO 1
RIVIERA NO 2
RIVIERA NO 2
RIVIERA NO 2
RIVIERA NO 2
RIVIERA NO 2
W PALM BEACH NO 2
W PALM BEACH NO 2
W PALM BEACH NO 2

Operating Designed
(c)

(e)

(d)

I

H~:88

H~:88 ~~

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
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
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

SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
SP
SP
SP
SP
H
H
H
H
H
H
H
SP
SP
H

H~:88

HS:88

~

Page 422.23

LENGTH (Pole miles)
Number
(In the case of
undergrovnd 11nes
of
report c1rcu1t m1les)
Oo Structure Oo Structures Circuits
ot ~1ne
of Another
Des1goated
Line
(h)

(g)

(f)

0.0~

0.33
1.20
3.00
8.23
2.20
0.05
0.53
1.46
0.05
2.98
2.30

0.05

0

1

0

0.53

2

0

1

4.81
3.46
2. 74
0.10
1.67
2.44
1.96
2.39
0.92
0. 04
2.99
11.25
0.27
0.67
13.59
0.27
2.30
2.19
0.02

0

1

0

1

0

1
1
1
2
2
1

0
0
0

0
0
0

1
1

0

1

0

0

1
1
1

0

1

0

1

0

0

1

0

2

0

1
1
1

0
0

0

1
1
1
1
1
2

0

1

0
0

0
0
0

8
TOTAL

FORM NO. 1 (ED. 12 -87)

Year of Report
Dec. 31, 1996

tion. 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.

VOLTAGE (KV)
(lnd1cate wliere
her fhas

DESIGNATION

Date of Report
(Mo, Da, Yr)

 N~me

of Respondent
Florida Power & L1ght Company

This Report 1$:
Date of Report
Year of Report
(1) fXl An Or1ginal
(Mo, Da, Yr)
(2)
J A Resuemission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and g1v1ng
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmi ssion line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

Siz.e of
Conductor
and Material
( i)

r-

I

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

Total
Expenses

Line
No.

(p)

1

ACSRAZ
ACSRAZ
954 ACSRAZ
954 ACSRAW
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAW
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAW
2-556 ACSRAW
954 ACSRAZ
2-556P ACSRAZ
954 ACSRAW
954 ACSRAZ
954 ACSRAW
1431 ACSRAZ
2-3508 CUHT
2-5568 ACSRAZ
2-3508 CUHT
900 CUHT
1431 ACSRAZ
900 CUHT
954 ACSRAW
954 ACSRAW
900 CUHT
ACSRAW
1 Z~ 1 ACSRAZ
FER C FORM NO. 1 (ED . 12 -87)

I

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

~~
36
Page 423.23

 of Respondent
Florida Power & L1ght Company

N~me

I

I

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 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;C2) H-frame,
wood, or steel poles; (5) tower; or (4) underground construe-

Type of
Supporting
Structure

g~her fha~

Liner-----------------------,------------------------+~~c~y~c~e~·~ph~a~s~e~)
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
36
FERC

From

To

(a)

(b)

RANCH
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
CEDAR
RIVIERA
RIVIERA
RIVIERA
RIVIERA
RIVIERA
RIVIERA
RIVIERA
RIVIERA
RIVIERA
RIVIERA
RIVIERA
RIVIERA
RECWAY
RECWAY
RECWAY
RECWAY
PLUMOSUS
PLUMOSUS
PLUMOSUS
PLUMOSUS
PLUMOSUS
PLUMOSUS
PLUMOSUS
PLUMOSUS
PLUMOSUS
PLUMOSUS
HOBE

W PALM BEACH NO 2
RANCH
RANCH
RANCH
RANCH
RANCH
RANCH
RANCH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
WEST PALM BEACH
RIVIERA
RIVIERA
RIVIERA
RIVIERA
RIVIERA NO 1
RIVIERA NO 1
RIVIERA NO 1
RIVIERA NO 1
RIVIERA NO 2
RIVIERA NO 2
RIVIERA NO 2
RIVIERA NO 2
RIVIERA NO 2
RIVIERA NO 2
HILLS RADIAL

Operating Designed
(c)

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
138.00
138.00
138.00
138.00
138.00
138.00
138.00

(e)

(d)

Year of Report
Dec. 31, 1996

(h)

(g)

(f)

~p

!:2~

8

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
230.0D
138.DD
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00

SP
SP
SP
SP
SP
SP
H
H
H
H
H
H
SP
SP
SP
H
H
H

3.27
5.49
0.07
0.76
2.20
0.92
0.03
0.59
3.78
3.57
0.03
0.27
0.29
0.55
0.35
0.01
0.07
0.45
3.17
0.27
2.47
0.69
1.70
0.32
0.15
13.05
0.07
7.08
0.02
1. 71
4.49

0

H

H
SP
SP
UG
H
SP
SP
SP
SP
SP
SP
SP

H~:88 ~~
Page 422.24

LENGTH (Pole miles)
Number
(In the case 9f
undergrovnd 11nes
of
report c1rcu1t m1les)
OQ Structure OQ Structures Circuits
ot ~1ne
ot Another
DeslgQated
Line

HR:88

0

1
1

0

1

0

0

1
1
2
1
1
1
1
1

0

1

0

0
0
0
0
0
0

0

1
1
1

0.01

2

0
0

1
1

0

1

0

0

1

0

1
1

0
0
0
0

1
1
1

0

1

0

1

0
0

1
1
1

0

1

0

0.06

TOTAL
FORM NO. 1 (ED. 12-87)

I

tion. 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.

VOLTAGE (KV)
(Inch cate wliere

DESIGNATION

Date of Report
(Mo, Da, Yrl

 N~me

of Respondent
Florida Power & L1ght Company

This Report Is:

[Xl An On gina l
(2) [ A Resuemission
I
TRANSMISSION LINE STATISTICS (Continued)
( 1)

7. Do not report the same transmission line structure twice.
Report lower voltage lines and higher voltage lines as one
line. Designate in a footnote if you do not include lower
voltage lines with higher voltage lines. If two or more trans·
mission 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).
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 other than a leased line, or portion thereof, for
which the respondent is not the sole owner but which the

Siz.e of
Conductor
and Material
( i)

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
( j)

(k)

( l)

I

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31, 1996

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 line, name of co-owner, basis of sharing
expenses of the line,and how the expenses borne by the respondent are accounted for, and accounts affected.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 (j) to
(l) on the book cost at end of year.

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
EXpenses

Maintenance
Expenses

Rents

Total
Expenses

(m)

(n)

(o)

(p)

Line
No.

~

~~~1

ACSRAW
ACSRAW
954 ACSRAZ
954 ACSRAW
954 ACSRAZ
954 ACSRAW
954 ACSRAZ
954 ACSRAW
900 CUHT
1431 ACSRAZ
2-3508 CUHT
2-5568 ACSRAZ
1431 ACSRAZ
1691 AAAC
1691 AAAC
2-3508 CUHT
1691 AAAC
2-5568 ACSRAZ
1431 ACSRAW
1431 ACSRAW
1431 ACSRAZ
900 CUHT
556.5 ACSRAW
900 CUHT
2400 AL
954 ACSRAW
795 ACSRAW
954 ACSRAW
795 ACSRAW
927.2 AAAC
954 ACSRAZ
927.2 AAAC
927 . 2 AAAC

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

AAAC
1 g~r-2ACSRAW

~~
36

FERC FORM NO. 1 (ED. 12-87)

Page 423.24

 Year of Report
Date of Report
This Report I!>: .
(Mo, Da, Yr)
( 1 ) [XJ An Or 1g1na l
Dec. 31, 1996
(2) [ A Resuemission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
by
the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission
line of a different type of construction need not
transmission lines below these voltages in group totals only
be
distinguished
from the remainder of the line.
for each voltage.
6. Report in columns (f)and(g) the total pole miles of each
2. Transmission lines include all lines covered by the
transmission line. Show in column (f) the pole miles of line
definition of transmission system plant as given in the Union structures the cost of which is reported for the line desiform System of Accounts. Do not report substation costs and
gnated; conversely, show in column (g) the pole miles of line
expenses on this page.
on structures the cost of which is reported for another line.
3. Report data by individual lines for all voltages if so
Report pole miles of line on leased or partly owned strurequired by a State commission.
ctures in column (g). In a footnote, explain the basis of
4. Exclude from this page any transmission lines for which
such occupancy and state whether expenses with respect to
plant costs are included in Account 121, Nonutility Property.
such structures are included in the expenses reported for the
5.Indicate whether the type of supporting structure reportline designated.
ed in column(e) is:(1) single pole,woQd or steel;(2) H-frame,
wood, or steel poles; (3) tower; or (4) underground construeLENGTH (Pole miles)
VOLTAGE (KV)
Number
(lnd1cate wnere
Type of
(In the case 9f
DESIGNATION
undergrovnd ~1ne!>
other than
report c1rcu1t m1les)
of
60 cycle,3 phase)
Supporting
Line
On Structure On Structures Circuits
Operating Designed Structure
of ~1ne
of Another
To
From
No.
Des1gnated
Line
N9me of Respondent
Florida Power & L1ght Company

(a)

1 HOBE
2 HOBE
3 HOBE
4 HOBE
5 HOBE
6 HOBE
7 HOBE
8 HOBE
9 HOBE
10 HOBE
11 HOBE
12 HOBE
13 HOBE
14 HOBE
15 HOBE
16 HOBE
17 MIDWAY
18 MIDWAY
19 MIDWAY
20 MIDWAY
21 MIDWAY
22 MIDWAY
23 MIDWAY
24 MIDWAY
25 HOBE
26 HOBE
27 MIDWAY
28 MIDWAY
29 MIDWAY
30 MIDWAY
31 MIDWAY
32 EMERSON
33 EMERSON
34 EMERSON
35 EMERSON
36
FERC FORM NO. 1 (ED. 12-87)

(C)

(b)

HILLS RADIAL
PLUMOSUS
PLUMOSUS
PLUMOSUS
PLUMOSUS
PLUMOSUS
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
SANDPIPER
COVE RADIAL
COVE RADIAL
HARTMAN
HARTMAN
HARTMAN
HARTMAN
HARTMAN
HARTMAN
HARTMAN
HARTMAN
HARTMAN

<FTP>
<FTP>
<FTP>
<FTP>
<FTP>
<FTP>
<FTP>
<FTP>
<FTP>

I

I

I

(e)

(d)

H~:88

H~:88 ~~

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
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
138.00
138.00
230.00
230.00
230.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00

H~:88

H~:88 ~~

(g)

(h)

8
0.49
0.04
11.23
0.44
0.27
1.48
0.04
0.14
0.15
0.42
0.44
14.90
0.20
1.31
5.10
0.04
0.50
8.10
0.57
0.16

SP
SP
SP
SP
H
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
H
SP

0

1

0

1
1

0
0

1

0

1
1
1
1
1
1

0
0
0
0
0
0
0

0

1.31

1
1
1
2

0

1

0

1

0

1
1
1

0
0
0

1

0
0

1.13
0.50

2

4.62
2.66
3.39
3.68
0.07
0.26
0.04
0.01
5.83

0

2
1

0

2

0

1

0

8:~~
TOTAL

Page 422.25

(f)

0

1
1
1

0.04

2

0

1
1

0

0

8

 of Respondent
Florida Power & L1ght Company

N~me

This Report Is:
Date of Report
Year of Report
(1) fXl An Or1ginal
(Mo, Da, Yr)
(2)
A Resuflmission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
B. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns {j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs

Siz.e of
Conductor
and Material
( i)

,.-.

I

(j)

(k)

{l)

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
EXpenses

Maintenance
Expenses

Rents

(m)

(n)

(o)

954 ACSRAII
795 ACSRAZ
795 ACSRAII
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
350 CUHT
795 ACSRAZ
795 ACSRAZ
954 ACSRAII
954 ACSRTII
350 CUHT
556.5 ACSRAZ
795 ACSRAZ
795 ACSRAII
954 ACSRTII
954 ACSRAZ
795 ACSRAZ
795 ACSRAII
795 ACSRAZ
954 ACSRAZ
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
954 ACSRAII
954 ACSRAII
954 ACSRAZ
954 ACSRAZ
954 ACSRAII
954 ACSRAZ
954 ACSRAII
954 ACSRAII
795 ACSRAZ
795 ACSRAII
954 ACSRAZ

Total
Expenses

Line
No.

(p)

~
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

~~
36

i
FERC FORM NO. 1 (ED. 12-87)

Page 423.25

 N~me

of Respondent
Florida Power & L1ght Company

I

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 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(~) is:(1) single pole,wood or steel;(2) H-frame,
wood, or steel poles; (3) tower; or (4) underground construe-

VOLTAGE (KV)
(lnd1cate wtiere
other than
bO cycle,3 phase)
Line~----------------------.------------------------+~~~~~~~~
Operating Designed
To
No.
From
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

(c)

(b)

(a)

EMERSON
EMERSON
EMERSON
EMERSON
IIEST
IIEST
IIEST
IIEST
IIEST
IIEST
IIEST
IIEST
IIEST
IIEST
IIEST
MALABAR
MALABAR
MALABAR
MALABAR
MALABAR
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLI E
EAU GALLI E
EAU GAL Ll E
INDIAN HARBOR
INDIAN HARBOR
INDIAN HARBOR
INDIAN HARBOR
INDIAN HARBOR
INDIAN HARBOR

<VER>
<VER>
<VER>
<VER>
<VER>
<VER>
<VER>
<VER>
<VER>
<VER>
<VER>

36
FERC FORM NO. 1 (ED. 12-87)

HARTMAN
IIEST
IIEST
IIEST
MALABAR
MALABAR
MALABAR
MALABAR
MALABAR
MALABAR
MALABAR
MALABAR
MALABAR
MALABAR
MALABAR
HARRIS
HARRIS
HARRIS
HARRIS
HARRIS
HARRIS
HARRIS
HARRIS
HARRIS
HARRIS
HARRIS
HARRIS
MALABAR NO 2
MALABAR NO 2
MALABAR
MALABAR
MALABAR
MALABAR
MALABAR
MALABAR

<FTP>
<VER>
<VER>
<VER>

l

Year of Report
Dec. 31, 1996

tion. If a transmission line has more than one type of support·
ing 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
Supporting
Structure

DESIGNATION

1

Date of Report
(Mo, Da, Yr)

(e)

(d)

~~R:88

~~R:88 ~~

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
138.00
138.00
138.00
138.00
138.00
138.00
138.00

138.00
138.00
138.0D
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
230.00
230.00
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

SP
SP
H
H
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
SP
SP
SP

HR:88 HR:88 §~

(g)

(f)

(h)

6:~r

8

7.05
1.88
0.02
0.31
28.42
2.32
3.02
6.65
0.10
2.00
0.15
0.01
0.12
0.09
0.09
0.71
3.94
2.06
3.14
0.14
0.02
0.01
4.94
0.16
1.62
1.91
9.81
0.96
7.82
0.08
0.12

0

0
0
0
0

0

0
0
0

0
0
0

0.16
0
0
0

1
1
1
1

1
1
1
1
1
1
2
1
2
1
1
1

0.15

2

0

2

0

1

0

1

0

1

0

1

0

1
1
1
1
1
1
1
1
1

0
0

0
0
0
0

0

0

8
TOTAL

Page 422.26

LENGTH (Pole miles)
Number
(In the case 9t
undergrovnd 11nes
report c1rcu1t mJ(es)
of
On Structure On Structures Circuits
of llne
of Another
Des1gnated
Line

 of Respondent
Florida Power & L1ght Company

Date of Report
Year of Report
This Report Is:
(Mo, Da, Yr>
(1) [XJ An Or1ginal
(2) [ A ResuElmission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furn i sh a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and g1v1ng
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines . If two or more trans respondent in the line, name of co·owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the respon·
dent are accounted for, and accounts affected.Specify whether
report the pole miles of the primary structure in column (f)
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property
and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
associated company.
terms of lease, and amount of rent for year. For any transmi10. Base the plant cost figures called for in columns (j) to
ssion line other than a leased line, or portion thereof, for
(l) on the book cost at end of year.
which the respondent is not the sole owner but which the

N~me

Siz.e of
Conductor
and Material
( i)
ACSRA\.1
g~~ ACSRA\.1
954 ACSRAZ
954 ACSRA\.1
954 ACSRAZ
1127 AAAC
954 ACSRAZ
954 ACSRAZ
954 ACSRA\.1
954 ACSRAZ
1127 AAAC
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRA\.1
795 ACSRAZ
795 ACSRA\.1
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
795 ACSRA\.1
350 CUHT
795 AA
795 ACSRAZ
2-3508 CUHT
2-4508 AA
795 ACSRAZ
795 ACSRAZ
954 ACSRAZ
927.2 AAAC
954 ACSRAZ
954 ACSRA\.1

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Construction and
Total Cost
Land
Other Costs
( j)

(K)

(l)

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

<n>

(0)

Total
Expenses

Line
No.

(p)

~
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

~~

llH ~~~§
FERC FORM NO. 1 (ED. 12-87)

I

I

36
Page 423.26

 Year of Report
Date of Report
This Report 1&: .
(Mo, Da, Yr)
(1) [XJ An Or1g1nal
Dec.
31, 1996
(2) [ A ResuElmission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
by
the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission
line of a different type of construction need not
transmission lines below these voltages in group totals only
distinguished
from the remainder of the line.
be
for each voltage.
6. Report in columns (f)and(g) the total pole miles of each
2. Transmission lines include all lines covered by the
transmission line. Show in column (f) the pole miles of line
definition of transmission system plant as given in the Union structures the cost of which is reported for the line desiform System of Accounts. Do not report substation costs and
gnated; conversely, show in column (g) the pole miles of line
expenses on this page.
on structures the cost of which is reported for another line.
3. Report data by individual lines for all voltages if so
Report pole miles of line on leased or partly owned strurequired by a State commission.
ctures in column (g). In a footnote, explain the basis of
4. Exclude from this page any transmission lines for which
such
occupancy and state whether expenses with respect to
plant costs are included in Account 121, Nonutility Property.
such
structures
are included in the expenses reported for the
5.Indicate whether the type of supporting structure reportline designated.
ed in column(e) is:(1) single pole,wood or steel;(2) H-frame,
wood, or steel poles; (5) tower; or (4) underground construeLENGTH (Pole miles)
VOLTAGE (KV)
Number
Type of
(In the case 9t
(I nd1 cate wliere
DESIGNATION
undergrovnd \lnes
Qther thao
of
report c1rcu1t m1!es)
Supporting
60 cycle,3 phase)
Line~----------------------,------------------------+~--~~~~--~
On Structure On Structures Circuits
Structure
Operating Designed
of ~1ne
of Another
To
From
No.
Des1gnated
Line
Name of Respondent
Florida Power & L1ght Company

I

(b)

(a)

3
4
5

INDIAN HARBOR
INDIAN HARBOR
INDIAN HARBOR
INDIAN HARBOR
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
BREVARD
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
OSCEOLA

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
FERC FORM NO. 1 (ED. 12-87)

MALABAR
MALABAR
MALABAR
MALABAR
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
EAU GALLIE
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
COCOA BEACH
SOUTH CAPE
SOUTH CAPE
SOUTH CAPE
SOUTH CAPE
RANCH

I

(c)

(e)

(d)

H~:88

H~:88 §~

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
138.0D
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.DO
138.00
138.00
138.00

230.00
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
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00

H
H
H
H
UG
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP

H~:88

H~:88

Hp

8

H

SP
SP

2.31

0

1

0

2.06

0.23
0.48
0.98
2.99
0.02
0.22
6.41
0.98
6.99
0.26
8.23
3.82
0.93
1.38
9.98
2.26
0.08
2.27
1.53
8.90
0.24
0.02
2.49
0.04

0

2
1

0

1
1

0

1

0

0

1

0

1
1

0
0

1

0

1

0
0

2
1
1
1
1
1

0
0
0

0
0

2

0

2

0

2

0

1
1
1
1

0
0
0
0
0

0

2.18

0.53
0.09
2.38
0.02

0

1
1

2
2

0

1
1

0

1

0

8
TOTAL

Page 422.27

(h)

(g)

(f)

 Year of Report
Date of Report
This Report Is:
(Mo, Da, Yr)
(1) [XJ An Or1ginal
Dec. 31, 1996
(2) [ A ResuElmission
TRANSMISSION LINE STATISTICS (Continued)
respondent operates or shares in the operation of, furnish a
7. Do not report the same transmission line structure twice.
succinct statement explaining the arrangement and giving
Report lower voltage lines and higher voltage lines as one
particulars (details) of such matters as percent ownership by
line. Designate in a footnote if you do not include lower
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the respondent are accounted for, and accounts affected.Specify whether
report the pole miles of the primary structure in column (f)
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
associated company.
terms of lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

of Respondent
Florida Power & L1ght Company

N~me

Siz.e of
Conductor
and Mater1al
( i)

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Total Cost
Land
Construction and
Other Costs
(j)

(k)

(l)

I

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

n~ ACSRAZ

Total
Expenses

Line
No.

(p)

~

7 AAAC
1127 AAAC
954 ACSRAII
350 CUHT
1127 AAAC
1250 cu
350 CUHT
954 ACSRAZ
1127 AAAC
652.4 AAAC
350 CUHT
1127 AAAC
1127 AAAC
954 ACSRAZ
954 ACSRAII
954 ACSRAZ
954 ACSRTII
954 ACSRAZ
954 ACSRAII
954 ACSRAZ
954 ACSRTII
954 ACSRAZ
954 ACSRAII
954 ACSRAII
556.5 AA
954 ACSRAZ
954 ACSRAII
954 ACSRAII
556.5 AA
927.2 AAAC
927.2 AAAC
600 CUHT
92 7.2 AAAC
350 CUHT

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

~~
36

FERC FORM NO. 1 (ED. 12-87)

Page 423.27

 of Respondent
Florida Power & L1ght Company

N~me

I

t~~sf~Jep~~to~~~inal
(2)
A ResuElmission

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 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 construe-

VOLTAGE (KV)
(!nd1cate wtiere
other fhao
60 eye e,5 phase)
Line~----------------------.------------------------+----~--r-~--~
Operating Designed
No.
From
To
(a)

OSCEOLA
OSCEOLA
OSCEOLA
OSCEOLA
OKEELANTA
OKEELANTA
OKEELANTA
OKEELANTA
OKEELANTA
OKEELANTA
OKEELANTA
BRADFORD
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
RANCH
RANCH
RANCH
RANCH
RANCH
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM

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
FERC FORM NO. 1 (ED. 12-87)

(b)

RANCH
RANCH
RANCH
RANCH
SOUTH BAY
SOUTH BAY
SOUTH BAY
HENDRY
HENDRY
HENDRY
HENDRY
DEER HAVEN
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
FORT MYERS NO
FORT MYERS NO
FORT MYERS NO
FORT MYERS NO
FORT MYERS NO
SOUTH BAY
SOUTH BAY
SOUTH BAY
SOUTH BAY
SOUTH BAY
HENDRY
HENDRY
HENDRY
HENDRY
ALICO Sll STA
ALICO Sll STA
ALICO Sll STA
ALICO Sll STA

<CLE>
<CLE>
<CLE>
<CLE>
<GVL>

2
2
2
2
2

<CLE>
<CLE>
<CLE>
<CLE>

I

Date of Report
(Mo, Da, Yr)

Year of Report
Dec. 31, 1996

tion. 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

1

I

(C)

(d)

Type of
Supporting
Structure
(e)

1~~:88

1~~:88 ~p

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
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
138.00
230.00
230.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00

1~~:88

1~~:88 ~

(g)

(t)

1

SP
SP
H
SP
SP
H
H
SP
SP
SP
H
SP
SP
SP
SP
H
SP
SP
H
SP
H
SP
SP
SP
SP
H
H
SP
SP
H
H

(h)

Z:r~

8

9.02
3.03
1. 71
0.02
5.34
9.27
4.21
0.05

0

2

0

2

0

1

0

1
2

0
0
0

1
1

0

1

0

5.34

2

11.27
4.23
0.03
0.04
0.95
0.19
3.09
0.15
0.34
0.44
0.73
9.27
0.05
2.40

0

1

0

1

0
0

1
1
1

0
0

0.05
52.17
0.11
0.08
0.13
15.01

0

0

2

0

1

0

0

1
1
1
1
1
1

0

0
0
0
0

2

9.02
3.03

2

0

1

2

0

1

0

0

1
1
1

0

1

0

8
TOTAL

Page 422.28

LENGTH (Pole miles)
(In the case ot
Number
undergrovnd 11nes
report c1rcu1t m1!es)
of
On Structure On Structures Circuits
of ~1ne
of Another
Des1gnated
Line

 Name of Respondent
Florida Power & L1ght Company

This Report Is:
Date of Report
Year of Report
(Mo, Da, Yr)
( 1 ) [XJ An Or 1gina l
31, 1996
Dec.
(2) [
A ResuElmission
i
TRANSMISSION LINE STATISTICS (Continued)
respondent operates or shares in the operation of , furnish a
7. Do not report the same transmission line structure twice.
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the respondent are accounted for, and accounts affected.Specify whether
report the pole miles of the primary structure in column (f)
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
10. Base the plant cost figures called for in columns (j) to
ssion line other than a leased line, or portion thereof, for
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

S~e

of
Co uctor
and Mater1al
( i)
~~t~ ACSRAZ
ACSRAW
556.5 ACSRAW
556.5 ACSRAW
556.5 ACSRAZ
556.5 ACSRAW
556.5 ACSRAW
556.5 ACSRAZ
556.5 ACSRAW
556.5 ACSRAW
556.5 ACSRAW
795 ACSRAZ
556.5 ACSRAZ
954 ACSRAZ
954 ACSRAZ
556.5 ACSRAZ
954 ACSRAW
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
556.5 ACSRAZ
556.5 ACSRAW
556.5 ACSRAZ
556.5 ACSRAW
556.5 ACSRAW
350 CUHT
556.5 ACSRAZ
556.5 ACSRAW
954 ACSRAW
954 ACSRAZ
954 ACSRAZ

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

( l)

I

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
EXpenses

Maintenance
Expenses

Rents

(m)

(n)

(o)

Total
Expenses

Line
No.

(p)

~
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

~~

~~~?~~~~~~RAW

36
FERC FORM NO. 1 CEO. 12·87)

Page 423.28

 Year of Report
Date of Report
This Report Is:.
(Mo, Da, Yr)
(1) [Xl An Dr1g1nal
Dec. 31, 1996
(2) [ A ResuElmission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support·
1. Report information concerning transmission lines,cost of
ing structure, indicate the mileage of each type of construction
lines, and expenses for year. List each transmission line
by the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission line of a different type of construction need not
transmission lines below these voltages in group totals only
be distinguished from the remainder of the line.
for each voltage.
6. Report in columns (f)and(g) the total pole miles of each
2. Transmission lines include all lines covered by the
transmission line. Show in column (f) the pole miles of line
definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and
on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line
expenses on this page.
on structures the cost of which is reported for another line.
3. Report data by individual lines for all voltages if so
Report pole miles of line on leased or partly owned strurequired by a State commission.
4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
such occupancy and state whether expenses with respect to
plant costs are included in Account 121, Nonutility Property.
5.Indicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
ed in column(e) is:(1) single pole,wood or steel;(2) H-frame,
line designated.
wood, or steel poles; (3) tower; or (4) undergrouna construeVOLTAGE (KV)
LENGTH (Pole miles)
Type of
(!nd1cate wtiere
(In the case ot
Number
DESIGNATION
undergrovnd \lnes
other fhao
60 eye e,3 phase)
report c1rcu1t m1!es)
of
Supporting
Line~----------------------.------------------------+----~--.-~--~
Operating Designed Structure
Do Structure Do Structures Circuits
No.
To
of ~1ne
of Another
From
Des1goated
Line
Name of Respondent
Florida Power & L1ght Company

I

(a)

1

BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
BUCKINGHAM
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
BUCKINGHAM
ALICO
ALICO
ALICO
ALI CO
ALICO
ALICO
ALICO
ALICO
ALICO
COLLIER
COLLIER
COLLIER
COLLIER
COLLIER
COLLIER
COLLIER
COLLIER
COLLIER

2
3
4
5
6
7
8
9
1D
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
FERC FORM NO. 1 (ED. 12-87)

(b)

ALI CO SW STA
ALICO SW STA
ALI CO SW STA
ALICO SW STA
ALICO SW STA
ALICO SW STA
ALICO SW STA
ALICO SW STA
ALICO SW STA
ALICO SW STA
ALICO SW STA
ALICO SW STA
ALICO SW STA
ALICO SW STA
ALICO SW STA
ALICO SW STA
LAZY ACRES
NAPLES
NAPLES

(C)

<LCCR>

~APLES

NAPLES
NAPLES
NAPLES
NAPLES
NAPLES
NAPLES
NAPLES
NAPLES
ALLIGATOR RADIAL
ALLIGATOR RADIAL
ALLIGATOR RADIAL
GOLDEN GATE RADIAL
GOLDEN GATE RADIAL
GOLDEN GATE RADIAL
GOLDEN GATE RADIAL

I

I

(d)

(e)

(g)

(f)

(h)

H~:88

H~:88 ~p

1J~

8

1

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
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
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

2.83
1.01
0.85
0.95

0
0

1
1

SP
SP
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
H
H
SP
H
H
H
SP
SP
SP
SP
SP
SP
H
SP
H
SP
SP
H
H

1

2
2
2

0

0.01
0

0

0.18

0
0

1.29
0.64
16.80
1.29
0.18
5.02
0.10
3.03
1.04
2.05
1.80
2.24
3.04
0.03
0.04
0.03
0.43

0
0
0
0

0

0.37
5.21
0

0
0
0
0
0
0
0
0
0

1
1
1
1
1

2
2
1
1
1
1
1
1

1
1
1
2

0

1

0

0

1
1
1
1
1

0

1

0
0
0

8
TOTAL

Page 422.29

1

0

0.01
3.98
5.35
0.22
0.81
3.22

H~:88 ~

0

 of Respondent
Florida Power & L1ght Company

This Report Is:
Date of Report
Year of Report
(Mo, Da, Yl")
(1) [Xl An Or1ginal
(2) [ A Resuemission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage l ines. If two or more transrespondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
9. Designate any transmission line leased to another company
8. Designate any transmission line or portion thereof for
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

N~me

Siz.e of
Conductor
and Material
( i)

I

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(k)

(l)

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
EXpenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

~a~-5 ACSRAZ

Total
Expenses

Line
No.

(p)

~

ACSRAZ
954 ACSRAZ
954 ACSRAW
795 ACSRAZ
556.5 ACSRAZ
795 ACSRAZ
795 ACSRAZ
954 ACSRAW
954 ACSRAZ
954 ACSRAZ
954 ACSRAW
336.4 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
336.4 ACSRAZ
954 ACSRAZ
954 ACSRAZ
336.4 ACSRAZ
954 ACSRAZ
954 ACSRAW
954 ACSRAZ
795 ACSRAZ
336.4 ACSRAZ
954 ACSRAII
954 ACSRAZ
954 ACSRAZ
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
954 ACSRAZ
1431 ACSRAZ
795 ACSRAZ

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

~~
36

FERC FORM NO. 1 (ED. 12-87)

Page 423.29

 Year of Report
Dec. 31, 1996

of Respondent
Florida Power & L1ght Company

N~me

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 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.!ndicate whether the type of supporting structure report·
ed in column(e) is:(1) single pole,wood or steel;(2) H·frame,
wood, or steel poles; (3) tower; or (4) underground construe-

tion. If a transmission line has more than one type of support·
ing 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 stru·
ctures 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.

VOLTAGE (KV)
(Indlcate wtiere
other than
bO cycle,5 phase)
Line~----------------------.------------------------+----~--T-~~~
Operating Designed
No.
From
To
DESIGNATION

(a)

1
2
3
4
5
6
7
8
9

COLLIER
COLLIER
COLLIER
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
FT MYERS PLANT
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
ALICO S~ STA
ALICO S~ STA
ALICO S~ STA
ALICO S~ STA
ALICO S~ STA
ALICO S~ STA
ALICO S~ STA
ALICO S~ STA
ALICO SW STA
ALICO S~ STA
HOWARD
HOWARD
HOWARD
HOWARO
HOWARD
HOWARD
HOWARD
HOWARD
HOWARD
HOWARD
CHARLOTTE
CHARLOTTE
CHARLOTTE

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
FERC FORM NO. 1 (ED. 12·87)

(b)

GOLDEN GATE RADIAL
GOLDEN GATE RADIAL
GOLDEN GATE RADIAL
FT MYERS
FT MYERS
FT MYERS
FT MYERS
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
COLLIER
COLLIER
COLLIER
COLLIER
COLLIER
COLLIER
COLLIER
COLLIER
COLLIER
COLLIER
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING
MYAKKA
MYAKKA
MYAKKA

(C)

Type of
Supporting
Structure
(e)

(d)

H~:88

H~:88 ~~

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
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
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

SP
SP
SP
H
H
H
H
H
H
H
UG
H
H
H
H
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
SP
H
SP
SP

HB:88 HB:88

~~

(g)

(f)

(h)

&~6

8

0.21
0.52

0

1.86

0.37
5.22
0.14
2.12
0.20
38.22

0
0
0
0
0
0
0
0

1
1
1

2
2

1
1
1

1
2

0

4.95

1.80

0

8.26
3.80
5.71
5.01
0.02
0.18
0.21
0.08

0

1
1

0

1

0

1
1
1
1
1

0

1.17
0.36
2.96
4.87
1.68
2.79

0
0
0
0

0

1

2.05

2

0

1
1
1

0
0

0

1
1
1

1.21

0

1

0.70

0

1

0
0
6.10

1.26
0.58

2

2

0

1

~:~
TOTAL

Page 422.30

LENGTH (Pole miles)
Number
(In the case 9f
undergrovnd ~1nes
report c1rcu1t ml(es)
of
0~ Structure 0~ Structures Circuits
ot l1ne
ot Another
Des1g~ated
Line

0

0

8

 Name of Respondent
Florida Power & L1ght Company

Year of Report
This Report Is: .
Date of Report
(Mo, Da, Yr>
(1) [Xl An Or1g1nal
(2) [ A Resuemission
Dec. 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
7. Do not report the same transmission line structure twice.
respondent operates or shares in the operation of, furnish a
Report lower voltage lines and higher voltage lines as one succinct statement explaining the arrangement and g1v1ng
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or more trans respondent in the line, name of co-owner, basis of sharing
mission line structures support lines of the same voltage,
expenses of the line,and how the expenses borne by the responreport the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
is leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of lease, and amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but which the
(l) on the book cost at end of year.

Si;z:e of
Conductor
and Material
( i)
ACSRAZ
~~~ ACSRAZ
795 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
556.5 ACSRAZ
556.5 ACSRAZ
350 CUHT
556.5 ACSRAZ
556.5 ACSRAZ
2500 cu
795 ACSR
795 SSACAW
954 ACSRAZ
336.4 ACSRAZ
795 ACSRAW
954 ACSRAZ
954 ACSRAW
336.4 ACSRAZ
954 ACSRAW
795 ACSRAZ
795 ACSRAW
795 ACSRAZ
954 ACSRAZ
954 ACSRAW
954 ACSRAZ
795 ACSRAZ
795 ACSRAW
795 ACSRAZ
954 ACSRAW
795 ACSRAZ
ACSRAW
~ ~~~ ACSRAZ

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Land
Construction and
Total Cost
Other Costs
(j)

(K)

( l)

I

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

<m>

(n)

(0)

Total
Expenses

Line
No.

(p)

~
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

~~
36

FERC FORM NO. 1 ( ED. 12-87)

Page 423.30

 j

Year of Report
Date of Report
This Report Is: .
(Me, Da, Yr)
( 1) [XJ An Or 1g 1na l
Dec. 31, 1996
(2) [ A Resuomission
TRANSMISSION LINE STATISTICS
tion. If a transmission line has more than one type of support1. Report information concerning transmission lines,cost of
lines, and expenses for year. List each transmission line
ing structure, indicate the mileage of each type of construction
by the use of brackets and extra lines. Minor portions of a
having nominal voltage of 132 kilovolts or greater. Report
transmission lines below these voltages in group totals only
transmission line of a different type of construction need not
be distinguished from the remainder of the line.
for each voltage.
2. Transmission lines include all lines covered by the
6. Report in columns (f)and(g) the total pole miles of each
definition of transmission system plant as given in the Unitransmission line. Show in column (f) the pole miles of line
on structures the cost of which is reported for the line desiform System of Accounts. Do not report substation costs and
expenses on this page.
gnated; conversely, show in column (g) the pole miles of line
3. Report data by individual lines for all voltages if so
on structures the cost of which is reported for another line.
required by a State commission.
Report pole miles of line on leased or partly owned stru4. Exclude from this page any transmission lines for which
ctures in column (g). In a footnote, explain the basis of
plant costs are included in Account 121, Nonutility Property.
such occupancy and state whether expenses with respect to
5.Indicate whether the type of supporting structure reportsuch structures are included in the expenses reported for the
line designated.
ed in column(e) is:(1) single pole,wood or steel;(2) H-frame,
wood, or steel poles; (3) tower; or (4) underground construeLENGTH (Pole miles)
VOLTAGE (KV)
DESIGNATION
(lnd1cate wnere
Type of
(In the case of
Number
other than
undergrovnd ~1nes
60 cycle,3 phase)
Supporting
report c1rcu1t m1tes)
of
Line
Operating Designed
Structure
On Structure Oo Structures Circuits
No.
From
To
of ~1ne
ot Another
Des1gnated
Line
of Respondent
Florida Power & L1ght Company

N~me

(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

CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
MYAKKA
MYAKKA
MYAKKA
MYAKKA
MYAKKA
MYAKKA
MYAKKA
MYAKKA
VENICE
VENICE
VENICE
VENICE
VENICE
LAURELWOOD
LAURELWOOD
LAURELWOOD
LAUREL\.IOOD
LAURELWOOO
LAURELWOOD
LAURELWOOO
LAURELWOOD
LAURELWOOD
LAURELWOOD
BRADENTON
BRADENTON
CORTEZ
CORTEZ
CORTEZ
CORTEZ
CORTEZ

36
FERC FORM NO. 1 (ED. 12-87)

I

I

(b)

MYAKKA
MYAKKA
MYAKKA
MYAKKA
MYAKKA
VENICE
VENICE
VENICE
VENICE
VENICE
VENICE
VENICE
ROTONDA RADIAL
LAURELWOOO
LAUREL\.1000
LAUREL WOOD
LAURELWOOO
LAURELWOOO
VENICE NO 2
VENICE NO 2
HOWARD
HOWARD
HOWARD
HOWARD
HOWARD
HOWARD
HOWARD
HOWARD
FRUIT INDUSTRIES
FRUIT INDUSTRIES
RINGLING
RINGLING
RINGLING
RINGLING
RINGLING

(c)

(e)

(d)

HH:88 HH:88

~~

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
138.00
138.00
138.00
138.00
138.00
138.00
138.00

SP
H
H
SP
SP
SP
SP
SP
SP
H
SP
SP
SP
SP
SP
H
SP
H
H
SP
SP
SP
SP
SP
H
SP
SP
SP
H
SP
SP

138.00
230.00
230.00
138.00
138.00
138.00
138.00
138.00
138.00
230.00
138.00
138.00
138.00
138.00
138.00
230.00
138.00
230.00
138.00
138.00
138.00
138.00
138.00
138.00
230.00
230.00
138.00
138.00
138.00
138.00
138.00

(h)

8

HH:88
TOTAL
Page 422.31

(g)

(f)

14.90
0.72
0.62
3.57
0.06
0.06
7.47
4.46
0.13

0

0

0.62

6.91
2.05
0.08
0.03
0.07
3.83
2.13

0
0

0

1

0

1

0
0

0

2
1
1
1
1
1
1
2
1
1
1
1
1

0

2

0

1
2
1
1

0
0

0
0

0
0

0

3.58

0. 04
1.92
2.54
0.29
3.32
10.22

0
0

0

1

0

1

0

1

0

1

0
0

3.83
0.32

2

0. 74

0

1

1.24
1.33
1.67
0.95

0
0
0
0

1
1

1~:~~

8

2

1
1

 Year of Report
Date of Report
(Mo, Da, Yl")
Dec . 31, 1996
( 2 [ A Resuomission
----------------------------~---TRANSMISSION LINE STAT ISTICS (Continued)
respondent operates or shares in the operation of, furnish a
7. Do not repo r rne same transmission line structure twice.
Report lower vol t age lines and higher voltage lines as one
succinct statement explaining the arrangement and giving
line. Designate in a footnote if you do not inc l ude lower
particulars (details) of such matters as percent ownership by
voltage lines with higher vo l tage lines. If two or more trans respondent in the line, name of co-owner, basis of sharing
expenses of the line,and how the expenses borne by the responmission line structures support lines of the same voltage,
report the pole miles of the primary structure in column (f)
dent are accounted for, and accounts affected.Specify whether
and the pole miles of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company .
8. Designate any transmission line or portion thereof for
9. Designate any transmission line leased to another company
which the resoondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annua l rent
is leased fr c another company, give name of lessor, date and
for year, and how determined. Specify whether lessee is an
terms of leasE ._, nd amount of rent for year. For any transmiassociated company.
ssion line other than a leased line, or portion thereof, for
10. Base the plant cost figures called for in columns (j) to
which the respondent is not the sole owner but wh i ch the
(l) on the book cost at end of year.

of Respondent
Florida Power & L1gh t Company

t 9 i s [~elp~~to~~~inal

N~me

rS~e of
Co uctor
and Material

( i)
ACSRA\.1
g~~ ACSRAZ
795 ACSRAZ
795 ACSRAZ
954 ACSRAZ
795 ACSRAZ
954 ACSRAZ
954 ACSRAZ
795 ACSRAZ
795 ACSRAZ
954 ACSRAZ
95~ ACSRAZ
954 ACSRA\.1
954 ACSRA\.1
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
795 ACSRAZ
1431 ACSRA\.1
954 ACSRA\.1
795 ACSRAZ
795 ACSRA\.1
954 ACSRA\.1
954 ACSRAZ
795 ACSRAZ
954 ACSRAZ
954 ACSRA\.1
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
795 ACSRAZ
' 7os ACSRA\.1

I

COST OF LINE (Include in column (j) land,
land rights, and clearing right-of-way)
Construction and
Total Cost
Land
Other Costs
(j)

(k)

(l)

I

I

EXPENSES, EXCEPT DEPRECIATION AND TAXES
Operation
Expenses

Maintenance
Expenses

Rents

(m)

(n)

(0)

Total
Expenses

Line
No.

(p)

1
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

~~

AA
· ~9~ A
CSRAZ

36
FERC FORM NO. 1 (ED. 12 -87)

Page .. 23.3 1

 of Respondent
Florida Power & L1ght Company

N~me

I~isr~elp~~to~~~inal

I (2) [
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 Uni·
form 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 report·
ed in column(~) is:(1) single pole,wood or steel;(2) H-frame,
wood, or steel poles; (5) tower; or (4) underground construe·

A Resuemission

VOLTAGE (KV)
(lnd1cate wliere
other thao
6D cycle,5 phase)
Liner-----------------------,------------------------t----~--r-~--~
Operating Designed
No.
From
To
(a)

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

(b)

Date of Report
(Mo, Da, Y)')

I

Year of Report
Dec. 31, 1996

tion. If a transmission line has more than one type of support·
ing 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 stru·
ctures 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.

DES! GNAT! ON

1
2
3
4
5
6

I

Type of
Supporting
Structure

LENGTH (Pole miles)
(In the case 9f
Number
undergrovnd 11nes
report c1rcu1t ml[es)
of
On Structure On Structures Circuits
of L1ne
ot_Another
Des1~~~ted
L1ne(g)
(h)

(C)

(d)

H~:88

HB:88

~

8:6~

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
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

H
SP
SP
SP
H
H
SP
SP
SP
SP
SP
SP
H
H
SP
SP
H
SP
SP
SP
SP
H

4.27
0.42
0.10
1.86
0.06
2.77
2.06
0.06
0.01
2.57
0.04
6.22
0.15
7.84
0.10
0.21
0.23
8.63
1.02
0.26
2.19
1.26

(e)

CORTEZ
CORTEZ
JOHNSON
JOHNSON
JOHNSON
JOHNSON
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
CHARLOTTE
B_RADENTON
BRADENTON
BRADENTON
JOHNSON
JOHNSON
JOHNSON
JOHNSON
CORTEZ
CORTEZ
RINGLING
RINGLING
RINGLING
RINGLING

RINGLING
RINGLING
FRUIT INDUSTRIES
FRUIT INDUSTRIES
FRUIT INDUSTRIES
FRUIT INDUSTRIES
PUNTA GORDA RADIAL
PUNTA GORDA RADIAL
PUNTA GORDA RADIAL
PUNTA GORDA RADIAL
PUNTA GORDA RADIAL
CORTEZ
CORTEZ
CORTEZ
RINGLING
RINGLING
RINGLING
RINGLING
JOHNSON
JOHNSON
SARASOTA
SARASOTA
SARASOTA
SARASOTA

TOTAL POLE MILES AT 115KV
TOTAL MILES AT 115KV

OVERHEAD
UNDERGROUND

668.87
0.18

TOTAL POLE MILES AT 69KV
TOTAL MILES AT 69KV

OVERHEAD
UNDERGROUND

166.02
11.42

SP=SINGLE POLE
UG=UNDERGROUND

H=MULTIPLE POLE
T=TOIIER

0.0~
0

0

1
1

0

1

0

1
1
1
1
1

0
0
0
0
0

0
0
0
0
0
0

1
1
1
1
1
1
1

0

1

0
0

1
1
1

0
0

1

0.50

2

0

1

"--~------------------------~-----------------------L------~L-----~------------~--~~~~+-----------4-----~
I

36
FERC FORM NO. 1 (ED. 12·87)

TOTAL

Page 422.32

5,625.93

367.92

1,393

 Date of Report
Year of Report
Th is Report 1$: .
(Mo, Da, Yn
(1) [XJ An Or1g1nal
(2) [
A Resuemission
Dec . 31, 1996
TRANSMISSION LINE STATISTICS (Continued)
respondent operates or shares in the operation of, furn i sh a
7. Do not report the same transmission line structure twice .
succinct statement explaining the arrangement and g1v1ng
Report lowe r voltage lines and higher voltage lines as one
line. Designate in a footnote if you do not include lower
particulars (details) of such matters as percent ownership by
voltage lines with higher voltage lines. If two or mo re trans ·
respondent in the line, name of co-owner, bas is of shar i ng
expenses of the line,and how the expenses borne by the responmission line structures support lines of the same voltage,
dent are accounted for, and accounts affected.Spec i fy whether
report t h ~ ~0 le miles of the primary structure in column (f)
and t h•
· i les of the other line(s) in column (g).
lessor, co-owner, or other party is an associated company.
8. (
c any transmission line or portion thereof fo r
9. Designate any transmiss ion line leased to another company
wh i ch t he ,. .o-spondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent
i s leased from another company, give name of lessor, date and
for year, and how determined. Specify whether lessee i s an
associated company.
terms of lease, and amount of rent for year. For any transmi ·
10. Base the plant cost figures called for i n columns (j) to
ssion line other than a leased line, or portion thereof, for
which the respondent is not the sole owner but which the
(l) on the book cost at end of year .

N9me of Respondent
Florida Power & L1ght Company

of
Conduc t · ·
and Ma •
-~
Si~e

( i)

I

I

I

COST OF LINE (Include in column (j) land,
EXPENSES, EXCEPT DEPRECIATION AND TAXES
land rights, and clearing right-of-way)
~------~--~.-------~~--~------~------~------~-----.----~----------.--------------.--------~--~Line
Land
Construction and
Total Cost
Operation
Maintenance
Rents
Total
No.
Other Costs
EXpenses
Expenses
Expenses
(j)

(k)

( l)

(m)

(n)

(o)

(p)

ACSRAZ
ACSRAZ
2·3368 ACSRAZ
795 ACSRAZ
954 ACSRAII
795 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAZ
954 ACSRAII
954 ACSRAZ
79? ACSRAZ
954 ACSRAII
795 ACSRAZ
795 ACSRAZ
2· 3368 ACSRAZ
954 ACSRAII
795 ACSRAZ
1127 AAAC
954 ACSRAZ
795 AA
795 ACSRAZ
795 AA
795 ACSRAZ

3
4
5
6
7
8
9

10
11
12
13
14
15
16
17
18
19
20
21
22

$238,955,180

$1,084,501,129

$1, 323 , 456,309

$11,342,081

$9,351,588

$16,216

23
24
25
26
27
28
29
30
31
32
$20, 709,885 33

$238, 95 5, 180
o= Rr •QRM NO . 1 ( ED. 12· 87)

$1,084, 50 1,1 29

$11,342, 081
$1 ,323,456 ,309
Page 423.32

$9,3 51, 588

$16,216

$20, 709, 885

TOTAL

,_.-

~~
36

 <

Page 422 Line 17 Column a

>

The Duval-Hatch and Duval-Thalmann 500 KV lines are jointly owned
by the respondent (0.5%) and Jacksonville Electric Authority
(99.5%). Expenses of these lines 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.

<

Page 422 Line 18 Column a >

See footnote for line 17 above.

Page 422-423 Footnote.1

 Year of Report
Date of Report
This Report Is:
(Mo, Da, Yr)
(1) [Xl An Or1ginal
Dec. 31, 1996
(2) [ A ResuElmission
TRANSMISSION LINES ADDED DURING YEAR
ground construction and show each transmission line separate1. Report below the information called for concerning
ly. If actual costs of completed construction are not readily
transmission lines added or altered during the year. It is
available for reporting columns (l) to (o), it is permissible
not necessary to report minor revisions of lines.
to report in these columns the estimated final completion
2. Provide separate subheadings for overhead and under-

of Respondent
Florida Power & L1ght Company

N~me

LINE DESIGNATION
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
35
36
37
38
39
40
41
42
43
44

I

I

I

From

To

Line
Length
In
M1 les

(a)

(b)

(c)

CIRCUITS PER
STRUCTURE

SUPPORTING
STRUCTURE
Type
(d)

Avebage
Num er
M1Pfres
(e)

Ultimate

Present
(f)

(g)

OVERHEAD TRANSMISSION LINES

--------------------------RANCH

MIDIIAY

DADE

FLAGAMI

0.40

1POLE CONCR

1

1

(0.31)
(0. 15)
(0.04)
(0.03)
(0. 15)
(0.43)
(0.05)
0.06
0.34
0.03

1POLE
2POLE
1POLE
1POLE
2POLE
1POLE
1POLE
1POLE
1POLE
1POLE

CONCR
IIOOD
IIOOD
IIOOD
11000
11000
11000
CONCR
CONCR
CONCR

1
2
1
1
2
1
1
1
1
1

1
1
1

0. 71
2.06
1.40
2.78
0.09

1POLE
2POLE
1POLE
1POLE
1POLE

IIOOD
CONCR
CONCR
CO NCR
CO NCR

1
2
1
2
1

1
2
1
2
1

1POLE
1POLE
2POLE
2POLE
1POLE

11000
CO NCR
CO NCR
IIOOD
CO NCR

1
1
2
1
1

MALABAR

HARRIS

-EAU

MALABAR

(0.18)
(0.01)
(2.06)
(4.01)
(0.07)

CONSERVATION

CORBETT

56.66

2POLE STEEL

1

C-5

624-A

(5.60)

2POLE IIOOD

1

BARNA

C-5

1.39
14.36
0.22

1POLE CONCR
1POLE CONCR
2POLE CONCR

1
2
2

1
2
2

624-A

BARNA

4.23
0.22
14.36

1POLE CO NCR
2POLE CO NCR
1POLE CO NCR

1
2
2

1
2
2

GALLI E

TOTAL

FERC FORM N0.1 (ED. 12-86)

Page 424

1

 of Respondent
Florida Power & L1ght Company

Yea r of Report
Dec . 31 , 1996

N~me

I

TRANSMISSION LINES ~ ED DURING YEAR (Continued)
3. t design voltage differs from ope r ating voltage,
costs. Designate, however, i f estimated amount s are r e ~. t ed.
Include cos t s of Clearing Land and Rights-of-Way, and R ds
indi c< such fact by footnote; also where l i ne is other
than 6u cycle, 3 phase, indicate such other characteri s tic.
and Tra i l s , in column (l) with appropriate footnote, ana
costs of Underground Condu i t i n column(m).
Ll NE COST

CONDUCTORS
Size
(h )

-

Specificat i on

Configuration
and Spac1ng

vogage
(Operating)

~-----------,--------------,-----------,-------------~Li ne

Land ~nd
Land R1ghts

Poles, Towers
and rixtures

Conductors
and Dev1ce

No.

Total

(n)
(i)
(j)
(k)
(l)
(m)
(o)
--~----------~----~------~----------+-----------1-----------~-----------+-------------+~1-1

1431

ACSR/AW

41V

230

101,513

90,112

191,625

954
795
954
954
795
795
795
954
954
795

ACSR/AZ
ACSR/AZ
ACSR/AZ
ACSR/AZ
ACSR/AZ
ACSR/AZ
ACSR/AZ
ACS R/AW
ACSR/AW
ACSR/AZ

31V1
32V1
31T
31T
32V
31T
31T
31V1
31V
31V

230
138
138
138
138
138
138
138
138
138

475' 259

78,704

553,963

795
795
795
795
795

ACSR/AZ
ACSR/AZ
ACSR/AZ
ACSR/AZ
ACSR/AZ

31V
42T
31V
32V
31V

138
138
138
138
138

795
795
795
795
795

ACSR/AZ
ACSR/AZ
ACSR/AZ
ACSR/AZ
ACSR/AZ

31V
31V
42H
31H
31T

138
138
138
138
138

3-1435

AAAC

51H1

500

26,821,433

36,776,848

24,159,479

87,757,760

350

CUHT

31H

115

1,359, 993

2,229,629

1,855,426

5,445,048

350
556.5
556.5

CUHT
ACSR/AW
ACSR/AII

31T
32V1
32H1

11 5
115

350
556.5
5556.5

CUHT
ACSR/AW
ACSR/AW

31T
32V1
32V1

115

RMN0 . 1 d'.J . 12-86)

2
3
4
5
6
7

8
9

10

11

628

36,882

73,525

36,015

*

*

115

*

115
115

Page 425

0

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

 N9me of Respondent
Florida Power & L1ght Company

I

t~~s[~elp~~to~~~inal
(2) [ A Resuemission

I

I

Date of Report
(Mo, Da, Yr)

Year of Report
Dec. 31, 1996

TRANSMISSION LINES ADDED DURING YEAR
ground construction and show each transmission line separate·
1. Report below the information called for concerning
transmission lines added or altered during the year. It is
ly. If actual costs of completed construction are not readily
not necessary to report minor revisions of lines.
available for reporting columns (l) to (o), it is permissible
2. Provide separate subheadings for overhead and underto report in these columns the estimated final completion
LINE DESIGNATION
Liner---------------------------.-------------------------~

No.

From

To

(a)

1

BRADFORD

(b)

STARKE #2

2
3

SUPPORTING
STRUCTURE

Line
Length
Jn
M1les

Type

(c)

(d)

CIRCUITS PER
STRUCTURE
Average
Number
per
M1Les
(e)

Present

Ultimate

(f)

(g)

(1.00)
( 1. 26)
(0.03)

1POLE CONCR
1POLE IIOOD
1POLE CONCR

2

1.00
1.26
0.03

1POLE CONCR
1POLE IIOOD
1POLE CONCR

2

1
1

4

5

BRADFORD

COLUMBIA

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

MORRIS

IIHIDDEN

(7.22)
0.13

6.12
(3.70)
3.70
ANDYTOIIN

FLAGAMI

ANOYTOIIN

CHAPEL RADIAL

1POLE
1POLE
1POLE
1POLE
1POLE

1
1

IIOOD
CONCR
IIOOD
IIOOD
CONCR

4.20

1POLE CONCR

(4.20)
(0.01)
(0.86)

1POLE CONCR
1POLE CONCR
2POLE IIOOD

2

(0.13)
(0.01)

2POLE IIOOD
1POLE IIOOD

2
1

-----------------------------MIAMI PLANT
LITTLE RIVER

(2.80)

PIPE

C5

624-A

(0.21)

PIPE

624-A

BARNA

0.18

PIPE

VENICE

VENICE DIST RADIAL

2
1
1

1
1

UNDERGROUND TRANSMISSION LINES

33

34
35
36
37
38
39
40
41
42
43
44

TOTAL

FERC FORM NO.1 (ED. 12-86)

81.41

Page 424.1

0

62

33

 Year of Report
Date of Report
This Report 1$:
(Me, Da, Yr)
(1) [Xl An Or1ginal
Dec. 31, 1996
(2) [ A Resuemission
TRANSMISSION LINES ADDED DURING YEAR (Continued)
3. If design voltage differs from operating voltage,
costs. Designate, however, if estimated amounts are reported.
indicate such fact by footnote; also where line is other
Include costs of Clearing Land and Right s- of-~ay, and Roads
than 60 cycle, 3 phase, indicate such other characteristic.
and Trails, in column (l) with appropriate footnote, and
costs of Underground Conduit in column(m).

of Respondent
Florida Power & L1ght Company

N~me

I

I

CONDUCTORS
Specification
(h)

I

LINE COST
Configuration
and spac1ng
(j)

( i)

Voltage
KV .
(Operat1ng)
(k)

r-------------.--------------.------------,---------------~Li ne

Land and
Land R1ghts
(l)

p~Aasti~~~~~~
<m>

(n)

22V
21T
21V

115
115
115

22V
21T
21V

115
115
115

53,348

69
69
69
69
69

16,302

AAAC

11T
31T
31T
11T
31T

954

ACSR/A~

41V1

230

11,422

954
1431
1431

ACSR/A~

ACSR/A~

41V1
41V2
42T

230
230
230

13,452

ACSR/A~

954
954

ACSR/AZ
ACSR/AZ

32V1

138
138

954
336.4
336.4
954
336.4
336.4
2/0
336.4
336.4
2/0
3!0

ACSR/A~

ACSR/AZ
ACSR/AZ
ACSR/A~

ACSR/AZ
ACSR/AZ

cu
ACSR/AZ
{CSR/AZ
;;u

31V

No.

Total

Conductors
and Dev1ce

(c)

*

0

19,100

72,448

240,314

224,012

11,422
55,857

42,405

*

350

cu

11CBL

69

1250

cu

31CBL

115

*

1250

cu

31CBL

115

*

2,622

$28, 182,D54

0. 1 (ED .

So >

4
5

6
7
8

0

FERC FORM

1

2
3

Page 425.1

$39,717 , 277

3,390

768

$26, 506,021

$94,-05, 352

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

 <

Page 425 Line 24 Column o

>

Included in line costs reported on line 18.

<

Page 425 Line 34 Column o

>

Included in line costs reported on line 32.

<

Page 425 Line 38 Column o

>

Included in line costs reported on line 32.

<

Page 425.1 Line 1 Column o >

Included in line costs reported on line 5.

<

Page 425.1 Line 21 Column o

>

Removal costs only.

<

Page 425.1 Line 28 Column o >

Included in line costs reported on line 32, page 425.

<

Page 425.1 Line 30 Column o >

Included in line costs reported on line 32, page 425.

Page 424-425 Footnote.1

 Year of Report
Date of Report
This Report 1$:.
(Mo, Da, Yr)
(1) [Xl An Or1g1nal
(2)
[
A
ResuElmission
Dec.
31, 1996
I
SUBSTATIONS
1. Report below the information called for concernresale, may be grouped according to functional character,but
ing substations of the respondent as of the end of the
the number of such substations must be shown.
year.
4. Indicate in column (b) the functional character of each
2. Substations which serve only one industrial or
substation, designating whether transmission or distribution
street railway customer should not be listed below.
and whether attended or unattended. At the end of the page,
summarize according to function the capacities reported for
3. Substations with capacities of less than 10 MVa
except
those serving customers with energy
for
the individual stations in column (f).
VOLTAGE (In MVa)
Line
Name and Location of Substation
Character of Substation
Primary
No.
Tertiary
Secondary
(a)
(b)
(c)
(d)
(e)
1
ABERDEEN
Distribution
230.00
24.00
2
ACME
Distribution
138.00
24.00
3
ACE RAGE
Distribution
230.00
24.00
4
ADAMS
Distribution
230.00
24.00
5
AIRPORT
Distribution
138.00
13.00
6
AIRPORT
Distribution
138.00
13.80
7
ALI CO
Transmission
240.00
138.00
8
ALLIGATOR
Distribution
138.00
24.00
9
ALVA
Distribution
230.00
24.00
10
ANDYTOIIN
Transmission
525.00
241.00
34.50
11
ARCADIA
Distribution
138.00
13.80
12
ARCH CREEK
Distribution
138.00
13.80
13
ATLANTIC
Distribution
138.00
13.80
14
AUBURN
Distribution
230.00
24.00
15
AURORA
Distribution
138.00
13.80
16
AVENTURA
Distribution
22.90
13.20
17
AVENTURA
Distribution
230.00
13.80
18
AVIATION
Distribution
138.00
13.80
19
AVOCADO
Distribution
138.00
24.00
20
BABCOCK
Distribution
138.00
24.00
21
BALDWIN
Transmission
230.00
115.00
13.20
22
BANANA RIVER
Distribution
138.00
13.80
BARNA
23
Transmission
230.00
115.00
24
BASSCREEK
Distribution
230.00
24.00
25
BEELINE
Distribution
138.00
13.80
26
BEKER
Distribution
138.00
13.80
27
BELL
Distribution
138.00
13.80
BELLE GLADE
28
Distribution
138.00
13.80
29
BELVEDERE
Distribution
138.00
13.80
30
BELVEDERE
Distribution
138.00
13.00
31
BELVEDERE
Distribution
138.00
13.80
BENEVA
Distribution
32
138.00
13.80
BEVERLY
Distribution
33
138.00
13.80
34
BIG THREE
Distribution
66.00
13.00
35
BIRD
Distribution
138.00
13.80
36
37
38
39
40
of Respondent
Florida Power & L1ght Company

N~me

I

-

FERC FORM NO. 1 (ED. 12-96)

Page 426

 I

Date of Report
Year of Report
This Report Is: .
(Mo, Da, Yt")
(1) (Xl An Or1g1nal
(2) (
A ResuDn1ission
Dec. 31, 1996
SUBSTATIONS (Continued)
of lessor, date and period of lease, and annual rent. For any
5. Show in columns (i),(j),and <k> special equipment such
substation or equipment operated other than by reason of sole
as rotary converters, rectifiers, condensers, etc. and auxownership or lease, give name of co-owner or other party, exiliary equipment for increasing capacity.
plain basis of sharing expenses or other accounting between
6. Designate substations or major items of equipment leased
from others,jointly owned with others, or operated otherwise
the parties, and state amounts and accounts affected in responthan by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, give name
co-owner, or other party is an associated company.
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Number
of
Numblr of
Trans ormers
r----------------------------------.--------~~--.---~----~--_,Line
Ca~acity of Substation
Sp~re
( n Serv1ce) (In MVa)
1n Serv1ce
Trans ormers
Type of Equipment
Number of Units Total Capacity
No.
(i)
(j)
(ln(~~a)
(g)
(f)
(h)
1
55.00
1
0
2
110.00
2
0
3
2
0
60.00
4
1
0
30.00
5
2
0
28.00
6
2
112.00
0
7
1
224.00
0
8
0
165.00
3
9
60.00
2
0
10
3,000.00
6
0
11
56.00
3
0
12
0
90.00
2
13
56.00
2
0
14
110.00
0
2
15
90.00
2
0
16
11.00
1
0
17
90.00
2
0
18
90.00
2
0
19
1
0
30.00
20
0
165.00
3
21
1
0
300.00
22
2
0
41.00
23
1
0
300.00
24
3
0
165.00
25
3
0
135.00
26
1
0
14.00
27
2
0
60.00
28
2
0
56.00
29
1
0
28.00
30
1
0
14.00
31
1
0
28.00
32
0
2
60.00
33
3
0
134.00
34
0
3
18.00
35
2
0
90.00
36
Name of Respondent
Florida Power & L1ght Company

-

,..-

37

38
39
40

FERC FORM NO. 1 (ED. 12-96)

Page 427

Next Page is 429

 of Respondent
Florida Power & L1ght Company

N~me

I

t~~s[~elp~~to~~~inal
(2) [ A ResuExnission

SUBSTATIONS
1. Report below the information called for concerning substations of the respondent as of the end of the
year.
2. Substations which serve only one industrial or
street railway customer should not be listed below.
3. Substations with capacities of less than 10 MVa
except
those serving customers with energy
for
Name and Location of Substation

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
35
36
37
38
39
40

-

{a)
BISCAYNE
BLUE LAGOON
BOCA RATON
BOCA TEECA
BONITA SPRINGS
BORDEN
BORDEN
BORDEN
BOULEVARD
BOYNTON
BRADENTON
BRADFORD
BRADFORD
BRANDON
BREVARD
BRIGHTON
BROIJARD
BUCKEYE
BUENA VISTA
BUENA VISTA
BUENA VISTA
BULOIJ
BUNNELL
BUTTS
CALDWELL
CAPE CANAVERAL PLANT
CAPE CANAVERAL PLANT
CAPRI
CARLSTROM
CASTLE
CEDAR
CELERY
CELERY
CHAPEL
CHARLOTTE

FERC FORM NO. 1 (ED. 12-96)

I

Date of Report
(Mo, Da, Yr)

Year of Report
Dec. 31, 1996

resale, may be grouped according to functional character,but
the number of such substations must be shown.
4. Indicate in column (b) the functional character of each
substation, designating whether transmission or distribution
and whether attended or unattended. At the end of the page,
summarize according to function the capacities reported for
the individual stations in column (f).
VOLTAGE (In MVa)
Character of Substation
Primary
Secondary
Tertiary
(c)
(d)
(e)
(b)
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
24.00
Distribution
Distribution
13.20
4.16
Distribution
22.90
13.20
Distribution
230.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Transmission
13.20
138.00
115.00
Transmission
230.00
13.80
115.00
Distribution
138.00
13.80
Transmission
230.00
138.00
Distribution
66.00
13.80
Transmission
230.00
13.20
138.00
Distribution
230.00
24.00
Distribution
138.00
13.00
Distribution
4.16
13.80
Distribution
138.00
13.80
115.00
Distribution
13.80
Transmission
230.00
130.00
13.80
Distribution
230.00
13.80
Distribution
138.00
13.80
Transmission
238.00
21.60
Transmission
230.00
130.00
13.20
Distribution
138.00
24.00
Distribution
230.00
24.00
Distribution
230.00
24.00
Transmission
230.00
138.00
Distribution
22.90
13.20
Distribution
115.00
13.80
Distribution
230.00
24.00
Transmission
230.00
138.00
13.80

Page 426 1

 Yea r of Report
Date of Report
T~h~l~· sfXRelpAort
Is:.
n 0 r1
g1 na l
(Mo, Da, Yl")
Dec. 31, 1996
A Resuomission
SUBSTATIONS (Continued)
5. Show in columns (i),(j),and (k) special equipment such
of lessor, date and period of lease, and annual rent. For any
substation or equipment operated other than by reason of sole
as rotary converters, rectifiers, condensers, etc. and aux iliary equipment for increasing capacity.
ownership or lease, give name of co-owner or other party, ex6. Designate substations or major items of equipment leased
plain basis of sharing expenses or other accounting between
from others,jointly owned .with others, or operated otherwise
the parties, and state amounts and accounts affected in responthan by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, give name
co-owner, or other party is an associated company.
Number of
Number of
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Capacity of Substation
Spijre
Transformers
r---------~----~~~-------------.~~----~~--~--~~--~~_,Line
(ln Serv1c
' "1 MVa)
1n Serv1ce
Type of Equipment
Number of Units Total Capacity
No.
Transformers
(i)
(j)
(ln(~~a)
(t,
(g)
(h)
90.00
2
0
1
56.00
2
0
2
0
3
88.00
3
0
135.00
3
4
165.00
0
3
5
22.00
2
6
0
11.00
1
0
7
60.00
2
0
8
112.00
0
9
2
88.00
3
0
10
90.00
2
11
0
224.00
1
0
12
2
0
400.00
13
2
60.00
0
14
1,000.00
2
0
15
2
16.00
0
16
1,120.00
2
0
17
110.00
2
0
18
2
28.00
0
19
5.00
1
0
20
56.00
2
0
21
0
2
60.00
22
300.00
1
0
23
90.00
24
2
0
56.00
2
0
25
0
2
26
920.00
392.00
2
0
27
0
28
60.00
2
0
29
60.00
2
3
0
30
145.00
2
0
31
900.00
0
2
32
22.00
0
60.00
33
2
34
55.00
1
0
35
224.DD
2
0
36
37
38
39
40
of Respondent
Florida Power & L1ght Company

N~me

,....

FERC FORM NO. 1 (ED. 12-96)

I

Page 427 1

I

Next Page is 429

 Year of Report
This Report Is: .
Date of Report
(1) [Xj An Or1g1nal
(Mo, Da, Y'r)
Dec. 31, 1996
(2) [ A Resuemission
SUBSTATIONS
resale, may be grouped according to functional character,but
1. Report below the information called for concernthe number of such substations must be shown.
ing substations of the respondent as of the end of the
4. Indicate in column (b) the functional character of each
year.
substation, designating whether transmission or distribution
2. Substations which serve only one industrial or
street railway customer should not be listed below.
and whether attended or unattended. At the end of the page,
summarize according to function the capacities reported for
3. Substations with capacities of less than 10 MVa
except
those serving customers with energy
for
the individual stations in column (f).
VOLTAGE (In MVa)
Name and Location of Substation
Line
Character of Substation
Primary Secondary
No.
Tertiary
(a)
(b)
(c)
(d)
(e)
1
CHARLOTTE
Transmission
138.00
69.00
7.60
CHULUOTA
Distribution
230.00
24.00
2
CITY POINT
3
Distribution
138.00
13.80
4
CITY POINT
Distribution
131.00
13.80
5
CLARK
Distribution
138.00
13.80
138.00
13.80
6
CLEARLAKE
Distribution
Distribution
138.00
13.80
7
CLEVELAND
CLEVELAND
Distribution
138.00
13.80
8
9
CLEIIISTON
Distribution
138.00
13.80
10
CLINTMOORE
Distribution
230.00
24.00
11
COCOA
Distribution
138.00
13.80
12
COCOA
Distribution
138.00
13.80
13
COCOA
Distribution
66.00
13.00
14
COCOA BEACH
Distribution
138.00
13.80
15
COCONUT GROVE
Distribution
138.00
13.80
16
COCOPLUM
Distribution
138.00
24.00
17
COLLEGE
Distribution
230.00
13.80
Transmission
230.00
138.00
18
COLLIER
13.20
COLONIAL
19
Distribution
138.00
13.80
20
COLONIAL
Distribution
138.00
13.80
COLUMBIA
Distribution
21
115.00
13.80
22
COMO
Distribution
115.00
13.80
CONSERVATION
Distribution
23
230.00
24.00
COPANS
24
Distribution
138.00
13.80
25
COPANS
Distribution
138.00
13.80
COQUINA
Distribution
26
115.00
24.00
CORAL REEF
Distribution
27
138.00
13.80
Transmission
525.00
241.50
CORBETT
34.50
28
Distribution
29
CORTEZ
138.00
24.00
CORTEZ
Distribution
138.00
13.80
30
COUNTRY CLUB
Distribution
138.00
13.80
31
COUNTY LINE
Distribution
138.00
13.80
32
Distribution
138.00
24.00
33
COURT
Distribution
COURTENAY
131.00
13.80
34
Distribution
138.00
24.00
COVE
35
36
37
38
39
40
of Respondent
Florida Power & L1ght Company

N~me

I

I

-

FERC FORM NO. 1 (ED. 12-96)

Page 426 2

 I

Year of Report
Date of Report
This Report Is:.
(Mo, Da, Y)-)
(1) [XJ An Or1g1nal
Dec. 31, 1996
(2) [ A Resuemission
SUBSTAT IONS (Continued)
5. Show in columns (i),(j),and (k) special equipment such
of lessor, date and period of lease, and annual rent. For any
substation or equipment operated other than by reason of sole
as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
ownership or lease, give name of co-owner or other party, ex6. Designate substa t ions or major items of equipment leased
plain basis of sharing expenses or other accounting between
from others,jointly owned ·with others, or operated otherwise
the parties, and state amounts and accounts affected in responthan by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, gi ve name
co-owner, or other party is an associated company.
Number
of
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Numb~r of
Trans ormers
Ca~acity of Substation
r-------~~--~~~-------------,~~--~~~--~--~~--~~Line
Sp~re
( n Serv1ce) (In MVa)
1n Serv1ce
Trans ormers
Type of Equipment
Number of Units Total Capacity
No.
(i)
(j)
(ln(~~a)
(f)
(g)
(h)
of Respondent
Florida Power & L1ght Company

N~me

-

-

50.00
30.00
25.00
28.00
135.00
56.00
14.00
30.00
27.00
165.00
28.00
28.00
11.00
56.00
110.00
110.00
60.00
900.00
28.00
60.00
135.00
30.00
55.00
56.00
28.00
30.00
58.00
2,000.00
110.00
90.00
90.00
90.00
165.00
56.00
60.00

FERC FORM NO. 1 (ED. 12-96 )

1
1
1
1
3
2
1
1
2
3
1
1
2
2
3
2
2
2
1
2
3
1
1
2
1
1
2
3
2
2
2
2
3
2
2

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0
0

I

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

Page 427 2

Next Page is 429

 of Respondent
Florida Power & L1ght Company

N~me

I

I~is[~elp~~to~~~inal

(2) [
SUBSTATIONS
1. Report below the information called for concerning substations of the respondent as of the end of the
year.
2. Substations which serve only one industrial or
street railway customer should not be listed below.
3. Substations with capacities of less than 10 MVa
except
those serving customers with energy
for
Name and Location of Substation

Line
No.

(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
36
37
38
39
40

-

cox
CRANE
CRESCENT CITY
CRESCENT CITY
CRYSTAL
CUTLER
CUTLER PLANT
CUTLER PLANT
CYPRESS CREEK
DADE
DADE
DAD ELAND
DAIRY
DANIA
DATURA STREET
DATURA STREET
DAVIE
DAVIS
DAVIS
DAYTONA BEACH
DEAUVILLE
DEAUVILLE
DEEPCREEK
DEERFIELD BEACH
DELAND
DELMAR
DELTONA
DEL TRAIL
DORR FIELD
DOUGLAS
DRIFTIIOOD
DUM FOUNDLING
DUVAL
EAU GALLIE
EAU GALLIE

FERC FORM NO. 1 (ED. 12-96)

A Resuemission

I

Date of Report
(Mo, Da, Yr)

Year of Report
Dec. 31, 1996

resale, may be grouped according to functional character,but
the number of such substations must be shown.
4. Indicate in column (b) the functional character of each
substation, designating whether transmission or distribution
and whether attended or unattended. At the end of the page,
summarize according to function the capacities reported for
the individual stations in column (f).
VOLTAGE (In MVa)
Character of Substation
Primary
Secondary
Tertiary
(d)
(b)
(c)
(e)
Distribution
230.00
24.00
Distribution
230.00
24.00
Distribution
115.00
13.80
Distribution
115.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Transmission
138.80
13.80
Transmission
138.80
17.30
Distribution
138.00
13.80
Transmission
230.00
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
66.00
4.16
Distribution
230.00
13.80
Transmission
230.00
138.00
13.20
Transmission
138.00
69.00
Distribution
115.00
13.80
Distribution
67.00
13.80
Distribution
67.00
13.80
Distribution
230.00
24.00
Distribution
138.00
13.80
Distribution
115.00
13.80
Distribution
230.00
13.80
Distribution
23D.OO
24.00
Distribution
230.00
24.00
Distribution
138.00
24.00
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Transmission
525.00
241.50
34.50
Distribution
138.00
13.80
Distribution
138.00
13.80

Page 426 3

 1

Date of Report
Year of Report
(Mo, Da, Yr)
Dec. 31, 1996
(2) [ A Resucmission
SUBSTATIONS (Continued)
of lessor, date and period of lease, and annual rent. For any
5. Show in columns Ci),(j),and (k) special equipment such
substation
equipment operated other than by reason of sole
as rotary converters, rectifiers, condensers, etc. and aux·
iliary equipment f c- increasing capacity.
oase, give name of co-owner or other party, ex·
ownership o
sharing expenses or other accounting between
6. Designate sub~ tations or major items of equipment leased
plain basis
from others,jointly owned · with others, or operated otherwise
the parties, and state amounts and accounts affected in respon·
than by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, give name
co-owner, or other party is an associated company.
Number of
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Numb1r of
Caracity of Substation
Trans ormers
~---------------------------------.--------------.-------------~Line
Sp~re
( n Service) (In MVa)
1n Serv1ce
Trans ormers
Type of Equipment
Number of Units Total Capacity
No.
(i)
(j)
(ln(~~a)
(f)
(g)
(h)
of Respondent
Florida Power & Light Company

N~me

-

30.00
60.00
11.00
11.00
84.00
56.00
80.00
180.00
135.00
1,120.00
110.00
110.00
90.00
88.00
56.00
17.00
60.00
1,120.00
50.00
90.00
50.00
50.00
110.00
135.00
3.00
60.00
110.00
110.00
30.00
135.00
90 00
58. 00
3,000.00
2e.oo
28.00

·oRM NO. 1 (ED . 12·96)

Iq~s[~elp~~to~~~inal

1
2
1
1
3
2
1
1
3
2
3
3
2
2
2
2
2
2
1
2
2
2
2
3
1
2
2
2
1
3
2
2
6
1
1

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

I

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

Page 427 3

Next Page is 429

 Year of Report
Date of Report
This Report Is:.
(Mo, Da, Yr)
(1) [XJ An Or1g1nal
Dec.
31, 1996
(2) [ A Resucmission
I
SUBSTATIONS
resale, may be grouped according to functional character,but
1. Report below the information called for concernthe number of such substations must be shown.
ing substations of the respondent as of the end of the
year.
4. Indicate in column (b) the functional character of each
substation, designating whether transmission or distribution
2. Substations which serve only one industrial or
street railway customer should not be listed below.
and whether attended or unattended. At the end of the page,
3. Substations with capacities of less than 10 MVa
summarize according to function the capacities reported for
except
those serving customers with energy
for
the individual stations in column (f).
VOLTAGE (In MVa)
Line
Name and Location of Substation
Character of Subs~ation
Primary Secondary
No.
Tertiar~
(a)
(e)
(b)
(c)
(d)
1
EDGEWATER
Distribution
115.00
13.80
2
EDISON
Distribution
138.00
13.80
3
EDISON
Distribution
13.80
138.00
4
ELKTON
Distribution
115.00
13.80
5.
ELY
Distribution
138.00
13.80
Transmission
230.00
138.00
6
EMERSON
7
ENGLEWOOD
Distribution
138.00
24.00
8
ESTERO
Distribution
138.00
23.00
9
FAIRMONT
Distribution
138.00
13.80
10
FASHION
Distribution
138.00
24.00
11
FISHERMAN
Distribution
13.20
4.16
12
FLAGAMI
Transmission
230.00
138.00
13.80
13
FLAGAMI
Distribution
138.00
24.00
14
FLAGLER BEACH
Distribution
22.90
13.20
15
FLAGLER BEACH
Distribution
115.00
24.00
16
FLEMING
Distribution
115.00
13.80
17
FLORIDA CITY
230.00
138.00
Transmission
18
FLORIDA CITY
Transmission
138.00
69.00
7.10
19
FLORIDA CITY
Distribution
138.00
35.00
20
FLORIDA STEEL
Distribution
230.00
13.80
Distribution
21
FOUNTAIN
230.00
24.00
Distribution
22 . FRANKLIN
138.00
24.00
Distribution
23
FRONTENAC
131.00
13.80
24
FRONTENAC
Distribution
115.00
13.80
Distribution
25
FRONTON
138.00
13.80
26
FRUIT INDUSTRIES
Distribution
138.0D
13.00
27
FRUIT INDUSTRIES
Distribution
138.00
13.80
2.40
28
FRUIT INDUSTRIES
Distribution
138.00
13.00
29
FRUITVILLE
Distribution
230.00
24.00
Distribution
30
FT. MYERS
138.00
13.80
31
FT. MYERS PLANT
Transmission
138.00
20.90
Transmission
32
FT. MYERS PLANT
138.00
69.00
7.20
Transmission
230.00
138.00
33
FT. MYERS PLANT
13.80
Transmission
239.00
34
FT. MYERS PLANT
13.20
35
FT. MYERS PLANT
Transmission
138.00
17.00
36
37
38
39
40
of Respondent
Florida Power & L1ght Company

N~me

FERC FORM NO. 1 (ED. 12-96)

I

Page 426 4

 I

Year of Report
This Report Is:.
I Date
of Report
(Mo, Da, Yr)
(1) [Xl An Or1g1nal
Dec. 31, 1996
(2) [
A ResuElmission
SUBSTATIONS (Continued)
5. Show in co l u~~s (i),(j),and (k) special equipment such
of lessor, date and period of lease, and annual rent. For any
as rotary conve r
rectifiers, condensers, etc. and auxsubstation or equipment operated other than by reason of sole
iliary equipmen t
increasing capacity.
ownership or lease, give name of co-owner or other party, ex6. Designate S L .. . ations or major items of equipment leased
plain basis of sharing expenses or other accounting between
from others,jointly owned -with others, or operated otherwise
the parties, and state amounts and accounts affected in responthan by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, give name
co-owner, or other party is an associated company.
Number of
Number of
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Capacity QT ~ ubstation
Transformers
Spare
r----------------------------------.--------------.-------------~Line
(ln Serv1ce) (In MVa)
1n Service
Transformers
Type of Equipment
Number of Units Total Capacity
No.
(i)
(j)
(ln(~~a)
(f)
(g)
(h)
N9me of Respondent
Florida Power & L1ght Company

110.00
45.00
90.00
30.00
88.00
400.00
110.00
165.00
85.00
60.00
4.00
1,120.00
112.00
11.00
60.00
86.00
400.00
112.00
56.00
60.00
90.00
110.00
28.00
30.00
132.00
28.00
42.00
14.00
110.00
90.00
460.00
50.00
896.00
720.00
180.00

FE RC F

~ 0.

1 (ED. 12-96)

2

0

1

1

0

2

2

0
0
0
0
0

1
3
1

2
3

0

2

0

2

0
0
0

2

2
2

1
2

2
2

0

1

1

5
6
7

8
9
10
11

12
13
14
15
16
17
18
19
20
21

0
0
0
0
0
0
0

3

3
4

2

0

2

0

22

1
1

0

23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40

3

2
3
1
2

0
0
0
0

2

0
0
0

1

0

1

0

4

0
0
0

6
1

Page 427 4

Next Page is 429

 Date of Report
Year of Report
This Report Is:
(1) [XJ An Or1ginal
(Mo, Da, Yr)
Dec. 31, 1996
(2) [ A ResuExnission
SUBSTATIONS
1. Report below the information called for concern resale, may be grouped according to functional character,but
ing substations of the respondent as of the end of the
the number of such substations must be shown.
year.
4. Indicate in column (b) the functional character of each
2. Substations which serve only one industrial or
substation, designating whether transmission or distribution
street railway customer should not be listed below.
and whether attended or unattended. At the end of the page,
3. Substations with capacities of less than 10 MVa
summarize according to function the capacities reported for
except
those serving customers with energy
for
the individual stations in column (f).
VOLTAGE (In MVa)
Line
Name and Location of Substation
Character of Substation
No.
Primary Secondary
Tertiary
(a)
(b)
(c)
(d)
(e)
1
FT. PIERCE
Distribution
138.00
13.80
FULFORD
2
Distribution
138.00
13.80
3
FULFORD
Distribution
138.00
13.80
4
GALLOWAY
Distribution
138.00
13.80
5.
GARDEN
Distribution
138.00
13.80
6
GARDEN
Distribution
138.00
13.80
7
GENERAL ELECTRIC
Distribution
115.00
13.80
8
GENEVA
Distribution
131.00
24.00
9
GERMANTOWN
Distribution
138.00
13.00
10
GERONA
Distribution
115.00
13.80
11
GLADEVIEW
Distribution
138.00
13.80
12
GLADEVIEW
Distribution
138.00
13.80
13
GLENDALE
Distribution
230.00
24.00
14
GOLDEN GATE
Distribution
138.00
24 . 00
15
GOLDEN GLADES
Distribution
138.00
13.80
16
GOLDEN GLADES
Distribution
138.00
13.80
17
GOLF
Distribution
138.00
13.80
18
GOULDS
Distribution
138.00
13.80
19
GRANADA
Distribution
230.00
24.00
20
GRANDVIEW
Distribution
131.00
13.80
21
GRANT
Distribution
138.00
24.00
22
GRAPELAND
Distribution
138 . 00
13.80
23
GRATIGNY
Distribution
138.00
13.80
24
GREENACRES
Distribution
138.00
13.80
25
GREYNOLDS
Transmission
230.00
138.00
13.20
26
GREYNOLDS
Distribution
138.00
13.80
27
GRISSOM
Distribution
115.00
4.16
28
HAINLIN
Distribution
138.00
13.80
29
HALLANDALE
Distribution
138.00
24.00
30
HALLANDALE
Distribution
138.00
24.00
31
HALLANDALE
Distribution
138.00
13.80
32
HARBOR
Distribution
138.00
24.00
33
HARRIS
Distribution
138.00
13.80
34
HASTINGS
Distribution
115.00
13.80
35
HAUL OVER
Distribution
138.00
13.80
36
37
38
39
40
of Respondent
Florida Power & L1ght Company

N~me

I

I

-

FERC FORM NO. 1 (ED. 12-96)

Page 426 5

 I

Year of Report
Date of Report
This Report Is:
(Mo, Da, Y'r)
(1) [Xl An Or1ginal
Dec. 31, 1996
(2) [ A Resuemission
SUBSTATIONS (Continued)
of lessor, date and period of lease, and annual rent. For any
5. Show in columns (i),(j),and (k) special equipment such
substation or equipment operated other than by reason of sole
as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
ownership or lease, give name of co-owner or other party, ex6. Designate substations or major items of equipment leased
plain basis of sharing expenses or other accounting between
from others,jointly owned with others, or operated otherwise
the parties, and state amounts and accounts affected in responthan by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, give name
co-owner, or other party is an associated company.
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Number of
Numb1r of
Trans ormers
Ca~acity of Substation
r---------~----~~~-------------.~~--~~~--~--~~--~--_,Line
Sp~re
( n Serv1ce) (In MVa)
1n Serv1ce
Trans ormers
Type of Equipment
Number of Units Total Capacity
No.
(i)
(j)
(ln(~~a)
(f)
(g)
(h)
56.00
2
1
0
45.00
1
0
2
45.00
0
3
86.00
3
4
0
25.00
5
0
2
58.00
0
6
7
90.00
2
0
28.00
8
0
90.00
2
0
9
2
60.00
10
0
25.00
11
1
0
76.00
3
12
0
30.00
1
13
0
110.00
2
14
0
28.00
1
15
0
58.00
16
2
0
90.00
2
0
17
56.00
18
2
0
19
55.00
0
2
20
56.00
0
30.00
21
0
80.00
2
0
22
2
90.00
0
23
2
90.00
0
24
560.00
1
25
0
90.00
26
2
0
20.00
27
2
0
28
58.00
2
0
29
55.00
1
0
45.00
1
30
0
2
90.00
31
0
110.00
32
2
0
88.00
33
3
0
34
16.00
2
0
35
111.00
2
0
36
37
38
39
40
N9me of Respondent
Florida Power & L1ght Company

I

,
,

,

,
,

-

FE C FOR M NO. 1 (ED. 12-96)

Page 427 5

Next Page is 429

 of Respondent
Florida Power & L1ght Company

N~me

I

t9~s[~elp~~t 0 ~~~inal
(2) [

A Resucmission

SUBSTATIONS
1. Report below the information called for concerning substations of the respondent as of the end of the
year.
2. Substations which serve only one industrial or
street railway customer should not be listed below.
3. Substations with capacities of less than 10 MVa
except
those serving customers with energy
for
Name and Location of Substation

Line
No.

(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
36
37
38
39
40

-

HAWKINS
HIALEAH
HIALEAH
HIATUS
HIBISCUS
HIELD
HIGHLANDS
HILLCREST
HILLCREST
HILLCREST
HILLS
HILLSBORO
HOBE
HOLLAND PARK
HOLLY HILL
HOLLYBROOK
HOLLYWOOD
HOLMBERG
HOLY CROSS
HOMELAND
HOMESTEAD
HOWARD
HUDSON
HUDSON
HUTCHINSON ISLAND
HYDE PARK
IBM
IMAGINATION
INDIALANTIC
INDIAN CREEK
INDIAN CREEK
INDIAN HARBOR
INDIAN RIVER
INDRIO
INDUSTRIAL

FERC FORM NO. 1 (ED. 12-96)

I

Date of Re~ort
(Mo, Da, Y )

Year of Report
Dec. 31 , 1996

resale, may be grouped according to functional character,but
the number of such substations must be shown.
4. Indicate in column (b) the functional character of each
substation, designating whether transmission or distribution
and whether attended or unattended. At the end of the page,
summarize according to function the capacities reported for
the individual stations in column (f).
VOLTAGE (In MVa)
Character of Substation
Secondary
Tertiary
Primary
(e)
(d)
(b)
(c)
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
230.00
24.00
Distribution
138.00
13.80
Distribution
230.00
24.00
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
13.20
Distribution
4.16
Distribution
66.00
13.00
138.00
13.80
Distribution
138.00
13.80
Distribution
Transmission
230.00
138.00
Distribution
138.00
13.80
Distribution
130.00
24.00
Distribution
230.00
24.00
Distribution
138.00
13.80
Distribution
230.00
24.00
Distribution
138.00
13.80
Distribution
230.00
24.00
Distribution
138.00
13.80
Transmission
230.00
138.00
Distribution
230.00
13.80
Distribution
115.00
13.80
Distribution
230.00
13.00
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
230.00
24.00
Distribution
138.00
13.80
Transmission
138.00
69.00
7.20
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
115.00
13.80
Distribution
138.00
24.00
Distribution
138.00
13.80

Page 426 6

 I~~s[~elp~~to~r~inal
(2) [ A ResuElmission

of Respondent
Florida Power & L1ght Company

N~me

I

Date of Report
(Me, Da, Yr)

I

Year of Report
Dec. 31, 1996

SUBSTATIONS (Continued)
of lessor, date and period of lease, and annual rent. For any
5. Show in columns (i),(j),and (k) special equipment such
as rotary converters, rectifiers, condensers, etc. and auxsubstation or equipment operated other than by reason of sole
ownership or lease, give name of co-owner or other party, exiliary equipment for increasing capacity.
plain basis of sharing expenses or other accounting between
6. Designate substations or major items of equipment leased
the parties, and state amounts and accounts affected in responfrom others,jointly owned with others, or operated otherwise
dent's books of account. Specify in each case whether lessor,
than by reason of sole ownership by the respondent. For
any substation or equipment operated under lease, give name
co-owner, or other party is an associated company.
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Number
of
Numb~r of
Trans ormers
Ca~acity of Substation
~---------------------------------.--------------.---------~--~Line
Sp1re
( n Serv1ce) (In MVa)
Trans ormers
1n Serv1ce
Type of Equipment
Number of Units Total Capacity
No.
(i)
(j)
(In(~~a)
(f)
(g)
(h)

,..-

-

-

84.00
14.00
90.00
110.00
135.00
55.00
60.00
60.00
8.00
3.00
30.00
56.00
400.00
25.00
112.00
160.00
86.00
55.00
134.00
55.00
56.00
224.00
60.00
40.00
56.00
90.00
90.00
100.00
56.00
200.00
112.00
56.00
90.00
30.00
86.00

3
1
2
2
3
1
2
2
1
1
1
2
1
1
2
2
3
1
3
1
2
1
2
1
2
2
3
2
2
2
2
2
2
1
3

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

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

FERC FORM NO. 1 (ED. 12- 96 )

Page 427 6

Next Page is 429

 of Respondent
Florida Power & Ltght Company

N~me

I

i~; s [~elp~~to~~~inal

(2) [
SUBSTATIONS
1 . Report below the information ca l led for concern ing substations of the respondent as of the end of the
year.
2. Substations which serve only one industrial or
street railway customer should not be listed below .
3. Substations with capacities of less than 10 MVa
except
those serving customers with energy
for

Line
No.

Name and Location of Substation

A Resucmission

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

-

INTERLACHEN
INTERNATIONAL
IONA
IVES
JACARANDA
JASMINE
JENSEN
JETPORT
JOHNSON
JOG
JUNO BEACH
JUPITER
JUPITER
KEEN TOliN
KENDALL
KEY BISCAYNE
KILLIAN
KIMBERLEY
KOGER
KROME
KROME
LABELLE
LAKE BUTLER
LAKE IDA
LAKE PARK
LAKEVIEW
LANTANA
LATIN QUARTER
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT
LAUDERDALE PLANT

FERC FORM NO . 1 (EO. 12-96)

Date of Report
(Mo, Da, Yr)

Yea r of Report
Dec. 31, 1996

resale, may be grouped according to functiona l character,but
the number of such substations must be shown.
4. Indicate in column (b) the functional character of each
substation, designating whether transmission or distribution
and whether attended or unattended . At the end of the page,
summarize according to function the capacities reported fo r
the individual stations in column (f).
VOLTAGE (In MVa)
Character of Substation
Primary
Secondary
Tertiary

(a)

1
2
3
4

I

(b)

Distribution
Distribution
Distribution
Distribution
Di stribution
Distribution
Distribution
Distribution
Transmission
Distribution
Distribution
Distribution
Distribution
Transmission
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Transmission
Transmission
Transmission
Transmission
Transmission
Transmission
Transmission

Page 426 7

(C)

138.00
138.00
138.00
138.00
230.00
230.00
138.00
230.00
230.00
230.00
138.00
138.00
138.00
230.00
138.00
138.00
230.00
230.00
230.00
66.00
66.00
138.00
115.00
138.00
138.00
230.00
138.00
230.00
138.00
230.00
239.00
138.00
239.00
138.00
239.00

(d)

13.80
24.00
24.00
13.80
24.00
24.00
13 . 80
24.00
138.00
13.80
13.80
13.80
13.80
69.00
13.80
13.80
13.80
24.00
24.00
4.16
4.16
24 . 00
13.80
13 . 80
13.80
13.80
13.80
13.80
13.80
138.00
13.20
17. 00
17.00
17.00
17.60

(e)

7.50

13.20

 Year of Report
Date of Report
T~h~,~· sfXRelpAort
Is:. na l
n 0 r1g1
(Mo, Da, Yr)
Dec. 31, 1996
A ResuDn1ission
SUBSTATIONS (Continued)
5. Show in columns (i),(j),and (k) special equipment such
of lessor, date and period of lease, and annual rent. For any
as rotary converters, rectifiers, condensers, etc. and auxsubstation or equipment operated other than by reason of sole
iliary equipment for increasing capacity.
ownership or lease, give name of co-owner or other party, ex6. Designate substations or major items of equipment leased
plain basis of sharing expenses or other accounting between
from others,jointly owned with others, or operated otherwise
the parties, and state amounts and accounts affected in responthan by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, give name
co-owner, or other party is an associated company.
Number of
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Numb1r of
Trans ormers
Ca~acity of Substation
r---------=-----~~~-------------.~~----~~--~--~~--~--~Line
Sp~re
( n Serv1ce) (In MVa)
1n Serv1ce
Trans ormers
Type of Equipment
Number of Units Total Capacity
No.
(i)
(j)
(ln(~~a)
(g)
(f)
(h)
of Respondent
Florida Power & L1ght Company

N~me

r--

-

28.00
110.00
165.00
84.00
110.00
110.00
88.00
60.00
448.00
60.00
135.00
28.00
56.00
75.00
110.00
58.00
90.00
110.00
55.00
8.00
15.00
60.00
22.00
30.00
90.00
135.00
86.00
30.00
480.00
1,568.00
480.00
660.00
210.00
210.00
450.00

; ERC FORM NO. 1 (ED. 12-96)

I

1
2
3
3
2
2
3
2
2
2
3
1
2
1
3
2
2
2
1
1
2
2
2
1
2
3
3
1
6
4
3
3
1
0
2

I

0

1

0

2

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
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
36
37
38
39
40

Page 427 7

Next Page is 429

 of Respondent
Florida Power & L1ght Company

N~me

1. Report below the information called for concerning substations of the respondent as of the end of the
year.
2. Substations which serve only one industrial or
street railway customer should not be listed below.
3. Substations with capacities of less than 10 MVa
those serving customers with energy
for
except

Line
No.

Name and Location of Substation
(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
36
37
38
39
40

-

LAUREL
LAURELIJOOD
LAIJRENCE
LAIJRENCE
LAIJTEY
LEJEUNE
LEJEUNE
LEMON CITY
LEVEE
LEIJIS
LINDGREN
LINTON
LITTLE RIVER
LIVE OAK
LOXAHATCHEE
LYONS
LYONS
LYONS
MACCLENNY
MADISON
MALABAR
MALLARD
MANATEE PLANT
MARGATE
MARION
MARKET
MARTIN PLANT
MARTIN PLANT
MARTIN PLANT
MARTIN PLANT
MASTER
MASTER
MATANZAS
MCARTHUR
MCDONNELL

FERC FORM NO. 1 (EO. 12-96)

t~~s[~Jep~~t 0 ~~~inal

I
SUBSTATIONS

(2) [

A Resubmission

I

Date of Re~ort
(Mo, Da , Y )

Year of Report
Dec. 31 , 1996

resale, may be grouped according to functional characte r ,but
the number of such substations must be shown .
4. Indicate in column (b) the functional character of each
substation, designating whether transmission or distribution
and whether attended or unattended. At the end of the page,
summarize according to function the capacities reported fo r
the individual stations in column (f).
VOLTAGE (In MVa)
Character of Substation
Primary Secondary
Tertiary
(b)
(c)
(d)
(e)
Distribution
115.00
4.16
Transmission
230.00
138.00
13.20
138.00
24.00
Distribution
138.00
13.80
Distribution
115.00
13.80
Distribution
138.00
13.80
Distribution
13.80
138.00
Distr i bution
138.00
13.80
Distribution
241.00
34.50
525.00
Transmission
130.00
13.80
Distribution
230 . 00
24 . 00
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
Distribution
115.00
13.80
Distribution
230.00
24.00
24.00
Distribution
138.00
138.00
24.00
Distribution
138.00
13.80
Distribution
115.00
Distribution
24.00
Distribution
131.00
13.80
13.80
Transmission
230.00
138.00
230.00
24.00
Distribution
239.00
20.90
Transmission
138.00
13.80
Distribution
Distribution
138.00
13.00
138.00
Distribution
13.80
Transmission
230.00
130.00
525.00
Transmission
22.00
239.00
19.50
Transmission
Transmission
525.00
240.00
Distribution
138.00
13.80
138.00
Distribution
13.80
115.00
13.80
Di stribution
138 . 00
Distribution
13.80
115.00
13.80
Distribution

Page 426 8

 I

Date of Report
Year of Report
This Report Is:.
(Mo, Da, Ytl
( 1 ) [XJ An Or 1g 1na l
Dec. 31, 1996
(2) [
A Resuemission
SUBSTAT IONS (Continued)
5. Show in columns (i),(j),and (k) special equipment such
of lessor, date and period of lease, and annual rent. For any
as rotary converters, rectifiers, condensers, etc. and aux substation or equipment operated other than by reason of sole
iliary equipment for increasing capacity.
ownership or lease, give name of co-owner or other party, ex6. Designate substations or major items of equipment leased
plain basis of sharing expenses or other accounting between
from others,jointly owned with others, or operated otherwise
the parties, and state amounts and accounts affected in responthan by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, gi ve name
co-owner, or other party is an associated company.
Number of
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Numb~r of
Trans ormers
Ca~acity of Substation
r---------------~--~-------------.--~----~~--.--------------4Line
Sp?re
( n Serv1ce) (In MVa)
1n Serv1ce
Trans ormers
Type of Equipment
Number of Units Total Capacity
No.
(i)
(j)
(ln(~~a)
(f)
(g)
(h)
15.00
0
2
1
448.00
2
0
2
45.00
0
1
3
45.00
1
0
4
16.00
0
2
5
1
45.00
0
6
1
45.00
0
7
56.00
0
2
8
3,000.00
0
6
9
74.00
0
3
10
165.00
0
3
11
90.00
0
2
12
45.00
1
0
13
56.00
0
2
14
110.00
0
2
15
1
56.00
0
16
55.00
1
0
17
90.00
2
0
18
60.00
2
0
19
56.00
0
2
20
2
672.00
0
21
240.00
0
3
22
1,900.00
4
0
23
135.00
3
0
24
90.00
2
0
25
110.00
0
3
26
1
112.00
0
27
2,880.00
4
0
28
660.00
0
3
29
1
3
2,000.00
30
25.00
1
0
31
2
56.00
0
32
2
56.00
0
33
0
118.00
3
34
0
60.00
2
35
36
37
38
39
40
of Respondent
Florida Power & L1ght Company

N~me

,.--

I

-

FE RC FORM NO. 1 (ED. 12-96)

Page 427 8

Next Page is 429

 of Respondent
Florida Power & L1ght Company

Date of Report
(Mo, Da, Yr)

N~me

I

SUBSTATIONS
1. Report below the information called for concerning substations of the respondent as of the end of the
year.
2. Substations which serve only one industrial or
street railway customer should not be listed below.
3. Substations with capacities of less than 10 MVa
except
those serving customers with energy for
Line
No.

Name and Location of Substation
(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
36
37
38
39
40

-

MCGREGOR
MCMEEKIN
MELBOURNE
MELBOURNE
MELBOURNE
MELBOURNE
MERCHANDISE
MERRITT
METRO
MIAMI
MIAMI
MIAMI
MIAMI
MIAMI BEACH
MIAMI BEACH
MIAMI BEACH
MIAMI BEACH
MIAMI BEACH
MIAMI LAKES
MIAMI LAKES
MIAMI SHORES
MIAMI SHORES
MICCO
MIDIIAY
MIDIIAY
MIDIIAY
MILAM
MILAM
MILITARY TRAIL
MILLER
MILLCREEK
MILLS
MIMS
MINING
MINUTEMAN

FERC FORM NO. 1 (ED. 12-96)

Year of Report
Dec. 31, 1996

resale, may be grouped according to functional character,but
the number of such substations must be shown.
4. Indicate in column (b) the functional character of each
substation, designating whether transmission or distribution
and whether attended or unattended. At the end of the page,
summarize according to function the capacities reported for
the individual stations in column (f).
VOLTAGE (In MVa)
Character of Substation
Primary Secondary
Tertiary
(b)
(c)
(d)
(e)
Distribution
230.00
13.80
Distribution
115.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
33.00
4.00
Distribution
138.00
13.00
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
24.00
Transmission
138.00
69.00
7.20
Distribution
13.80
4.00
Distribution
138.00
13.80
Transmission
230.00
138.00
13.20
Distribution
66.00
4.16
Distribution
66.00
32.00
Distribution
138.00
13.80
Distribution
66.00
4.00
Transmission
138.00
69.00
13.80
Distribution
230.00
24.00
Distribution
230.00
13.80
Transmission
230.00
138.00
Distribution
138.00
13.80
Distribution
138.00
13.80
Transmission
525.00
241.00
34.50
Transmission
138.00
69.00
6.30
Transmission
230.00
138.00
13.80
Distribution
22.90
13.20
Distribution
230.00
24.00
Distribution
138.00
13.80
Distribution
230.00
13.80
Transmission
230.00
130.00
Distribution
230.00
24.00
Distribution
115.00
13.80
Distribution
115.00
24.00
Distribution
138.00
13.80

Page 426 9

 N9me of Respondent
Florida Power & L1ght Company

Date of Report
(Mo, Da, Yr)

1

Year of Report
Dec. 31, 1996

SUBSTATIONS (Continued )
5. Show in columns (i),(j),and (k) special equipment such
of essor, date and period of lease, and annual rent. For any
as rotary converters, rectifiers, condensers, etc. and auxsubstation or equipment operated other than by reason of sole
iliary equipment for increasing capacity.
ownership or lease, give name of co-owner or other party, ex6. Designate substations or majo r items of equipment leased
plain basis of sharing expenses or other accounting between
from others, jointly owned with othe r s , or operated otherwise
the parties, and state amounts and accounts affected in responthan by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, give name
co-owner, or other party is an associated company.
Number of
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Numb~r of
Trans ormers
Ca~acity of Substation
~--------------~--~-------------.--~----~~--~--~----~---1Line
Sp?re
( n SerVICe) (In MVa)
Trans ormers
1n Service
Type of Equipment
Number of Units Total Capacity
No.
(i)
(j)
(ln(~~a)
(f)
(g)
(h)

-

-

30.00
23.00
45.00
45.00
3.00
14.00
90.00
58.00
110.00
224.00
12.00
255.00
1,120.00
9.00
40.00
101.00
7.00
200.00
110.00
90.00
400.00
90.00
60.00
2,000.00
50.00
448.00
22.00
166.00
90.00
90.00
300.00
60.00
56.00
14.00
56.00

FE RC FORM NO. 1 (ED. 12- 96 )

1
2
1
1
1
1
2
2
2
1
1
5
2
1
1
2
1
1
2
2
1
2
2
3
1
2
2
3
2
2
1
2
2
1
2

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0

1
2

3
4
5
6
7

8
9

10
11
12
13

14
15
16
17
18 ·-

tiT
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40

p,

27 9

Next Page is 429

 of Respondent
Florida Power & L1ght Company

N~me

I

I~lsr~elp~~to~~~inal

(2) [
SUBS TAT IONS
1. Report below the information called for concerni ng substations of the respondent as of the end of the
year.
2. Substations which serve only one industrial or
street railway customer should not be listed below.
3. Substations with capacities of less than 10 MVa
except
those serving customers with energy for
Name and Location of Substation

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
35
36
37
38
39
40

-

(a)
MIRAMAR
MIRAMAR
MIRAMAR
MIRAMAR
MIRAMAR
MITCHELL
MOBILE SUB - COCOA
MOBILE SUB - DAYTONA
MOBILE SUB - DAYTONA
MOBILE SUB - FL
MOBILE SUB - MIAMI
MOBILE SUB - MIAMI
MOBILE SUB - ED
MOBILE SUB - ED
MOBILE SUB -IJD
MOFFETT
MONET
MONET
MONTEREY
MONTGOMERY
MOTOROLA
MOTOROLA
MOULTRIE
MURDOCK
MYAKKA
NAPLES
NASH
NATOMA
NATOMA
NEll RIVER
NEilTON
NOBHILL
NORMANDY BEACH
NORMANDY BEACH
NORRIS

FER C FORM NO. 1 (ED. 12-96)

'

A ResuDn1iss ion

I

Date of Report
(Me, Da, Yr)

Year of Report
Dec. 31, 1996

resale, may be grouped according to functional character,but
the number of such substations must be shown.
4. Indicate in column (b) the functional character of each
substation, designating whether transmission or distribution
and whether attended or unattended. At the end of the page,
summarize according to function the capacities reported for
the individual stations in column (f).
VOLTAGE (In MVa)
Character of Substation
Primary Secondary
Tertiary
(e)
(c)
(d)
(b)
Distribution
138.00
13.80
138.00
4. 16
Distribution
Distribution
67.00
4.16
Distribution
138.00
13.80
66.00
4.00
Distribution
Oi stribut ion
138.00
13.80
138 . 00
24.00
Distribution
138.00
24.00
Distribution
16.00
115.00
24.00
Distribution
138.00
24.00
Distribution
13.00
66.00
Distribution
138.00
24.00
Distribution
138.00
24.00
Distribution
138.00
24.00
Distribution
230.00
24.00
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Distribution
138.00
Distribution
13.80
Distribution
138.00
24.00
Distribution
22.90
13.20
Distribution
230.00
24.00
Distribution
115.00
13.00
Distribution
138.00
24.00
Transmission
230.00
138.00
Distribution
138.00
13.80
Distribution
115.00
13.80
Distribution
138.00
13.80
Distribution
138.00
13.80
Transmission
13.80
131.00
69.00
230.00
Distribution
24.00
Distribution
230.00
24.00
Transmission
138.00
69.00
13.80
Distribution
138.00
13.80
Transmission
230.00
115.00
13.50

Page 426 10

 of Respondent
Florida Power & L1ght Company

N~me

I~~s[~elp~~to~~~inal
(2) [ A Resu001ission

I

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31, 1996

SUBSTATIONS (Continued)
of lessor, date and period of lease, and annual rent. For any
5. Show in columns (i),(j),and (k) special equipment such
substation or equipment operated other than by reason of sole
as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
ownership or lease, give name of co-owner or other party, ex6. Designate substations or major items of equipment leased
plain basis of sharing expenses or other accounting between
from others,jointly owned with others, or operated otherwise
the parties, and state amounts and accounts affected in responthan by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, give name
co-owner, or other party is an associated company.
Number of
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Numb1r of
Ca~acity of Substat ion
Trans ormers
r---------------~--~-------------.--~----~~--.-------------~Line
Sp1re
( n Serv1ce) (In MVa)
1n Serv1ce
Type of Equipment
Number of Units Total Capacity
No.
Trans ormers
(i)
(j)
(ln(~~a)
(f)
(g)
(h)
0
28.00
1
1
5.00
0
1
2
8.00
0
1
3
1
28.00
0
4
1
5.00
0
5
56.00
0
2
6
0
27.00
1
7
1
0
27.00
8
1
0
8.00
9
1
0
27.00
10
6.00
1
0
11
1
0
25.00
12
1
0
20.00
13
0
20.00
1
14
20.00
1
0
15
60.00
0
2
16
0
1
28.00
17
56.00
0
2
18
60.00
0
2
19
110.00
0
2
20
11.00
0
1
21
165.00
0
3
22
60.00
0
2
23
0
2
110.00
24
224.00
0
1
25
112.00
0
2
26
30.00
0
1
27
0
2
50.00
28
0
2
50.00
29
0
2
112.00
30
0
1
55.00
31
0
2
110.00
32
0
1
33
112.00
0
2
90.00
34
0
2
150.00
35
36
37
38
39
40

-

FE ~C

FORM NO. 1 (ED. 12-96)

Page 427 10

Next Page is 429

 Year of Report
Date of Report
This Report 1:>:
(Mo, Da, Yr)
( 1 ) [Xl An Or 1gina l
Dec. 31, 1996
(2) [
A ResuExnission
SUBS TAT IONS
resale, may be grouped according to functional character,but
1. Report below the information called for concern ing substations of the respondent as of the end of the
the number of such substations must be shown.
year.
4. Indicate in column (b) the functional character of each
2. Substations which serve only one industrial or
substation, designating whether transmission or distribution
street railway customer should not be listed below.
and whether attended or unattended. At the end of the page,
3. Substations with capacities of less than 10 MVa
summarize according to function the capacities reported for
except
those serving customers with energy
for
the individual stations in column (f).
VOLTAGE (In MVa)
Line
Name and Location of Substation
Character of Substation
No.
Primary
Secondary
Tertiary
(a)
(e)
(b)
(c)
(d)
1
NORTHWOOD
Distribution
138.00
13.80
138.00
24.00
NORTON
2
Distribution
OAKES
138.00
13.00
Distribution
3
138.00
13.80
4
OAKLAND PARK
Distribution
138.00
13.80
5
OAKLAND PARK
Distribution
24.00
6
OAKLAND PARK
Distribution
138.00
7
OJUS
138.00
Distribution
13.80
8
OKEECHOBEE
67.00
13.80
Distribution
9
OKEECHOBEE
138.00
13.80
Distribution
10
OLYMPIA
138.00
Distribution
24.00
11
OLYMPIA HEIGHTS
230.00
Distribution
13.80
12
ONECO
Distribution
138.00
13.80
13
OPA LOCKA
Distribution
138.00
13.80
14
OPA LOCKA
Distribution
138.00
13.80
15
ORANGE RIVER
Transmission
525.00
241.00
34.50
16
ORANGEDALE
Distribution
230.00
24.00
17
ORMOND
Distribution
115.00
13.80
18
ORTIZ
Distribution
138.00
24.00
19
OSBORNE
Distribution
138.00
13.80
20
OSBORNE
Distribution
138.00
13.80
21
OSCEMILL
Distribution
138.00
13.80
Distribution
22
OSLO
138.00
13.80
OSLO
Distribution
23
138.00
13.80
Distribution
24
OSPREY
138.00
13.80
PACIFIC
Distribution
25
115.00
13.80
26
PAHOKEE
Distribution
67.00
13.80
Distribution
27
PAHOKEE
138.00
13.80
PALATKA
Distribution
28
130.00
13.80
29
PALM AIRE
Distribution
138.00
13.80
PALM BAY
30
Distribution
138.00
13.80
31
PALM BAY
Distribution
138.00
13.80
32
PALMA SOLA
138.00
Distribution
13.80
33
PALMA SOLA
Distribution
138.00
24.00
PALMETTO
Distribution
34
230.00
24.00
PARK
Distribution
35
230.00
24.00
36
37
38
39
40
of Respondent
Florida Power & L1ght Company

N~me

I

I

-

FERC FORM NO. 1 (ED. 12-96)

Page 426 11

 N9me of Respondent
Florida Power & L1ght Company

I~~s(~elp~~to~~~inal
(2) ( A Resuemission

I

Date of Report
(Mo, Da, Yr)

I

Year of Report
Dec. 31, 1996

SUBSTATIONS (Continued)
of lessor, date and period of lease, and annual rent. For any
5. Show in columns (i),(j),and (k) special equipment such
substation or equipment operated other than by reason of sole
as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
ownership or lease, give name of co-owner or other party, ex6. Designate substations or major items of equipment leased
plain basis of sharing expenses or other accounting between
from others,jointly owned with others, or operated otherwise
the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor,
than by reason of sole ownership by the respondent. For
co-owner, or other party is an associated company.
any substation or equipment operated under lease, give name
Number of
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Numb~r of
Trans ormers
Ca~acity of Substation
~---------------------------------.--------------.--------------1Line
Sp~re
1n Serv1ce
Trans ormers
Type of Equipment
Number of Units Total Capacity
No.
( n Serv1ce) (In MVa)
(i)
(j)
(ln(~~a)
(f)
(g)
(h)
1
88.00
3
0
56.00
2
2
0
90.00
3
2
0
4
1
0
40.00
5
0
2
101.00
6
1
0
30.00
7
0
3
88.00
8
1
0
13.00
9
0
2
56.00
10
0
2
110.00
11
2
0
60.00
12
3
0
135.00
13
2
0
53.00
14
1
0
30.00
15
3
0
1,500.00
16
2
0
60.00
17
0
110.00
2
18
2
0
110.00
19
1
0
28.00
20
1
0
28.00
21
1
0
14.00
22
0
2
60.00
23
1
0
28.00
24
2
0
56.00
25
0
2
41.00
26
0
1
13.00
27
0
1
28.00
28
2
0
58.00
29
0
2
90.00
30
0
1
45.00
31
0
2
90.00
32
0
2
90.00
33
0
2
110.00
34
0
2
110.00
35
0
2
11D.DO
36
37
38
39
40

-

"ERC •ORM NO. 1 (ED. 12-96)

Page 427 11

Next Page is 429

 Year of Report
This Report Is:.
Date of Report
(Mo, Da, Yr)
(1) [Xl An Or1g1nal
Dec. 31, 1996
(2) [ A Resuemission
SUBSTATIONS
resale, may be grouped according to functional character,but
1 . Report below the information called for concerning substations of the respondent as of the end of the
the number of such substations must be shown.
year.
4. Indicate in column (b) the functional character of each
2. Substations which serve only one industrial or
substation, designating whether transmission or distribution
street railway customer should not be listed below.
and whether attended or unattended. At the end of the page,
summarize according to function the capacities reported for
3. Substations with capacities of less than 10 MVa
except
those serving customers with energy
for
the individual stations in column (f).
VOLTAGE (In MVa)
Line
Name and Location of Substation
Character of Substation
No.
Primary Secondary
Tertiary
(b)
(c)
(d)
(e)
<a>
1
PATRICK
Distribution
138.00
13.80
2
PATRICK
Distribution
138.00
13.80
Distribution
3
PAYNE
138.00
13.80
Distribution
4
PEMBROKE
138.00
13.80
5
PENNSUCO
Distribution
230.00
24.00
6
PERRINE
Distribution
138.00
13.80
7
PERRINE
Distribution
138.00
13.80
PERRY
Distribution
8
138.00
13.80
PHILLIPPI
Distribution
9
138.00
13.80
10
PHOENIX
Distribution
230.00
24.00
11
PINE RIDGE
Distribution
24.00
138.00
Distribution
12
PINEHURST
138.00
13.80
13
PLANTATION
Distribution
138.00
13.80
14
PLAYLAND
Distribution
138.00
13.80
15
PLUMOSUS
Transmission
230.00
138.00
16
POINSETT
Transmission
34.50
525.00
241.50
POMPANO
17
Distribution
138.00
13.80
18
POMPANO
Distribution
138.00
13.80
PORT
19
Distribution
138.00
13.80
20
PORT EVERGLADES PLANT
Transmission
239.00
13.20
21
PORT EVERGLADES PLANT
Transmission
239.00
20.90
Transmission
22
PORT EVERGLADES PLANT
230.00
138.00
23
PORT EVERGLADES PLANT
Transmission
138.00
21.00
24
PORT MAYACA
Distribution
13 . 20
22.90
Distribution
25
PORT MAYACA
138.00
24.00
PORT ORANGE
26
Distribution
130.00
13.80
PORT ORANGE
115.00
27
Distribution
13.80
28
PORT SEWALL
Distribution
138.00
13.80
29
PRATT WHITNEY
Distribution
230.00
13.80
30
PRIMAVISTA
Distribution
138.00
13.80
PRINCETON
31
Distribution
138.00
13.80
Distribution
32
PRINCETON
138.00
13.80
33
PROCTOR
Distribution
230.00
24.00
PUNTA GORDA
Distribution
34
13.80
2.40
138.00
35
PUNTA GORDA
Di stri but ion
13.80
36
37
38
39
40
Name of Respondent
Florida Power & L1ght Company

I

I

-

FER C FORM NO. 1 (ED. 12-96)

Page 426 12

 of Respondent
Florida Power & L1ght Company

N~me

t~~s[~elp~~t 0 ~~~inal
(2) [

A Resuemission

I

Date of Re~ort
(Mo, Da, Y )

Year of Report
Dec. 31, 1996

SUBSTATIONS (Continued)
5. Show in columns (i),(j),and (k) special equipment such
of lessor, date and period of lease, and annual rent. For any
substation or equipment operated other than by reason of sole
as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
ownership or lease, give name of co-owner or other party, ex6. Designate substations or major items of equipment leased
plain basis of sharing expenses or other accounting between
from others,jointly owned .with others, or operated otherwise
the parties, and state amounts and accounts affected in responthan by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, give name
co-owner, or other party is an associated company.
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Number of
Numb~r of
Trans ormers
Ca~acity of Substation
~---------------------------------.--------~~--.---~----~--~Line
Sp~re
1n Serv1ce
Trans ormers
( n Serv1ce) (In MVa)
Type of Equipment
Number of Units Total Capacity
No.
(i)
(j)
(ln(~~a)
(f)
(g)
(h)
1
90.00
2
0
1
28.00
2
0
2
0
3
112.00
4
2
0
73.00
0
5
2
90.00
2
0
6
56.00
1
0
28.00
7
3
0
84.00
8
9
3
0
135.00
10
2
0
110.00
0
11
3
165.00
2
0
90.00
12
3
0
13
134.00
60.00
14
2
0
1
400.00
15
0
16
3
1
2,000.00
17
2
0
56.00
1
0
30.00
18
2
0
19
56.00
20
3
0
480.00
2
0
920.00
21
1
0
280.00
22
0
520.00
2
23
1
0
24
11.00
2
0
25
60.00
1
0
26
28.00
27
2
0
107.00
0
28
3
135.00
2
0
29
70.00
30
2
0
60.00
1
0
31
28.00
1
0
32
28.00
2
0
33
110.00
34
1
0
4.00
0
35
3
135.00
36
37
38
39
40

-

FERC FORM NO . 1 (ED. 12-96)

Page 427 12

Next Page is 429

 Year of Report
Date of Report
This Report Is:.
(Mo, Da, Yr)
(1) [XJ An Or1g1nal
Dec. 31, 1996
(2) [ A ResuElmission
SUBSTATIONS
resale, may be grouped according to functional character,but
1. Report below the information called for concernthe number of such substations must be shown.
ing substations of the respondent as of the end of the
4. Indicate in column (b) the functional character of each
year.
2. Substations which serve only one industrial or
substation, designating whether transmission or distribution
street railway customer should not be listed below.
and whether attended or unattended. At the end of the page,
summarize according to function the capacities reported for
3. Substations with capacities of less than 10 MVa
the individual stations in column (f).
except
those serving customers with energy
for
VOLTAGE (In MVa)
Line
Name and Location of Substation
Character of Substation
No.
Primary
Secondary
Tertiary
of Respondent
Florida Power & L1ght Company

N~me

I

I

(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
36
37
38
39
40

-

PURDY LANE
PUTNAM PLANT
PUTNAM PLANT
PUTNAM PLANT
QUAKER OATS
QUAKER OATS
QUANTUM
RAJ LIIAY
RANCH
RAVENSIIOOD
RED ROAD
REED
REGIS
REMSBURG
RESERVATION
RICE
RINEHART
RINGLING
RIO
RIVERSIDE
RIVIERA
RIVIERA PLANT
RIVIERA PLANT
ROCK ISLAND
ROCKLEDGE
ROEBUCK
ROHAN
RONEY
ROSELAIIN
ROSS
ROTONDA
RUBONIA
SABAL
SAGA
SAMPLE ROAD

FERC FORM NO. 1 (ED. 12-96)

(b)

Distribution
Transmission
Transmission
Transmission
Distribution
Distribution
Distribution
Distribution
Transmission
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Transmission
Distribution
Transmission
Distribution
Distribution
Distribution
Transmission
Transmission
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution

Page 426 13

(c)

(d)

138.00
239.00
239.00
230.00
66.00
66.00
138.00
138.00
230.00
138.00
138.00
115.00
115.00
138.00
138.00
525.00
230.00
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
230.00
230.00
138.00
138.00

13.80
13.20
13.20
130.00
4.16
4.16
13.80
13.80
138.00
13.80
13.80
13.80
24.00
24.00
13.80
241.50
13.80
138.00
13.80
13.80
13.80
19.00
69.00
13.80
13.80
13.80
13.80
13.80
13.80
24.00
24.00
24.00
24.00
13.80
13.80

(e)

13.80

34.50
13.80

14.40

 l

Year of Report
Date of Report
This Report 1$: .
(Mo, Da, Yt")
(1) [Xl An Or1g1nal
Dec. 31, 1996
(2) [
A Resuemission
SUBSTATIONS (Continued)
of lessor, date and period of lease, and annual rent. For any
5. Show in columns (i),(j),and (k) special equipment such
substation or equipment operated other than by reason of sole
as rotary converters, rectifiers, condensers, etc. and auxownership or lease, give name of co-owner or other party, exiliary equipment for increasing capacity.
plain basis of sharing expenses or other accounting between
6. Designate substations or major items of equipment leased
the parties, and state amounts and accounts affected in responfrom others, jointly owned with others, or operated otherwise
dent's books of account. Specify in each case whether lessor,
than by reason of sole ownership by the respondent. For
co-owner, or other party is an associated company.
any substation or equipment operated under lease, give name
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Number of
Num~r of
~--------------~~~~-----------.~~----~~~~--~~--~~~Line
Trans ormers
Ca~acity of Substation
Sp1re
Type of Equipment
Number of Units Total Capacity
No.
( n Serv1ce) (In MVa)
1n Service
Trans ormers
(i)
(j)
(ln(~~a)
(h)
(f)
(g)
N9me of Respondent
Florida Power & L1ght Company

110 00
240.00
320.00
336.00
8.00
7.00
60.00
242.00
1,060.00
58.00
135.00
60.00
60.00
110 00
56.00
2,000.00
30.00
1,120.00
60.00
86.00
56.00
690.00
75.00
84.00
56.00
58.00
56.00
90.00
135.00
110.00
110.00
30.00
30.00
58.00
141.00
0

0

-

':RC FORI-' 1r

1 (ED. 12-96)

2
2
2
2
1
1
2
4
2
2
3
2
2
2
2
3
1
2
2
3
2
2
1
3
2
2
2
2
3
2
2
1
1
2
3

l

1

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

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

Page 427 13

Next Page is 429

 Name of Respondent
Florida Power & L1ght Company

Date of Report
This Report Is:
Year of Report
(1) [XJ An Or1ginal
(Mo, Da, Y)")
(2) [ J A Resuemission
Dec. 31, 1996
SUBSTATIONS
1. Report below the information called for concernresale, may be grouped according to functional character,but
ing substations of the respondent as of the end of the
the number of such substations must be shown.
year.
4. Indicate in column (b) the functional character of each
2. Substations which serve only one industrial or
substation, designating whether transmission or distribution
street railway customer should not be listed below.
and whether attended or unattended. At the end of the page,
3. Substations with capacities of less than 10 MVa
summarize according to function the capacities reported for
except
those serving customers with energy
for
the individual stations in column (f).
VOLTAGE (In MVa)
Name and Location of Substation
Line
Character of Substation
No.
Primary Secondary
Tertiary

I

I

(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
36
37
38
39
40

-

SAN MATEO
SANDAL FOOT
SANDPIPER
SANFORD
SANFORD PLANT
SANFORD PLANT
SANFORD PLANT
SARASOTA
SARASOTA
SARNO
SATELLITE
SAVANNAH
SAVANNAH
SCOTTSMOOR
SEABOARD
SEAGULL
SEBASTIAN
SEMI NOLA
SHADE
SHERIDAN
SHERMAN
SHERMAN
SHERMAN
SIMPSON
SISTRUNK
SISTRUNK
SNAKE CREEK
SNAPPER CREEK
SNAPPER CREEK
SO. CAPE
SO. CAPE
SOLANA
SORRENTO
SOUTH BAY
SOUTH BAY

FERC FORM NO. 1 (ED. 12-96)

(b)

Distribution
Distribution
Transmission
Distribution
Transmission
Transmission
Transmission
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Distribution
Transmission
Transmission
Distribution
Transmission
Distribution
Distribution
Distribution
Distribution
Transmission
Distribution
Distribution
Distribution
Transmission
Distribution

Page 426 14

(C)

(d)

115.00
230.00
230.00
115.00
230.00
239.00
115.00
138.00
138.00
230.00
138.00
138.00
138.00
115.00
138.00
230.00
138.00
138.00
138.00
230.00
230.00
230.00
230.00
138.00
230.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00
138.00

13.80
13.00
138.00
13.80
130.00
22.80
17.00
13.80
24.00
13.80
13.80
13.80
13.80
24.00
13.80
24.00
24.00
13.80
24.00
13.80
24.00
130.00
69.00
13.80
138.00
13.80
13.80
13.80
13.80
115.00
13.80
13.80
13.80
69.00
13.80

(e)

13.20
13.20

13.80
13.20

13.80

7.10

 I

Year of Report
Date of Report
This Report Is: .
(Mo, Da, Yr)
(1) [XJ An Or1g1nal
Dec. 31, 1996
(2) [ A Resubmission
SUBSTATIONS (Continued)
of lessor, date and period of lease, and annual rent. For any
Show in columns (i),(j),and (k) special equipment such
substation or equipment operated other than by reason of sole
t ary converters, rectifiers, condensers, etc. and auxownership or lease, give name of co-owner or other party, ex' equipment for increasing capacity.
plain basis of sharing expenses or other accounting between
Designate substations or major items of equipment leased
the parties, and state amounts and accounts affected in respontr am others,jointly owned -with others, or operated otherwise
dent's books of account. Specify in each case whether lessor,
than by reason of sole ownership by the respondent. For
co-owner, or other party is an associated company.
any substation or equipment operated under lease, give name
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Number of
Numbfr of
~---------------------------------.--------~----.---------~---4Line
Trans ormers
ca~acity of Substation
Sp~re
Type of Equipment
Number of Units Total Capacity
No.
( n Serv1ce) (In MVa)
1n Service
Trans ormers
(i)
(j)
(In(~~a)
(g)
(h)
(f)
1
2
0
60.00
2
0
2
90.00
3
1
0
400.00
4
2
0
60.00
5
2
0
336.00
6
2
0
920.00
7
0
1
180.00
8
0
2
90.00
9
2
0
60.00
10
2
0
60.00
11
1
0
30.00
12
1
0
28.00
13
1
0
30.00
14
1
0
30.00
15
4
0
104.00
16
2
0
110.00
17
2
0
60.00
18
3
0
80.00
19
2
0
110.00
20
2
0
58.00
21
2
0
60.00
22
1
0
75.00
1
0
23
50.00
24
2
0
56.00
25
1
0
560.00
26
3
0
125.00
0
27
2
60.00
1
0
28
28.00
1
0
29
28.00
30
1
0
168.00
0
31
1
30.00
32
2
0
112.00
0
33
2
58.00
34
0
2
125.00
35
2
0
27.00
36
37
38
39
40
of Respondent
Florida Power & L1ght Company

N~me

,.....

-

FE RC FORM NO. 1 (ED .

?- 96)

Page 427 14

I

Nex t Page i s 429

 of Respondent
Florida Power & L1ght Company

I

Year of Report
Date of Report
Thi s Report Is: .
(1) (Xl An Or1g1nal
(Mo, Da, Yr)
(2) ( A ResuDI11ission
Dec. 31, 1996
SUBSTATIONS
1 . Report below the information called for concern resale, may be grouped according to functional character,but
ing substations of the respondent as of the end of the
the number of such substations must be shown.
year.
4. Indicate in column (b) the functional character of each
2. Substations which serve only one industrial or
substation, designating whether transmission or distribution
street railway customer should not be listed below.
and whether attended or unattended. At the end of the page,
3. Substations with capacities of less than 10 MVa
summarize according to function the capacities reported fo r
except
those serving customers with energy
fo r
the individual stations in column (f).
VOLTAGE (In MVa)
Li ne
Name and Location of Substation
Character of Substation
No.
Primary
Secondary
Tertiary
(a)
(b)
(c)
(d)
(e)
1
SOUTH DAYTONA
Distribution
131.00
13.80
SOUTH DAYTONA
2
115.00
Di stribution
13.80
3
SOUTH MIAMI
Distribution
138.00
13 . 80
4
SOUTH MIAMI
Di stribution
138.00
13.80
SOUTH VENICE
5
Distribution
138.00
13.80
6
SOUTH VENICE
Distribution
138.00
13 .80
7
SOUTHSIDE
Distribution
138.00
13.80
8
SOUTHSIDE
Distribution
24.00
138 . 00
9
SPRINGTREE
Distribution
230 . 00
24.00
10
SPRUCE
Distribution
115.00
24.00
11
SQUARE LAKE
Distribution
138.00
13.80
12
ST. AUGUSTINE
Distribution
115.00
13.80
13
ST. JOE
Distribution
115.00
24.00
14
ST. JOHNS
Transmission
230.00
115.00
Transmission
15
ST. LUCIE PLANT
239.00
20.90
STARKE
16
Transmission
115.00
69.00
2.40
17
STARKE
Distribution
67.00
13.80
18
STEELBALD
Distribution
230.00
24.00
STIRLING
19
138.00
Di stribution
13 . 80
20
STONEBRIDGE
Di stribution
230.00
24.00
STUART
21
138.00
Di stribution
13.80
SUN I LAND
Distribution
22
138.00
13.80
SUNNY ISLES
Distribution
23
138.00
13.80
24
SUNNY ISLES
Distribution
138.00
13 .80
SUNTREE
Distribution
25
138.00
24.00
26
SWEATT
Distribution
138.00
24.00
27
SWEETWATER
Distribution
230.00
24.00
SYKES CREEK
28
Distribution
138.00
13.80
29
SYKES CREEK
Distribution
138.00
13.80
30
SYLVAN
Distribution
230.00
13.80
Distribution
31
TAMIAMI
138.00
13.80
Distribution
32
TARTAN
230.00
24.00
TAYLOR
Distribution
115.00
13.00
33
Distribution
34
TERMINAL
13.80
4.16
TERMINAL
Distribution
138.00
13.80
35
36
37
38
39
40
N~me

I

-

FERC FORM NO . 1 (ED. 12-96)

Page 426 15

 I

Year of Report
Date of Report
Th i s Report Is: .
(Mo , Da, Yt-)
(1) [XJ An Or1g1nal
Dec. 31, 1996
(2) [
A ResuDinission
SUBSTATIONS (Continued)
of lessor, date and period of lease, and annual rent. For any
5. Show in columns (i),(j),and (k) special equipment such
substation or equipment operated other than by reason of s ole
as rotary converters, rectifiers, condensers, etc. and auxownership or lease, give name of co-owner or other party, exiliary equipment for increasing capacity.
plain basis of sharing expenses or other accounting between
6. Designate substations or major items of equipment leased
the parties, and state amounts and accounts affected in responf r om others, jointly owned ·with others, or operated otherwise
dent's books of account. Specify in each case whether lessor,
than by reason of sole ownership by the respondent. For
co-owner, or other party is an associated company.
any substation or equipment operated under lease, give name
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Number of
Numb~r of
Trans ormers
Ca~acity of Substation
~-------------~--~-------------.--~----~----~--~--------~Line
spre
1n Serv1ce
Trans ormers
Type of Equipment
Number of Units Total Capacity
No.
( n Serv1ce) (In MVa)
(i)
(j)
(ln(~~a)
(f)
(g)
(h)
N9me of Respondent
Florida Power & L1ght Company

-

-

56.00
30.00
80.00
65.00
45.00
45.00
60.00
60.00
165.00
60.00
60.00
58.00
110.00
200.00
2,220.00
38.00
23.00
180.00
112.00
110.00
86.00
56.00
45.00
45.00
60.00
30.00
110.00
56.00
28.00
30.00
60.00
110.00
60.00
5.00
56.00

2
1
2
2
1
1
2
2
3
2
2
2
2
1
4
2
2
3
2
2
3
2
1
1
2
1
2
2
1
1
2
2
2
1
2

I

0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

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

L---------------~--------~----------~------------- -·--------~----------~--------~--~

-ER C FOR r-' •iC. 1 (ED. 12-96)

Page 427 15

'

t

Page i s 429

 I

Year of Report
Date of Report
This Report Is: .
(Mo, Da, Yr>
(1) [XJ An Ortgtnal
Dec. 31, 1996
(2) [ A Resuemission
SUBSTATIONS
resale, may be grouped according to functional character,but
1. Report below the information called for concern·
the number of such substations must be shown.
ing substations of the respondent as of the end of the
year.
4. Indicate in column (b) the functional character of each
2. Substations which serve only one industrial or
substation, designating whether transmission or distribution
street railway customer should not be listed below.
and whether attended or unattended. At the end of the page,
summarize according to function the capacities reported for
3. Substations with capacities of less than 10 MVa
the individual stations in column (f).
except
those serving customers with energy for
VOLTAGE (In MVa)
Name and Location of Substation
Character of Substation
Line
Tertiary
Primary Secondary
No.
(C)
(d)
(e)
(a)
(b)
138.00
13.80
Distribution
1
liCE
230.00
13.80
Distribution
2
TIMBERLAKE
13.80
131.00
Distribution
3
TITUSVILLE
115.00
13.80
Distribution
4
TOLOMATO
230.00
24.00
Distribution
5
TOMOKA
230.00
24.00
Distribution
6
TRACE
22.90
13.20
Distribution
7
TRAIL RIDGE
13.80
115.00
Distribution
8
TRAIL RIDGE
13.80
138.00
Distribution
9
TRAIN
138.00
13.80
Distribution
10
TROPICAL
13.80
138.00
Distribution
11
TROPICANA
239.00
20.90
Transmission
12
TURKEY POINT PLANT
24.00
230.00
Distribution
13
TURNPIKE
138.00
13.80
Distribution
14
TUTTLE
138.00
13.80
Distribution
15
ULETA
138.00
13.80
Distribution
16
ULETA
13.80
138.00
Distribution
17
UNIVERSITY
24.00
230.00
Distribution
18
VALENCIA
138.00
24.00
Distribution
19
VAMO
138.00
13.80
Distribution
20
VENETIAN
138.00
13.80
Distribution
21
VENICE
138.00
13.80
Distribution
VERENA
22
138~00
13.80
Distribution
VERENA
23
138.00
13.80
Distribution
24
VILLAGE GREEN
138.00
13.80
Distribution
25
VIRGINIA KEY
13.20
230.00
115.00
Transmission
VOLUSIA
26
138.00
24.00
Distribution
27
IIABASSO
138.00
13.80
Distribution
28
IIALKER
67.00
13.80
Distribution
29
IIEST PALM BEACH
2.40
66.00
12.50
Distribution
IIEST PALM BEACH
30
13.80
66.00
Distribution
31
IIEST PALM BEACH
138.00
69.00
13.20
Transmission
IIEST PALM BEACH
32
13.80
138.00
Distribution
IIESTINGHOUSE
33
138.00
24.00
Distribution
34
IIESTINGHOUSE
138.00
13.80
Distribution
35
IIESTON VILLAGE
36
37
38
39
40
of Respondent
Florida Power & Ltght Company

N~me

FERC FORM NO. 1 (ED. 12-96)

I

Page 426 16

 l

of Respondent
Florida Power & L1ght Company

N~me

Date of Report
(Mo, Da, Yt)

I

Year of Report
Dec . 31 , 1996

SUBSTATIONS (Continued)
of lessor, date and period of lease, and annual rent. For any
5. Show in columns (i),(j),and (k) special equipment such
subs tation or equipment operated other than by reason of sole
as rotary converters, rectifiers, condensers, etc. and aux·
owne rship or lease, give name of co-owner or other party, exiliary equipment for increasing capacity.
plain basis of sharing expenses or other accounting between
6. Designate substations or major items of equ i pment leased
from others,jointly owned with others, or operated otherwise
the parties, and state amounts and accounts affected in responthan by reason of sole ownership by the respondent. For
dent's books of account. Specify in each case whether lessor,
any substation or equipment operated under lease, give name
co-owner, or other party is an associated company.
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Number of
Numb~r of
Trans ormers
Ca~acity of Substation
~--------------~--~-------------,--~----~~--.---~------~~Line
Sp?re
( n Serv1ce) (In MVa)
1n Serv1ce
Type of Equipment
Number of Units Total Capacity
No.
Trans ormers
(i)
(j)
(ln(~~a)
(f)
(g)
(h)
56.00
2
1
0
90.00
2
0
2
90.00
2
0
3
56.00
2
0
4
60.00
2
0
5
110.00
2
0
6
16.00
2
0
7
27.00
2
0
8
30.00
1
0
9
134.00
3
0
10
53.00
2
0
11
2,620.00
4
0
12
110.00
2
0
13
90.00
3
0
14
56.00
1
0
15
55.00
1
0
16
50.00
2
0
17
110.00
2
0
18
85.00
2
0
19
112.00
2
0
20
135.00
3
0
21
85.00
2
0
22
45.00
1
0
23
90.00
2
0
24
56.00
2
0
25
1,000.00
3
0
26
60.00
2
0
27
90.00
2
0
28
70.00
2
0
29
3.00
1
0
30
10.00
2
0
31
224.00
2
0
32
90.00
2
0
33
30.00
1
0
34
56.00
2
0
35
36
37
38
39
40

-

FERC FORM

~

. 1 (ED. 12·96)

Page 427 16

Ne xt Page is 429

 l

Date of Report
Year of Report
This Report I~: .
(1) [Xl An Or1g1nal
(Mo, Da, Yr)
(2) [ A Resuemission
Dec. 31, 1996
SUBSTATIONS
resale, may be grouped according to functional character,but
1. Report below the information called for concernthe number of such substations must be shown.
ing substations of the respondent as of the end of the
4. Indicate in column (b) the functional character of each
year.
substation, designating whether transmission or distribution
2. Substations which serve only one industrial or
and whether attended or unattended. At the end of the page,
street railway customer should not be listed below.
summarize according to function the capacities reported for
3. Substations with capacities of less than 10 MVa
the individual stations in column (f).
except
those serving customers with energy
for
VOLTAGE (In MVa)
Character of Substation
Name and Location of Substation
Line
Primary Secondary
Tertiary
No.
(b)
(c)
(d)
(e)
(a)
138.00
13.80
Distribution
1
IIESTIIARD
230.00
69.00
Transmission
IIHIDDEN
2
138.00
13.80
Distribution
IIHISPERING PINES
3
13.80
138.00
Distribution
IIHITE CITY
4
138.00
13.80
Distribution
IIHITFIELD
5
115.00
13.00
Distribution
IIILLOII
6
131.00
13.80
Distribution
IIILLOII
7
138.00
24.00
Distribution
8
IIINKLER
24.00
115.00
Distribution
III REM ILL
9
115.00
24.00
Distribution
10
III REM ILL
230.00
13.80
Distribution
11
IIOODLANDS
13.2D
230.00
138.00
Transmission
12
YAMATO
24.00
230.00
Distribution
YULEE
13
138.00
13.80
Distribution
14
137TH AVENUE
230.00
4.20
Distribution
137TH AVENUE
15
13.80
230.00
Distribution
137TH AVENUE
16
66.00
13.00
Distribution
40TH STREET
17
13.80
138.00
Distribution
40TH STREET
18
4.16
67.00
Distribution
40TH STREET
19
13.80
138.00
69.00
Transmission
40TH STREET
20
138.00
13.80
Distribution
62ND AVENUE
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Name of Respondent
Florida Power & L1ght Company

-

FERC FORM NO. 1 (ED. 12-96)

Page 426 17

 Year of Report
Date of Report
T~h~,~- sfRXejpAort
Is:. l
(Mo, Da, Yr)
n 0 r1g1na
Dec . 31, 1996
A Resubmis si on
SUBSTATIONS (Continued)
of lessor, date and period of lease, and annual rent. For any
5. Show in columns (i),(j),and (k) special equipment such
substation or equipment operated other than by reason of sole
as rotary converters, rectifiers, condensers, etc. and auxownership
or lease, give name of co-owner or other party, exiliary equipment for increasing capacity.
plain basis of sharing expenses or other accounting between
6. Designate substations or major items of equipment leased
the parties, and state amounts and accounts affected in responfrom others,jointly owned with others, or operated otherwise
dent's books of account. Specify in each case whether lessor,
than by reason of sole ownership by the respondent. For
co-owner, or other party is an associated company.
any substation or equipment operated under lease, give name
CONVERSION APPARATUS AND SPECIAL EQUIPMENT
Number of
Number of
~--------------------------------~--------------.-------------~Line
Transformers
spare
Capacity of Substation
Type of Equipment
Number of Units Total Capacity
No.
Transformers
1n Service
(ln Serv1ce) (In MVa)
(i)
(j)
(ln(~~a)
(h)
(g)
(f)
of Respondent
Florida Power & L1ght Company

N~me

135.00
75.00
60.00
60.00
90.00
60.00
28.00
110.00
14.00
30.00
90.00
560.00
60.00
14.00
17.00
22.00
5.00
112.00
8.00
280.00
85.00

I

I

,

3

0

1

0

2

2

0

3

2

0

4

2

0

5

2

0

6

1

0

7

2

0

8

1
1

2

0
0
0
0
0

1

0

1
1
1

0

2

1

9

10
11

0

0

2

0

1
1

0
0

2

0

CAPACITY SUMMARY:
(MVA)
DISTRIBUTION
TRANSMISSION

34,996
67,091

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

FER C FORM NO. 1 (ED. 12· 96 )

Page 427 17

Next Page is 429

 Nfme of Respongent
F orida Power
L1ght Company

This Report 1:,:
Year of Report
Date of Re~ort
(Mo, Da, Y )
~~~ fXl A
An Resu
Or1~nal
ission
Dec. 31, 1996
ELECTRIC DISTRIBUTION METERS AND LINE TRANSFORMERS
1. Report below the information called for concerning
lease, give name of lessor, date and period of lease, and andistribution watt-hour meters and line transformers.
nual rent. If 500 or more meters or line transformers are held
2. Include watt-hour demand distribution meters, but not
other than by reason of sole ownership or lease, give name
external demand meters.
of co-owner or other parties, explain basis of accounting for
3. Show in a footnote the number of distribution watt-hour
expenses between the parties, and state amounts and acmeters or line transformers held by the respondent under
counts affected in respondent's books of account. Specify
lease from others, jointly owned with others, or held otherin each case whether lessor, co-owner, or other party is an
wise than by reason of sole ownership by the respondent.
associated company.
If 500 or more meters or line transformers are held under a
Line
LINE TRANSFORMERS
No.
Item
Number of Watt-Hour Meters
Number
Total Capacity (In MVa)
(a)
(b)
(c)
(d)
1 Number at Beginning of Year
3,735,824
38,024
692,735
2 Additions During Year
3
Purchases
114,663
1,880
26,345
Associated with Utility Plant Acquired
4
5
TO!A~~~~tions (Enter Total of lines
1,880
114,663
26,345
6 Reductions During Year
719
Retirements
66,695
13,399
7
8
Associated with Utility Plant Sold
9
TOTAL Re~uctions (Enter Total of
719
i nes
and 8)
66,695
13,399
3,783,792
705,681
39,185
10
Number at End of Year (lines 1+5-9)
670
45,429
6,368
11 In Stock
176,399
12 Locked Meters on Customers' Premises
13 Inactive Transformers on System
38,403
3,561,629
697,894
14 In Customers' Use
112
335
1,419
15 In Company's Use
16
TOT~L E~ of Yy~r (E~ter Total of
1nef 1 to
, T s l1ne
39,185
3,783,792
705,681
shou d equal 1ne 1 .)

l

j

0

FERC FORM NO. 1 (ED. 12-88)

Page 429

l

 Year of Report
Date of Re~ort
Th is Report Is: .
(Me, Da, Y )
~B fXl A
An Resu
Or1flri,nal
Dec. 31, 1996
ission
ENVIRONMENTAL PROTECTION FACILITIES
or low sulfur fuels including storage and handl 1. For purposes of this response, environmental protect i on
ing equipment
building, structure,
facil i t i es shall be defined as any
(3)
Monitoring
equipment
or
improvement
designed
and
constructed
facility,
equipment,
(4) Other.
solely for centro l, reduction, prevention or abatement of
B. Water pollution control f ac i l it i es:
discharges or releases into the environment of gaseous, liquid,
( 1) Cooling towers, ponds, piping, pumps, etc.
or solid substances, heat, noise or for the control,
(2) Waste water treatment equipment
reduction, prevention, or abatement of any other adverse im(3) Sanitary waste disposal equipment
pact of an activity on the environment.
(4) Oil interceptors
2. Report the d i fferences in cost of facilities i ns talled
(5) Sediment control facilities
for environmental considerations over the cost of alternative
(6) Monitoring equipment
facilities which would otherwise be used without environmental
(7) Other.
considerations. Use the best engineering design achievable
without environmental restrictions as the basis for determining
c. Solid waste disposal costs:
(1) Ash handling and disposal equipment
costs without environmental considerations. It is not
(2) Land
intended that special design studies be made fo r purposes of
(3) Settling ponds
this response. Base the response on the best engineering
(4) Other .
judgement where direct comparisons are not available.
Include in these differences in costs the costs or estimated
D. Noise abatement equipment:
costs of environmental protection facilities i n service,
( 1) Structures
constructed or modified in connection with the production,
(2) Mufflers
transmission, and distribution of electrical energy and shall
(3) Sound proofing equipment
(4) Monitoring equipment
be reported herein for all such environmental
fac i lities
placed in service on or after January 1, 1969, so long as it
(5) Other.
is readily determinable that such facilities were constructed
E. Esthetic costs:
or modified for environmental rather than operational purposes.
(1) Architectural costs
Also report similar
expenditures for environmental plant
(2) Towers
included in construction work in progress. Estimate the cost
(3) Underground lines
of facilities when the original cost is not available or
(4) Landscaping
facilities are jointly owned with another utility, provided the
(5) Other.
respondent explains the basis of such estimations .
F. Additional plant capacity necessary due to
Examples of these costs would include a portion of the cost s
restricted output from existing facilities, or addiof tall smokestacks, underground lines, and landscaped substation of pollution control facilities.
tions. Explain such costs in a footnote .
G. Miscellaneous:
(1) Preparation of environmental reports
3. In the cost of facilities reported on this page, i nclude
an estimated portion of the cost of plant that is or will be
(2) Fish and wildlife plants included in Accounts
used to provide power to operate associated environmental pro330, 331, 332, and 335.
tection facilities. These costs may be estimations on a per(3) Parks and related facilities
centage of plant basis. Explain such estimations in a footnote.
(4) Other.
4. Report all costs under the major classifications provided
5. In those instances when costs are composites of both
below and include, as a miniiiUil, the items listed hereunder:
actual supportable costs and estimates of costs, specify
A. Air pollution control facilities:
in column (f) the actual costs that are included in
(1) Scrubbers, precipitators, tall smokestacks, etc.
column (e).
(2) Changes necessary to accommodate use of
6. Report construction work in progress relating to enenvironmentally clean fuels such as low ash
vironmental facilities at line 9.
CHANGES DURING YEAR
Line
Classification of Cost
Actual Cost
Balan7e at
Adjustments
No.
Additions
Retirements
End o Year
(a)
(b)
(c)
(d)
(e)
(f)
1 Air Pollution Control Facilities
$1,396,330
$798,382
$1,202,075
$174,223,572
$174,223,572
Water Pollution Control Facilities
2,560,119
81,630
2
118,220
317,488,566
317,488,566
Solid Waste Disposal Costs
582,050
3
71,559,657
491,708
71,559,657
4
Noise Abatement Equipment
125,400
35,056
97,020
32,586,200
32,586,200
5
Esthetic Costs
3,397,128
1,999,075
25,406
46,936,928
46,936,928
Additional Plant Capacity
6
0
0
7
Misce l laneous ( Iden ti f y s ign if icant )
3 , 922, 40 1
6 , 582 ,1 05
1, 253, 708, 995
( 14,863' 097) *
1, 253, 708 , 995
$11 , 983,428
$9,987, 956
($ 13 , 420,376 )
B TOTAL (T eta l of l i nes 1 th ru 7 )
$1 ,896,5 03 ,918 $1, 896, 503, 918
Cons
tru.:
t1
on
Wo
rk
in
Progres
s
64 , 566 , 349
64, 566,349
l
Page 430
FE DC F'''"' ' .. 1 (ED. 12 -88)
Nfme of Respongent
F orida Power
L1ght Company

-

I

I

I

 <

Page 430 Line 7 Column e

>

Includes all nuclear environmental protection facilities to
prevent and mitigate the consequences of a release of radioactive material into the environment and the equipment and
components to dissipate heat created in the nuclear process.

Page 430 Footnote.l

 Nrme of Respon~ent
F orida Power
L1ght Company

This Report Is: .

~~~ fXl A
An Resu
Or1~nal
ission
I
I
ENVIRONMENTAL PROTECT JON EXPENSES

Date of Report
(Mo, Da, Yr)

Year of Report
Dec . 31, 1996

tion of pollution control equipment,use of alternate en1. Show below expenses incurred in connection with
vi ronmenta ll y preferable fuels or environmental regula·
the use of environmental protection facilities, the
tions of governmental bodies. Base the price of replace cost of which are reported on page 430. llhere it is
ment power purchased on the average system price of
necessary that allocations and/or estimates of costs
purchased power if the actual cost of such replacement
be made,state the basis or method used.
power is not known. Price internally generated replace2. Include below the costs incurred due to the
ment power at the system average cost of power generated
operation of environmental protection equipment,
if the actual cost of specific replacement generation
facilities, and programs.
is not known.
3. Report expenses under the subheadings listed
6. Under i tern 8 include ad valorem and other taxes
below.
assessed
directly on or directly relatable to environmendifference
in
cost
be4. Under item 6 report the
tal facilities. Also inc l ude under item 8 licensing and
tween environmentally clean fuels and the alternative
similar fees on such f aci l i t i es .
fuels that would otherwise be used and are available
7. In those instances where expenses are composed of
for use.
both actual supportable data and estimates of costs,
5. Under item 7 include the cost of replacement power,
specify in column (c) the actual expenses that are inpurchased or generated, to compensate for the defieluded in column (b).
ciency in output from existing plants due to the addiAmount
Actual Expenses
Line
Classification of Expenses
(C)
(b)
(a)
No.
$77.990.871
1
Depreciation
*
2
Labor[ _M9intenance, Materials, and Supplies Cost Related to Env.
Fac1 1t1es an Programs
23,921,658
3
Fuel Related Costs
4
Operation of Facilities
2,976,438
Fly Ash and Sulfur Sludge Removal
524,094
5
Difference in Cost of Envi ronmenta ll y Clean Fuels
6
28,927,550
*
7
Replacement Power Costs
2,212,269
*
8
Taxes and Fees
1,983,184
Administrative and General
9
Other (Identify significant)
10
11
TOTAL
$138,536,064 *

-

-

'
-

FE RC FORM NO. 1 (ED. 12 -88)

Page 431

Next Page is 450

 <

Page 431 Line 1 Column b

>

Depreciation expense related to environmental protection
facilities was calculated by applying a composite depreciation
rate to average plant balances.

<

Page 431 Line 6 Column b

>

The difference in the cost of environmentally clean fuels was
calculated based upon the average price differential between
0.7%, 1.0%, 2.0%, or 2.2% fuel purchased and 2.5%
sulfur fuel oil.

<

Page 431 Line 7 Column b >

Replacement power costs represents the cost for power generated
to compensate for the deficiency in output due to the addition
of pollution control equipment.

<

Page 431 Line 11 Column c

>

Actual expenses are not available.

Page 431 Footnote.1

 Schedule

INDEX

Accrued and prepaid taxes .................................................................................... .
Accumulated Deferred Income Taxes .. ............... ....... ............................ .. ...................... .
Accumulated provisions for depreciation of
common utility plant ........................................... .... ...................................... .
uti l i ty plant .............................................. . ............................................. .
utility plant (summary) ...................•........................................................•......

r-

Advances
from associated companies .................. . ............................................................. .
Allowances ............................•....•.......•...................... • ...................................
Amortization
mi see ll aneous •....•.........................•....•...•..•.........................•....................•..
of nuclear fuel •........•.......................................•..•.......................•.... •• ........
Appropriations of Retained Earnings .•..............................••..•.............................•........
Associated Companies
advances from ......•............................. • ..• • .. • ...• . ............................................
corporations controlled by respondent .................................................................... .
control over respondent .......................•......•...•..•...•.......•..•..............................
interest on debt to ...............................................................•.....•..........••.....
Attestation ••••...•.•...........••...•..••......••...•..•.......•.....••..•....•..•..•..•..•...•..••...•...•..
Balance sheet
comparative .•........................•.......••...•..••..•...•......•.. • ..••..•.. . ........•.......•.....• .
notes to .........................................••..••.••..•....•.••..•..•...•....•...•..•.........•.••..
Bonds .......•••....•....•...•••.•...•...............................•..•.......•.......••.....••.•...•....••..
Capital Stock ...........•.•.•..•.•.•••............................. ••.•• ......... . ......•..•......•...•...••..
discount ..............................•..•.......................................... .. ... .. .......•... • .. .
expense
installments received ............•..•••..••..•............................•..•..• ...• .. • ..•........•......
premil.ms •....•••...••........................•...•...........................•..•...•.••..••.......•......
reacquired ...••....• •• .••..•••.•.•..............••...•..•..••..................................•.....•....
subscribed ••........•..•...•...••...............•...•..•.............................•....•...•..•......••
Cash flows, statement of .............•..••..••..•..............•..••.....•..•............................... • .
_!:hanges
important during year
Construction
overheads, electric . . . . . . . . . . . • . . • • • . • • . . • • . . . • . . . . . • • . . . • . . • . . • • . . • . . . . . . . . . . . . . . . . . . . . . • . . • • . . • . . • . . . . . .
overhead procedures, general description of .. .. .. .. .. .. .. .. .. .. .. .. .. .. . .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. ..
work in progress · common utility plant . .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. ..
work in progress - electric .. .. .. .. .. .. .. .. .. .. .. .. .. . .. . .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. . .. .. .. .. .. ..
work in progress- other utility departments
Control
corporations cont rolled by respondent •.••..•• • .............................••..•..•.••....................
over respondent .........................•.... . .•..........................•....•.....•..•..•..............
security holders and voting powers .•......... . .... .. ......•..••.••.. •...•... ..........................•...
Corporation
controlled by
incorporated . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • • . . . • . • • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . • . . • • . . . . . .
CPA, background information on . . . . . . • • . . . • . . . • • . . • . . . • . . . • . . • • . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
CPA Certification, this report form . • • . . . • . . . • • . . • • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . .

FERC FORM NO.1 (ED. 12- 93 )

Index 1

Page No.
262-263
234
272-277
356
219
200 - 201
256-257
228-229
340
202-203
118-119
256-257
103
102
256-257
1
110-113
122-123
256-257
251
254
254
252
252
251
252
120-121
108-109
217
218
356
216
200-201
103
102
106 - 107
103
101
101
i-ii

 Schedule

INDEX (Continued)

Deferred
credits, other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
debits, miscellaneous . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
income taxes accumulated - accelerated
amortization property .................................................................................. .
income taxes accumulated
other property ..........................•......................................
income taxes accumulated - other ......................................................................... .
income taxes accumulated - pollution control facilities .................................................. .
Definitions, this report form
Depreciation and amortization
of corrmon utility plant . . . . . . . . • . . • . . • . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . • . • . • . . . . . . . . . . . . . . . . . . . . . • . .
of electric plant . . . . . . . . . . . . . . . . • . . • . . • . . . . . . . . . . . . . . . . • . . • . . . . . . . . . . . . . . . . . . • . • . . • . • . . . . . . . . . . . . . . . . . . . .
Directors .............•.....•.......•..•........................•....•........................................
Discount on capital stock •....•......................................•......•.................................
Discount - premi urn on long- term debt .....•.......•...••.•....•................................•...............
Distribution of salaries and wages .•..•..•....•....•...................................•......•.•.............
Dividend appropriations .................•.........•.........•.................................................
Earnings, Retained .•.................•..................................•........•.............•..............
Electric energy account ............................................•....•.•....•.•.•.•........................
Environmental protection
expenses ..•..•....••....•..•..•............•......•....•.•....•..•.•.•....•.•.•......•......•....•........
f ac i l i t i es .....•..........•.................•.............................................................
Expenses
electric operation and maintenance ..•..•.•....•..•.•.•.•..•....•.•.••.•......•.•.•..•.............•.....•.
electric operation and maintenance, summary .•.•.•...........•....•.............•.•.•....•......•..........
unamortized debt .............•..........•..•.•..•.•.•......•..•.•..•.•.•..•.•.•.•.••.....•....•.•.........
Extraordinary property losses ..•.••.•...............•......•.•..•........•..•.•.•....•.•.•......•......•......
Filing requirements, this report form ........................................................................ .
General description of construction overhead procedure ..•.•....•....•.........................................
General information ...........•....•..•..•..•.•......•...........•....•......•................................
Instructions for filing the FERC Form 1 .....•.............•......•.••.•............•...............•..........
Gene~ating plant statistics
hydroelectric (large) ...••.•..•...........................................................................
punped storage (large) •.•.....•....................................•............•.........................
small plants ..............•..•..•.••.••.••.•.••••.•.••....................................................
steam-electric (large) ................•.....•.•...•...••.•.••.•.•..•.•.•.•..•.•.•.•.••...•.•.•............
Hydro-electric generating plant statistics ................•......••.....••.•.•.•.••.•.•.•.•..•.•.•............
Identification .••.•....•.........................•...••...••.•.•..•.•.•••..•.•...••.•.•....•.•.•.•..•..•......
Important changes during year .•.••.•...............•..........................................................
Income
statement of, by departments ................................. • ............................................
statement of, for the year (see also revenues) •..•...•...........•........................................
deductions, interest on debt to associated companies ..................................................... .
deduc;tions, miscellaneous amortization •.•....•....•.•..•.•....•.•..•...•..................................
deductions, other income deduction
deductions, other interest charges ....••....•.•..•.•.••.•.••.•.•.•..•.•..•.•.•.•.•..•.•.•.•....•.•........
Incorporation information •.....................••...••••.•.•..•.•.••.•.•....•...•...............•.•.•.........
Installments received on capital stock .•..•.•..•..•.•.........................................................

FERC FORM NO. 1 (ED. 12-95)

Index 2

Page No.

269
233
272-273
274-275
276-277
234
iii
356
219
336-337
105
254
256-257
354-355
118-119
118-119
401
431
430
320-323
323
256
230
i-ii
218
101
i- iv
406-407
408-409
410-411
402-403
406-407
108-109
114-117
114-117
340
340
340
340
101
252

 INDEX (Continued)

Schedule

Interest
charges, on debt to associated companies ................................................................. .
charges, other ........................................................................................... .
charges, paid on l ong-term debt, advances, etc ....•.......................................................
Investments
nonut i l i ty property ................................. . .................................................... .
subsidiary companies ............................•.........................................................
Investment tax credits, accumulated deferred •.................................................................
Law, excerpts applicable to this report form ................................................................. .
List of schedules, this report form ..................•..................•.....................................
Long-term debt ..•.......•.....................................................................................
Losses - Extraordinary property ........................••...•..••.......••..•.................................
Materials and supplies ...............•.........•...••...•..••..•....•...•............•...........•...••.......
Meters and line transformers ............................•..........••...•...••...•...•........................
Miscellaneous general expenses ...•...••...••........•...•...•.......••..•....•................................
Notes
to balance sheet ••..•...••....••..•....•....••..••...•...•......••...••..••...............................
to statement of changes in financial position .................................•............•..............
to statement of income ...••...•.....•...........••...•...•........•.......•..••..•...•...•..•..•...••.....
to statement of retained earnings ..............•.•..••..••..••......•....•......•.........................
Nonut i l i ty property ...............•.................... • •.....................................................
Nuclear fuel materials .........................•...•...•......................................................
Nuclear generating plant, statistics ........................•..•..•........ . ...•..•... • .......................
Nllli:ler of Electric Department Employees ..•....•...............................................................
Officers and officers' salaries ..........•...••...••...•..•..............................•..........•.........
OpC'
es - electric
ex,_ ; es - electric (slfilllary) . . • • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Other
., capital ••••..••..•••...••..•••..•••.•.•...•.......................................................
pa i
1s received from stockholders •....•..•.•...........................................................
do·
ga
,n resale or cancellation of reacquired
cap1 tal stock . . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . • . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
miscellaneous paid-in capital . . . . . . . . . . . . . . . . . . . . . . . . . . • . . . • . . • . . . • . . . . . . . . . . . . . . . • . . . . • . . . . . . . . . . • . . . . . . .
reduction in par or stated value of capital stock • • . . . • • . • . . . . . . . . . . . . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . . .
regulatory assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . • • . • • . . . • . . . • . . • • . . . . . . • . . . • . . • . . . • . . . . . . . . . • . . . . . . . . . . . . . . .
regulatory liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . • • • . • • . . . • . . • • . . • • . • • • . . • . . • . . • . . . . . . . . . . . . . . . . . . . . . . . . . .
Overhead, construction - electric • • • . . • • • . . . • • • . • • . . • • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Peaks, monthly, and output . . • • . . . . • • • . • • • • . • • • • . • • • . • • • . • • • . . . . . . . . . . . . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Plant, Common utility
accllllUlated provision for depreciation .....•.......•••..••..•..••..•...•...•.••...•.••....•.•••••..••..••.
acquisition adjustments ••...••••..•••.•••..••...•..•••.••..••.•••.••..•...•••••..••.••..••..•..••..••..•••
allocated to utility departments ......................................................................... .
completed construction not classified ........................••...........................................
construction work in progress . ; .......................................................................... .
expenses .....•.....................................................................•...............•......
held for future use ......•...........•.....•..••.......••.•. . ................•.............................
in service ...............................•....•...•..••... . ..•...•......•......••.........................
leased to others .•....•........•••.........................................•...•...•..•......••..••.•.....
Plant data ••.......•.•. . . ....•. •. ..••...••••• . • • .••.....••.........................•.••.........•••.•.•..•....

i ER~

FORM NO.

<ED. 12-95)

Index 3

Page No.

340
340
256-257
221
224-225
266-267
iv

2-4
256-257
230
227
429
335
122-123
122-123
122-123
122 - 123
221
202-203
402-403
323
104
320-323
323
253
253
253
253
253
232
278
217
401
356
356
356
356
356
356
356
356
356
217-218
336-337
401-429

 Schedule

INDEX (Continued)

Plant - electric
accumulated provision for depreciation ................................................................... .
construction work in progress ............................................................................ .
held for future use ...................................................................................... .
in service ............................................................................................... .
leased to others ................................•.........................................................
Plant - utility and accumulated provisions for depreciation
amortization and depletion (su11111ary) • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Pollution control facilities, accumulated deferred
income taxes ................................................................•..........•..................
Power Exchanges ...................•...........................................................................
Premillll and discount on long-term debt ............................•....•......................................
Premillll on capital stock •..•..•.............................................•....•............................
Prepaid taxes •..•.•..•..•..•..•..•......•..•..................................................................
Property - losses, extraordinary ............................................................................. .
Pl.lllped storage generating plant statistics ..........•......................•..................•...............
Purchased power (including power exchanges) ................•..........•....•...........•.•....•...............
Reacquired capital stock ...•.............•....................................................................
Reacquired long-term debt .•.••................................................................................
Receivers' certificates •...•.•.....•................................................................•.........
Reconciliation of reported net income with taxable income
from Federal income taxes ................................................................................ .
'
Regulatory c011111ission expenses deferred
Regulatory c011111ission expenses for year
Research, development and demonstration activities ........................................................... .
Retained Earnings
amortization reserve Federal ............................................................................. .
appropriated ..............•.....•........................................•....................... .- ....... .
statement of, for the year ............................................................................... .
unappropriated •••.••..•..•..•.••..••••.••.•.••.•..•.•..•.•..•.•..•....•.•....•.••...•.....................
Revenues - electric operating ................................................................................ .
Salaries and wages
·directors fees •...•..•........•.....•...........................................................•.........
distribution of •.••...............................................•......•...•............•...............
officers' ..................•........•..•..•.•.••.•.•.••.•..•...•..•........•.•............•..•......•.•.•.
Sales of electricity by rate schedules ..•.•..•....•..•.•.•..•.•.....•.....•....•..... ·.· ...............•.......
Sales - for resale ..•..•...................................•.....•.•....•.....................................
Salvage - nuclear fuel ••..••..................................................................................
Schedules, this report form
Securities
exchange registration ..•..•..•.....•............•......................................................•..
holders and voting powers ................................................•..•.•.•.....••...•..............
Statement of Cash Flows •..•.•...........................•....•.•.•.••.•....•....•.....•....•.•.•....•.•.•.....
Statement of income for the year .......••.••••.•..•.•....•....................................................
Statement of retained earnings for the year ....•................•.....•...•.•..•.•.••..•......•...............
Steam-electric generating plant statistics .........•............•.•.••.•.•..•.•....•.•.•........•.•..•.•......
Stock liability for conversion ..•..•..••.•.••.•.••...•.....•......•.........•.•.......................••.•...•
Substations ........•.....................•....•....•.........................••.........•.....................
Supplies -materials and ...................•....•.................................•...........................

FERC FORM NO.1 (ED. 12-90)

Index 4

Page No.

219
216
214
204-207
213

201
234
326-327
256
251
262-263
230
408-409
326-327
250
256-257
256-257
261
233
350-351
352-353
119
118-119
118-119
118-119
300-301
105
354-355
104
304
310-311
202-203
2-4
250-251
106-107
120-121
114-117
118-119
402-403
252
426
227

 INDEX (Continued)
Schedule
Taxes
accrued and prepaid ····················· ...... ........................................... ... ............... .
charged during year
on income, deferred and accumulated ........... . ......... ... ............................ .
reconciliation of net income with taxable income for . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Transformers, line - electric
Transmission
l i nes added during year .....................................................•.............................
lines statistics ...••.......................................•...•.................•.......................
of electricity for others ............................................•...•.......................•........
of electricity by others ............................•...•....•...•...•............................••......
Unamortized
debt discount .....................................................................•... •. .. • ...............
debt expense .......................................................................................•......
premi urn on debt ••...••.............••...•....•...•...•...•....•...................• •. ..•..................
Unrecovered Plant and Regulatory Study Costs ......•................•..........................................

FERC f ORM

~

1 (ED. 12-90 )

Index 5

Page No.

262 - 263
262-263
234
272-277
261
429
424-425
422-423
328-330
332
256-257
256-257
256-257
230

 FLORIDA PUBLIC SERVICE COMMISSION
SIGNATURE PAGE
I certify that I am the responsible accounting officer of

FLORIDA POWER & LIGHT COMPANY;
that I have examined the following report; that to the best of my knowledge,
information, and belief, all statements of fact contained in the said report are true
and the said report is a correct statement of the business and affairs of the
above named respondent in respect to each and every matter set forth therein
during the period from January 1, 1996 to December 31 , 1996, inclusive.
I also certify that all affiliated transfer prices and affiliated cost allocations were
determined consistent with the methods reported to this Commission 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
with the intent to mislead a public servant in the
performance of his official duty shall be guilty of
a misdemeanor of the second degree, punishable as
provided in s. 775.082, s. 775.083 , or s. 775.084.

April 15, 1997
Date

K. M. Davis
Name

Signed K M Davis
Signature

Vice President, Accounting , Controller and Chief Accounting Officer
Title

 DECEMBER 31 , 1996

FLORIDA POWER & LIGHT COMPANY

Affiliation of Officers and Directors
For the Year Ended December 31, 1996
For each director and officer of the Company, list the principal occupation or business affiliation
and all affiliations or connections with any other business or financial organizations, firms , or
partnerships . For purposes of this part, the official will be considered to have an affiliation with
any business or financial organization, firm or partnership in which he is an officer, director,
trustee, partner, or a person exercising similar functions.

DIRECTORS OF FLORIDA POWER & LIGHT COMPANY

James L. Broadhead - Chairman of the Board and Chief Executive Officer
FPL Group, Inc., Juno Beach, FL, Director, Chairman of the Board, President, and Chief
Executive Officer
FPL Group Capital Inc, Juno Beach, FL, Director, President and Chief Executive Officer
FPL Group International, Inc, North Palm Beach, FL, Director and Chairman of the Board (as
of 04/18/96)
ESI Energy, Inc., North Palm Beach, FL, Director
Turner Foods Corporation , Punta Gorda, FL, Director
Barnett Banks, Inc., Jacksonville, FL, Director
Delta Air Lines, Inc., Atlanta, GA, Director
The Pittston Company, Glen Allen , VA, Director
Dennis P. Coyle- General Counsel and Secretary
FPL Group, Inc., Juno Beach, FL, General Counsel and Secretary
FPL Group Capital Inc, Juno Beach, FL, Secretary
FPL Group International, Inc., North Palm Beach, FL, Secretary (as of 04/18/96)
Agricultural Management Services Company, Punta Gorda, FL, Assistant Secretary
Alandco Inc., North Palm Beach, FL, Director and Secretary
Alandco I, Inc., North Palm Beach, FL, Director and Secretary
Alandco/Cascade, Inc., North Palm Beach, FL, Director and Secretary
Avon Citrus Nursery, Inc., Punta Gorda, FL, Assistant Secretary
Cable GP, Inc., Juno Beach, FL, Director, President and Secretary
Cable LP I, Inc., Juno Beach, FL, Director, President and Secretary
Cable LP II, Inc., Juno Beach, FL, Director, President and Secretary
Cable LP Ill , Inc., Juno Beach, FL, Director, President and Secretary
Cable LP (Pasco) , Inc., Juno Beach, FL, Director, President and Secretary
Colonial Penn Capital Holdings, Inc., Juno Beach, FL, Director, President and Secretary
ESI Energy, Inc., North Palm Beach, FL, Director and Secretary
FPL Enersys, Inc., Miami, FL, Secretary
FPL Energy Services, Inc. , Miami, FL, Secretary
FPL Energy Services II, Inc., Miami, FL, Secretary (as of 10/30/96)

Page 451

 FLORIDA POWER & LIGHT COMPANY

DECEMBER 31 , 1996

DIRECTORS OF FLORIDA POWER & LIGHT COMPANY (Continued)
Dennis P. Coyle- General Counsel and Secretary (Continued)
FPL Group Holdings 1, Inc., Juno Beach, FL, Director and Secretary (as of 07/09/96)
FPL Group Holdings 2, Inc., Juno Beach, FL, Director and Secretary (as of 07/09/96)
FPL Holdings Inc, Juno Beach, FL, Director, President and Secretary
FPL Investments Inc, North Palm Beach, FL, Secretary
Land Resources Investment Co., Juno Beach, FL, Secretary
MBR Services, Inc. , Juno Beach, FL, Director and Secretary
Praxis Group, Inc. , Juno Beach, FL, Director and Secretary
QuaiTec Professional Services, Inc., Juno Beach, FL, Secretary
River Run Caretaking Service, Inc. , Punta Gorda, FL, Assistant Secretary (until12/31/96)
Telesat Cablevision , Inc., Juno Beach, FL, Director, President and Secretary
Telesat Cablevision of South Florida , Inc., Juno Beach, FL, Director, President and Secretary
Turner Aquaculture, Inc., Punta Gorda, FL, Assistant Secretary (until12/31/96)
Turner Corporation, Punta Gorda, FL, Assistant Secretary
Turner Foods Corporation , Punta Gorda, FL, Secretary
Adelphia Communications Corporation, Coudersport, PA, Director
Paul J. Evanson- President
FPL Group, Inc., Juno Beach, FL, Director
ESI Energy, Inc., North Palm Beach, FL, Director
FPL Enersys, Inc., Miami, FL, Director
FPL Energy Services Inc. , Miami, FL, Director
FPL Energy Services II, Inc. , Miami, FL, Director (as of 10/30/96)
Lynch Corporation , Greenwich, CT, Director
Southern Energy Homes, Inc., Addison , AL, Director
Jerome H. Goldberg- President Nuclear Division (until 03/01/96)
None
Lawrence J. Kelleher -Senior Vice President Human Resources
FPL Group, Inc., Juno Beach, FL, Vice President, Human Resources
Land Resources Investment Co., Juno Beach, FL. Director and President
QuaiTec Professional Services, Inc., Juno Beach, FL, Director
Turner Foods Corporation, Punta Gorda, FL, Director
- Thomas F. Plunkett- President Nuclear Division (as of 03/01/96)
Vice President, Turkey Point Nuclear Station (until 03/01/96)
C. 0 . Woody - Senior Vice President Power Generation
St. Johns River Power Park, Jacksonville, FL, Executive Committee
Scherer Plant Managing Board, Atlanta , GA, Member

451 -A

 DECEMBER 31 , 1996

FLORIDA POWER & LIGHT COMPANY

DIRECTORS OF FLORIDA POWER & LIGHT COMPANY (Continued)

,.....

Michael W . Yackira - Senior Vice President Finance and Chief Financial Officer
FPL Group, Inc., Juno Beach, FL, Vice President, Finance and Chief Financial Officer
FPL Group Capital Inc, Juno Beach, FL, Director, Vice President and Chief Financial Officer
FPL Group Holdings 1, Inc., North Palm Beach , FL, Director and President (as of 07/09/96)
FPL Group Holdings 2, Inc., North Palm Beach , FL. Director and President (as of 07/09/96)
FPL Group International, Inc., North Palm Beach, FL, Director and Vice President (as of
04/18/96; Chief Financial Officer (as of 06/25/96)
Alandco Inc. , North Palm Beach , FL, Director
FPL Enersys, Inc., Miami, FL, Director
FPL Energy Services , Inc., Miami, FL, Director
FPL Energy Services II, Inc., Miami, FL, Director (as of 10/30/96)
FPL Investments Inc, West Palm Beach , FL, Director
MBR Services, Inc., Juno Beach, FL, Director
Palmetto Insurance Company Limited , Georgetown, Cayman Islands, Director
Palms Insurance Company Limited, Georgetown , Cayman Islands, Director
Turner Foods Corporation, Punta Gorda, FL, Director

451-B

 FLORIDA POWER & LIGHT COMPANY

DECEMBER 31 , 1996

OFFICERS OF FLORIDA POWER & LIGHT COMPANY
William H. Bohlke - Vice President. Nuclear Engineering (05/13/96 until 12/02/96)
Florida Power & Light Company, Vice President, Nuclear Engineering & Licensing (until
02/05/96) ; Vice President, St. Lucie Nuclear Station (02/05/96 until 05/13/96)
Kenneth R. Craig - Acting Vice President. Nuclear Engineering & Licensing (02/05/96 until
05/13/96)
None
K. Michael Davis -Vice President. Accounting . Controller and Chief Accounting Officer
FPL Group, Inc., Juno Beach, FL, Controller and Chief Accounting Officer
FPL Group Capital Inc, Juno Beach, FL, Controller and Chief Accounting Officer
FPL Group International, Inc. , North Palm Beach , FL, Controller (04/18/96 until 06/25/96)
Land Resources Investment Co. , Juno Beach , FL, Vice President and Treasurer
James E. Geiger- Vice President. Nuclear Assurance (until 02/05/96)
None
William W . Hamilton - Vice President. Customer Service
FPL Energy Services, Inc., Miami, FL, Director
FPL Energy Services II , Inc., Miami, FL, Director (as of 10/30/96)
FPL Enersys, Inc., Miami , FL, Director
MBR Services , Inc. , Juno Beach , FL, Director and President
James P. Higgins- Vice President. Tax
FPL Group, Inc., Juno Beach , FL, Vice President, Tax
MES Financial Corp., Wilmington , DE , Director
Mayberry Investments, Inc. , Wilmington , DE, Director and Vice President (as of 12/26/96)
Robert J. Hovey. Vice President. Turkey Point Nuclear Station
None
Dennis M . Klinger- Vice President. Information Management
None
Rajiv S. Kundalkar - Vice President. Nuclear Engineering (as of 12/16/96)
None
Larry J. Laseter- Vice President. Sales and Marketing (as of 10/21/96)
FPL Energy Services, Inc, Miami, FL, Director and President (as of 10/21/96)
FPL Energy Services II , Inc., Miami, FL, Director and President (as of 10/30/96)
FPL Enersys, Inc., Miami , FL, Director and President (as of 10/21/96)
FPL Services, Miami, FL, Management Committee Member (as of 10/21/96)
Sidney H. Levin- Vice President. Corporate and External Affa irs
None
451-C

 DECEMBER 31 , 1996

FLORIDA POWER & LIGHT COMPANY

OFFICERS OF FLORIDA POWER & LIGHT COMPANY (Continued)
Robert M . Marshall- Vice President. Distribution
None
Jack G . Milne -Vice President. Corporate Communications
FPL Group, Inc., Juno Beach , FL, Vice President, Corporate Communications
Armando J. Olivera -Vice President. Power Delivery
Advanced Joint Operations, Inc., Miami, FL, President
Antonio Rodriguez - Vice President. Operations
None
David A. Sager- Vice President. Nuclear Assurance (02/05/96 until 05/13/96)
Vice President, St. Lucie Nuclear Station (until 02/05/96)
Dilek L. Samil - Treasurer and Assistant Secretary
FPL Group, Inc., Juno Beach , FL, Treasurer
FPL Group Capital Inc, Juno Beach, FL, Director, Vice President, Treasurer and Assistant
Secretary
Alandco Inc., North Palm Beach , FL, Treasurer
Alandco I, Inc., North Palm Beach, FL, Treasurer
Alandco/Cascade, Inc., North Palm Beach , FL, Treasurer
Cable GP, Inc., Juno Beach, FL, Treasurer
Cable LP I, Inc. , Juno Beach , FL, Treasurer
Cable LP II , Inc., Juno Beach, FL, Treasurer
Cable LP Ill, Inc. , Juno Beach, FL, Treasurer
Cable LP (Pasco), Inc., Juno Beach , FL, Treasurer
Colonial Penn Capital Holdings, Inc. , Juno Beach, FL, Director, Vice President and Treasurer
ESI Energy, Inc., North Palm Beach , FL, Treasurer
FPL Energy Services, Inc., Miami, FL, Treasurer and Assistant Secretary
FPL Energy Services II, Inc., Miami, FL, Treasurer and Assistant Secretary (as of 10/30/96)
FPL Enersys, Inc., Miami, FL, Treasurer and Assistant Secretary
FPL Group International, Inc., North Palm Beach , FL, Vice President (04/18/96 until 06/25/96) ;
Treasurer and Assistant Secretary (as of 04/18/96)
FPL Holdings Inc, Juno Beach, FL, Director, Vice President and Treasurer
FPL Investments Inc, West Palm Beach , FL, Treasurer
MBR Services, Inc., Juno Beach, FL, Treasurer
Palmetto Insurance Company, Limited , Georgetown, Cayman Islands, Director, Treasurer and
Assistant Secretary
Palms Insurance Company, Limited , Georgetown, Cayman Islands, Director, Treasurer and
Assistant Secretary
Praxis Group, Inc., Juno Beach , FL, Treasurer
QuaiTec Professional Services, Inc., North Palm Beach, FL, Director and Treasurer
Telesat Cablevision, Inc., Juno Beach , FL, Treasurer
Telesat Cablevision of South Florida , Inc., Juno Beach , FL, Treasurer
451-D

 FLORIDA POWER & LIGHT COMPANY

DECEMBER 31 , 1996

OFFICERS OF FLORIDA POWER & LIGHT COMPANY (Continued)
James E. Scalf- Vice President. Engineering and Technical Services
None

J..c .A. Stall - Vice President.

St. Lucie Nuclear Station (as of 05/13/96)

:me
Robert E. Stewart, Jr.- Vice President. Marketing (until10/21/96)
FPL Enersys, Inc., Miami, FL, Director and President (until10/21/96)
FPL Energy Services, Inc., Miami, FL, Director (until1 0/21/96)
FPL Services, Miami, FL, Management Committee Member (10/21/96)
William G . Walker. Ill -Vice President. Regulatory Affairs
None
Michael M. Wilson, Vice President
None

Page 451-E

 BUSINESS CONTRACTS WITH OFFICERS, DIRECTORS AND AFFILIATES

FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

List all contracts , agreements , or other business arrangements* entered into during the
calendar year (other than compensation-related to position with respondents) between the
respondent and each officer and director of the Company. 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

James L. Broadhead

Amount

Identification of
Product or Service

Barnett Banks, Inc.
Jacksonville, FL

$29,177

Banking Services

James L. Broadhead

Delta Air Lines, Inc.
Atlanta , GA

$1 ,028,284

Air Travel

Dennis P. Coyle

Adelphia Communications
Corporation
Coudersport, PA

$4,931

Cable TV Services

C. 0 . Woody

St. Johns River Power Park
Jacksonville, FL

$77,220,410
$48,647 ,621

Capacity Charges
Energy Charges

Note: The above listing excludes contributions, payments to educational institutions, hospitals and
industry associations and other dues. See pages 454 through 459 for disclosure of diversification activity.

Page 452

 Reconciliation of Gross Operating Revenues
Annual Report versus Regulatory Assessment Fee Return
Florida Power & Light Company

Company:

.
I
1

(a)

Line

Description

No .
1

Total Sales to Ultimate Customers (440-446, 448)

2

Sales for Resale (44 7)

For the Year Ended December 31, 1996
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).
(b)
(d)
(e)
(f)
(c)
(g)
(h)

Gross Operating

Interstate and

Adjusted Intrastate

Gross Operating

Interstate and

Adjusted Intrastate

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)

$5,725,754 ,733

$5,725,754,733

$5 ,725,754,733

$5 ,725 ,754 ,733

$0

158,508,788

158,508,788

0

158,508,788

158,508 ,788

0

0

5,884,263,521

158,508,788

5,725 ,754,733

5,884 ,263,521

158,508,788

5,725 ,754 ,733

0

(53)

0

j

3
I

Total Sales of Electricity

4

Provision for Rate Refunds (449.1)

J

Total Net Sales of Electricity

i

Total Other Operating Revenues (450-456)

(11

7

Other (Specify)

w

8

-!:>

(12, 175,689)

(12 , 175,636)

(53)

(12, 175,689)

(12, 175,636)

5,872 ,087 ,832

146,333 ,152

5,725,754 ,680

5,872 ,087 ,832

146,333,152

5,725,754,680

0

114,339,895

818 ,906

113,520,989

114,339 ,895

818 ,906

113,520 ,989

0

$5,986,427 ,727

$147,152,058

$5,839,275,669

$5,986,427 ,727

$147,152,058

$5 ,839 ,275 ,669

$0

I

9
!

,6

Total Gross Operating Revenues

Notes:

i

'

I
I

i

--~

----- -- -

 FLORIDA PUBLIC SERVICE COMMISSION

DIVERSIFICATION REPORT
FLORIDA POWER & LIGHT COMPANY

1996

PSC/AFA/16 (12/94)

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Changes in Corporate Structure
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31 , 1996

Provide any changes in corporate structure including partnerships,
minority interests and joint ventures, and an updated organizational chart.

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

Effective
Date
(a)
Various

Description
of Change
(b)

As described below and per attached organizational structure dated
December31 , 1996.

04/20/95

WB Cable Associates, Ltd ., a limited partnership, sold and deleted
from Telesat Cablevision , Inc. organization .

02/08/96

Port 95-3, Ltd. added as a limited partnership within Alandco , Inc.
organization.

03/05/96

ESI Brady Power Services, Inc. added as a subsidiary within
ESI Energy, Inc. organization.

03/31/96

Dixie Valley Power Partners , a general partnership , sold and
deleted from ESI Energy, Inc. organization .

04/17/96

FPL International, Inc. added as a subsidiary within FPL Group
Capital Inc organization .

04/22/96

Crete I Cayman, Inc. added as a subsidiary within FPL Group
International, Inc. organization .

04/22/96

Crete II Cayman, Inc. added as a subsidiary within FPL Group
International, Inc. organization .

04/22/96

Crete Ill Cayman, Inc. added as a subsidiary within FPL Group
International , Inc. organization .

04/22/96

Faeto Cayman , Inc. added as a subsidiary within FPL Group
International, Inc. organization .

04/22/96

FPL Cayman HT, Inc. added as a subsidiary within FPL Group
International , Inc. organization .
Page 454
Schedule 1 - PSC/AFA/16 (12/94)

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Changes in Corporate Structure
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

Provide any changes in corporate structure including partnerships,
minority interests and joint ventures, and an updated organizational chart.

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

Effective
Date
(a)
04/22/96

Description
of Change
(b)
FPL Cayman LT, Inc. added as a subsidiary within FPL Group
International , Inc. organization .

04/22/96

FPL Cayman SF, Inc. added as a subsidiary within FPL Group
International , Inc. organization .

04/22/96

Monte San Giorgio Cayman , Inc. added as a subsidiary within
FPL Group International, Inc. organization.

04/22/96

Mynydd Gordu Cayman , Inc. added as a subsidiary within FPL Group
International, Inc. organization .

04/22/96

Owenreagh Cayman , Inc. added as a subsidiary within FPL Group
International, Inc. organization .

04/22/96

Riva-Caleone Cayman , Inc. added as a subsidiary within FPL Group
International, Inc. organization .

04/22/96

San Bartolomeo Cayman , Inc. added as a subsidiary within FPL Group
International , Inc. organization.

04/22/96

Werfa Cayman , Inc. added as a subsidiary within FPL Group
International, Inc. organization.

06/18/96

SEMASS Investors LP, a limited partnership, sold and deleted from
ESI Energy, Inc. organization .

06/18/96

SEMASS Partnership , a limited partnership, sold and deleted from
ESI Energy, Inc. organization .

06/26/96

FPL Cayman HT, Inc. changed its name to FPL International Holdings,
Inc. with in FPL Grou p International, Inc. organization .
Schedule 1- PSC/AFA/16 (12/94)
Page 4541

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Changes in Corporate Structure
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

Provide any changes in corporate structure including partnerships,
minority interests and joint ventures, and an updated organizational chart.

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

Effective
Date
(a)
06/26/96

Description
of Change
(b)

FPL Cayman LT, Inc. changed its name to FPL International Holdings II,
Inc. within FPL Group International, Inc. organization.

06/26/96

FPL Cayman SF, Inc. changed its name to FPL International Investment
Company within FPL Group International, Inc. organization .

06/27/96

FPL Mamonal, Inc. added as a subsidiary within FPL Group International,
Inc. organization .

06/27/96

FPL TermoCandelaria , Inc. added as a new subsidiary within
FPL Group International, Inc. organization .

06/27/96

FPL Termovalle, Inc. added as a subsidiary within FPL Group
International, Inc. organization.

07/08/96

FPL Group Holdings 1, Inc. added as a subsidiary within FPL Group
Capital Inc organization .

07/08/96

FPL Group Holdings 2, Inc. added as a subsidiary within FPL Group
Capital Inc organization.

07/18/96

KRM Columbia I, L.P. added as a limited partnership within FPL Group
International, Inc. organization .

07/25/96

Owenreagh Cayman Power Partners, LLC added as a subsidiary
within FPL Group International, Inc. organization .

07/26/96

Owenreagh Power Partners added as a limited partnership within
FPL Group International, Inc. organization.

07/30/96

FPL International, Inc. changed its name to FPL Group International , Inc.
within FPL Group Capital Inc organization .
..
Page 45411
Schedule 1 - PSC/AFA/16 (12/94)

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Changes in Corporate Structure
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31 , 1996

Provide any changes in corporate structure including partnerships,
minority interests and joint ventures, and an updated organizational chart.

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

Effective
Date
(a)
08/28/96

Description
of Change
(b)

ESI Bay Area GP, Inc. added as a subsidiary within ESI Energy, Inc.
organization .

08/30/96

Karaha Sodas Investment Corp. added as a subsidiary within FPL
Group International, Inc. organization .

09/26/96

ESI Energy Australia Pty. Limited dissolved and deleted from
ESI Energy, Inc. organization .

09/26/96

ESI Energy Australia Hunter Valley Pty. Limited dissolved and
deleted from ESI Energy, Inc. organization .

10/02/96

KRM Columbia II , L.P. added as a limited partnership within FPL
Group International, Inc. organization .

10/08/96

ESI Doswell GP, Inc. added as a subsidiary within ESI Energy, Inc.
organization .

10/08/96

ESI Doswell GP II , Inc. added as a subsidiary within ESI Energy, Inc.
organization .

10/23/96

FPL Group International South America , Inc. added as a subsidiary
within FPL Group International, Inc. organization .

10/23/96

FPL Group International South America II , Inc. added as a subsidiary
within FPL Group International, Inc. organization.

10/28/96

ESI Doswell Power Services , Inc. added as a subsidiary within
ESI Energy, Inc. organization .

10/28/96

ESI DLP-LP Holdings, added as a subsidiary within ESI Energy, Inc.
organization.
...
Schedule 1 - PSC/AFN16 (12/94)
Page 454ru

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Changes in Corporate Structure
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

Provide any changes in corporate structure including partnerships ,
minority interests and joint ventures, and an updated organizational chart.

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

Effective
Date
(a)
10/30/96

Description
of Change
(b)

FPL Energy Services II , Inc. added as a subsidiary within Florida
Power & Light Company organization .

11/08/96

FPL Group International Brazil (Cayman) I, Inc. added as a subsidiary
within FPL Group International, Inc. organization .

11/08/96

FPL Group International Brazil (Cayman) II, Inc. added as a subsidiary
within FPL Group International organization .

12/04/96

ESI Cherokee Holdings, Inc. added as a subsidiary within ESI Energy,
Inc. organization.

12/04/96

ESI Cherokee MGP, Inc. added as a subsidiary within ESI Energy, Inc.
organization .

12/04/96

HJT Holdings, Inc. added as a subsidiary within FPL Group Capital Inc
organization .

12/04/96

EMB Investments, Inc. added as a subsidiary within FPL Group Capital
Inc organization .

12/04/96

LCR Holdings, Inc. added as a subsidiary within FPL Group Capital Inc
organization.

12/10/96

ESI Cherokee County, L.P. added as a limited partnership within
ESI Energy, Inc. organization .

12/10/96

Port 95-4 , Ltd. added as a limited partnership within Alandco, Inc.
organization .

12/12/96

SRM Investments, L.P. added as a limited partnership within
FPL Group Capital Inc organization .
Page 4541v
Schedule 1- PSC/AFA/16 (1 2/94)

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Changes in Corporate Structure
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31 , 1996

Provide any changes in corporate structure including partnersh ips,
minority interests and joint ventures, and an updated organizational chart.

Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16

Effective
Date
(a)
12/19/96

(b)

Cherokee County Cogeneration Corp. added as a subsidiary within
ESI Energy, Inc. organization.

12/26/96

ESI Vansycle GP, Inc. added as a subsidiary within ESI Energy, Inc.
organization .

12/26/96

ESI Vansycle LP , Inc. added as a subsidiary within ESI Energy, Inc.
organization .

12/26/96

Mayberry Investments, Inc. added as a subsidiary within Telesat
Cablevision , Inc. organization .

12/27/96

ESI Vansycle Partners, L.P. added as a limited partnership
within ESI Energy, Inc. organization .

12/31/96

AMS Realty, Inc., a subsidiary, dissolved and deleted from Turner
Foods Corporation organization .

12/31/96

River Run Caretaking Service , Inc., a subsidiary, dissolved and deleted
from Turner Foods Corporation organization .

12/31/96

Turner Aquaculture , Inc., a subsidiary, dissolved and deleted from
Turner Foods Corporation organization .

17

18
19
20
21
22
23
24
25
26
27
28
29
30
31
32

Description
of Change

Page 454v

Schedule 1 - PSC/AFN1 6 (12/94)

 FPL Attachment
FPSC Schedule 1 • PSC/AFA/16
12/31/96 ·Organization Chart
Rev. 22
Page 1 of 8

FPL GROUP, INC. AND SUBSIDIARIES

I

FPL GROUP, INC.

I

I

I

FLORIDA POWER
& LIGHT COMPANY

FPL ENERSYS, INC.

-

FPLENERGY
SERVICES, INC.

'--

FPLENERGY
SERVICES II, INC.

1--

I

FPLGROUP
CAPITAL INC

I

I
ALANDCO INC.

See Chart 1A

1---

ESI ENERGY, INC.

See Chart 1B

f--

FPL HOLDINGS INC

CAS INVESTMENTS, INC.

f-

-

FPLGROUP
FOUNDATION, INC.

f-

I
'-

FPLGROUP
HOLDINGS 1, INC.

FPL SERVICES
(GP)

COLONIAL PENN CAPITAL
HOLDINGS, INC.

-

T
FPL HISTORICAL
MUSEUM, INC.
JEA 500 KV

TRANSMISSION

-

-

-

FPLGROUP
INTERNATIONAL, INC.

-

MBA SERVICES, INC.

-

LINE (..N)

KPB FINANCIAL CORP.

FPLGROUP
HOLDINGS 2, INC.

BAY LOAN AND
INVESTMENT BANK

HJT HOLDINGS, INC.

-

f.--

LCR HOLDINGS, INC.

f.--

1---

LAND RESOURCES
INVESTMENT CO.
ROBERT W. SCHERER
ELECTRIC GENERATING
PLANT- UNIT #4 (JV)
ST. JOHNS RIVER
POWER PARK (JV)

See Chart 1C

1---

T

SAM INVESTMENTS, L P.
(LP)
1---

~

(GP) • GENERAL PARTNERSHIP
(..N) • JOINT VENTURE
(LP) "' LIMITED PARTNERSHIP

PALMETTO INSURANCE
COMPANY, UMITED

I
EMB INVESTMENTS, INC.

PALMS INSURANCE
COMPANY, UMITED

-

PRAXIS GROUP, INC.

---1 QUALTEC PROFESSIONAL
SERVICES, INC.

454A

-

TELESAT
CABLEVlSION, INC.

See Chart 1D

-

TURNER FOODS
CORPORATION

See Chart 1E

 FPL Attachment
FPSC Schedule 1 - PSC/AFA/16
12/31/96- Organization Chart
Rev. 22
Page 2 of 8
CHAAT1A

ALANDCO INC.

FPL GROUP, INC.

FPL GROUP CAPITAL INC

ALANDCO INC.

ALAN DC0/CASCADE, INC.

L
L
-

TAMPA 301 ASSOCIATES JOINT VENTURE (JV)
FOUNTAIN SQUARE ASSOCIATES (JV)

ALANDC 0 I, INC.

-PORT95 COMMERCE PARK ASSOCIATION, INC. (PA)
-PORT95- 1, LTD. (LP)
-PORT95- 2, LTD. (LP)
t - - - PORT 95- 3, LTD. (LP)
t - - - PORT 95- 4, LTD. (LP)
'--------

TWC SIXTY-THREE, INC.

(JV) • JOINT VENTURE
(LP) .. UMITED PARTNERSHIP
(PA) ""PROPERTY OWNERS ASSOCIATION

4548

 FPL Attachment
FPSC Schedule 1 • PSC/AFN1e
12/31/ge ·Organization Chart
Rev.22
Page 3 of 8

CHART 18

ESI ENERGY, INC.
FPL GROUP, INC.

I
FPL GROUP CAPITAL INC

l
ESI ENERGY, INC.
ALPHA JOSHUA (PRIME), INC.
ALPHA MARIAH (PRIME), INC.
BETA MARIAH (PRIME), INC.
BETA WILLOW (PRIME), INC.

(OT)
(OT)
(OT)
(OT)

}
SAGEBRUSH (GOP)

BIRCH LIMITED PARTNERSHIP
ESIANTILLES, INC.
OWER BARGE ANTILLES, L.P.
p
L PBAJAMAICA LIMITED
ESIA NTILLES LP, INC.

I

ESIAU STRALIA II, INC.
ESIBAY AREA, INC.
NDPOWER PARTNERS
NDPOWER PARTNERS
WI NDPOWER PARTNERS
WI NDPOWER PARTNERS
WI NDPOWER PARTNERS
ESI BAY AREA GP, INC.

p~

1989, L.P.
1990, L.P.
1991, L.P.
1991-92, L.P.
1992, L.P.

ESIB RADY,INC. *
L ESl BH LIMITED PARTNERSHIP
L BRADY POWER PARTNERS (GP)
ESICALIFORNIA HOLDINGS, INC.
CH ORMESA,INC.
ACME ORMESA II PARTNERS, L.P.
EAST MESA PARTNERS (GP)
ORMESA GEOTHERMAL II (GP)
ORMESA OPERATORS (GP)
CH ORMESA LP, INC.
CH POSDEF, INC.
~ ACME POSDEF PARTNERS, L.P.
I L POSDEF POWER COMPANY, L.P.
CH POSDEF LP, INC.
ESI SKY RIVER, INC. *
L ESI SKY RIVER LIMITED PARTNERSHIP
L SKY RIVER PARTNERSHIP (GP)
L SAGEBRUSH PARTNER FIFTEEN, INC.
L SAGEBRUSH (GOP)

r

•
(GOP)
(GP)
(On

•
•
•
•

rt

Aleo In Partnership with ESI LP, Inc.
General Co-Ownerahlp Partnership
General Partnership
Owner Trust
Continued on Page 4 of 8

454C

......

 FPL Attachment
FPSC Schedule 1 - PSC/AFA/16
12/31/96 - Organization Chart
Rev.22
Page 4 of 8

CHART 18 - Continued

ESI ENERGY, INC.

ESI ENERGY, INC.

(Continued)

ESICH EROKEE GP, INC.
ESI CHEROKEE COUNTY, L.P.
ESICH EROKEE LP, INC.
ESI CH EROKEE HOLDINGS, INC.
tESI CHEROKEE MGP, INC.
CH EROKEE COUNTY COGENERATION CORP.
ESI Dl XIE VALLEY, INC.
L ESI DV PARTNERS, L.P.
ESI Dl XIE VALLEY LP, INC.
ESIDLP-LP HOLDINGS, INC.
ESI DO MINICAN REPUBLIC, INC.
ESIDOSWELL, INC.*
L ESI DOSWELL, L.P.
L DOSWELL II LIMITED PARTNERSHIP
L DOSWELL LIMITED PARTNERSHIP
ESI DO SWELL GP, INC.

r

ESI DO SWELL GP II, INC.
ESI DO UBLE "C", INC.
L ESI CC LIMITED PATNERSHIP
L DOUBLE "C" LIMITED (LP)
ESIKE AN FRONT, INC.
L 'tl KF LIMITED PARTNERSHIP
KERN FRONT LIMITED (LP)
ESI SIE RRA,INC.
L 'tl HS LIMITED PARTNERSHIP
HIGH SIERRA LIMITED (LP)

KERN FRONT PIPELINE
JOINT VENTURE

ESIEB ENSBURG, INC.
L~ ENSBURG INVESTORS LIMITED PARTNERSHIP
EBENSBURG POWER COMPANY (GP)
ESIGE OTHERMAL, INC.
L ~ CA LIMITED PARTNERSHIP
COSO FINANCE PARTNERS (GP)
~IGE OTHERMAL II, INC.
II LIMITED PARTNERSHIP
~CA
COSO FINANCE PARTNERS II (GP)
ESI JONESBORO, INC.
Sl JONESBORO LIMITED PARTNERSHIP
BABCOCK-ULTRAPOWER JONESBORO (GP)
ESIJO NESBORO LP, INC.
ESI LP, INC.
VG LIMITED PARTNERSHIP
VICTORY GARDEN PHASE IV PARTNERSHIP
L SAGEBRUSH PARTNER SIXTEEN, INC.
L SAGEBRUSH (GOP)
ESIVICTORY, INC.
ESI MONTGOMERY COUNTY, INC.
L MONTENAY MONTGOMERY LIMITED PARTNERSHIP

It

rE~l

* • Alao In Partnership with ESI LP, Inc.
(GOP) = General Co-Ownership Partnersh ip
(GP) = General Partners hip
- 0) = Umited Partnership
Continued on Page 5 of 8

454D

 FPL Attachment
FPSC Schedule 1 • PSC/AFA/16
12/31/96 ·Organization Chart
Rev. 22
Page 5 of 8

CHART 18 - Continued

ESI ENERGY, INC.

ESI ENERGY, INC.
(Continued)

ESI MULTITRADE LP, INC.
MULTITRADE OF PITISYLVANIA COUNTY, L.P.
ESIPITISYLVANIA, INC.

f-

ESI PANAMA, INC.
ESIPHIUPPINES, INC.
ESIO PERATING SERVICES, INC.

t~

Sl BRADY POWER SERVICES, INC.
Sl DOSWELL POWER SERVICES, INC.
Sl VIRGINIA POWER SERVICES, INC.

ESISAN EMIDIO, INC.
ESI SEMASS CORP. LP, INC.
ESISTEAMBOAT, INC.
ESIU AI, INC.
ESIVANSYCLE GP, INC.
~ ESI VANSYCLE PARTNERS, LP.
ESIVANSYCLE LP, INC.
ESI WEST ENFIELD, INC.
Sl WEST ENFIELD LIMITED PARTNERSHIP

IE

L BABCOCK-ULTRAPOWER WEST ENFIELD (GP)

ESIW EST ENFIELD LP, INC.
ESI WTE DEVELOPMENT, INC.
FPLI NVESTMENTSINC
L FPL-BT VENTURES (JV)
HAR PER LAKE OPERATIONS, INC.
HYPERION VIII, INC.
HARPER LAKE COMPANY VIII
LUZ SOLAR PARTNERS LTD. VIII (LP)

t

HYPERION IX, INC.
HLC IX COMPANY
LUZ SOLAR PARTNERS LTD. IX (LP)

[

MES FINANCIAL CORP.
* • Aleo In Partnership with ESI LP, Inc.
(GP) • General Partnership
(LP) • Umtted Partnership
(JV) '"' Joint Venture
454E

 FPL Attachment
FPSC Schedule 1 • PSC/AFA/16
12/31/96 ·Organization Chart
Rev.22
Page 6 of8

CHART 1C

FPLGROUP
INTERNATIONAL, INC.

FPL GROUP, INC.

FPL GROUP CAPITAL INC

FPLGROUP
INTERNATIONAL, INC.
CRETE I CAYMAN, INC.
CRETE II CAYMAN, INC.
CRETE Ill CAYMAN, INC.
FAETO CAYMAN, INC.
FPL GROUP INTERNATIONAL SOUTH AMERICA, INC.

r-~

FPL GROUP INTERNATIONAL BRAZIL (CAYMAN) I, INC.
FPL GROUP INTERNATIONAL BRAZIL (CAYMAN) II, INC.

FPL GROUP INTERNATIONAL SOUTH AMERICA II, INC.
FPL TERMOCANDELARIA, INC.
FPL INTERNATIONAL HOLDINGS, INC.

f- KMR COLUMBIA II, LP. (LP)

FPL TERMOVALLE, INC.
FPL INTERNATIONAL HOLDINGS II, INC.

~

I

OWENREAGH CAYMAN POWER PARTNERS, LLC

L OWENREAGH POWER PARTNERS (LP)

OWENREAGH CAYMAN, INC.
FPL INTERNATIONAL INVESTMENT COMPANY

~

KMR COLUMBIA I, L.P. (LP)

FPL MAMONAL, INC.
KARAHA SODAS INVESTMENT CORP.
MONTE SAN GIORGIO CAYMAN, INC.
MYNYDD GORDU CAYMAN, INC.
RIVA-CALEONE CAYMAN, INC.
SAN BARTOLOMEO CAYMAN, INC.
WERFA CAYMAN, INC.

(LP) "' Umlted Partnership

454F

 FPL Attachment
FPSC Schedule 1 - PSC/AFN16
12/31/96- Organization Chart
Rev. 22
Page 7 of 8
CHART 1D

TELESAT CABLEVISION, INC.

FPL GROUP, INC.

FPL GROUP CAPITAL INC

TELESAT
CABLEVISION, INC.

MAYBE RAY INVESTMENTS, INC.

TELESAT CABLEVISION OF SOUTH FLORIDA, INC.
CABLE GP, INC.

~

OLYMPUS COMMUNICATIONS, L.P.

CABLE LP Ill, INC.

t

CABLE LP I, INC.
CABLE BY CHOICE, LTD. (LP)
DYNAMIC CABLEVISION OF FLORIDA, LTD. (LP)

CABLE LP II, INC.
CABLE LP (PASCO) , INC.

L

FLORIDA SATELUTE NETWORK, LTD. (LP)

(LP) - Umlted Partnership

454G

 FPL Attachment
FPSC Schedule 1 • PSC/AFA/16
12/31/96- Organization Chart
Rev. 22
Page 6 of 6

CHART1E
TURNER FOODS CORPORATION

FPL GROUP, INC.

FPL GROUP CAPITAL INC

TURNER FOODS
CORPORATION

AGRICULTURAL MANAGEMENT SERVICES COMPANY, INC.
(DBA: AMS ENGINEERING AND ENVIRONMENTAL)

AVONCI TAUS NURSERY, INC. (DBA: FLORIDA CITRUS NURSERY)

~ TURNER

CORPORATION

454H

 ANALYSIS OF DIVERSIFICATION ACTIVITY
New or Amended Contracts with Affiliated Companies
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

Provide a synopsis of each new or amended contract, agreement or arrangement with affiliated
companies for the purchase, lease, or sale of land , 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
Company
Line
(a)
No.
1 KPB Financial Corp.
2
3
4
5
6
7
8
9
10
11
12 KPB Financial Corp.
13
14
15
16
17
18
19
20
21
22
23
24
25 Turner Foods Corporation
26
27
28
29
30
31
32

Synopsis of
Contract
(b)
FPL and KPB Financial Corp. (KPB) entered into a Purchase and Sale
Agreement effective on January 3, 1996. Pursuant to the agreement, for a
sale price of $350,020,000, KPB agreed to sell and assign its rights to FPL
in various accounts, accounts receivable and other rights to the payment of
money which KPB acquired from FPL under a purchase and sale agreement
dated December 29, 1995. FPL agreed to purchase the above items by
forgiving KPB's indebtedness (as evidenced by KPB's December 29, 1995,
$350,000,000 Purchase Money Note), and for a cash payment of $20,000.
In addition, KPB paid FPL accrued interest of $272,222 .22 due on the
Purchase Money Note.
FPL and KPB Financial Corp. (KPB) entered into a Purchase and Sale
Agreement effective on December 31, 1996. Pursuant to the agreement, for
a sale price of $375,000,000, FPL agreed to sell and assign its rights to
KPB for the following FPL assets: accounts receivable generated from the
sale and/or provision by the seller of electricity and other goods and
services, and other rights to the payment of money derived from short term
financing, employee advances, income taxes, reimbursable projects,
damage claims, transmission service and interchanges, trade payables and
other miscellaneous items. In return, KPB agreed to purchase the above
receivables for a $375,000,000 promissory note, payable on demand and
bearing interest at 8% per annum. Interest payments on the promissory
note shall be paid monthly, commencing January 31, 1997.
Turner Foods Corporation (Turner Foods) has contracted water permit
modifications for FPL land in Desoto County with Water and Environment
Services, a non-affiliated company. The vendor is billing Turner Foods
directly for the services and the contract for these services is between the
vendor and Turner Foods. Turner Foods is billing FPL for only the contract
charges (no mark-up or any additional fees) . The contract is for $150,000. At
December 31 , 1996 approximately $74,000 had been paid by Turner Foods
and reimbursed by FPL.
Page 455
Schedule 2- PSC/AFA/16 (12/94)

 ANALYSIS OF DIVERSIFICATION ACTIVITY
New or Amended Contracts with Affiliated Companies
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

Provide a synopsis of each new or amended contract, agreement or arrangement with affiliated
companies for the purchase, lease, or sale of land, 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
Line
Company
No.
(a)
1 Palms Insurance
2
Company, Limited

3
4
5

6
7
8

Synopsis of
Contract
(b)
Effective January 1, 1996 Palms Insurance Company, Limited (Palms)
issued an insurance policy to FPL by which Palms provided indemnification
insurance for certain FPL contractor workers' compensation claims for
payment of a net premium of $1 ,751,479. The indemnified portion of each
claim is that portion above a modest self insured deductible to a maximum
of $500,000/claim (above $500,000/claim, commercial insurance is
purchased). Gross premium payments made by FPL to Palms totaled
$2,126,952.

9
10 FPL Energy Services, Inc. In 1996, FPL paid $91,800 to FPL Energy Services, Inc. for training FPL
employees. All training was related to the DUCT System Testing and Repair
11
program. This training instructs employees in the proper techniques for
12
testing air conditioning/heating ducts and repairs thereto.
13
14
In 1996, Florida Power & Light Company (FPL) assigned to FPL Services
15 FPL Services
all rights, title and interest in and to all amounts due or to become due under
16
Authorizations FPL had in effect with the General Service Administration
17
of the United States. These assigned Authorizations related to Demand Side
18
Management (DSM) related feasibility studies and/or DSM related retrofits.
19
FPL Services agreed to pay FPL $1 ,265 in 1996 and $364 in 1997 for the
20
rights related to ten assignments.
21
22
On September 9, 1996 FPL and FPL Services entered into a Letter of
23 FPL Services
Agreement
whereby FPL would conduct a study and develop a preliminary
24
interconnection design for FPL Services' NASA C5 Project. FPL Services
25
will pay FPL's actual costs incurred to perform the study and was required
26
to pay FPL an initial deposit of $6,000.
27
28
29
30
31
32
Schedule 2- PSC/AFA/16 (12/94)
Page 455A

 ANALYSIS OF DIVERSIFICATION ACTIVITY
New or Amended Contracts with Affiliated Companies
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

Provide a synopsis of each new or amended contract, agreement or arrangement with affiliated
companies for the purchase, lease, or sale of land , 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
Line
Company
No.
(a)
1 MBR Services, Inc.
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

FPL Group, Inc.

Synopsis of
Contract
(b)
Effective January 1, 1996, MBR Services, Inc., became inactive and
contracts with Palm Coast Utilities, the City of Naples and the City of Ft.
Myers were reassigned to FPL. FPL will record revenues and associated
expenses below the line for reading water meters for the existing clients
until such time as the contracts expire or are otherwise terminated . The
contract between the City of Ft. Myers and FPL to read the City's water
meters was terminated effective February 15, 1996 upon customer request.
Every time a subsidiary is added or deleted by an FPL Group, Inc. company
it becomes a party to, or is deleted from , the tax allocation arrangement of
the FPL Group Inc. consolidated return . Therefore, any corporate structure
changes reported on page 454 would also be reflected in FPL Group's tax
sharing arrangement.

27
28
29
30
31
32
Page 4558

Schedule 2- PSC/AFA/16 (12/94)

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Individual Affiliated Transactions in Excess of $500,000
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31 , 1996

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-recurring" item for the period in which it occurs.
Line

Name of
Affiliate

Description of
Transaction

Dollar
Amount

No.

(a)

(b)

(c)

2

FPL Group Foundation , Inc.

Charitable Contribution

$2,430,000
$59,176,775

3

FPL Group, Inc.

Florida Income Tax Payments

4
5

FPL Group, Inc.
FPL Group, Inc.

Federal Income Tax Payments
Thrift Plan Company Match Payments

$306,100,000
$18,720,045

6

FPL Group, Inc.

Common Dividend Payments

7

FPL Group, Inc.

FPL Group Billing 1/96-12/96

8

FPL Group, Inc.

State of Florida Income Tax Refund
Equity Contributions to FPL
Property Taxes

$592,815,157
$10,529,028
$11,452,367
$195,000,000
$3,205,382
$9,819,863
$3,975 ,009
$21 ,920,259

9 FPL Group, Inc.
10 Land Resource Investment Co.
11 Land Resource Investment Co.
12 KPB Financial Corp.

Management Fee
Draw Down from Storm Fund - Hurricane Andrew
Storm & Property Reserve Fund Contributions

13 KPB Financial Corp.
14 Palms Insurance Company,

Contract Employees Wrap-up Insurance

$5,331 ,881

1.5
Limited
16 Palms Insurance Company ,

Employee Workers Compensation Insurance

$6,208,093

17

Limited

18
19
20
21

NOTE: See page 458 for Assets or Rights Purchased from or Sold to Affiliates.

22
23
24
25
26
27
28
29
30
31
32
Pag e 456

Sched ule 3 - PSC/AFA/16 I

~ -:J J

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Summary of Affiliated Transfers and Cost Allocations
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

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 a purchase 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
(a)
FPL Group, Inc.
FPL Investments
Turner Foods Corporation
FPL Holdings, Inc.
Alandco, Inc.
Telesat Cablevision, Inc.
ESI Energy, Inc.
FPL Group Capital, Inc.
MBR Services, Inc.

FPL Group, Inc.
FPL Group, Inc.
- FPL Group, Inc.
FPL Group, Inc.
FPL Group, Inc.
FPL Group, Inc.
FPL Group, Inc.
FPL Group, Inc.
FPL Group, Inc.

Type of Service
and/or
Name of Product
(b)

Relevant Contract
or Agreement and
Effective Date
(c)

"P" or
"S"
(d)

Total Charge for Year
Dollar
Account
Number
Amount
(e)
(f)

See
See
See
See
See
See
See
See
See

Note
Note
Note
Note
Note
Note
Note
Note
Note

1
1
1
1
1
1
1
1
1

s
s
s
s
s
s
s
s
s

146
146
146
146
146
146
146
146
146

$822,870
$381
$408,087
$30
$107,016
$309,546
$1,305,715
$5,135,231
$23 ,624

See
See
See
See
See
See
See
See
See

Note 2
Note 2
Note 2
Note 2
Note 2
Note 2
Note 2
Note 2
Note 2

p
p
p
p
p
p
p
p
p

107
143
146
165
186
228.3
232
241
242

$35,872
($22,413)
$200
$90,348
$51,675
$994,948
($2,703)
($479)
$1,185,150

Page 457

Schedule 4- PSC/AFA/16 (12/95)

 ANJ.

"SIS OF DIVERSIFICATION ACTIVITY

Summary of Affiliated Transfers and Cost Allocations
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

Name of
Affiliate
(a)

Type of SeNice
and/or

or Agreement and

Name of Product
(b)

Effective Date
(c)

FPL Group, Inc.

See Note 2

FPL Group, Inc.

See Note 2
See Note 2

FPL Group, Inc.

FPL Group, Inc.

See Note 2
See Note 2
See Note 2

FPL Group, Inc.

See Note 2

FPL Group, Inc.
FPL Group, Inc.

Relevant Contract

See Note 2
See Note 2

FPL Group, Inc.
FPL Group, Inc.

See Note 2
See Note 2

FPL Group, Inc.
FPL Group, Inc.

See Note 2
See Note 2

FPL Group, Inc.
FPL Group, Inc.

"P" or
"Sit
(d)

Total Charge for Year
Account
Dollar
Number
Amount
(f)
(e)

p
p
p
p
p
p
p
p
p
p
p
p
p

408.1
415
500

$117 ,424
($12,716)
$34,666
$1,764
$74,227
$3,852

510
517
546
551

$1 ,176

908
920
921
923

$6,994
$4,374,761
$2,473,207
$700,427

926
930.2

$3,228,814
$1,187,914

FPL Group Capital, Inc.

Bay Loan -Property Loss

No Purchase Order

p

146

Turner Foods

Fruit Baskets

No Purchase Order

p

146

$1 ,155

921

$10,976

560
580

$36,900
$36,900

Corporation

Turner Foods

No Purchase Order

Permitting

Corporation

p
p

$27,156

Note 1: Services primarily provided by FPL include accounting , financial, consulting , human resources systems and programs.
education and training , land management, legal, payroll, management and administrative, computer services, printing
and duplicating , physical facilities, software maintenance, license fees, and aviation services .

Note 2:Services primarily received by FPL include the following : (1) human resources including compensation, incentive programs
and directors' fees ; (2) financial services; and (3) management services.

Page 457A

Schedule 4- PSC/AFA/16 (12/96)

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Summary of Affiliated Transfers and Cost Allocations
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

Type of Service
and/or
Name of Product
(b)

Name of
Affiliate
(a)

Relevant Contract
or Agreement and
Effective Date
(c)

"P" or
"Su

Total Charge for Year
Account
Dollar
Amount
Number

(d)

(e)

(f)

KPB Financial Corp.

Capital Contributions

No Purchase Order

p

123.1

$280,000

KPB Financial Corp.

Administrative Fee

No Purchase Order

p

426.5

$20,000

KPB Financial Corp.

Federal Income Tax Liability

No Purchase Order

p

146

$272,284

$50,000

on Storm Fund

FPL Historical Museum

Exhibit

No Purchase Order

p

930.2

FPL Group, Inc.

Flexible Dividend

No Purchase Order

p

232

$4,120

926

$256,600

FPL Energy Services, Inc Cash Advances

No Purchase Order

s

234

$30,000

FPL Energy Services, Inc Training Classes

No Purchase Order

p

908

$91 ,800

FPL Services

Cash Advances

No Purchase Order

s

234

$1 ,995,572

FPL Services

Cash Re-Payments

No Purchase Order

p

FPL Services

Interest on Cash Advances

No Purchase Order

s

234
234

$3 ,059,926
$75,069

FPL Services

Safety Awards

No Purchase Order

p

588

$479

FPL Services

Duct Incentive Certificate-

No Purchase Order

p

908

$63,536

No Purchase Order

p

908

$131,894

No Purchase Order

p

908

$10,000

Assigned to FPL Services
by Customer

FPL Services

Lighting Incentive CertificateAssigned to FPL Services
by Customer

FPL Services

Thermal Incentive CertificateAssigned to FPL Services
by Customer

Page 4578

Schedule 4- PSC/AFA/16 (12/96)

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Summary of Affiliated Transfers and Cost Allocations
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996
Total Charge for Year

Type of Service

Relevant Contract

Name of

and/or

or Agreement and

"P" or

Account

Dollar

Affiliate

Name of Product

Effective Date

"S"

Number

Amount

(a)

(b)

(c)

(d)

(e)

(f)

FPL Services

Demand Side Management

$321,672

See Note 3

No Purchase Order

(DSM) Service Charge

Palms Insurance
Company, Limited

Palms Insurance
Company, Limited

Contract Employees Wrap-up

No Purchase Order

Insurance

Employee Workmen's

No Purchase Order

Compensation Insurance

p
p
p
p
p
p
p

163

$44,640

165

$6,248,860

186

($100,000)

242

($951 ,979)

593

$5,610

184

$60,000

456

$24,750

p
p

165

$8,300,000

242

($2,091 ,907)

FPL Services

Deposit for Project Study

Job Order 101-82

s

174

$6,000

FPL Services

Contract Authorizations -

No Purchase Order

s

146

$369

907
921

$728

Assigned to FPL Services by
FPL.

$168

FPL Services

Booth Space at Energy EXPO

No Purchase Order

s

908

$300

Turner Foods

Lease of land for citrus grove

License Agreement -

s

454

$12,870

s

236

$15,544

s

510

$42,908

Corporation

at the Manatee Plant

3/31/91 - 6/15/2001

Property Taxes on this land

Turner Foods
Corporation

Remove Old Structure and
Construct New Building

No Purchase Order

551

$4,767
See Note 4

NOTE 3: DSM Service Charges are billed and collected by FPL and forwarded to FPL Services or its designee.

NOTE 4: The amounts reported on the two above lines include $37,675 paid in 1996 and $10,000 paid in 1995.
The $10,000 paid in 1995 was incorrectly reported as a "P" (purchase) in the 1995 annual Diversification Report.

Page 457C

Schedule 4- PSC/AFA/16 (12/9C

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Assets or Rights Purchased from or Sold to Affiliates
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

Provide a summary of affiliated transactions involving asset transfers or the right to use assets.

,......

Description
Name of
of Asset
Affiliate
or Right
PurQhases!T[ansfers frQm Affiliates:
· KPB Financial
Accounts
Corp. (KPB)
Receivable

Accumulated
Depreciation

Net Book
Value

Fair Market
Value

Purchase
Price

$350,000,000

$0

$350' 000' 000

-

$350,020,000
(A)

YES

$1 ,185,399

$0

$1 ,185,399

-

$1 ,185,399

YES

Land Resources Delray Beach
Investment Co. District Office Site

$646 ,218

$0

$646,218

-

$646,218

YES

Land Resources Indiantown
Investment Co. Warehouse

$486,949

$192,053

$294,896

-

$294,896

YES

Land Resources Hollywood Service
Investment Co. Center

$170,336

$2,286

$168,050

-

$168,050

YES

land Resources Desoto Plant Site
Investment Co.

$147,788

$0

$147,788

-

$147,788

YES

Land Resources North Dade
Investment Co. District Office
Land
(LRIC)

,.....

Title

Cost/Orig .
Cost

Total
(A) Includes $20,000 administrative fee paid to KPB.

Yes/No

$352 ,462 ,351

I

Sales!Traosfers tQ Affiliates:
KPB Financial
Accounts
Receivable
Corp.

Passed

$375,000,000

$0

$375,000,000

-

Sales PriQe
$375,000,000

YES

Land Resources Improvements to
Investment Co.
General Office

$528,956

$5 ,547

$523,409

-

$523,409

YES

Land Resources Improvements to
Investment Co. System Control
Center

$53,828

$5,387

$48,441

-

$48,441

YES

$375,571 ,850

Total
Page 458

Schedule 5- PSC/AFA/16 (12/94)

 ANALYSIS OF DIVERSIFICATION ACTIVITY
Employee Transfers
FLORIDA POWER & LIGHT COMPANY
For the Year Ended December 31, 1996

List employees earning more than $30,000 annually transferred to/from the utility to/from an affiliate company .

Line
No.
1
2
3
4

New

Company
Transferred
From

Company
Transferred
To

Old
Job
Assignment

Job
Assignment

FPL

ESI

Human Resources
Field Operations
Coordinator

Human Resources
Field Operations
Coordinator

Transfer Permanent
or Temporary
and Duration
Permanent

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
~~

~-

Schedule 6- PSC/AFA/16 (12/94)
459