NEVADA POWER COMPANY d/b/a NV Energy BEFORE THE PUBLIC UTILITIES COMMISSION OF NEVADA IN THE MATTER of the Application of NEVADA POWER COMPANY, filed pursuant to NRS 704.110(3), for authority to change its annual revenue requirement for general rates charged to all classes of customers to recover costs related to the One Nevada transmission line, and investments in other generating, transmission and distribution plant, facilities and systems the company uses to provide safe and reliable electric service to customers at predictable and reasonable rates, to reflect changes in the cost of capital, the cost of service; and for relief properly related thereto. __________________________________________ ) ) ) ) ) ) ) ) ) ) ) ) Docket No. 14-05_____ VOLUME 20 of 24 Responses to Selected Master Data Requests Master Data Request 94 Attachment 01 through 02, 95 through 96, 99 through 102, 104 through 107 Recorded Test Year ended December 31, 2013 Index Page 2 of 273 Nevada Power Company d/b/a NV Energy Responses to Selected Master Data Requests Volume 20 of 24 Index Page 1 of 1 MDR No. 94 95 96 99 100 101 102 104 105 106 107 Description Dues, Industry Associations MDR 94 Attachment 01 MDR 94 Attachment 02 Contributions Operational Performance Metrics MDR 96 Attachment 01 Vintage Year Costs Transmission System MDR 99 Attachment 01 Vintage Year Costs Distribution System MDR 100 Attachment 01 Vintage Year Costs Services MDR 101 Attachment 01 Vintage Year Costs Transformers MDR 102 Attachment 01 Revenue MDR 104 Attachment 01 Interdepartmental Expense Allocations Work Orders Greater Than $100,000 MDR 106 Attachment 01 Line Extension Agreements Greater Than $100,000 MDR 107 Attachment 01 Page No. 04 146 173 174 175 183 184 202 203 211 212 216 217 250 251 254 255 256 269 270 Page 3 of 273 14-05XXX; MDR 094 Attach 01 . . Nevada Power Company MDR 94 Section C Edison Electric Institute (EEl) . . Page 4 of 273 14-05XXX; MDR 094 Attach 01 . . Edison Electric Institute RESULTS IN REVIEW Power by Association' Our 2012 accomplishments demonstrate Power by Association and reflect the value that EEl brings to our members. Through the multi-faceted Defend My Dividend campaign, secured permanent parity between the tax rates for dividends and capital gains, and prevented a nearly 190-percent increase in the top dividend tax rate. Achieved Dodd-Frank rules at CFTC that preserved and strengthened the end-user exemption, ensuring that EEl members are not miscast as swap dealers and that most utility transactions are not regulated as swaps. Coordinated the industry's response to Superstorm Sandy and worked with affected companies on supplemental appropriations to ensure they remain eligible for emergency CDBG funding. Legislation is pending. Organized a classified cyber security briefing for CEOs, and initiated executive-level coordination with DOE and DHS to clarify respective private sector and government responsibilities in addressing high-impact infrastructure risks and threats. t Advocated in support of the industry's cyber security legislative priorities with House and Senate leadership, resulting in House passage of information sharing legislation. Developed a Threat Scenario Project to identify the top security threats to the industry and provide guidance on mitigation measures. Coordinated member company review and improvements to the latest NERC Critical Infrastructure Protection Standards. Continued to advocate that EPA's final§ 316(b) rule be both environmentally protective and cost-effective, and that the national "willingness-to-pay" survey results not be used as a cost-benefit justification for the rule or in individual permit proceedings. Advocated that coal ash be regulated as non-hazardous waste, building bipartisan congressional support for legislation that likely will be reintroduced in the 113th Congress. Successfully advocated for improved final particulate matter NAAQS that do not address visibility and include better monitoring requirements. Through a CEO work group, engaged with EPA toward improved regional haze decision-making in some states. , Supported the industry on other key environmental issues, including utility MACT implementation; GHG NSPS; Clean Water Act jurisdiction; effluent guidelines; water quality standards; and siting and natural resources issues. Secured a favorable pension funding stabilization provision in legislation enacted in July. Successfully advocated that EPA's final GHG vehicle standards incentivize EVs and recogni ze the immediate GHG reductions associated with using EVs. Secured a two-year extension of the expired 30C tax credit supporting alternative fuel vehicle fueling infrastructure. J Obtained favorable "robocall" guidance from the FCC. Continued to lead industry advocacy efforts in support of full LIHEAP funding. Secured a FERC policy statement that continues the favorable incentives policy for qualifying transmission projects, including ROE adders. t Through the Distribution 2020 initiative, built support for increased distribution system investments and changed the debate among policymakers and customers on policies related to net metering, interconnection charges, standby rates, and utility participation in distributed energy resource markets. Launched a major smart grid communications campaign to refocus customer attitudes on AMI. Continued outreach to state-level policymakers and consumers through the Critical Consumer Issues Forum and other forums. Sponsored Powering the People 2.0, in partnership with lEE, to showcase the value of electricity, innovation in the power sector, and utility and technology company partnerships. Highlighted the industry's workforce development initiatives underway through CEWD and Troops to Energy Jobs. Please see reverse for 2013 outlook. . . Page 5 of 273 14-05XXX; MDR 094 Attach 01 . . 1 U LOOK 2013 promises to bring significant regulatory and policy challenges-and opportunities-for our industry. Fundamental corporate tax reform, including the treatment of normalization, excess deferred taxes, deductibility of debt interest, and corporate and dividend tax rates II Reauthorization of the Toxic Substances Control Act-PCB provisions, risk standards, prioritization of review of additional chemicals Final polar bear Endangered Species Act§ 4(d) rule addressing GHG issues-due in February Continued CFTC Dodd-Frank implementation issues Cyber security-imminent Executive Order, reintroduction of cyber legislation, and ongoing public-private coordination FERC approval of version 5 of the Critical Infrastructure Protection Standards t Storm response and restoration-clarify and strengthen FERC electric-natural gas coordination issues public-private partnership, promote lessons learned, and work to reduce legal and regulatory barriers that may delay restoration Proposed FERC reliability standards to address geomag­ netic disturbances ) Possible consideration of federal portfolio standards on clean energy, renewable energy, or energy efficiency Additional energy efficiency legislation on building codes and appliance standards FERC implementation of transmission planning, renewable energy integration, and demand response rules I Possible sequestration of all discretionary funding, includ­ ing LIHEAP Federal and state barriers to transmission siting Overhaul of the NERC standards development process Final§ 316(b) rule governing cooling water intake struc­ tures-due by June .~ ~ Regulatory pushback on authorized returns and CAPEX programs Likely reintroduction of legislation to regulate coal ash as non-hazardous waste Increased distribution system investments Continued EPA regulatory effort on coal combustion resid­ uals, coordinated with effluent limitation guidelines (ELGs) Emerging disruptive new distributed generation and micro­ grid technologies Enhanced need to assure that distribution rates allocate costs among customer groups fairly, assure cost recovery, and maintain reasonable rate levels • Steam electric ELGs-proposed rule expected in April Final EPA rule on GHG NSPS for new fossil-fueled power plants-expected early 2013 Continued Wall Street/Regulator dialogues and state-level policymaker outreach Proposed EPA rule on GHG NSPS for existing fossil-fueled power plants-expected fall2013 Acceleration of the International Reporting Standards pro­ cess and shareholder access issues Utility MACT implementation-ongoing Proposed tighter ozone NAAQS-expected late 2013 ~ FERC implementation of transmission investment incen­ tives EPA implementation of the 2008 ozone, 2010 1-hour nitro­ gen dioxide, 2010 1-hour sulfur dioxide, and 2012 particu­ late matter NAAQS Continued Court review of the Cross-State Air Pollution Rule or EPA efforts to craft a replacement State-specific regional haze programs Proposed EPA rule and possible legislative action to expand Clean Water Act jurisdiction Continued EPA efforts to expand the Total Maximum Daily Load authority to additional water bodies, leading to stricter water discharge permits ~ Revision of the industry-specific OSHA standard on opera­ tions and maintenance-due early 2013 Ongoing collaboration with DoD on energy security and bypass issues Promote 2013 as the Year of Electrification through: a customer-oriented "The Electric Generation" campaign to engage PEV enthusiasts; major outreach with C&l custom­ ers; and support of member company efforts to expand their electrification of large customers (data centers, ports, airports, manufacturing and mining, etc.) Powering the People 3.0 conference in Washington in March January 2013 . . Page 6 of 273 14-05XXX; MDR 094 Attach 01 . . =poWERED 2013 ASSOCIATION Review Highlights to Date • Through its Defend My Dividend campaign, EEl and the industry began 2013 with a major victory-passage of leg­ islation to keep dividend tax rates low and permanently linked to the tax rates for capital gains. • Leading the industry's efforts on cybersecurity, EEl: - Worked to ensure that the industry's policy positions were reflected in President Obama's Executive Order on cyber issued in February. The Order improves infor­ mation sharing and access to classified information, and focuses government authority on responding to specific, imminent threats. - - - - Helped to formalize the industry-government partner­ ship on cyber through the creation of the Electricity Subsector Coordinating Council, which is now working with multiple federal agencies. Conducted national public opinion research and poli­ ing to guide messaging and collateral development. - Published A Policy Framework for Designing Distrib­ uted Generation Tariffs to advocate for appropriate pricing of DG resources. - Commissioned third-party studies and assembled experts to engage in state proceedings/forums. - Worked to educate member companies and key con­ stituents through Webinars, meetings, and forums. - Released, through lEE, an issue brief: The Value of the Grid to DG Customers. - Coordinated member company CEO panel discus­ sions before NARUC and other forums focused on industry initiatives to safeguard against cyber attacks. Convened three regional summits and participated in the Critical Consumer Issues Forum consisting of state commissioners, consumer advocates, and EEl mem­ ber companies. CCIF adopted 21 consensus princi­ ples on distributed energy resources. - Created a members-only Internet workroom and online toolkit of research and advocacy resources. Is supporting government-industry exercises to prepare for disruptions related to national security. Created an internal EEl crisis management plan. • Through ongoing outreach to key stakeholders and allies, EEl continues to advocate that EPA's final §316(b) rule should maintain maximum compliance flexibility. Efforts to date have resulted in positive changes on many issues. • In coordination with USWAG and a broad coalition of allies, EEl is calling for coal ash to be regulated as non­ hazardous waste. Bipartisan legislation passed the House in July; Senate action is pending. . - Continued to advocate for comprehensive federal legislation that preserves the existing regulatory structure and facilitates information sharing between the government and private sector. The House passed the Cyber Intelligence Sharing and Protection Act in April. The Senate Commerce Committee approved the Cybersecurity Act of 2013 in July. Hosted the second Threat Scenario Project Work­ shop; nearly 40 member companies were represented. - • EEl continues to advocate for equitable distributed gen­ eration (DG) and net metering policies that end cost shifting and ensure all electricity customers pay their fair share toward the cost of the grid. Among our efforts, EEl: - Launched a multi-faceted industry-wide campaign calling for net metering updates in the states. Worked to secure favorable resolutions or statements from several national and state policy organizations. • EEl continues its focus on ensuring that the legislative intent of the Dodd-Frank financial reform law is pre­ served to avoid burdening end users. In House testimony, EEl advocated legislative action on the de minimis level to ensure that the $8 billion threshold remains in place. • EEl is educating lawmakers about industry priorities for comprehensive tax reform, including normalization, the treatment of excess deferred taxes, corporate and divi­ dend tax rates, and the deductibility of interest on corpo­ ~e~~. ~ . Page 7 of 273 14-05XXX; MDR 094 Attach 01 . . • Working with member companies, EEl is promoting trans­ portation electrification in on-road, non-road, and fleet applications, including utility fleets. The customer-oriented "The Electric Generation" campaign engages EV enthu­ siasts, and ties into major outreach underway with com­ mercial and industrial customers to expand electrification. • Through a new white paper and outreach to FERC, NARUC, and the media, EEl is seeking compensatory returns on equity (ROEs) that reflect the risks of devel­ opment and the long asset life of transmission facilities. • Partnering with lEE, EEl showcased the value of electric­ ity, utility and technology company partnerships, electric transportation, and the electric revolution that is shaping the 21st century during the March Powering the Peo­ ple: Innovations for a Better World conference. • Working with the Center for Energy Workforce Develop­ ment, EEl unveiled the Troops to Energy Jobs National Template to be used for military outreach, education, recruiting, and retention. EEl joined PG&E and Third Way, a centnst think tank, in highlighting the need for Infrastruc­ ture investment during a policy forum sponsored by The AtlantiC 1n Sep­ tember in Washington . PG&E Corporation Chairman, CEO and President Tony Earley delivered opening remarks. stressing how essential a robust, modem electric grid is to integrating technologies and how Important it is for the industry to invest now for the future. Other Important Developments Environmental Activities • EEl continues to advocate that EPA's GHG NSPS for new and existing power plants provide a range of compli­ ance options that are cost-effective and technologically available for all fuels. Consistent with EEl's comments, EPA's re-proposed new plant rule recognizes the need for achievable standards for all natural gas-based units over a range of real-world operating conditions. • Working closely with member companies and UWAG, EEl led the development of industry comments on EPA's proposed effluent limitations guidelines rule, advocat­ ing for flexibility and the use of cost-effective and feasible technologies . . EEl's leadership team participates in a media briefing with reporters attending the EEl convention in June. (L to R) EEl Chairman Michael Yackira and EEl Vice Chairmen Ted Craver, Nick Akins, and Tom Fanning. • Through its leadership in the Waters Advocacy Coalition, EEl continues to educate Congress and key Administra­ tion officials about proposals to expand Clean Water Act jurisdiction; EEl also is undertaking technical and eco­ nomic analyses in anticipation of a formal rulemaking. • EEl worked to achieve House passage of bipartisan legis­ lation to protect electricity generators from environmental fines or lawsuits during emergency grid operations. Action is pending in the Senate. • EEl continues to work with Senate and House staff on reauthorization of the Toxic Substances Control Act to ensure any reform legislation addresses PCBs and other industry issues. • EEl-supported language directing EPA to update two key too!s used in regional haze decisions is included in an appropriations bill approved by a House subcommittee. • EEl continues to work on compliance timeline issues for the final MATS rule and also is closely monitoring litiga­ tion associated with the rule. • EEl continues to advocate for reasonable ozone stan­ dards and for a resolution to BART concerns raised by the vacatur of the Cross-State Air Pollution Rule. • Through APLIC, EEl continues to work with member com­ panies and federal agencies on avian protection issues. • EEl continues to work with the Administration's Rapid Response Team for Transmission to develop a stream­ lined pre-application process for transmission siting and permitting on federal lands. The final ESA section 4(d) rule for the polar bear issued in February re-adopts, without change, the 2008 rule that EEl supported. . Page 8 of 273 14-05XXX; MDR 094 Attach 01 . . Storm Response and Mutual Assistance Among the lessons learned from Superstorm Sandy was the need to enhance the industry's mutual assistance program and to scale it to a national level during sig­ nificant outage events that require restoration resources from multiple reg1ons. These efforts led to consolida­ tion of some regional mutual assistance groups and widespread discuss1on of best practices. EEl's Board approved the new industry-Wide "national response event" (NRE) framework 1n September. Nearly 60 rep­ resentatives from 36 member companies participated in the NRE development effort. EEl IS preparing to mark the one-year anmversary of President Obama meets w1th EEl Pres1dentTom Kuhn and memberSandy in late October by touting the Industry's efforts to company CEOs at the Department of Energy Qn May 8, 2013. enhance the mutLJal assistance network; to fortify sy~(Photo courtesy. Whlf9 House) terns to mitigate damage: and to cont1nue to strengthen our Industry-government partnership to help identify and elim1nate any bureaucratic roadblocks that may delay future power-restoration efforts and to identify steps that w111 expedite them Smart Grid/Energy Efficiency Developments • EEl continues to deploy its smart grid third-party experts to assist member companies in addressing data privacy, radio frequency, and opt-out issues. B EEl worked with DOE to structure a public collaborative to identify requirements for a voluntary code of conduct to protect customer data privacy. • DOE's final energy efficiency standards for distribu­ tion transformers will ensure that EEl member compa­ nies have the ability to choose from multiple vendors and technologies, which EEl supported. • EEl advocated for new DOE appliance standards that do not create market distortions or lead to fuel switching. Outreach to Major Government Customers • EEl worked closely with its member companies to advo­ cate that Utility Energy Service Contracts be on equal footing with Energy Savings Performance Contracts and remain a viable tool to help the federal government meet its energy goals in a cost-effective manner. • EEl continued to collaborate with DOD on energy security and bypass issues to ensure that microgrids planned for military installations are compatible with local utility interconnection requirements and systems and to create opportunities for utility investments on military bases. . Financial Initiatives • EE!'s ongoing Wall Street regulatory dialogues edu­ cated regulators and consumer advocates on DG and net metering issues, as well as the importance of full rate recovery and reasonable ROEs to support the capital expenditures involved in the build-out of utility infrastruc­ ture and environmental compliance. • EEl is conducting a study to determine the distribution capital expenditure needs of the industry for the next 25 years. • EEl briefed more than 150 analysts on the industry's top priorities during our annual Wall Street visit in February. Federal Regulatory Actions • Related to Dodd-Frank, the CFTC issued no-action let­ ters and final rules on several issues that will reduce the time, burden, and expenses associated with implementa­ tion. EEl also achieved a victory at the Federal Reserve in a final rule preserving the ability of member companies with market-facing affiliates to use the end-user excep­ tion. • An EEl-led coalition defeated a petition to the STB that would have limited coal shippers' ability to challenge rates. • EEl continued its work to ensure that the SEC will pre­ serve a standard on rate-regulated accounting in the event that International Financial Reporting Standards are required. ~ . Page 9 of 273 14-05XXX; MDR 094 Attach 01 . . • EEl joined other groups in asking DOT to temporar­ ily exempt utility relocations required by federal trans­ portation projects from expanded Buy America rules; the Federal Highway Administration granted a transition period through 2013. • EEl continues to help member companies analyze and prepare to compiy with the SEC's conflict minerals rule. Natural Gas Policy • EEl successfully advocated last year that electric-nat­ ural gas issues are regional in nature and continues to work with member companies to ensure that issues are addressed regionally and to find areas of consensus to present to FERC. • EEl filed comments at FERC in response to a proposed rulemaking on communication of operational information between natural gas pipelines and electric transmission operators. Stakeholder & Member Company Outreach • EEl hosted more than 750 member company CEOs, Members of Congress, governors, regulators, and other elected officials and stakeholders for the 57th Presiden­ tial Inauguration in January. • EEl hosted the International Electricity Summit in San Diego in April, bringing together industry executives from electricity associations around the world. • EEl's political action committee, PowerPAC, helps to educate federal policymakers about our industry's posi­ tions on critical issues and has raised nearly $400,000 to date for Members of Congress for the 2014 election cycle. • EEl educated NARUC on key industry issues; this out­ reach culminated in several positive resolutions. • EEl sponsored dialogues to bring together FERC com­ missioners, state regulators, consumers, Wall Street ana­ lysts, and industry leaders to discuss key issues facing the industry. • EEl's advanced rate course and rate analyst training helped member companies deal with the growing number of rate cases. • EEl assembled labor and industry leaders at the Sixth Annual National LAMPAC meeting in March. • EEl brought together more than 400 utility professionals and suppliers to celebrate the 30th anniversary of EEl's Supplier Diversity program. • EEl attracted top industry leaders to the EEl Annual Convention/Expo in San Francisco in June. EEl's National Key Accounts program hosted two workshops and facilitated numerous customer-specific dialogues, bringing together member companies and key customers to engage on industry issues. EEl President Tom Kuhn leads a discussion with former Secretary of State Condoleezza Rice during EEl's Annual Convention in June. • EEl hosted an October External Affairs Conference for member company federal, state, and local government affairs representatives to discuss advocacy tools and strategies to involve employees, shareholders, retirees, and other stakeholders in advocacy efforts. October 2013 Edison Electric Institute '/111 PP.nnsjl":ania A':e., N.W. I Washington, D.C. 20!104-2696 I2!1Z.bllR.b!IOO ! www.r.ei.org Powar ty Associatioll"' . . Page 10 of 273 14-05XXX; MDR 094 Attach 01 . . :m 2013 RESULTS 1nREVIEW • Launched a multi-faceted education and advocacy cam­ paign calling for equitable distributed generation (DG) and net metering policies that are transparent, end cost shifting, recognize the value of the grid, and ensure all electricity customers pay their fair share for the grid. • In support of APS, achieved a fixed charge for rooftop solar customers in Arizona to support the grid. • Secured passage of legislation to keep dividend tax rates low and permanently linked to the tax rates for capital gains through the Defend My Dividend campaign. Educated lawmakers about industry priorities for compre­ hensive tax reform, including normalization, the treatment of excess deferred taxes, corporate and dividend tax rates, and the deductibility of interest on corporate debt. • Continued to focus on ensuring that the legislative intent of the Dodd-Frank financial reform law is preserved to avoid burdening end users. Advocated legislative action on the de minimis level to ensure that the $8 billion thresh­ old remains in place. • Advocated for compensatory returns on equity (ROEs) that reflect the risks of development and the long asset life of transmission and distribution facilities. • Helped to formalize the industry-government partnership on cybersecurity through the creation of the Electricity Subsector Coordinating Council (ESCC) and ensured that the industry's cyber positions were reflected in Presi­ dent Obama's Executive Order. II Participated in NERC's Grid Ex II cyber exercise and sup­ ported government-industry national security exercises. • Advocated for comprehensive federal cybersecurity legislation that preserves the existing regulatory structure and facilitates industry-government information sharing. • Worked closely with several government agencies to raise awareness of physical security threats to grid assets. • Facilitated the creation of a new industry-wide "national response event" framework for storm response and restoration. • Continued outreach and advocacy efforts calling for EPA's final §316(b) rule to maintain maximum compliance flexibility. • Worked with a broad coalition of allies to advocate that coal ash be regulated as non-hazardous waste. Biparti­ san legislation passed the House; action is pending in the Senate. . • Continued to advocate that EPA's GHG performance standards for new and existing power plants provide a range of compliance options that are cost -effective and technologically available for all fuels. • Participated in international climate change negotia­ tions in Poland. • Led the development of industry comments on EPA's proposed effluent limitations guidelines (ELGs) rule that advocate for flexibility and the use of cost-effective and feasible technologies. • Led industry efforts on other key environmental issues, including Clean Water Act jurisdiction, water quality standards, MATS compliance, regional haze, ozone, and siting and natural resources issues. Continued to lead industry advocacy efforts in support of full LIHEAP funding. Ill Achieved changes in DOE's final energy efficiency standards for distribution transformers, ensuring that member companies have the ability to choose from multiple vendors and technologies. • Expanded outreach to state policymakers, regula­ tors, and other stakeholders through NARUC, the Critical Consumer Issues Forum, and other forums, and secured several positive policy resolutions on key issues. • Showcased the value of electricity and utility and tech­ nology company partnerships during the March Power­ ing the People: Innovations for a Better World conference. • Promoted transportation electrification in on-road, non-road, and fleet applications, including utility fleets. • Highlighted the industry's workforce development initiatives and developed the Troops to Energy Jobs National Template. • Hosted the International Electricity Summit, bringing together industry executives from around the world. • Raised more than $41 0,000 through EEl's political action committee, PowerPAC, to educate federal policymakers about our industry's positions on critical issues. 2014 Outlook 1111- . Page 11 of 273 14-05XXX; MDR 094 Attach 01 . . 20140UTLOOK • Enhanced collaboration and outreach with member com­ panies and allies to promote common-sense net metering policies that recognize the value of the grid and avoid cost shifting • Expanded efforts to promote a full understanding of the grid upgrade costs and power quality challenges that local generation sources and microgrids impose • Continued advocacy and education for improved rate design and cost recovery and the elimination of externali­ ties in rates • Ongoing industry-government cyber and physical security coordination through the ESCC and the deployment of detection technologies and improved information sharing and recovery capabilities Federal cybersecurity legislation-EEl's goal is to preserve the existing regulatory structure and facilitate industry­ government coordination • Storm response and restoration-continue to clarify and strengthen the industry-government partnership and work to reduce legal and regulatory barriers that may delay restoration efforts • Expanded participation in the Spare Transformer Equip­ ment Program (STEP) • Fundamental corporate tax reform, including the treat­ ment of normalization, excess deferred taxes, deductibility of debt interest, depreciation, and corporate and dividend tax rates • Reauthorization of the Commodities Exchange Act (includes Dodd-Frank issues) • Continued implementation of Dodd-Frank, including the position limits and aggregation rules • Nomination and confirmation of FERC and CFTC commissioners • Proposed EPA rule on GHG performance standards for existing fossil-fueled power plants-expected June 2014 Final §316(b) rule governing cooling water intake struc­ tures-due January • Continued EPA regulatory effort on coal combustion residuals, coordinated with ELGs, and Senate consider­ ation of House-passed legislation to regulate coal ash as non-hazardous waste • Proposed EPA rule and possible legislative action to expand Clean Water Act jurisdiction • Utility MATS implementation-ongoing • D.C. Circuit decision on MATS-expected by summer 2014 • Supreme Court decision on the Cross-State Air Pollution Rule (CSAPR)-expected by June 2014-and EPA pro­ posed replacement rule on CSAPR (expected mid-2014) Clarification of BART concerns raised by the vacatur of CSAPR • Proposed tighter ozone NAAQS- expected by fall 2014 • EPA implementation of the 2008 ozone, 2010 1-hour nitrogen dioxide, 201 0 1-hour sulfur dioxide, and 201 3 particulate matter NAAQS • Continued EPA efforts to expand the Total Maximum Daily Load authority • Reauthorization of the Toxic Substances Control Act­ PCB provisions, risk standards, prioritization of review of additional chemicals • FERC proceedings to impact wholesale power markets • FERC action to address pending complaints on ROEs for transmission investment • FERC proposed rules impacting electric-natural gas coordination • SEC proposed rules impacting proxy access and disclosures • Continued movement toward International Financial Reporting Standards Possible consideration of the Shaheen-Portman energy efficiency bill • Congressional and Executive Branch promotion of perfor­ mance contracting • Re-proposed EPA rule on GHG performance standards for new fossil-fueled power plants-comments due in February/March • Continued support for state and federal programs and incentives that advance transportation electrification • Implementation of the Administration's Climate Action Plan through other federal administrative and regulatory powers, such as the use of the societal cost of carbon and power purchase requirements • Reauthorization of federal transportation programsan opportunity to enact pro-shipper reforms at the Surface Transportation Board and to promote alternative fuel vehicles Edison Electric Institute Power by Associatioa . • Final steam ELGs-due May January 2014 . Page 12 of 273 14-05XXX; MDR 094 Attach 01 . . Edison Electric Institute Regular Activities 2013 Statement of Operations (Unaudited) YTD as of Au~st 15, 2013 Better (Worse) Budget Actual Variance 2013 Budget Revenues: Investor-owned electric utilities dues Programs, publications and meetings Investment income International affiliates dues Associate members dues Strategic partners Total dues and revenues $ Expenses: Salaries Employee benefits Programs, publications and meetings General office and administrative Total expenses Net Operating Income . 51,282,000 8,568,000 3,100,000 1,200,000 1,176,000 500,000 65,826,000 $ 25,254,000 14,534,000 17,256,000 8,782,000 65,826,000 $ 51,282,000 4,798,000 1,912,000 1,200,000 737,000 500,000 60,429,000 $ 15,826,000 9,108,000 10,938,000 5,503,000 41,375,000 $ 19,054,000 $ 51,086,000 5,126,000 1,800,000 1,035,000 752,000 500,000 60,299,000 (130,000) 15,420,000 8,672,000 10,828,000 5,441,000 40,361,000 1,014,000 19,938,000 $ 884,000 . Page 13 of 273 14-05XXX; MDR 094 Attach 01 . . Edison Electric Institute Separately Funded Activities 2013 Statement of Expenses (Unaudited) 2013 Budget Fund Description Industry Issues (2) $ $ 3,187,000 $ 3,171,000 1,525,000 953,000 836,000 Environmental 420,000 262,000 174,000 Restore Power 475,000 297,000 422,000 Avian Power Line 230,000 144,000 123,000 Spare Transformer 288,000 180,000 206,000 Water Advocacy Coalition 122,000 76,000 67,000 Employment Testing Total SFA Expense, net of U-Groups . 5,100,000 YfD as of August 15, 2013 Actual Budget (1) $ 8,160,000 $ 5,099,000 $ 4,999,000 Funds not controlled by EEl Utility Air Regulatory Group 8,343,000 5,214,000 4,940,000 Utility Solid Waste Activities Group 3,622,500 2,264,000 2,186,000 (1) All SFA budgets are estimates and are subject to available funds contributed on a voluntary basis. (2) The EEl Board approved a 10% voluntary assessment, based on dues, for the Industry Issues SF A. . Page 14 of 273 14-05XXX; MDR 094 Attach 01 . . 14-0SXXX MDR94 Attachment 01 Nevada Power Company MDR 94 Section C Utilities Telecom Council (UTC) . . Page 15 of 273 14-05XXX; MDR 094 Attach 01 . . UTCO UTILITIES TELECOf\1 COUNCIL UTC Core Membership Enrollment Form 2012-2013 ANNUAL Name of Primary Contact (will receive all correspondence and invoices) KEVt~JU ~ Revenue < $15 $15 s Revenue s $25M $25M s Revenue s $50M $50M < Revenue s $100M $100M < Revenue S $250M $250M < Revenue s $500M $500M < Revenue s $750M Title Company Mailing Address Alternate Address City Zip/Post Code State/Province $750M < Revenue :S $1.258 $1.258 < Revenue s $58 $58< Revenue s $108 Revenue > $108 MEMBERSHIP DUES $500 $750 $1,500 $2,500 $3,750 $5,000 $7,500 $10,000 $15,000 $20,000 $30,000 Country Fax Phone Web-site Address E-mail Address Which of the following best describes your company's primary business? (Check all that apply) Services: [J [J [J [J [J [J [J Distribution Educational Electric Financial Gas Generation Petroleum [J [J [J [J [J [J Pipeline Public Safety Transportation Transmission Telecom Svc. Provider Water I Wastewater Ownership: [J [J [J [J Cooperative Investor Federal Government Municipality [J [J [J [J Privately Held Publicly Held Local Government State Government Business Development Engineering Executive Management [J [J [J Finance Gov't Relations Telecom /IT Indicate your areas of interest: (Check all that apply) [J [J [J [J [J [J [J [J [J [J AMR Building Access Business Dev. Frequency Coord. Federal Govt. Rei. Fiber Optics International IT Public Policy MAS Amount Due: U.S.$._ _ _ _ __ D D D Check or money order enclosed (Made payable to Utilities Telecom Council) Bank/wire transfer of funds: Please contact UTC's Accountant at 202.872.0030 Please charge my credit card (check one): [J Visa [J Mastercard [J American Express Which of these best describe your primary job function? [J [J [J What is your holding company's current total gross revenue? U.S.$~----- [JPower Line Carriers [JPower Line Communications [JRural Users [JSCADA [JSecurity [JSmart Grid [JState/Local Govt. Rei. [JSpectrum Services [JTelecom [JWireless Communications Other areas of interest include:, _____________ Cardholder's Name Card Number Billing Address Code Expiration Date City/State Zip/Postal Cardholder's Signature To Join Now MAIL: Payment with enrollment fonn to: UTC Membership P.O. Box 79358 Baltimore, MD 21279-0358 USA FAX: Enrollment fonn (if not paying by check) to: +1.202.872.1331, ATIN: UTC Membership ONLINE: www.utc.org See page 2 for additional information and to add additional company contacts. Page 1 of2 . . Page 16 of 273 14-05XXX; MDR 094 Attach 01 . . Additional Contacts (will receive all regular membership correspondence): Title Name Company Mailing address State/Province City Phone Zip/Postal Code Fax E-mail address Title Name Company Mailing address City Zip/Postal Code State/Province Fax Phone E-mail address Member Categories: Core Members - use this enrollment form Utility, pipeline, energy, and other critical infrastructure companies that operate mission-critical telecommunications and data networks in support of their non-telecom/data core business. Associate Members Any company that does not qualify as a regular member (e.g. telecom and technology equipment manufacturers, service providers, law firms, consultants) may join UTC as non-voting Associate Members. Dues are based on the company's annual sales revenue to the utility industry (in US Dollars). Additional Information: • • • • UTC Membership Year: 101112012 -913012013 UTC's Federal Tax ID: 52-6042453 UTC estimates that 5% of dues revenue will be allocated to nondeductible lobbying activities during the ensuing fiscal year. Questions? Contact Kamel Thomas, VP, Member and Industry Services at 202.833.6816 or karnel.thomas@utc.org. Page 2 of2 . . Page 17 of 273 14-05XXX; MDR 094 Attach 01 . . Return of Organization Exempt From Income Tax DepL1ment or the Tiasury Intent• R8Yat.,. Servioe Under section 501 (c), 527, or 4947(a)(1) of the Internal Revenue Code (except black lung benefit trust or private foundation) .... The organization may have to use a copy of this return to satisfy state reporting requirements. A For thd011 calendllr yeer•or tax veer beginning C Name of organization 8 Chec:k If OCT 1 2 0 11 • OMB No. 154!>-11047 2011 ,, and enclng SEP 3 0 2 0 12 D Employer identification number .. •PPHc:abi•: DAdd"""' ct!ango UTILITIES TELECOM COUNCIL 52-6042453 change Dolna Business t.;s oln:lllll Number and street (or P.O. box if man is not delivered to street address) l'tlum ~oom/suite E Telephone number o=r~~~l202) 833-6817 1129 20TH STREET, NW 50 7,009,168 • G GRID reoelpts$ . City or town, state oroountry, and ZIP+ 4 return Dm'l;c. WASHINGTON. DC 20036 H(a) Ia thi& a group return pending F Name and address of principal officer:CONNIE OURCSAI< for affiliates? Dves 00No 1129 20TH STREET, NW, SUITE 350, WASHINGTON, H(b) Are all affinates included? DYes No I Tax-exempt statu&: t J 501 (c)(3) LX..l 501(c)( 6 1<11111 (Insert no.l [ ] 4947falf1l or [ 527 If 'No,' attach a list. (see instructions) J Website.: .... WWW. UTC • ORG Htcl Grouo exemotlon number .... l othar .... K E.orm of ornanizatlon: f X I Corporation [ ] Trust I I Association I L Year of fonnatlon: 19 4 81 M ~t.:dP. of leoal domicile: DC I~ ~~~ Summary 1 Briefly describe the organization's mission or moat significant activities: EDUCATE AND REPRESENT MEMBER ORGANIZATIONS ON COMMUNICATIONS ISSUES • 2 Cheek this box .... If the organization discontinued Ita operations or diapoeed of more than 25'J6 of Its net asaeta. 58 3 Number of voting members of the governing body (Part VI, Une 1a) nw ooo •o••• •• •• • ••• •••••••••••••• • ••• • ••• • • • ••• • • • • ••••••• • • 3 eJ 56 4 Number of Independent voting members ot the goveming body (Part VI, line 1b) .......................... ................ 4 26 5 Total number of individuals employed In calendar year 2011 (Part V, line 2a) .................................... ............ 5 0 8 Total number of volunteers (estimate If n~sary) ................... .................................................................... 8 314,442. 7 • Total unrelated business revenue from Part VIII, oolumn (C), line 12 ........................ ······· ................ ·-···-· 7a 60,041. b Nat unrelated business taxable Income from Form 990·T line 34 .......................................................... ........ 7b oName DAm«KKad D r I• D .i • I -~- ... Prior Year o. Current Ye•r o. and grants (Part VIII, line 1h) I 89 Contributions 6.274,264. 7,006,613. Program service reven•·s (Part VIU,Iine 2g) oo ooooooooo.ooou oo• • •• •• • •• • • ••• •• ••••••••••••••••••••o.••••••• 3,195. 2,555. 10 Investment Income (Part VIII, column (A), linea 3, 4, and 7d) ····························--········· II: 0 .. 11 Other revenue (Part VIII, column (A), lines 5, 6d, Be, 9c, 10c, and 11e) ........................ 6,277,459. 7,009,168. 12 Total revenue· add fines 8 through 11 (must eQual Part VIII column tAl. line 12) ......... 232,833. 88,429. 13 Grants and similar amounts paid (Part IX, column (A), lines 1--3) ......... ........................ 0. 14 Benefits paid to or for members (Part IX, column (A), line 4) ......................................... 2,934,508. 2,615,581. 16 Salaries, otheroompensation, employee benefits (Part IX, oolumn (A), lines 5-10) ......... 18a Professional fundralsing fees (Part IX. column (A), fine 11 e).. ........................................ r ~:'wtr~ • lt -~t~&~. 't.":·· r.z~r1r-~""::~--~~ ~~ b Total fundraising expenses (Part IX, column (D), line 25) 3,420.507. 3,755,867. 17 Other e.xpenses (Part IX, oolumn (A), lines 11 a•11 d, 11 f·24e) ....................................... 6,268,921. 6,778,804. 18 Total expenses. Add linea 13·17 (rnuet equal Part IX, column (A), line 25) ..................... 230,364. 8,538. 19 Revenue less exoenses. Subtract line 18 from nne 12 ....................................... .......... ... Btolnnlna or Curran1 Ytar End of Year 4,850,564. 5,020,882. 20 Total assets (Part X, line 16) ..................................................................................... 4,474,026. 4.413.980. ~ 21 Total liabilities (Part X, line 28) 376.538. 606,902. line 20 ........ ."................................. ~ 22 Net assets or fund balances. !Q,.,......-Iine 21 • • • • • • • • • • • • • • • • • • • • • o o o o o o o o oo o oo o o o o ooooooooooooooooonooooo• I o. i S' o. o• .... ·. o. o. iJ o o o o 4 o •OO o o o • 4 0 0 • 0 0 0 0 0 o • O O o • OO • from • o o • oo • • • • 0 " ' ' ' " 0 0 0 0 0 0 0 0 0 0 0 H O O O O O O O O OOOOOOOOOOO l;l *adlli J Signature Block Under penalties of perjury,! declare that I have examined this ~&tum, Including accompanying schedules and statements, and to the best of my knowledge and belief, it Is true, correct, and complete. DeclaraUon of re rer other than office is based on all infonnation of which Sign Signature of officer Here CONNIE DURCSAK, Type or print nam& and title PRESIDENT/CEO ---------------r----------~~~~~--~~~r-~-----~~~pn=N~------- Pald 00456765 Praparer UsaOnly J--!-!!!~=:.........~~~~~====--======-~:=--=:=:=-=::::==:~;-;;-------1...:.=::..=....::::.:...:..__;;.5-=4_--=1-=4..::.9..=8..::.9-=5-=0~ 400 Phone no. Ma t 1a2001 . r shown above? see lnstructrons IRS discuss this return with the 01-23-12 LHA For Paperwork Reduction Act Notice, see the sepal'llte instructions. . Page 18 of 273 14-05XXX; MDR 094 Attach 01 . . ~1 ~=~ UTILITIES TELECOM COUNCIL 52-6042453 P e2 Statement of Program Service Accomplishments Check if Schedule 0 contains a response to any question In this Part Ill ............... ................. .... ...... ...... .................. ..................... Briefly describe the organization's mission: 1 00 EDUCATE AND REPRESENT ITS MEMBER ORGANIZATIONS ON ALL COMMUNICATIONS ISSUES WHICH COULD IMPACT MEMBER ORGANIZATIONS BUSINESS OPERATIONS. Did the organization undertake any significant program services during the year which were not lleted on 2 the prior Fonn 990 or 990-EZ? ..................... ................................................................................................... ............... Dves 00 No If 'Yes,' describe these new aeMc:es on Schedule 0: Did the organiZation cease conducting, or make slgnfficant changes in how It conducts, any program services?.................. DYes [X] No If 'Yes,' describe these changes on Schedule Describe the organization's program service accomplishments for each of Ita three largest program eervices, as measured by expenses. Section 501 (c)(3) and 501 (c)(4) organizations and section 4947(a)(1) trusts are required to report the amount of grant& and allocations to othars, the total expense&, and revenue, If any, for each program service reported. (Code: ) (Experves$ Including grants of$ ) (Ret.tenueS 3 o. 4 4a 4b 4c 4d MEMBERSHIP SERVICES - PROVIDES A FORUM IN WHICH OUR MEMBE=R-c=o~MP~AN~I~E~S~CAN BENEFIT FROM EDUCATION AND INFORMATION SERVICES FOR THEIR EMPLOYEES. . (Code: ) (exp..ea S Including WJ~nts of$ ) {RevenueS (Code: ) (Expon•• ;: Including 11111nts of$ ) (Revenue$ ANNUAL CONFERENCE - PROVIDES EDUCATIONAL AND NETWORKING o=pp=o=R=T=UN==I=T=I=E=s~ FOR EMPLOYEES OF MEMBER COMPANIES AND THEIR TECHNOLOGY PARTNERS. FREQUENCY COORDINATION - COORDINATES RADIO FREQUENCIES To-=su=p~p~O~R~T~T=H=E~ NEEDS OF THE TELECOMMUNICATIONS INDUSTRY AS A NON-PROFIT ORGANIZATION APPROVED BY THE FEDERAL COMMUNICATIONS COMMISSION. Other program services (Describe in Schedule 0:) @!pen... f 4e lndl.MIInp piB of$ ) (Revenue$ Total program service expenses .... Form 990 (2011} 132002 02-09·12 15000812 783690 0861-001 . 2 2011.05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 19 of 273 14-05XXX; MDR 094 Attach 01 . . UTILITIES TELECOM COUNCIL -· ·l Checklist of Required Schedules Fotr.1990l21t1H [ ~Ge3 52-6042453 3 Yes No Is the organization described in section 501 (c)(3) or 4947(8)(1) (other than a private foundation)? ""Yes," comp/em Schedule A .................................................... ................................................... ................................. ..... 1---!1-+--t-:X~ Is the organization required to complete Schedule B, Schedule of Contributonfl .. ..... .. ... ... .. .. ..... .... ... .. .... ..... .... .. ... .. .......... ... 1---"2'--1--+...:X=-Did the organization engage In drect or Indirect political campaign activities on behalf of or in opposition to candidates for 4 public office? If "Yes, " complete Schedukl c, Ptut J ................................................................................. ........................... !---'=3~-....f--'X=-Section 601 (c)f.') orpnl:q,tions. Did the organization engage in lobbying activities, or have a section 501 (h) election In effect ! 1 2 !----"4'---i--+-- during the tax year? If "Yes, • complete Schedule C, Part II .. .... ......... ......... ...... ............ ...... .... . .... .... ...... ......... ............ .. ......... Is the organization a section 501 (c)(4), 501 (c)(S), or 501 (c)(6) organization that receives membetship dues, assessments, or similar amounts as defined In Revenue Procedu~e 98-197 If "Yes, • complete Schedule c, Pstt IJJ .......................................... Did the organization maintain any dOnor advised funds or any similar. funds or accounts for which donors have the right to provide advice on the distribution or Investment of amounts in such funda or accounts? If "Yes, • complete Schedule D. Part I Old the Dfganization receive or hold a conservation easement, lncluc:lng easements to preserve open space, the environment, historic land areas, or historic structures? If "Yes, • complete Schedule D. Part II.......................................... Did the organization maintain collections of works of art, historical treasures. or other similar assets? If "Yes, " complete 5 8 7 8 r--:S'--1-=X=-+-r--:8~.'----t...:X=-~7~--+...:X==--- Schsdule D, Part Ill .... .. .. . ... ...... .. .. ... ... ..... ... ...... ... .. .... ...... ... ... .. ...... .. ...... ...... ... ... .. ...... .... ..... .. ..... ...... ......... .... ..... .. ... ............ 1-"'8--+--+-X..;.__ Did the organization report .-. amount in Part X, line 21: serve as a custodian for amounts not listed h Part X; or provide credit counseling, debt management, credit repair, or debt negotiation services? If "Yes, • complete ScheduleD, Part IV ...... e X 10 Did the organization, directly or through a related organization, hold assets in temporarily restricted endowments, pennanent endowments, or quasi-endoWments? If "Yes," comp~te SChedule D, Part V ...................................................................... .. 11 If the organization's answer to any of the following questions is "Yea,' then complete ScheduleD, Parts VI, VII, VIII, IX, or X as applicable. a Old the organization report an amount for land, buildings, and equipment In Part X, line 10?/f "Yes," complete Schedule D, 9 Part\11 ....................................................................... ........................................................... ....................... ...... ........... ... . b Did the organization report an amount for investments· other securities in Part X, line 12 that is 5% or more of its total assets reported In Part X, line 16? If "Yes," complete ScheduleD, Ptut VII ........................................................................... Is 596 or more of Its total assets reported in Part X, line 16'1 If "Yes," COITJ)Iete Schedule D, Part VIII . ........... .... ..... .... ....................... ...... .... ..... ........ .... Did the organization report an amount for other assets in Part X. line 15 that Is 5% or more of Hs total assets reported In Part X, line 16? If "Yes," complete ScheduleD, Ptut ~j( ..................................... .............. ......... ................................ ............. Did the organization report an amount for other liabilities In Part X. line 25? If "Yes, • complete Schedule D. Part X.................. Did the organization's separate or consolidated financial statementa for the tax year Include a footnote 1hat addresses the org~ization's liability for uncertain tax positions under FIN 48 (ASC 740)? If "Yes, • complete ScheduleD, Part X ............ Did the Dfganizatlon obtain separate, independent audited financial statements for the tax year? If "Yes, • comp/etB ScheduleD, Parts XI, XII, tllld XIII ....................................................................................................................................... Was the organization included In consolidated, independent auclted financial statements for the tax year? If 'Yes,"lllld If the organization answered "No" to Hne 12s, then completing ScheduleD, Parts XJ, XJI, and XIII is optional......... Is the organization a school described In section 170(b}(1)(AJfil)? If "Yes,' ~Jete Schedule E ............................ .............. Old the organization malntail an office, empbyees, or agents outside of the United States? ...... ..................... ..................... Old the organization have aggregate revenuee or expenses of more than $10,000 from grantmaking, fundralalng, business, Investment, and program service activities outside the United States. or aggregate foreign investments valued at $100,000 or more? II "Yes, • cotnplete Schedule F, Parts I and N ......................................................................................................... Did the organization report on Part IX, column (A), line 3, more than $5,000 of grants or assistance to any organization or entity located outside the United States? If "Yes, • complete Schedule F, Parts II and IV .......... ........................................ . Old the organization report on Part IX. column (A), line 3, more than $5.000 of aggregate grants or assistance to individuals located outside the United States? If "Yes, • complete Schedule F, Parts Ill and IV ................. .............................................. Did the organization report a total of more than $1 5,000 of expenses for professional fundraislng services on Part IX, column (A), lines 6 and 11 e? If "Yes,' complela Schedule G, Part I ........................................................................................ Did the organization report more than $15,000 total of fund raising event groea Income and contributions on Part VIII, fines 1c and 8a? If "Yes," complete Schedule G, Part II ... ............................................... ............................................................ . Did the organization report more than $15,000 of gross income from gaming activities on Part VIII, line 9a? If "Yes, • complete Schedule G, Part Ill ........................................................................................................................ .................... . 11b X 11o X o Did the organization report an amount for Investments· program related In Part X, line 13 that d e f 12a b 13 14a b 15 16 17 18 19 20• b X 11d 11e X 11f X 12a X 12b X 13 14a X 1<1b X 10 X X X 18 I l 17 l I I X I 18 ' X 18 20e 20 I X X Form 990 (2011) 1:!2003 01·23·12 3 15000812 783690 0861-001 . 2011.05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 20 of 273 14-05XXX; MDR 094 Attach 01 . . FornQ9012_Ctl·il UTILITIES TELECOM COUNCIL Il"tft:JT>1 Checklist of Required Schedules (continued) 52-6042453 Pace4 No Yes 21 Old the organization report more than $5,000 of grants and other assistance to any government or organization in the 21 United States on Part IX. column (A), Une 1 ? If 'Yes, • comp/tlte Schedule I, Parts I and II ............................. ...... .................. . Did the organization report more than $5,000 of grants and other assistance to Individuals In the United States on Part IX, column (A), line 2? If "Yes,' complete Schedule I, Parts I and Ill ......................................................................................... . ' 22 Old the organization answer 'Yes' to Part VII, Section A, line 3, 4, or 5 about compensation of the organization's current and former officers, directors, trustees, key employees, and highest compensated employees? If 'Yes, ' complete 22 23 23 ScheduleJ .................................................................................................................................................................... .. .. 241. Did the organization have a tax-exempt bond issue with an outstanding principal amount of more than $100,000 as of the last day of the year, that was issued after December 31, 2002? If "Yes,' snswer lines 24b through 24d snd COf7V)Iete Schedule K. If 'No", go to line 25 ....................................................................................................................................... 24e b Old the organization Invest any proceeds of tax-eltempt bonds beyond a temporary period exception? ................................. c Did the organization maintain an escrow account otM.r than a refunding escrow at any time during the year to defease 24b d 25a b 28 27 28 a b c 29 30 31 32 33 34 35a b 38 37 38 any tax-exempt bonds? ......................................... ;............................................................................................................ Did the organization act as an 'on behalf of' Issuer for bonds outstanding at any time during the year? ............................... .. Secrtlon 501 (o)(3) and 501 (c)(4) organizations. Old the organization engage in an excess benefit transaction with a disqualified person during the year? If 'Yes,' complete Schedule L. Psrt I .......................................................................... . Is the organization awara that It engaged In an excess benefit transaction with a dia~ualified peraon In a prior year, and that the transaction has not been reported on any of the organization's prior Forms 990 or 990·EZ? N 'Yes," complete Schedule L. Part I ............................................................................................................................................................ Was a loan to or by a current or former officer, director, trustee, key employee, highly compensated employee, or disqualified person outstanding as of the end of the organization's tax year? If "Yes, • complete Schedule L. Part II ................................ . Did the organization provide a grant or other assistance to an officer, director, trustee, key employee, substantial contributor or employee then!Of, a grant selection committee member, or to a 35% controlled entity or family member of any of these persons? If "Yes,' complete Schedule L, Part 111 ......................................................................................... . Was the 9f'ganlzation a party to a business transaction with one of the following parties (see Schedule L, Part IV instructions for applicable filing thresholds, conditions, and exceptions): A current or fonner officer, director, trustee, or key employee? If "Yes, • complete Schedule L. Perl N ................................ . A family member of a curnlflt or former officer, director. truatee, or key employee? If "Yes," complete Schedule L. Part IV ...... An entity of which a currant or former officer, director, trustee, or key employee (or a family member thereof) was an officer, director, trustee, or direct or Indirect owner? If 'Yu, • complete Schedule L. Part IV.............................. .................. ............. .. Did the organization receive more than $25,000 In non-cash contributions? If ''Yes," complete Sc/'ledJie M .......................... . Did the organization receive contributions of art, hlsforical treasures, or other similar assets, or qualified conservation contributions? If "Yes, • complete Schedule M ..................................................................................................................... Old the organization liquidate, terminate, or dissolve and cease operations? If "Yes," eotnplete Schedule N, Pert I ................................................................................................................................. Did the organization sell, excllange, dispose of, or transfer more than 2596 of its net aeaets?If "Yes," complete Schedule N, Part II ......................... .............................. ................................................................................................ .... . Did the organization own 10096 of an entity dfsreg&lded as separate from the organization under Regulations sections 301.7701·2 and 301.7701~? If "Yes, • c.omplete ScheduleR, Part I ....................................................................... . Was the organization related to any tax-exempt or taxable entity? If "Yes, • complete Schedu/P. R, Parts II. Ill, IV, snd V, line 1 ................................................................................................... Did the organtzatlon have·a controlled entity within the meaning of section 512(b)(13)? ...................................................... Did the organization receive any payment from or engage In any transaction with a controlled entity within the meaning of ' section 512(b)(13)? If "Yes,' co~lete ScheduleR, Pllrl V, Hne 2 ......................................................................................... . Section 501 (c)(3) organizations. Did the organization make any transfers to an exempt non-charitable related organization? If "Yes," complete SchedJJie R, Part V, lfne 2 ........................................................................................................................ Did the organization conduct more than 596 of its activities through an entity that is not a related organization i and that is treated as a partnem,ip for federal Income tax purposes? If "Yes, • complete SchedlJfe R, Part V1 ....................... . i Provide Did the organization complete Schedule 0 and explanations.In Schedule 0 for Pert VI, fines 11 and 19? Note. All Form 990 fliers are reauired to comolete Schedule 0 ........................................................................................... i X i X X I X 2Ac 2Ad 25a 215b X 28 27 ~~ X., .. ,. ,_._ lf";,;.,.: ·-~t ' . •. ~ -' . 28b 28c X 29 X 30 X 31 X 32 X 33 X 34 36a ~ X X 2Ba X 35b X X 36 37 , X aalxi Form 990 (2011) !32004 01·23-12 4 15000812 783690 0861-001 . 20'11. 05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 21 of 273 14-05XXX; MDR 094 Attach 01 . . 11 UTILITIES TELECOM COUNCIL 52-6042453 5 p Statements Regarding Other IRS Filings and Tax Compliance Check If Schedule 0 contains a response to any question in this Part V . ..... .. ...... .•. ... ........ .•. . ...... ... .. .... .•. ..... .... ... .. ...... ... ... .. ..... .... D !ves No b 5a b c 8a b At any time during the calendar year, did the organization have an interest in, or a signature or other authority over, a financial account In a foreign country (such es a bank aooount, securities account, or other financial account)? . .. ......... .... .... . ~4a;;,..i,....;;:X=:-+...-~ lf'Yes, 1 enterthenameoftheforeign country: .... . ::C..::AN=AD=A::=.L,--=B:;.;E=L:..;:G:..;:I:;..U;;.;M:.=. ._ ____________ :.;~.'~ · ,~ ., '! See instructions for filing requirements for Form m F 9D-22.1, Report of Foreign Bank and Financial Accounts. [J't;. . ,_ . , · ... ,:: ·-;: Was the organization a party to a prohibited tax shelter transaction at any time during the tax year? .. ...... .•.... .... ...... ... ... ... .. . 5a X Did any taxable party notify the organization that it was or is a party to a prohibited tax shelter transaction?.... ....................... 5b X If 'Yes, • to line Sa or 5b, did the organization fila Form 8886-T7 .... .............. ................... ...... ... ......... ......... ....•. ..•. ................ 6c Does the organization have annual groaa receipts that are normally greater than $100,000, and did the organization solicit X any contributions that were not tax deductible? ....................................................................... .......................................... . 88 If 'Yes, 1 did the organization include with every solicitation an expreas statement that such cootributions or g:rts were not tax deductible? ........................ .••. ....................................................................................................................... ~8brn,..,""'*"'"'!"":Orgenlzaaona that may receive deductible contribUtions under section 170(c). l.E_;~. ·'· :: · ·· : :,' :i • Oid the o~ganizatlon receive a payment In excess of $75 made partly as a contribution and partly for goOds and services provided to the payor? t-=-7•=-;--+-b If 'Yes,• did the organization notify the donor ofthe value of the goods or services provided? ........................ ..................... ~--"-'7b:::....j--+-c Did the organization sell, exchange, or otherwise dispose of tangible personal property for which It was required 7 d e f g h ~o~~~~:!~!h.·~~;;;~~-~82~·~-d~~~-~~~~;;;,···::::::::::::::::::::::::::::::::::::::::::::::::··r;d··r·······.................. -~r?·.rr .~· Did the organization receive any funds, directly or Indirectly, to pay premiums on a personal benefit contract? ...... ...... ..... .... 7e X Did the organization, during the year, pay premiums, directly or Indirectly, on a personal benefit contract? ...•....................... 7f X If the organization received a contribution of qu~ified Intellectual property, did the organization file Form 8899 aa required?... 7g X If the organization receiVed a contribution of cara, boats, airplanes, or other vehicles, did the organization file a Form 1098-c? h"-7h:.;..,t~-;;:+..::X.:...., 8 Spansorina organizatloll maintaining donor advllad ttn~s and sactlon 509(1)(3) 11ppartfng organizations. Did the supporting ?~1-:~ :::U-..::;..: organization, or a donor advised fund maintained by a sponsoring organization, have excess business holdings at any time during the yaar? a X 9 Sponsoring organizations maintaining donor adVIsed funds. .. ·.;i; ~'-·~: ~ . ·,:1.) a Did the organization make any taxable distributions under aectlon 4986? .. ................... ........ .•. ... ....... .. ........ ........ .....•...•.•.. .... Ia X X b Old the organization make a distribution to a donor, donor advisor, or related person? ....... ... ..... ........... ......... .. ... ............ ..... &b 10 Section 501(c}(7) organizations. Enter: I~C'· ~~."· t;";;~ ..... > -t:r;;t:: [;~.}' t:~ ...J ·i;,~ .< ·''' f ; 1ft~~· ~:~; ~~ lt ,. a Initiation fees and capital contributions Included on Part VIII, Une 12 .. ...... ............. ............ ............ II-1""'0a:=...tl_ _ _ _ _ _ b Gross receipts, Included on Form 990, Part VIII, line 12, for public use of club facilities .................. 10b 11 Section 501(cJ(12) organl:ratlons. Enter: , :::: :~=:= ::::::~~:~: ~~t~-d~~·;;;d·t~~h~-~~~~·~~~···........ 12a b 13 • f~~fi' PlJ..... ., ·~ 118 -::t! .. ~~ ' :<; •' amounts due or received from them.) ... ...... .... ... ......... ... ... ..... .................................. ............ ........ i...1~1:!:b~--~---r- · · .. ..~' ' · !:~ -~' Section 4947(8)(1) non-exempt charitable trusts. Is the organization filing Form 990 n lieu of Form 10411 b1~2a3-l~rl=-. If 'Yes,* enter the amount of tax-exempt interest received or accrued during the year ........... .. ......l12b '~~~ K_:-~t ·~-· <: Section 601 (cJ(29J qualified nonprofit health insurance Jssuen. "· ~· r " · ~~ Is the organization licensed to issue qualflad health plans In more than one state? ................................. ..................... .... ..... ·~ · 1;..;3aFi"'i~rl--. Note. See the lnstructlon8 for additional information the organizlltlon must report on Schedule 0. ·' i rff~ ~ 'Zj : Enter the amount of reserves the organization Is ·required to maintain by the states In which the .'!, :< tf' ~· ;· , ·- · I t: . b organization ia licensed to Issue qualmed health plal'!s •...... ..... .............. .... ...... .......... .... ..... ...... ..... ll-1""'3"'b'-!l---------l~\.A 11j • .( :~~~ ·;;·?: c Entertheamountofreservesonhand .......................................................................................... 13ci f.~·~. ~ ·, ·· ·. ::iescrlbe the process In Schedule 0 (see Instructions). 16a Did the organization Invest in, contribute assets to, or participate In a joint venture or similar arrangement with a taxable entity during the year? ......................................................................................................................................... . b If 'Yes,• did the organization follow a written policy or procedure requiring the organization to evaluate its participation in joint venture arrangements under applicable federal tax law, and take steps to safeguard the organlzation'a I .... ........... ........ .... .... ... ..... .... .. ..................................... . 18b exemot status with resDect to such arranaementa? ... .. .. ,, t"¥5 ',: Sect1on C. DlsclosLr8 17 Ust the states with which a copy of this Form 990 is required to be filed ...._ __;N:. :. c:Oc::.NEc:. =. .________________ 18 Section 6104 requires an organization to make Its Forms 1023 (or 10241f applicable), 990, and 990-T (Section 501 (c)(3)s only) available for public lnapectlon. Indicate how you made these available. Check all thet apply. Own website Another's website. Upon request Describe In Schedule 0 whether (and If so, how), the organization made ita governing documents, conflict of Interest policy, and financial statements available to the public during the tax year. State the name, physical address, and telephone number of the person who possesses the books and records of the organization: ..,. _ __ D 10 20 192tJOQ D 00 THE ASSOCIATION - 202-872-0030 1129-20TH STREET, NW, SUITE 350, WASHINGTON, DC 20036 Form 990 (2011) 01-2:>-12 6 15000812 783690 0861-001 . 2011.05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 23 of 273 14-05XXX; MDR 094 Attach 01 . . of Dlrectons. Employees, and Independent Contractors Check If Schedule 0 contains a response to any question in this Part VII.... ................................ .................. ................................. Section A. Officers, Directors, Trustees, K!Y Employees, and Highest Compensated EmploYees 1a Complete this table for all persons ItqulreCI to be lstacl. Report compensation for the calendar year ending with or within the organization's tax year. 0 • Ust all of the o~lzatlon's cum~nt officers, directors, trustees (whether individuals or organizations), regardless of amount of compensation. Enter -o- in columns (D), (~, and (F) If no compensation was paid. • Ust all of the organization's c...,.nt key employees, If any. See Instructions for definition of "key employee." • List the organization's five currant highest compenaatacl employees (other than an officer, director, trustee, or key employee) who received reportable compensation (Box 5 of Form W·2 and/or Box 7 of Form 1099-MISC) of more than $100,000 from the organization and any related organizations. • Ust all of the organization's former officers, key employees, and highest compensated employees who received more than $100,000 of reportable compensation from the organization and any rel8ted organlzatlcins. • Ust all of the organization's former directors or tnastees that received, In the capacity as a fonner director or trustee of the organization, more than $10,000 of reportable compensation from the organization and any related organizations. Ust persons In the following order: Individual trustees or di'ectors; Institutional trustees: officers; key employees; highest compensated employees; and former such persons. D Checkt hisbox If ne1ther the omanlzation nor any related oraanlzstion comoensated any current officer director or trustee. (B) (A) (D) (E) (C) Position Name and THie Average Reportable Reportable (do not cb- _,_ then one hours per boX, UIIIIIU p!nlln Ill bOIII6'1 compensation compensation ofllc:er ~d a dlleCID,_,s!IIOj week from from related (describe the organizations organization hours for (W·211099·MISC) Is i (W-2/1 099·MISC) related .;: organizations i In Schedule 10) .& i (F) Estimated amount of other I compensation from the organization and related organizations "' I, I i ~ I !'I I I (1) RC»l BECK CKAIRKA!I OP 'l'BB BOARD (2) VICJI CHAIRMAH 07 THE BOARD (3) 131,673. 13,690. 35.00 X X 1.00 X X o. o. o. o. 35.00 X X 181,025. TROY wiST IMIIEDIATI PAST CBAIRMlUI (6) X 1.00 X JABOll GRIFFI'l'H SBClUITARY /!'RIASURBR (5) 1.00 X X CODJIB DURCSAE PRBSIDEIII!'/CBO U) o. o. o. X o. o. 1.00 X 'I'OM PBRRY KID OLDA1C ASSIS'l'AB'l' SBCJI.JITAJI.Y/TRU.SU (7) ED CAMPBELL AtJ!)I'J' COIOII'l'TBB (8) DID POll!'BRFIELD SBCURI'l'Y COMHI'1'TBE CHAIR (9) RCDJ BILODBAD 1.00 X o. 1.00 X 0. ' 1.00 X BOSUlBSS DEVELOPlllDl'r DIVIS ( 10) D"l!KI'l'B. WAJSIOOI' 1.00 X IBTBRKATIOKAL DIVISION CO(11) MIGUIL ~GIL SAVCHBZ FOIUJIB 1.00 X D1'l'BRHA!'IOXAL DIVISIO. CO(12) KID LOWE .I I MEMBER SBRVICIS DIVISIOM C P~lCY 1 •.00 X i RBGIORAL DIVISION CHAIR (15) ROlf TAYLOR TBCEMICAL DIVISION CHAIR i 1.00 X DrviSlOR CHA (U) JAIME LEAL I I l ( 17 ) KID ZACCA MORRAY (35) DAVJI WBDLBll ~ other compensation from the X 1.00 (29) ERIC Pli.I'l'Z u~~ (F) Estimated amount of I BI~ !!!_ER. (28) SCOT!' lllGHBS WIRELESS 52-6042453 • ,,.,.....t;,,..,{l _ and related organizations I J I i} (27) QARY ... , and Hiahest REGIOll_ (REGI (36) RARDY HOPKIRS ROR'I'RWIS'l' RBGIOlT 9 (37) CARL RICHOLS O'I'ILISITI COUNCIL (38) EARL BARBER DIRECTORS ( 39 ) ROlWDTB FmTG DIRBC'l'O:RS X ( 4 0 l '1'0liY IIARSHALL DIRBC'l'Ol!S 1.00 IX ( 41) SOllYA BASURVILLil 1.00 X (42) JBPP RICBOLS ( 43) .JOB ROWACznt DIR:J!:C'l'O:RS ( U) RICJ: SPBCI: DIRBCTO:RS ( 4.5 ) JtJDl" 'l'OMAS ZEWSKI DIRIC'I'O:RS 0. ( 4.6) ROGBR BRYANT 0. 0. _!). g. o. 0. o. o. o. o. o. o. o. o. Total to Part VII, Section A. line 1c 132201 D5-DH1 9 15000812 783690 0861-001 . 20-11.05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 26 of 273 14-05XXX; MDR 094 Attach 01 . . UTILITIES TELECOM COUNCIL Form 990J2011) Section A. -.rvm Offi~;ers. 52-6042453 Directors, Trustees Kev E"!ployees and Highest Compensated Employees (continued) (A) Name and title I (B) I I Average hours per III I week l5 J.! s I .:; I I ~ II i I I DIRECTORS ! ... I ( '7) CHUCJ[ IIACDJBY (D) (C) Position i (check all that apply) 1.00 ! II! I I Reportable I compensation from the organization (E) (F) Reportable compensation from related organiZations Estimated amount of other compensation from the organization and related organizations I I I rt/·211 099·MISC) I rt/·211099·MISC) .. lj ~ iII o. X ( 68) DOUG IICG:UDJI S DIRECTORS 0. 0. ' 1.00 X 0. o. 1.00 X o. o. o. 1.00 X o. 0. 0. 1.00 X o. o. 1.00 X o. o. 1.00 X o. 1.00 X o. o. o. o. o. 0. o. 1.00 X o. 0. o. 1.00 X o. o. 1.00 X 0. o. o. 0. 1.00 o. 0. 0. (49) JOHN MACHILLY DIRECTORS o. (50) ALOURDBS SULLY U'l'C CAI1ADA RBPRESD'l'ATIVBS (51) AL PIIlDZR U'l'C CAMADA R.DRBSD'l'ATIVBS (53) GBOFFRBY TROFIMDK UTe CAllADA REPRBSBR'l'ATIVBS (53) JEAN DB SBVE 1J'1'C CUADA RBI'RJ:SDlTATIVBS (54) JXRRY OBRIST PAST UTC BOARD CHAIRXDT ( 55) BBRRABD JACOB PAS'l' UTC BOARD CHAIRMBII' (56) JIK S'l'~L PAST tJ'l'C BOARD CHAIRKDI (57) JBPP SBLlllUl PAS'!' tJ'l'C BOARD CBAIRMBII (58) JBPP D.'l'Z PAST IJ'l'C BOARD CHAIRMD X ( 59 I IAUIL THoMAS VICE PRBSIDEM'l' - K!KBBR (60) ~LBBM 4o .. ·oo X 133,477. 0 .. 23,748. 40.00 X 143,169. 0. 17,070. 40.00 X 118,949. o. 23,491. 40.00 X 117,451. o. 18,899. 100,371. l 0 .l 17,626. FI'l'ZPAT.RICK VICE PRBSIDBR'l' - OPBRATIOUS (61) BRETT KILBCURBB VICB PRES - GOY r. DIDUST AI' FAIRS 1 Dll (62) KLAUS BBMDBR SR. DIRBC'l'OR STMTDARDS AHD EliGDJBBR ( 63) DOifALD VASEK DIRECTOR SPBC~ 40 .. 00 SERVICES X ( U) WrLLIAK MORODY 40.00 PORKER PRBSIDERT/CBO X I I I . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .! l Total to Part VII, Section A, line 1c I 165 f 744 .j I! 0 .I 18,905. l i ' 779, 161.! 119,739. 132201 0!5·01·1, 15000812 783690 0861-001 . 10 2011.05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 27 of 273 14-05XXX; MDR 094 Attach 01 . . 52-6042453 CB) Related or exempt function (C) Unrelated business Page9 (D) Revenue excluded from tax under sections 512, 513,or514 Federated campaigns Membership dues ....•. .................. c Fundralsing events .. .................. .... r1;.;:::c+·--------t d Related organizations .............. .... l-'1:..::d:..r--------i e Govemment grants (contributions) t-'1;.::::•+----'------t f All other contnbutions, gifts, grants, and g h Total. Add lin 2• MEMBERSHIP DUES 8 b !I 0 ANNUAL CONFERNCE AND E SPECTRUM SERVICES d EUROPE PROGRAMS ~ • ADVERTISING f l REVENUE lnveatment Income Oncludlng dividends, Interest, and other similar amounts) .................................................. . Income from investment of tax-exempt bond proceeds 3 4 15 r. .=....~···~.. -~.. ·-~·..=··..r···~. -~....~. -~. ~~~-;;;;:z;:;;~~:;:::;::;::;;n:t~:;:::::::rE:t:~~;:-""7"~ Royalties .............. ............ ..... e. Gross rents .... ..... ..... ... .. b Lass: rental expenses......... t - - - - - + - - - - - i!. c Rental Income or 6oss) ...... .__-~---'-----:---1 d Net rental Income or (loss) "r·..""' ...:;· ·:. :... :""'":. :;· ·:...:. :.:.:...:..:; .. ·:...:. :;:-..·:. ..:. :" "· :. :;·" :...:. :.:.:...·"'"·....:;..--t~~~~,....,.,.....,ji-:-:"T"....,....,.,.,...,=-~~--"!"""..,.,..,_~....,...-_.,,.,.......,., 1 Securities · Other 7e GN;l&s amount from sales of assets other than inventory b Leas: cost or other basis and sales expenses ........ . c Gain or (loss) .................... . d Net gain or (loss) ................................... ·......F"!.!;'":.!.!""'-" "'"-'-"':..:..:""---"---+=~~~=+~~~==-i-nr='~-:::-~=:"t-:~;-.o-."':!'":~~ 8 • Gress Income from fundralalng events (not Including $ of contributions reported on lina1c). See b Part IV, line 18 .................. ..................... • 1 - - - - - - - ; LeSs: direct expenses.............................. b L---------f c Net income or Ooss) from fundraislng events r" .;.:."·'-""""-"":..:; "·""'··.:..·....::....-+:-:r-=~=--~~~~...,.;~~~~-::'"',.......~=d~~~...-..-~ 9 • Gross income from gaming activities. See Part1V,Dne19 ....................................... • 1 - - - - - - - i b Leas: direct expenses .......... ................ , b .____ _---:---f c Ne1 Income or (loss) from gaming actlvttles 1 0 • Gross sales of inventory, less retums and anowances ...................................... . b Less: cost of goods sold ....................... . 11 • --------------~-----------­ b -------------------------- c d All other revenue ................. ..................... . e Total. Add lines 11a-1_1d .. ................. .... ...... ;............... .... 12 Total revenua. See Instructions . ................................. ..... .... 132009 01·23-12 15000812 783690 0861-001 . 11 2011.05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 28 of 273 14-05XXX; MDR 094 Attach 01 . . 52-6042453 [flt:JI[Statement of Functional Expenses Page10 Section 501 (c}(3) and 501(c)(4) organizations must complete elf columns. A/f other Olf)IJI1izations must complete column (~ but 8/fJ not required to complete colul11fls {B), (C), and ,D). Check if Schedule 0 contains a resoonse to anv auestion in this Part IX .................................. .......... ................................. . :~~:~:::~~;::=~~=3:: f-------+--------+.~f,·i*-;,:.: ~i~ ~~L ~;:;; r .:! 21 .... .~=====~· the United States. See Part IV, line 22 4 5 li..· .: .J ......... 88,429. Benefits paid to or for members ....... .... .... ..... . Compensation of current officers, direotors, 8 trusteea, .and key employees ........................ Compensation not Included above, to disqualified persons (as defined und&rs&ctlon 4958(f)(1)) and 7 Other salaries and wages .. ............................ 8 Pension plan accrualS and contributions Ondude 9 other employee benefit8 ............................. . 10 Payroll taxes ......................................... ..... . Fees for services (no~ployees): 11 18 17 18 18 20 21 ' • I-...:2::...J,~0=-=-6-=l~,-=l:..:7:...:2~.1---------ll--------t------- 150,560. 257.440. 152,638. .. . . :'li Investment managementfeea ....................... . Other ........................................................... . Advertising and promotion ......................... .. 11, 911 • 56 , 9 7 4 • Office expenses............................................. Information technology .... ........ ............... .... .. Royalties ..................................................... . Occupancy ................................................... Travel .... .................................................... . Payments of travel or entertainment expenses for any federal, state, or iocal pubRc off'.cials 1--....;:3;..::2:....:0:::....,~6:....:5:....:2=-=-1.f--------t--------+------ Conferences, conventions, and meetings ...... 1-------+--~----+-------t------Interest ........................... ........................... 1-----~~+--------+-------t------Payment!l to affiftates ................................ .... --~:'7'"--:-.......-:o:-fl-------f-------+------Depreciation, depletion, and amortization ...... 1---=-9-=6;..~1•-=2=-4=-0:::....:.•I---------11---------4- - - - - - 1-' 22 23 24 a b c d Insurance ................................................... 1:<:.-:.-: ,•·_;:-:--:,.; ~.-,.~:""'·;"'"' :·:; .....-,,........... ~; ·-:.;,-. ,.t.-..,~ .._; -::-,:..,...,.-,........""".""'·.,...,,;"·'""""' ~ ~,..jr~<,-,..., _, .~,"~~-.,<"':""""..':"' ,r.=~~ - ~---........-f~~ --. -~"""·"...,~,............,......, . ...,.,_ Other expenses. Itemize expenses not cover&d . ~-~»! ·· ~· ·,... , i-;.,,;.;i (}:.~i¥ ~).t[·. i»><..:K 1· "; ·.·. '0.. ;, ~:. · ~~ , · ·(. ;,: ,.- · ~ -,, ~ .. ; above. (List ndscellaneous eJqillnses In line 24e.lf line j ·."'1~.~~ ·,·.' , , ; -:*-4-;,!~J)[:·~[·:'~~"· t~~' -~ . '· ·~ ; 1~,-,<:' ~F;.:., )}~f'-.~:~ -:t,· ~ · "~': ~ :~ ; 24eamo~nt!xceeds 10"1a ofllne25,column (A) b.}·~·~:.. "" : <._i',~~~'-''~·:.. ·:· ~ .L: · ' : ~· }:_._ -...>ki_. ~>:} .. ,_.9 • · · ; . - · £·. · -~ amount, l1st lme 24eexpenses on Schedule 0.) ... ... ~-:::i:·' ,_.;~· f .~ . ~f:.,~~.··~.-~L'. ~M.' _ :, . :_~_: !'<· persons described In section 4958(c)(3)(B) ......... aeclton 401(11) •nd aectlon 403(b) employeroontrlbutior1o) ;~~ ~~--{:lt ~-;,.- ;' 1~- ';':·~- · :-i ~m;!~=~7d ~~~~-~-~~~:~-~:~:-~~~~-~~-~~ . . . . . . . . . b~""':'":~~~...---:-~,..;:5~"""""'""""'""'"'~r"""'....-..--,or, employers and sponsoring organizations of section 501(c)(9) voluntary employees' beneflc!ary organizations (see instrUctions) ................................. J 52-6042453 Paae11 Sheet }I l\/ _:_· _,~--~ ~~~-~ ~~' -~- -.} f.!i'~; ~- _.: : _-:;_'_,~: _, __;d 1-------+....:8,_ _ _ _ _ __ Notes and loans raceivable, net .................... ~ ............................ .................... 1-------+-=7:.-.t-- - - - - 8 Inventories for sale or use........................... ................................................... 8 D P~paldexpensesanddeferredcharges ............................ ....................... ... 443,706. 9 404,772. 10a land, buldlngs, and equipment: cost or other !~-;{:;.;.~· -h~ [~·i ~~~J~J basis.CompletePartVJotSchedureo _________ 10. 562,156. ,.~;-:~y · , ·- .;,}__ L .. ·_~ ..-~·~ .~ b Less:accumulateddepreclatlon .................. 10b 350,915. 255,507. 10c 211,241. 7 "f ,;:, i 11 12 13 14 15 18 17 18 18 20 21 22 .I .... 23 24 25 .;;u'!l....:_:_j _ :_·: .. Investments· publicly traded secLN'ftles ......................................................... Investments· other securities. See Part IV, line 11 .... ...................................... . 11 12 Investments· program-related. See Part IV, llne-11 .............. :........................ 1---------+-2-+--- - - - - lntanglble aaaeta ..... ...................... .... ............... .................. .... ...... ................ 1----:.--=....----:--:::-::.--+~+--~-=.-:---=-~,..... Other assets. See Part IV, One 11 ........................................ ................... ....... t-----=~-==-i-1~~-=+-~+--~..;..;;..;.L.:;..;..::...:.. Tot.lassets. Add lines 1 throuah 15 Cmust eauallina 341 ............................ .. AcCounts payable and accrued expenses .................................................... .. Grants payable ............. ........... ................................................................... .. Deferred revenue ................. ..................................................................... .... Tax-exempt bond liabilities ........................................................................... 21 Escrow or custodial account liability. Complete Part IV of ScheduleD .... ...... .. Payables to current and former offlcera, dffectora, trustees, kay employees, highest compensated employees, and disqualified persons. Complete Part ll of Schedule L ..... ................... ............... ............... ........ ... ........... ... .............. 1-----;:;;:-=-~=-=-+-=22=-+-~----=-==--=-=-Secured mortgages and notes payable to unrelated third parties .................. ,__ _ _8=..0.::..!..,=2-=8-=6:..:•:r--:23=---i----=6:.:5::;__,,L8=-5=-=-9.:.• Unsecured notes 8f!d'loana payable to unrelated third parties ..................... .. . Other liabilities (Including federal income tax, payables to related third parties, and other liabilities not Included on linea 17·24). Complete Part X of r.25=-f-l ,1 i-59:--:-• ScheduleD .... ......... ...................... .... .......... .................... .... .... .................. . l----7l.L,_:;:8-=3-79.L, TotalliabiiHies. Add lines 17 throuah 25 ...................................................... 4, 4 7 4 , 0 2 6 • 28 4 1 413, 9 8 0 • o--nlzatlonsthlltfollowSFAS117,ch8clc:here_ ~ fXla_ ndoornplete ~>~'*-~,, · .· '1:; ·~'-,....i.. f·t ~~~- ·~' :7:~, '~; ~0--;;;7~4..:..• 28 · :-· ·- ~ 1($. • ~- c~ · """" :J' "'\... <' .,_ ··' ,,·___ _. -~1.L,~8.;.5::-2~ •,, ;;;:~ '"',., ' ,.' · - . ' .:. _''..'- . ' linea 27 through 29,and lines 33 and 34. ~~+_ __ :_~ - f::. -:. ~.-::.-~ .. -~i< ·~ Unrestricted net assets ............... __....................................... __ ...... __ ........ _... ... I-----=3:..7:...;6:..1L ,5::..:.3-=.8..:.•._,:::ZI~_ __:6:.:0:...6::..L,9=-=-0=-2.:..• Temporarily restricted net assets ............................................ ...................... 1---------+-==28~--~---Permanently restricted net assets ......................................... ...................... r,...,..,..........,.,....,...,....,_,........,.. -~~29=--t-· .,...,.,.,........,.......,..,..,...,-.~ :::::':'th~:~SFAS 30 31 32 33 34 117, check here ~ 0 and _ !~:f~-~-- ~-~ t:::::~~rtr:; If :l~~::~~~t_, ,~~;-\ _: : _ ~' ~ CapltalstockortruetprlnclpaJ,orcurrentfunds ............................................. 1---------+~30~------Paid-in or capital surplus, or land, building, or equipment fund ........................ 1--------+-=3.:...1+-- - - - - - Retained eaminge, endowment, accumulated income, or other funds ....... ..... 1----=,.-:::----="'=-=-+~32~1----==-=-=--==-Total net assets or fund balances .................................................................. I--~3=-7~6L-:, ,5..;3,.:;8;..:.+'...:33~----=----=6;.,;0;..;6;...,t...:9~0~2-=-. Total liabilities and net assets/fund balances ........ .... .................................. 4, 850.564 .I 34 5, 020,882. Form 990 (2011) 132011 OH!3·12 15000812 783690 0861-001 . 13 2011.05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 30 of 273 14-05XXX; MDR 094 Attach 01 . . Fotm990l2"011l UTILITIES TELECOM COUNCIL F~Jti Reconciliation of Net Assets 52-6042453 Page12 Check If Schedule 0 -contains a response to any question in this Part XI .... ...... ... ..... ..... .... .. .... .......... ... ... .. .. .. ..... .. ... ... .... ... ... .... ..... D Total revenue (must equaf Part VIII, column (A), line 12) ............................ .......... .... ..................... ........ ....... 1----!~--~:..-=::-=..t...:~;..: Total expenses (must equal Part IX. -column (A), line 25) .................. .... ..... .......... ................. ........................ j---!=---J----=-~..;....;~:-;...;-:. Revenue less expenses. Subtract line 2 from line 1 .................................................................................... Net assets or fund balances at beginning of year (muSt equal Part x.·nne 33, column (A)) ............................. . Other changes In net assets or fund balances (explain In Schedule 0) ......................................................... 1 2 3 4 5 D 1 2a b o d 3a b 00 D Accounting method used to prepare the Form 990: Cash Accrual Other If the organization changed Its method of accounting from a prior year or checked "Other, • explain In Schedule 0. Were the organization's financial statements compilecl or reviewed by an Independent accountant? . ......... ... ... .... .. .... ...... ... . i--==+-=--+--==-Were the organization's financial statements audited by an independent accountant? .. .. ..... .......... .... .... .... .. .... ............. ...... . 1---"'"4--==-+-If "Yes • to line 2a or 2b, does the organization have a committee that assumes responsibHity for oversight of the audit, review, or compilation of Its financial statements and selection of an independent accountant? ........................................... .. If the organization changed either Its oversight process or selection process during the tax year, explain in Schedule 0. If "Yes • line 2a or 2b, check a box below to indicate whether the financial statements for the year were issued on a separate basis, consolidated basis, or both: 0 Separate basis CXJ Consolidated basis D Both consolidated and separate basis As a result of a federal award, was the organization required to undergo an audit or audits as se1 forth in the Single Audit Act and OMB Circular A·133? ............................................................................................................................................. 3a X If 'Vas," did the organization undergo the required audit or audits? If·the organization did not undergo the required audit · wh in Schedule 0 and describe an ste s taken to unde such audits. .. ... ...... .... .... .. .. .. ................ ....... 3b Form 990 (2011) to 132012 01-23-t:! 15000812 783690 0861-001 . 14 2011 . 05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 31 of 273 14-05XXX; MDR 094 Attach 01 . . SCHEDULEO (Form 890 or 990-EZ) Department o!the T-..ry ln18mal Political Campaign and Lobbying Activities OMB No. 1 545·0047 2011 Far Organiutions Exempt From Income Tax Under section 501 (c) ~ sect1011 627 -:~. . . . .<' ·.: . :~ ::'~W.; :·;;: .... Complete if 1he organization is described below. .... Attach to Form 990 or Form 990-EZ. .··.·, F!eVem;e Selvtce ~Seese rate lnstnH:tlons. If the organlzati011 answered "Yes" to Form HO, Part IV, line 3, or Form 910-EZ, Part V, 6ne 48 (Pol"dical Campaign Activities), then • Section 501 (c)(3) organizations: Col1'1)1ete Parts I·A and B. Do not complete Part I.C. • Section 501 (c) (other than section 501 (c)('J)) organizations: Complete Parts I·A and C below. Do not complete Part 1·8. • Section 527 organiza1ions: Complete Part I·A only. If the organization answered "Yes• to Form 910, Part IV.IIne 4, or Form 990-EZ, Part VI, line 47 (Lobbying Activities), then • Section 501 (c)(3) organizations that have filed Fonn 5768 (election under section 501 (h)): Complete Part II·A. Do not complete Part II-B. • Section 501 (c)(3) organizations that have NOT filed Form 5768 (election under section 501 (h)): Complete Part li·B. Do not complete Part li·A. If the organization answered "Yea 0 to Form 990, Part IV, line 5 (ProX)' Tax), or Form 980-EZ, Part V, li1111 36c (Prole¥ Tex), 1hen 1 Provide a description of the organization's direct and lndrect political campaign activities in Part IV. 2 Political expenditures ............................................. .".......................·................................................................... S - -- - - - - 3 Volunteer hours ................................................................................................................................................ IM'G11 Complete If the organization Is exempt under section 501 (c)(3). 1 Enter the amount of any excise tax Incurred by the organization under section 4955 ........................................... $ - -- - - - - 2 Enter the amount of any excise tax Incurred by organization managers under section 4955 ............ ...................... $ - ...... 3 If the organization Incurred a section 4955 tax, did It file Form 4720 for thla year? .... ................ ........................... .... ...... Yes No 4a Was a correction made? . ............... .............. ... ... ............ ... ..... ..... .... .......... .... .•. ... .... ........... .... .•. .••. ................. .•. .... .•... . Yea No b If 'Yes • describe in Part IV. · =-------- D D tM8i1 0 D Complete if the organJzation is exempt under section 501 (c), exuept section 601 (c)(3). 1 Enter the amount directly expended by the filing orgai,izatron for section 527 exempt function activities ............ .... $ - -- - - - - 2 Enter the amount of the filing organization's funds contributed to other organizations for section 527 exempt function activities ..... .............. .................................................... ........................... ................................ $ - - - - - - - 3 Total exempt function expenditures. Add lines 1 and 2. Enter here and on Form 1120..POL, -------....,...-=r- line 17b , ................. ............................... ......................... ........... ...................... .................................................. S Did the fDing organization file Form 1120-POL for this year? ........... ............ ...... ................................................ .......... Yes No 5 Enter the names, addresses and employer identification number (EIN) of all section 527 political organizations to Which the filing organization made payments. For each organization listed, enter the amount paid from the filing organization's funds. Also enter the amount of political contributions received that ~ere promptly and dlrecUy. delivered to a separate political organization, such as a separate segregated fund or a political action conmittee (PAC). If additional space is needed, provide information In Part IV. 0 4 (a) Name (b) Address (c) EIN D C.J Amount of political contributions received and promptly and directly delivered to a separate political organization. If none, enter .0·. (d) Amount paid from filing OfV81tlzatlon's funds. If none, enter -o-. l ! I i ! I I ! I I I I I For Papenvork Reduction Act Notice, see the Instructions for Form 990 or 990-EZ. Schedule C (Form 990 or 990-EZJ 2011 lHA 132041 01·27·12 15000812 783690 0861-001 . 15 2011.05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 32 of 273 14-05XXX; MDR 094 Attach 01 . . P e2 B Check .... D if the filing organization belongs to an affiliated group (and list In Part IV each affiliated group member's name, addrass, EIN, expenses, and share of excess lobbying expenditures). if the min · · (b) Affiliated group (a) Filing Umlts on Lobbying Expenclit11res organization's totals (The term "expenditures" means amounts paid or Incurred.) totals 1a b c d e Total lobbying expenditures to Influence public opinion (grass roots lobbying) ............................. . Total lobbying expendlturas to influence a legislative body (direct lobbying) ............................... .. Total lobbying expenditures (add lines 1a and 1b) ....·.................................................................... Other exempt purpose expendlturas .................... :..................................................................... Total exempt purpose expendltu1'8S (add lines 1o and 1d} ............................................................ f Lob nontaxable amount. Enter the amount from the followln table In both columns. 17 000000 :• Grassroots nontaxable amount (enter 25% of fine 1f) h Subtract line 1g from line 1a. If zero or leea, enter .0· Subtract .line 1f from line 1c. lfzero or leea, enter .0· ................................................................. . If there is an amount other than zero on either lne 1h or line 1i, did the organization file Fonn 4720 repertlngsectlon 4911 taxforthlsyear? ...................................................................... ........................... ......... ........ DYes 4-Year Averaging Period Under Section 501(h) (Some organlzdona lhat made • section 501 (h) election do nat have to complete all of the five columna beloW. See the instructions tor lines 2a through 2f on page 4.) Lobbying Expenditures During 4-Yaar Averaging Period Calendar year (or fiSCal year beginning In) (a)2008 (c) 2010 (b) 2009 (d) 2011 (e) Total 2a Lo In nontaxable amount b Lobbying ceiling amount 15096 of line 2a, colomn(e ) c Total lo e Grassroots ceiling amount (150% of line 2d, column (e f G Schedule C CForm 990 or 990-EZ) 2011 132042 01·27·12 16 15000812 7B3690 0861-001 . 2011.05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 33 of 273 14-05XXX; MDR 094 Attach 01 . . ScheduleC'For ·· 990or990· 2011 UTILITIES TELECOM COUNCIL For each •yes" response to lines 1a through 7i below, provide In Part IV a detailed deserfption of the lobbying actfvfty. 1 52-6042453 p e3 Complete if the organization is exempt under section 601 (c)(3) and has NOT filed Form 5768 (election under section 501 (h)). (a} Yes (b} No Amount During the year, did the filing organization attempt to Influence foreign, national, state or local legislation, including any attempt to influence public opinion on a legislative metter or referendum, through the use of: • b c d Volunteers? ................................................................................................................................. Paid staff or management fmclude compensation in expenses reported on lines 1c through 1Q? .. . Media advertisements? ............................................................................................................... MaiUngs to members, legialatora, or the public? ...... .'.................................................................... e Publications, or published or broadcast statements? ................................................................ .. f Grants to other organizatio~s for lobbying purposes? ............................................. ....... .............. 9 Direct CO!Itact with legislators, their staffs, government officials, or a legislative body? ................ .. t----+----+------ h Rallies, demonstrations, semlnata, conventions, speeches, lectures, or any similar means? ........... . I Other activities? .................. .................................................................................................... .. j Total. Add Ones 1c through 1i .................................................................................................... .. 2e Did the activities In line 1 cause the organization to be not descrbed In section 501 (c)(3)? .......... .. b If 'Yes,' enter the amount of any tax Incurred under section 4912 ............................................... . c If "Yes." enter the amount of any tax Incurred by organization managers under section 4912 ........ . d the 1Jin anlzatlon Incurred a lon 9 2 t did It file Form 4720 for this ear? ................. . Complete if the organization ie exempt under section 501(c)(4), section 501 (c)(S), or section 501(c)(6). Yes 1 2 Were substantially all (90% or more) dues received nondeductible by members? .......... .......... ..... .... ..... ........... ...... Did the organization make only In-house lobbying expenditures of $2,000 or leas? ............. .... .... ... ....... ................. Did the o~ anlzatlon rae to over I I and · cal dltures from the · r ... ....... .... ............. No X 1 2 3 X X Complete if the oraanlzation l.s exempt under section 501 (c)(4}. section 501(c)(5), or section 501(c)(6) and if either (a) BOTH Part 111-A, lines 1 and 2, are answered •No 11 OR (b) Part 111-A, line 3, is answered ''Yes. u 1 2 Dues, assessments and similar amounts from members ....................................................................................... Section 1B2(e) nondeductible lobbying and political expenditures (do not include amounts of political 1,905,604. 1 expenses for which the section 527(f) tu Wlls pei4. 53,092. a Current year ..................................................................................................................................................... . b carryover from last year ., ... ........ ..... .... .. ... ........... .......... ..... ...... ....... .. ...... ... .... .. ... .... ............... ... .... ....... ... ..... .... 2b cTotal ............................. , .................................................................................................................................... 2c 53,092. 3 Aggregate amount reported in section 6033(e)(1?(A) notices of nondeductible section 162(e) dues ........................ ~3:...;.--..::9-=9~,~9::......;..7;;::2...:... 4 If notices were sent and the amount on line 2c exceeds the amount on line 3, What portion of the axcess t~t ~ does the organization agree to carryover to the reasonable estimate of nondeductible lobbying and political ~-~' ;_, , 6 expenditure next year? ................................................. ..................................................................................... . Taxable amount of lobbying and P01iticai8XJ)&ndltures (saelnstructlons) ............................................................. .. ._dW~l 4 6 -46,880. SuoDiementallnfonnation Complete this part to provide the descriptions required for Part I·A, line 1; Part I·B, One 4; Part I·C, fine 5; Part II·A; and Part IJ.B, line 1. Also, complete this part for any additionallnfonnatlon. Scheci.!le C (Form 990 or 990-EZ) 2011 132043 01·27·12 15000812 783690 0861-001 . 17 2011.05090 UTILITIES TELECOM COUNCIL 0861-001 . Page 34 of 273 14-05XXX; MDR 094 Attach 01 . . 14-0SXXX MDR94 Attachment 01 Nevada Power Company MDR 94 Section C Western Electricity Coordinating Council (WECC) . . Page 35 of 273 14-05XXX; MDR 094 Attach 01 . . ~ WECC 2014 Business Plan and Budget Western Electricity Coordinating Council Approved by: WECC Board of Directors . Date: June 28, 2013 . Page 36 of 273 14-05XXX; MDR 094 Attach 01 . . Table of Contents Introduction ................................................................................................................... 3 Organizational Overview ...................................................................................................... 3 Membership and Governance .............................................................................................. 4 Statutory Functional Scope .................................................................................................. 5 2014 Key Assumptions ......................................................................................................... 5 2014 WECC Business Objectives ........................................................................................ 6 2014 Overview of Cost Impacts ............................................................................................ 6 Personnel Analysis ............................................................................................................... 9 2013 Budget and Projection and 2014 Budget Comparisons ............................................... 10 Section A- 2014 Business Plan ............................................................................... 12 Reliability Standards Program .............................................................................................12 Compliance Monitoring and Enforcement and Organization Registration and Certification Program ........................................................................................................................16 Hearings ..............................................................................................................................23 Reliability Assessment and Performance Analysis Program ................................................24 Training, Education, and Operator Certification Program ....................................................29 Situation Awareness and Infrastructure Security Program ...................................................33 Administrative Services .......................................................................................................36 Technical Committees and Member Forums ....................................................................... 37 General and Administrative .................................................................................................41 Legal and Regulatory ..........................................................................................................44 Information Technology .......................................................................................................47 Human Resources ..............................................................................................................50 Finance and Accounting ......................................................................................................53 Section B - Supplemental Financial Information .................................................... 57 Reserve Balance .................................................................................................................57 Penalty Sanctions ...............................................................................................................60 Supplemental Funding ........................................................................................................61 Personnel Expenses ...........................................................................................................63 Consultants and Contracts ..................................................................................................65 Office Rent ..........................................................................................................................67 Office Costs ........................................................................................................................68 Professional Services ..........................................................................................................69 Other Non-Operating ...........................................................................................................70 Section C- 2014 Non-Statutory Business Plan and Budget ................................. 72 Western Renewable Energy Generation Information System (WREGIS) ............................ 72 Personnel Analysis ..............................................................................................................75 Reserve Analysis- 2013-2014 ......................................................................................... 76 Section D- Additional Consolidated Financial Statements .................................... 78 2014 Consolidated Statement of Activities by Program, Statutory, and Non-Statutory ......... 78 Statement of Financial Position ...........................................................................................79 Appendix A: Organizational Chart ............................................................................. 80 Appendix B: 2014 Budget & Projected 2015 and 2016 Budgets .............................. 81 Appendix C: Adjustment to the AESO 2014 Assessment ........................................ 82 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 2 . Page 37 of 273 14-05XXX; MDR 094 Attach 01 . . 2014 Business Plan and Budget Introduction Introduction Non-statutory FTEs Total FTEs Statutory Expenses Non-Statutory Expenses Total Expenses Statutory lnc(Dec) in Fixed Assets Non-Statutory lnc(Dec) in Fixed Assets Totallnc(Dec) in Fixed Assets Statutory Working Capital Requirement" Non-Statutory Working Capita! Requirement'" 1---....!...!.:::=~ Total Working Capital Requirement Statutory Funding Requirement Non-Statutory Funding Requirement Total Funding Requirement IStatutory Funding Asaassrnents 1No1n-st:atultorv Fees *An as a full-time equivalent employee. **Refer to the Statutory Reserve Analysis on page 57 in Section B. ***Refer to the Non-Statutory Reserve Analysis on page 76 in Section C. ****NEL is defined as Net Energy for Load. Organizational Overview The Western Electricity Coordinating Council (WECC) is a 501(c)(4) entity operating in the "best interest of the public welfare." WECC's mission is to promote and foster a reliable Bulk Electric System (BES) in the Western Interconnection. WECC's website is http:l/www.wecc.biz. WECC's geographic area is the Western Interconnection -an area in which the use and generation of electricity is synchronized. This area includes all or part of 14 Western states in the United States, two Canadian provinces, and a portion of Baja California Norte, Mexico. WECC's business philosophy is guided by the following core values: Integrity- We are honest, ethical, and trustworthy. We honor our commitments. We take personal responsibility for our actions. We treat everyone fairly and with respect. Teamwork- We recognize our strength is derived from collaborative efforts. We continually learn, and share ideas and knowledge. We encourage cooperative efforts across all activities in the Western Interconnection. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28,2013 . 3 . Page 38 of 273 14-05XXX; MDR 094 Attach 01 . . 2014 Business Plan and Budget Introduction Excellence- We strive for continuous quality improvement in all that we do. Inclusiveness- We foster an open and participatory environment that encourages innovative ideas and diverse perspectives from all stakeholders. Professionalism- We conduct ourselves with skill, good judgment, and polite behavior across all committees, forums, and stakeholder interactions. Membership and Governance WECC has 421 members 1 divided into the following five membership classes: 1. Large Transmission Owners 2. Small Transmission Owners 3. Transmission Dependent Energy Service Providers 4. End Users 5. Representatives of State and Provincial Governments WECC membership is open to any person or entity that has an interest in the reliable operation of the Western Interconnection BES. WECC membership is not a requirement for participation in the WECC standards development process. 2 WECC is governed by a nine-member Independent Board of Directors and the Chief Executive Officer. The nine Independent Directors are not full-time employees of any Registered Entity, nor are they affiliated with any member or Registered Entity operating in the Western Interconnection, nor are they directors of an entity performing the function of Reliability Coordinator in the Western Interconnection. The WECC Board is elected by the WECC membership and the directors are compensated for their time. One Board Committee, the Governance Committee, oversees implementation and amendment of the WECC Bylaws, and addresses such other issues pertinent to Governance as delegated by the Board. The Governance Committee will consist of five directors. The Board Chair will designate one of the committee members to be the Chair of the Governance Committee. Under the direction of the WECC Board, five Standing Committees - the Member Advisory Committee (MAC), the WECC Standards Committee (WSC), the Planning Coordination Committee (PCC), the Operating Committee (OC), and the Market Interface Committee (MIC)- provide technical work and policy recommendations to the WECC Board. All member organizations are eligible for representation on the Standing Committees. 1 As of July 9, 2013 Non-WECC members may participate in standards drafting teams, and Participating Stakeholders may vote on Regional Reliability Standards. A Participating Stakeholder is defined in Section 3.21 of the WECC Bylaws and the Participating Stakeholder Application Process is described in Section 8.6.2. The Reliability Standards Voting Procedure is outlined in Section 8.6.1.2 of the WECC Bylaws. 2 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 4 . Page 39 of 273 14-05XXX; MDR 094 Attach 01 . . 2014 Business Plan and Budget Introduction 1. The Member Advisory Committee (MAC) - advises the Board on any matters the Board requests the committee to evaluate or consider, and advises the Board on matters as the MAC deems appropriate. The MAC Chair attends the WECC Board meetings to provide advice, clarifications or respond to directors' questions. The Board gives serious consideration to the MAC's recommendations and responds to MAC recommendations through a means that the Board determines appropriate. The MAC is comprised of three representatives from each of the five Member Classes, for a total of 15 members. 2. WECC Standards Committee (WSC) - oversees the process for responding to requests for Regional Reliability Standards and Regional Criteria in accordance with the Reliability Standards Development Procedures. The WECC Standards Committee consists of one member from each of the WECC Standards Voting Sectors and a member of the WECC Board who shall act as chair of the committee. 3 Planning Coordination Committee (PCC)- advises the Board and makes recommendations on all matters within the jurisdiction of WECC pertaining to maintaining reliability through evaluating generation and load balance and the adequacy of the physical infrastructure of the BES within the Western Interconnection. 4 Operating Committee (OC)- advises the Board and makes recommendations on all matters within the jurisdiction of WECC pertaining to maintaining reliability through the operation and security of the BES in the Western Interconnection. 5 Market Interface Committee (MIC)- advises the Board and makes recommendations on the development of consistent Market Interface practices and compatible commercial practices within the Western Interconnection. It considers matters pertaining to the impact of North American Electric Reliability Corporation (NERC) Reliability Standards and WECC's Regional Reliability Standards, Regional Business Practices, Regional Criteria, procedures on the commercial electricity market in the Western Interconnection, and facilitates analysis of the impact of electricity market practices on electric system reliability. Statutory Functional Scope WECC has been approved by the Federal Energy Regulatory Commission (FERC) as a Regional Entity, with authority- pursuant to the WECC /NERC Delegation Agreement - to create, monitor, and enforce standards for the reliability of the BES in the Western Interconnection. 2014 Key Assumptions NERC and the Regional Entities' business plans and budgets reflect a set of Common Assumptions developed jointly by NERC and the Regional Entities as part of the annual business plan and budget process. The entire set of Common Assumptions is provided in Exhibit A to the NERC 2014 Business Plan and Budget. These Common Assumptions and WECC's assumptions are described in each statutory program area in Section A of this document. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 5 . Page 40 of 273 14-05XXX; MDR 094 Attach 01 . . 2014 Business Plan and Budget Introduction 2014 WECC Business Objectives WECC's business objectives for 2014 are as follows: 1. Execute delegated authority with a high degree of excellence to reduce the frequency and severity of system events. 2. Facilitate the reliable and cost-effective integration of variable generation and non-traditional resources in the Western Interconnection. 3. Improve cost-effectiveness and efficiency of WECC processes to optimize the use of assessments. 4. Produce Interconnection-wide studies to support the development of a reliable, robust transmission system and assure resource adequacy. 5. Increase organizational readiness to respond to external drivers. 6. Provide data and analysis to support informed decisions related to system reliability and efficient competitive power markets. 7. Identify and mitigate potential risks and vulnerabilities to improve system reliability. 2014 Overview of Cost Impacts WECC's proposed 2014 statutory budget is $25.6 million, a $25.4 million (49.7 percent) decrease from the 2013 statutory budget. The decrease is mainly attributable to the creation of an independent new entity housing the Reliability Coordinator and Interchange Authority registered functions. Expenses associated with activities related to the U.S. Department of Energy (DOE) grants decrease by $2.3 million. Non-grant expenditures decrease by $23.1 million. Full-time equivalents (FTE) represent the fractional allocation of a full-time position's cost to one or more functional areas. Head count represents either vacant or filled positions. Significant changes to the 2014 statutory budget from the 2013 statutory budget are as follows: • Personnel Expenses decrease by $15.5 million primarily due to the transfer of 111 FTEs to the Reliability Coordination Company (RCCo) in the WECC bifurcation process. Additionally, most personnel expenses were reduced by 15 percent to budget for labor float (turnover, hiring delays, etc.). • Travel and Meeting Expenses decrease by $639,000, which is due to the creation of the new entity. • Consultants and Contracts decrease by a net $1.4 million. The budget for Situation Awareness was $2.4 million in 2013 and, due to the creation of the new entity, the Situation Awareness budget for Consultants and Contracts is zero in 2014. Reliability Assessment and Performance Analysis increases by $840,000 due to the continuation of the Regional Transmission Expansion Planning grant, which is offset by DOE grant funding. Human Resources increases by $120,000 due to a new compensation and benefits survey. • Other operating costs decrease by $5.9 million primarily due to the creation of the new entity. Two office facilities are transferring to the RCCo and Reliability Coordinator licensing and Internet bandwidth costs also transfer to the RCCo. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 6 . Page 41 of 273 14-05XXX; MDR 094 Attach 01 . . 2014 Business Plan and Budget Introduction • Fixed Assets expenditures decrease by $1.9 million primarily due to the creation of the new RCCo entity. A summary of funding requirements for WECC's primary statutory functional areas is shown in the following table and graphs: Program Projection 2013 Budget 2014 Variance 2014 Budget v 2013 Budget Va~e % 975,302 879,525 1,023,001 47,699 4.9% 13,159,281 13,103,076 14,763,348 1,604,067 12.2% 7,363,003 6,m,714 9,054,046 1,691,043 23.0% 533,258 519,358 689,277 156,019 29.3% Situation Awareness and Infrastructure Security 28,994,248 44,776,460 108,410 (28,885,838) -99.6% Total By Program 51,025,092 66,052,134 25,638,082 (25,387,010) Reliability Standards Compliance Entbrcamant and Organization Registration Reliability Assessment and Perfonnance Analysis Training, Education, and Operator Certification 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . Budget 2013 7 . Page 42 of 273 14-05XXX; MDR 094 Attach 01 . . 2014 Business Plan and Budget Introduction Comparison of 2014 to 2013 Budgeted Funding Requirements 35,000,000 . , - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - . +----------- ------- - - - - - 20,000,000 +-----------------------25,000,000 •2013 Funding •2014 Funding +------5,000,000 +------- 10,000,000 Reliability Standards Compliance Enforcement and Orgarization Registration Reliability Assessment and Performance Analysis Training, Education, Situation Awareness and Operator and Infrastructure Certification SecU"ity Percentage Change in Funding • Percenl>lge Change in Fundi111 Reliability Standards Compliance Reliability Enforcement and Assessment and Performance Organization Analysis Registration Training, Education, and Operator Certification Situation Awareness and Infrastructure Security The percentage change in funding is described in detail in Section A of the Business Plan and Budget, starting on page 12. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 8 . Page 43 of 273 14-05XXX; MDR 094 Attach 01 . . Introduction 2014 Business Plan and Budget Personnel Analysis In 2014, there is a net decrease of 81.3 FTEs (1 08 positions). Three new positions are being added in 2014 and 111 are being transferred to the RCCo. Jotal FTEs b Program Area Operational Program~ Reliability Standards Direct Shared Total FTEs Change Budget Projection FTEs 2014 FTEs. 2014 2014 from 2013 2013 2013 Budget Bud et Budget Budget STAJUTG Compliance and Organization Registration and Certification Training and Education Reliability Assessment and Performance Analysis Situation Awareness and Infrastructure Security 3.5 50.5 1.5 19.6 85.0 3.3 54.5 1.5 21.7 97.5 4.0 58.0 2.0 23.6 0.5 0.0 0.0 0.0 0.0 0.0 4.0 58.0 2.0 23.6 0.5 0.5 7.5 0.5 4.0 (84.5) Total FTEs Operational Programs 160.0 178.5 88.1 0.0 88.1 (71 .9) Administrative Programs Technical Committees and Member Forums General & AdminlstratM Information Technology Legal and Regulatory Human Resources Finance and Accounting 7.6 18.8 9.0 12.1 3.1 5.7 6.6 17.3 8.2 9.6 3.6 7.0 9.0 15.2 9.0 6.0 3.0 4.7 0.0 0.0 0.0 0.0 0.0 0.0 9.0 15.2 9.0 6.0 3.0 4.7 1.4 (3.6) Total FTEs Administra ti ve Progra ms 56.3 52.3 46.9 0.0 46.9 (9.4) Total FTE~ 216.3 230.8 135.0 0.0 135.0 (81.3) (6.1) (0.1) (~.0) ·A shared FTE is defined as an employee who performs both Statutory and Non-statutory functions. WECC's methodology for budgeting for labor float (turnover, hiring delays, etc.) changed in 2014. In 2013, 15 FTEs were removed from the WECC budget in various departments to budget for labor float. In 2014, those FTEs were added back in and instead, WECC reduced salaries, payroll taxes, retirement contributions, and insurance by 15 percent across the organization to maintain the integrity of FTE values. WECC's average turnover rate for the past few years has been approximately 15 percent. At the bottom of each Statement of Activities in each Program Area, headcount values have been provided in addition to FTE values to provide a more comprehensive picture of actual positions being added compared to the adjustment in FTEs. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 9 . Page 44 of 273 14-05XXX; MDR 094 Attach 01 . . 2014 Business Plan and Budget Introduction 2013 Budget and Projection and 2014 Budget Comparisons Statement of Activities, Fixed Assets Expenditures, and Change in Working Capital 2013 Budget & Projection, and 2014 Budget STATUT ~~~"''-:-'':-'-~j ':f 'i·i!2PJ'W .. 2013 2013 2013 Projection v 2013 Budget 2014 Budget Projection Over{Under) Budget Va riance Variance Funding WECC Funding WECC Assessments Penalty Sanctions Total WECC Funding Membership Dues Federal GraMs SenAces & Software Workshops Interest Miscellaneous Total Funding (A) Expenses Pe1110nnel Expenses Salaries Payroll Taxes Benefits Retirement Costs Total Pe1110nnel Expenses Meeting Expenses Meetings Travel Conference Calls Total Meeting Expe!UIIIs $ $ 40,962,547 2,966,850 43,929,397 $ I $ $ $ $ 869,335 256,630 (66,927) 58,139,890 (15,965) (34,281) (I0,606) $ 7,114,798 $ 26,782,685 24,445,264 1,757,632 3,443,465 1,593,510 31,239,871 1,939,887 3,638,095 1,819,237 7,235,849 12,096,225 774,001 2,129,744 774001 15,773,971 $ (12,349,038) (983,631) (1,313,721) (819,509) $ !15,465,900) (34,529) 8,383 (54,309) !80,455) $ $ 5,830,998 1,975,323 6,214,635 722,829 $ 13,841,654 1,857,522 7,876,507 1,237,323 $ 8,010,656 4,400,446 29,213,452 224,211 $ 10,293,433 $ 66,421,648 I ~8431 957,929 69,000 $ 961,725 1,950,384 118183 3,030,292 !443,310) (2,287,297) $ 2,337,421 182,255 192,630 225,727 $ 2,938,033 $ 53,270,637 $ 3,628,308 23,219,138 996,254 1,942,001 172492 3,110,747 I $ $ $ $ (117,801) 1,661,872 514,494 873,476 1,484,456 114,222 2,472,154 $ 4,387,302 936,072 1,405,454 758,756 $ (1,443,696) $ 13,151,011 $ 26,313,709 $ ~6,956,929) $ I (151,534) !541, 111) I I I $ 65,826,805 $ 12,999,477 ! Change In Aseta $ 11,802,2351 $ 1!,686,9151 $ 15,8~6801 $ 1!!553,4591 $ (4,176,235) 1,253,000 34,000 1,087,000 $ (4,400,446) 1,502,744 11,000 1,650,158 1,461,873 $ (224,211) 249,744 (23,000) 563,158 1,461,873 $ (580,000) 309,487 $ $ (3,596,235) $!10,~43~ 52,827,327 $ (1,039,251) (4,809,181) 35,927 580,000 8,067,584 $ Allocation of Fixed Assets $ (122,778) (457,545) (58,270) (638,593) ! Total Expenses (B) Fixed Asseta Depreciation Computer & Software CapEx Fumiture & Fixtures CapEx Equipment CapEx Leasehold Improvements (33,800) I ~177,904 $ $ (25,331,695) $ (25,365,495) 72,629 (221,911) (3,879) $j27,805,954l I $ $ I 15,630,852 2,933,050 18,563,902 $ $ 885,300 290,911 3879 51,025,092 Total Direct Expenses Other Non-Operating Expen•s $ 13,151,454 4,176,235 18,920,019 $ $ $ $ $ Indirect Expemms $ 2,966,850 43,929,397 5,915,605 Operating Expenses Consultants & Contracts 01!ice Rent 01!ice Costs Professional SI!Nces Miscellaneous Depneciation Total Operating Expenses $ $ 40,962,547 I 2013 Budget v 2012 Budget Over{ Under) $ 1!7,801) $ 2~772,598 136,000 $ 1~7,o54,729l $ 1!51,2241 $ 3,596,235 (943,513) (34,000) (951,000) $ 1 80 JQ-!$~).i~}:l.x~~~~~c(~ .,i>.. - '{;W'"'~.,.., .5 r-~~~~,· -~! . > __.,..;;. _.. ""::'- ~-~-, ... ~_;... .....r... . ~ ---.~ ~-,;. ~- - ....*1 k ~:~l,;_;,.,J: . 15 ~a.~t-;...t}flk~- T.J-.:..·. ,.f!34;£,1J!;ex~~:--;t-:l,;.~~~~ 51,025,092 TOTAL BUDGET (B+C) TOTAL CHANGE IN WORKJNG CAPITAL (A-~) $ FTEs HC 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 66,052,134 ! 216.3 243.0 1!,912.2441 230.8 253.0 15,027,041 $ 1!,91~2441 14.5 10.0 25,638,084 ! j2,41B19461 135.0 135.0 ~5,387,008) $ 2141819461 (81 .3) (108.0) 10 . Page 45 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - Statutory Programs 2014 Business Plan and Budget 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 11 . Page 46 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan Reliability Standards Program Section A- 2014 Business Plan Reliability Standards Program Reliability Standards Program (in whole dollars) 2013 Sltd_g et Total FTEs Increase (l)_tcre_.a §e ) 2014 Budgm 4.0 3.5 0.5 Direct Expenses $ 677,776 $ 597,739 $ (80,037) Indirect Expenses $ 310,317 $ 432,890 $ 122,573 Other Non-Operating Expenses $ lnc(Dec) in Fixed Assets $ (12,790' $ Total Funding Requirement $ 975,303 $ - $ - (7,628) $ 1,023,001 - $ $ 5,162 47,698 Program Scope and Functional Description WECC's standards development activities are divided into two categories: 1. Participation in the NERC Reliability Standards Development Procedure. 2. Development of Western Interconnection Regional Reliability Standards (RRS), Regional Criteria, and Regional Business Practices. WECC's standards development process is overseen by the WECC Standards Committee and is open to participation by all parties interested in providing input during the drafting, comment, and approval processes. Each standard is recommended by vote of a ballot pool formed from the WECC Ballot Body. Standards are balloted electronically during 15-day ballot windows. Upon approval by the ballot pool, standards are forwarded to the WECC Board for approval. Once approved by the WECC Board, the standards are sent to the NERC Board of Trustees for adoption. NERC then files these reliability standards with FERC for approval. The WECC Reliability Standards Development Procedures are also used for the development of WECC Regional Criteria and Regional Business Practices. Regional Criteria are requirements that are approved by the WECC Board. They do not require NERC or FERC approval. WECC develops its Regional Criteria to meet the requirements of NERC Fill-in-the-Blank Standards. 3 Regional Business Practices are requirements that are approved by the WECC Board. They do not require NERC or FERC approval. WECC develops its Regional Business Practices to establish consistency among WECC member entities with respect to specific business practices, technical procedures, documentation procedures, or administrative procedures. 3 Fill-in-the-Blank Standards are reliability standards developed by NERC that require the Regional Reliability Organizations to develop criteria for use by users, owners, or operators within the region. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 12 . Page 47 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan Reliability Standards Program 2014 Key Assumptions • Integration of renewable resources may require new or modified NERC Reliability Standards. • WECC will continue to rely on stakeholder volunteers for the staffing of NERC Standards drafting teams. • WECC Standards staff will take an active role in the coordination and communication of NERC Standards drafting teams' activities to the Western stakeholders. • WECC expects that a significant proportion of the work required to develop regional standards, regional criteria, and regional business practices will continue to be performed by voluntary stakeholder participation. • Depending on the final treatment of the NERC Fill-in-the-Blank Standards, it may be necessary to develop one or more RRSs to address any regional obligations in this area. 2014 Goals and Key Deliverables • Ensure the Western Interconnection perspective is represented in NERC continent-wide Reliability Standards. • Ensure that the WECC Standards Department meets the needs of the Western stakeholders in the area of RRSs, Regional Criteria, and Regional Business Practices. • Ensure that WECC members and stakeholders are informed and engaged in the NERC Standards development efforts. • Provide leadership and guidance to the Western Interconnection efforts to advance the NERC Results-Based Standards initiative. • Undertake regular outreach to keep stakeholders informed about standards development and the NERC Results-Based Standards initiative. Provide support to NERC's informal outreach efforts. • • Ensure that WECC's procedures are developed to comply with the requirements of the NERC Fill-in-the-Blank Standards. • Triage NERC Standards development projects and provide timely analyses to WECC members. • Continue updates and enhancements to the WECC Standards Outreach Web page. • Facilitate and support the activities of the WECC Standards Committee. Funding Sources and Requirements- Explanation of Increase (Decrease) Funding Sources (Other than Electric Reliability Organization (ERO) Assessments) • • Assessments are offset by the allocation of $133,000 in penalty sanctions received by WECC on or prior to June 30, 2013. Interest revenue is allocated based on FTEs. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 13 . Page 48 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2014 Business Plan Reliability Standards Program Personnel Expenses • Personnel Expenses decrease by $43,000 primarily due to a 15 percent reduction in salaries, payroll taxes, insurance, and retirement costs in 2014 to budget for labor float. Meeting Expenses • Total Meeting Expenses decrease by $14,000, primarily due to lower attendance at NERC Board of Trustees meetings. Indirect Expenses • Indirect Expenses are allocated based on FTEs. The reliability standards allocation increase is due to the creation of the new entity. The percentage of Standards FTEs to total WECC FTEs increases in 2014 as a result of the reduction in total WECC FTEs. Other Non-Operating Expenses • Not applicable. Fixed Asset Additions • Not applicable. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28,2013 . 14 . Page 49 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan Reliability Standards Program Reliability Standards Program Funding sources and related expenses for the Reliability Standards section of the 2014 Business Plan and B et are shown in the table below. 21113 Budget Funding WECC Funding WECC Assessments Penalty Sanctions Total WECC Funding $ Membership Dues Federal Grants SBnlices & So!tware Workshops Interest Miscellaneous Total Funding (A) Expenses Personnel Expenses Salaries Payroll Taxes Benefits Retirement Costs Total Personnel Expenses ! 903,967 64,888 96!!z855 $ 6,363 85 975,303 $ $ Meeting Expenses Meetings Trawl Conference Calls Total Meeting Expenses $ $ Operating Expenses Consultants & Contracts Office Rent Office Costs Professional SBnlices Miscellaneous Depreciation Total Operating Expenses 2013 Projection ! 903,967 64,888 968,855 $ 5,739 (1,249) 973,345 $ 464,771 34,916 60,156 40,139 599,982 $ 14,754 43,000 11,400 69,154 $ $ $ Variance 2013 Projection v 2013 Budget 0\er(Under) 2014 Budget $ $ $ $ $ (624) (1,334) j1,958l 447,768 30,138 48,499 30,138 556,543 $ 528 28,360 4,188 33,076 $ $ $ $ (3,230) (85} j48,821l $ $ 7,170 ~5061 $ $ $ (113,787) 68,281 ! 926,482 14,754 43,000 11,400 69,154 8,640 $ $ $ $ 790,180 133,169 923,349 3,133 439,541 32,972 48,728 30,206 551,447 $ (25,230) (1,944) (11,428) (9,933} (48,5351 Variance 2014 Budget v 2013 Budget 0\er(Under) $ $ (1,470) $ $ (17,003) (4,778) (11,657) (10,001} {43,4391 (14,226) (14,640) (7,212} {36,078} $ 8,120 (520) $ 8,640 $ 7,170 $ {1,4701 $ 8,120 $ !5201 $ 677,776 $ 627,771 $ {50,0051 $ 597,739 $ (!0,0371 Indirect Expenses $ 310,317 $ 256,802 $ !53,5151 $ 432,890 $ 122,573 Other Non-Operating Expenses ! Total Direct Expenses ! $ $ $ Total Expenses (B) $ 988,093 $ 884,573 ! 1103,5201 ! 1,030,629 $ 42,536 Change In Assets $ j12a7901 $ 88,771 ! 1011561 ! 1104,14!1 $ 1!1,3571 $ (12,790) $ (5,048) $ 7,742 $ (7,628) $ 5,162 j12,7901 $ Fixed Assets Depreciation Computer & Software CapEx Furniture & Fixtures CapEx Equipment CapEx Leasehold lmp!'O'oerTlents Allocation of Fixed Assets :.~,~~~~~~t!~~~~">';C~~p:.we.!t:~i~~;!;tj"-(:i WJ$11'~-- 879,525 $ 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . .:._.~·· -~" 975,303 93,819 3.3 4.0 1,023,001 (95.7781 ! 931819 (0.3) I 1!!.5191 4.0 4.0 I 47,698 $ 1!6,5191 0.5 15 . Page 50 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2013 Business Plan Compliance Monitoring and Enforcement Compliance Monitoring and Enforcement and Organization Registration and Certification Program eoliiplia~ci' Nionitc>rin9 ·alia ·entott:ijffi~'M 'iii\a bt9antiall8'rf'Re9iStra1iori"lria Certification Program (in whole dollars) 2'0'1'~ B.utlg~t Total FTEs Direct Expenses 50.5 $ 8,931,897 4,477,429 Increase (mf«.rease,) 2014-=S.uj:Jg:eJ 58.0 $ 8,592,053 $ 6,276,897 7.5 $ (339,844\ Indirect Expenses $ Other Non-Operating Expenses $ $ $ lnc(Dec) in Fixed Assets $ (250,045' $ (105,602) $ 144,443 Total Funding Requirement $ $ 1,604,067 13,159,281 $ 14,763,348 $ 1,799,468 Program Scope and Functional Description Compliance monitoring and enforcement is essential to WECC's mission as a Regional Entity, and to its fulfillment of the requirements of the WECC/NERC Delegation Agreement. This agreement delegates compliance monitoring and enforcement authority in the United States portion of the Western Interconnection to WECC. WECC's Compliance Monitoring and Enforcement Program (CMEP) is implemented by WECC Compliance staff members who are independent of all users, owners, and operators of the BES. All approved and effective mandatory reliability standards are monitored and enforced under the CMEP, including standards made mandatory pursuant to FERC Order 693, 4 and the Critical Infrastructure Protection (CIP) standards under FERC Order 706. 5 Under the CMEP, WECC undertakes the following activities: 1) Recommends the registration of entities for applicable functions to NERC. WECC facilitates the registration process, ensures that there are no omissions in the registration of entities in the Western Interconnection, and helps resolve registration disputes. 2) Monitors Registered Entities' compliance with reliability standards using the following methods: Compliance Audits - Conducts either on-site or off-site audits of all Registered Entities. Self-Certification- Reviews Registered Entities' annual certifications of compliance or non-compliance with standards. Spot-Checks- Verifies compliance with specific standards in connection with reviews of self-certification, or in scheduled CIP spot checks. 4 Mandatory Reliability Standards for the Bulk-Power System, Order No. 693, 72 FR 16,416 (Apr. 4, 2007), FERC Stats. & Regs. ,-r 31,242 (2007). 5 Mandatory Reliability Standards for Critical Infrastructure Protection, Order No. 706, 73 FR 7368 (Feb. 7, 2008), 122 FERC ,-r 61,040 (2008). 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 16 . Page 51 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2013 Business Plan Compliance Monitoring and Enforcement Compliance Investigations- Investigates violations; usually as the result of a system event or disturbance, but possibly from other sources. Self-Reports - Reviews and follows up on reports from Registered Entities' continuous monitoring efforts by their internal compliance programs. Periodic Data Submittals - Reviews monthly and quarterly reports that are submitted in compliance with certain standards. Exception Reporting - Requires reports on a small set of standards when violations occur. Complaints - Investigates whether a violation has occurred when the WECC Compliance staff is alerted to a potential violation. 3) Conducts enforcement activities that include: Mitigation Plans - Reviews, monitors, and verifies mitigation plans filed by Registered Entities to correct violations. Penalty Calculations- Determines, as appropriate, proposed penalties for alleged violations. Settlement Negotiations- Conducts settlement negotiations with Registered Entities when requested. The Compliance function also undertakes the following processes in support of its activities: System Events - Reviews certain events and encourages registered entities to perform an internal assessment of compliance for those events. Also, considers self-reporting violations and other compliance monitoring processes as appropriate. Entity Impact Evaluations (formerly known as Risk-Based Assessments) ­ Conducts a review and assessment of Registered Entities to determine scope of audits. Lessons Learned and Best Practices - Develops lessons learned from all monitoring and enforcement activities and communicates these during interactions with Registered Entities: for example; during audits, reviews of Self­ Reports, or reviews of proposed or completed Mitigation Plans. Hearings and Appeals- Participates in any hearings and appeals as needed. Outreach and Education - Manages an active educational program, holding numerous in-person meetings and monthly calls in an effort to educate Registered Entities on compliance issues and to improve their compliance programs. The Hearings budget is included in the Compliance budget and is reflected in the table on page 22. For structural and governance purposes, the Hearings function is discussed separately in this section. Compliance in Alberta, British Columbia, and Mexico Alberta and British Columbia, Canada; and Baja California Norte, Mexico are all part of the WECC footprint, and have adopted or are adopting mandatory reliability standards 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 17 . Page 52 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2013 Business Plan Compliance Monitoring and Enforcement based on FERC-approved standards. WECC has entered into agreements with the Alberta Market Surveillance Administrator (MSA), the British Columbia Utilities Commission (BCUC), and Mexico's Comisi6n Federal de Electricidad (CFE) under which WECC performs compliance monitoring activities to help assure reliability across international borders within the Western Interconnection. These monitoring activities began during 2010, increased considerably during 2011 and 2012, and will continue to increase in 2013 and 2014, primarily due to audits in CFE that are scheduled to begin this year. Reliability Management System (RMS) In 1996, the Western Systems Coordinating Council (WSCC)6 created the RMS, a contract-based compliance enforcement mechanism. The RMS grew to encompass 14 criteria. In the U.S., since all RMS Criteria have been adopted either as RRSs or NERC Standards, the RMS was terminated in 2011. The RMS in British Columbia was terminated in 2010 as the province adopted equivalent standards. The adoption of Alberta Standards is expected to be completed during 2013, after which the RMS will be terminated in Alberta. The CFE (Baja California, Mexico) is also in the process of adopting mandatory standards, with highest priority given to standards corresponding to RMS Criteria. Governmental entities in Alberta and Mexico will ultimately decide when to replace all RMS criteria with applicable standards and terminate the RMS. WECC anticipates that the impact of RMS Criteria on resources will be negligible. 2014 Key Assumptions WECC Compliance is incorporating Key Assumptions relevant to 2014 from the 2014 NERC Business Plan and Budget, Exhibit A: Common Assumptions, 7 used by NERC and the Regional Entities in formulating 2014 budgets. At this time the impact of many of the Assumptions is speculative; therefore, additions to the 2014 budget based on the Assumptions are not being proposed. If it becomes evident that impacts emerge that cannot be absorbed by current staffing levels and the existing proposed 2014 budget, then Compliance may seek approval for additional funds. The most significant assumptions (in bold) are from the Common Assumptions, and WECC's current assessment of the impact these assumptions may have is detailed below: "External factors will continue to affect both resource needs and allocation ... ": "The final definition of the BES, as well as the number of exception requests." Depending on the outcome and timing of these initiatives, Compliance may register and monitor additional Registered Entities - or de-register and monitor fewer. At this time it is uncertain what Compliance resources will be required to manage the filings by Registered Entities claiming inclusions and exclusions under the new BES definition as well as requests for exceptions. WECC did not 6 The WSCC was one of the companies and regional transmission associations that merged to form WECC. 7 Shared Business Plan and Budget Assumptions: NERC and the Regional Entities, 2014-2016 Planning Period, provided in Exhibit A to the NERC 2014 Business Plan and Budget. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 18 . Page 53 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2013 Business Plan Compliance Monitoring and Enforcement budget forBES inclusion, exclusion, or exception processing in the 2014 budget due to the uncertainty and timing of the BES definition approval and of the processing requirements. Additionally, WECC carries adequate reserve levels to fund the work if the need arises. Compliance Monitoring and Enforcement and Organization Registration and Certification Program: Compliance and Enforcement "Improvements in consistency among Regional Entities, and registered entities are expected from an improved centralized compliance, registration, analysis, and tracking system. A significant multiyear investment will be required to develop and implement the system." It is uncertain what impact this may have on WECC's Program Administration and how widely Regional Entities will be expected to alter their current practices, equipment, and programs; what the associated costs might be; and how they might be allocated. To the extent this initiative succeeds, it could provide further efficiencies in WECC's interactions related to reporting data and sending information to NERC. In addition, during 2014 (as in every year), WECC Compliance is expected to respond to FERC directives and orders as well as to significant new initiatives not currently identified that may be generated by NERC. An uncertainty that may result in significant impact on resources is the transition from CIP version 3 standards to CIP version 5. Possible impacts include additional workload, need for increased outreach and training, and the actual transition and associated guidance that may be issued by NERC. 2014 Goals and Key Deliverables • Monitor and enforce compliance with mandatory standards in accordance with the WECC/NERC Delegation Agreement, including the Rules of Procedure and the CMEP within the U.S. and, with respect to non-U.S. jurisdictions, monitor compliance in accordance with the approved memoranda of understanding with Canadian and Mexican authorities. • Ensure all auditors meet NERC auditor training requirements. • Work with Registered Entities within the WECC Region to promote a strong culture of compliance and reliability improvement. Identify key areas needing improvement and implement educational efforts to improve compliance in those areas, based on Compliance program results and system events. • Identify where existing NERC Reliability Standards can be improved or clarified. • Use technology effectively to collaborate and share information. • Use resources effectively and efficiently. • Participate in and represent the Western Interconnection on issues that will impact WECC in NERC and regional initiatives for example: refining risk-based monitoring, streamlining enforcement processing, and monitoring information technology initiatives. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 19 . Page 54 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2013 Business Plan • Compliance Monitoring and Enforcement Perform CMEP tasks that are estimated based on 2012 and 2013 data, and expected impact from the 2013-2015 Assumptions. These estimates may change as more information becomes available: o Conduct 90 assessments and make recommendations based on current rules in effect relating to the registration of entities. o Conduct 21 on-site audits of Operations and Planning standards. o Conduct 20 on-site audits of Cyber Security standards. (Note that due to transition to new versions of CIP standards, CIP audits may be more time­ consuming than they have been in the past.) o Conduct 130 off-site audits (for both Operations and Planning, and Cyber Security Standards). o Process 15,000 self-certification forms. o Process 500 self-report forms. o Perform 15 spot-checks. o Process 625 violations. o Review 750 mitigation plans. o Review 325 completed mitigation plans. o Conduct three Compliance Investigations. o Validate, track, and monitor Technical Feasibility Exception (TFE} requests. If proposed changes to the TFE process are adopted by FERC, the administrative burden will be less than in the past but auditors still will be required to validate TFEs. o Complete 35 reviews or compliance assessments relating to Event Analysis. Funding Sources and Requirements - Explanation of Increase (Decrease) WECC is the largest of the Regional Entities with 466 Registered Entities that include 1,239 registered functions (according to the NERC Registry as of May 31, 2013). The Compliance Department manages the CMEP processes for every Registered Entity and registered function in the Western Interconnection. The resource needs for the registration, audit, investigations, and enforcement activities for 2014 are expected to increase minimally over 2013. This estimation is based on: • actual workload in 2012; • experience gained in 2013; • assumptions in the 2013 WECC Business Plan and Budget; and • assumptions in the 2014 WECC Business Plan and Budget. Funding Sources (Other than ERO Assessments) • Assessments are offset by the allocation of $1.9 million in penalty sanctions received by WECC on or prior to June 30, 2013. • Interest revenue is allocated based on FTEs. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 20 . Page 55 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2013 Business Plan Compliance Monitoring and Enforcement Personnel Expenses • FTEs increase by 7.5 due to the addition of one position and the methodology change for budgeting for labor float. • Salaries decrease by $249,000 primarily due to a 15 percent reduction for labor float. • Payroll Taxes decrease by $48,000 with Salaries. • Benefits increase by $38,000 primarily due to a 20 percent increase in insurance premiums and additional employee training. Meeting Expenses • Travel increases by $94,000 due to an increase in audit engagements as well as employee training opportunities. Operating Expenses • Consultants and Contracts decrease by $45,000 due to the departure of one contractor and fewer significant cases requiring outside expertise. • Office Costs decrease by $44,000 primarily due to software enhancements completed in 2013. Indirect Expenses • Indirect Expenses are allocated based on FTEs. The Compliance allocation increases by $1.7 million due to the creation of the new entity. The percentage of Compliance FTEs to total WECC FTEs increases in 2014 as a result of the overall reduction of total WECC FTEs. Other Non-Operating Expenses • Not applicable. Fixed Asset Additions • Not applicable. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 21 . Page 56 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2013 Business Plan Compliance Monitoring and Enforcement Compliance Enforcement and Organization Registration and Certification Program Funding sources and related expenses for the Compliance Enforcement and Organization Registration and Certification section of the 2014 Business Plan are shown in the table below. ~~~~~~~~~Variance 2013 Projection v 2013 Budget Owr(Under) 2013 Projection $ 11,696,264 $ 11,696,264 $ $ 936,241 936,241 $ 12,632,505 ! $ Funding WECC Funding WECC Assessments Penalty Sanctions Total WECC Funding $ Membership Dues Federal Grants Senices & Software Workshops Interest Miscellaneous Total Funding (A) 433,750 91,802 1224 $ 13,159,281 433,550 81,335 (20,948} $ 13,126,442 ! $ 5,019,223 $ $ 370,015 757,788 314,433 6,461,439 $ Expenses Personnel Expenses Salaries Payroll Taxes Benefits Retirement Costs Total Personnel Expenses Meeting Expenses Meetings Trawl Conference Cells Total Meeting Expenses Operating Expensas Consultants & Contracts Olllce Rent Olllce Costs Professional Senices Miscellaneous Depreciation Total Operating Expen88s Total Direct Expenses Variance 2014 Budget 2013 Budget ! 1~632,505 $ $ 452,g85 872,000 64,550 1,389,535 $ 470,000 $ $ $ 494,423 1,000 115,500 5,154,544 390,471 649,760 348,859 6,543,634 464,585 703,462 23,806 1,191,673 700,363 3,619 392,059 $ $ I $ $ 1,080,923 $ 82,730 1,178,771 $ (200) (10,467) (22,172} (32,839} v 2013 Budget 2014 Budget 10,955,928 1,930,952 12,886,880 o.er(Under) $ $ (740,336) 994 711 254,375 4,375 (46,376) (1,224} 211,150 438,125 45,426 ! 13,370,431 $ $ 4,769,767 322,315 795,563 322,315 $ (249,456) {47,700) 37,795 7,882 ! 6~9,960 I ~1,479) 11,600 (188,518) (40,944) (197,8621 $ $ $ 462,503 966,340 41,780 1,470,623 $ 9,518 94,340 (22,770) 81,088 230,363 3,619 {102,364) (1,000) $ 424,800 $ (45,200) 135,321 20,456 (106,008) 34426 82,195 450,670 (43,753) (1,000) (32,770) 97,848 $ 38,000 911,470 $ (79,500) (169,4531 $ 8,931,897 $ 8,91~078 $ (17,8191 ! 8,592,053 I (339,8441 Indirect Expenses $ 4,477,429 $ ~306,377 I (171,052) s 6,276,897 s 1,799,488 Other Non-Operating Exp&11$8S $ $ Total Expenses (B) $ 13,409,326 ! Change in Assets s s Fixed Assets Depreciation Computer & Software GapEx Furniture & Fixtures CapEx Equipment GapEx Leasehold lrnprowments Allocalion of Fixed Assets 1250,0451 (115,500) 50,000 $ (164,545) I 13,220,455 (188,871) s $ 156,032 $ (82,730) 50,000 $ (64,649) $ ! ! 32,770 $ 99,896 1~888,950 $ 1,459,624 11.498,5191 $ 11,248,4741 {36,000) 10,000 79,500 (40,000) 31,000 31,000 (110,602) $ s 73,943 ~~~~~J:;~,~L~!~:!a!:~~*t J !-,'!;tf! ",-, ·\.-.~~V:~7fl_ , ,_~-,. .-.~... 132,666 '-~iiil:i:'"! ~l· :-.~~ - wJ1&\~U-~.a'fr§'·1#12it?,~ 2 .. ·a TOTAL BUDGET (B+C) TOTAL CHANGE IN WORKING CAPITAL (A-a-C) FTEs HC 13,159,281 s $ 50.5 57.0 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 13,103,076 23,366 54.5 57.0 (56,2051 s 23,366 4.0 1,604,087 14,763,348 ! 11,392,91!1 58_0 58.0 $ !1 13S9171 7.5 1.0 22 . Page 57 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2013 Business Plan Hearings Hearings Background The WECC 2014 budget for Hearings is reflected in the following table. These expenditures are included in the Compliance Program Statement of Activities. Hearings (in whole dollars) 2013 Budget 2014 Budge.t - - Total FTEs Direct Expenses $ Indirect Expenses $ lnc(Dec) In Fixed Assets $ Total Funding Requirement $ 14 550 14,550 lncreaat (Decrease) - $ - $ $ - $ $ $ $ $ (14,550) (14,550) Program Scope and Functional Description The role of the Hearing Officer is to coordinate and conduct evidentiary hearings of disputes and then issue initial decisions to the Hearing Panel for approval. In cases of particular complexity or significant regional interest, the Hearing Panel may conduct or participate in the evidentiary hearing. The Compliance Hearing Body (CHB) is comprised of volunteers from the WECC Board, WECC members, and consultants. The Hearing Panel will be drawn from a pool of individuals on the CHB. Legal Department staff will support the Hearing Officer and Hearing Panel and those staff members will be screened from compliance matters when a hearing is pending. 2014 • • • Key Assumptions WECC will maintain current operations. NERC expectations in terms of hearing requirements will be clearly defined. WECC does not anticipate any hearings in 2014. 2014 Goals and Key Deliverables • Provide independent, fair, efficient, and cost effective support to the WECC Hearing Panel. • Meet all timelines identified in the WECC Hearing Procedures. • Maintain hearing records. • Manage the hearing budget. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 23 . Page 58 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2014 Business Plan Reliability Assessment and Performance Analysis Reliability Assessment and Performance Analysis Program Reliability Assessment and Perfonnance Analysis (in whole dollars) 2013 Budget 19.6 Total FTEs Increase (Decrease} 2-014 Bud,get 23.6 4.0 Direct Expenses $ 5,408,087 $ 6,516,514 $ 1,108,427 Indirect Expenses $ 1,734,819 $ 2,554,048 $ 819,229 Other Non-Operating Expenses $ $ - lnc(Dec) in Fixed Assets $ 220,096 $ (16,516 $ (236,612) Total Funding ReQuirement $ 7,363,002 $ $ 1,691,044 - 9,054,046 $ - Program Scope and Functional Description WECC staff conducts a variety of studies and assessments essential to the reliable planning and operation of the BES in the Western Interconnection. In addition, WECC staff compiles and distributes planning data and information that is used by WECC members to aid in local planning studies. These integrated planning efforts enhance WECC's overall ability to participate in, and respond to, the major planning and public policy issues emerging both in the Western Interconnection and nationally. The Reliability Assessment and Performance Analysis (RAPA) budget supports the efforts of the Transmission Expansion Planning function, the Planning Services function and the Reliability Assessments function. Transmission Expansion Planning WECC assists with fulfilling the FERC Order 890 requirement for regional transmission planning cooperation in the Western Interconnection through its Transmission Expansion Planning (TEP) activities. Specifically, WECC provides credible data, tools, and analysis about the future of the Western Interconnection. This work is conducted in an open, public process led by the WECC Transmission Expansion Planning Policy Committee (TEPPC). WECC's TEP activities are partially funded by a DOE grant through 2014 under the Regional Transmission Expansion Planning (RTEP) project. TEPPC is a WECC Board Committee of 20 members representing all classes of stakeholders with representation from all geographic subregions of WECC. TEPPC and its subgroups work closely and coordinate with Western Interconnection state, provincial, and federal government entities. Transmission Expansion Planning's deliverables are: • • • Oversee and maintain a public database for production cost and related analysis; Develop and implement Interconnection-wide expansion planning processes; Guide and improve the economic analysis and modeling of the Western Interconnection and conduct transmission studies; and 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 24 . Page 59 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan • Reliability Assessment and Performance Analysis Prepare Interconnection-wide transmission plans consistent with applicable NERC and WECC Reliability Standards. Planning Services The Planning Services function, working with the Planning Coordination Committee and its subcommittees, collects and compiles information needed to develop planning resources for WECC member entities. These resources include interconnection-wide base case models, study assessments, and transmission facility maps. In addition, Planning Services provides power system subject matter expertise to industry activities such as NERC Standards development and BES Definition exception request processing. Planning Services is proposing a one-time expenditure of $400,000 in 2014 for further development of the composite load model and to develop Remedial Action Scheme (RAS) and relay models for use in power flow and stability simulation programs. These efforts include contracting with subject matter specialists who can provide expertise and with vendors that can provide tools needed to develop equipment models. Planning Services' deliverables are: • Power Flow and Stability Base Cases. • Annual Study Program Report. • WECC Transmission Maps (existing and planned). • Project Coordination and Project Rating Review Process Logging. • Path Rating Catalog. • Dynamic Model Development and Validation. • BES Definition exception request processing. • Support for all WECC groups under the PCC except the Loads and Resources Subcommittee (LRS). • Monitor and support the activities of the NERC Planning Committee, the Systems Analysis and Modeling Subcommittee, and associated work groups. Reliability Assessments The Reliability Assessments function, working with the PCC's LRS, creates and analyzes supply and demand assessments for the Western Interconnection. The mission of the Reliability Assessments group is to produce and distribute credible data, information, and analyses. The Reliability Assessments group creates reliability adequacy assessments that include the Power Supply Assessment, NERC seasonal assessments, and the Long-Term Reliability Assessment. In addition, the Reliability Assessment function has been appointed to oversee the analysis of data related to system outages, compliance violations, system performance, and planning data. This data will be analyzed to identify trends and potential system 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 25 . Page 60 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan Reliability Assessment and Performance Analysis vulnerabilities and will be compiled in the annual WECC State of the Interconnection Report. Reliability Assessments' deliverables are: • NERC Long-Term Reliability Assessment. • Seasonal assessments (summer and winter). • NERC Probabilistic Reliability Assessment. • WECC Power Supply Assessment. • Support of the LRS. • Annual State of the Interconnection Report. • NERC Transmission Availability Data System (TADS}, Generator Availability Data System (GADS), and Demand Response Availability Data System (DADS) filing verification and submittal. • Monitor and support the activities of the NERC Reliability Assessment Subcommittee, the Performance Analysis Subcommittee, and associated work groups. 2014 New Initiatives and Goals The PCC began implementing the Base Case Coordination System (BCCS) in 2013 and implementation efforts will continue into 2014. 8 Efforts will be focused on populating the database and ensuring that it produces credible base cases. Extensive WECC member outreach and training associated with the BCCS is also planned. Ongoing costs related to database management and software updates are expected to begin in 2015, and are expected to total approximately $85,000 annually. Funding Sources and Requirements- Explanation of Increase (Decrease) Funding Sources (Other than ERO Assessments) • Assessments are offset by the allocation of $786,000 in penalty sanctions received by WECC on or prior to June 30, 2013. • WECC will receive $3.6 million in DOE grant funding for the RTEP project. The funds directly offset expenditures related to the RTEP project. • Interest revenue is allocated based on FTEs. Personnel Expenses • Salaries increase by a net of $86,000 primarily due to an increase of four FTEs. Salaries were also reduced by 15 percent due to the change in budgeting for labor float. 8 The BCCS will be a Web-accessible, centralized database that automates existing processes. It will provide a central location for maintaining base-case information. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 26 . Page 61 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan • Reliability Assessment and Performance Analysis Benefits increase by $59,000 due to an estimated 20 percent increase in insurance premiums. Meeting Expenses • Meetings decrease by $46,000 due to a reduction in the number of meetings and the expected number of participants. • Travel increases by $14,000 primarily due to an increase in FTEs and increased staff attendance at path rating study meetings. Operating Expenses • Consultants and Contracts increase by $840,000. o Consultants and Contracts related to the RTEP grant increase by $700,000 due to additional activities being undertaken as part of the grant extension through 2014. o Consultants and Contracts in non-grant activities increase by $140,000. This increase is primarily related to the continued development of the BCCS, and additional model development and system validation efforts of the Model Validation Work Group (MVWG). • Office Costs increase by $52,000 primarily due to software licensing fees for the Long-Term Planning Tool used by RTEP. Two years of licensing fees were included in the original purchase price. 2014 will be the first year these fees are paid as a renewal. • Professional Services decrease by $30,000 due to the elimination of Non­ Affiliated Director fees associated with the RTEP grant. • Depreciation was under-budgeted in 2013. Depreciation increases by $143,000 in 2014 to more accurately reflect actual depreciation. Indirect Expenses • Indirect Expenses are allocated based on FTEs. The Reliability Assessment and Performance Analysis Program allocation increases by $762,000 due to the creation of the new entity. The percentage of RAPA FTEs to total WECC FTEs increases in 2014 as a result of the overall reduction of total WECC FTEs. Other Non-Operating Expenses • Not applicable. Fixed Asset Additions • Cap Ex increases by a net $64,000, primarily due to the acquisition of load forecasting software for the RTEP grant and the allocation of Fixed Assets from Administrative Services areas. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 27 . Page 62 of 273 14-05XXX; MDR 094 Attach 01 . . Reliability Assessment and Perfonnance Analysis Section A- 2014 Business Plan Reliability Assessment and Performance Analysis Program Funding sources and related expenses for the Reliability Assessment and Performance section of the 2014 Business Plan are shown in the table below. ..;...,... Funding WECC Funding WECC Assessments Penslty Sanctions Total WECC Funding $ 3,834,675 $ 3,834,675 $ $ 362,755 ~197,430 362,755 $ ~ 197,430 ! $ 3,129,529 2,664,502 ! Interest &penses PenonneiExpenses Salaries Payroll Taxes Benefits Retirement Costs Total Penonnel Expenses Meeting Expenses Meetings TIB\el Conference Calls Total Meeting Expenses Operating Expanses Consultants & Contracts 01lice Rent Office Costs Professional Sen.ices Miscellaneous Depreciation Total Operating Expenses Total Direct Expenses Indirect Expenses 35,569 474 $ 7,36;002 31,396 (7,4021 $ &,885,925 $ 1,928,608 142,732 237,122 133,061 $ 2,441,523 $ 3,628,308 (4,173) 18,484 (67,366) 422,943 ! 35~5n 498,779 (17,085) (4741 836,797 ! (4n,om $ 8,199,799 $ $ 2,024,098 153,356 250,306 153,657 $ 2,581,417 $ 95,490 10,624 13,184 20596 139,894 $ 2,014,830 134,116 296,187 134 116 $ $ 2,579~ ! $ $ $ $ $ 65,065 148,800 30,750 244,615 $ (46,358) 13,900 (2,250) (34,7081 $ 3,368,000 $ 840,459 s ! (28,279) (37,409) (4,4541 (!0,142) $ 2,527,541 $ 1,842,698 $ (684,843) 61,300 30,000 119,326 8,563 $ 58,026 (21,437) 86,222 (8,616) 59,065 1 055 137,726 52,350 (30,000) 113,e50 142,600 211 000 68,400 163,676 s 2,687~1 $ 2,134~ ! 95,276 ~9781 $ ~~850 $ 1,~409 ! 5~087 $ ~~861 ! (483,228) $ 6,516,514 ! 1,108,427 $ 1,7~819 ! ! (17,7991 ! ~554,048 ! 819,229 1,717,020 i $ $ 7,142,906 $ &,641,881 $ (501,025) $ Change in Alset& $ s 244,045 $ 23,949 s Fixed Aseets Depreciation Computer & Software CapEx Furniture & Fixtures CapEx Equipment CapEx Leasehold lmpro~ements 2201096 (68,400) (163,676) 329,260 360,000 $ (71,504) $ (33,751) 37,753 9,070,562 187017631 s $ (211,000) 239,487 (95,276) (30,740) $ i $ Total &panses (B) Allocation of Fixed Assets $ Q: 18761 $ Other Non.Oparatlng Expanses 3,767,309 785,698 4,553,007 (465,027) 83,144 97,491 28,546 209,181 $ 111,423 134,900 33,000 279,323 Variance 2014 Budget v 2013 Budget Owr(Under) 2014 Budget 2013 Projection Membership Dues Federal Grants Sel'\ices & Software Wor11shops Miscellaneous Total Funding (A) Variance 2013 Projection v 2013 Budget Owr(Under) 2013 Budget $ (45,003) 1,927,656 1 1109018591 (142,600) (120,513) $ 26,501 ~\~~.~~~~:~~~~:JW»l~=&~··Z!.:I~f~!'~sdlllil;i-·&f~~~~:-~~~~:~13i.S~~~~ TOTAL BUDGET (B+C) TOTAL CHANGE IN WORIONG CAPITAL (A.S.C) FTEs HC $ s 19.6 24.0 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . &,n3,714 7,363,002 112,212 21.7 24.0 (589,288) s 112,212 2.1 9,054,046 s (!54,247! 23.6 23.0 1,691,044 $ j8541247l 4.0 (1 .0) 28 . Page 63 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan Training, Education, and Operator Certification Training, Education, and Operator Certification Program Training, Education, and Operator Certification {in whole dollars) Increase 2013 Bu~,pt 1.5 Total FTEs (O$crea~) 2014 Budget 0.5 2.0 Direct Expenses $ 427,889 $ 496,262 $ 68,373 Indirect Expenses $ 110,851 196,829 $ 85,978 Other Non-Operating Expenses $ lnc{Dec) in Fixed Assets $ {5,482) $ (3,814) $ 1,668 Total Funding Requirement $ 533,258 $ 689,277 $ 156,019 - $ $ - $ - Program Scope and Functional Description The Training Department provides education and training for system operators and schedulers. The WECC training staff develops the annual training curriculum with the assistance of the Operations Training Subcommittee (OTS). These training sessions will primarily be held at the Salt Lake City Training Center, with the balance hosted by WECC members. The Training Department also provides two System Overview Workshops each year. These two-day workshops are designed for those who have not been directly involved in day-to-day power system operations and are interested in better understanding this aspect of the power industry. The Training Department and the OTS organize and host an annual Train-the-Trainer workshop. This workshop is targeted at training staff from WECC members and includes presentations from industry training experts. In addition, WECC's Training Department organizes and hosts the Systematic Approach to Training (SAT) Instructor's Course. This week-long course is designed to assist WECC members' training staff to design, develop, and implement training programs. The SAT also provides individual training activities to assist training staff in meeting the requirements in the NERC Reliability Standard PER-005. 2014 Key Assumptions • Attendance during 2012 continued to decline. Revenue budget for 2014 is based on actual attendance from 2012 training sessions. Early indications in 2013 show an increase in attendance for the first few classes. With this increased attendance trend in 2013, coupled with improvements to the content of the training sessions, WECC is optimistic that training attendance in 2014 will continue to trend upward. • There are no significant changes in operator certification continuing education unit requirements for 2014. • The Training, Education, and Operator Certification program area is self-funded in 2014. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 29 . Page 64 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan • Training, Education, and Operator Certification One additional FTE will be added in 2014 to support expanded use of a Dispatcher Training Simulator, examination of computer-based training, and support of corporate training opportunities. The primary responsibility of this position will be to develop the training scenarios for simulation exercises. This position will also be responsible for developing, updating, and delivering, where appropriate, the WECC training programs for electric utility operations personnel (System Operators, Power Schedulers, and Sub-transmission Operators) and providing a contingency plan for backup instructor. 2014 Goals and Key Deliverables • Facilitate sound decision making to improve reliability by providing high-quality operator training through the WECC-sponsored Training Program, to include: o Review and revise curriculum as needed; o Support the Continuing Education Program for system operators requiring NERC Certification; o Expand the use of the simulator and practical Western Interconnection­ specific training. This will include creation and implementation of simulator cases that are specific to the Western Interconnection; and o Evaluate member feedback and concerns and address through training program improvements. • Ensure the Western Interconnection is represented in reliability matters by participating in the NERC Personnel Subcommittee and other industry forums. Funding Sources and Requirements - Explanation of Increase (Decrease) Funding Sources (Other than ERO Assessments) • Assessments are offset by the allocation of $67,000 in penalty sanctions received by WECC on or prior to June 30, 2013. • Workshop revenue increases by $68,000 due to the increase in the total number of sessions and a preliminary estimate of operators scheduled to attend training sessions. • Interest revenue is allocated based on FTEs. Personnel Expenses • Personnel Expenses increase by a net $50,000 due to a 0.5 increase in FTEs and 15 percent reduction in expenses related to the change in methodology for budgeting for labor float. Meeting Expenses • Meetings decrease by $44,000 due to a decrease in the number of meetings and an anticipated decrease in the number of attendees. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 30 . Page 65 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2014 Business Plan Training, Education, and Operator Certification Operating Expenses • Consultants and Contracts increase by $14,000 due to the increased use of consultants to conduct training sessions. • Office Costs increase by $47,000 due to an incremental simulator license fee. Indirect Expenses • Indirect Expenses are allocated based on FTEs. Other Non-Operating Expenses • Not applicable. Fixed Asset Additions • Not applicable. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 31 . Page 66 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan Training, Education, and Operator Certification Training, Education, and Operator Certification Program Funding sources and related expenses for the Training, Education, and Operator Certification section of the 2014 Business Plan are shown in the table below. Statement of Activities, Fixed Assets Expenditures, and Change in Working Capital 2013 Budget & Projection, and 2014 Budget 2013 Budget Funding WECC Funding WECC Assessments Penalty Sanctions Total WECC Funding Membership Dues Federal Grants SeNices & Software Workshops Interest MisceRaneous Total Funding (A) Expenses Personnel Expenses Salaries Payroll Taxes Benefits Retirement Costs Total Personnel Expensas Meeting Expenaes Meetings Trawl Conference Cells Total Meeting Expenses Operating Expenaea Consultants & Contracts Ollice Rant Ollice Costs Professional SeNices Miscellaneous Depreciation Total Operating Expenses $ $ 2013 Projection 51,135 27,809 78,944 $ s 451,550 2,727 36 51,135 27,809 78,944 Variance 2013 Projection v 2013 Budget Owr(Under) $ $ 36,290 66,585 I $ 10~875 435,785 2,439 @ll I ~257 I 516,591 $ $ 103,772 7,689 21,306 7264 140,031 $ 103,m 7,862 (4,180) 8,568 116,042 $ $ $ $ 99,950 6,350 600 106,900 s $ s 92,500 47,478 40,980 $ I 180,958 $ 64,481 6,350 600 71,431 Variance 2014 Budget v 2013 Budget 0\er(Under) 2014 Budget (15,765) (268) (613) (16,666) $ s 519,804 1,566 (14,845) 38,n6 23,931 68,254 (1, 161) (36) I 624,245 I 90,988 0 173 (25,466) 1,324 $ $ i ~3,989) i 146,942 10,136 22,654 10136 189,868 43,170 2,447 1,346 2872 49,837 $ (35,469) $ 56,040 7,836 I $ 804 I (35,.469) (43,910) 1,466 204 (42,220) I ~680 I $ 106,502 47,472 87,740 $ 14,002 (6) 46,760 92,500 43,745 79,446 $ $ 215,691 $ 34,733 I 241,714 I 80,756 (3,733) 38,466 s 427,889 i 403,164 I (24,725) $ 496,262 I 68,373 Indirect Expenses $ 110,851 $ 118,524 I 7,673 I 196,829 i 85,978 Other No!Klperatlng Expenaes $ s (17,052) i 693,091 $ 386 $ l!8,846l $ 3,152 $ (3,814) $ Total Direct Expenses ! $ Change in A&Rts s 15,482! $ ~02!! $ $ (5,482) $ (2,330) $ 538,740 $ s i Total ExpenSIIS (B) 521,688 I 154,351 Fixed A&Rts Depreciation Computer & Software CapEx Furniture & Fixtures CapEx Equipment CapEx Leasehold lmpro~ements Allocation of F!xed Assets ~~~-!~~~~J21 't-~~"1!~--r~:;:, .J .< . J!~~t,. TOTAL BUDGET (B+C) TOTAL CHANGE IN WORKING CAPITAL (A~) FTEs HC 1°1 1.5 2.0 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . .t._ ,,_ .,.1~,.~~,:.:·-'1-• m..!'-:.:~- ._q~~~? 11At'*~**'*'{\·!JfJrm,hs:'fl& -e 1#l!t~ 519,358 533,258 $ 1,668 $ !P!!l 1.5 2.0 (13,899) $ 1!:767! &8912n $ j&51032l 2.0 2.0 156,019 $ 165,032! 0.5 32 . Page 67 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2014 Business Plan Situation Awareness and Infrastructure Security Situation Awareness and Infrastructure Security Program Situation Awareness and Infrastructure Security (in whole dollars) 2013 BudjJet 85.0 Total FTEs Direct Expenses $ 24,469,496 6,278,766 (84.5) 0.5 $ 60,156 $ 49,207 Indirect Expenses $ Other Non-Operating Expenses $ lnc(Dec) in Fixed Assets $ (1,754,014) $ Total Funding ReQuirement $ 28,994,248 $ - Increase (Decrease) 2014 Bl!.dg~t $ - $ (24,409,340) $ j6,229,559) $ (953\ $ 108,410 $ 1,753,061 (28,885,838) Program Scope and Functional Description The Reliability Coordinator and Interchange Authority functions will be assumed by the new RCCo entity effective January 1, 2014. Reference the 2014 RCCo Business Plan and Budget for more information. The tables referencing the 2013 budget for this Program are presented in this document to provide a complete picture of the WECC 2013 budget. As required under the Delegation Agreement and NERC Rules of Procedure, the 2014 WECC Situation Awareness and Infrastructure Security (SAIS) Program Area includes funding and resources consisting of 0.5 FTE to review and respond to incidents and events that impact the reliability of the BES, and to respond to information requests from NERC, FERC, and internal WECC Management. The goal of the SAIS Program Area is to maintain real-time awareness about the conditions of the interconnected BES in the Western Interconnection and to respond to events by providing coordination, assistance and communications with the Western Interconnection Reliability Coordinator (RC), Stakeholders, WECC Management, and the NERC SAIS personnel. 2014 Key Assumptions • SAFNR will provide additional situation awareness capabilities at both NERC and Regional Entity levels. • The WECC Situation Awareness process will be used to support NERC and FERC's efforts for situation awareness of current system conditions. 2014 Goals and Key Deliverables • Staff will monitor System Events, collect information and coordinate the distribution of timely updates on System Events to WECC Management, industry stakeholders and NERC SAIS staff. • Staff will continue to monitor system data, weather, and technological developments to understand trends that affect reliability for the near- and long­ term horizons. • Staff will continue to develop and enhance ways to improve upon the use of SAFNR data to further support SAIS. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 33 . Page 68 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2014 Business Plan Funding Sources and Requirements - Situation Awareness and Infrastructure Security Explanation of Increase (Decrease) Funding Sources (Other than ERO Assessments) • Assessments are offset by the allocation of $17,000 in penalty sanctions received by WECC on or prior to June 30, 2013. • Interest revenue is allocated based on FTEs. Personnel Expenses • Personnel Expenses decrease by $12.9 million due to the creation of the new RCCo entity. Meeting Expenses • Meetings decrease by $454,000 due to the creation of the new RCCo entity. Operating Expenses Operating Expenses decrease by $11.0 million due to the creation of the new RCCo entity. Indirect Expenses • • Indirect Expenses are allocated based on FTEs. Other Non-Operating Expenses • Not applicable. Fixed Asset Additions • Fixed Assets are zero due to the creation of the new RCCo entity. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 34 . Page 69 of 273 14-05XXX; MDR 094 Attach 01 . . Situation Awareness and Infrastructure Security Section A - 2014 Business Plan Situation Awareness and Infrastructure Security Program Funding sources and related expenses for the Situation Awareness and Infrastructure Security section of the 2014 Business Plan are shown in the table below. Funding WECC Funding WECC Assessments Penalty Sanctions Total WECC Funding Membership Dues Federal Grants Senrices & Software Workshops Interest Miscellaneous Total Funding (A) Expanses Personnel Expenses Salaries Payroll Taxes Benefits Retirement Costs Total Personnel Expenses Meeting Expenses Meetings Trawl Conference Calls Total Meeting Expenses Operating Expenses Consultants & Contracts Office Rent Office Costs Professional SenAces Miscellaneous Depreciation Total Operating Expen1111s 2013 Budget 2013 Projection $ 24,476,506 $ 24.476,506 1,575,157 $ 26,051,663 $ 26,051,663 2,786,076 10,486,952 2014 Budget $ $ $ $ 1,575,157 $ (24,395,361) (1,558,511) $ ~5,953,872) 7,700,876 135,721 (36,750) 154,450 2,059 81,145 16,646 97,791 (2, 786,076) (18,729) 391 ~8,809) $ 28,994,248 $ 36,637,586 $ 7,643,338 $ 98,182 $ $ 10,500,212 $ 12,279,930 $ $ 47,976 3,228 5,724 3 228 60,156 $ 907,970 1,306,921 824,045 $ 15,318,866 1,779,718 162,124 213,501 176,878 2,332,221 $ 745,846 1,093,420 647,167 $ 12,986,645 $ $ 13,002 176,61!9 2,637 $ 453,646 $ 2,422,290 768,081 4,518,304 5,000 $ 19~308 $ $ (453,646) $ 10,156,531 $ 7,734,241 (1,047) 1,602,304 77,144 $ $ (2,422,290) (768,081) (4,518,304) (5,000) $ $ 767,034 6,120,608 82,144 $ (437,726) (15,920) 3,759,841 $ 20,886,158 $ 444 311 9,856,953 $ $ 24,469,496 $ 36,850,978 $ 12,381,482 $ 60,156 Indirect Expanses I $ $ 1,428,464 $ 49,207 Other Non.Oparatlng Expenses 7,707,230 s s I Total Expenses (B) 1 30,748,262 1 441 ~208 $ 13,809,946 $ 109,363 $ Change In Assets $ (1,754,0141 ! $ 16.166.608! $ 111,181! s Allocation of Fixed Assets (3,315,530) 843,000 29,000 1,000,000 $ ~'3}~~i':\~~1.~~-J~h~·~,;"";:·~:t4.?:r.";,..~ I TOTAL BUDGET (B+C) TOTAL CHANGE IN WORKING CAPITAL (A·B-C) FTEs HC (310,484) • ·<",···:'" I 1!1920.622! $ (151,498) 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 $ (6,229,559) ~0,638,899) $ 158,986 $ 2 (953) $ 53 44,776,460 97.5 108.0 108,410 15,782,212 $ j!.138,874j 12.6 12.0 1,742,833 3,315,530 (843,000) (29,000) (1,000,000) -~ \\\~~.>~ "~-y:;;J/~?ff'ff~: !:'''rMl'>ft'><'·!t J ·}-~--"' $ 18.138,8741 85.0 96.0 (24,409,340) (444,311) 235,367 (23,000) 563,352 1,461,873 (3,759,841) 1,078,367 6,000 1,583,352 1,481,873 11,754,014) -· $ 28,994,248 $ (3,315,530) (11,029,205) $ $ Fixed Assets Depreciation Computer & Software CapEx FumHure & Fixtures CapEx Equipment CapEx Leasehold lmprowments (10,452,236) (742,618) (1,087,696) (643,939) (12,926,489) $ 3,315,530 6,278,766 $ (154,059) (2,059) 1!!,896,066) 13,002 614,395 18,557 645,954 437,726 15,920 I $ $ 11,029,205 Total Direct Expenses . 2013 Projection v 2013 Budget 0\er(Under) $ 11012281 0.5 $ 309,531 ~·?5310~;1 ; j28,8SS,638) 11012281 (84.5) (96.0) 35 . Page 70 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan Administrative Services Administrative Services Administrative Services (in whole dollars) 2013 Budget Direct Expenses $ lnc(Dec} in Fixed Assets $ Working Capital Requirement $ 13,355,492 $ - (9.4} 46.9 56.3 Total FTEs Increase (Dec;rease;l 2014 Budget $ $ 10,050,982 $ - $ $ (3,304,510' - Program Scope and Functional Description WECC's Administrative Services consists of Technical Committees and Member Forums, General and Administrative, Legal and Regulatory, Information Technology, Human Resources, and Finance and Accounting. The budgets for these programs are addressed in the subsequent sections of the Business Plan and Budget. Methodology for Allocation of Administrative Services Expenses to Programs Administrative Services expenses are allocated to statutory and non-statutory program areas based on FTEs. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 36 . Page 71 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2014 Business Plan Technical Committees and Member Forums Technical Committees and Member Forums Technical Committees and Member Forums (in whole dollars) 201~Bu~et Total FTEs 7.6 Total Direct Expenses $ lnc(Dec) in Fixed Assets $ Working Capital Requirement $ 2,218,267 - Increase (Decr:ea...sc:l 2014 B~.Qet 9.0 $ 2,246,509 1.4 $ $ - $ $ - $ 28,242 - Program Scope and Functional Description WECC provides forums for members and other interested stakeholders within its footprint to discuss and share reliability, compliance, and operating concerns. These forums include the Board of Directors, committees, subcommittees, work groups, and task forces. 2014 Key Assumptions • Members and interested stakeholders are responsible for all expenses to attend WECC forums. • WECC budgets for meeting space, meals, and logistics associated with WECC forums and most meetings will be held at the Salt Lake City meeting facilities. • The same level of forums and forum support will carry forward into 2014. • Committees will coordinate with the RCCo as appropriate for participation and efficiency. • The Joint Synchronized Information Subcommittee will initiate a project to validate synchrophasor data and will also pursue a project to demonstrate voltage stability applications that use synchrophasor data. • One additional position was added to the 2014 budget to enhance analytical resources to identify reliability trends and vulnerabilities based on system data and event analysis. • The number of "qualified system events," as defined in the NERC Events Analysis Process, is expected to remain steady. • The approved NERC Event Analysis Program will be augmented with a robust program of causal analysis and metrics. 2014 Goals and Key Deliverables • Staff will work directly with registered entities and NERC staff to develop cause codes for WECC Brief Reports and Events Analysis Reports. • Create a more effective organization by facilitating and encouraging cross­ departmental coordination and consistency. • Review the Standing Committee organizational structure; evaluate the value of member groups; determine whether consolidation of groups or creation of ad hoc 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 37 . Page 72 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2014 Business Plan Technical Committees and Member Forums groups provides a more effective and efficient forum for addressing specific reliability issues. • Continue support of activities associated with the September 8, 2011 Arizona­ Southern California Outage event and complete committee assignments according to proposed timelines. • Address the vulnerabilities that could impact reliability by identifying and promoting the projects that can improve reliability and mitigate vulnerabilities. • Optimize stakeholder involvement and value by structuring meetings and agendas to meet member needs, communicating WECC processes and initiatives to committees, and providing strong staff support to member committees. • Facilitate sound decision making to improve reliability by providing detailed analysis on emerging issues, including alternatives examined, recommendations, and rationale for recommendations. • Ensure the Western Interconnection is represented in reliability matters by participating in the NERC Operating Committee, NERC Integration of Variable Generation Taskforce, and other industry forums. • Ensure the Western Interconnection is represented in the development of continent-wide processes and reliability standards including Frequency Responsive Reserve, Reliability Based Control, and Event Analysis. • Continue the categorization and review of key WECC documents to ensure consistent formatting and quality. Assure WECC members have access to the most current and applicable documentation in support of maintaining a high level of reliability in the Western Interconnection. Funding Sources and Requirements - Explanation of Increase (Decrease) Funding Sources (Other than ERO Assessments) • Not applicable. Personnel Expenses • Personnel Expenses increase by a net of $48,000 primarily due to the increase of 1.4 FTEs and the reduction in expenses due to the change in methodology of budgeting for labor float. Meeting Expenses • Meetings decrease by $19,000 due to use of lower cost vendors. • Travel decreases by $21,000 due to a reduced number of Board members. Operating Expenses • Consultants and Contracts increase by $45,000 due to a data validation and voltage stability project. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 38 . Page 73 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan Technical Committees and Member Forums Indirect Expenses • Technical Committees and Member Forums expenses are allocated to statutory functional areas based on FTEs. Other Non-Operating Expenses • Not applicable. Fixed Asset Additions • Not applicable. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 39 . Page 74 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan Technical Committees and Member Forums Technical Committees and Member Forums Funding sources and related expenses for the Technical Committees and Member Forums section of the 2014 Business Plan are shown in the table below. 2013 Budget Funding WECC Funding WECC Assessments Penalty Sanctions Total WECC Funding Membership Dues Federal Grants S&Nces & Software Workshops Interest Miscellaneous Total Funding (A) Expenses Personnel Expen111s Salaries Payroli Taxes Benefits Retirement Costs Total Pel'liOJinal Expenses Meeting Expenses Meetings Travel Conference Galls Total Meedng Expensas Operadng Expen111s Coosuitants & Contracts Office Rent Office Costs Professional SenAces Miscellaneous Depreciation Total Operating Expenses 2013 Projection Variance 2013 Projection v 2013 Budget Q\er(Under) 2014 Budget $ $ $ $ $ $ s ! $ $ $ $ $ ! s $ ! $ 902,239 67,808 86,657 63157 1,119,860 $ ! 877,506 68,107 107,960 65,234 1,118,807 (24,733) 299 21,303 2077 (1,053} $ s s ! 874,612 59,075 115,178 59,075 1,107,940 $ $ (19,358) (21,105) (8,600} $ (49,063} s 46,333 $ 11,513 20,787 (8,275} $ $ 308,961 170,612 19,125 498,698 ! ~025 $ 278,090 128,720 18,800 425,810 $ 120,000 $ (48,687) $ 212,000 $ $ 297,448 149,826 27,400 474,873 $ 186,867 40,068 401,000 10,893 163,876 60,961 684,875 ! 35,203 485,756 (27,627) (8,733) 28,521 (4,062) (11,920} (4,865) 64,756 $ 16,000 623,734 ! 735,836 ! (16,000) 112,102 $ 71~959 $ (16,00Cl 89,225 $ 2,218,267 $ 2,353,341 ! 135,073 $ 2,248,509 ! 28,241 Indirect Expenses $ (2,218,267} $ (2,353,341} $ (135,075} $ (2,246,509} s s s ! ! s (28,243} Other No~perallng Expen111s Total Expenses (B) $ $ $ ! $ Change in .Assets $ $ ! s $ Total Direct Expenses Fixed .Assets Depreclallon Computer & Software CapEx Furniture & Fixtures CapEx Equipmenl CapEx Leasehold lmprowments Allocation of Fixed Assats $ 16,000 16,000 $ FTEs HC 16,000 $ (16,000) $ ~ • $ TOTAL BUDGET (B+C) TOTAL CHANGE IN WORKING CAPITAL (A-B-C) (0} (16,000) ~~1~~~~~~~~~~~I.~?fi~_L~~~!: T 1.y4 jiif·*:z;; ·if· fw.~Wst- £t • ' {Gg ¥ .... . ,.,%iPh : ·"'":i·1 ···hE·* · ·§ $ • t: ---•n ·~=t\Jit& (16,000) . W¢·12t· 1 (01 $ $ 7.6 8.0 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28,2013 . Variance 2014 Budget v 2013 Budget 0\er(Under) $ 6.6 6.0 $ $ (1 .0) (2.0) 9.0 9.0 1.4 1.0 40 . Page 75 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2014 Business Plan General and Administrative General and Administrative General and Administrative (in whole dollars} 2013 Buqget 18.8 Total FlEs Increase (0ecre:a5e}. 2014 aoctget (3.6\ 15.2 Direct Expenses $ 4,941,753 $ 3,695,570 $ lnc(Dec) in Fixed Assets $ Working Gapital Requirement $ - - $ $ (1 ,246,183\ $ $ - Program Scope and Functional Description The General and Administrative Program provides executive leadership, communications, and administrative support for WECC staff, committees, members, and management, as well as logistics support of the Salt Lake office and meeting facilities. In addition, indirect costs such as Office Rent that benefit multiple functional areas are accounted for in this budget. 2014 Key Assumptions • WECC will receive an exemption from Washington State income tax. 2014 Goals and Key Deliverables • WECC will continue to conduct its annual "Measures of Success" and stakeholder surveys. • Provide executive leadership and strategic guidance for the activities undertaken byWECC. • Improve the quality and efficiency of administrative support provided to staff and members. • Redesign the WECC Intranet and Internet websites. Funding Sources and Requirements- Explanation of Increase (Decrease) Funding Sources (Other than ERO Assessments) • Not applicable. Personnel Expenses • Salaries decrease by $393,000 primarily due to a net reduction of 3.6 FTEs due to the creation of the new entity and a 15 percent reduction of personnel expenses for labor float. • Payroll Taxes decrease by $50,000 with Salaries. • Benefits decrease by $27,000 with Salaries. • Retirement Costs decrease by $61 ,000 with Salaries. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 41 . Page 76 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2014 Business Plan General and Administrative Travel Expense • Travel decreases by $47,000 primarily due to decreased attendance at external meetings. Operating Expenses • Consulting and Contracts decrease by $20,000 primarily because the WECC stakeholder survey was conducted in 2013 and is only performed every other year. • Office Rent decreases by $271,000 due to the transfer of two office facilities to the newly formed RCCo. • Office Costs decrease by $80,000 partially due to the creation of the RCCo, and also due to bank charges and property taxes being accounted for in the Finance and Accounting function in 2014. • Depreciation was over-budgeted in 2013. Depreciation decreases by $297,000 in 2014 to more accurately reflect actual depreciation. Indirect Expenses • General and Administrative expenses are allocated to statutory functional areas based on FTEs. Other Non-Operating Expenses • Not applicable. Fixed Asset Additions • Not applicable. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 42 . Page 77 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2014 Business Plan General and Administrative General and Administrative Funding sources and related expenses for the General and Administrative section of the 2014 Business Plan are shown in the table below. Statement of Activities, Fixed Assets Expenditures, and Change in Working Capital 2013 Budget & Projection, and 2014 Budget G_ENEMLANB AB INIS'I'RI\ml_lii 2013 Projection 2013 Budget Funding WECC Funding WECC Assessments Penalty Sanctions Total WECC Funding Membership Dues Federal Grants Sen ~~ (238,991) . $ $ 205,000 . $ $ (286,179) . -~ .~ -;;t·"-::t~-z -•:Z·-i@jtiJc-:¥~-.&fiitk"" Za}·: )l ~·, 'XU.·C-!:d£::@-!!1 TOTAL BUDGET (B+C) TOTAL CHANGE IN WORKING CAPITAL (A-B-C) FTEs HC $ $ 18.8 19,0 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . $ 17,3 17,0 $ (1,5) (2.0) $ 15.2 16.0 (3.6) (3,0) 43 . Page 78 of 273 14-05XXX; MDR 094 Attach 01 . . Legal and Regulatory Section A- 2014 Business Plan Legal and Regulatory Legal and Regulatory (in whole dollars) ' (6.1\ 6.0 12.1 Total FTEs Increase {De cr.e.ase 'i 2014 Budget :2013 l3ud11et Direct Expenses $ 2 447,593 $ 1,099,606 $ lnc(Dec) in Fixed Assets $ $ - $ Working Capital Requirement $ - $ - $ (1 ,347,987\ - Program Scope and Functional Description The Legal program area provides coordinated legal services to the WECC Board, committees, and staff. In addition, the program area provides consistent legal interpretations of relevant statutes, regulations, court opinions, and regulatory decisions. The Legal program area also develops specific subject matter expertise to further assist WECC with its legal needs. On occasion, major efforts may be outsourced to select law firms, but the responsibility for all legal matters remains with the General Counsel and Legal program area. WECC's international operations and its broad scope of activities require significant legal support and review. Arranging for legal support is complicated by the technical nature of this developing area of law and there are many potential areas of conflict prohibiting the use of law firms with energy practices. 2014 Key Assumptions • WECC will maintain the scope of its current operations. However, the operating environment may change in the event of unanticipated direction from FERC, NERC, or both. • The creation of an independent company responsible for the Reliability Coordinator and Interchange Authority registered functions will be effective January 1, 2014; provision of legal services in support of this company will be the responsibility of that company's Legal department. 2014 Goals and Key Deliverable& • Provide efficient, cost-effective legal support to the WECC Board, committees, and staff through a combination of in-house and outside resources. • Update and advise the WECC Board and CEO on pending legal issues. • Advise WECC departments on specified legal matters and general matters relating to WECC business. • Provide legal support to the WECC Compliance Department and facilitate the processing of possible and alleged violations. • Represent WECC in legal and regulatory proceedings. • Review and advise WECC business units on draft agreements. • Improve tracking for development of WECC regulatory policies. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 44 . Page 79 of 273 14-05XXX; MDR 094 Attach 01 . . Section A - 2014 Business Plan • Legal and Regulatory Implement a corporate records management system. Funding Sources and Requirements- Explanation of Increase (Decrease) Funding Sources (Other than ERO Assessments) • Not applicable. Personnel Expenses • Salaries decrease by a net $1.07 million primarily due to the transfer of seven positions to the newly formed entity as well as a 15 percent reduction in personnel expenses for labor float. • Payroll Taxes decrease by $82,000 with Salaries. • Benefits decrease by $77,000 with Salaries. • Retirement Costs decrease by $76,000 with Salaries. Meeting Expenses • Travel decreases by $32,000 due to the reduction of legal staff. Operating Expenses • Office Costs decrease by $21,000 due to reduced number of cell phones, legal subscriptions, and membership dues as a result of the bifurcation of WECC. Indirect Expenses • Legal and Regulatory expenses are allocated to statutory functional areas based on FTEs. Other Non-Operating Expenses • Not applicable. Fixed Asset Additions • Not applicable. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 45 . Page 80 of 273 14-05XXX; MDR 094 Attach 01 . . Section A- 2014 Business Plan Legal and Regulatory Legal and Regulatory Funding sources and related expenses for the Legal and Regulatory section of the 2014 Business Plan are shown in the table below. Statement of Activities, Fixed Assets Expenditures, and Change in Working Capital 2013 Budget & Projection, and 2014 Budget . .EGAL A D. 2013 Budget Funding WECC Funding WECC Assessments Penalty Sanctions Total WECC Funding Membership Dues Federal Grants SEINices & Software Wortperatlng Expenses Allocatior. of A1ted Assets Variance 2014 Budget v 2013 Budget 2014 Budget 1,806,731 Indirect Ex pan•• ~~.;· Variance 2013 Projection v 2013 Budget Owr(Under) ~667 594,843 ! ! ! 1,606,557 ! 322,622 ! 1,658,980 ! 150,834 21!!!678 $ 1366159!) ! .244,820 ! 1116~) 6,000 $ (6,000) $ $ $ ~~~~~~~;J!~,;·~~~-L~~.,.l=:~f:lzs- ::~·~_;,~~~\ :;\~-,=~ :z ~~~Pi·& ·~·~:;. :::·:~.~~-~.~~~J Z!!IZZ! ! ~!'ass.:-~~~~ 0 TOTAL BUDGET (=B+C) TOTAL CHANGE IN WORKING CAPITAL(=~) $ FTEs HC 355,064 5.0 5.0 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 1 1,612,557 1,514,146 ! 2121678 4.8 5.0 ! 1366,59!) (0.3) 144,834 1,658,980 322,622 $ .244,820 ! 111012441 5.0 5.0 74 . Page 109 of 273 14-05XXX; MDR 094 Attach 01 . . Personnel Analysis Section C- 2010 Non-Statutory Business Plan and Budget Personnel Analysis FTEs are defined as full-time equivalent employees only. Fractional FTEs reflect part­ time employees or employees who worked in fewer than all four quarters of the year. Shared FTEs' Total FTEs 20111 Bud et 2014 Bud et Change from 2013 Budget Budget Projection Direct FTEs 2013 2013 2014 Bud et 00 00 00 00 00 00 WREGIS 5.0 4.8 5.0 0.0 5.0 0.0 Total FTEs Adrnullslrat1ve Programs 5.0 4.8 50 00 50 00 Tota I FTEs 5.0 4.8 5.0 0.0 50 00 Total FTEs b Pro ram Area OperatiOnal Programs Total FTEs Operational Programs Admm1strat1ve Programs 1 A shared F1E is defined as an employee who performs both Statutory and Non-statutory functions. There are no changes to personnel within the non-statutory function. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 75 . Page 110 of 273 14-05XXX; MDR 094 Attach 01 . . Section C - 2010 Non-Statutory Business Plan and Budget Reserve Analysis Reserve Analysis- 2013-2014 • I; .... ~ • Working Capital Reserve Analysis 2012-2013 .~Jj"f.?'';:~~t~ff,~Q!,~~jj;m~· -..~' ~. ,. .;~ .; • ... ~ ,. .. r"' WREGIS Resen.es Beginning Working Capital Re1111rve (Deficit), December 31, 2012 . ,_ ... r • "! WECC Norr Statutory Resen.es 1,954,861 Plus: 2013 WREGIS Funding Plus: 2013 Other funding sources 1,825,235 Less: 2013 Projected expenses & capital expenditures (1,612,557) 5,874,245 Projected Working Capital Reserve (Deficit), December 31, 2013 2,167,539 5,874,245 Projected Working Capital Reserve, December 31, 2014* 2,167,539 0 (2,167,539) (5,874,245) 0 (5,874,245) Less: Projected Working Capital Resen.e, Oecember31, 2013 Adjustments to achieve Working Capital Reserve, December 31, 2013 2013 Funding Sources Less: Expenses and Capital Expenditures Transfer Reserws to Statutory con~oerting Non-statutory Reser~oeS not (5,874,245) 244,820 2014 Funding (reserve adjustment) *WECC Is 1,903,800 (1,658,980) (5,874,245) related to WREGIS to Statutory in the 2014 Business Plan and Budget. WECC's Working Capital Reserve balance decreases in 2014. WECC's Board has approved a Working Capital Reserve balance equal to one month of Personnel and Operating Expenses, to be achieved by 2016. In 2014, WECC is transferring $5.87 million of Non-statutory Working Capital Reserves, which were on-hand when WECC originally signed its Delegation Agreement in 2006, to Statutory Working Capital Reserves. Those funds have not been used for any purpose in the past seven years. WECC Management and the WECC Board believe it would be prudent to use that money to minimize the impact on Assessments due to the budget increases in 2014 and future years. The total Working Capital Reserves will be used to offset the impact of the creation of the new entity and other increases on Assessments for both WECC and the RCCo in 2014 and 2015. 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28,2013 . 76 . Page 111 of 273 14-05XXX; MDR 094 Attach 01 . . Section D - Additional Consolidated Financial Statements 2014 Business Plan and Budget 2014 WECC Business Plan and Budget Approved by Board of Directors: June 28, 2013 . 77 . Page 112 of 273 . I~ a.,.._ Ui,f'3Q.a51 I,N7,t,. 17,.411,1711 Toi.. Dhal~ ~ C.pEir ,.... LO ... ,.... 111.0 21,ttl,tM ~141) JtU20 (tM.J1lt IDl ... ,....., ,,.. (580."""1 ~ ZI.T71.111 (S41,1tt) H.J1J.711 1,017,5154 510000 1,405,454 ""'·""' ....... 4,317,3CI2 11o4 222 2.472.154 t,<41C,.cse 117SA71 15,77!,171 12.oee.m 77-4,001 2,121,744 774,001 D.lft.tll 157.021 ....,. ......... t.tau.IG3 ~~N .. .,. (1.!12.1111 .... .... ...... 14J!!.MI lfii,.IU) (110,102) .,,.. 1'1-00CI) ..... ,,_~ '"'-'!!.!!!. ~- ttt,A7'0 !!,lXXI ,_... ......,. -- U70,11123 4t 710 - .sc o412.SCD 1.20!,!!0 ...111.m 3U..3Hii 715,513 m.ats 1a.:ne,Q1 431tU 12,UI,UG (1!.120) 1.tD.to2 (1,!1!) (7.11211) (1M,t41t _1,DIO,ao ........ 87,7.. UZO 1,120 13,078 21.310 :!.1M 521 55!.544 :sa.t:sa 447.718 30.131 41.o411 121.412 '-"' tSJJ.• ID,NI -- w-~ 1:,8!3,GIID 11,111:1,101 1,-.- ....... 2013 WECC Business Plan and Budget Approved by Board of Directors: June 25, 2012 "" 140.0 111.1 111.0 fTEoo (2.!11....1 1!,174,1!!! 2I,IUJIIA IJ',M,tM TOTAL ctWIQ~ If WOIUING CW'ITAL (AoloC) 1114.111) IDl 131,000 ....... (500,000) ~~ ,... . . . . !541,111 (541,111) 21,172,- 1,1'1J,HI 11.500 557,050 ..... 74,225 11,000 21.111.701 'iOi7.5ii ..... _..,.,.. "'"'""' 1,-405.-454 4,387,3QZ 2.472.154 1~4..2ZZ 1,e4,8 TO TN.. IUDQET fi.CJ IDl C1M,I1!) lno(Deo) In Flllill , . .... (C) '"'""" Moc:allonof fiad.._.. LduhoJdlrrlnwnwiO ~nni:C.'!ll Flnlltn & eo,... & Softwl,. CllpEx ~""'·"""' ......7 (Z.IDI,Gt) FtadAI..t• O.pnodill:llll Z7,G1,171 ctvlrotlnAtHta ....... Toi•IE...-(at Olher NOftoOp6fd"'IIIEarpliMU ................ .......... TDliiO,.,ftlntl~ 1,112,504 773,,.. .,.,on 4,RS,302 15411371 ""* 23,715 11!1,835 237ts ~73J 1,•.• 7,DJ 1,(-}8,000 ....... ...... t5,7TI,tm 1S.Z38.M5 Ul,n>t 1,545,61 1f.4,2Z2 11,(181.225 774,001 2,121,744 774,oo1 P.l1t,tH 051...... 3,828,301 15.1!0,151 2,133,050 11,1U.II1 12.4411.055 717,718 2,115,879 m.11e 11.121.111 00,000 ....729 ......... ,_..,. 11,11S,IOt ..!a!!!!! "'""Co"' ProfiMbrala.MoM ~R•nl: c...... & eanr.a Opahtlng &Ji;pMIU TDtiiMHt4rt~...,..,._ """'"""'"'"' ,_ Mmln1b!WI... M•ttrw• Tnowl Rellr.n.nl:eo.t. Toi1IP.,.,,... B"•"' Pii~T•­ S.lllles PHM~m .. E. .n'lln ......... Tllhll'unclng M....._ ~ 'N:Irbt.f* s.m:..&Sclftwln .. NDn..t.t.nty F\l"drw Ftld.raiO,.,. Total wecc l'ana. .....l:y&nalla~ MCChMn-m wa:c­ !!!:-a ... ~m ti,!!S ~ _2~1.71-4 ~.7offJ ....... .,,.,. !!,&:JD 104 r.aa 51,040 111,!1! 10,tH 22,4154 tOt31 i•,a.a ... .... (!!4,Ml! I.IM.MI C11,111) (...003) N41'r' (211-CIOP) (170.,7a) 111.411 (!A) - 111,111) t!USSI 01.22!1 ..... ... UU!! C1,114) (),114) (11,147) '110,• ____....!!!:!!!..___ _t_u,aa 49,201 10,111 80,168 :sm q/iTTB 3,221 &,724 ,., H.11J .... 17,711 ~~ -~ !!U!I 511004 111.171 2,554,048_ _ _ _ 111,121 lt,'!_l.111 UIZ,ISO 211,000 113,150 ~- 244,615 1-..::o 30,750 15,085 2.D'Io4,13D 134,118 2H,117 1:w,t1e 2,571,2!50 u•.nt 111111 3,821,:101 4,118,017 •m~ '·' ... C2,Z441.&G8) J..JM.IOI nz.a "-"" ........ 212.000 1UOD 425,110 ue.no l7'B.C8) t 107,!:!0 !!,07!i 11&,178 5,07!1 174.~:~1z 11,D 1U ....... (>05.000) (3,11115,570J_ S,~ UIOAit 2C!5.000 t =:!.t,IIIO fll,l!'Jt ...... 1.1«1 141,141J 121,7Sl U,2&D 1.1!101.127 92,311 1t'.J,22o4 92,311 2173- 2014 Consolidated Statement of Activities by Program, Statutory, and Non-Statutory I ·-""" 1!'_...~,""-., Section D - Additional Consolidated Financial Statements Section D -Additional Financial Statements 1,000 221.1110 ...... ..... (.OOCI) {1,011,108) t,II,IGI - ....... ...... .... 1.200 .e.ooo 123.7115 857,7811 44,3U 77,152 44.3lJJ 101,000 412.100 .. ... ...... (50.000) iDS.ODO (101.000) (1365, ....1) U11.441 ...~· 7,... (7.- (1.072.014) 1,171,114 ua, '100 7000 17.000 Sl,iOO 11.200 150,000 . .... ....... 10,200 1.000 354,SJB to4,190 414.878 t:!.tao 1.27.7&4 20.4110 1uoa 7.200 112.141 m,101 -45,103 101,821 45.tos ... 4-T 7.000 (7,000) -~ 171,712 177,1110 2.!!. ...... ...... 11,1!10 tt,250 CXI 312.542 11,182 AJ'SI 111,192 280.811) ' ..... 78 2!4,1JO Ua.HG ZW,t:ZO 1.•.uo So4ff11 1,117,- ----m:;so K7,G50 ...... 74,225 . ...... ..... ZM,121D 1.-.-a 244,10 1,111.111 541,1tf 1,117,10 578.&50 I MOO 557,000 ..... 74225 1S,22S n .ooo 1U25 ssa,na 23,115 15,8S5 H.ns o414,0N 1.111.110 7,100 1,H8.000 •"~~~~~ tt.ooo 350.730 23.715 fi5,135 23.715 44.0!M un.eoo 7,800 1,8911,000 •..:;~..:!t..,•l·'l ~r:.J 14-05XXX; MDR 094 Attach 01 . . . Page 113 of 273 14-05XXX; MDR 094 Attach 01 . . Section D -Additional Financial Statements Statement of Financial Position Statement of Financial Position 2012 Audited, 2013 Projection, and 2014 Budget STAtUTORY and NON-sTATUTORY thousan (Per Audit) 31-Dec-12 Projected 31-Dec-13 Budget 31-Dec-14 ASSETS Cash and cash equivalents $ 39,940,191 $ 25,679,956 $ 2,843,277 Certificates of deposit 1,436,598 1,500,000 1,125,000 Investments 5,930,113 6,000,000 4,500,000 12,908,228 14,199,051 5,470,798 835,773 626,830 470,122 11,964,467 14,357,360 3,589,340 Accounts receivable, net Prepaid expenses and other assets Property and equipment Total Assets $ 73,015,370 $ 62,363,197 $ 17,998,537 LIABILITIES AND NET ASSETS Liabilities Accounts payable Accrued payroll and related liabilities Deferred revenue Other liabilities Total Liabilities $ 2013 WECC Business Plan and Budget Approved by Board of Directors: June 25, 2012 . 5,668,040 2,834,020 1,892,947 2,044,383 1,226,630 24,381,993 24,577,528 9,378,511 7,051,156 5,640,925 1,410,231 40,883,483 $ 32,131,887 Unrestricted net assets Total Liabilities and Net Assets 7,557,387 $ 73,015,370 37,930,876 $ 3,149,145 24,432,321 $ 62,363,197 14,849,392 $ 17,998,537 79 . Page 114 of 273 . 2014 WECC Business Plan and Budget Approved by Board of Directors: June 2X, 2013 • Statutory Program Area Adminisirative Services Program Area • Non-statutory Program Area Appendix A: Organizational Chart Appendix A - Organizational Chart General& 7.6--+95 Legal and Regulatory 121-6.0 Technical Committees and Member Forums Administratrve 18.8 --+ 15.2 Finance and Aecounting 5.1'-4.7 Chief Executive Officer 3\1 _. 3.0 Hl!lrnan Resources lnformatton Technology 9.0-9.0 80 14-05XXX; MDR 094 Attach 01 . . . Page 115 of 273 14-05XXX; MDR 094 Attach 01 . . Appendix B - 2013 Budget & Projected 2013 and 2014 Budgets Appendix B: 2014 Budget & Projected 2015 and 2016 Budgets Statement of Activities and Capital Expenditures 2014 Budget & Projected 2015 and 2016 Budgets Statu tor 2014 Budset Funding ERO Funding WECC Assessments Penalty Sanctions Total ERO Funding $ 15,630,852 2,933,050 18,563,902 $ Membership Dues Federal Grants Wolkshops Interest Miscellaneous Total Funding (A) $Change 14v 15 2015 Pr!!Jectlon $ 22,973,055 $ $ 22,97:!,0!15 $ 7,342,203 !2,933,050! !,409,153 47.0% -100.0% 23.8% -100.0% s (3,628,309) 996,246 (886,169) (69,000! 821,923 3,628,308 957,929 69,000 23,219,138 24,041,061 12,096,225 n4,oo1 2.129.744 n1.001 1~n31 971 $ 12,789,847 804,594 2,141.592 $ 16,540,619 $ 693,622 30,593 11.848 30,585 76!!J649 $ 873,476 1,484,456 111.222 $ $ 2,47~154 $ 908,415 1,543,834 11!!,791 2,571,040 $ $ 4,397,302 936,072 1.405,454 758,756 $ $ Benefits Retlnament Costs Total Personnel Expenses $ Meeting Expenses Meetings Tra1oel Conference Calls Total Meeting Expenses Operating Expenses Consultants & Contracts Office Rent Office Costs Professional Ser\lces Miscellaneous Depreciation Total Operating Expenses Total Direct Expen£as 996,246 71,760 s $ Expenses Personnel Expenses Salaries Payroll Taxes %Change 14v15 560,000 8,067,684 $ I 26,31:!,709 $ Indirect Expenses $ 23,591,976 $ 618,923 2.7% $ 23,691,978 I 618,923 2.7% 39,850 2,870 4.0% 4.0% 1,036,096 74,630 24,7~704 $ 661,643 2.8% 5.7% 4.0% 0.6% 4.0% 4.9% $ $ $ $ 13,301,441 836,776 2,227,256 836,768 17,202,243 $ 511,594 32,184 85,664 32,182 661,624 4.0% 4.0% 4.0% 4.0% 4.0% 34,939 59,376 1.569 98,886 4.0% 4.0% 4.0% 4.0% $ 944,752 1,605,588 123543 $ ~67:!,883 36,337 61,754 4752 102,643 4.0% 4.0% 4.0% 4.0% 1,n6,394 973,515 1.619,945 769,106 (2,610,908) 37,443 214.491 30,350 -59.5% 4.0% 15.3% 4.0% $ 1,647,450 1,012,455 1,684,743 820,670 (128,944) 38,940 64,798 31,564 -7.3% 4.0% 4.0% 4.0% 696,000 !!.854.960 $ 116,000 ~212,6241 20.0% -27.4% $ !!.18!!.318 ! !696,000! m!!!z~ -100.0% -11.8% !1,347,090! -5.1% $ 25,041,444 $ 74,825 0.3% (!,0871 1.7% !572,206! !22,008! 4.0% ~966,619 $ 1550,19!} !541,1111 %Change 15v16 s ~586 $ -92.5% -100.0% 3.5% $Change 15v 16 2016 ProJection s $ Other Non-operating Expenses $ 25,772,598 $ Change In Assets $ (!15!2.4591 $ (37~3601 $ $ (590,000) 445,487 $ (696,000) $ 179,200 141,440 Fixed Assets Depreciation Computar & Software CapEx Fumiture & Fixtures CapEx Leasehold lmp101ements J,~~~~J~~~t~,~.~~;~;;;.,-;;· .. ·: . •., TOTAL BUDGET (B+C) TOTAL CHANGE IN WORKING CAPITAL FTEs HC (A~) -is c 2!!,6:!!!,085 $ $ (!141818461 $ 1 $ {1,356,1!!} -5.3% $ 24,469,238 $ 52,817 0.2% !11781099 -85.3% $ m.466 s 6081826 -162.2% 20.0% -59.8% $ $ 696,000 (92,932) 5,658 -100.0% -51.8% 4.0% (116,000) (266,287) 141,440 86,368 147,098 1 .fo\~W! ::!.:z'" a13~7~!-lf~ 1z!~l· ·*' ·~~JE • · ~'rii!b:l~. - -~~~ 2.8% 9 135.0 135.0 2014 WECC Business Plan and Budget Approved by Board of Directors: June 2X, 2013 . 24,416,421 Total Expenses (B) ~041,061 135.0 135.0 s !1,597,024! $ !14181946 $ o.o 0.0 -6.2% $ ~702,704 661,643 $ $ 0.0% 0.0% I 135.0 135.0 0.0% 0.0% 81 . Page 116 of 273 14-05XXX; MDR 094 Attach 01 . . Appendix C -Adjustment to the AESO 2014 Assessment Appendix C: Adjustment to the AESO 2014 Assessment 2013 2014 Compliance Budget Compliance Budget AESO NEL Allocation AESO NEL Allocation WECC Compliance Costs Direct Costs less Direct Revenue $ Fixed Asset Expenditures Total Net Costs, Including Fixed Assets Reserve Offset Net total to be allocated 2014 WECC Business Plan and Budget Approved by Board of Directors: June 2X, 2013 . 12,832,505 $ $ 12,632,505 $ 888,182 (1051602J $ 14,279,797 $ (1,392,917) $ 12,886,880 6.835% $ 93.56% $ 810,419 8,108,502 6,276,897 6.857% %Credit (47.25 of 50.5 FTE for 2013, 54.98 of 58.0 FTE for 2014) AESO Credit for Compliance Costs $ (2501045J $ AESO NEL Share (2011 &2012) AESO Proportional Share of Compliance Costs, including Fixed Assets 8,405,121 4,477,429 Indirect Costs 880,818 94.79% $ 834,955 82 . Page 117 of 273 14-05XXX; MDR 094 Attach 01 . . 14-0SXXX MDR94 Attachment 01 Nevada Power Company MDR 94 Section C Western Energy Supply and Transmission Association (WEST} . . Page 118 of 273 14-05XXX; MDR 094 Attach 01 . . Western Energy Supply and Transmission Association Statement of Support, Revenue, & Expenses - Cash Basis January through December 2013 Jan- Dec 13 Ordinary Income/Expense Income 47200 · Program Income 47250 · Section 111 d Subgroup 47230 · Membership Dues Total47200 ·Program Income 45000 · lnvesbnents 45030 • lntarest-Savlngs, Short-tarm CD Total 45000 · lnvesbnents 34,464.32 188,169.00 222,633.32 175.63 175.63 222,808.95 Total Income Expense 62124 • Section 111d Subgroup 62130 · Management Contracts 62134 • Holliday Strategic Team 62132 · Premier 34,464.27 134,500.00 13,200.00 Total 62130 · Management Contracts 147,700.00 62121 ·Government Affairs 62123 ·Meetings 62121 • Government Affairs- Other 47.32 7.00 54.32 Total 62121 · Government Affairs 65061 · Board Activities 65060 ·Board meetings Total 65061 · Board Activities 63000 · Consultants 63301 · Modeling (Joe Scire) 63500 · NESARC Total 63000 • Consultants 68300 • Travel & Admin Expenses 88312 · Accounting Fees 88311 · Bank charges 88310 ·Administrative Expenses 88300 · Travel & Admin Expenses - Other Total 68300 • Travel & Admin Expenses 7,794.88 7,794.88 10,000.00 5,000.00 15,000.00 1,800.00 35.00 43.41 924.50 2,802.91 207,816.38 Total Expense Net Ordinary Income Net Income 14,992 .57 14,992.57 See Acountant's CompUatlon Report . . Page 119 of 273 14-05XXX; MDR 094 Attach 01 . . 14-0SXXXMDR94 Attachment 01 Nevada Power Company MDR 94 Section C Consortium for Energy Efficiency, Inc. (CEE) . . Page 120 of 273 Page 121 of 273 ., v. II ONSORTIUM FER ENERGY EFFICIENCY 2012 for Emmy Ef?ciincy HER ANNUAL MDR 094 Attach O1 Attach 01 MDR 094 CINV ?3)1Vidn .LEJMEIVW EQVHHODNEI CINV iNEIDlzlel AQHHNEI CINV BHJ. SMHOM 33:) l/xl?v?c?jOOtlcl GNV 8V9 GNV SV Page 122 of 273 . In addition to improving public health with cleaner air, business analysts have shown that energy efficiency has a high return compared with other types of energy investments. Efficiency enhances the impact of ratepayer investments and can reduce risk and lead to increased profitability. By getting out ahead with "connected" specifications, Members talk a lot about meeting regulatory requirements, staying ahead of rising minimums, and increasing savings targets, but the tangible benefits derived from the work of CEE members are already numerous and significant. Because of managed demand, consumers and businesses save money on their bills, capital expenses can be avoided, and lower rates may be possible in the future. Emissions are reduced and natural resources are protected. By joining forces at CEE, individual electric and gas efficiency entities expand their partnership potential, working not only with their peers, but Efficiency doesn't just happen. Solving for efficiency requires working together across a range of issues to devise solutions that are relevant, practical, and strategic. CEE is proud to be the consortium of energy efficiency program administrators where members derive the solutions for achieving the benefits of energy efficiency for both the United States and Canada. Through CEE, members find program approaches that work across jurisdictions to increase the availability of efficient goods and services. we can expect to see increases in comfort, financial benefit, and, potentially, grid stability over the long term. SOLVE FOR EFFICIENCY. Program strategies are evolving across the board at CEE. Two recent efforts to incorporate demand response and address strategic energy manage­ ment illustrate how CEE members continue to also with other industries, trade associations, and government agencies. When program administrators work together, they accelerate the delivery of energy efficiency benefits and increase customer satisfaction. Most people think about mathematical equations as having definable properties and being eminently solvable given the right amount of skill and determination. The energy efficiency diagram relates people, markets, technology, and policy. All the factors are dynamic and entail constant assessment and consideration. As the consortium of program administrators, CEE is uniquely positioned to encourage and foster the kind of innovative platform building and partnering that addresses the fundamental values embedded in the energy efficiency equation. These values are at the center of each of our integrated programs and initiatives. Consortium for Energy Efficiency • u 0 0 "'c :J E . .E w c ~ . :>. ~ u c . u :>. N 0 N c c . ~ " ·;:; u . >. 5N N . u 5N N ~n-Connel. t~vrthe<>.st DR. DAVID GOLDSTEIN Natural Resources Defense Council JANICE S. BERMAN Pacific Gas and Electric ROBERT BALZAR Tennessee Valley Authority SUSIE ADAMS Duke Energy SARAH VAN DER PAELT TREAS 1JPER Union Gas MIKE STOCKARD SECRETARY Oncor Corporation DR. CARL BLUMSTEIN SECOND VICE CHAIR American Council for an Energy-Efficient Economy JIM PARKS FIRSl VIC S C. HAIR Sacramento Mun1c1pal Utility Dlstnct Xcel Energy .::H r~IR DEBitA L. SUNDIN i'cnn. DAN ZAWESKI Long Island Power Authority EDWARD WHITE National Grid SUSAN STRATTON Northwest Energy Efficiency Alliance GENE RODRIGUES Southern California Edison TED REtiULY San 01ego Gas and Electnc KAREN MEADOWS Bonneville Pow•r Administration PENELOPE MCLEAN-CONNER Northeast Uttllties FREDERICK LEUTHAUSER MidAmerican Enerm- VAL JENSEN Commonwealth Ed1son STEVE HOBSON BC Hydro KAREN HAMILTON New Yor~ State Energy Research and Development Authority Utilitoes working together with peers at CEE." JOHN COCKBURN Natural Resource~ Canada DR. KATHLEEN HOGAN US Department of Energy ELIZABETH CRAIG US Environmental Protection Agency SPECIAL ADVISORS trigger just the right market change to advance efficiency. at the heart of every savings opportunity. The resulting i "CEE, in its unique mission to serve program admin Board of Directors 14-05XXX; MDR 094 Attach 01 . . . Page 128 of 273 Page 129 of 273 AED OhrO Alabama Power Company .AI ant Energy?Iowa Ameren r?oi; Utilirres Ame'er? Maisoun {Jr-,Fona Publi: Service Arkaneae Wesmrn Gas Co Atmos Er -rg_v Corporation Austin Energy Aumt? Baitimow Gu? 5'4 Co EEC Hydro Berkshire Gar. Company macs: HIL inergy Bonncv Ha- Casc- LI- Cameo:- Centev'uo Ht Energy- Entire-'15 Lirierqv Group City cf mm mamas Citv u: ei? MO Columbia Gas of Nasser sen; Columma Gus (min ComFd Con Edison Cor-rechcu: Gas Corner-"man Consumers Eur-toy DC Sustainable Energy Lt-hty Deli-3 Gu'; DTE Energv Duke Ef?uent); ~14an Ef?ciency ?in Hour: Econ?: ET cnvx- v?r'mcr't Ema?.ij Gran-1n Eng-ewe War!- anrcx Greg W'unc Natural Ea: k. Circa-1 Tiwl" L-nr? Gul' Poww Hawaii Energy liff'lciency Program Idaho Power CEE members deliver efficiency and, through CEE. contribute and refine the Indianapolis f-?owni a Light Company Iowa E-Ic-rgy Cent!" Cny Para-?r F. I- LOSE rim: Enr-ri; LLC Lu?g? Island Pom-u Authority r??gr?n: Eleoia'trr-n-w: a- P: Down: r-iiz?j?-mericnr? Envgv rviinnesotn Deparrmen: a! Commerce 1:55: alppl Dcrwoi Montana-Dakota National NatLHr?il Resourcrx?. .- Ii" I IF. Var? - "1'11! roimn -ri ~1i-ri I-wcl-o Poi-um Gas ast ULiIIlit??s? [\Iort'neu'n Calliorniu ogerty 3n :ncliana Public knowledge of what works and what doesn't for programs. Orr-rays Pubilc Oncor Pacn?ic 6-33 and Elect?: Company :3 FICorp PPI. Eiectrlu Utilitie? Seru-?ce 8. Puget Sound Er-ergv Gas Company Houn' ri Power- th-m Rocky Moo". Pen-er? :30 "1mg bur-l .- Sugar-c: 5:.11 river Elm]: cr {Ir-dint ieattle Clt'y Light. Eihnhomiel?l (To-uni SourceGas South Jersey (in; 'SouLhern Cul"ornia Edison Southern California Gas Company Southern Company gob-thew Corneczrcu: G'ltz. Mini-mitt) Emu-e" Jig-ency- Err-s Tacoma Bower Tamna Eiectr'c Veiley Author Tucson Electric Power Comps-w Ear; UmSource linequ tlnnil Vecrren Vermont c-1' Pub-?c Arliaoce to SENG Em Energy-E: Energy on O'Flc?s for t: and Environmen?. Fri who-Fer CSE Lawrence Berkeley Laboratory Mae; Midwest Energy Ef?ciency flu-"nears. Emil-gr Fifi: Deanery-Moe r-fori'nrear Erergy Efl'iCIr-nc': Nlrance Dr?iLr. Ridge Manama! Laboratory Pacific Northwest N: Ion-'il . aboraiory Energy Birming- Dialer; iceel or; MDR 094 Attach 01 Page 130 of 273 ?It?s the - - ?We have 1 ?We have a sol Slaw chson. BC Hydro MDR 094 Attach 01 . It has proJecl. industrial initiatives-Premtum Efficiency Motors, Motor Systems Including th.e Motor Decisions MatterSH campaign, Distribution Transformers, .and CEE advanced savings epportunltfes In four INDUSTRIAL SECTOR expiQrfng 'an advanced roo'ftep controls in commerclat'81)i;rreations.The ETC is also atlon.of An ~rly ~~~~~ commercial develop a·proc:ed&li for Energy, end Xcel Energy. On the efficient motors front, CEE is supporting ~~r outreach, especially with greater ·~ on adjustable speed drives, motor 1~ i:>Ptimization, and motor svstem manage· merit concepts. The resulting CEE MQtor Efl/cfencY; Selection. and Management Guidebook has already become frontline consumer information for members Pacific Gas and Electric, MidAmerlcan technology providers. Vetted with energy management service and SEM elements to establish common.terms and cl8fln1tl0ns fol"key concepts. DevelOped with fr,put from more than 20 organizations. the US DePartment of Energy, and the us Environmental ~ion Agency, the elemelits were also Municipal Water and Wastewater F~J;;IIitfes. All four offer a•system and facUIP' pers~ectlve on customer solutions. The Strat-egic Enet;gy Management CSEM) exploration, as Zl pJatfol'f't'l for long-term customer engagement, made significant headway toward supporting Industrial programs. As part of that effort, CEE published Strategic Energy Management Program Case Studies. ThiS members-only report paints a landscape of SEM progtams. including goals, budgets, delivery strategy, and results. Members also .I dentified cor• tow::ca:contlnUed'to CEE members.,. sell~ to tnc:ries4t the~ they dellverto natur1l gd'C utt:omet'll$ trte·WQided c::o:stot natural gas remains explor~ this dynamic througt.l extstll'l9 errorts. Gas portfolio mana!;iers are working to Integrate new end uses and non.o.energy benefits Into programs to meet the challenges of the gas efficiency program Industry. GAS SECTOR together~ and sut*ort e new bustnfla plan fOr the ~l'gn;, ~ rno§w.repalr and 5eMce cen~«s. and motor end . adjustable spHd driYe'~rei'*; came ehefJIY ~Ieney programs. motOr twsttng ~ Based .o n thls year'$ extensive review, M~tor e ecistons Matt•r. a biMtfonal commuhleattons ~~orm. will be expanded In 2013 to pi~ mor. ernihasis 01\..~otor systems and vanablaspHd drives~total <>f 19 organf~ tndudfng A Year of Accomplishments 14-05XXX; MDR 094 Attach 01 . . . Page 131 of 273 . I'll G-aTli!..r:rrert'IC~I ,alr·.Qondl~'i~l"'lng, membe_r-s are exJ!)IQr,ih g .w.lilJ~~he-f e(llmbJned ~ystems .effl.~lene:y, startft'\9 .w ith efficient r0of;top t.i_i'lits IAtegrated Wi1ih. qema-r.tn;JPIE!~ end uses. CEE ts q>llecttng consistent IT'l fer mafiol'll•an dem·af!d control ventilation and air~flew-. man~ge"ment: This will enable members to id.entlfiY m l nim~m containment 'and control capablliti,e's ~h_at .ae-hi:ev.~ high Impact, cost-effective savings. All ~.f-tnese> areas inf_luence the Whole Building Performa,nee exploratfon; mthis are<:!~CEE assessed e]lersw management program· approaches. The commerctal sector Is looking beyond one~ for-one equipment replacement strati:!gtes towar-d advanced performance'sy~tem approaches. Notably, CEE members ara pllo:t1t:1~lthJ~ Lts~ of a Warehouse Lighting Des)s f\, eeJY)liJiate .tc:>-,.eh9bJe contractors to upsell h'lgJ:I> q~o~alley; ~l.nllll.ilhase of t:he Coalitior:'t fa.r S,.:l'itR.G-y STAR~ \Mi:lter Heat"f!rs. During the first three-,Ye~rs a.f 'tht s ~r,c:>je.~l. rking,,grj()_,yp J.o assess set-top q,o_x. ef.flo1enlSY• <\:EE lil\!e.mbef:&' continue to promote _al.!ali\~ rnsla'lla~Jori ~f H')p(c _in coordination Yli"t_ h EPA . thrmornaw clesign competition ~C!lntimue-cl to -advance Ure mar,ket for well·d~s~~ned. -efficien-t Hg-~t1 ng, eliTlphastzing· LED' fl>,<{'ure~. LED1'e_p_ 1ac::eme-nt ·lamps w >o ;;::: ·u"' c >o u N 0 N <( c 0:: "' :J "'c c. 0 ~ 14-05XXX; MDR 094 Attach 01 . . . Page 133 of 273 . 41) u 0 <: £ :;; :J E .E UJ <: "'~ >. ~ ·u t: ., >. u 0N N :J t: t: <( iii 0: ..c. 0 ~ Total revenue and support from operations Membership dues Government grants Net assets released from restrictions Other income Revenue and Support from Operations Statement of Activities Total assets Cash and investments Government grants and memberships receivable Fixed assets, net of depreciation Other assets Assets Statement of Financial Position Audited 2011 Financial Statements $3,600 $57 $2,299 $431 $813 in thousand s $1,862 $234 $92 $598 $938 in thousands Liabilities and Net Assets Nonoperating Activities $1,187 $1,240 Net assets, end of year $53 $1 ($1) in thousands $53 $3,547 $2,719 $828 in thousands $1,862 $852 $388 $567 $55 in thousands Net assets, beginning of year Change In net assets Interest income Net realized and unrealized gain on investments Increase in net assets from nonoperating activities ---------------· Net decrease in net assets from operations Total revenue and support from operations Program Administration Operating Expense ---------------- Total liabilities and net assets Current liabilities Long term liabilities Unrestricted net assets Temporarily restricted net assets 14-05XXX; MDR 094 Attach 01 . . . Page 134 of 273 . Ed Wisniewski G e:wlsnlewskf@c:ee1.org G 61i7.337.!J261 If you are interest Ady.ancing Efficien in working witb you. 14-05XXX; MDR 094 Attach 01 . . . Page 135 of 273 Consortium for Energy Efficiency CEE~ ~i G cee1.org • 617.589.3949 8 . 0 2013 Consortium for Energy Efficiency, Inc. Design: Cahoots 98 North Washington Street, Suite 101, Boston MA 02114-1918 14-05XXX; MDR 094 Attach 01 . . . Page 136 of 273 14-05XXX; MDR 094 Attach 01 . . 2012 Open to Publ1c Inspection D E""Joyorldattlflcatlon number 68-0257528 r r Name change Inrtal retum E Telephone rrenmnoll!d r r Amended ...tum AppliCatiOn pending G GR>ss 1ea11pt5 $ 3,827,466 F Name and address of pr1nc1p11l officer H(a) Is this 11 group return for ~~----~~----~----------~----~~~~~=----- EDWARD WISNIEWSKI 98 N WASHINGTON ST BOSTON,MA 02114 afflli1tes, rYes j7 No r H(b) Are all affiliates mcluded,r Yes No If "No," attach a list (see Instructions) H(c) Wet.lte: ... WWWCEEl ORG J number 589-3949 Group exemption number.,.. 1 Bnefty descnba the organization's miSSion or most s1gn1f1cant activities ENCOURAGE THE ADVANCEMENT OF ENERGY EFFICIENCY ACROSS A VARIETY OF INITIATIVES 1 Check thiS box ..,-If the organ1z1t1on d1scontmued 1ts operations or disposed of more than 25% of1ts net assets Number ofvotmg members of the govemmg body (Part VI, line la) 3 • 4 Number of mdependent votmg members of the govemmg body (Part VI, lone 1 b) 5 Total number of 1nd1v1duals employed 1n calendar year 2012 (Part V, lone 2a) 8 Total number of volunteers (estimate If necessary) • 711Total unrelated bus mess revenue from Part VIII, column (C),Ime 12 b Net unrelated business taxable mcome from Form 990-T,Iine 34 !!! ;:: Ill :0 Q• a: I !ll • d1 ~ 8 Contnbut1ons and grants (Part VIII,Iine 1h) • 9 Program serv1ce revenue (Part VIII, I me 2g) • 10 Investment 1ncome (Part VIII, column (A), lines 3, 4, and 7d) 11 Other revenue (Part VIII, column (A), lines 5, 6d, Be, 9c,10c, and lle) 11 Total revenue-add Iones 8 through 11 (must equal Part VIII, column (A), lone 13 Grants and s1mllar amounts paid (Part IX, column (A), Iones 1-3 ) 14 Benefits pa1d to or for members (Part IX, column (A),I1ne 4) 15 Salanes, other compensation, employee benefits (Part IX, column (A), lines 5-10) 14111 b Profen1onal fllndra1smg fees (Part IX, column (A), lone lle) • • , Tolal fUnd raiSing expenses (Part IX, mlumn (D), '""' 25) .,..0-.;__ _ _ _ _ _ _ __ 17 Other expenses (Part IX, column (A), lines 11a-lld, llf-24e) 18 Total expenses Add lmes 13-17 (must equal Part IX, column (A),Iine 25) 19 Revenue less es Subtract lone 18 from hne 12 , ~~ t~ ~~ z=11.... 10 Total assets (Part X, lone 16) 11 Totalllab111t1es (Part X, line 26) • 11 Net assets or fUnd balances Subtract lme 21 from line 20 Under 1 ofpel']ury, I that I have exammed th1s return, my knowledge and belief, It IS true, correct, and complete Declaration of preparer has any knowledge Sign Here For Paperwork Reduct ion Act Notice, see the MPII1'11te instructions. . . Page 137 of 273 . Form 990 (2012) Bnefly descnbe the organrzat1on's m1ss1on r Page t I Yes Yes P"' No P'" No ) (Expenses$ 2,836,665 Jncludrng grants of$ 538,506) (Revenue$ 3,288,960 ) 2 Total program service expenses II>- 4e 2,8 36,665 Other program serv1ces (Descnbe m Schedule 0 ) (Expenses $ mcludmg grants of$ 4d mdudmg grants of$ ) (Expenses$ (Code 4c 1ndud 1ng grants of $ ) (Expenses$ (Code ) (Revenue$ ) (Revenue$ ) (Revenue$ Form 990 (2012) TliE ORGANIZATION BRINGS EFFICIENCY ADMINISTRATORS TOGETHER PROVIDING A FORUM TO EXPIDRE COMMON INTERESTS STAKEHOLDERS CAN ENHANCE TliEIR INDMDUAL EFFORTS TO ADVANCE THE ENERGY EFFICIENCY MARKET BETTER ENERGY-EFFICIENCY PROGRAMS RESULT IN CONSUMER SAVINGS, REDUCED ENERGY AND WATER USAGE, BUSINESSES THAT ARE MORE PROFITABLE, LESS POWJTlON AND IMPROVED ELECTRICAL SYSTEM REL.IABD.lTY (Code Descnbe the organ1zatron's program serv1ce accomplishments for each of 1ts three largest program servrces, as measured by expenses Sectron 50 1(c)(3) and 501 (c)(4) organrzatrons are requrred to report the amount of grants and allocatrons to others, the total expenses, and revenue, 1f any, for each program servrce reported If "Yes/ descnbe these changes on Schedule 0 Drd the organrzatron cease conductrng, or make s1gnrfrcant changes m how 1t conducts, 11ny program servrces7 If"Yes,n descnbe these new servrces on Schedule 0 D1d the organrzat1on undertake any s1gnrfrcant program servrces dunng the year wh1ch were not listed on the prror Form 990 or 9 90-EZ7 4b 4a 4 3 2 CEE MEMBERS FROM ACROSS THEUS AND CANADA COMBINE THEIR STRENGTHS TO ADVANCE ENERGY EFFICIENCY FOR THE BENEFIT OF THE PUBLIC BY WORKING TOGETHER TO ENHANCE AND HARMONIZE EFFICIENCY PROGRAMS 1 I#I§JJWIII Statement of Program Service Accomplishments Check If Schedule 0 contams a response to any question m this Part III 14-05XXX; MDR 094 Attach 01 . . . Page 138 of 273 14-05XXX; MDR 094 Attach 01 . . 14-0SXXXMDR94 Attachment 01 Nevada Power Company MDR 94 Section C E Source . . Page 139 of 273 14-05XXX; MDR 094 Attach 01 . . Gain the E Source MEMBERSHIP ADVANTAGE E Source offers annual, subscription-based membership services that provide utilities with in-depth research and advice. We provide reports, presentations, best practices, benchmarks, and exclusive networking Benefits of an E SOURCE MEMBERSHIP Access for your whole team. Your company gets access to resources that will make your team more productive, help them discover solutions, and allow events as well as inquiry time with our research analysts for actionable information on industry trends, opportunities, and threats. HOW CAN E SOURCE HELP YOU? them to avoid mistakes. Inquiry time with ou1 research analysts. Think of E Source as an extension of your staff! Ask us questions, E Source can help your utility advance its energy-efficiency goals and build stronger bounce ideas off of our researchers, customer relationships with tools and insights for making better, more-informed, and or contact us whenever you need an faster business decisions. Get your staff up to speed quickly on industry best practices unbiased third-party perspective. while avoiding the mistakes others have already made. Timely research delivered multiple Our goal is to facilitate a win-win relationship between you and your customers. With E Source, you can: • Meet rapidly growing goals through more-effective design for your efficiency, demand-response, and smart grid programs ways. Get the latest independent, unbiased, and well-documented research delivered the way you want it-through reports, events, web conferences, databases, and other tools. • Get clear, balanced analysis of energy-consuming products and services so you can tell your customers about the best technologies for their applications Exclusive networking events. Develop your peer community as we facilitate • • Increase participation in your programs with data-driven analysis and your ability to meet and network with marketing best practices energy leaders from across North Create a cohesive customer experience strategy to ensure superior service and inspire loyalty • Improve business customer satisfaction through effective account management and outreach America E Source Forum. This annual event is held exclusively for E Source members. Every year, the agenda is packed with more than 25 sessions in four • • Take charge of your brand with strategies for monitoring your reputation in the topical tracks-Customer Experience, media and quickly creating thoughtful, proactive public communications Demand-Side Management, Marketing Improve customer satisfaction and productivity while driving customers to self­ service channels . and Communications, and End-Use Technologies. . Page 140 of 273 14-05XXX; MDR 094 Attach 01 . . Create the E Source Membership That's Right for You Demand-Side Management Business Marketing Technology Assessment Account Management Experien(e & CommumGlbons Management E-Channel CUSTOMER EXPERIENCE Experience & Communications Management Take charge of your reputation and messaging with tools, best practices, and benchmarks for improving brand image and customer satisfaction scores. You'll get utility-specific corporate communications strategies and case studies for crafting your customer experience road map and dealing with reputation management, crisis communications, and social media. EFFICIENCY Demand-Side Management Discover best practices that affect the entire life cycle of demand-side management (DSM) programs and portfolios-from program planning and design through evaluation. Our analysis and tools can help you successfully execute your programs and benchmark your results against other utilities, making it easier and Jess expensive to achieve energy and demand savings. Technology Assessment E-Channel Ensure that your company has the best possible online presence, which can significantly improve the efficiency of your operations. You'll have access to in-depth analysis, research, web benchmarks, and best-practice tools, helping you meet your customers' growing online requirements while increasing paperless billing adoption rates and online customer service. Utility Customer Care Enhance your utility's focus on customer service. You'll get up-to-date research on topics such as outsourcing trends, performance metrics, measuring customer satisfaction and loyalty, new technology solutions, human resource issues, and integrating customer service into your overall business operations. Easily evaluate vendor claims and quickly vet new and emerging technologies with our fuel-neutral, vendor-neutral analy­ ses of energy-using technologies. Our resources help you give sound advice to your customers, translate technical jar­ gon into layman's terms, and ensure that you won't get burned by "black boxes.H MARKETING & ACCOUN T MANAGEMENT Residential Marketing Use our data-driven analysis to develop, implement, and effectively manage your residential marketing programs. You'll get best-practice tools for advertising, segmentation, and marketing to create and promote residential programs, thereby increasing participation, outreach, Business Marketing Get the tools, research, and analysis to effectively promote your programs and services to your business customers of all sizes. Drive program participation and improve customer satisfaction with "customer-ready" content that you can share with business customers and access other resources for business customer marketing, communication, segmentation, and education. Account Management Increase your effectiveness in serving business customers of all sizes with industry-specific market intelligence, benchmarking tools, and other resources for business account management. Our tools will show you how to best manage and strengthen your business customer relationships, educate your staff, and measure the efficacy of your account management practices. Business Energy Advisor Help your commercial and industrial customers find savings and information with a web-based library that integrates with your existing website. With access to more than 100 pages of expert guidance, your customers will get the energy­ efficiency information they need to take action with your programs. revenue, and customer satisfaction. . . Page 141 of 273 14-05XXX; MDR 094 Attach 01 . . MEMBERSHIP BENEFITS The E Source Demand-Side Management Service helps utilities gain efficiencies by implementing industry best practices that affect the entire lifecycle of demand-side management (DSM) programs and portfolios-from program planning, design, and all the way through evaluation. Members get access to analysis and tools that can help you more-effectively execute your programs and benchmark your results against other utilities. We supply our members with guidance on how to reduce operating costs, defer capital expansions, and flatten your load curves, while making energy and demand savings more effective and less expensive. WHAT YOU GET WITH THE DEMAND-SIDE MANAGEMENT SERVfC~ Member Inquiries. Get just-in-time answers and consulting assistance from our experts by asking us your questions, bouncing ideas off of our researchers, or contacting us whenever you need an unbiased, third-party perspective. We'll answer your questions about program design, implementation, and evaluation for efficiency, demand response, and renewable energy programs. Research findings. With the latest independent, unbiased, and well-documented research, you'll be able to stay current on what's happening with DSM portfolios and programs across North America. We deliver actionable profiles of innovative and experimental programs and keep you up-to-date on the issues driving today's DSM market and to help you implement cost-effective portfolios. DSMdat. Our exclusive DSM programs database of more than 5,000 DSM programs in the US and Canada provides the most user-friendly and comprehensive reporting available today on energy­ efficiency, load management, demand-response, and customer-sited renewable generation offerings from electric and gas utilities, government agencies, and nonprofit organizations. oM •Ill Benchmark Studies. Our benchmark studies in Direct Load Control, Small Business Direct-Install, and DSM Achievements and Expenditures will help you compare the performance of your DSM portfolios against that of your utility peers. Web conferences and leaders group calls give you a unique opportunity to collaborate and interact with industry experts and your peers who are also being challenged to meet rapidly growing goals for energy efficiency without having to travel to a meeting or conference, saving you time and money. E Source DSM Executive Council. Nominate one high-level DSM leader to be part of our exclusive executive-only council. Council members come together twice per year to share wisdom and war stories. Members tackle strategic and management issues in a closed-door, peer-group setting where frank conversations can take place. E Source Forum. In this exclusive annual conference for E Source members, we offer a special DSM topical track as well as tracks in Customer Service, End-Use Technologies, & Marketing. Past session topics have included "deep-dive" programs, successful partnerships with vendors and contractors, optimizing your demand-response portfolio, and the impact of U.S. federal funding on DSM portfolios. Monthly e-mail newsletter. Each month, our newsletter will showcase the best utility programs and unravel key strategic and policy issues driving today's DSM market, along with top picks from recently released resources. © 2013 E Source Companies LLC . . Page 142 of 273 14-05XXX; MDR 094 Attach 01 . . ~ ANSWERING YOUR DSM QUESTIONS Here's a sample of some Member Inquiry questions we've been answering for our E Source Demand-side Management Service members: • • • • • Which vendors provide DSM tracking systems, and what features do they provide? What mechanisms do residential behavior-change programs use to claim energy savings? How much on an incentive are utilities offering for light-emitting diodes in outdoor lighting applications? Which community programs provide financing for energy-efficiency and renewable energy projects? What market penetration ranges can I expect from a residential load control program? ~ ACCESS OUR EXCLUSIVE DSM PROGRAMS DATABASE DSMdat is designed to help you get the information you need to build and improve your portfolio by giving you details on thousands of programs across North America. We update the database regularly, so you'll always have the most current information. Members save time and gain efficiencies by using DSMdat to: • Learn what programs other utilities in your state or province-or in the entire U.S. or Canada-are running Do an internal comparison of your portfolio of programs versus other similar utilities Rnd out how much of an incentive other program administrators offer Learn what measures other programs include • • • ~ VALIDATE PERFORMANCE AND MAKE INDUSTRY COMPARISONS FOR YOUR DSM PROGRAMS E Source performs comprehensive industry surveys that will allow you to find out how your programs stack up against the portfolios of other utilities. We collect and analyze data of utilities across US and Canada for: • • • m Direct Load Control (DLC) Programs Benchmark Study. Our reach in the market is extensive, accounting for nearly 50 percent of DLC participants nationwide. We have combined data on participation, available load, program expenditures, incentive methods and structures, load control technologies, and program delivery to produce benchmarking findings that shed light on trends, reveal key performance indicators, and provide rankings for how these programs stack up against one another. This benchmarking report is an invaluable tool in helping DLC program managers assess the success of their programs and identify areas for improvement. DSM Achievements and Expenditures Benchmark Study. Each year, we analyze key metrics such as overall energy savings, energy savings as a percentage of retail sales, overall portfolio cost­ effectiveness, and per-capita energy savings. This data will help you benchmark against your peer utilities and determine areas for improvement. Small Business Direct-Install Benchmark Study. We collect and analyze substantial quantitative and qualitative data from small and midsize business (SMB) efficiency programs, focusing on direct-install program~arge and small, new and old, basic and comprehensive-from across the US and Canada. Because the SMB sector generally makes up around 80 percent of a utility's commercial customer base, the results of these surveys hold huge opportunities to capture significant cost-effective energy savings. INTERACTIVE DISCUSSIONS WITH INDUSTRY EXPERTS & PEERS We know your peers are one of the best ways for you to learn and grow, which is why we facilitate several opportunities to bring you together in a secure, vendor-free environment. Membership includes attendance to our web conferences, leaders group calls, DSM Executive Council, and annual Forum conference, which all provide opportunities to learn what others are doing and ask questions on hot topics. @ 2013 E Source Companies LLC . September 2013 . Page 143 of 273 14-05XXX; MDR 094 Attach 01 . . MEMBERSHIP BENEFITS The E Source Technology Assessment Service provides utilities with objective, accurate, and defensible research and analysis about energy-consuming products and services. We give our members resources for staying abreast of the latest technology developments, technical advice, and tips to avoid getting burned by "black-box'' products, allowing you to conserve precious staff time and resources. WHAT YOU GET WITH THE TECHNOLOGY ASSESSMENT SERVICE Member Inquiries. Get just-in-time answers and consulting assistance from our experts by asking us your questions, bouncing ideas off of our researchers, or contacting us 'Nhenever you need an unbiased, third­ party perspective. Our expertise on end-use technologies is extensive-we can offer advice on everything from common household appliances to the newest emerging industrial technologies. Research findings. You'll have access to our comprehensive library of research, analysis, and tools, as well as other reference and training materials. Members also get in-depth case studies and cost-effective options for applying specific technologies and strategies. Emerging Technology Database. This repository of research gives you access to hundreds of objective studies on emerging or underutilized technologies. Web conferences and leaders group calls. Our web conferences give you a unique opportunity to collaborate and interact with industry experts and your peers without having to travel to a meeting or conference, saving you time and money. End-Use Technology Leadership Council. Nominate one high-level DSM leader to be part of our exclusive executive-only council. Council members come together twice per year to share wisdom and war stories. Members tackle strategic and management issues in a closed-door, peer-group setting 'Nhere frank conversations can take place. -.:li' E Source Forum. In this exclusive annual conference for E Source members, we offer a special End-Use Technology topical track as well as tracks in Customer Experience, DSM, and Marketing. This exclusive annual event for E Source members includes a special technology track with insights and updates on the latest technologies. Session topics include the best lighting technologies, electric vehicles, smart grid technologies, and black-box evaluations. Membership includes two seats. Monthly e-mail newsletters. Each month, our newsletter will shovvcase the latest technology developments, along with top picks from recently released resources. @ 2013 E Source Companies LLC . . Page 144 of 273 14-05XXX; MDR 094 Attach 01 . . ~ GET ANSWERS TO YOUR TECHNOLOGY QUESTIONS Here's a sample of some Member Inquiry questions we've been answering for our E Source Technology Assessment Service members: • • • • • • • I recently came across some research articles that describe potential negative health effects from the emission of UV radiation from CFLs. Is this a valid concern regarding CFL use? We're hearing about new insulating paints that claim annual cooling savings of up to 40 percent when applied to exterior walls. Can these claims be verified? How can some of the problems that come from draining a customer's electric car battery for vehicle-to­ grid implementation be avoided? Do under-roof coatings that claim to reduce radiative heat transfer through a roof actually reduce cooling loads? What causes the lights to flicker when a ground source heat pump starts up, and what can be done to fix it? How do you differentiate between efficiency measures that are considered retrofits and those that are conducted as part of existing building commissioning? What is the current status of aerogel technology? Can it be used effectiveiy in building construction? ~ STAY CURRENT ON DEVELOPMENTS IN EFFICIENCY TECHNOLOGIES All of the technology research you need is now easily accessible with the E Source Emerging Technology Database! This repository of research will give you: • • • • (\ Access to objective and rigorous studies on efficiency technologies Data to support or debunk "black-box" technologies Flexible search options that enable you to find technologies that are specific to your utility program Robust results to help guide your technology program planning TAKE ACTION WITH OUR DEFENSIBLE RESEARCH AND ANALYSIS Because technology changes quickly, we frequently publish brief reports covering the latest developments in how residential, commercial, and industrial customers are using energy. Along with these reports, you'll also have access to: • • • • lit Libraries on LED Lighting and Black-Box Technologies Technology Atlases which provide a comprehensive overview of specific technologies. Topics include lighting, space heating, residential appliances, and more. Resource Guides which provide a targeted and detailed summary of technologies such as vehicle electrification, cooling thermal storage, sector-specific demand response, and more. Operations and Maintenance Checklists which provide strategies and resources to help plan and track progress for a variety of commercial technologies. Topics include 'Nhole-building energy evaluation, and management strategies, nonrefrigerative cooling systems, commercial unitary air conditioners, and commercial lighting systems. JOIN INTERACTIVE DISCUSSIONS WITH YOUR PEERS AND INDUSTRY EXPERTS We know your peers are one of the best ways for you to learn and grow, 'Nhich is why we facilitate several opportunities to bring you together in a secure, vendor-free environment. Membership includes attendance to our web conferences, leaders group calls, End-Use Technology Leadership Council, and the annual Forum conference, 'Nhich all provide opportunities to learn what others are doing and ask questions on hot topics. «'J 2013 E Source Companies LLC . September 2013 . Page 145 of 273 14-05XXX; MDR 094 Attach 02 . . Nevada Power Company MDR 94 Section D Edison Electric Institute (EEl) . . Page 146 of 273 14-05XXX; MDR 094 Attach 02 . . I!!P!I!I Edison Electric Institute liiil.al . ,_.,....,. 701 Pemaylvania Avenue, N.W. • Washington, D.C. 20004-2696 • Phone (202) !iQ8.5IXJO Invoice for Membership Dues .... MR. MICHAEL W. YACKIRA PRESIDENT & CEO 11/21J2012 NV ENERGY POBOX98910 LAs VEGAS, NV 89151-0001 -DuEs201345 Payment due on or before 113112013 ........ , IIIII 2013 EEl Membership Dues for: Regular Activities of Edison Electric Institute 1 Industry Issues 2 Restore Power 3 $728,272 72,827 5,000 2013 Contribution to The Edison Foundation, ·which funds lEE • 15,000 Total $821:,089 1 The~ of 2013 mem~ dues relating to Influencing leglslaUon, which Is not deductible for federal Income laX purposes, II estimated to be 22. 2 The portion of the 2013 industry issueB support relating to lnftuencilg legislation is eatimaled to be 34%. 3 Restore Power is relatsd to Improvements for the rapid response to disasters. No portion of 1hls assessment is alocable to influencing legislation. 4 The Edison Foundation is an IRC 501(c)(3) educational and charitable organizaion. Conitutiona are deductible for federal income tax purpose to the extent provkied by law. Please consult your tax advisor with respect to your specific situation. PLEASE N01E INFORMAnON FOR ELECtRONIC PAYMENT The folbwing inslrudions should be used when transferring funds electronically (ACH or wire) to Edison Electric lnsli1ute: Benellclary's Bank: WeUs Fago Bank, NA Bank's Address: washington, DC S.k'l ABA Number: 121000248 Baneftclaty: Edlaan Beclrlc lnstitufa Benellclaly'l Acct No: 2000013842897 BentllclaiJ's Addr111: 701 Pennsylvania Awnue, NW Washington, DC 20004-2696 USA Beneficiary Reference: 2013 Membership Dues Please refer any questions to Teni Oliva, EEl Controller. (202) 508-5541 or membeltlues@eei.org . . Page 147 of 273 . NEVADA POWER COMPANY 378,881.97 378,881.97 (31,573.50) (31,573.50) JANUARY 315,734.98 (31,573.50) (31,573.50) (31,573.50) FEBRUARY 284,161.48 (31,573.50) (31,573.50) (31 ,573.50) MARCH (31,573.50) 221,014.48 252,587.98 (31,573.50) (31 ,573.50) MAY (31,573.50) (31 ,573.50) (31,573.50) APRIL • Nota: Per Tim Coughlin, as of 01/01/09 we will not make the addiUonalepllt of 25% to lobbying with the monthly amor11zallon. The original Invoice will be the only split between above the line and below the line. Charge all amor1lzatlon to above the line 930200 account. 347,308.47 . 178,811 .97 ADDS2013 Account Balance 165211 BAL.2012 (31,573.50) TOTALS 01113-12/13 TERM 100% TO 930200 AMORTIZATION: uUIIze dept D010 EDISON ELECTRIC INSTITUTE ACCOUNT 165211 2013 PREPAID EEl DUES AMORTIZATION SCHEDULE 189,440.99 (31,573.50) (31,573.50) (31,573.50) JUNE 157,887.49 (31 ,573.50) (31 ,573.50) (31 ,573.50) JULY 128,293.99 (31,573.50) (31,573.50) (31,573.50) AUGUST 94,720.49 (31,573.50) (31,573.50) (31 ,573.50) SEPTEMBER 83,147.00 (31,573.50) (31 ,573.50) (31 ,573.50) OCTOBER BALANCE 31,573.50 (31,573.50) (31,573.50) (31 ,573.50) (31 ,573.50) (31 ,573.50) (31,573.50) NOVEMBER DECEMBER FORWARD 14-05XXX; MDR 094 Attach 02 . . . Page 148 of 273 14-05XXX; MDR 094 Attach 02 . . SPPC Regular Activities Industry Structure Assessment Mutual Assistance Program Edison Foundation 22% 34% 0% 100% 62,485.74 9,656.86 NPC Regular Activities Industry Structure Assessment Mutual Assistance Program Edison Foundation 22% 34% 0% 100% 97,734.10 15,104.32 TOTAL COMPANY Regular Activities Industry Structure Assessment Mutual Assistance Program Edison Foundation 39% 39% 39% 39% D. Zahar 2/26/201411:26 f.N. . 2013 CAttOLATIONS Leg1slat10n allocation ACCOUNT (BTL) (ATL) 426410 5,850.00 77,992.60 9,150.00 121,988.42 SPPC 284,026.08 28,402.53 1,950.00 5,850.00 320,228.61 78% 66% 100% 0% 78% 66% 100% 0% 61% 61% 61% 61% ACCOUNT 165211 TOTAL 221,540.34 100% 284,026.08 18,745.67 100% 28,402.53 1,950.00 100% 1,950.00 5,850.00 242,236.01 320,228.61 346,511.82 100% 444,245.92 29,320.15 100% 44,424.47 3,050.00 100% 3,050.00 9,150.00 378,881.97 500,870.39 NPC 444,245.92 100% 728,272.00 44,424.47 100% 72,827.00 5,000.00 3,050.00 100% 9,150.00 15,000.00 500,870.39 821,099.00 Page 1 of 1 EEl calculation.xls . Page 149 of 273 14-05XXX; MDR 094 Attach 02 . . 7D1 PellllSJ(variaAwaue. N.W. ~ wasllinllbn. D.C. 211111'-7.696 ZD2.511.5615IW1Mf.Jii.l!rg Power by Assllciation"' 1!!1!11 Edison Electric 1iii1iii11 Institute Lewis Hay, Ill fJisimln tJf"" lloanJ November 26, 2012 Mr. Michael W. Yackira President & CEO NV Energy POBox98910 Las Vegas, NV 89151-0001 Dear Michael: Enclosed please find an invoice for your company's 2013 Edison Electric Institute dues. Our companies face many important regulatory and policy cballenges, and I hope you agree that we continue to accomplish much through our work in EEL The enclosed "2012 in Review" highlights the progress that we made to advance the industry's positions in a number of areas and demonstrates the Power by Association that EEI represents. This year, we've worked together through the Defend My Dividend campaign to advocate for an extension of today's dividend tax rates that are on par with the tax rates for capital gains. EEl also achieved favorable final roles reflecting oar positions on Dodd-Frank implementation. On cyber security, EBI organized a classified CEO briefing with the Departments of Homeland Security and Energy; developed the threat scenario project to identify and respond to key threats; and coordinated member company response to NERC's Critical Infrastructure Protection Standards. In the environmental arena, EBI continued to advocate for favorable fmal rules governing cooling water intake structures and coal ash management, while laying the groundwork for major activity on the forthcoming greenhouse gas new source performance standards. Superstorm Sandy reinforced the incomparable value of industry collaboration, as our companies united in a herculean effort to restore power lost in the wake of one of the most powerful storms on record. EEl helped to build an unprecedented public-private parmership through daily CEO calls that involved officials from several federal agencies and the White House, including President Obama on October 30, maximizing our industey's effectiveness in responding to the immense restoration challenges. Looking ahead to 2013. we anticipate a very busy legislative and regulatory agenda, and our job of educating policymakers. regulators, and other stakeholders will be as vital as ever. Strong member-company commitment remains the critical foundation of EEl's success, and I thank you for your active engagement in EEl's mission and your participation in developing common industry positions. . . Page 150 of 273 14-05XXX; MDR 094 Attach 02 . . Mr. Michael W. Yackira November 26, 2012 Page Two EEl is an important and respected resource and advocate for our industry in Washington. and it is my great privilege to serve as your EEl chairman. If you have any questions or would like to talk about EEl and its direction, please call me or Tom Kuhn. Sincerely, LewisHay,m EEl Chairman, and Executive Chairman, NextEra Energy, Inc. Enclosures . . Page 151 of 273 . 1 0000014516 Edison Ell!d:rlc lnstttutl! 1 0000014516 Edison El~c lnstltutl! 1 0000014516 Edison El!!ctric Institute Source: ERP Query-lGL_Afr_DETAIL_ALLOCATED_ERP 2013 2013 2013 APNPC APNPC APNPC SPPCO NVPWR NVPWR NVPWR NVPYJR APACC45500 APACC45497 APACC45497 0010 220 0010 210 0010 210 EEl 220 210 210 NPX1 A904 70 Cnl 0.0000 0.0000 0.0000 242236.010 121988.420 378881.970 12198!.42 378881.97 0.0000 DST 0.0000 DST llooor 0 2013 Membership Dues 0 2013 Membership Dun 0 2013 Membership Dues 0 2013 Membership Dues 14-05XXX; MDR 094 Attach 02 . . . Page 152 of 273 14-05XXX; MDR 094 Attach 02 . . 14-0SXXX MDR94 Attachment 02 Nevada Power Company MDR 94 Section D Utilities Telecom Council (UTC) . . Page 153 of 273 14-05XXX; MDR 094 Attach 02 . . Utilities Telecom Councll 1129 20th Street, NW Suite 350 Washington, DC 20036 Ullll'f!E!: TELECOrt: CO\J:JC:t Mike Zaccagnino NVEnergy . 7155 Lindell Road Invoice OV ( Invoice Date: . . ~; ' l'3 1 Las Vegas NV Description UTC Renewai'Membership Quantity 1 Price Total Amount $15,000.00 $15,000.00 -·-···---··---..·-----·------~---- ------·---------·-~·------· 2013-2014 UTC Invoice Total $15,000.00 Membership. Thank you! Taxes $0.00 Amount Paid $O.OQ PLEASE PAY $15,000.00 --·-i\'f~O--·- -·--·-- ·-.---·--·--·- . ------·-------- ·------ __________. ______ -·--·-- ~C ~ ~~ 1\(\\~ PLEASE DETACH AND REMIT WITH YOUR PAYMENT ,., 1." . ~sv t.,Ct$)'1 ~~~ Mike Zaccagnino NV Energy 7155 undetl Road Select Payment Method L Check Endosed Card Provider _ __ _ _ _ _,Exp ~te -'#____________________________ Card Card Holder's Name Card Holder's Signature Remit Payment to: UtUities Telecom Council POBox79358 Baltimore. MD 21279-0358 Total Due: $15;100.00 Amt Remitted: -.,./~--:--"l ,Ji •"; :~ ., ~~0 I htq!s:l/data.ute.orglmmwfllldex.pbp . j m.912013 . Page 154 of 273 . 10 10/3/2013 00605929 10 10/3/2013 00605929 1 0000012556 Utilities Tel~am Council 1 0000012556 Utilities Telecom Coundl Source: ERP Query- ZGI.,_AP_DETAil,_AU.OCATED_ERP 2013 2013 Vonclor,... Utilities Telecom Coundl Utilities Telecom Coundl APNPC APNPC APNPC NVPWR NVPWR NVPWR NVPWR NVPWR NVPWR APACCS86-I-4 APACCS8644 APACCS8644 0806 210 0806 210 UTC 510 610 A381 70 NPCl NPCl Nev•d• Power A381 10 A381 70 NPC1 C927 C927 am 7,500.00 7,500.00 7,500.00 7.8000 37.1000 585.00 2,782.50 1.0000 DST 1.0000 DST 0001029621 0001029621 Deoor 1 2013-2014 UTC Membership 1 2013-2014 UTC Member$hip 1 2013-2014 UTC Membership 1 2013·2014 UTC Membersttlp 14-05XXX; MDR 094 Attach 02 . . . Page 155 of 273 14-05XXX; MDR 094 Attach 02 . . 14-0SXXX MDR94 Attachment 02 Nevada Power Company MDR 94 Section D Western Electricity Coordinating Council (WECC) . . Page 156 of 273 14-05XXX; MDR 094 Attach 02 . . ·~ I WECC ACCOUNT: Nevada Power Company dba NV Energy INVOICE#: A130086 P.O. Box 10100 6100 Nell Road Reno, NV 89520 INVOICE DATE: November 15, 2012 DUE DATE: January 2, 2013 ATTENTION: Mario Villar FOR: 2011 Annual Net Energy for Load and 2013 Assessments This invoice is for load within the following Balancing Authority: Nevada Power Company The Balancing Authority reported your Net Energy for Load (NEL) MWh as: 21,639,158 The WECC Board of Directors (on June 25, 2012) and the Federal Energy Regulatory Commission (FERC) (on November 2, 2012) approved an assessment of $40,962,547 to Western Interconnection Balancing Authorities and/or Load-Serving Entities for WECC's 2013 Statutory Costs. Your organization's share of that assessment is listed below. This amount was calculated in accordance with Section 12 of the WECC Bylaws. Also listed below are your organization's shares of the North American Electric Reliability Corporation's and Western Interconnection Regional Advisory Body's 2013 Statutory Assessments, as approved by FERC on November 2, 2012. Description Amount Western Electricity Coordinating Council (WECC) Statutory Assessment North American Electric Reliability Corporation (NERC) Statutory Assessment Western Interconnection Regional Advisory Body (WIRAB) Statutory Assessment Total Due: $1,043,243 $230,757 $13,506 $1,287,507 Payment is due no later than January 2, 2013. Please reference the invoice number on all forms of payment, including wire transfers. If you have any questions or concerns, please contact Scott Roberts at (801) 883-6893 or by email at Assessments@wecc.biz. Please make checks payable to: WESTERN ELECTRICITY COORDINATING COUNCIL WESTERN ELECTRICITY COORDINATING COUNCIL • WWW.WECC.BIZ 155 NORTH 400 WEST • SUITE 200 • SALT LAKE CITY • UTAH • 84103-1114 • PH 801.582.0353 • FX 801.582.3918 . . Page 157 of 273 14-05XXX; MDR 094 Attach 02 . . T: WECC I Nevada Power Company 2011 NEL and 2013 Assessments Load-Serving Entity City of Boulder City Colorado River Commission of Nevada Lincoln County Power District No. 1 Net Energy for Load 162,539 801,002 Overton Power District No. 5 90,235 378,808 Valley Electric Association, Inc. 413,528 City of Las Vegas Las Vegas Valley Water District Southern Nevada Water Authority City of Henderson Clark County Water Resources Nevada Power Company dba NV Energy Total 45,810 90,574 790,997 14,207 6,075 21,639,158 24,432,933 Percent of Total NEL (%) 0.6652% 3.2784% 0.3693% 1.5504% 1.6925% 0.1875% 0.3707% 3.2374% 0.0581% 0.02491'/0 88.5655% 100.0000% WECC Assessment $7,836 NERC Assessment $1,733 WIRAB Assessment $101 $38,617 $4,350 $8,542 $962 $500 $18,263 $4,040 $236 $19,937 $4,410 $258 $2,209 $4,367 $489 $966 $29 $57 $38,135 $685 $8,435 $152 $494 $9 $293 $1,043,243 $65 $230,757 $4 $13,506 $1,177,934 $260,550 $15,250 $56 WESTERN ELECTRICITY COORDINATING COUNCIL • WWW.WECC.BIZ 155 NORTH 400 WEST • SUITE 200 • SALT LAKE CITY • UTAH • 84103-1114 • PH 801.582.0353 • FX 801.582.3918 . . Page 158 of 273 14-05XXX; MDR 094 Attach 02 . . 2011 Balancing Authority Area NEL and 2013 Assessments Balancing Authority Alberta Electric System Operator Net Energy for Load 58,737,634 Arizona Public Service Company 32,148,109 3.7527% Avlsta Corporation 12,614,204 1.4725% Bonneville Power Administration 54,888,094 British Columbia Hydro Comision Federal de Electricidad PUD No. 1 of Chelan County california Independent System Operator Percent of Total NEL (%) 6.8566% WECC Assessment $2,201,651 NERC Assessment $466,437 WIRAB Assessment $36,662 $1,549,891 $342,822 $20,065 $608,141 $134,516 $7,873 6.4072% $2,646,205 $585,319 $34,259 60,568,272 7.0703% $3,167,462 $683,972 $37,804 11,041,442 1.2889% S5n,42o $124,686 $6,892 3,782,502 0.4415% $182,358 $40,336 $2,361 229,559,674 26.7972% $11,067,279 $2,447,993 $143,282 PUD No. 1 of Douglas County 1,435,488 0.1676% $69,206 $15,308 $896 El Paso Electric Company 8,342,238 0.9738% $402,187 $88,961 $5,207 PUD. No. 2 of Grant County 4,150,711 0.4845% $200,110 $44,263 $2,591 Imperial Irrigation District 3,598,464 0.4201% $173,485 $38,374 $2,246 Idaho Power Company 16,653,214 1.9440% $802,866 $1n,588 $10,394 Los Angeles Department of Water and Power 28,863,039 3.3693% $1,391,513 $307,792 $18,015 Nevada Power Company 24,432,933 2.8521% $1,1n,934 $260,550 $15,250 PaclfiCorp Eastern Balancing Area 47,858,167 5.5866% $2,307,285 $510,353 $29,871 PaclflCorp Western Balancing Authority 20,883,821 2.4378% $1,006,828 $222,702 $13,035 $12,865 Portland General Electric Company 20,611,284 2.4060% $993,689 $219,796 Public Service Company of New Mexico 15,257,277 1.7810% $735,567 $162,702 $9,523 Public Service Company of Colorado 42,291,121 4.9368% $2,038,893 $450,987 $26,396 $15,709 Puget Sound Energy 25,168,550 2.9380% $1,213,399 $268,394 Seattle Department of Ughting 10,188,883 1.1894% $491,215 $108,653 $6,360 Balancing Authority of Northern Csllfomla 17,452,751 2.0373% $841,412 $186,U4 $10,893 Sierra Pacific Power Company 11,425,347 1.3337% $550,826 $121,838 $7,131 Salt River Project 30,360,138 3.5440% $1,463,690 $323,756 $18,950 Tucson Electric Power Company 13,594,185 1.5869% $655,388 $144,967 $8,485 2,499,228 0.2917% $120,490 $26,651 $1,560 Turlock Irrigation District 10,747,661 1.2546% $518,154 $114,612 $6,708 5,074,707 0.5924% $244,656 $54,116 $3,167 Western Area Power Administration - Col orad 23,240,509 2.7129% $1,120,446 $247,834 $14,506 Western Area Power Administration, Lower Co 8,576,929 1.0012% $413,501 $91,463 $5,353 Western Area Power Administration - Upper G 609,796 0.0712% $29,399 $6,503 $381 $40,962,547 $9,020,357 $534,692 NorthWestern Energy Tacoma Power Total 856,656,372 100.0000% WESTERN ELECTRICITY COORDINATING COUNCIL • WWW.WECC.BIZ 155 NORTH 400 WEST • SUITE 200 • SALT LAKE CITY • UTAH • 84103-1114 • PH 801.582.0353 • FX 801.582.3918 . . Page 159 of 273 . Western Eloctriclty CoonllnBti!!l! Council 2013 Annual Dues Paid in 2012 563000 D200 510 NPC1 A355 81 C200 PRPDDuea NEVADA POWER COMPANY Aooount 1165136 2013 Aooount Balance 1/1/2013-12/31/2013 Balance 858,338.00 1,072,922.50 1,180,214.75 966,630.25 (107,292.25) (107,292.25) (107,292.25) APRIL (107.292.25) MARCH 1.287,507.00 FEBRUARY (107,292.25) (107,292.25) (107,292.25) JANUARY (107,292.25) 2013 Adcltlon• 1,287,507.00 12/31/12 (107,292.25) 643,753.50 751,045.75 (107,292.25) JUNE (107,292.25) (107,292.25) MAY 536,461.25 (107.292.25) (107,292.25) JULY 429,169.00 (107,292.25) (107,292.25) AUG 321,876.75 (107.292.25) (107.292.25) SEPT 214,584.50 (107.292.25) (107,292.25) OCT 107,292.25 (107,292.25) (107,292.25) NOV (107,292.25) (107,292.25) DEC FORWARD 14-05XXX; MDR 094 Attach 02 . . . Page 160 of 273 14-05XXX; MDR 094 Attach 02 . . 14-0SXXX MDR94 Attachment 02 Nevada Power Company MDR 94 Section D Western Energy Supply and Transmission Association (WEST) . . Page 161 of 273 14-05XXX; MDR 094 Attach 02 . . - Western Energy Supply and Transmission Association WEST AssOCIATES Starla Lacy WEST Associates' Treasurer 6226 W Sahara Ave, M/S 30 Las Veoas. NV 89146-0001 12/10/2013 I 44 NV Energy Starla Lacy 6226 West Sahara Ave Las Vegas, NV 89146-0001 · fiii(o • ~~ Dues . ".t~!llir~ill!E. Wl®lJ 2014 WEST Associates Dues A total of 10% of the 2014 dues are non-deductible to me mbers fo r lobbying 28,511.00 Total $28,511.00 . Page 162 of 273 . 12/13/2013 00613501 12 1 0000018644 WEST Associates 1 0000018644 WEST Associates Source: ERP Query- ZGL_AP_DETAI1..}1110CATED_ERP 12/13/2013 00613501 12/13/2013 00613501 12 12 2013 2013 2013 APNPC APNPC NVPWR NVPWR NVPWR NVPWR APACC62385 APACC62385 0857 210 0857 210 0857 210 West Associates 410 510 610 0010001972 0010001972 0010001912 C952 C952 A3So ·1o C952 A3jO 70 28,511.00 2s,su.oo 28,511.00 37.1000 7.8000 53.6000 to,sn.ss 2,223.85 15,281.89 1.0000 DST 1.0000 DST 0 WEST Associates Dues- 2014 0 WEST Associates Dues - 2014 0 WEST Associates Dues- 2014 14-05XXX; MDR 094 Attach 02 . . . Page 163 of 273 14-05XXX; MDR 094 Attach 02 . . 14-05XXXMDR94 Attachment 02 Nevada Power Company MDR 94 Section D Consortium for Energy Efficiency, Inc. (CEE) . . Page 164 of 273 14-05XXX; MDR 094 Attach 02 . . CEE~ Invoice - Consortium for Energy Efficiency, Inc. 98 North Washington Street Suite 101 Boston, MA 02114-1918 Date Invoice# 31111.2013 !42013-72 Bill To NV Energy LaayHolmes 6226 W. Sahara Blvd Las Vegas. NV 89151 Terms Net30 Description Membership Dues - based on Electric Customer Count: for tbe period lllfl013- 1213112013 Membership Minimum Dues <250,000 ' . : . •'• • • t• • • •'• • ••! •'•• ',, ••• '_.,, '' ' ~ ' • • ' 0 ' ' ' ' ''' 0 ' : • ."''• ,, , '' ' , ', ,• '• ,, , ,•,, ,• o., ':, • ••• ,, , 0 •:, • •• I , •• Membership is intended for organizations that are entrusted by a regulatory or legislative authority to admlnister energy efficiency programs for the entity's constituents. Membership is also open to other public benefit organizations that wish to advance the work at the Consortium and whose mission and . . Page 167 of 273 14-05XXX; MDR 094 Attach 02 . . . . .... • _. . -- .. . ... ... ---·--. -· - - ·- - --- -· ... ~ ~ . - .. .. .. ... ... ... . . ... ._ .. ' ·-- . . .... _ .. :._ ...... . :. ·, .. . operations axe compatible with that of the Consortium. Members comprise utilities, including investor· owned, municipally managed, and authorities of a state or province; state efficiency program administrators; state energy offices; nonprofit program administrators; nonprofit research or advocacy organizations; and :pationallaboratories engaged in re~earch.re1ated to energy effi.ci~ncy, M.~~.b~rship_C~t~:gories _·. ._:_ ·,· ·.. . . · .· The definitions below axe ~ed in determining membership category for dues calculation. Efficiency Program Administrator An entity entrusted by a state, province, county, or other jurisdictional body,legislative or regulatory, to administer energy efficiency programs on behalf of the entity's constituency. Special Utility . . A speciall,ltility is a distinction provided :to th.ose whose ratepa~rs are represented at CEE by.a separate ·~fficiency ·pro.~m ~~at.Or, yet wish to parti~pate directly ~t CEE ~ a member . . . . . . . .. - . . . -. Efficiency Organization Efficiency organizations and R&D laboratories are evaluated for membership on a case-by-case basis to determine their alignment with the CEE mission. Efficiency organizations are not charged with . . a~te~ p~ograms. . ·.. it • • • State Government-A state government ,agency wi~ aJ;l energy efficiency up.iesion. National ~vermi:ten~A national govenim.ent ~ncy wi~. an energy ef;ficiency mission. R&D Organization-A federal, state, nonprofit, or higher educ~ti9n organization involved in energy efficiency research and development. Nonprofit-A public purpose organization deemed to l:!e supportive of the CEE mission and complementary to its operations. Membership eligibility, categories, and dues are subject to change without notice at the disctetion of the Board of Directors of CEE. Members and on behalf of members are . those attending any meeting . expected to abide by CEE published po~es and guide~es. •• . Working Together, Advancing'Effic:ieney . •1 · . . . . . .. . -• • - ... . -- • ..: • .. 2 . Page 168 of 273 . 2013 10 1 0000027429 Consortium for Energy Efflci!!ncy Source: ERP Query- ZGL_AP_DETAIL_ALLOCATI!!D_ERP APNPC NVPWR NVPWR APACC599£.5 CEE 410 NPC1 A381 70 C640 19,070.95 ~ O.OO::C ~ 1.0000 DST 14-05XXX; MDR 094 Attach 02 . . . Page 169 of 273 14-05XXX; MDR 094 Attach 02 . . 14-0SXXXMDR94 Attachment 02 Nevada Power Company MDR 94 Section D E Source . . Page 170 of 273 14-05XXX; MDR 094 Attach 02 . . •••"' 0 0 • • • : ••••• , , , _ _ • " . . : , , , , .. • · - ;' . · , ; , • •• ",.. • -•···~·••• ••• ••• "•• ,'. ", '•••• ''"'" ••· •• ••• ••- oool • "'''''''', • :•·• o ., • Mo • *' " - ·: • • 0 • • • ••• \. • • : ~ .. • •. . . :·· INVOICE 174538th S1rHt, Boulder, Coloralfa ~1 ~ Bill To 11~13 2237 N P~ rnvokle # NVEne(Q)' Melissa Fernandez 6226 West Sahara las Vegas, NV 89146· P.O. No. Terms Due on receipt · Amount 27,980.00 27,960.00 T9chnology Assessment Service Membemhip Demand-Side ~anagement Service !"embersllip Period ot serviCe:. {O~ID~I2014" 1213112014.) .. = Please Remit to: Attn: Accls Receivable e Source Companies, LLC 1745 38th Street Boulder, CO 80381 FoderaiiDI: 20-44028?'0 ·.· For Electronic Payment: ColoraCto Business Bank 82t 17th Sln!ef: . . . ~~~;w~~ilii.~:~~·.·:·: Aceount no.: 3444899 Routing no.: 102003206 . . . . ::. . ·.·.:.:. . ·.-:... ::. .·.: ·.·. : ·: .-: ·.~· :. :.·. :.. ·~ .~·:: :.· .-. . .: .· ·: . .:..:. ··. . . . . . :::.- ·::·.·.· -.· ....:..... :.·.:·:: ~ .- . . .. . · · To pay by credit card, please confactAIIcla at3D3.345.9106. . . Page 171 of 273 Attach 02 MDR 094 Page 172 of 273 Nevada Power Company d/b/a NV Energy RESPONSE TO INFORMATION REQUEST DOCKET NO.: 14-05XXX REQUEST NO.: MDR 095 REQUESTER: REQUEST DATE: 2/4/2014 RESPONDER: McLean, Erika REQUEST: Contributions. For employee associations, sports related expenditures, universities and colleges, support for the arts, charitable contributions, musical events, political contributions, legislative efforts, and any other similar expenditure: a. Provide by account for the test period, the dollar amount that the company is requesting recovery in its revenue requirement. List amounts paid directly, by reimbursement, or otherwise booked by the company. For each, describe the purpose of the expenditure and provide any information that establishes a causal relationship between the expenditure and corporate performance. b. Provide copies of paid vouchers and invoices supporting these expenditures. c. Disclose whether all or any portion of any such expenditure was allocated or charged to the company and disclose the amount so charged or allocated. Show where and exactly how such items charged to the company appear in this case. RESPONSE CONFIDENTIAL (yes or no): No TOTAL NUMBER OF ATTACHMENTS: None RESPONSE: The Company is not seeking recovery of any listed expenses. Page 173 of 273 Nevada Power Company d/b/a NV Energy RESPONSE TO INFORMATION REQUEST DOCKET NO.: 14-05XXX REQUEST NO.: MDR 096 REQUESTER: REQUEST DATE: 1/31/2014 RESPONDER: McDonald, Gary REQUEST: Operational performance metrics. Provide a list of operational performance metrics routinely utilized by the applicant during the test period that demonstrate efficient business practices and procedures are used in the normal course of business. For each metric listed, include a description and sufficient information to readily locate any related documentation. RESPONSE CONFIDENTIAL (yes or no): No ATTACHMENTS CONFIDENTIAL (yes or no): No TOTAL NUMBER OF ATTACHMENTS: One RESPONSE: Please see attached file for 2013 performance metrics which were utilized by Nevada Power during the test period. Page 174 of 273 . . December 17, 2013 President and Chief Executive Officer Michael Yackira (STIP) 2013 Compensation Committee Short Term Incentive Program BOARD/CONFIDENTIAL . . 14-05XXX; MDR 096 Attach 01 Page 175 of 273 . . 0 1 2.80 2.15 1.04 90% Score 2 2 3 2013 MPAT STIP Score Histogram *Merger costs have been excluded from the Payout % calculation Off Target Below Target 1 1 Above Target On Target 1 Well Beyond Target MPAT Operational Excellence MPAT Customer Satisfaction Financial Performance Payout %* MPAT STIP Off Target 0 Below Target 1 4 4 12/16/2013 On Target 2 Above Target 3 5 Well Beyond Target 4 2 BOARD/CONFIDENTIAL . . 14-05XXX; MDR 096 Attach 01 Page 176 of 273 . . 0 1 *Merger costs have been excluded from the Payout % calculation Off Target 1 2 On Target Below Target 2 1 3.04 2.38 1.04 94% Score 2 2013 L1245 STIP Score Histogram Above Target Well Beyond Target 1245 Operational Excellence 1245 Customer Satisfaction Financial Performance Payout %* 1245 STIP Off Target 0 3 3 Below Target 1 12/16/2013 On Target 2 Above Target 3 4 Well Beyond Target 4 3 BOARD/CONFIDENTIAL . . 14-05XXX; MDR 096 Attach 01 Page 177 of 273 . . NVE B) Preventable Vehicle Accidents MPAT Operational Excellence Score Zero Major Notices of Violation (NOV) & no more than 2 minor NOV 2) Compliance Metrics Calculation: Safety Control Report Source Data: OSHA 300 Log NVE A) OSHA Recordable Incident Rate 1) Safety MPAT Operational Excellence - 30% of Total STIP 20% 20% 60% Weight % 66 2.41 FY 2012 Actual 43 2.36 2013 Target 54 1.49 2013 Actual 2.80 2.00 0.02 4.00 Score 0 N/A 54 1 N/A 49 2.66 1 0 2.95 Below Target Off Target MPAT Operational Excellence 2 0 NOV & 2 or less Minor Violations 43 2.36 2 On Target 2013 Ranges 3 N/A 38 2.07 3 Above Target 4 N/A 32 1.77 4 4 Well Beyond Target BOARD/CONFIDENTIAL . . 14-05XXX; MDR 096 Attach 01 Page 178 of 273 . . NVE-N B) Preventable Vehicle Accidents L1245 Operational Excellence Score Zero Major Notices of Violation (NOV) & no more than 2 minor 2) Compliance Metrics Calculation: Safety Control Report Source Data: OSHA 300 Log NVE-N A) OSHA Recordable Incident Rate 1) Safety L1245 Operational Excellence - 30% of Total STIP 20% 20% 60% Weight % 21 4.26 FY 2012 Actual 17 3.94 2013 Target 18 1.89 2013 Actual 3.04 2.00 1.18 4.00 Score 0 N/A 21 1 N/A 18 4.43 1 0 4.93 Below Target Off Target 1245 Operational Excellence 2 0 NOV & 2 or less Minor Violations 17 3.94 2 On Target 2013 Ranges 3 N/A 15 3.45 3 Above Target 4 N/A 13 2.96 4 Well Beyond Target 5 BOARD/CONFIDENTIAL . . 14-05XXX; MDR 096 Attach 01 Page 179 of 273 . . NVE NVE *Merger costs have been excluded from the O&M total MPAT Customer Satisfaction Score O&M MWh Calculation: O&M (in 000s) divided by MWh sold; based on actuals Source Data: Earnings Model, ERP and General Ledger 5% 10% NVE 7.5% 7.5% 70% Weight % 3) Total Non-Fuel O&M vs. MWh Sold ($/MWh)* Definition: Measure that indicates the percentage of time a generating unit was fully available for service during a period C) Equivalent Availability Factor (EAF) Calculation: Total net accumulated customer interruptions over a given period divided by the average the number of customers served during that period. It is expressed as interruptions / customer Note: Targets are set based on a 5-year average (Actuals excluding high and low values) B) SAIFI Calculation: Total net customer outage hours divided by average number of customers served. Expressed as hours/customer. Source Data: Monthly Distribution Reliability Report A) SAIDI 2) Reliability Calculation: Goal ranges are based on results at year end (summing across all four quarters at the 90% confidence level). The percentages represent the percent of customers who provide an "overall satisfaction" rating on a 0-10 scale. Weighted 50/50 between North and South Source Data: Customer Satisfaction & Loyalty Survey conducted by Market Strategies. Final score rounded to the nearest decimal 1) NV Energy Customer Perception MPAT Customer Satisfaction - 35% of Total STIP $16.50 87.70 0.4652 0.7588 72.0% 2013 Target $16.81 86.31 0.5930 1.0854 73.5% 2013 Actual $455,209 $457,145 $442,922 29,418,019 26,838,786 27,072,587 $15.54 86.30 0.5363 0.9126 71.8% FY 2012 Actual 2.15 0.11 1.60 0.00 0.00 2.94 Score 0 102% 93% 120% 1 101% 96% 110% 110% 1 70.0% 0 68.0% 120% Below Target Off Target MPAT Customer Satisfaction 2 100% 100% 100% 100% 2 72.0% On Target 2013 Ranges 3 99% 103% 95% 95% 3 73.6% Above Target 4 98% 107% 90% 90% 4 75.2% 6 Well Beyond Target BOARD/CONFIDENTIAL . . 14-05XXX; MDR 096 Attach 01 Page 180 of 273 . . NVE-N NVE-N *Merger costs have been excluded from the O&M total L1245 Customer Satisfaction Score O&M MWh Calculation: O&M (in 000s) divided by MWh sold; based on actuals Source Data: Earnings Model, ERP and General Ledger 5% 10% NVE 7.5% $16.50 87.70 0.7389 1.3036 72.0% 2013 Target $16.81 86.31 0.8420 1.2680 73.5% 2013 Actual $457,145 $442,922 $455,209 29,418,019 26,838,786 27,072,587 $15.54 86.30 0.8016 1.5941 71.8% 70% 7.5% FY 2012 Actual Weight % 3) Total Non-Fuel O&M vs. MWh Sold ($/MWh)* Definition: Measure that indicates the percentage of time a generating unit was fully available for service during a period C) Equivalent Availability Factor (EAF) Calculation: Total net accumulated customer interruptions over a given period divided by the average the number of customers served during that period. It is expressed as interruptions / customer Note: Targets are set based on a 5-year average (Actuals excluding high and low values) B) SAIFI Calculation: Total net customer outage hours divided by average number of customers served. Expressed as hours/customer. Source Data: Monthly Distribution Reliability Report A) SAIDI 2) Reliability Calculation: Goal ranges are based on results at year end (summing across all four quarters at the 90% confidence level). The percentages represent the percent of customers who provide an "overall satisfaction" rating on a 0-10 scale. Weighted 50/50 between North and South Source Data: Customer Satisfaction & Loyalty Survey conducted by Market Strategies. Final score rounded to the nearest decimal 1) NV Energy Customer Perception L1245 Customer Satisfaction - 35% of Total STIP 2.38 0.11 1.60 0.60 2.55 2.94 Score 0 102% 93% 120% 1 101% 96% 110% 110% 1 70.0% 0 68.0% 120% Below Target Off Target 1245 Customer Satisfaction 2 100% 100% 100% 100% 2 72.0% On Target 2013 Ranges 3 99% 103% 95% 95% 3 73.6% Above Target 4 98% 107% 90% 90% 4 75.2% 7 Well Beyond Target BOARD/CONFIDENTIAL . . 14-05XXX; MDR 096 Attach 01 Page 181 of 273 . . *Merger costs have been excluded from the EPS calculation Financial Performance Score Source Data: 10Q, 10K, and general ledger, Earnings Model EPS Forecast vs. Actual* 1) Optimize Shareholder Value Financial Performance - 35% of Total STIP 100% Weight 2 % t 100% 2013 Target $1.25 96% 2013 Actual 1.04 1.04 Score Financial Performance 0 92% Off Target 0 1 96% Below Target 1 2 100% On Target 2 2013 Ranges 3 104% Above Target 3 4 108% 8 Well Beyond Target 4 BOARD/CONFIDENTIAL . . 14-05XXX; MDR 096 Attach 01 Page 182 of 273 Nevada Power Company d/b/a NV Energy RESPONSE TO INFORMATION REQUEST DOCKET NO.: 14-05XXX REQUEST NO.: MDR 099 REQUESTER: REQUEST DATE: 2/4/2014 RESPONDER: Foley, Patrick REQUEST: Vintage Year Costs. Provide transmission system, preferably in a computer file or files, for each vintage year through the end of the test period for each voltage class the installed cost and the installed linear feet for the transmission system. RESPONSE CONFIDENTIAL (yes or no): No ATTACHMENTS CONFIDENTIAL (yes or no): No TOTAL NUMBER OF ATTACHMENTS: One RESPONSE: Please see the attached spreadsheet which provides installed costs by vintage year and voltage class (where available) for the transmission system. Linear footage in transmission are not recorded in the Power Plant fixed asset database system and therefore, not available. Page 183 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1938 1938 1938 Total 1940 1940 1940 1940 Total 1946 1946 Total 1951 1951 Total 1954 1954 Total 1955 1955 1955 1955 1955 Total 1956 1956 1956 1956 1956 1956 1956 1956 Total 1957 1957 1957 1957 1957 1957 1957 Total 1958 1958 Total Major location NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 69.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 69.0 NPC TS - Transmission Sub 69.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC SP - CLARK STATION NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC TS - SPARE PARTS NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 69.0 NPC TS - Transmission Sub 230.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 1,207.26 57,593.09 58,800.35 49.09 6,550.00 1,462.86 8,061.95 198,540.51 198,540.51 179,820.06 179,820.06 10,000.00 10,000.00 37,654.12 11,516.99 85,103.89 5,505.35 139,780.35 151,651.90 (0.00) 87,123.18 35,348.21 68,764.01 480,960.51 486,580.83 1,310,428.64 3,366.46 4,614.79 187.32 13,652.37 617,669.06 50,886.96 690,376.96 378.34 378.34 Page 184 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1959 1959 1959 1959 1959 Total 1960 1960 1960 1960 Total 1961 1961 1961 1961 1961 1961 1961 Total 1962 1962 1962 1962 1962 Total 1963 1963 1963 1963 1963 1963 1963 Total 1964 1964 1964 1964 1964 1964 Total 1965 Major location NPC TL - Transmission Line 69.0 NPC TS - SPARE PARTS NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 69.0 NPC SP - CLARK STATION NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 69.0 NPC SP - CLARK STATION NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC SP - REID GARDNER STATION $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 136,448.52 4,556.83 39,323.47 14,308.69 194,637.51 173,452.28 1,059.71 1,994.93 176,506.92 287,030.47 19,266.92 2,756.70 37,228.35 306,907.15 3,322.89 656,512.48 25,192.38 13,980.83 54,351.53 9,483.45 103,008.19 8,919.05 156.01 200,707.84 81,359.74 98,964.30 84,883.44 474,990.38 7,070.95 213,127.37 131,798.58 7,810.38 155,224.27 515,031.55 465,962.95 Page 185 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1965 1965 1965 1965 1965 1965 1965 Total 1966 1966 1966 1966 1966 1966 Total 1967 1967 1967 1967 1967 1967 Total 1968 1968 1968 1968 1968 1968 1968 1968 Total 1969 1969 1969 1969 1969 1969 1969 1969 Total Major location NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC SP - REID GARDNER STATION NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 340,337.79 1,523,931.50 37,726.18 161,954.68 680,077.39 37,327.24 3,247,317.73 28,013.96 139,528.82 87,249.81 43,614.72 1,402.11 299,809.42 51,576.90 244,780.34 10,233.90 226,564.46 58,428.87 591,584.47 58,000.00 139,142.15 1,472,764.32 72,760.34 491,259.66 1,051,729.94 73,032.40 3,358,688.81 14,877.22 384,508.74 112,986.18 352,160.12 76,685.88 1,071,023.00 994.84 2,013,235.98 Page 186 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1970 1970 1970 1970 1970 1970 1970 1970 1970 Total 1971 1971 1971 1971 1971 1971 1971 1971 1971 1971 Total 1972 1972 1972 1972 1972 1972 1972 1972 1972 Total 1973 1973 1973 1973 1973 1973 1973 Major location NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC SP - MOHAVE STATION NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 52,768.41 4,236.86 305,734.84 1,548,473.72 65,929.92 18,378.62 1,147,144.60 101,945.35 3,244,612.32 51,799.76 532,347.70 6,447.45 5,394.04 684,354.27 17,689.73 74,892.53 46,462.57 92,653.67 1,512,041.72 17,930.08 (12,292.08) 27,697.05 19,856.92 402,113.34 13,944.86 942,329.43 759.48 1,412,339.08 79,183.84 3,622.92 31,171.76 99,508.51 353,822.05 50,832.33 334,975.75 Page 187 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1973 Total 1974 1974 1974 1974 1974 1974 1974 1974 1974 1974 1974 1974 Total 1975 1975 1975 1975 1975 1975 1975 1975 1975 1975 1975 1975 1975 Total 1976 1976 1976 1976 1976 1976 1976 1976 1976 Major location NPC DS - Distribution Substation NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC SP - NAVAJO ST (AZ) Do Not Use NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC SP - NAVAJO ST (AZ) Do Not Use NPC SP - REID GARDNER STATION NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 953,117.16 23,343.71 1,982,024.22 2,569,418.79 514,803.38 17,591.44 53,481.18 4,728.06 186,173.08 133,927.40 27,348.03 545,875.83 6,058,715.12 14,559.05 232,108.43 2,881,092.37 3,194,540.02 604,414.56 109,479.74 848,078.13 15,490.57 198,162.77 41,006.23 1,548.47 1,265.47 8,141,745.81 191,679.20 331,686.40 2,495,836.48 1,822,246.62 630,713.53 4,035.10 83,771.55 237,642.51 1,642,512.97 Page 188 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1976 1976 Total 1977 1977 1977 1977 1977 1977 1977 1977 1977 1977 1977 1977 Total 1978 1978 1978 1978 1978 1978 1978 1978 1978 1978 1978 1978 Total 1979 1979 1979 1979 1979 1979 1979 1979 1979 Major location NPC TS - Transmission Sub 69.0 NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 287.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 56,861.53 7,496,985.89 77,080.09 32,053.19 9,013.02 121,931.47 6,737.50 4,665.14 96,314.00 30,044.05 1,966,188.22 1,018,844.40 65,224.97 3,428,096.05 75,789.38 174,423.35 2,036,385.03 37,019.59 970,237.12 415.37 65.54 344,617.53 261,702.72 18,696.26 47,335.80 3,966,687.69 39,454.84 641,842.26 134,049.84 41,607.66 96,687.33 3,420.00 209,588.24 343,714.15 1,226,018.53 Page 189 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1979 1979 Total 1980 1980 1980 1980 1980 1980 1980 1980 1980 1980 1980 1980 Total 1981 1981 1981 1981 1981 1981 1981 1981 1981 1981 1981 Total 1982 1982 1982 1982 1982 1982 1982 1982 1982 1982 Major location NPC TS - Transmission Sub 230.0 NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 287.0 NPC TS - Transmission Sub 69.0 NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - 1982 SPEED CLOSINGS NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 138,463.62 2,874,846.47 (31,185.97) 14,411.35 400.35 302,418.51 996,058.52 52,782.63 439,095.68 413,081.13 368,368.45 19,616.98 90,151.66 2,665,199.29 401,195.30 10,580.76 447.49 572,974.00 969,118.77 111,293.44 1,780,474.50 731,860.95 2,415,757.34 52,272.74 7,045,975.29 (0.01) 33,292.66 1,413,589.15 4,668.72 4,576.18 425,428.56 5,997.55 3,467,793.21 427,125.28 33,303.04 Page 190 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1982 Total 1983 1983 1983 1983 1983 1983 1983 1983 1983 1983 1983 1983 1983 Total 1984 1984 1984 1984 1984 1984 1984 1984 Total 1985 1985 1985 1985 1985 1985 1985 1985 1985 1985 Total 1986 1986 1986 Major location NPC SP - REID GARDNER STATION NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 287.0 NPC TS - Transmission Sub 69.0 NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - Transmission Line 138.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 5,815,774.34 440,298.21 1,168,447.69 4,935,975.37 1,708.80 417,289.55 2,120,277.38 231,865.70 977,950.32 944,449.41 5,610,225.58 0.01 19,124.91 16,867,612.93 126,235.62 69,460.85 3,961.72 276,982.50 521,476.85 266,524.48 15,505.37 1,280,147.39 615.19 5,702.54 0.69 543,022.93 2,316.89 (57.32) 15,396.22 3,454,622.44 232,060.87 4,253,680.45 68,072.05 19,602.61 58,410.12 Page 191 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1986 1986 1986 1986 1986 Total 1987 1987 1987 1987 1987 1987 1987 1987 1987 Total 1988 1988 1988 1988 1988 1988 1988 1988 1988 Total 1989 1989 1989 1989 1989 1989 1989 1989 1989 1989 1989 1989 Total Major location NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - SPARE PARTS NPC TS - Transmission Sub 138.0 NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 287.0 NPC TS - Transmission Sub 69.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 337,818.07 139,221.72 154,482.00 490,043.40 1,267,649.97 (652.46) 13,101.59 67.50 80,498.69 (5,431.29) 67,191.89 158,620.35 427,364.48 740,760.75 19,519.65 55,784.91 5,520,338.28 149,161.82 1,015,833.18 1,157,119.54 88,021.20 4,795,111.91 12,800,890.49 10,775.28 83,515.20 (993.11) 98,390.74 4,691,913.03 4,113,174.65 914,847.30 90,601.25 846,985.76 8,649.00 30,545.22 10,888,404.32 Page 192 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1990 1990 1990 1990 1990 1990 1990 1990 1990 1990 1990 1990 Total 1991 1991 1991 1991 1991 1991 1991 1991 Total 1992 1992 1992 1992 1992 1992 1992 1992 1992 1992 Total 1993 1993 1993 1993 1993 Major location NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - NAVAJO TRANS SYSTEM (UT) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 345.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 345.0 NPC TS - Transmission Sub 69.0 NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 345.0 NPC TS - Transmission Sub 50.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC SP - CLARK STATION NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 335,323.45 77,778.01 69,700.84 2,385,534.44 10,342,794.84 15,973,565.30 1,755,222.27 4,451,932.37 7,997,211.41 12,718,903.79 59,023.59 56,166,990.31 25,159.07 639,964.74 1,358,698.30 1,758,929.26 4,082,942.98 4,427,265.30 1,023,053.72 13,316,013.37 2,021,645.42 1,592,274.20 67,053.56 996,797.94 13,276,826.99 3,060,188.73 34,264.09 26,710.99 543,726.65 21,619,488.57 134,795.35 58,014.01 3,073,811.48 66,051.22 1,409,671.74 Page 193 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1993 1993 1993 1993 Total 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 Total 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 1995 Total 1996 1996 1996 1996 1996 1996 1996 1996 Major location NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 69.0 NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 287.0 NPC TS - Transmission Sub 345.0 NPC TS - Transmission Sub 50.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 2,800,477.37 4,660.01 7,440.66 7,554,921.84 (596.76) 596.76 1,933,278.41 516,951.67 817,104.02 2,928,664.71 1,823,136.45 18,965.12 120,322.34 23,770.42 13,653.93 8,195,847.07 212,901.10 180.78 5,550,800.75 1,776,047.76 830,764.80 825,080.59 1,837,735.77 3,330,877.38 (2,273.08) 870,167.72 15,232,283.57 152,004.06 1,094.83 43,324.79 5,120,927.70 1,670,062.22 43,831.91 966,677.25 1,485,776.95 Page 194 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1996 1996 1996 1996 Total 1997 1997 1997 1997 1997 1997 1997 1997 1997 1997 1997 1997 1997 Total 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 1998 Total 1999 1999 1999 1999 1999 Major location NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - NAVAJO TRANS SYSTEM NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC OP - CLARK STATION NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - SPARE PARTS NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC TL - NAVAJO TRANS SYSTEM NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 4,216,038.75 0.27 2,463,220.34 16,162,959.07 2,160,861.07 15,907.05 75,736.31 8,254.09 2,212,174.08 271,004.79 174,851.04 1,801,782.24 2,018,093.56 134,581.15 866.97 1,019,621.70 9,893,734.05 137,050.12 (2.20) 73,974.57 7,212,635.96 25,266,221.88 526,961.09 1,621,925.40 149,490.14 5,678,051.17 41,858,415.75 105,537.26 1,658,189.35 84,288,450.49 590,472.43 81,345.70 28,964,924.51 29,044,834.20 4,305,695.82 Page 195 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 1999 1999 1999 1999 1999 1999 1999 1999 1999 Total 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 2000 Total 2001 2001 2001 2001 2001 2001 2001 2001 2001 2001 2001 2001 Major location NPC TS - SPARE PARTS NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 287.0 NPC TS - Transmission Sub 345.0 NPC TS - Transmission Sub 50.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - NAVAJO TRANS SYSTEM NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - SPARE PARTS NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 50.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC OP - CLARK STATION NPC SP - REID GARDNER STATION NPC TL - NAVAJO TRANS SYSTEM NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 345.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 287.0 NPC TS - Transmission Sub 50.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 1,924,026.18 1,221,661.31 11,275,983.35 20,510.22 7,979.02 2,577,846.42 53,276,968.16 1,707,405.51 134,999,652.83 7,423.97 8.57 413,062.70 17,554,609.70 5,662,507.91 566.05 2,828,269.54 61,142.91 2,276,065.72 3,296,343.04 15,742.82 671,225.39 1,213,944.07 34,000,912.39 53,623.64 115,806.50 21,747.87 19,878.76 4,897,575.89 21,131,888.70 156,256.06 4,595,936.47 1,515,982.99 12,522,213.92 23,518.79 1,842,822.24 Page 196 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 2001 2001 2001 Total 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 2002 Total 2003 2003 2003 2003 2003 2003 2003 2003 2003 2003 2003 2003 Total 2004 2004 2004 2004 2004 2004 2004 2004 2004 Major location NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - NAVAJO TRANS SYSTEM (AZ) NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC GP - COMMUNICATION NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 5,221.89 1,002,503.23 47,904,976.95 5,130.74 (1,995.09) 3,708,143.62 21,844,827.48 4,904,740.28 4,251,959.67 5,988,167.35 4,697,211.21 16,915,927.69 1,275,281.13 63,589,394.08 (3,819.53) 382,805.26 1,052.46 1,250,900.99 10,474,893.88 39,645,532.65 (184,446.69) 700,884.61 6,911,989.54 18,283,494.73 160,384.43 77,623,672.33 (0.29) (1,035.87) (33,213.76) 5,993,516.43 5,642,033.95 80,528.84 712,182.27 1,056,322.43 588,211.69 Page 197 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 2004 2004 2004 2004 Total 2005 2005 2005 2005 2005 2005 2005 2005 2005 2005 2005 2005 2005 2005 Total 2006 2006 2006 2006 2006 2006 2006 2006 2006 2006 2006 2006 2006 2006 Total 2007 2007 2007 Major location NPC TS - Transmission Sub 50.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC GP - COMMUNICATION NPC OP - CLARK STATION NPC OP - LENZIE NPC TL - NAVAJO TRANS SYSTEM NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC OP - PHOTOVOLTAIC NPC SP - MOHAVE STATION NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - SPARE PARTS NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 50.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Other Trans $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 12,527,272.43 40,026,076.79 422,532.12 67,014,427.03 22,082.14 291.93 53,847.11 71,243.58 21,994.87 1,010,472.43 12,846,222.48 59,463.87 804,123.88 2,536,257.84 631,681.01 159,070.94 242,560.51 18,459,312.59 1,569,956.34 (62,959.05) 4,329,840.85 5,071,774.84 3,067,156.48 1,937,658.96 1,619,074.79 33,937.17 5,189,340.31 10,066,557.68 253,453.28 21,326,924.64 490,952.42 54,893,668.71 7,115.12 (5,130.74) 2,066,307.37 Page 198 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 2007 2007 2007 2007 2007 2007 2007 2007 2007 2007 2007 Total 2008 2008 2008 2008 2008 2008 2008 2008 2008 2008 Total 2009 2009 2009 2009 2009 2009 2009 2009 2009 2009 2009 2009 Total 2010 2010 Major location NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - SPARE PARTS NPC TS - Trans to Gen - Lenzie NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - SPARE PARTS NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC DS - Distribution Substation NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - SPARE PARTS NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 345.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC TL - NAVAJO TRANS SYSTEM NPC TL - Other Trans $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost 13,418,162.46 2,834,367.45 77,211,346.86 2,035,502.34 118,015.69 1,600,508.31 1,249,347.48 26,218,068.51 3,372,941.55 3,323,787.50 133,450,339.90 7,442,102.61 13,722,075.70 4,526,012.62 2,066,342.05 100,798.69 6,009,570.23 10,026,665.27 6,687,907.46 2,008,208.43 52,589,683.06 188,929.09 3,818,023.82 149,239.63 30,745,894.22 7,536.91 5,073,369.53 6,098,247.09 47,265,875.13 42,324.99 1,978,449.59 354,826.55 95,722,716.55 564,494.31 3,035,060.40 Page 199 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 2010 2010 2010 2010 2010 2010 2010 2010 Total 2011 2011 2011 2011 2011 2011 2011 2011 2011 2011 Total 2012 2012 2012 2012 2012 2012 2012 2012 2012 2012 2012 Total 2013 2013 2013 2013 2013 2013 Major location NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC TS - SPARE PARTS NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 287.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 69.0 NPC TS - SPARE PARTS NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 345.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 NPC TL - NAVAJO TRANS SYSTEM NPC TL - Other Trans NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 230.0 NPC TL - Transmission Line 34.5 NPC TL - Transmission Line 500.0 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Cost (50,177.39) 1,350,333.29 288,514.74 246,841.33 21,887,730.44 3,664,190.49 101,489.19 31,088,476.80 (20,163.75) 17,895.04 154,755.49 (694,161.54) 8,274,026.54 2,779,108.38 61,873.10 788,194.07 176,416.28 11,537,943.61 9,638.99 574,330.07 (138,473.72) 380,990.30 49,542.73 986,263.76 3,152,342.86 63,605.70 1,069,518.60 420,235.21 6,567,994.50 1,424,426.35 2,660,055.92 177,684.44 19,189.28 59,449.73 106,504,845.43 Page 200 of 273 14-05XXX; MDR 099 Attach 01 NEVADA POWER COMPANY d/b/a NVEnergy MDR 99 ATTACHMENT Vintage Year Costs. Transmission System. As of 12/31/2013 Vintage year 2013 2013 2013 2013 2013 2013 2013 Total Grand Total Major location NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC TS - Transmission Sub 345.0 NPC TS - Transmission Sub 500.0 NPC TS - Transmission Sub 69.0 $ $ $ $ $ $ $ $ Cost (185,411.75) 1,063,557.23 29,426.75 23,022.85 33,582,334.86 299,416.13 145,657,997.22 1,324,474,650.02 Page 201 of 273 Nevada Power Company d/b/a NV Energy RESPONSE TO INFORMATION REQUEST DOCKET NO.: 14-05XXX REQUEST NO.: MDR 100 REQUESTER: REQUEST DATE: 2/4/2014 RESPONDER: Foley, Patrick REQUEST: Vintage Year Costs Distribution System. Provide, preferably in a computer file or files, for each vintage year through the end of the test period for each voltage class the installed cost and the installed linear feet for the distribution system. RESPONSE CONFIDENTIAL (yes or no): No ATTACHMENTS CONFIDENTIAL (yes or no): No TOTAL NUMBER OF ATTACHMENTS: One RESPONSE: Please see the attached spreadsheet which provides the installed costs by vintage year for the distribution system. The installed costs are not recorded by voltage class or in linear feet. Assets with a transmission description are the result of the T&D demarcation order from FERC. Therefore, these assets are properly recorded within the distribution system. Page 202 of 273 14-05XXX; MDR 100 Attach 01 NEVADA POWER COMPANY MDR 100 ATTACHMENT Vintage Year Costs. Distribution System. As of 12/31/2013 Vintage year Major location Cost 1938 1938 1938 Total 1939 1939 Total 1940 1940 1940 1940 Total 1941 1941 Total 1942 1942 Total 1945 1945 Total 1946 1946 Total 1947 1947 1947 Total 1948 1948 1948 Total 1949 1949 1949 Total 1950 1950 1950 Total 1951 1951 Total 1952 1952 1952 1952 Total 1953 1953 1953 1953 Total 1954 1954 1954 Total 1955 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DS - Distribution Substation NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL 3,598.12 16,909.27 20,507.39 2,130.64 2,130.64 500.00 116.02 2,025.48 2,641.50 66.35 66.35 773.00 773.00 100.89 100.89 (7.12) (7.12) 6,240.87 4,614.72 10,855.59 14,620.94 2,610.00 17,230.94 18,837.95 1,501.50 20,339.45 38,606.59 158,334.68 196,941.27 28,523.93 28,523.93 89,690.91 13,536.34 4,125.84 107,353.09 169,415.40 3,039.58 274.45 172,729.43 300,294.47 45,080.88 345,375.35 304,763.38 Page 203 of 273 14-05XXX; MDR 100 Attach 01 NEVADA POWER COMPANY MDR 100 ATTACHMENT Vintage Year Costs. Distribution System. As of 12/31/2013 Vintage year Major location Cost 1938 1955 1955 1955 Total 1956 1956 1956 1956 1956 Total 1957 1957 1957 1957 Total 1958 1958 1958 1958 1958 Total 1959 1959 1959 1959 1959 Total 1960 1960 1960 Total 1961 1961 1961 1961 1961 1961 1961 Total 1962 1962 1962 1962 1962 1962 Total 1963 1963 1963 1963 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ NPC DS - Distribution Substation NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 34.5 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 34.5 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 34.5 NPC TL - Transmission Line 69.0 3,598.12 93,504.03 1,151.08 399,418.49 221,347.96 444,724.35 354,809.82 176.27 1,021,058.40 212,084.63 211,532.03 1,500.00 425,116.66 191,950.42 201,388.04 317.12 64,888.59 458,544.17 274,370.43 94,204.18 183,684.44 2,034.60 554,293.65 532,638.66 62,032.47 594,671.13 647,888.09 58,582.42 3,527.41 27,812.19 5,955.98 84,296.58 828,062.67 991,991.21 349,693.98 6,663.66 5,563.40 3,046.46 1,356,958.71 2,345,178.03 327,291.44 137,250.87 1,244.81 Page 204 of 273 14-05XXX; MDR 100 Attach 01 NEVADA POWER COMPANY MDR 100 ATTACHMENT Vintage Year Costs. Distribution System. As of 12/31/2013 Vintage year Major location Cost 1938 1963 Total 1964 1964 1964 1964 1964 1964 Total 1965 1965 1965 1965 1965 Total 1966 1966 1966 1966 1966 Total 1967 1967 1967 1967 1967 1967 Total 1968 1968 1968 1968 Total 1969 1969 1969 1969 Total 1970 1970 1970 1970 Total 1971 1971 1971 1971 Total 1972 1972 1972 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 34.5 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 3,598.12 2,810,965.15 1,492,120.19 637,506.98 6,899.65 4,360.16 37,778.44 2,178,665.42 913,504.60 585,723.79 3,179.11 1,711.20 1,504,118.70 784,428.67 847,518.27 2,837.66 15,497.09 1,650,281.69 716,116.24 529,444.75 12,425.06 773.36 1,427.06 1,260,186.47 1,188,861.26 316,413.16 56,534.30 1,561,808.72 1,150,563.79 898,132.03 9,094.93 2,057,790.75 1,141,906.65 789,613.56 64,177.03 1,995,697.24 1,626,038.67 657,852.42 271,102.09 2,554,993.18 1,767,532.64 503,218.53 4,420.47 Page 205 of 273 14-05XXX; MDR 100 Attach 01 NEVADA POWER COMPANY MDR 100 ATTACHMENT Vintage Year Costs. Distribution System. As of 12/31/2013 Vintage year Major location Cost 1938 1972 1972 Total 1973 1973 1973 1973 Total 1974 1974 1974 1974 1974 Total 1975 1975 1975 1975 Total 1976 1976 1976 1976 Total 1977 1977 1977 1977 1977 Total 1978 1978 1978 1978 1978 Total 1979 1979 1979 1979 1979 Total 1980 1980 1980 1980 1980 Total 1981 1981 1981 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 3,598.12 10,453.75 2,285,625.39 3,650,142.50 983,606.96 13,863.26 4,647,612.72 3,523,391.77 1,886,247.54 20,711.43 15,219.97 5,445,570.71 2,774,743.55 1,840,091.92 3,092.61 4,617,928.08 3,660,735.91 450,826.04 38,699.66 4,150,261.61 6,532,377.30 1,124,966.09 2,482.87 26,937.67 7,686,763.93 8,264,556.60 2,326,777.36 19,558.37 2,628.48 10,613,520.81 10,116,131.09 2,745,279.76 74,348.69 13,952.11 12,949,711.65 10,569,329.36 5,374,876.73 49,623.00 28,966.79 16,022,795.88 10,374,510.34 3,392,086.30 29,681.26 Page 206 of 273 14-05XXX; MDR 100 Attach 01 NEVADA POWER COMPANY MDR 100 ATTACHMENT Vintage Year Costs. Distribution System. As of 12/31/2013 Vintage year Major location Cost 1938 1981 1981 Total 1982 1982 1982 1982 1982 Total 1983 1983 1983 1983 1983 Total 1984 1984 1984 1984 Total 1985 1985 1985 1985 1985 Total 1986 1986 1986 1986 1986 1986 Total 1987 1987 1987 1987 1987 Total 1988 1988 1988 1988 Total 1989 1989 1989 1989 1989 Total 1990 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 230.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL 3,598.12 575,945.42 14,372,223.32 10,379,929.26 2,985,009.01 2,698.66 549,589.73 13,917,226.66 12,604,520.86 1,757,085.04 5,347.77 48,807.64 14,415,761.31 13,006,794.90 881,140.25 172,625.68 14,060,560.83 12,196,243.49 4,156,302.53 303,709.33 26,028.00 16,682,283.35 24,664,668.51 2,080,670.79 2,509.27 9,168.56 71,501.20 26,828,518.33 13,979,368.19 4,802,956.43 38,809.44 15,276.40 18,836,410.46 20,757,617.89 3,399,901.54 67,998.77 24,225,518.20 35,124,589.64 9,145,364.12 6,172,677.20 2,721,052.61 53,163,683.57 34,271,487.37 Page 207 of 273 14-05XXX; MDR 100 Attach 01 NEVADA POWER COMPANY MDR 100 ATTACHMENT Vintage Year Costs. Distribution System. As of 12/31/2013 Vintage year Major location Cost 1938 1990 1990 1990 1990 1990 Total 1991 1991 1991 1991 1991 Total 1992 1992 1992 1992 1992 Total 1993 1993 1993 1993 1993 1993 Total 1994 1994 1994 1994 Total 1995 1995 1995 1995 1995 Total 1996 1996 1996 1996 1996 1996 Total 1997 1997 1997 1997 1997 1997 Total $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ NPC DS - Distribution Substation NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 500.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 3,598.12 13,302,783.83 1,078,994.39 2,179,855.13 694,721.09 51,527,841.81 58,213,466.19 13,220,924.46 681,294.76 200,928.79 72,316,614.20 51,486,740.11 5,143,109.47 351,809.43 1,784,574.99 58,766,234.00 42,831,448.94 13,534,108.83 266,432.50 619,870.68 250,330.25 57,502,191.20 66,902,802.32 13,732,820.48 121,268.40 80,756,891.20 75,859,542.59 7,651,559.60 104,042.71 101,887.82 83,717,032.72 89,154,240.08 14,501,973.70 (83,237.27) 989,332.18 466,627.02 105,028,935.71 82,459,528.96 23,769,815.60 32,165.90 166,347.02 1,236,093.27 107,663,950.75 Page 208 of 273 14-05XXX; MDR 100 Attach 01 NEVADA POWER COMPANY MDR 100 ATTACHMENT Vintage Year Costs. Distribution System. As of 12/31/2013 Vintage year Major location Cost 1938 1998 1998 1998 1998 1998 1998 1998 Total 1999 1999 1999 1999 1999 Total 2000 2000 2000 Total 2001 2001 2001 Total 2002 2002 2002 Total 2003 2003 2003 2003 Total 2004 2004 2004 Total 2005 2005 2005 2005 Total 2006 2006 2006 Total 2007 2007 2007 2007 Total 2008 2008 2008 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC TL - Transmission Line 69.0 NPC TS - Transmission Sub 138.0 NPC TS - Transmission Sub 230.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DL - RADIAL LINE NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 69.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TL - Transmission Line 138.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC SP - CLARK STATION NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC SP - NAVAJO STATION (AZ) 3,598.12 185,183,752.12 26,124,784.91 7,061.07 63,670.62 1,177,952.95 3,648,881.11 216,206,102.78 65,604,746.33 159,803.99 34,176,386.62 5,954.64 99,946,891.58 82,444,300.93 34,645,077.44 117,089,378.37 48,503,026.51 19,231,600.91 67,734,627.42 75,104,551.71 16,328,640.56 91,433,192.27 101,181,723.96 27,767,656.50 (5,954.64) 128,943,425.82 106,433,740.60 29,799,007.39 136,232,747.99 106,411,283.14 42,579,415.13 541,998.43 149,532,696.70 121,509,646.44 40,831,044.48 162,340,690.92 125,879,356.14 43,635,857.57 11,169.29 169,526,383.00 111,189,706.74 60,698,876.40 7,976.22 Page 209 of 273 14-05XXX; MDR 100 Attach 01 NEVADA POWER COMPANY MDR 100 ATTACHMENT Vintage Year Costs. Distribution System. As of 12/31/2013 Vintage year Major location Cost 1938 2008 Total 2009 2009 2009 Total 2010 2010 2010 Total 2011 2011 2011 Total 2012 2012 2012 2012 Total 2013 2013 2013 2013 Total 2014 2014 Total Grand Total $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC TS - Transmission Sub 138.0 NPC DL - OTHER DISTRIBUTION FACIL NPC DS - Distribution Substation NPC Unspecified NPC DL - OTHER DISTRIBUTION FACIL 3,598.12 171,896,559.36 143,318,965.12 21,896,500.28 165,215,465.40 155,259,856.75 6,849,480.23 162,109,336.98 56,577,036.99 10,696,149.51 67,273,186.50 63,694,343.20 1,010,448.56 164,679.54 64,869,471.30 48,830,454.72 2,910,575.99 0.05 51,741,030.76 1,195.55 1,195.55 2,928,432,244.00 Page 210 of 273 Nevada Power Company d/b/a NV Energy RESPONSE TO INFORMATION REQUEST DOCKET NO.: 14-05XXX REQUEST NO.: MDR 101 REQUESTER: REQUEST DATE: 2/4/2014 RESPONDER: Foley, Patrick REQUEST: Vintage Year Costs Services. Provide, preferably in a computer file or files, for each vintage year through the end of the test period for each voltage class the installed cost and the installed linear feet for services. RESPONSE CONFIDENTIAL (yes or no): No ATTACHMENTS CONFIDENTIAL (yes or no): No TOTAL NUMBER OF ATTACHMENTS: One RESPONSE: Please see the attached spreadsheet which provides the installed costs for services by vintage year. Voltage class as well as linear footage for services are not recorded in the Power Plant fixed asset database system and therefore, not available. Page 211 of 273 14-05XXX; MDR 101 Attach 01 NEVADA POWER COMPANY MDR 101 ATTACHMENT Vintage Year Costs. Services. As of 12/31/2013 Vintage year 1959 1959 Total 1960 1960 Total 1961 1961 Total 1962 1962 Total 1963 1963 Total 1964 1964 Total 1965 1965 Total 1966 1966 Total 1967 1967 Total 1968 1968 Total 1969 1969 Total 1970 1970 Total 1971 1971 Total 1972 1972 Total 1973 1973 Total 1974 1974 Total 1975 1975 Total 1976 Major location NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL Cost $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 5,215.16 5,215.16 91,086.99 91,086.99 109,298.71 109,298.71 180,591.01 180,591.01 298,001.73 298,001.73 194,894.07 194,894.07 145,976.15 145,976.15 117,466.61 117,466.61 113,041.35 113,041.35 151,821.99 151,821.99 186,450.69 186,450.69 183,316.30 183,316.30 338,072.73 338,072.73 450,765.37 450,765.37 481,522.39 481,522.39 344,248.54 344,248.54 425,077.65 425,077.65 588,387.92 Page 212 of 273 14-05XXX; MDR 101 Attach 01 NEVADA POWER COMPANY MDR 101 ATTACHMENT Vintage Year Costs. Services. As of 12/31/2013 Vintage year 1976 Total 1977 1977 Total 1978 1978 Total 1979 1979 Total 1980 1980 Total 1981 1981 Total 1982 1982 Total 1983 1983 Total 1984 1984 Total 1985 1985 Total 1986 1986 Total 1987 1987 Total 1988 1988 Total 1989 1989 Total 1990 1990 Total 1991 1991 Total 1992 1992 Total 1993 1993 Total Major location NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL Cost $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 588,387.92 1,202,979.65 1,202,979.65 1,048,285.18 1,048,285.18 1,493,775.15 1,493,775.15 1,259,738.35 1,259,738.35 1,418,085.26 1,418,085.26 1,156,338.14 1,156,338.14 1,303,068.13 1,303,068.13 1,366,258.74 1,366,258.74 1,581,087.10 1,581,087.10 2,756,214.25 2,756,214.25 1,880,905.40 1,880,905.40 2,826,834.46 2,826,834.46 4,285,827.76 4,285,827.76 3,774,571.77 3,774,571.77 6,818,289.82 6,818,289.82 5,610,916.50 5,610,916.50 5,824,578.35 5,824,578.35 Page 213 of 273 14-05XXX; MDR 101 Attach 01 NEVADA POWER COMPANY MDR 101 ATTACHMENT Vintage Year Costs. Services. As of 12/31/2013 Vintage year 1994 1994 Total 1995 1995 Total 1996 1996 Total 1997 1997 Total 1998 1998 Total 1999 1999 Total 2000 2000 Total 2001 2001 Total 2002 2002 Total 2003 2003 Total 2004 2004 Total 2005 2005 Total 2006 2006 Total 2007 2007 Total 2008 2008 Total 2009 2009 Total 2010 2010 Total 2011 Major location NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL Cost $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 6,933,697.63 6,933,697.63 8,380,780.41 8,380,780.41 10,477,990.77 10,477,990.77 621,481.26 621,481.26 67,616,853.26 67,616,853.26 444,179.66 444,179.66 3,395,087.33 3,395,087.33 (1,084,441.93) (1,084,441.93) 15,285.88 15,285.88 24,842.29 24,842.29 3,679.92 3,679.92 153,053.68 153,053.68 4,699.04 4,699.04 574,251.42 574,251.42 (97,676.18) (97,676.18) 3,678,698.62 3,678,698.62 80,513.75 80,513.75 2,318.37 Page 214 of 273 14-05XXX; MDR 101 Attach 01 NEVADA POWER COMPANY MDR 101 ATTACHMENT Vintage Year Costs. Services. As of 12/31/2013 Vintage year 2011 Total 2012 2012 Total 2013 2013 Total Grand Total Major location NPC DL - OTHER DISTRIBUTION FACIL NPC DL - OTHER DISTRIBUTION FACIL Cost $ $ $ $ $ $ 2,318.37 3,208,101.70 3,208,101.70 161,598.28 161,598.28 154,607,984.53 Page 215 of 273 Nevada Power Company d/b/a NV Energy RESPONSE TO INFORMATION REQUEST DOCKET NO.: 14-05XXX REQUEST NO.: MDR 102 REQUESTER: REQUEST DATE: 2/4/2014 RESPONDER: Foley, Patrick REQUEST: Vintage Year Costs Transformers. Provide, preferably in a computer file or files, for each vintage year through the end of the test period the installed cost by size and voltage class of transformers for the transmission system and for the distribution system. RESPONSE CONFIDENTIAL (yes or no): No ATTACHMENTS CONFIDENTIAL (yes or no): No TOTAL NUMBER OF ATTACHMENTS: One RESPONSE: Please see the attached spreadsheet which provides installed costs of transformers for the transmission and distribution systems by vintage year and voltage class. The sizes of transformers are not recorded in the Power Plant fixed asset database system and therefore, not available. Current, regulating and substation transformers are not recorded by size or voltage. Page 216 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 VINTAGE RETIREMENT UNIT 1946 SUBSTATION TRANSFORMER 1946 TRANSFORMER 1946 TRANSFORMER, 75 KVA 1946 Total 1947 TRANSFORMER, 100 KVA 1947 TRANSFORMER, 150 KVA 1947 TRANSFORMER, 200 KVA 1947 TRANSFORMER, 25 KVA 1947 TRANSFORMER, 3 KVA 1947 TRANSFORMER, 5 KVA 1947 TRANSFORMER, 7.5 KVA 1947 TRANSFORMER, 75 KVA 1947 Total 1948 TRANSFORMER, 10 KVA 1948 TRANSFORMER, 100 KVA 1948 TRANSFORMER, 15 KVA 1948 TRANSFORMER, 200 KVA 1948 TRANSFORMER, 37.5 KVA 1948 TRANSFORMER, 50 KVA 1948 TRANSFORMER, 75 KVA 1948 Total 1949 TRANSFORMER, 100 KVA 1949 TRANSFORMER, 15 KVA 1949 TRANSFORMER, 25 KVA 1949 TRANSFORMER, 50 KVA 1949 TRANSFORMER, 75 KVA 1949 Total 1950 TRANSFORMER, 100 KVA 1950 TRANSFORMER, 15 KVA 1950 TRANSFORMER, 167 KVA 1950 TRANSFORMER, 200 KVA 1950 TRANSFORMER, 250 KVA 1950 TRANSFORMER, 3 KVA 1950 TRANSFORMER, 50 KVA 1950 TRANSFORMER, 75 KVA UTILITY ACCOUNT 3530 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers ACTIVITY COST $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 338,209.30 (231,530.73) (7.12) 106,671.45 (195.48) (0.18) 5,209.54 (126.32) 1,261.52 (48.32) 159.18 (12.00) 6,247.94 (8.78) (208.11) (5.85) 8,160.63 (88.93) (416.52) (188.57) 7,243.87 (32.05) (9.30) (47.44) (344.66) (91.92) (525.37) (290.82) (55.27) (132.01) 1,919.04 (60.84) (0.14) (617.03) (179.39) Page 217 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1950 Total 1951 TRANSFORMER, 100 KVA 1951 TRANSFORMER, 37.5 KVA 1951 TRANSFORMER, 75 KVA 1951 Total 1952 TRANSFORMER, 10 KVA 1952 TRANSFORMER, 15 KVA 1952 TRANSFORMER, 167 KVA 1952 TRANSFORMER, 250 KVA 1952 TRANSFORMER, 333 KVA 1952 TRANSFORMER, 5 KVA 1952 TRANSFORMER, 50 KVA 1952 TRANSFORMER, 500 KVA 1952 TRANSFORMER, 75 KVA 1952 Total 1953 TRANSFORMER, 10 KVA 1953 TRANSFORMER, 100 KVA 1953 TRANSFORMER, 167 KVA 1953 TRANSFORMER, 333 KVA 1953 TRANSFORMER, 5 KVA 1953 TRANSFORMER, 500 KVA 1953 TRANSFORMER, 75 KVA 1953 Total 1954 SUBSTATION TRANSFORMER 1954 TRANSFORMER, 10 KVA 1954 TRANSFORMER, 100 KVA 1954 TRANSFORMER, 1500 KVA 1954 TRANSFORMER, 167 KVA 1954 TRANSFORMER, 5 KVA 1954 TRANSFORMER, 500 KVA 1954 TRANSFORMER, 75 KVA 1954 Total 1955 SUBSTATION TRANSFORMER 1955 TRANSFORMER, 10 KVA 1955 TRANSFORMER, 100 KVA 1955 TRANSFORMER, 167 KVA 1955 TRANSFORMER, 200 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 583.54 (201.21) (37.05) (278.57) (516.83) 5,448.17 (159.45) (203.48) (104.83) (82.35) 4,316.18 (833.91) (7.44) (236.33) 8,136.56 8,756.35 (447.21) (216.12) (2.97) 4,410.95 (4.15) (330.89) 12,165.96 1,265.16 18,378.26 (356.29) (68.21) (579.75) 10,760.96 (662.34) (761.99) 27,975.80 5,830.26 32,548.16 (462.95) (447.19) (2.55) Page 218 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1955 TRANSFORMER, 37.5 KVA 1955 TRANSFORMER, 5 KVA 1955 TRANSFORMER, 500 KVA 1955 TRANSFORMER, 75 KVA 1955 Total 1956 SUBSTATION TRANSFORMER 1956 SUBSTATION TRANSFORMER 1956 TRANSFORMER 1956 TRANSFORMER, 10 KVA 1956 TRANSFORMER, 15 KVA 1956 TRANSFORMER, 167 KVA 1956 TRANSFORMER, 3 KVA 1956 TRANSFORMER, 37.5 KVA 1956 TRANSFORMER, 5 KVA 1956 TRANSFORMER, 500 KVA 1956 TRANSFORMER, 75 KVA 1956 Total 1957 SUBSTATION TRANSFORMER 1957 SUBSTATION TRANSFORMER 1957 TRANSFORMER 1957 TRANSFORMER, 10 KVA 1957 TRANSFORMER, 100 KVA 1957 TRANSFORMER, 15 KVA 1957 TRANSFORMER, 167 KVA 1957 TRANSFORMER, 37.5 KVA 1957 TRANSFORMER, 75 KVA 1957 Total 1958 SUBSTATION TRANSFORMER 1958 TRANSFORMER, 10 KVA 1958 TRANSFORMER, 100 KVA 1958 TRANSFORMER, 15 KVA 1958 TRANSFORMER, 167 KVA 1958 TRANSFORMER, 250 KVA 1958 TRANSFORMER, 3 KVA 1958 TRANSFORMER, 37.5 KVA 1958 Total 1959 SUBSTATION TRANSFORMER 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 40,852.80 6,758.16 (380.49) (1,373.50) 83,322.70 28,593.34 77,589.08 314,120.37 7,732.73 11,058.54 (186.76) (6.25) 22,081.15 (29.55) (206.41) (994.40) 459,751.84 89,690.15 3,442.90 243,067.90 9,960.78 (80.69) 12,046.17 (231.08) 13,430.52 (288.02) 371,038.63 96,300.41 1,327.96 (265.80) 12,088.69 (357.61) (11.79) 705.11 11,595.98 121,382.95 2,585.42 Page 219 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1959 TRANSFORMER 1959 TRANSFORMER, 10 KVA 1959 TRANSFORMER, 100 KVA 1959 TRANSFORMER, 15 KVA 1959 TRANSFORMER, 167 KVA 1959 TRANSFORMER, 25 KVA 1959 TRANSFORMER, 250 KVA 1959 TRANSFORMER, 3 KVA 1959 TRANSFORMER, 37.5 KVA 1959 TRANSFORMER, 500 KVA 1959 TRANSFORMER, 75 KVA 1959 Total 1960 SUBSTATION TRANSFORMER 1960 TRANSFORMER, 10 KVA 1960 TRANSFORMER, 100 KVA 1960 TRANSFORMER, 15 KVA 1960 TRANSFORMER, 167 KVA 1960 TRANSFORMER, 25 KVA 1960 TRANSFORMER, 250 KVA 1960 TRANSFORMER, 3 KVA 1960 TRANSFORMER, 37.5 KVA 1960 Total 1961 SUBSTATION TRANSFORMER 1961 SUBSTATION TRANSFORMER 1961 TRANSFORMER, 10 KVA 1961 TRANSFORMER, 15 KVA 1961 TRANSFORMER, 25 KVA 1961 TRANSFORMER, 250 KVA 1961 TRANSFORMER, 3 KVA 1961 TRANSFORMER, 37.5 KVA 1961 TRANSFORMER, 50 KVA 1961 TRANSFORMER, 500 KVA 1961 TRANSFORMER, 75 KVA 1961 Total 1962 SUBSTATION TRANSFORMER 1962 TRANSFORMER, 15 KVA 1962 TRANSFORMER, 25 KVA 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 9,055.36 28,091.89 (23,479.78) 21,544.06 (246.49) 9,426.98 (5.63) 1,965.62 29,033.87 (225.13) (604.99) 77,141.18 1,594.30 2,067.16 (742.08) 33,552.54 (912.62) 26,821.88 (3.49) 3,905.78 54,077.55 120,361.02 10,644.14 92,543.53 750.94 31,383.69 49,647.16 (75.67) 705.10 51,541.18 (1,932.25) (11.85) (2,648.09) 232,547.88 110,583.45 26,751.17 55,280.82 Page 220 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1962 TRANSFORMER, 37.5 KVA 1962 TRANSFORMER, 5 KVA 1962 TRANSFORMER, 500 KVA 1962 TRANSFORMER, 833 KVA 1962 Total 1963 SUBSTATION TRANSFORMER 1963 SUBSTATION TRANSFORMER 1963 TRANSFORMER, 15 KVA 1963 TRANSFORMER, 25 KVA 1963 TRANSFORMER, 250 KVA 1963 TRANSFORMER, 37.5 KVA 1963 TRANSFORMER, 833 KVA 1963 Total 1964 SUBSTATION TRANSFORMER 1964 SUBSTATION TRANSFORMER 1964 TRANSFORMER, 15 KVA 1964 TRANSFORMER, 25 KVA 1964 TRANSFORMER, 250 KVA 1964 TRANSFORMER, 37.5 KVA 1964 TRANSFORMER, 5 KVA 1964 TRANSFORMER, 833 KVA 1964 Total 1965 SUBSTATION TRANSFORMER 1965 SUBSTATION TRANSFORMER 1965 TRANSFORMER 1965 TRANSFORMER, 15 KVA 1965 TRANSFORMER, 25 KVA 1965 TRANSFORMER, 250 KVA 1965 TRANSFORMER, 333 KVA 1965 TRANSFORMER, 37.5 KVA 1965 TRANSFORMER, 750 KVA 1965 TRANSFORMER, 833 KVA 1965 Total 1966 SUBSTATION TRANSFORMER 1966 SUBSTATION TRANSFORMER 1966 TRANSFORMER 1966 TRANSFORMER, 10 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 40,843.75 (1.83) (95.90) 25,084.37 258,445.83 9,227.92 65,769.49 59,798.86 77,913.18 4,122.56 149,650.42 53,120.03 419,602.46 4,722.20 74,451.93 22,024.69 21,674.55 3,287.39 46,410.14 (1.80) 56,874.60 229,443.70 61,659.96 111,023.48 220,398.95 11,749.30 16,385.97 12,447.81 2,361.34 28,558.96 (95.07) 64,349.27 528,839.97 113.85 388,258.77 772.40 248.46 Page 221 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1966 TRANSFORMER, 25 KVA 1966 TRANSFORMER, 250 KVA 1966 TRANSFORMER, 3 KVA 1966 TRANSFORMER, 37.5 KVA 1966 TRANSFORMER, 750 KVA 1966 TRANSFORMER, 833 KVA 1966 Total 1967 SUBSTATION TRANSFORMER 1967 SUBSTATION TRANSFORMER 1967 TRANSFORMER 1967 TRANSFORMER, 15 KVA 1967 TRANSFORMER, 225 KVA 1967 TRANSFORMER, 25 KVA 1967 TRANSFORMER, 250 KVA 1967 TRANSFORMER, 2500 KVA 1967 TRANSFORMER, 300 KVA 1967 TRANSFORMER, 833 KVA 1967 Total 1968 SUBSTATION TRANSFORMER 1968 SUBSTATION TRANSFORMER 1968 TRANSFORMER 1968 TRANSFORMER, 1000 KVA 1968 TRANSFORMER, 15 KVA 1968 TRANSFORMER, 150 KVA 1968 TRANSFORMER, 1500 KVA 1968 TRANSFORMER, 225 KVA 1968 TRANSFORMER, 25 KVA 1968 TRANSFORMER, 2500 KVA 1968 TRANSFORMER, 3 KVA 1968 TRANSFORMER, 300 KVA 1968 TRANSFORMER, 37.5 KVA 1968 TRANSFORMER, 833 KVA 1968 Total 1969 SUBSTATION TRANSFORMER 1969 SUBSTATION TRANSFORMER 1969 TRANSFORMER 1969 TRANSFORMER, 1000 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 10,556.24 8,490.43 53,061.00 20,539.36 (285.25) 17,643.33 499,398.59 40,636.51 247,911.97 2,370.60 (55.93) (50.13) 15,170.82 (4.05) (6.82) (121.08) 15,061.32 320,913.21 30,977.40 6,881.19 553,510.00 (761.54) (82.55) (52.33) (350.11) (107.71) 13,780.85 (463.37) (683.18) (319.17) 603.11 10,396.09 613,328.68 10,591.97 563,061.53 695,542.61 (392.41) Page 222 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1969 TRANSFORMER, 15 KVA 1969 TRANSFORMER, 2000 KVA 1969 TRANSFORMER, 225 KVA 1969 TRANSFORMER, 25 KVA 1969 TRANSFORMER, 2500 KVA 1969 TRANSFORMER, 333 KVA 1969 Total 1970 SUBSTATION TRANSFORMER 1970 SUBSTATION TRANSFORMER 1970 TRANSFORMER 1970 TRANSFORMER, 225 KVA 1970 TRANSFORMER, 25 KVA 1970 TRANSFORMER, 50 KVA 1970 TRANSFORMER, 500 KVA 1970 Total 1971 SUBSTATION TRANSFORMER 1971 SUBSTATION TRANSFORMER 1971 TRANSFORMER 1971 TRANSFORMER, 150 KVA 1971 TRANSFORMER, 25 KVA 1971 TRANSFORMER, 250 KVA 1971 TRANSFORMER, 3 KVA 1971 TRANSFORMER, 50 KVA 1971 TRANSFORMER, 833 KVA 1971 Total 1972 SUBSTATION TRANSFORMER 1972 TRANSFORMER 1972 TRANSFORMER, 1000 KVA 1972 TRANSFORMER, 112.5 KVA 1972 TRANSFORMER, 167 KVA 1972 TRANSFORMER, 25 KVA 1972 TRANSFORMER, 2500 KVA 1972 TRANSFORMER, 37.5 KVA 1972 TRANSFORMER, 50 KVA 1972 TRANSFORMER, 500 KVA 1972 TRANSFORMER, 833 KVA 1972 Total 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 477.91 (311.40) (329.68) 34,332.04 (972.26) 18,020.94 1,320,021.25 12,783.42 340,393.28 439,657.47 (298.59) 37,581.96 39,159.25 0.01 869,276.80 13,497.43 242,804.27 1,204.87 (286.92) 25,782.27 3,137.55 7,178.65 110,186.97 14,820.86 418,325.95 259,209.48 641,899.18 (370.24) (84.52) 8,312.60 74,213.13 (68.71) (2.16) 164,928.29 30,054.32 10,123.64 1,188,215.01 Page 223 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1973 SUBSTATION TRANSFORMER 1973 SUBSTATION TRANSFORMER 1973 TRANSFORMER 1973 TRANSFORMER, 100 KVA 1973 TRANSFORMER, 150 KVA 1973 TRANSFORMER, 1500 KVA 1973 TRANSFORMER, 25 KVA 1973 TRANSFORMER, 250 KVA 1973 TRANSFORMER, 2500 KVA 1973 TRANSFORMER, 3 KVA 1973 TRANSFORMER, 300 KVA 1973 TRANSFORMER, 333 KVA 1973 TRANSFORMER, 50 KVA 1973 TRANSFORMER, 500 KVA 1973 TRANSFORMER, 75 KVA 1973 TRANSFORMER, 750 KVA 1973 Total 1974 SUBSTATION TRANSFORMER 1974 SUBSTATION TRANSFORMER 1974 TRANSFORMER, 100 KVA 1974 TRANSFORMER, 112.5 KVA 1974 TRANSFORMER, 150 KVA 1974 TRANSFORMER, 1500 KVA 1974 TRANSFORMER, 200 KVA 1974 TRANSFORMER, 225 KVA 1974 TRANSFORMER, 25 KVA 1974 TRANSFORMER, 250 KVA 1974 TRANSFORMER, 300 KVA 1974 TRANSFORMER, 50 KVA 1974 TRANSFORMER, 500 KVA 1974 TRANSFORMER, 75 KVA 1974 TRANSFORMER, 750 KVA 1974 Total 1975 SUBSTATION TRANSFORMER 1975 SUBSTATION TRANSFORMER 1975 TRANSFORMER, 100 KVA 1975 TRANSFORMER, 150 KVA 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 43,430.64 765,437.00 625.46 36,618.13 10,209.37 53,193.72 54,974.85 32,052.72 (1,071.89) 9,143.03 27,606.41 7,793.25 142,165.52 90,301.43 67,351.76 19,597.48 1,359,428.88 32,831.24 1,005,583.25 94,149.83 (129.33) 15,629.73 8,700.24 15,701.25 12,901.56 60,219.99 25,540.92 30,056.91 183,267.83 48,887.58 163,283.17 10,074.54 1,706,698.71 960.90 1,450,154.50 35,962.40 9,661.96 Page 224 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1975 TRANSFORMER, 1500 KVA 1975 TRANSFORMER, 167 KVA 1975 TRANSFORMER, 200 KVA 1975 TRANSFORMER, 2000 KVA 1975 TRANSFORMER, 225 KVA 1975 TRANSFORMER, 25 KVA 1975 TRANSFORMER, 250 KVA 1975 TRANSFORMER, 300 KVA 1975 TRANSFORMER, 50 KVA 1975 TRANSFORMER, 500 KVA 1975 TRANSFORMER, 75 KVA 1975 TRANSFORMER, 750 KVA 1975 TRANSFORMER, 933 KVA 1975 Total 1976 SUBSTATION TRANSFORMER 1976 SUBSTATION TRANSFORMER 1976 TRANSFORMER 1976 TRANSFORMER, 100 KVA 1976 TRANSFORMER, 150 KVA 1976 TRANSFORMER, 167 KVA 1976 TRANSFORMER, 2000 KVA 1976 TRANSFORMER, 225 KVA 1976 TRANSFORMER, 25 KVA 1976 TRANSFORMER, 250 KVA 1976 TRANSFORMER, 3 KVA 1976 TRANSFORMER, 300 KVA 1976 TRANSFORMER, 50 KVA 1976 TRANSFORMER, 500 KVA 1976 TRANSFORMER, 667 KVA 1976 TRANSFORMER, 75 KVA 1976 TRANSFORMER, 750 KVA 1976 TRANSFORMER, 933 KVA 1976 Total 1977 SUBSTATION TRANSFORMER 1977 SUBSTATION TRANSFORMER 1977 TRANSFORMER 1977 TRANSFORMER, 100 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 13,612.10 6,970.30 17,890.22 12,270.50 11,510.87 43,810.63 75,832.70 14,047.18 110,334.52 73,440.90 129,793.22 9,430.53 41,870.17 2,057,553.60 15,716.30 123,585.10 293,407.04 49,661.55 4,810.94 17,347.28 42,788.21 9,272.17 69,028.41 27,367.19 25,802.67 13,739.83 252,436.04 25,951.40 21,255.34 217,580.54 (391.62) 7,375.36 1,216,733.75 34,158.00 452,407.84 1,897,055.02 135,959.90 Page 225 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1977 TRANSFORMER, 150 KVA 1977 TRANSFORMER, 1500 KVA 1977 TRANSFORMER, 167 KVA 1977 TRANSFORMER, 225 KVA 1977 TRANSFORMER, 25 KVA 1977 TRANSFORMER, 3 KVA 1977 TRANSFORMER, 300 KVA 1977 TRANSFORMER, 50 KVA 1977 TRANSFORMER, 500 KVA 1977 TRANSFORMER, 75 KVA 1977 TRANSFORMER, 750 KVA 1977 TRANSFORMER, 933 KVA 1977 Total 1978 SUBSTATION TRANSFORMER 1978 SUBSTATION TRANSFORMER 1978 TRANSFORMER, 10 KVA 1978 TRANSFORMER, 100 KVA 1978 TRANSFORMER, 112.5 KVA 1978 TRANSFORMER, 15 KVA 1978 TRANSFORMER, 150 KVA 1978 TRANSFORMER, 1500 KVA 1978 TRANSFORMER, 167 KVA 1978 TRANSFORMER, 200 KVA 1978 TRANSFORMER, 225 KVA 1978 TRANSFORMER, 25 KVA 1978 TRANSFORMER, 250 KVA 1978 TRANSFORMER, 3 KVA 1978 TRANSFORMER, 300 KVA 1978 TRANSFORMER, 37.5 KVA 1978 TRANSFORMER, 5 KVA 1978 TRANSFORMER, 50 KVA 1978 TRANSFORMER, 500 KVA 1978 TRANSFORMER, 7.5 KVA 1978 TRANSFORMER, 75 KVA 1978 TRANSFORMER, 750 KVA 1978 Total 1979 SUBSTATION TRANSFORMER 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 5,276.53 26,346.73 44,674.61 38,756.78 65,202.85 13,813.17 23,566.71 362,818.70 37,530.89 327,488.29 13,953.61 15,490.25 3,494,499.88 44.84 947,451.56 1,705.77 339,631.22 14,461.72 (167.16) 15,615.18 73,010.88 135,748.06 1,934.06 26,655.22 155,249.33 8,941.94 72,526.48 56,890.81 2,132.02 (83.55) 864,119.00 77,359.15 (2.43) 562,166.11 66,069.58 3,421,459.79 22,873.16 Page 226 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1979 SUBSTATION TRANSFORMER 1979 TRANSFORMER, 100 KVA 1979 TRANSFORMER, 112.5 KVA 1979 TRANSFORMER, 150 KVA 1979 TRANSFORMER, 1500 KVA 1979 TRANSFORMER, 167 KVA 1979 TRANSFORMER, 2000 KVA 1979 TRANSFORMER, 225 KVA 1979 TRANSFORMER, 25 KVA 1979 TRANSFORMER, 300 KVA 1979 TRANSFORMER, 50 KVA 1979 TRANSFORMER, 500 KVA 1979 TRANSFORMER, 75 KVA 1979 TRANSFORMER, 750 KVA 1979 Total 1980 SUBSTATION TRANSFORMER 1980 SUBSTATION TRANSFORMER 1980 TRANSFORMER, 100 KVA 1980 TRANSFORMER, 112.5 KVA 1980 TRANSFORMER, 150 KVA 1980 TRANSFORMER, 1500 KVA 1980 TRANSFORMER, 167 KVA 1980 TRANSFORMER, 2000 KVA 1980 TRANSFORMER, 225 KVA 1980 TRANSFORMER, 25 KVA 1980 TRANSFORMER, 2500 KVA 1980 TRANSFORMER, 300 KVA 1980 TRANSFORMER, 50 KVA 1980 TRANSFORMER, 500 KVA 1980 TRANSFORMER, 75 KVA 1980 TRANSFORMER, 750 KVA 1980 TRANSFORMER, 833 KVA 1980 Total 1981 SUBSTATION TRANSFORMER 1981 SUBSTATION TRANSFORMER 1981 TRANSFORMER, 100 KVA 1981 TRANSFORMER, 112.5 KVA 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 1,067,431.11 213,731.48 39,652.50 30,741.02 32,144.10 136,216.16 12,540.70 33,147.63 71,981.42 45,140.54 934,506.99 152,728.14 826,457.32 86,251.15 3,705,543.42 (6.68) 3,072,881.52 415,564.50 12,102.12 51,805.72 75,179.17 104,565.90 65,844.51 51,248.36 34,931.45 23,004.33 52,886.14 859,949.85 78,720.46 320,379.46 78,228.22 34,467.74 5,331,752.77 79,398.41 1,217,110.25 173,409.52 50,259.01 Page 227 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1981 TRANSFORMER, 150 KVA 1981 TRANSFORMER, 1500 KVA 1981 TRANSFORMER, 167 KVA 1981 TRANSFORMER, 225 KVA 1981 TRANSFORMER, 25 KVA 1981 TRANSFORMER, 250 KVA 1981 TRANSFORMER, 2500 KVA 1981 TRANSFORMER, 300 KVA 1981 TRANSFORMER, 50 KVA 1981 TRANSFORMER, 500 KVA 1981 TRANSFORMER, 75 KVA 1981 Total 1982 SUBSTATION TRANSFORMER 1982 SUBSTATION TRANSFORMER 1982 TRANSFORMER 1982 TRANSFORMER, 100 KVA 1982 TRANSFORMER, 1000 KVA 1982 TRANSFORMER, 112.5 KVA 1982 TRANSFORMER, 150 KVA 1982 TRANSFORMER, 1500 KVA 1982 TRANSFORMER, 167 KVA 1982 TRANSFORMER, 225 KVA 1982 TRANSFORMER, 25 KVA 1982 TRANSFORMER, 2500 KVA 1982 TRANSFORMER, 3 KVA 1982 TRANSFORMER, 300 KVA 1982 TRANSFORMER, 50 KVA 1982 TRANSFORMER, 500 KVA 1982 TRANSFORMER, 75 KVA 1982 TRANSFORMER, 750 KVA 1982 TRANSFORMER, 833 KVA 1982 Total 1983 SUBSTATION TRANSFORMER 1983 SUBSTATION TRANSFORMER 1983 TRANSFORMER 1983 TRANSFORMER, 100 KVA 1983 TRANSFORMER, 1000 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 86,511.38 103,357.51 259,187.33 129,753.91 48,652.45 24,415.57 207,289.23 48,995.83 581,808.23 62,287.80 608,297.16 3,680,733.59 138,153.55 764,323.70 457,601.20 214,104.98 29,044.52 22,815.77 67,056.98 36,497.06 183,055.63 44,504.19 2,904.89 75,911.39 25,595.17 42,774.02 356,348.03 116,309.09 395,827.46 49,545.75 14,774.89 3,037,148.27 156,375.77 556,046.68 3,792,931.19 764,503.82 45,262.34 Page 228 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1983 TRANSFORMER, 112.5 KVA 1983 TRANSFORMER, 150 KVA 1983 TRANSFORMER, 1500 KVA 1983 TRANSFORMER, 167 KVA 1983 TRANSFORMER, 2000 KVA 1983 TRANSFORMER, 225 KVA 1983 TRANSFORMER, 25 KVA 1983 TRANSFORMER, 2500 KVA 1983 TRANSFORMER, 3 KVA 1983 TRANSFORMER, 300 KVA 1983 TRANSFORMER, 50 KVA 1983 TRANSFORMER, 500 KVA 1983 TRANSFORMER, 75 KVA 1983 TRANSFORMER, 750 KVA 1983 Total 1984 SUBSTATION TRANSFORMER 1984 TRANSFORMER, 100 KVA 1984 TRANSFORMER, 1000 KVA 1984 TRANSFORMER, 112 KVA 1984 TRANSFORMER, 112.5 KVA 1984 TRANSFORMER, 15 KVA 1984 TRANSFORMER, 150 KVA 1984 TRANSFORMER, 1500 KVA 1984 TRANSFORMER, 167 KVA 1984 TRANSFORMER, 2000 KVA 1984 TRANSFORMER, 225 KVA 1984 TRANSFORMER, 25 KVA 1984 TRANSFORMER, 250 KVA 1984 TRANSFORMER, 2500 KVA 1984 TRANSFORMER, 3 KVA 1984 TRANSFORMER, 300 KVA 1984 TRANSFORMER, 50 KVA 1984 TRANSFORMER, 500 KVA 1984 TRANSFORMER, 667 KVA 1984 TRANSFORMER, 75 KVA 1984 TRANSFORMER, 750 KVA 1984 Total 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 63,376.36 17,245.75 218,287.22 572,767.34 29,543.20 150,135.27 85,268.73 148,307.80 118,640.14 56,592.44 646,661.10 75,603.62 1,655,121.04 90,474.62 9,243,144.43 295,866.15 991,595.18 72,559.26 (244.31) 125,219.84 (85.21) 74,150.87 132,319.77 336,886.37 85,055.38 62,165.20 43,124.90 55,885.55 321,343.04 35,579.11 134,072.85 1,325,060.59 168,060.20 14,901.74 1,438,928.98 82,983.21 5,795,428.67 Page 229 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1985 SUBSTATION TRANSFORMER 1985 SUBSTATION TRANSFORMER 1985 TRANSFORMER 1985 TRANSFORMER, 100 KVA 1985 TRANSFORMER, 1000 KVA 1985 TRANSFORMER, 112.5 KVA 1985 TRANSFORMER, 150 KVA 1985 TRANSFORMER, 1500 KVA 1985 TRANSFORMER, 167 KVA 1985 TRANSFORMER, 2000 KVA 1985 TRANSFORMER, 225 KVA 1985 TRANSFORMER, 25 KVA 1985 TRANSFORMER, 2500 KVA 1985 TRANSFORMER, 300 KVA 1985 TRANSFORMER, 50 KVA 1985 TRANSFORMER, 500 KVA 1985 TRANSFORMER, 75 KVA 1985 TRANSFORMER, 750 KVA 1985 Total 1986 SUBSTATION TRANSFORMER 1986 SUBSTATION TRANSFORMER 1986 TRANSFORMER 1986 TRANSFORMER, 10 KVA 1986 TRANSFORMER, 100 KVA 1986 TRANSFORMER, 1000 KVA 1986 TRANSFORMER, 112.5 KVA 1986 TRANSFORMER, 15 KVA 1986 TRANSFORMER, 150 KVA 1986 TRANSFORMER, 1500 KVA 1986 TRANSFORMER, 167 KVA 1986 TRANSFORMER, 225 KVA 1986 TRANSFORMER, 25 KVA 1986 TRANSFORMER, 250 KVA 1986 TRANSFORMER, 2500 KVA 1986 TRANSFORMER, 3 KVA 1986 TRANSFORMER, 300 KVA 1986 TRANSFORMER, 37.5 KVA 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 90,947.79 825,304.46 74,379.84 555,540.78 193,151.84 47,716.49 100,284.62 18,503.66 406,631.73 70,388.56 142,455.66 72,001.17 265,377.82 171,340.94 869,900.22 286,413.39 1,056,830.47 167,038.57 5,414,208.01 28,644.80 777,306.81 7,026.56 17,323.57 543,841.94 420,611.09 113,791.05 21,619.00 193,594.40 313,831.18 867,758.08 371,868.43 122,909.77 75.20 478,294.96 327,782.38 157,402.89 (3.87) Page 230 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1986 TRANSFORMER, 5 KVA 1986 TRANSFORMER, 50 KVA 1986 TRANSFORMER, 500 KVA 1986 TRANSFORMER, 75 KVA 1986 TRANSFORMER, 750 KVA 1986 Total 1987 SUBSTATION TRANSFORMER 1987 SUBSTATION TRANSFORMER 1987 TRANSFORMER 1987 TRANSFORMER, 100 KVA 1987 TRANSFORMER, 1000 KVA 1987 TRANSFORMER, 112.5 KVA 1987 TRANSFORMER, 150 KVA 1987 TRANSFORMER, 1500 KVA 1987 TRANSFORMER, 167 KVA 1987 TRANSFORMER, 2000 KVA 1987 TRANSFORMER, 225 KVA 1987 TRANSFORMER, 25 KVA 1987 TRANSFORMER, 250 KVA 1987 TRANSFORMER, 2500 KVA 1987 TRANSFORMER, 300 KVA 1987 TRANSFORMER, 50 KVA 1987 TRANSFORMER, 500 KVA 1987 TRANSFORMER, 75 KVA 1987 TRANSFORMER, 750 KVA 1987 Total 1988 SUBSTATION TRANSFORMER 1988 SUBSTATION TRANSFORMER 1988 TRANSFORMER 1988 TRANSFORMER, 100 KVA 1988 TRANSFORMER, 1000 KVA 1988 TRANSFORMER, 112.5 KVA 1988 TRANSFORMER, 150 KVA 1988 TRANSFORMER, 1500 KVA 1988 TRANSFORMER, 167 KVA 1988 TRANSFORMER, 2000 KVA 1988 TRANSFORMER, 225 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ (4.03) 896,199.90 506,954.38 1,453,187.65 287,048.86 7,907,065.00 12,269.47 1,907,696.68 19,901.23 546,237.47 92,608.96 49,287.73 121,338.82 28,979.74 290,566.74 188,746.18 216,754.36 (55,559.62) 24,468.83 212,089.77 119,654.86 1,014,059.49 249,879.30 1,436,714.97 175,678.26 6,651,373.24 97,206.81 1,575,008.26 2,899,432.73 777,919.92 101,988.79 231,078.06 154,458.01 100,772.79 611,031.24 137,817.82 295,045.31 Page 231 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1988 TRANSFORMER, 25 KVA 1988 TRANSFORMER, 2500 KVA 1988 TRANSFORMER, 3 KVA 1988 TRANSFORMER, 300 KVA 1988 TRANSFORMER, 50 KVA 1988 TRANSFORMER, 500 KVA 1988 TRANSFORMER, 75 KVA 1988 TRANSFORMER, 750 KVA 1988 Total 1989 SUBSTATION TRANSFORMER 1989 SUBSTATION TRANSFORMER 1989 TRANSFORMER, 100 KVA 1989 TRANSFORMER, 1000 KVA 1989 TRANSFORMER, 112 KVA 1989 TRANSFORMER, 112.5 KVA 1989 TRANSFORMER, 150 KVA 1989 TRANSFORMER, 1500 KVA 1989 TRANSFORMER, 167 KVA 1989 TRANSFORMER, 2000 KVA 1989 TRANSFORMER, 225 KVA 1989 TRANSFORMER, 25 KVA 1989 TRANSFORMER, 2500 KVA 1989 TRANSFORMER, 300 KVA 1989 TRANSFORMER, 50 KVA 1989 TRANSFORMER, 500 KVA 1989 TRANSFORMER, 75 KVA 1989 TRANSFORMER, 750 KVA 1989 TRANSFORMER, 833 KVA 1989 Total 1990 SUBSTATION TRANSFORMER 1990 SUBSTATION TRANSFORMER 1990 TRANSFORMER 1990 TRANSFORMER, 100 KVA 1990 TRANSFORMER, 1000 KVA 1990 TRANSFORMER, 112.5 KVA 1990 TRANSFORMER, 150 KVA 1990 TRANSFORMER, 1500 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 66,685.49 195,490.34 343.54 307,527.61 1,345,584.01 359,662.86 1,721,458.20 146,327.23 11,124,839.02 91,883.05 6,999,774.80 1,590,070.44 185,944.02 (108.86) 93,440.03 5.45 170,673.74 883,891.67 168,170.73 133,713.11 69,405.21 786,581.12 107,469.84 2,169,992.85 369,550.51 2,720,655.14 252,694.06 18,667.96 16,812,474.87 5,551,696.42 9,549,040.87 6,753,818.48 1,431,859.10 335,711.09 114,383.02 190,740.48 289,903.81 Page 232 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1990 TRANSFORMER, 167 KVA 1990 TRANSFORMER, 2000 KVA 1990 TRANSFORMER, 225 KVA 1990 TRANSFORMER, 25 KVA 1990 TRANSFORMER, 2500 KVA 1990 TRANSFORMER, 300 KVA 1990 TRANSFORMER, 50 KVA 1990 TRANSFORMER, 500 KVA 1990 TRANSFORMER, 75 KVA 1990 TRANSFORMER, 750 KVA 1990 TRANSFORMER, 833 KVA 1990 Total 1991 SUBSTATION TRANSFORMER 1991 SUBSTATION TRANSFORMER 1991 TRANSFORMER 1991 TRANSFORMER, 100 KVA 1991 TRANSFORMER, 1000 KVA 1991 TRANSFORMER, 112.5 KVA 1991 TRANSFORMER, 150 KVA 1991 TRANSFORMER, 1500 KVA 1991 TRANSFORMER, 167 KVA 1991 TRANSFORMER, 2000 KVA 1991 TRANSFORMER, 225 KVA 1991 TRANSFORMER, 2500 KVA 1991 TRANSFORMER, 300 KVA 1991 TRANSFORMER, 50 KVA 1991 TRANSFORMER, 500 KVA 1991 TRANSFORMER, 75 KVA 1991 TRANSFORMER, 750 KVA 1991 Total 1992 SUBSTATION TRANSFORMER 1992 SUBSTATION TRANSFORMER 1992 TRANSFORMER 1992 TRANSFORMER, 100 KVA 1992 TRANSFORMER, 1000 KVA 1992 TRANSFORMER, 112.5 KVA 1992 TRANSFORMER, 150 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 201,086.76 452,243.51 352,688.08 14,027.91 386,921.10 457,625.86 2,701,824.66 830,477.65 3,450,167.93 224,456.75 11,617.03 33,300,290.51 574,595.35 8,133,902.79 43,787.78 714,611.85 157,453.12 135,603.10 195,392.84 223,486.47 250,466.64 281,131.79 308,235.80 116,261.57 358,173.30 1,131,538.30 691,872.29 3,321,545.65 386,003.78 17,024,062.42 2,498,927.19 1,232,778.72 2,552,897.42 1,026,339.56 510,402.52 278,483.60 322,423.19 Page 233 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1992 TRANSFORMER, 1500 KVA 1992 TRANSFORMER, 167 KVA 1992 TRANSFORMER, 2000 KVA 1992 TRANSFORMER, 225 KVA 1992 TRANSFORMER, 25 KVA 1992 TRANSFORMER, 250 KVA 1992 TRANSFORMER, 2500 KVA 1992 TRANSFORMER, 300 KVA 1992 TRANSFORMER, 50 KVA 1992 TRANSFORMER, 500 KVA 1992 TRANSFORMER, 75 KVA 1992 TRANSFORMER, 750 KVA 1992 Total 1993 SUBSTATION TRANSFORMER 1993 SUBSTATION TRANSFORMER 1993 TRANSFORMER, 100 KVA 1993 TRANSFORMER, 1000 KVA 1993 TRANSFORMER, 112.5 KVA 1993 TRANSFORMER, 150 KVA 1993 TRANSFORMER, 1500 KVA 1993 TRANSFORMER, 167 KVA 1993 TRANSFORMER, 2000 KVA 1993 TRANSFORMER, 225 KVA 1993 TRANSFORMER, 25 KVA 1993 TRANSFORMER, 2500 KVA 1993 TRANSFORMER, 300 KVA 1993 TRANSFORMER, 50 KVA 1993 TRANSFORMER, 500 KVA 1993 TRANSFORMER, 667 KVA 1993 TRANSFORMER, 75 KVA 1993 TRANSFORMER, 750 KVA 1993 Total 1994 SUBSTATION TRANSFORMER 1994 SUBSTATION TRANSFORMER 1994 TRANSFORMER 1994 TRANSFORMER, 100 KVA 1994 TRANSFORMER, 1000 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 804,262.92 94,570.90 396,777.03 481,774.77 62,950.08 (8,743.91) 881,339.91 425,887.93 1,404,218.21 807,320.28 2,181,509.13 566,105.07 16,520,224.52 161,983.50 5,720,152.59 1,256,054.03 206,260.36 294,853.73 240,251.01 224,922.67 639,840.14 69,211.30 373,650.71 68,325.93 492,574.69 301,769.90 1,897,872.52 497,890.74 26,589.42 2,233,864.33 315,428.95 15,021,496.52 316,961.47 4,508,059.49 11,751.86 1,496,134.70 396,813.88 Page 234 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1994 TRANSFORMER, 112.5 KVA 1994 TRANSFORMER, 150 KVA 1994 TRANSFORMER, 1500 KVA 1994 TRANSFORMER, 167 KVA 1994 TRANSFORMER, 2000 KVA 1994 TRANSFORMER, 225 KVA 1994 TRANSFORMER, 25 KVA 1994 TRANSFORMER, 2500 KVA 1994 TRANSFORMER, 3 KVA 1994 TRANSFORMER, 300 KVA 1994 TRANSFORMER, 50 KVA 1994 TRANSFORMER, 500 KVA 1994 TRANSFORMER, 75 KVA 1994 TRANSFORMER, 750 KVA 1994 Total 1995 SUBSTATION TRANSFORMER 1995 SUBSTATION TRANSFORMER 1995 TRANSFORMER 1995 TRANSFORMER 1995 TRANSFORMER, 1 KVA 1995 TRANSFORMER, 100 KVA 1995 TRANSFORMER, 1000 KVA 1995 TRANSFORMER, 112.5 KVA 1995 TRANSFORMER, 150 KVA 1995 TRANSFORMER, 1500 KVA 1995 TRANSFORMER, 167 KVA 1995 TRANSFORMER, 2000 KVA 1995 TRANSFORMER, 225 KVA 1995 TRANSFORMER, 25 KVA 1995 TRANSFORMER, 2500 KVA 1995 TRANSFORMER, 3 KVA 1995 TRANSFORMER, 300 KVA 1995 TRANSFORMER, 50 KVA 1995 TRANSFORMER, 500 KVA 1995 TRANSFORMER, 75 KVA 1995 TRANSFORMER, 750 KVA 1995 Total 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 291,037.22 282,210.87 86,057.37 523,850.49 146,822.56 295,505.75 99,628.89 399,536.25 558,151.95 567,818.69 2,284,337.75 629,206.63 3,845,784.01 347,848.92 17,087,518.75 163,507.04 2,521,951.56 65,736.53 837.93 589.91 2,914,933.84 277,559.18 275,223.37 99,419.13 102,879.24 807,880.30 156,411.82 284,505.11 3,397.42 654,672.11 1,432.04 327,791.18 1,236,565.87 495,191.86 4,141,862.01 377,719.32 14,910,066.77 Page 235 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1996 REGULATING TRANSFORMER 1996 SUBSTATION TRANSFORMER 1996 SUBSTATION TRANSFORMER 1996 TRANSFORMER 1996 TRANSFORMER 1996 TRANSFORMER, 1 KVA 1996 TRANSFORMER, 10 KVA 1996 TRANSFORMER, 100 KVA 1996 TRANSFORMER, 1000 KVA 1996 TRANSFORMER, 112.5 KVA 1996 TRANSFORMER, 15 KVA 1996 TRANSFORMER, 150 KVA 1996 TRANSFORMER, 1500 KVA 1996 TRANSFORMER, 167 KVA 1996 TRANSFORMER, 2000 KVA 1996 TRANSFORMER, 225 KVA 1996 TRANSFORMER, 2500 KVA 1996 TRANSFORMER, 3 KVA 1996 TRANSFORMER, 300 KVA 1996 TRANSFORMER, 333 KVA 1996 TRANSFORMER, 50 KVA 1996 TRANSFORMER, 500 KVA 1996 TRANSFORMER, 7.5 KVA 1996 TRANSFORMER, 75 KVA 1996 TRANSFORMER, 750 KVA 1996 Total 1997 SUBSTATION TRANSFORMER 1997 SUBSTATION TRANSFORMER 1997 TRANSFORMER 1997 TRANSFORMER, 10 KVA 1997 TRANSFORMER, 100 KVA 1997 TRANSFORMER, 1000 KVA 1997 TRANSFORMER, 112.5 KVA 1997 TRANSFORMER, 15 KVA 1997 TRANSFORMER, 150 KVA 1997 TRANSFORMER, 1500 KVA 1997 TRANSFORMER, 167 KVA 3530 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 418.17 125,659.68 5,451,002.16 2,820,626.61 41,659.64 1,364.98 (2,978.68) 796,759.29 334,181.99 436,084.77 688.83 365,425.59 470,633.41 120,100.36 136,508.52 645,005.52 31,161.83 21,878.10 227,382.26 5,326.58 1,279,261.04 483,971.17 1,935.47 1,797,574.44 499,130.89 16,090,762.62 509,445.79 10,700,887.27 123,262.32 1,665.69 1,405,995.78 327,124.07 256,339.27 2,721.72 308,916.98 104,552.52 107,867.32 Page 236 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1997 TRANSFORMER, 2000 KVA 1997 TRANSFORMER, 225 KVA 1997 TRANSFORMER, 25 KVA 1997 TRANSFORMER, 250 KVA 1997 TRANSFORMER, 2500 KVA 1997 TRANSFORMER, 3 KVA 1997 TRANSFORMER, 300 KVA 1997 TRANSFORMER, 37.5 KVA 1997 TRANSFORMER, 45 KVA 1997 TRANSFORMER, 50 KVA 1997 TRANSFORMER, 500 KVA 1997 TRANSFORMER, 75 KVA 1997 TRANSFORMER, 750 KVA 1997 TRANSFORMER, 833 KVA 1997 Total 1998 CURRENT TRANSFORMER 1998 CURRENT TRANSFORMER 1998 POTENTIAL TRANSFORMER 1998 REGULATING TRANSFORMER 1998 REGULATING TRANSFORMER 1998 SUBSTATION TRANSFORMER 1998 SUBSTATION TRANSFORMER 1998 TRANSFORMER 1998 TRANSFORMER 1998 TRANSFORMER, 100 KVA 1998 TRANSFORMER, 1000 KVA 1998 TRANSFORMER, 112.5 KVA 1998 TRANSFORMER, 15 KVA 1998 TRANSFORMER, 150 KVA 1998 TRANSFORMER, 1500 KVA 1998 TRANSFORMER, 167 KVA 1998 TRANSFORMER, 2000 KVA 1998 TRANSFORMER, 225 KVA 1998 TRANSFORMER, 25 KVA 1998 TRANSFORMER, 250 KVA 1998 TRANSFORMER, 2500 KVA 1998 TRANSFORMER, 300 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 131,120.98 611,833.51 72,932.99 1,338.44 34,057.14 (189,030.49) 320,966.16 3,250.40 403.63 562,177.38 674,500.27 2,282,251.61 340,889.34 9,024.00 18,704,494.09 7,482.51 7,622.66 370,180.50 93,575.87 985,842.42 4,019,301.32 9,659,356.48 7,451,465.12 181,295.03 3,051,536.29 360,409.17 851,069.72 969.68 1,248,073.56 397,219.11 828,584.26 104,289.57 1,283,119.19 381,097.09 10.47 387,663.35 12,266.05 Page 237 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1998 TRANSFORMER, 300 KVA 1998 TRANSFORMER, 37.5 KVA 1998 TRANSFORMER, 50 KVA 1998 TRANSFORMER, 500 KVA 1998 TRANSFORMER, 667 KVA 1998 TRANSFORMER, 75 KVA 1998 TRANSFORMER, 750 KVA 1998 Total 1999 CURRENT TRANSFORMER 1999 CURRENT/POTENTIAL TRANSFORMER 1999 POTENTIAL TRANSFORMER 1999 POTENTIAL TRANSFORMER 1999 REGULATING TRANSFORMER 1999 REGULATING TRANSFORMER 1999 SUBSTATION TRANSFORMER 1999 SUBSTATION TRANSFORMER 1999 TRANSFORMER 1999 TRANSFORMER, > 2500 KVA 1999 TRANSFORMER, 1 KVA 1999 TRANSFORMER, 1.5 KVA 1999 TRANSFORMER, 10 KVA 1999 TRANSFORMER, 100 KVA 1999 TRANSFORMER, 1000 KVA 1999 TRANSFORMER, 112.5 KVA 1999 TRANSFORMER, 150 KVA 1999 TRANSFORMER, 1500 KVA 1999 TRANSFORMER, 167 KVA 1999 TRANSFORMER, 2000 KVA 1999 TRANSFORMER, 225 KVA 1999 TRANSFORMER, 25 KVA 1999 TRANSFORMER, 25 KVA 1999 TRANSFORMER, 2500 KVA 1999 TRANSFORMER, 300 KVA 1999 TRANSFORMER, 37.5 KVA 1999 TRANSFORMER, 50 KVA 1999 TRANSFORMER, 500 KVA 1999 TRANSFORMER, 75 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 1,104,193.11 813.93 2,835,261.78 1,575,041.37 11,878.14 5,495,749.99 697,291.13 43,402,658.87 6,423.10 19,426.82 535,566.63 131,157.90 209,391.18 206,779.45 28,559,255.80 11,034,693.87 209,763.79 (1,269.22) 501.32 143.42 25,888.11 2,817,370.30 485,172.07 760,092.66 906,937.12 346,875.35 469,297.69 291,386.72 1,086,708.96 18,552.33 239,334.92 303,812.75 882,941.86 2,232.23 3,908,886.65 1,689,360.08 4,971,660.16 Page 238 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 1999 TRANSFORMER, 750 KVA 1999 Total 2000 CURRENT/POTENTIAL TRANSFORMER 2000 POTENTIAL TRANSFORMER 2000 REGULATING TRANSFORMER 2000 REGULATING TRANSFORMER 2000 SUBSTATION TRANSFORMER 2000 SUBSTATION TRANSFORMER 2000 TRANSFORMER 2000 TRANSFORMER, > 2500 KVA 2000 TRANSFORMER, 1 KVA 2000 TRANSFORMER, 10 KVA 2000 TRANSFORMER, 100 KVA 2000 TRANSFORMER, 1000 KVA 2000 TRANSFORMER, 112.5 KVA 2000 TRANSFORMER, 15 KVA 2000 TRANSFORMER, 150 KVA 2000 TRANSFORMER, 1500 KVA 2000 TRANSFORMER, 167 KVA 2000 TRANSFORMER, 2000 KVA 2000 TRANSFORMER, 225 KVA 2000 TRANSFORMER, 25 KVA 2000 TRANSFORMER, 25 KVA 2000 TRANSFORMER, 250 KVA 2000 TRANSFORMER, 2500 KVA 2000 TRANSFORMER, 300 KVA 2000 TRANSFORMER, 37.5 KVA 2000 TRANSFORMER, 50 KVA 2000 TRANSFORMER, 50 KVA 2000 TRANSFORMER, 500 KVA 2000 TRANSFORMER, 75 KVA 2000 TRANSFORMER, 750 KVA 2000 TRANSFORMER, 833 KVA 2000 Total 2001 CURRENT TRANSFORMER 2001 REGULATING TRANSFORMER 2001 REGULATING TRANSFORMER 3680 - Line Transformers 3620 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 769,760.69 60,888,104.71 50,818.82 96,505.24 121,392.96 21,999.63 599,277.75 8,656,331.84 419,247.68 4,625.59 4,340.08 189,367.33 2,188,578.52 591,603.12 868,630.26 8,112.70 1,534,450.76 946,968.71 310,028.02 250,861.81 1,266,042.93 1,372.42 331,191.36 13,999.32 894,266.80 1,103,567.05 24.14 2,081.29 4,390,556.80 1,533,575.00 4,207,917.26 1,204,963.88 295,127.32 32,107,826.39 61,427.43 26,527.88 854,475.30 Page 239 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 2001 SUBSTATION TRANSFORMER 2001 SUBSTATION TRANSFORMER 2001 TRANSFORMER 2001 TRANSFORMER, 10 KVA 2001 TRANSFORMER, 100 KVA 2001 TRANSFORMER, 1000 KVA 2001 TRANSFORMER, 112.5 KVA 2001 TRANSFORMER, 15 KVA 2001 TRANSFORMER, 150 KVA 2001 TRANSFORMER, 1500 KVA 2001 TRANSFORMER, 167 KVA 2001 TRANSFORMER, 2000 KVA 2001 TRANSFORMER, 225 KVA 2001 TRANSFORMER, 25 KVA 2001 TRANSFORMER, 25 KVA 2001 TRANSFORMER, 2500 KVA 2001 TRANSFORMER, 300 KVA 2001 TRANSFORMER, 37.5 KVA 2001 TRANSFORMER, 50 KVA 2001 TRANSFORMER, 500 KVA 2001 TRANSFORMER, 75 KVA 2001 TRANSFORMER, 750 KVA 2001 Total 2002 CURRENT TRANSFORMER 2002 CURRENT/POTENTIAL TRANSFORMER 2002 POTENTIAL TRANSFORMER 2002 REGULATING TRANSFORMER 2002 REGULATING TRANSFORMER 2002 SUBSTATION TRANSFORMER 2002 SUBSTATION TRANSFORMER 2002 TRANSFORMER 2002 TRANSFORMER, 1 KVA 2002 TRANSFORMER, 10 KVA 2002 TRANSFORMER, 100 KVA 2002 TRANSFORMER, 1000 KVA 2002 TRANSFORMER, 112.5 KVA 2002 TRANSFORMER, 15 KVA 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3530 - Station Equipment 3530 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 2,976,230.87 5,952,860.31 (21,010,979.43) 116,567.23 6,856,661.62 733,485.01 571,600.65 4,210.86 1,334,401.55 961,689.47 1,345,777.23 263,984.39 1,221,057.31 15,742.94 259,649.30 543,496.23 1,541,855.93 1,130.76 6,601,384.80 1,987,439.73 8,640,734.20 1,208,704.71 23,070,116.28 19,721.87 2,682.88 247,995.03 92,591.32 27,845.94 2,569,855.42 8,399,054.52 35,170.07 21,392.71 67,658.10 3,645,493.14 535,842.77 343,738.83 375.12 Page 240 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 2002 TRANSFORMER, 150 KVA 2002 TRANSFORMER, 1500 KVA 2002 TRANSFORMER, 167 KVA 2002 TRANSFORMER, 2000 KVA 2002 TRANSFORMER, 225 KVA 2002 TRANSFORMER, 25 KVA 2002 TRANSFORMER, 25 KVA 2002 TRANSFORMER, 2500 KVA 2002 TRANSFORMER, 300 KVA 2002 TRANSFORMER, 37.5 KVA 2002 TRANSFORMER, 50 KVA 2002 TRANSFORMER, 500 KVA 2002 TRANSFORMER, 75 KVA 2002 TRANSFORMER, 750 KVA 2002 Total 2003 CURRENT/POTENTIAL TRANSFORMER 2003 POTENTIAL TRANSFORMER 2003 REGULATING TRANSFORMER 2003 REGULATING TRANSFORMER 2003 SUBSTATION TRANSFORMER 2003 SUBSTATION TRANSFORMER 2003 TRANSFORMER 2003 TRANSFORMER, 10 KVA 2003 TRANSFORMER, 100 KVA 2003 TRANSFORMER, 100 KVA 2003 TRANSFORMER, 1000 KVA 2003 TRANSFORMER, 112.5 KVA 2003 TRANSFORMER, 15 KVA 2003 TRANSFORMER, 150 KVA 2003 TRANSFORMER, 1500 KVA 2003 TRANSFORMER, 167 KVA 2003 TRANSFORMER, 167 KVA 2003 TRANSFORMER, 2000 KVA 2003 TRANSFORMER, 225 KVA 2003 TRANSFORMER, 25 KVA 2003 TRANSFORMER, 2500 KVA 2003 TRANSFORMER, 300 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3530 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 764,698.83 347,319.51 495,986.11 89,367.47 702,170.81 4,922.87 74,568.52 261,162.71 847,994.16 880.39 2,886,857.37 1,106,354.10 4,053,257.55 1,071,826.75 28,716,784.87 5,991.70 59,939.06 78,304.59 158,417.12 14,973,167.66 10,534,649.92 33,236.91 150,550.93 12,924.72 2,787,561.08 424,697.79 397,927.80 3,837.03 670,578.03 667,841.19 3,309.72 376,649.70 174,992.50 682,655.08 112,718.26 117,320.41 878,130.46 Page 241 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 2003 TRANSFORMER, 37.5 KVA 2003 TRANSFORMER, 50 KVA 2003 TRANSFORMER, 500 KVA 2003 TRANSFORMER, 75 KVA 2003 TRANSFORMER, 75 KVA 2003 TRANSFORMER, 750 KVA 2003 Total 2004 CURRENT TRANSFORMER 2004 CURRENT/POTENTIAL TRANSFORMER 2004 REGULATING TRANSFORMER 2004 REGULATING TRANSFORMER 2004 SUBSTATION TRANSFORMER 2004 SUBSTATION TRANSFORMER 2004 TRANSFORMER 2004 TRANSFORMER, 10 KVA 2004 TRANSFORMER, 100 KVA 2004 TRANSFORMER, 1000 KVA 2004 TRANSFORMER, 112.5 KVA 2004 TRANSFORMER, 15 KVA 2004 TRANSFORMER, 150 KVA 2004 TRANSFORMER, 1500 KVA 2004 TRANSFORMER, 167 KVA 2004 TRANSFORMER, 2000 KVA 2004 TRANSFORMER, 225 KVA 2004 TRANSFORMER, 25 KVA 2004 TRANSFORMER, 2500 KVA 2004 TRANSFORMER, 300 KVA 2004 TRANSFORMER, 37.5 KVA 2004 TRANSFORMER, 50 KVA 2004 TRANSFORMER, 500 KVA 2004 TRANSFORMER, 75 KVA 2004 TRANSFORMER, 750 KVA 2004 Total 2005 CURRENT TRANSFORMER 2005 POTENTIAL TRANSFORMER 2005 POTENTIAL TRANSFORMER 2005 REGULATING TRANSFORMER 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3620 - Station Equipment $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 1,567.96 3,677,769.77 1,271,238.93 2,064.43 4,681,550.31 1,184,442.93 44,124,035.99 36,228.53 6,949.72 81,979.49 60,360.75 23,736,249.33 14,321,293.29 9,366.50 36,844.85 5,491,468.93 971,033.74 430,424.76 3,150.60 564,491.06 594,910.74 313,688.36 185,667.69 785,046.11 129,201.70 269,289.32 921,955.33 (130.67) 3,655,358.95 1,346,673.44 5,137,260.82 946,521.09 60,035,284.43 64,321.37 5,977.27 20,881.30 99,349.55 Page 242 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 2005 SUBSTATION TRANSFORMER 2005 SUBSTATION TRANSFORMER 2005 TRANSFORMER 2005 TRANSFORMER, 10 KVA 2005 TRANSFORMER, 100 KVA 2005 TRANSFORMER, 1000 KVA 2005 TRANSFORMER, 112.5 KVA 2005 TRANSFORMER, 15 KVA 2005 TRANSFORMER, 150 KVA 2005 TRANSFORMER, 1500 KVA 2005 TRANSFORMER, 167 KVA 2005 TRANSFORMER, 2000 KVA 2005 TRANSFORMER, 225 KVA 2005 TRANSFORMER, 25 KVA 2005 TRANSFORMER, 25 KVA 2005 TRANSFORMER, 250 KVA 2005 TRANSFORMER, 2500 KVA 2005 TRANSFORMER, 300 KVA 2005 TRANSFORMER, 37.5 KVA 2005 TRANSFORMER, 50 KVA 2005 TRANSFORMER, 50 KVA 2005 TRANSFORMER, 500 KVA 2005 TRANSFORMER, 75 KVA 2005 TRANSFORMER, 75 KVA 2005 TRANSFORMER, 750 KVA 2005 Total 2006 CURRENT TRANSFORMER 2006 CURRENT TRANSFORMER 2006 POTENTIAL TRANSFORMER 2006 POTENTIAL TRANSFORMER 2006 REGULATING TRANSFORMER 2006 SUBSTATION TRANSFORMER 2006 SUBSTATION TRANSFORMER 2006 TRANSFORMER 2006 TRANSFORMER, 10 KVA 2006 TRANSFORMER, 100 KVA 2006 TRANSFORMER, 1000 KVA 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 1,725,001.14 12,294,764.01 7,121.81 24,346.61 4,842,118.26 683,125.66 555,878.84 3,979.85 783,742.90 371,246.99 510,502.78 116,329.43 866,894.54 2,545.24 121,903.65 54,176.67 163,841.70 1,416,565.99 15,570.24 1,242.02 3,696,150.15 1,583,046.69 3,022.84 5,600,189.94 1,378,267.38 37,012,104.82 7,755,661.10 14,603.12 32,106.44 5,545.02 294,484.62 2,823,319.33 8,812,927.09 25,726.24 11,403.64 4,906,272.62 1,026,051.74 Page 243 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 2006 TRANSFORMER, 112.5 KVA 2006 TRANSFORMER, 150 KVA 2006 TRANSFORMER, 1500 KVA 2006 TRANSFORMER, 167 KVA 2006 TRANSFORMER, 2000 KVA 2006 TRANSFORMER, 225 KVA 2006 TRANSFORMER, 25 KVA 2006 TRANSFORMER, 25 KVA 2006 TRANSFORMER, 2500 KVA 2006 TRANSFORMER, 300 KVA 2006 TRANSFORMER, 37.5 KVA 2006 TRANSFORMER, 5 KVA 2006 TRANSFORMER, 50 KVA 2006 TRANSFORMER, 500 KVA 2006 TRANSFORMER, 75 KVA 2006 TRANSFORMER, 75 KVA 2006 TRANSFORMER, 750 KVA 2006 Total 2007 CURRENT TRANSFORMER 2007 CURRENT TRANSFORMER 2007 CURRENT/POTENTIAL TRANSFORMER 2007 POTENTIAL TRANSFORMER 2007 REGULATING TRANSFORMER 2007 REGULATING TRANSFORMER 2007 SUBSTATION TRANSFORMER 2007 SUBSTATION TRANSFORMER 2007 TRANSFORMER 2007 TRANSFORMER, 10 KVA 2007 TRANSFORMER, 100 KVA 2007 TRANSFORMER, 100 KVA 2007 TRANSFORMER, 1000 KVA 2007 TRANSFORMER, 112.5 KVA 2007 TRANSFORMER, 150 KVA 2007 TRANSFORMER, 1500 KVA 2007 TRANSFORMER, 167 KVA 2007 TRANSFORMER, 167 KVA 2007 TRANSFORMER, 2000 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 481,942.80 863,776.38 1,395,928.26 431,443.43 238,296.26 1,006,794.21 1,632.15 234,921.05 144,888.37 1,676,121.98 51,357.22 1,331.36 4,231,501.55 1,881,564.24 6,423.14 5,977,600.07 1,592,069.59 45,925,693.02 9,144.48 26,256.74 9,102.64 10,800.30 219,266.56 26,818.15 10,144,275.89 9,183,039.63 1,102,955.00 12,221.34 5,165.02 4,589,138.56 1,329,682.02 434,936.12 1,063,007.58 1,416,357.54 3,409.18 624,869.33 576,276.90 Page 244 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 2007 TRANSFORMER, 225 KVA 2007 TRANSFORMER, 25 KVA 2007 TRANSFORMER, 2500 KVA 2007 TRANSFORMER, 300 KVA 2007 TRANSFORMER, 37.5 KVA 2007 TRANSFORMER, 50 KVA 2007 TRANSFORMER, 50 KVA 2007 TRANSFORMER, 500 KVA 2007 TRANSFORMER, 525 KVA 2007 TRANSFORMER, 75 KVA 2007 TRANSFORMER, 750 KVA 2007 Total 2008 CURRENT TRANSFORMER 2008 CURRENT TRANSFORMER 2008 CURRENT/POTENTIAL TRANSFORMER 2008 CURRENT/POTENTIAL TRANSFORMER 2008 POTENTIAL TRANSFORMER 2008 POTENTIAL TRANSFORMER 2008 REGULATING TRANSFORMER 2008 REGULATING TRANSFORMER 2008 SUBSTATION TRANSFORMER 2008 SUBSTATION TRANSFORMER 2008 TRANSFORMER 2008 TRANSFORMER, > 2500 KVA 2008 TRANSFORMER, 10 KVA 2008 TRANSFORMER, 100 KVA 2008 TRANSFORMER, 1000 KVA 2008 TRANSFORMER, 112.5 KVA 2008 TRANSFORMER, 150 KVA 2008 TRANSFORMER, 1500 KVA 2008 TRANSFORMER, 167 KVA 2008 TRANSFORMER, 2000 KVA 2008 TRANSFORMER, 225 KVA 2008 TRANSFORMER, 25 KVA 2008 TRANSFORMER, 25 KVA 2008 TRANSFORMER, 2500 KVA 2008 TRANSFORMER, 300 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 1,041,712.59 225,761.62 251,723.36 1,772,153.36 47,675.26 2,658.20 3,285,222.85 3,030,994.44 1,600,508.31 5,319,365.49 2,118,513.70 49,483,012.16 11,609.50 1,176,652.48 1,453,012.05 29,633.32 5,051.32 44,703.61 354,920.69 322,100.81 5,667,055.29 23,892,747.78 317,141.61 56,536.67 8,685.19 2,029,355.02 1,125,863.97 516,199.41 844,616.28 994,574.83 803,470.44 406,028.86 1,230,881.37 2,665.73 173,182.16 150,265.58 3,551,872.69 Page 245 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 2008 TRANSFORMER, 300 KVA 2008 TRANSFORMER, 37.5 KVA 2008 TRANSFORMER, 50 KVA 2008 TRANSFORMER, 500 KVA 2008 TRANSFORMER, 75 KVA 2008 TRANSFORMER, 75 KVA 2008 TRANSFORMER, 750 KVA 2008 Total 2009 CURRENT TRANSFORMER 2009 CURRENT TRANSFORMER 2009 CURRENT/POTENTIAL TRANSFORMER 2009 CURRENT/POTENTIAL TRANSFORMER 2009 POTENTIAL TRANSFORMER 2009 POTENTIAL TRANSFORMER 2009 REGULATING TRANSFORMER 2009 SUBSTATION TRANSFORMER 2009 SUBSTATION TRANSFORMER 2009 TRANSFORMER 2009 TRANSFORMER, 10 KVA 2009 TRANSFORMER, 100 KVA 2009 TRANSFORMER, 100 KVA 2009 TRANSFORMER, 1000 KVA 2009 TRANSFORMER, 112.5 KVA 2009 TRANSFORMER, 15 KVA 2009 TRANSFORMER, 150 KVA 2009 TRANSFORMER, 1500 KVA 2009 TRANSFORMER, 167 KVA 2009 TRANSFORMER, 2000 KVA 2009 TRANSFORMER, 225 KVA 2009 TRANSFORMER, 25 KVA 2009 TRANSFORMER, 2500 KVA 2009 TRANSFORMER, 300 KVA 2009 TRANSFORMER, 37.5 KVA 2009 TRANSFORMER, 50 KVA 2009 TRANSFORMER, 50 KVA 2009 TRANSFORMER, 500 KVA 2009 TRANSFORMER, 75 KVA 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 1,702,069.03 31,491.63 2,451,364.82 2,212,763.74 16,080.42 3,209,614.87 2,148,679.99 56,940,891.16 691,719.58 55,911.47 148,807.42 6,106.21 18,680.64 39,474.47 361,686.68 36,851,512.99 12,167,996.75 6,641,956.46 5,152.53 19,350.30 2,017,034.59 443,784.61 381,621.25 1,951.61 525,009.73 1,105,309.40 836,168.86 49,611.30 448,635.28 200,204.94 140,241.41 998,278.89 17,671.27 4,001.24 2,551,111.44 1,220,857.43 2,597,841.14 Page 246 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 2009 TRANSFORMER, 750 KVA 2009 Total 2010 CURRENT TRANSFORMER 2010 POTENTIAL TRANSFORMER 2010 REGULATING TRANSFORMER 2010 SUBSTATION TRANSFORMER 2010 TRANSFORMER 2010 TRANSFORMER 2010 TRANSFORMER, 10 KVA 2010 TRANSFORMER, 100 KVA 2010 TRANSFORMER, 1000 KVA 2010 TRANSFORMER, 112.5 KVA 2010 TRANSFORMER, 150 KVA 2010 TRANSFORMER, 1500 KVA 2010 TRANSFORMER, 167 KVA 2010 TRANSFORMER, 2000 KVA 2010 TRANSFORMER, 225 KVA 2010 TRANSFORMER, 25 KVA 2010 TRANSFORMER, 250 KVA 2010 TRANSFORMER, 250 KVA 2010 TRANSFORMER, 300 KVA 2010 TRANSFORMER, 37.5 KVA 2010 TRANSFORMER, 50 KVA 2010 TRANSFORMER, 50 KVA 2010 TRANSFORMER, 500 KVA 2010 TRANSFORMER, 75 KVA 2010 TRANSFORMER, 75 KVA 2010 TRANSFORMER, 750 KVA 2010 Total 2011 CURRENT TRANSFORMER 2011 POTENTIAL TRANSFORMER 2011 POTENTIAL TRANSFORMER 2011 REGULATING TRANSFORMER 2011 SUBSTATION TRANSFORMER 2011 SUBSTATION TRANSFORMER 2011 TRANSFORMER, > 2500 KVA 2011 TRANSFORMER, 100 KVA 3680 - Line Transformers 3530 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3530 - Station Equipment 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3620 - Station Equipment 3530 - Station Equipment 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 959,062.66 71,506,752.55 108,199.84 12,492.84 113,341.51 14,268,667.06 768,115.08 9,291.57 2,139.06 2,143,575.73 288,437.42 117,422.82 329,805.47 476,894.84 544,787.89 299,323.48 325,449.01 243,171.47 19,891.62 6,012.40 349,932.14 9,160.97 7,029.04 2,572,014.70 541,733.67 4,635.40 2,798,648.02 723,543.26 27,083,716.31 223,184.30 7,002.84 782.98 423.25 7,760,938.48 1,960,267.41 113,938.65 1,767,896.55 Page 247 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 2011 TRANSFORMER, 1000 KVA 2011 TRANSFORMER, 150 KVA 2011 TRANSFORMER, 1500 KVA 2011 TRANSFORMER, 167 KVA 2011 TRANSFORMER, 2000 KVA 2011 TRANSFORMER, 225 KVA 2011 TRANSFORMER, 25 KVA 2011 TRANSFORMER, 250 KVA 2011 TRANSFORMER, 2500 KVA 2011 TRANSFORMER, 300 KVA 2011 TRANSFORMER, 37.5 KVA 2011 TRANSFORMER, 50 KVA 2011 TRANSFORMER, 50 KVA 2011 TRANSFORMER, 500 KVA 2011 TRANSFORMER, 75 KVA 2011 TRANSFORMER, 750 KVA 2011 Total 2012 SUBSTATION TRANSFORMER 2012 TRANSFORMER 2012 TRANSFORMER, 10 KVA 2012 TRANSFORMER, 100 KVA 2012 TRANSFORMER, 1000 KVA 2012 TRANSFORMER, 112.5 KVA 2012 TRANSFORMER, 150 KVA 2012 TRANSFORMER, 1500 KVA 2012 TRANSFORMER, 167 KVA 2012 TRANSFORMER, 225 KVA 2012 TRANSFORMER, 25 KVA 2012 TRANSFORMER, 2500 KVA 2012 TRANSFORMER, 300 KVA 2012 TRANSFORMER, 37.5 KVA 2012 TRANSFORMER, 50 KVA 2012 TRANSFORMER, 500 KVA 2012 TRANSFORMER, 7 KVA 2012 TRANSFORMER, 75 KVA 2012 TRANSFORMER, 750 KVA 2012 Total 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3530 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3620 - Station Equipment 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 71,044.78 64,769.75 76,402.27 451,747.97 142,822.36 176,519.48 75,852.81 6,737.86 165,435.86 159,865.56 5,800.93 2,633.63 2,007,656.88 305,620.70 2,929,290.14 59,197.26 18,535,832.70 34,072.34 3,197,800.57 9.50 1,412,579.23 318,143.82 15,865.00 71,557.07 89,981.25 425,480.31 58,640.11 96,093.42 108,550.16 118,062.01 4,208.18 1,694,742.00 45,184.83 4,412.79 2,202,135.72 222,540.00 10,120,058.31 Page 248 of 273 14-05XXX; MDR 102 Attach 01 NEVADA POWER COMPANY MDR 102 ATTACHMENT Vintage Year Costs. Transformers by size and voltage class. As of 12/31/2013 2013 TRANSFORMER, 100 KVA 2013 TRANSFORMER, 112.5 KVA 2013 TRANSFORMER, 150 KVA 2013 TRANSFORMER, 1500 KVA 2013 TRANSFORMER, 167 KVA 2013 TRANSFORMER, 225 KVA 2013 TRANSFORMER, 25 KVA 2013 TRANSFORMER, 300 KVA 2013 TRANSFORMER, 50 KVA 2013 TRANSFORMER, 500 KVA 2013 TRANSFORMER, 75 KVA 2013 TRANSFORMER, 750 KVA 2013 Total Grand Total 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers 3680 - Line Transformers $ $ $ $ $ $ $ $ $ $ $ $ $ $ 428,274.66 13,641.83 13,696.48 109,228.83 140,975.36 13,520.06 52,132.47 22,502.99 486,376.96 45,013.19 954,535.62 69,592.76 2,349,491.21 860,220,706.45 Page 249 of 273 Nevada Power Company d/b/a NV Energy RESPONSE TO INFORMATION REQUEST DOCKET NO.: 14-05XXX REQUEST NO.: MDR 104 REQUESTER: REQUEST DATE: 2/4/2014 RESPONDER: Mundy, Joe REQUEST: Revenue. Provide, in a computer file or files, the revenue, the number of customers and the units sold by month for each individual rate schedule for the test period. RESPONSE CONFIDENTIAL (yes or no): No ATTACHMENTS CONFIDENTIAL (yes or no): No TOTAL NUMBER OF ATTACHMENTS: One RESPONSE: Please see the attached for the test period items. Page 250 of 273 RS-TOU-E - Res -TOU Enhanced RS-CPP- Res -TOU-Critical Peak ORS-TOU Option A-HEV ORS-TOU Option B ORS-TOU Option B-HEV RS Residential Service RS Rresidential-Prepaid RM- Residential Multi Family RS-L Large Residential Service ORS-TOU Option A ORM-TOU Option A RS-PAL Res Svc-Priv Area Light GS General Service OGS-TOU-Op Gen Svc TOU GS-PAL Gen Svc-Priv Area Light LGS-1 Lg General Service - 1 SSR-3 LGS-1 Standby OLGS-1-TOU-Opt LGS-1-TOU LGS-2-P---Primary LGS-2-S---Secondary LGS-3---Primary LGS-3-S---Secondary LGS-3-T---Transmission LSR-2 (LGS-3P) Lg Standby LSR-2(LGS-3T) Lg Standby LSR-1(LGS-2T) LSR-1(LGS-2P) LGS-X-P Extra Lg LGS Primary LGS-X-S Extra Lg LGS Secondary LGS-X-T Extra Lg LGS Trans LGS-WP-2--Primary LGS-WP-2-Secondary LGS-WP-3--Primary LGS-WP-3--Secondary SL-St/Traffic Lting-Metered Sl-St/Traffic Lting-Non-Meter MSL-Municipal St. Lting-Public MSL-Municipal St. Lting-Cust GS General Service-DO LGS-1 Lg General Service-1-DO LGS-2-S--Secondary--DO LGS-3-P--Primary-DO LGS-3-S--Secondary--DO LGS-3-T--Transmission--DO LGS-S-WP2-Secondary-DO LTS-T-WP2-Transmission-DO LGS-P-WP3-Primary-DO LGS-S-WP3-Secondary-DO LGS-T-WP3-Transmission-DO Grand Total 50 Rate Schedule (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 43 44 45 46 47 48 49 Ln No 2,290 10,843 2,566 41,526,796 1 14,327,266 214,687 121,256 5,957 17,182 5,084,365 25,528 21,829 20,850,350 1,024 112,298 320,769 9,937,888 9,184,366 4,250,244 678,005 182,169 654,911 3,345 19 1,295,158 28,968 1,854,312 43,401 24,998 43,598 12,508 602,797 393 4,164 1,225 23 2,308 19,846 23,992 28,893 55,202 3,767 3,023 37,480 13,469 21,996 February (c) $ 111,657,474 $ 2,441 11,547 1,988 61,017,744 19,065,278 296,646 155,625 6,117 (2,519) 5,558,840 28,282 24,434 20,127,904 1,197 99,344 335,442 10,100,403 9,355,088 4,424,493 779,009 190,310 721,882 3,669 4,628 1,581,941 30,529 2,024,688 44,302 28,163 39,494 15,806 751,119 394 4,174 1,235 23 2,216 19,459 24,199 29,195 55,620 3,726 3,028 37,905 13,474 21,935 $ 137,042,419 $ January (b) 77 2,254 11,716 1,851 43,717,466 13,907,633 234,649 121,055 6,518 9,130 5,555,242 25,401 26,525 23,538,565 934 120,955 341,093 11,481,142 10,798,612 5,037,677 739,123 205,821 704,948 3,140 1,666,237 42,124 2,078,678 49,170 38,096 44,670 13,175 653,813 396 4,176 1,233 23 2,397 19,494 23,616 25,935 52,841 3,726 3,017 37,260 13,448 22,647 $ 121,387,700 $ March (d) 143,938 294,874 2,536 12,450 2,169 43,842,602 13,233,470 209,148 121,803 6,586 9,747 5,637,171 26,476 27,754 26,111,363 916 96,518 391,042 12,472,647 11,941,325 5,555,028 905,085 237,388 825,156 3,362 1,903,167 43,764 2,627,248 73,840 33,027 60,023 21,813 648,278 417 4,262 1,286 23 2,473 24,399 24,249 21,442 57,217 3,756 3,049 39,699 13,517 26,391 $ 127,743,895 $ April (e) June (g) $ 247,468,930 24,952 $ 117,147 62,775 254,697 3,017 8,374 13,819 17,336 4,693 3,221 64,250,295 113,961,543 2 5 18,366,969 26,859,432 285,395 488,912 132,560 528,433 7,364 18,885 (2,461) 8,469 6,214,801 6,818,822 29,470 25,215 30,956 16,593 29,588,277 33,087,978 905 901 122,488 191,187 446,375 570,840 13,772,014 19,937,532 12,102,905 22,424,421 6,325,208 8,972,052 1,356,600 1,735,674 247,766 498,493 953,580 2,049,070 3,006 3,153 3,159 2,113,145 3,794,300 36,525 101,945 2,715,221 3,826,520 104,011 123,153 37,211 109,673 82,632 115,167 21,991 18,246 591,405 555,522 423 421 4,295 4,284 1,312 1,305 23 23 2,626 2,756 24,822 25,286 36,389 14,745 21,255 21,777 58,192 60,652 3,886 4,120 3,073 3,122 41,442 43,684 13,548 13,628 28,193 30,218 $ 160,288,513 $ May (f) 221,082 456,834 20,320 42,256 8,231 148,284,482 5 33,646,117 539,244 805,788 15,156 8,471 7,282,044 34,341 28,693 36,630,896 1,407 256,986 854,993 29,513,034 27,234,174 13,569,272 1,874,246 594,581 2,591,651 7,664 4,373,933 136,427 6,373,215 116,929 237,830 116,159 27,831 528,892 451 4,402 1,376 79 2,752 26,214 28,467 22,651 60,223 4,495 3,157 43,353 13,931 28,420 $ 316,673,153 $ July (h) Nevada Power Company d/b/a NV Energy Nevada Jurisdiction MDR 104 - Revenues Twelve Months Ended December 31, 2013 468,753 919,417 12,850 55,881 7,866 110,688,738 28,344,008 505,341 937,335 55,384 8,579 6,889,228 28,947 25,178 35,437,758 1,096 312,898 799,513 24,564,049 23,940,425 11,537,349 1,902,646 546,042 2,409,999 6,909 4,124,003 83,299 5,317,883 112,177 214,928 127,749 41,673 602,610 462 4,467 1,425 78 2,799 26,078 29,052 23,883 62,862 4,600 3,172 45,779 13,964 29,486 $ 261,278,618 $ August (i) 376,181 673,475 39,557 55,175 38,062 82,768,542 21,292,604 272,134 585,033 19,725 8,467 6,333,595 50,700 22,921 31,162,384 1,103 330,189 740,453 23,558,391 23,316,124 11,022,110 1,569,766 509,373 2,127,091 29,033 3,441,277 104,348 4,690,001 73,158 91,220 95,245 51,813 697,221 460 4,459 1,420 50 2,830 25,291 29,159 24,324 61,755 5,075 3,154 46,025 13,961 29,162 $ 216,393,598 $ September (j) Grand Total (n) $ 2,080,740,053 63,188 $ 1,694,098 57,867 3,337,444 3,514 100,631 26,343 258,921 7,367 77,989 52,584,806 839,406,763 13 15,597,812 230,913,126 264,998 3,835,242 105,279 3,672,406 13,318 152,692 9,677 103,254 5,701,237 72,319,841 198,116 763,043 28,673 313,771 23,075,133 333,260,369 9,162 19,800 90,912 1,989,688 433,894 6,149,562 11,699,337 194,464,154 11,196,923 183,387,960 4,935,151 87,770,118 738,836 13,849,360 218,653 3,871,362 685,587 15,487,548 (9,138) 78,320 7,805 1,581,281 29,325,936 23,963 712,959 2,152,587 39,175,783 44,795 918,419 55,894 1,090,038 47,779 948,112 12,455 300,521 951,319 8,224,435 452 5,207 4,351 52,019 1,395 16,096 24 468 2,344 30,274 23,164 284,522 49,669 338,214 19,956 289,046 51,463 692,000 3,697 50,137 2,569 36,545 33,914 491,429 11,110 161,327 19,856 311,288 December (m) $ 132,830,682 137,702 $ 306,997 3,309 12,504 12,831 37,197,257 11,983,348 195,325 1,724 (11,488) 20,290 5,655,872 (18,132) 37,710 26,766,020 1,147 59,274 337,734 9,761,012 10,596,244 4,361,403 991,007 134,124 504,412 10,430 1,644,454 57,639 1,863,022 53,329 33,718 86,135 14,602 904,443 467 4,489 1,440 50 2,492 24,993 26,071 24,975 58,200 4,573 3,092 43,238 13,320 28,233 November (l) $ 113,951,032 141,079 $ 310,507 169 (10,948) (12,855) 39,566,492 14,289,189 328,763 56,514 9,170 8,222 5,588,624 308,697 22,504 26,883,740 8 196,639 577,414 17,666,705 11,297,352 7,780,130 579,363 306,642 1,259,262 13,746 (0) 1,807,040 23,430 3,652,408 80,153 185,279 89,462 48,608 737,016 469 4,498 1,445 50 2,280 25,475 28,605 24,760 57,775 4,717 3,088 41,648 13,957 24,751 $ 134,024,039 $ October (k) 50 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 Ln No 14-05XXX; MDR 104 Attach 01 Page 251 of 273 RS-TOU-E - Res -TOU Enhanced RS-CPP- Res -TOU-Critical Peak ORS-TOU Option A-HEV ORS-TOU Option B ORS-TOU Option B-HEV RS Residential Service RM- Residential Multi Family RS-L Large Residential Service ORS-TOU Option A ORM-TOU Option A RS-PAL Res Svc-Priv Area Light GS General Service OGS-TOU-Op Gen Svc TOU GS-PAL Gen Svc-Priv Area Light LGS-1 Lg General Service - 1 SSR-3 LGS-1 Standby OLGS-1-TOU-Opt LGS-1-TOU LGS-2-P---Primary LGS-2-S---Secondary LGS-3---Primary LGS-3-S---Secondary LGS-3-T---Transmission LSR-2 (LGS-3P) Lg Standby LSR-2(LGS-3T) Lg Standby LSR-1(LGS-2T) LSR-1(LGS-2P) LGS-X-P Extra Lg LGS Primary LGS-X-S Extra Lg LGS Secondary LGS-X-T Extra Lg LGS Trans LGS-WP-2--Primary LGS-WP-2-Secondary LGS-WP-3--Primary LGS-WP-3--Secondary SL-St/Traffic Lting-Metered Sl-St/Traffic Lting-Non-Meter MSL-Municipal St. Lting-Public MSL-Municipal St. Lting-Cust GS General Service-DO LGS-1 Lg General Service-1-DO LGS-2-S--Secondary--DO LGS-3-P--Primary-DO LGS-3-S--Secondary--DO LGS-3-T--Transmission--DO LGS-S-WP2-Secondary-DO LTS-T-WP2-Transmission-DO LGS-P-WP3-Primary-DO LGS-S-WP3-Secondary-DO LGS-T-WP3-Transmission-DO Grand Total 49 Rate Schedule (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 43 44 45 46 47 48 Ln No ` 850,655 31 104 11 497,305 246,674 242 2,592 197 74,739 328 26,655 1 108 30 1,222 120 163 3 2 9 1 1 7 5 4 11 29 4 2 5 1 3 6 3 5 8 4 1 8 7 4 January (b) 852,484 37 115 22 497,402 248,417 242 2,677 205 74,219 333 27,023 1 121 30 1,221 121 164 3 3 9 1 7 5 4 11 30 4 2 5 1 3 6 3 5 8 4 1 8 7 4 February (c) 850,605 1 3 6 3 5 8 4 1 8 7 4 1 3 7 3 4 8 4 1 8 7 4 856,018 - 7 5 4 11 30 4 2 5 - 7 5 4 11 30 4 2 5 42 119 13 496,257 247,567 244 2,578 200 74,642 307 26,848 1 111 30 1,226 121 164 3 3 9 1 April (e) 1,126 2,436 48 124 20 496,117 248,505 242 2,610 199 75,613 313 26,905 1 112 29 1,199 121 164 3 3 9 1 1 March (d) 1 3 7 4 4 8 4 1 8 7 4 858,072 - 7 5 4 11 30 4 2 5 1,128 2,427 50 121 24 496,827 249,465 245 2,608 202 75,867 327 27,004 1 115 31 1,210 121 164 3 3 9 1 May (f) 1 3 7 2 4 8 4 1 8 7 4 861,131 - 7 5 4 11 31 4 2 5 1,118 2,416 53 116 16 498,763 250,755 241 2,528 205 75,861 315 26,963 1 121 29 1,207 121 168 3 3 9 1 June (g) 3 3 7 3 4 8 4 1 8 7 4 861,106 - 7 5 4 11 31 4 2 5 1,083 2,344 57 126 26 499,048 250,256 243 2,629 200 75,587 320 27,411 1 101 30 1,220 121 166 3 3 9 1 July (h) Nevada Power Company d/b/a NV Energy Nevada Jurisdiction MDR 104 - Customers Twelve Months Ended December 31, 2013 3 3 7 3 4 8 4 1 8 7 4 862,994 - 7 5 4 11 31 4 2 5 1,075 2,344 42 124 16 500,178 251,480 247 2,408 200 74,846 314 27,925 1 112 30 1,230 121 164 3 3 9 1 August (i) (k) 2 2 7 3 4 8 5 1 8 7 4 863,717 - 7 5 4 11 30 4 3 5 1,050 2,283 57 141 22 500,920 250,688 239 2,746 204 75,439 338 27,793 1 119 32 1,221 121 167 3 3 8 2 2 2 7 3 4 8 5 1 8 7 4 863,863 - 7 5 4 11 30 4 3 5 1,015 2,241 51 137 19 500,501 249,931 238 2,611 198 74,998 2,574 27,567 1 114 30 1,216 123 163 3 3 7 2 September October (j) (m) 2 2 7 3 4 8 5 1 8 7 4 862,374 - 7 5 4 11 29 4 3 5 1,004 2,222 89 129 42 502,388 250,464 243 2,492 189 73,569 321 27,460 1 106 29 1,209 122 160 3 3 8 2 4 2 7 5 4 8 5 1 8 7 4 865,124 - 7 5 4 11 29 4 3 5 985 2,204 95 126 46 502,801 250,597 184 2,434 195 73,789 2,597 27,292 3 116 29 1,209 122 161 3 3 8 2 November December (l) 10,308,143 9,585 20,917 652 1,482 277 5,988,507 2,994,799 2,850 30,913 2,394 899,169 8,387 326,846 14 1,356 359 14,590 1,455 1,968 36 35 103 16 1 84 60 48 132 360 48 28 60 22 32 81 38 51 96 52 12 96 84 48 49 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 Ln Grand Total No (n) 14-05XXX; MDR 104 Attach 01 Page 252 of 273 (a) RS-TOU-E - Res -TOU Enhanced RS-CPP- Res -TOU-Critical Peak ORS-TOU Option A-HEV ORS-TOU Option B ORS-TOU Option B-HEV RS Residential Service RM- Residential Multi Family RS-L Large Residential Service ORS-TOU Option A ORM-TOU Option A RS-PAL Res Svc-Priv Area Light GS General Service OGS-TOU-Op Gen Svc TOU GS-PAL Gen Svc-Priv Area Light LGS-1 Lg General Service - 1 SSR-3 LGS-1 Standby OLGS-1-TOU-Opt LGS-1-TOU LGS-2-P---Primary LGS-2-S---Secondary LGS-3---Primary LGS-3-S---Secondary LGS-3-T---Transmission LSR-2 (LGS-3P) Lg Standby LSR-2(LGS-3T) Lg Standby LSR-1(LGS-2T) LSR-1(LGS-2P) LGS-X-P Extra Lg LGS Primary LGS-X-S Extra Lg LGS Secondary LGS-X-T Extra Lg LGS Trans LGS-WP-2--Primary LGS-WP-2-Secondary LGS-WP-3--Primary LGS-WP-3--Secondary SL-St/Traffic Lting-Metered Sl-St/Traffic Lting-Non-Meter MSL-Municipal St. Lting-Public MSL-Municipal St. Lting-Cust GS General Service-DO LGS-1 Lg General Service-1-DO LGS-2-S--Secondary--DO LGS-3-P--Primary-DO LGS-3-S--Secondary--DO LGS-3-T--Transmission--DO LGS-S-WP2-Secondary-DO LTS-T-WP2-Transmission-DO LGS-P-WP3-Primary-DO LGS-S-WP3-Secondary-DO LGS-T-WP3-Transmission-DO Grand Total 49 Rate Schedule 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 Ln No (b) (c) 1,293,598,208 111,645 1,735,826 1,446,592 1,922,603 10,889,602 280,352 50,479 3,485,743 1,469,898 3,202,334 103,546 1,588,502 1,522,221 1,776,957 11,091,215 250,333 52,718 3,692,838 1,477,250 3,174,415 1,579,131,937 42,464 159,472 45,278 332,789,754 121,014,509 1,952,661 1,997,468 88,851 156,978 49,043,833 454,607 208,957 239,253,346 10,426 2,154,529 5,766,963 159,557,410 171,259,863 73,821,471 14,856,654 3,319,590 12,057,267 68,609 23,638,375 487,539 40,282,250 643,157 281,071 777,318 262,974 12,486,168 7,589 33,522 22,211 February 46,023 201,638 38,213 513,132,031 169,489,274 2,778,195 2,810,825 113,407 (21,800) 57,088,462 518,013 236,649 245,120,593 12,780 1,968,409 6,235,437 165,997,040 181,024,559 78,270,376 17,641,487 3,554,642 14,009,820 75,862 27,910 30,966,990 556,517 44,683,279 671,399 271,659 688,260 351,283 15,779,388 7,589 33,522 22,211 January (d) (e) 1,409,612,069 96,974 1,616,661 1,296,771 1,479,410 9,833,590 257,618 47,479 3,379,341 1,362,520 3,502,478 1,454,533,681 125,871 2,170,008 1,531,555 1,211,540 11,819,467 275,354 62,654 4,560,906 1,774,261 5,227,876 33,402,767 723,545 53,694,660 1,164,078 377,704 1,096,036 483,628 12,399,683 7,590 33,522 22,211 30,998,188 743,622 44,796,715 732,437 430,053 783,676 268,406 13,491,965 7,589 33,522 22,211 40,148 172,414 34,409 346,059,056 113,782,199 2,114,149 1,905,182 90,350 82,478 52,065,466 432,405 253,239 265,168,286 9,158 2,230,089 6,018,537 183,792,884 199,757,683 87,052,975 16,196,313 3,843,859 13,265,167 63,346 1,809,497 3,682,327 43,458 172,866 34,815 338,603,717 104,373,574 1,824,801 1,800,839 80,630 85,421 50,572,535 412,705 256,603 281,165,862 7,786 1,796,313 6,679,842 191,720,354 207,375,527 92,320,169 18,471,852 4,216,600 14,797,326 63,346 April 1,051 March 1,810,375,607 146,342 2,319,217 2,464,917 1,136,657 12,255,015 356,153 73,462 5,384,584 1,992,734 6,058,074 38,213,024 595,819 55,088,221 1,709,866 494,469 1,555,398 472,148 11,359,475 7,589 33,522 22,211 298,838 767,112 51,967 208,643 88,456 521,456,332 154,515,692 2,557,685 2,133,245 107,974 (22,985) 58,894,300 463,893 286,046 326,398,169 7,084 2,165,440 7,720,582 217,499,310 215,420,655 107,318,549 28,156,638 4,436,196 17,651,303 55,586 May (f) 2,455,816,577 150,482 2,485,819 1,555,540 1,332,011 13,351,468 496,428 96,288 6,493,967 2,581,959 6,991,528 37,676,621 1,306,689 53,312,613 2,094,672 2,609,123 2,261,363 397,733 10,656,394 7,589 33,522 22,211 1,503,201 3,267,741 86,531 299,976 58,048 966,428,119 238,350,326 4,522,867 4,565,704 158,815 74,684 69,005,021 318,434 152,231 383,866,848 7,084 2,540,564 7,126,763 231,746,270 242,907,272 108,302,227 18,787,493 4,967,432 20,799,616 59,290 June (g) (h) 2,808,432,680 34,565,805 1,364,154 54,264,357 1,537,509 5,569,898 1,693,405 622,488 8,926,695 7,589 33,522 22,211 6,674 152,068 2,576,765 2,887,400 1,401,083 12,936,856 659,720 112,434 6,200,699 2,846,223 6,162,834 2,326,925 5,155,724 145,555 363,007 85,375 1,250,919,176 300,805,087 4,901,886 4,148,740 38,674 74,334 72,366,350 240,441 251,760 405,110,698 9,560 1,503,446 7,358,266 229,141,412 224,216,701 107,694,366 16,690,709 5,474,594 24,781,725 77,780 July Nevada Power Company d/b/a NV Energy Nevada Jurisdiction MDR 104 - kWh Sales Twelve Months Ended December 31, 2013 (i) 2,405,314,508 39,173,099 810,670 56,220,547 1,553,215 4,605,072 2,091,883 836,508 10,458,519 7,589 33,522 22,211 5,720 157,899 2,468,903 3,089,732 1,875,621 14,132,213 725,316 119,268 7,064,085 3,013,831 6,653,877 2,660,273 5,897,801 88,943 312,387 48,247 917,057,934 247,300,806 4,565,961 5,784,075 332,677 74,408 65,660,580 310,000 221,173 383,911,532 7,837 2,620,799 7,924,675 222,636,678 224,944,550 107,805,841 21,833,951 5,104,363 23,018,053 71,664 August (j) (k) 1,430,547,408 28,198,640 391,244 48,852,359 1,132,957 4,108,123 1,392,064 893,143 13,642,564 7,588 33,522 22,211 2,560 140,804 2,297,733 2,942,918 1,856,383 11,831,195 488,627 80,401 4,562,835 1,993,757 4,472,168 32,169,415 1,100,482 49,633,520 983,666 1,813,707 1,440,633 932,619 12,170,709 7,589 33,522 22,211 2,521 146,482 2,198,542 3,111,891 2,007,308 13,618,808 685,848 110,858 6,620,309 2,893,028 6,505,007 1,989,121,855 1,464,787 3,360,263 24,709 18,500 (92,871) 322,348,614 119,944,614 3,007,431 762,001 62,237 72,904 51,937,345 3,255,681 204,705 289,418,414 1,817,986 7,445,782 198,622,975 175,512,137 92,281,216 15,460,182 2,733,000 11,440,000 101,000 October 2,120,370 4,776,710 264,959 464,720 321,738 677,932,153 182,093,747 2,401,081 3,684,570 113,716 73,518 59,668,927 493,876 201,853 333,091,030 9,274 2,903,223 7,383,259 208,187,630 222,217,187 101,445,747 17,125,615 4,563,817 19,157,214 217,246 September (l) 1,353,876,090 33,310,578 1,038,862 50,245,660 704,882 386,125 1,466,884 261,859 15,735,765 7,589 33,522 22,211 2,903 145,380 2,448,659 2,254,066 1,867,453 12,216,036 429,187 82,092 5,471,448 1,989,550 6,076,733 1,585,304 3,529,789 108,189 164,224 207,870 265,956,196 86,682,292 1,612,295 1,267,777 (39,189) 171,874 47,302,296 305,939 331,896 273,197,040 10,277 2,073,160 7,035,240 186,261,192 208,346,515 89,960,591 20,862,013 4,250,465 16,174,083 321,318 November (m) 1,569,805,692 27,929,118 397,371 42,140,104 609,790 975,458 733,087 158,012 16,993,531 7,589 33,522 22,211 2,304 150,105 2,175,953 5,122,180 1,756,317 10,952,896 376,424 61,439 4,057,071 1,376,987 4,249,539 882,912 1,826,108 121,886 259,207 118,017 459,722,561 139,719,905 2,592,842 2,224,620 194,294 81,821 56,660,127 2,412,893 251,969 272,158,195 183,563 1,746,383 7,513,965 186,851,772 196,641,680 85,204,627 15,469,274 3,601,244 12,961,256 123,563 December 21,560,166,312 14,653,158 32,263,575 1,064,832 2,797,054 987,595 6,912,405,643 1,978,072,025 34,831,854 33,085,046 1,342,436 903,635 690,265,242 9,618,887 2,857,081 3,697,860,013 274,829 25,520,341 84,209,311 2,382,014,927 2,469,624,329 1,131,478,155 221,552,181 50,065,802 200,112,830 1,298,610 27,910 390,242,620 9,516,514 593,214,285 13,537,628 21,922,462 15,980,007 5,940,801 154,100,856 91,068 402,264 266,532 22,682 1,627,598 26,082,588 29,225,783 19,623,343 144,928,361 5,281,360 949,572 60,973,826 24,771,998 62,276,863 49 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 (n) Ln Grand Total No 14-05XXX; MDR 104 Attach 01 Page 253 of 273 Nevada Power Company d/b/a NV Energy RESPONSE TO INFORMATION REQUEST DOCKET NO.: 14-05XXX REQUEST NO.: MDR 105 REQUESTER: REQUEST DATE: 2/4/2014 RESPONDER: Young, Cindy REQUEST: Applicant’s interdepartmental expense allocations. If the applicant operates more than one utility department as described in general instruction 13 of the FERC System of Accounts, 18 CFR 101 or 18 CFR 201, provide in a computer file or files by account and month for the test period: a. b. c. d. e. f. The interdepartmental expense allocations. Each allocation source. The dollar amount before allocation. An identification of the allocation factor or factors used. The value of the allocation factor or factors. The dollar amount after allocation. RESPONSE CONFIDENTIAL (yes or no): No TOTAL NUMBER OF ATTACHMENTS: None RESPONSE: Nevada Power Company operates as an electric utility only and does not make interdepartmental expense allocations. Page 254 of 273 Nevada Power Company d/b/a NV Energy RESPONSE TO INFORMATION REQUEST DOCKET NO.: 14-05XXX REQUEST NO.: MDR 106 REQUESTER: REQUEST DATE: 2/4/2014 RESPONDER: McElwee, Curtis REQUEST: Provide a list, preferably in a computer file or files, of all work orders greater than $100,000 in total cost closed to plant since the end of the immediately preceding test period. At a minimum, include the work order number, the date closed to plant, the expenditure amount, the AFUDC/IDC amount, and if available, any CIAC amounts. RESPONSE CONFIDENTIAL (yes or no): No ATTACHMENTS CONFIDENTIAL (yes or no): No TOTAL NUMBER OF ATTACHMENTS: One RESPONSE: Please see the attached spreadsheet. This file contains a list of all work orders greater than $100,000 in total cost closed to plant since the end of the immediately preceding test period. Date range is from 01/01/2011 to 12/31/13. Listed are the work order number, work order description, date closed to plant (posting date), expenditure amount, AFUDC amount and CIAC amount. Page 255 of 273 Page 256 of 273 Work Order 9823023501 Total 0010002477 Total 9832614301 Total 9828427701 Total 0010002686 Total 9830364901 Total 0000194370 Total 0010004317 Total 0000187646 Total 0000190428 Total 0000193838 Total 0010004440 Total 0010002647 Total 9830706201 Total 0010000307 Total 0000189297 Total M000036228 Total 0010002130 Total 0010002962 Total 0000193084 Total 9819266201 Total 0000190362 Total 0010002132 Total 9830975301 Total 9827534102 Total 9834477301 Total 3000100398 Total 3000120608 Total 9831029901 Total 0010004695 Total 0010002059 Total 9834477201 Total M000040728 Total 0000181881 Total M000046577 Total M000038876 Total M000038765 Total 0000193829 Total 0010004046 Total 0010003347 Total 0010002712 Total 3000104231 Total 0010002772 Total 9828739401 Total TS395T8IN7 Total M000043254 Total M000044405 Total HACSU02099 Total 0000193549 Total M000033516 Total 0000175393 Total 3000081058 Total M000035554 Total 9832337001 Total 0010002804 Total 0001002182 Total M000037159 Total 0000188157 Total 0010003564 Total 0000192670 Total LR657XBENV Total 0010003145 Total 0010002597 Total 0000179502 Total 3000243147 Total 0010002928 Total Work Order Description RG1 BOILER INSULATION & SHEET SAN Switch Architecture LZ GAS DETECTING CAMERA RG3, BATTERIES/CHARGER, REPLAC NAV COM - COMP NET INFRSTRCTRE SH ASPHALT ROADWAY EXPANSION I MATERIALS CRUSHER ADDITION Energy Supply Remodel BOULDER HWY. BRT IMPROVEMENTS LIVEWORKS LAS VEGAS PARCEL E VA SATELLITE OUTPATIENT CLINIC Pearson Cable Management NAV COM - PULVRIZR DYNMC ANLYS LZ AIR COOLED CONDENSER CLEANI NAV COM-CONTRL SYST ALARM OPT CNLV-N. 5TH ST IMPROV-PH II RETRENCH 3600 NEEDLES HWY - LA NAV COM - RELAY PROTECT REPL NAV COM-Plnt Pipng Rplcmnt Canyon Falls Estates RG1 MERCURY MONITORS, CORELINK DATA CENTER UPGRADE NAV COM - REPL ERV ISO VALV U3 RGS FUEL ISLAND, REPLACEMENT SH1 CTB EVAPORATIVE MEDIA REPL LZ CCW VALVE LEGAL AID CENTER OF SOUTHERN N BUFFALO RANCH PHASE III LENZIE GT1 & GT2 COMPRESSOR ST AMI Optimization-Meters South Lorenzi Sub-DistTelemetering LZ PB2 HRH DRAIN POT, REPLACE RETRENCH 3535 RIO MAYO CLV - BUS TURNOUT PROJECT FY 2 RETRENCH @ 4749 WOODLAKE AVE RETRENCH 722 - 732 ARROWHEAD T PRI RETRENCH 2000 S WALNUT RD SANTA BARBARA PALMS SR APTS Windows RMS SrvrInstall-NVE(S) General Fiber Repl Prog 2012 GCR Phases 2 & 3 - NVE South AMPAC APARTMENTS Pearson DC Infrastructr Upgrad RG1 AIR HEATER SEALS, REPLACE INSTALL NEW ION METERS WINTERWOOD SUB REPAIR 69KV CLE PRI RETRENCH @ 2860 MILLER LN HACCP - WWT Plant Improvements CCPW LV BLVD SERENE STORM DRAI PRI RETRENCH 3749 LA JUNTA DR TERRACINA III OH RELOCATE PRI RETRENCH 2268 WHIPPLETREE CABLE INJECTION - POLLOCK U2 PPT EXCITATION TRANSFORMER ApexSub CT/PT&Insulator ChgOut I-215 AT GIBSON RETRENCH LINDELL 1207 AND 1208 SUNRISE HIGHLANDS UNIT 46-1 SupplyChainPSEnhancements-NVES COLLEGE VILLAS CC LANDFILL ENERGY - ENV Crystal ATS2 Replacement Dist Mapping Evaluation Softwa GREEN VALLEY 45 CORONADO EASTERN APTS WAN Optimization - S 2011 Posting Date 100,334.26 91,120.21 97,995.59 100,932.94 106,775.23 123,210.63 103,145.46 105,788.81 101,910.97 103,756.01 104,195.72 104,826.66 102,357.37 114,096.42 94,748.50 83,517.72 95,724.58 64,363.60 112,845.00 109,614.64 59,648.42 108,254.05 29,656.65 - 01/01/2011 - 05/31/2011 100,000.00 100,532.73 9,500.03 2,731.08 100,849.16 101,010.14 (5,632.00) (22,031.29) 101,445.75 102,047.83 (1,041.40) 102,576.84 (3,075.75) 1,229.37 103,156.79 103,853.94 104,105.59 104,438.87 105,636.83 3,294.21 105,791.02 106,531.88 106,980.98 107,251.51 107,257.80 (6,500.00) 107,934.18 108,069.26 13,363.29 108,366.83 109,031.36 109,177.78 109,550.39 109,599.69 109,605.98 109,631.18 109,866.97 109,991.42 27,049.45 15,162.65 111,390.17 111,738.94 112,386.15 48,288.77 112,818.93 112,845.64 3,287.49 112,999.55 113,005.09 113,234.54 53,792.08 113,486.35 113,588.25 113,658.24 113,942.37 114,229.92 6,013.72 85,087.45 114,760.61 114,805.73 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 100,000.00 100,334.26 100,532.73 100,620.24 100,726.67 100,849.16 100,932.94 101,010.14 101,143.23 101,179.34 101,445.75 102,047.83 102,104.06 102,576.84 102,713.06 103,140.34 103,156.79 103,756.01 103,853.94 104,105.59 104,195.72 104,438.87 104,826.66 105,636.83 105,651.58 105,791.02 106,531.88 106,980.98 107,251.51 107,257.80 107,596.42 107,934.18 108,069.26 108,111.79 108,366.83 109,031.36 109,177.78 109,550.39 109,599.69 109,605.98 109,631.18 109,866.97 109,991.42 110,567.17 110,887.23 111,390.17 111,738.94 112,386.15 112,652.37 112,818.93 112,845.00 112,845.64 112,902.13 112,999.55 113,005.09 113,234.54 113,440.50 113,486.35 113,588.25 113,658.24 113,942.37 114,229.92 114,267.77 114,744.10 114,760.61 114,805.73 01/01/2011 - 12/31/2013 1,857.51 158.14 1,062.44 65.89 1,328.62 4,221.04 578.22 140.87 126.18 1,707.50 1,880.70 7,420.22 0.00 1,998.44 878.41 665.12 698.51 42,740.70 245.76 3,729.81 79.84 662.77 151.68 463.46 60.86 840.68 854.12 154.76 4,013.99 9.90 6.78 1,036.62 332.33 135.10 722.44 984.69 137.92 232.21 82.75 3,054.18 1,212.29 209.01 1,085.96 5,360.10 162.99 60.12 896.40 8.69 51.46 2,303.37 878.84 447.44 498.50 1,171.38 476.52 - AFUDC Debt 2,206.59 193.44 1,294.93 80.04 1,733.96 5,091.72 701.98 171.24 169.14 2,057.93 2,341.73 8,724.57 (0.03) 2,548.52 1,064.60 810.82 837.42 50,925.62 298.74 4,481.85 95.78 812.34 203.72 568.96 72.99 1,008.45 1,003.90 207.85 4,777.37 12.72 8.29 1,331.04 398.57 173.65 866.61 1,204.74 165.43 284.05 101.23 3,640.08 1,531.07 267.02 1,302.65 6,443.05 209.50 72.11 1,094.20 10.66 65.01 2,888.82 1,060.72 547.31 598.51 1,425.11 618.84 - AFUDC Equity (23,402.00) (251,515.00) (191,512.00) (172,625.00) (0.00) (361,881.00) (6,518.00) (111,958.00) (149,619.00) (90,647.98) (59,114.00) 112,845.00 (74,288.00) (18,781.00) (0.15) - CIAC (380,719.99) - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 1 of 13 Page 257 of 273 Work Order TL522S5SWB Total M000040900 Total 0010002124 Total 9830329201 Total 3000004343 Total 3000005674 Total 0010003623 Total 0010002963 Total 9829554101 Total 9833114601 Total 0010004442 Total 0010003532 Total 3000125250 Total 0000181095 Total 0010002748 Total TL668M6TPT Total 9830698401 Total 0010003600 Total 9827533901 Total 9831395001 Total 3000010249 Total COE92D2CMM Total M000044469 Total 0010003071 Total TL588TRGHE Total 0000194068 Total COF69MXCMM Total CO716QOSWE Total 0010000656 Total 0000187737 Total 3000023745 Total 9828996101 Total 0010002628 Total M000037147 Total 0010003090 Total 0000180882 Total M000027725 Total 0010004005 Total 9828159701 Total 0010003334 Total 3000152648 Total 0010003303 Total 0010003076 Total 0010002867 Total 3000057708 Total 3000107655 Total 0000174062 Total 0010004015 Total 0010002599 Total COD79ATCMM Total 0010003417 Total 0010003481 Total 3000249629 Total 3000010500 Total 3000093825 Total M000035972 Total 0010003340 Total 9827995201 Total M000040330 Total 9827853701 Total M000041131 Total 9827662701 Total 0010003447 Total 9832620901 Total 9830105301 Total M000035375 Total Work Order Description SURGE WTR 69KV TAP LNE UPGRADE PRI RETRENCH @ 4095 E. FLAMING NAV COM - CIRC BRKR REP, COMM WH1&2 HRSG 01HP526 & 02HP526 H PRI RETRENCH 3831 HADDOCK AVE RETRENCH 6944 CLOUD CIR eCompPlus NVE South NAV COM-Control Systm Rplcmnt HA - HARVEY WELL PUMP MOTOR RE RGC1-4 4KV & 7KV BREAKER GROUN Remodel Pearson Cafeteria Perillon EMIS build NPC GRANDVIEW LV BUILDING 5 GRANDE POINT, PHASE 3 Sahara TelemeteringUpgd 2011 TEMP TROP T TAP (RECONDUCTOR) RG4 HYDROGEN PURITY SYSTEM, RE HR Remodel - Pearson SH1 CTA EVAPORATIVE MEDIA REPL RG4 REHEAT FAN & STACK BREACH Smith Williams Senior Apartmen DI ROAD MICROWAVE BYPASS PRI RETRENCH MH-4000 TO MH-336 Informatica Licenses NVE-South COH (EAST) GALLERIA Half St SNRHA PERRY PLAZA Gypsum PV Co 106 (Comm) ENTI ROBINSON 500/345KV State Farm Building Improvemen SH II - MP ADDENDUM 2 SECTA Replacement Phase 1 CK 9 & 10 COOLING TOWER DRIFT Burnham 12kV Telemetering Upgr C/O BAD XFMR HHH-43078 @ 5255 BI Infa 9.1 Upg - NVE South SUMMER VILL. 16 E, J & K PH I CABLE INJECTION - MOUNTAIN VIS Beltway Interiors Requests RG2 GRAND SEAL STEAM REGULATOR Replace Concrete Slabs Ryan Town Center 44/50 WAN Optimization-NVES 2012 Switchgear Repl Lindell Sub South Online Equal Pymnt Plan SUTTER RANCH/ ESTATES PH 1 DATA CENTER @ 7710 W. CHEYENNE DONNA DEER SPRINGS UNIT 2A Pearson Interior Cap Proj SDLC Phase II Change Control Audrey - Harmon FOC System E-Services Web Enhancements NAV-12-33M U3 Boiler Ovrhl, Fu SILVER LEAF PH 2 Goddard Henderson PA 1204 OH REBUILD RETRENCH @ 4317 WOODCREST RD Improve Space-Leasing Ryan SH OPERATION SURVEILLANCE SYST PRI RETRENCH @ 3720 BASIN ST RC1-4 ARC SAFE REMOTE BREAKER PRI RETRENCH @ 4036 TACOMA AV CK8, TURB TRANS PIECE INSTALL Telemetering Tenaya RG4 CONVEYORS FIRE PROTECTION REPLACE HRSG 1 AND 2 MAIN STEA PRI RETRENCH CHEYENNE & JONES Posting Date 1,212.64 116,720.02 126,657.22 121,956.68 122,605.44 7,121.39 123,335.85 126,420.67 101,961.78 128,802.76 128,801.14 265,663.49 130,491.23 01/01/2011 - 05/31/2011 115,250.75 116,715.37 117,019.16 117,100.34 117,209.87 117,355.10 117,435.12 118,150.61 118,292.31 118,469.93 118,737.69 118,767.88 118,976.66 119,199.47 119,219.88 119,274.94 119,864.97 (6,688.95) 120,008.06 120,044.25 120,132.33 120,664.33 120,683.04 120,697.57 120,818.04 121,195.08 121,371.27 121,961.47 122,375.50 122,407.39 122,498.94 122,731.24 115,873.37 123,889.00 124,092.23 124,504.57 124,615.20 125,009.72 125,300.57 125,842.43 125,903.60 125,904.19 126,165.27 2,938.00 126,375.49 24,538.30 126,541.13 126,570.55 126,597.49 126,734.20 127,600.29 128,139.63 128,261.88 (488.25) 128,442.26 129,063.47 (135,912.63) 130,101.65 130,442.69 130,464.49 - 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 116,463.39 116,715.37 116,720.02 117,019.16 117,100.34 117,209.87 117,355.10 117,435.12 118,150.61 118,292.31 118,469.93 118,737.69 118,767.88 118,976.66 119,199.47 119,219.88 119,274.94 119,864.97 119,968.27 120,008.06 120,044.25 120,132.33 120,664.33 120,683.04 120,697.57 120,818.04 121,195.08 121,371.27 121,956.68 121,961.47 122,375.50 122,407.39 122,498.94 122,605.44 122,731.24 122,994.76 123,889.00 124,092.23 124,504.57 124,615.20 125,009.72 125,300.57 125,842.43 125,903.60 125,904.19 126,165.27 126,273.85 126,375.49 126,420.67 126,500.08 126,541.13 126,570.55 126,597.49 126,734.20 127,600.29 128,139.63 128,261.88 128,314.51 128,442.26 128,801.14 129,063.47 129,750.86 130,101.65 130,442.69 130,464.49 130,491.23 01/01/2011 - 12/31/2013 (2,532.97) 375.85 1,783.60 2,425.93 1.88 7.93 960.91 1,742.51 24.55 2,186.84 210.11 110.74 566.57 140.09 5,338.34 663.42 129.48 798.18 81.30 284.88 195.12 3,841.45 941.23 749.90 1,433.94 3,630.03 591.69 17.30 5,919.13 55.62 917.67 1,038.55 1,208.60 13.33 83.81 423.55 1,791.78 2.06 3,550.11 3,004.90 83.26 43.65 2,995.86 47.73 4,627.08 899.68 277.18 6.17 1.10 1,247.69 2,974.34 642.75 1,663.24 AFUDC Debt (3,087.36) 454.00 2,162.42 2,987.26 2.25 9.50 1,152.67 2,127.61 32.97 2,634.60 257.91 132.16 693.07 168.05 6,765.36 813.12 158.40 957.46 104.50 341.85 257.66 4,882.92 1,151.07 902.54 1,754.04 4,354.42 777.17 21.16 7,473.74 66.72 1,100.80 1,263.58 1,454.11 16.31 100.53 562.17 2,114.65 2.52 4,417.25 3,604.54 107.01 53.39 3,717.83 57.90 5,945.18 1,087.90 340.04 7.40 1.30 1,496.68 3,823.14 771.02 1,982.18 AFUDC Equity 111,000.00 (36,028.00) (71,988.00) (148,086.00) (224.00) (6,784.00) 94,096.00 (182,228.00) (188,035.00) 2,938.00 (155,717.00) (31,106.00) - CIAC 150,365.53 (30,000.00) - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 2 of 13 Page 258 of 273 Work Order M000034874 Total M000034602 Total 9827969801 Total 0010002136 Total 3000259576 Total 9832983801 Total 0010002011 Total 9832613001 Total TL430P9PCB Total HACNS22500 Total M000046275 Total 9830518701 Total 9832859501 Total 0000192259 Total M000036245 Total 0010003869 Total 0000175890 Total M000038225 Total M000035756 Total 0010003824 Total 3000007087 Total 0010002747 Total 3000035582 Total 0010003381 Total 0010002801 Total 3000041214 Total 0010002184 Total 3000187368 Total 0010004363 Total 0000182156 Total 0000191995 Total M000045660 Total 9828930301 Total HACNS14000 Total 0000194463 Total M000036989 Total 0010002100 Total TSC44QSSUB Total M000031291 Total 9833210901 Total 0010002639 Total 0010002770 Total 9830739501 Total 9831681201 Total 3000080921 Total M000036150 Total 9831681301 Total 0010001630 Total M000038731 Total 0010004553 Total 9826575801 Total M000030135 Total M000034407 Total 9822836301 Total M000035382 Total M000036337 Total 9823634701 Total M000027757 Total 9832889601 Total 0000180976 Total 0010003783 Total 0010003079 Total M000025838 Total 0010003013 Total 0010004031 Total M000037163 Total Work Order Description CABLE INJECTION - OAK CANYON PRI RETRENCH 905 WINWOOD ST RG1-3 MESA POND MONITORING WEL NAV COM - CNTRL SYS REPL, COMM Tropicana Hotel Transformer so LZ PARTIAL DISCHARGE BUS COUPL South Service Center Telephone WH ST GEN EXCITER BRUSH RIGGIN SINATRA 138KV (BELLAGIO SHOOFL HACCP - Water Pipeline PRI RETRENCH @ 4665 SUN VALLEY RG3 EMERGENCY DIESEL GENERATOR SH 500 KV BUSHINGS MONITORING PRIORITY PLASTICS EXPANSION PRI FAULT REPAIR @ 3020 S TENA Alta 1255 Breaker C/O CLIFFS EDGE MASTER PLAN RETRENCH BLUE BONNET/CARNATION SA 1206 OH REBUILD DLP/Firewalls - NVE(S) Apex Regional Landfill Gas Del Mayfair TelemeteringUpgd 2011 Winco Foods Henderson Purchase System Spare 230kV po NPC Mainframe App Mgr - 2011 PRI RETRENCH 2517 HERROD DR NAV COM - SERV BLDG REFURB CABLE INJECTION - DAKOTA STATI Sub Oil Containment - Quail PROVIDENCE POD 123 A&B PH III INDIAN SPRINGS WASTE WATER UPG RETRENCH PRIMARY 3751 S NELLIS HIGGINS CI OUTAGE (CT1 & CT2) HACCP - PROJECT PERMITTING NDOT - NEON/ US-95 Crossing RETRENCH 2238 LUCERN DR. NAV COM - COAL FLAME SCANNERS Sinatra Bank # 5 Removal RETRENCH 2749 HERITAGE DR WHC INLET AIR EVAPORATOR COOLE Opsolve Transition NVE-S PBX Succession Upgrades S-2011 HA HARVEY WELL MOTOR AND PUMP HA RADIO SYSTEM, REPLACEMENT GALLAGHER CREST ELECTRICAL REL RIVERROAD 69 KV POLES CL RADIO SYSTEM, REPLACEMENT Rep Relay Westside Michael69kv RETRENCH - 933 KONGA DR Distc Design Remodel WH, PERMANENT CHEMICAL STORAGE PRI RETRENCH 4404 WAVECREST DR REMOVING MANHOLE 5757 WAYNE NE RG1-4 POND D STORM WATER DETEN RETRENCH @ 501 ROLLY ST CABLE INJECTION - OLIVE RG1-4, MESA FENCE, INSTALL PRI RETRENCH 1515 E RENO AVE 1 HIGGINS BUSHINGS MONITORING SY GOLDEN NUGGETT EXPANSION PeopleTools Upgrade 8.52 NVES Security Enhancements-South PAL CAP "DON'T CLOSE" NW 230kV Battery&Charger Repla Replace Beltway prkg lot light RETRENCH @ 5255 S BOULDER HWY Posting Date 5,645.51 133,217.32 133,770.05 137,682.42 179,080.06 1,110.70 149,213.65 838.79 142,514.90 109,277.65 144,148.11 145,490.80 140,471.67 150,269.91 133,124.41 151,767.50 152,001.57 169,682.34 65,804.00 85,099.70 01/01/2011 - 05/31/2011 126,152.71 131,907.92 132,429.74 133,354.70 133,446.06 135,167.49 135,359.54 (1,840.68) 136,191.94 136,220.70 136,270.10 (42,408.00) 137,037.09 137,223.28 136,622.88 137,960.04 138,827.62 138,875.48 139,122.14 139,161.54 139,572.03 140,181.63 140,571.19 141,055.66 (8,096.06) 141,238.38 141,372.59 140,592.72 143,038.45 143,172.34 34,580.51 143,871.07 (855.54) 145,011.35 145,374.55 146,372.91 6,322.65 147,144.80 147,702.94 147,751.21 147,840.17 148,580.17 148,585.66 148,632.02 148,699.99 148,707.31 148,984.10 150,127.08 17,496.52 151,919.76 (17,646.08) 152,264.57 86,759.00 152,582.06 152,694.99 152,710.60 152,995.54 153,618.23 68,706.84 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 131,798.22 131,907.92 132,429.74 133,217.32 133,354.70 133,446.06 133,770.05 135,167.49 135,359.54 135,841.74 136,191.94 136,220.70 136,270.10 136,672.06 137,037.09 137,223.28 137,733.58 137,960.04 138,827.62 138,875.48 139,122.14 139,161.54 139,572.03 140,181.63 140,571.19 141,055.66 141,117.59 141,238.38 141,372.59 141,431.51 142,514.90 143,038.45 143,172.34 143,858.16 143,871.07 144,148.11 144,635.26 145,011.35 145,374.55 146,372.91 146,794.32 147,144.80 147,702.94 147,751.21 147,840.17 148,580.17 148,585.66 148,632.02 148,699.99 148,707.31 148,984.10 150,127.08 150,269.91 150,620.93 151,767.50 151,919.76 152,001.57 152,036.26 152,264.57 152,563.00 152,582.06 152,694.99 152,710.60 152,995.54 153,618.23 153,806.54 01/01/2011 - 12/31/2013 89.10 223.76 3,284.86 228.13 456.23 1,576.15 1,374.97 5,845.07 282.56 2.94 904.74 3,249.43 2,473.07 84.15 6,055.58 1,007.13 1,097.47 212.11 29.28 366.71 82.23 204.36 2,168.24 205.31 1,411.36 994.15 552.39 1,984.05 2,244.56 9,697.47 975.51 895.59 42.89 1,688.21 222.68 2,056.70 4,864.79 559.11 170.07 972.37 13.58 1,604.25 16.80 93.90 8,753.95 222.00 3,040.55 7,589.54 2,317.58 649.63 585.93 324.77 251.62 79.76 - AFUDC Debt 108.32 273.39 3,937.46 293.23 586.42 1,902.01 1,767.37 6,975.68 363.19 3.51 1,177.96 3,934.79 2,995.36 100.94 7,264.09 1,286.84 1,335.68 254.44 35.83 448.56 100.58 245.14 2,648.27 263.79 1,660.59 1,192.55 729.04 2,370.96 2,720.59 11,939.98 1,193.31 1,062.56 52.46 2,113.42 286.23 2,515.85 5,956.93 670.68 204.01 1,142.81 16.28 1,928.20 20.44 126.06 10,830.53 271.17 3,652.05 9,283.87 2,777.63 835.01 747.00 392.00 307.81 104.67 - AFUDC Equity (140,484.99) (97,224.00) (0.01) (142,013.00) (13,548.00) 152,563.00 - CIAC 135,359.54 (1,246,719.55) - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 3 of 13 Page 259 of 273 Work Order 9826650301 Total 0010002753 Total 0010004030 Total 0000191794 Total 9832614701 Total 0000183781 Total M000034817 Total 9832454701 Total M000031424 Total 3000114050 Total 0000185987 Total M000040867 Total 0010002966 Total 9828204701 Total LNELOCAT09 Total 0010002378 Total 0010002817 Total 9828093801 Total 0010002240 Total 9830993501 Total M000047623 Total M000046508 Total 9832200201 Total 0010002964 Total 0010003482 Total 0010003233 Total 3000020861 Total 0000184015 Total 9831491001 Total 0010003762 Total TSB31T8ION Total EDANNUNGEN Total 9826528401 Total 0010002773 Total 9832375201 Total 9830731801 Total 0000185345 Total 9827704301 Total HACNS15000 Total 9834032801 Total M000047362 Total 0010003326 Total M000047701 Total HACSU02093 Total M000029814 Total 9827657901 Total M000047423 Total ASDPDEVIC10 Total M000036335 Total 9832286101 Total M000038577 Total 0010004587 Total 9827956201 Total 9827994701 Total 9830733401 Total 0000193786 Total 0010003492 Total 0010002564 Total M000046626 Total 0000183506 Total 9828428301 Total 0010003531 Total 0000192362 Total M000039235 Total 9827853201 Total M000031539 Total Work Order Description SHS MIST ELIMINATOR DRIFT CCW Misc. Capital Electrical Flat plate heat exchanger METRO HQ HIGGINS AND CLARK TESTING & DI WEST PARK (ENCLAVE 2, LOT 4) RETRENCH @ 5879 NATURES DR WHC CEMS ANALYZER, REPLACEMENT RE-TRENCH @ 4203 PINECREST WES WINDMILL APARTMENTS AVILLINO #2 RETRENCH 4094 SYRACUSE NAV COM-Precipitator Deck Rplc LZ MIXED RESIN BED REPLACEMENT Line Locates Capitalization Fac Upgrad/Remodel 2010 Fiber Mapping-2012 NVES LZ CT LUBE OIL PURIFIER REPLAC BI Supply Chain Phase II GC-S GE SYS 1 UPGRADE-OPTIMIZA PRI RETRENCH 14135 GRAND TETON PRI RETRENCH 70 RADWICK DR WHC BOP / ST BATTERY BANK, REP NAV COM-DCS Field Devices NAV-12-34M U3 Boiler Ov Water Tele Mac&Unforseen-2012 NVES EVAPS Law Office TUSCANY PARCEL 10 RC14 STEARNS BUILDING MODIFICA PI SYTEM UPGRADE INSTALL NEW ION METERS ALL TIE Eldorado-repl annunc /bkup gen RG4, SCRUBBER COLLECTION SYSTE Garrettcom Switch Replace-2011 RG3 UNDERBOILER SUMP SYSTEM LZ, BMS FUEL GAS REGULATOR UPG SYMPHONY PARK PH I- AKA UNION RG1 SCRUBBER AREA CONCRETE, RE HACCP - ENVIRONMENTAL COMPLIAN LZ DESERT TORTOISE FENCING, IN PRI RETRENCH 4200 W OAKEY BLVD Furnishings/Remodels 2012 PRI RETRENCH @ 7168 MONTCLIFF HACCP Safety Platforms Ladders PRI RETRENCH 2797 HORSESHOE DR R01 HYDROGEN COOLER, REPLACE PRI RETRENCH 4575 E PHILADELPH DataPower Devices CABLE INJECTION - NORWAY MAPLE RG1-3 EMERGENCY COOLING TOWER PRI RETRENCH 4957 SOUZA DR Lync Expansion - NVE(S) RG1-3 CARBONATE (SODA ASH) REC HA PI SOFTWARE AND SERVER UPGR HA PAVING AND CONCRETE, INSTAL BUFFALO PHASE 1 NAV-12-70M Cntrl Systm Replcmn NAV COM-SD FACILITY ENLRGMNT PRI RETRENCH 6996 HOPKINS DR CLV-HORSE DRIVE IMPROVEMENT RG1-4 DILUTION WATER HEATER, R Repl generator-christmas tree CRAIG/US95 COMMERCIAL RETRENCH 705 CRAGIN PARK RG1 SCRUBBER VENTURI PUMP VALV PRI RETRENCH 5398 BRIDGETTE WY Posting Date 148,333.28 311,424.47 1,212.91 155,486.56 149,673.23 175,428.65 158,520.06 161,862.15 144,448.37 194,159.85 170,577.76 188,073.29 174,376.82 175,573.70 161,859.51 177,983.48 (1,726.63) 239,630.95 - 01/01/2011 - 05/31/2011 5,478.04 154,406.75 154,891.50 (156,283.69) 155,162.14 154,180.51 155,660.14 156,256.87 156,333.72 6,830.50 157,736.25 157,893.94 (17,522.89) 158,469.47 159,134.12 (0.00) 161,927.67 161,991.90 162,788.76 162,848.20 162,902.55 162,919.40 162,934.38 163,565.03 163,570.22 163,639.58 163,854.19 164,135.87 164,679.54 164,821.83 20,885.69 166,427.30 167,412.23 168,521.18 168,601.89 (25,547.30) (1,804.57) 168,987.64 169,158.37 170,258.03 170,445.29 170,996.89 172,084.94 (15,373.62) 173,622.32 174,933.62 175,442.67 175,722.36 175,814.07 176,179.03 1,219.49 177,094.77 15,476.73 177,369.30 12.35 178,981.01 181,080.00 179,418.82 179,822.62 180,000.66 180,564.16 (58,736.85) 181,559.10 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 153,811.32 154,406.75 154,891.50 155,140.78 155,162.14 155,393.42 155,486.56 155,660.14 156,256.87 156,333.72 156,503.73 157,736.25 157,893.94 157,905.76 158,469.47 158,520.06 159,134.12 161,862.15 161,927.67 161,991.90 162,788.76 162,848.20 162,902.55 162,919.40 162,934.38 163,565.03 163,570.22 163,639.58 163,854.19 164,135.87 164,679.54 164,821.83 165,334.06 166,427.30 167,412.23 168,521.18 168,601.89 168,612.55 168,773.19 168,987.64 169,158.37 170,258.03 170,445.29 170,996.89 172,084.94 172,699.67 173,622.32 174,376.82 174,933.62 175,442.67 175,722.36 175,814.07 176,179.03 176,793.19 177,094.77 177,336.24 177,369.30 177,995.83 178,981.01 179,353.37 179,418.82 179,822.62 180,000.66 180,564.16 180,894.10 181,559.10 01/01/2011 - 12/31/2013 217.38 4,566.04 423.21 1,791.39 (0.01) 689.59 540.35 1,482.27 67.81 914.69 143.95 1,389.66 278.58 3,993.68 968.33 3,800.02 7,488.76 738.48 50.47 232.01 610.35 2,785.95 3,736.89 2,460.80 1,119.11 62.31 429.66 1,139.28 4,813.50 11,244.21 1,791.60 7.19 1,888.00 5,760.00 10,855.65 2.19 12,641.53 18.55 7,221.60 4,526.74 469.99 505.76 275.80 0.86 4,091.99 734.22 175.60 1,837.25 4,081.48 220.90 479.53 666.03 38.14 1,525.77 1,481.64 5,045.54 42.58 819.32 831.08 AFUDC Debt 255.50 5,548.77 567.78 2,302.61 0.01 844.90 694.55 1,812.63 81.33 1,106.71 172.67 1,694.28 340.77 4,811.48 1,138.07 4,565.23 9,037.72 885.87 66.22 298.21 784.53 3,402.45 4,482.65 2,951.89 1,357.21 71.00 515.33 1,382.85 5,801.21 13,584.97 2,166.35 8.79 2,426.70 7,204.81 13,149.58 2.57 15,378.44 23.84 9,179.31 5,430.65 603.45 618.67 324.14 1.03 4,928.65 986.12 214.80 2,249.26 4,981.08 268.36 575.19 784.26 49.01 1,830.27 1,837.29 6,143.59 52.09 1,003.45 1,016.62 AFUDC Equity (259,259.00) (143,670.00) (28,713.00) (198,938.00) (54,968.00) (77,564.00) (148,738.00) 181,080.02 (72,045.00) - CIAC - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 4 of 13 Page 260 of 273 Work Order 0010002376 Total 0010004589 Total 9827852701 Total 3000435215 Total 0000187694 Total 3000318815 Total 0001002091 Total M000031902 Total 0010003586 Total M000048234 Total 0000194131 Total 0010001749 Total 0010003491 Total M000041465 Total 9830706801 Total 9832889301 Total 0010002258 Total COD97GRCMM Total 0010003190 Total 9830706301 Total M000035885 Total COB97F8CMM Total 9831066001 Total M000030855 Total 0000180088 Total 9831006501 Total 0010003493 Total NAVRLYSCRT Total 9831006601 Total 0010002766 Total 0010002433 Total 0010003780 Total 9827853101 Total 0010003154 Total 9827854901 Total 9831793701 Total 0000191089 Total M000048401 Total 0010003446 Total 0000194151 Total M000035435 Total 0010003178 Total M000047546 Total M000040323 Total 9833603401 Total 0010004343 Total M000038485 Total 3000021344 Total 0010004035 Total 9830706401 Total 3000013048 Total 3000365014 Total 3000093813 Total 0010003621 Total 9817244001 Total M000043357 Total 0000192920 Total 0010002259 Total LR865YGBLM Total 0010003904 Total COB87X3CMM Total TL429QPMGT Total 9829171501 Total COB86X2CMM Total NV13521756 Total 9826180201 Total Work Order Description Misc Capital Elect Proj 2010 Sharepoint Internal Web-NVE(S) RG13 AIR WASHER, REPLACE CABLE INJECTION - COYOTE PEAK MIA-TERMINAL 1 BACK UP (SNT) PRI RETRENCH 3997 DELLING CT CAPACITOR VOLTAGE TRANSFORMERS NLV 1212 OH REBUILD AUD ENHANCEMENTS - SOUTH POLES DOWN N/W MERCURY 138 PYLE APARTMENTS Upgrade 1-IFC-11-2 to 11-3 NAV-12-66M Plant Piping Replcm RETRENCH @ 3633 BELMONT ST SH PAGING SYSTEM UPGRADE SH CONDENDATE PUMP DISCHARGE V Rate Case Automation Ph2-TM Perm Comm Solution/Goodsprings NW 343R Circuit Switcher LZ AUX BOILER CONTROL SYSTEM, PRI RETRENCH 5900 W TROPICANA RFL IMUX Upgrade and Replaceme GOODSPRINGS RELIABILITY UPGRAD AR 1211 PHASE C OH REBUILD ONE QUEENSRIDGE PLACE PH. #2 RG2 BALL CHARGE, REPLACE NAV-12-72M RailRd Cetanary Navajo Relays & Security Upgrd RG1 BALL CHARGE, REPLACE Fiber GIS Mapping - 2011 NAV COM - MAINTURBN FIRE SUPPR SOA WebSphere Upg - NVE Sout LZ OPERATIONS VIDEO SURVEILLAN Carpet tiles for circ hallways CKC FIRE EVACUATION ALARMS, IN RG1 SUMP PUMP, REPLACEMENT WOODBRIDGE I PRI RETRENCH @ 4516 BENNETT DR Telemetering Artesian ANN/GRAND CANYON SUB PRI RETRENCH 805 SAM JONAS DR DPS/ Badger Alarm Unit Repl RETRENCH @ 5355 MOONFLOWER CT RETRENCH- 3629 BASIN ST HA REPLACE INLET AIR FILTERS F Pearson Wellness Fac Improvemt RETRENCH 1600 N BUFFALO NLV 1209 OH MAINTENANCE Pearson Roof Replacement SH WEATHER PROTECTION FOR HRSG PRI RETRENCH 904 BILJAC ST CABLE INJECTION - CLOUDBURST PR 1206 OH REBUILD Kiosk - South AD CK10 CONDENSER, RETUBE REPLACE CABLE 1139 LINN LN CC215 NO. BELWAY TENAYA TO DEC CCS-EWQ Phase 3 2013 BLM Linear Easements Sharepoint Upgrade NVE-S SUNRISE MT MOBILE RADIO SITE ONLine Management Team CK11-22 GSU CONTINUOUS DGA MON MOBILE RADIO SYSTEM VIDA SWITC Navajo - repl brkrs / swchyrd RG1 ELEVATOR, REPLACE Posting Date 181,908.68 183,689.55 (4,077.83) 185,439.09 165,945.70 187,406.34 139,264.84 193,553.21 195,053.44 189,812.84 208,777.04 191,589.51 1,644.20 213,210.25 216,653.61 01/01/2011 - 05/31/2011 182,889.48 183,884.74 189,046.99 185,246.82 20,704.27 187,140.94 187,293.56 187,377.31 188,346.40 189,383.16 190,105.33 190,405.72 191,159.95 51,985.60 191,403.07 192,061.70 192,616.00 192,924.37 193,376.04 193,627.28 194,287.80 194,378.14 196,053.26 196,483.17 7,140.80 197,787.08 (10,964.43) 198,426.57 7,067.75 199,776.24 198,697.20 200,569.12 201,350.62 201,454.12 202,146.84 202,339.62 203,474.43 203,889.34 204,266.88 204,920.92 205,413.11 206,114.23 206,276.90 207,566.53 207,757.69 208,725.63 208,865.70 209,208.90 209,411.00 209,771.23 210,303.90 211,879.23 211,941.24 212,428.47 212,518.37 213,457.08 213,720.25 565.44 214,846.73 614.05 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 181,908.68 182,889.48 183,689.55 183,884.74 184,969.16 185,246.82 185,439.09 186,649.97 187,140.94 187,293.56 187,377.31 187,406.34 188,346.40 189,383.16 190,105.33 190,405.72 191,159.95 191,250.44 191,403.07 192,061.70 192,616.00 192,924.37 193,376.04 193,553.21 193,627.28 194,287.80 194,378.14 195,053.44 196,053.26 196,483.17 196,953.64 197,787.08 197,812.61 198,426.57 198,657.26 199,776.24 200,341.40 200,569.12 201,350.62 201,454.12 202,146.84 202,339.62 203,474.43 203,889.34 204,266.88 204,920.92 205,413.11 206,114.23 206,276.90 207,566.53 207,757.69 208,725.63 208,865.70 209,208.90 209,411.00 209,771.23 210,303.90 211,879.23 211,941.24 212,428.47 212,518.37 213,457.08 213,720.25 213,775.69 214,846.73 217,267.66 01/01/2011 - 12/31/2013 4,225.58 268.85 1.42 126.29 12.20 901.07 196.11 81.29 115.22 2,969.97 1,367.28 2,603.03 762.20 6,723.77 299.95 1,458.80 1,278.78 2,076.75 842.98 504.08 8,980.49 5,599.74 4,467.83 6,898.59 5,724.49 1,305.22 1,657.76 971.00 1.56 1,244.98 1,368.20 566.14 287.59 2,390.67 925.00 467.16 2,880.78 241.46 2,890.95 343.60 920.90 155.03 298.43 633.52 1,902.78 2,645.81 3,309.67 1,830.11 7,009.45 2,365.39 2,945.01 1,250.08 3,668.31 11,119.98 230.88 2,366.93 1,157.63 (148.37) AFUDC Debt 5,013.59 345.57 1.67 169.62 15.68 1,073.32 235.25 109.18 140.94 3,562.68 1,640.14 3,286.78 998.21 8,118.02 366.91 1,749.96 1,533.97 2,519.13 1,031.17 604.65 10,943.82 6,865.80 5,359.44 8,331.22 7,016.37 1,596.61 1,948.36 1,189.55 1.83 1,493.45 1,674.84 679.13 386.26 2,866.30 1,122.10 562.25 3,455.70 324.22 3,480.53 456.79 1,126.47 189.63 389.26 759.95 2,444.07 3,451.23 4,110.62 2,330.56 8,798.03 2,877.48 3,851.78 1,606.81 4,468.80 13,953.93 282.43 2,857.65 1,401.78 (174.38) AFUDC Equity (298,983.00) (94,980.00) 115,432.00 (195,493.00) - CIAC - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 5 of 13 Page 261 of 273 Work Order COD363ZCMM Total CO912NIECL Total 0010003651 Total 0010001772 Total 9832889701 Total M000031778 Total 0010003052 Total M000042252 Total 3000015211 Total COG20X4EDG Total 9830698501 Total 9826439701 Total 0000188536 Total 9832889201 Total TL917MXTRN Total 9830706501 Total ASBANRTS10 Total COA31AAADX Total 0010003236 Total HACAD02000 Total 0010003180 Total 3000057714 Total 9830793901 Total 0010002006 Total M000036339 Total 3000050891 Total 0010004034 Total 9829104701 Total 0010004033 Total 0010004056 Total 0010002863 Total 0010004109 Total 0000186365 Total 3000109022 Total 9823710201 Total 0010003554 Total 9834165401 Total 0010002148 Total 9830698601 Total 9828414601 Total 9827438301 Total 0010002769 Total M000033669 Total 0010002381 Total 0010002943 Total COC22ONCMM Total M000036197 Total CO916ORCCK Total COA20SYSCY Total M000039004 Total CO954ONBRP Total COE86B2CMM Total 9816507101 Total 9832888801 Total 9832879801 Total COA48OERSU Total COD77MBSEC Total 0010003711 Total TL779WYWSP Total 9830698001 Total 9830039701 Total 0010003231 Total 3000418039 Total 3000097731 Total 0010002972 Total 0010004433 Total Work Order Description Radio System Support 2012 EMS COMM LINE EXPANSION AND LI Navajo Sys Batteries Chrg 2012 Comm Battery&Charger Repl 2009 WHC GSU CONTINUOUS DGA MONITOR PRI/SEC RETRENCH 727 STRAWBERR Finance Statemnt Rept Auto/Opt Work Order Addition HORIZON 88 PHASE 1 MOBILE RADIO SYSTEM MIGRATION RG4 AIR WASHER, REPLACE RC14 RAW WATER FEED TO SEAL WA POLE OH/ UG - CRAIG RANCH PK SH POND DOSING AND TRANSFER SY Gypsum PV Co 106 (Sub Entrance SH SILVERHAWK ENGINEER AND INS Banner Test Server S 2010 RINGDOWN SYSTEM REPLACEMENT Call Center Automtn-2012 NVES HACCP - Builders Risk Replace Obsolete RTU's 2012 SUMMERLIN WATER PARK RG1-4 BLR DRAIN & BLOWDOWN REC IVR Expansion - South 2009 CABLE INJECTION - RAMROD I.C.E BUILDING US IMMIGRATION Beltway Fleet Fuel Tank SH1 EVAPORATIVE BLOWDOWN CONTR Beltway Fire Suppression Intel Srvr Evrgreen-NVE(S) Intel Srvr Evrgreen-June11 SOA Evergreen HIGHLANDS RANCH 5A Eldorado RCL No.24 PH2 RG1-3, MESA POND ACCESS ROAD QAS PH3_UCAPREM-S SH CT INLET AIR FILTERS, REPL Eldorado Control Rm Equipment RG1 AIR WASHER, REPLACE RG1-4, LANDFILL AREA MONITORIN LZ GAI-TRONICS EQUIPMENT INSTA Call Ctr Auto South - 2011 MA 1215 PHASE B OH REBUILD Construction Proj <150K 2010 ePerformance Implementation LV BADGER ALARM REPLACE PH 2 CABLE INJECTION - VANTAGE CESIUM DS 1 CLOCK REFERENCE SUB SECURITY PHASE VI 2010 SO POLES/WIRE DWN 5205 E CHARLEST BADGER ALARM UNIT REPLACEMENT BLACK START TELECOM DC POWER CK7-9 & WTP DCS DPU, UPGRADE HARRY ALLEN PHYSICAL SERCURITY WHC FIRE EVACUATION ALARM, INS RADIO SYSTEMS SUPPORT 2010 Substation Security 2012 Pearson Chiller # Replacement WARM SPRINGS AND I-15 WIDENING RG4 CONDENSER CP REPLACE-COATI LNZ ASPHALT ROADWAY EXPANSION ACD Expnsn&Back-up-2012 NVES CABLE INJECTION - PINE BLUFF WIGWAM APARTMENTS NPC-Pearson Space Frame Cyber Security Tools - NVES Posting Date 218,237.73 231,980.64 6,961.50 231,505.77 235,832.65 235,670.84 3,288.53 303,993.26 249,141.59 249,993.29 244,565.06 255,067.53 248,517.33 261,451.30 252,136.09 283,494.96 - 01/01/2011 - 05/31/2011 217,367.87 218,379.77 (10,168.43) 223,218.87 223,543.35 223,663.84 225,404.25 226,613.79 226,689.49 226,793.88 227,033.16 220,411.14 228,223.99 228,800.95 230,655.62 232,255.68 232,636.40 (2,103.27) 235,504.93 235,552.65 235,664.48 235,892.26 236,235.56 236,282.95 236,447.33 236,456.21 237,042.40 238,274.59 241,640.32 238,366.49 246,706.21 (57,099.01) 247,187.33 247,233.28 249,390.85 249,508.93 251,367.75 7,515.19 255,234.39 9,691.55 259,344.08 9,917.11 263,168.97 263,534.25 264,229.97 264,372.00 265,557.49 266,218.83 (16,917.62) 267,144.96 268,171.57 269,898.69 269,985.75 270,123.90 271,423.36 271,568.31 272,667.56 273,652.35 274,537.35 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 217,367.87 218,237.73 218,379.77 221,812.21 223,218.87 223,543.35 223,663.84 225,404.25 226,613.79 226,689.49 226,793.88 227,033.16 227,372.64 228,223.99 228,800.95 230,655.62 231,505.77 232,255.68 232,636.40 233,729.38 235,504.93 235,552.65 235,664.48 235,670.84 235,892.26 236,235.56 236,282.95 236,447.33 236,456.21 237,042.40 238,274.59 241,640.32 241,655.02 246,706.21 246,894.25 247,187.33 247,233.28 249,141.59 249,390.85 249,508.93 249,993.29 251,367.75 252,080.25 255,067.53 255,234.39 258,208.88 259,344.08 261,451.30 262,053.20 263,168.97 263,534.25 264,229.97 264,372.00 265,557.49 266,218.83 266,577.34 267,144.96 268,171.57 269,898.69 269,985.75 270,123.90 271,423.36 271,568.31 272,667.56 273,652.35 274,537.35 01/01/2011 - 12/31/2013 3,137.91 11,728.07 872.36 276.24 445.01 5,955.85 1,258.04 3,311.86 190.27 5,851.08 14.69 1,753.16 8,187.66 930.71 130.50 2,422.29 40,093.40 4,894.69 776.74 6,479.49 3,348.95 414.35 1,015.86 9,949.50 68.46 3,116.96 896.80 2,428.78 8,328.88 6,156.49 5,968.11 584.94 5,226.64 388.73 12,189.29 41.83 2,088.67 (0.00) 2,886.28 2,877.30 3,722.11 20,669.80 4,516.36 377.97 2,946.61 5,530.00 573.54 2,776.58 5,880.57 10,383.37 9,415.81 1,694.18 116.42 674.50 5,871.60 1,051.90 49.73 9,726.22 2,979.08 AFUDC Debt 3,764.12 14,438.58 1,071.16 355.06 543.71 7,197.70 1,573.75 4,321.91 228.26 7,098.43 17.61 2,288.78 10,463.12 1,113.10 159.64 2,905.69 49,167.89 5,919.68 934.46 8,350.37 4,046.56 499.49 1,362.88 12,161.39 90.61 4,073.17 1,097.02 3,141.49 10,451.03 7,360.86 7,511.03 785.63 6,170.86 466.31 14,878.53 49.17 2,554.96 (0.01) 3,392.20 3,519.65 4,374.57 25,252.24 5,308.00 462.35 3,604.42 6,790.93 763.04 3,640.53 6,911.31 13,221.69 12,122.83 2,032.28 139.66 825.08 7,043.39 1,412.79 59.65 11,706.10 3,918.11 AFUDC Equity (77,631.00) (59,553.00) (105,041.00) (84,722.00) (59,792.00) - CIAC (215,000.00) (430,761.53) - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 6 of 13 Page 262 of 273 Work Order 9830698301 Total 0000190416 Total 9831451701 Total 9823853101 Total 0010003344 Total 3000098978 Total 0000185373 Total COD353DCMM Total 0010003632 Total 9830156801 Total COD394JCMM Total 9830697801 Total COC45QEWCK Total 9825853901 Total 0010002765 Total 0010002826 Total 9830698201 Total 0010004090 Total 9830333201 Total 0000182425 Total 0000194297 Total 9831395201 Total 0010002425 Total 0010002957 Total 0000187446 Total M000027978 Total 3000080899 Total 0010004318 Total 0010002486 Total 9832989201 Total 0010001440 Total 9828437501 Total 9827355901 Total CO713QPOAS Total COC43QECMP Total 0000191701 Total 0010002131 Total M000029090 Total 3000053216 Total 0010002819 Total 0010004032 Total M000036328 Total 0000188587 Total COC99XBCMM Total 9829782101 Total 0010002861 Total 0010002451 Total 0000192477 Total COC46QECNR Total 0010002751 Total 0010004051 Total 9832612601 Total 0010002931 Total 9831806901 Total 0010003394 Total 0010003179 Total 9825223602 Total M000037149 Total 0000181194 Total 0010003398 Total 9827760001 Total HACSU02080 Total 0010002877 Total 9821991101 Total COF38B2Y13 Total COB88X4CMM Total Work Order Description RG4 DEAERATOR CTRL VALVES, REP NDOT: I -15 DESIGN/BUILD SOUTH RG4 ISOPHASE HV BUSHING, REPLA RG3 SCRUBBER PIPING, MODIFY BI Corp Fin Rptng - NVE South BRN 1205 OH REBUILD SUMM VILL 16 EJ&K PH II RADIO SYSTEM SUPPORT 2011 Ntwrk Design & Firewall Implem RG3 PULVERIZER 3A&3B BALL CHAR T&D Analog Transport Equipment RG1-4 MUTI MEDIA FILTER-RW TO ON Line New Site Willard Creek RG3 4160 VOLT FEED FROM AUX TR Telephone Mac&Unforeseen-2011 Restack Office Areas-Pearson RG4 DEWATERING SUMP, REPLACE EMS Telemetering - Alta RG B-POND AERATION, INSTALL BUFFALO RANCH - ADDENDUM #1 COMMERCE SUB REPLACE - DIST D6 RG4 CSA TANK FLOOR REPLACE & C Rate Case Automate (PH3-RATES) NAV COM- Main Steam Rplcmt Lin THE MERCER LLC COLUMBIA CABLE REPLACEMENT LONE MOUNTAIN DC M & D Center Laughlin Service Ctr Sewer LZ NEW AIR COMPRESSOR Comm Battery & Chrgr Repl 2008 HA5 & 6 TURBINE EXHAUST NOX AN WH - ALSTOM TURBINE STOP VALVE Construct 3 new OA Sites ON Line New Site Comet Peak FLAMINGO DIVERSION CHANNEL NAV COM - PRECIP DECK REPL U2 CABLE INJECTION - HONOLULU 2 CC - TROPICANA WASH - 4" CONDU Sub Ethernet Equipment Upgrd Pearson Piping Conversion CABLE INJECTION - ADOBE CLIFFS CLV-PEDESTRIAN BRIDGES CC LANDFILL ENERGY - COMM RG1-4 DIESEL FIRE PUMP, REPLAC Firewall Install - South Comm Battery &Chrger Repl 2010 CNLV - N. 5TH ST. IMPROV. PH#1 ON Line New Site Conner's Pass Furnishing /Remodel<150,000 AIX Server Evergreen-NVE(S) WHCC FUEL GAS HEATER INLET VAL SOA Infrastructure Growth - LV RG2 SUPERHEATER ATTEMPERATOR S Big Bend Recloser Replacement Comm Battery&Charger Repl 2012 SH2 LTMP (LONG TERM MAINTENAN REPLACE WIRE DOWN 4810 KNOTTY FORT APACHE / CACTUS Westside 69kV Switch Replacemn RG1 EXPANSION JOINT, REPLACE HACCP - CSA AGREEMENT SAN Storage Mgmt Software HAC MET TOWER, INSTALL Black Start Telecm DC Pwr 2013 MOBILE RADIO SYS MIGRATION PH1 Posting Date 276,390.25 0.00 296,833.10 135,100.69 202,863.99 308,683.37 328,666.00 321,477.98 328,113.04 294,505.55 315,116.36 341,153.88 261,441.33 254,214.66 350,774.11 355,625.70 395,747.16 01/01/2011 - 05/31/2011 275,857.43 279,844.39 280,025.55 285,414.23 285,903.90 286,498.42 286,649.97 288,777.99 289,851.28 290,969.23 291,373.85 291,464.52 (5,000.00) 296,203.34 297,895.03 298,412.77 298,903.19 299,923.25 167,506.22 99,868.51 302,936.86 303,431.23 305,079.13 307,934.29 228.93 309,127.29 309,158.31 313,670.99 315,692.26 (12,000.00) 317,445.22 (3,200.00) 318,464.85 325,091.83 326,072.43 34,821.55 330,838.31 331,419.16 332,148.39 17,216.17 333,887.50 335,677.81 336,133.23 336,244.65 (4,547.94) 338,702.00 339,057.98 339,064.72 339,782.26 340,519.85 345,583.26 345,654.63 347,551.22 347,620.46 347,986.08 87,351.47 94,972.55 350,350.28 351,421.00 354,173.65 357,444.05 (38,242.30) 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 275,857.43 276,390.25 279,844.39 280,025.55 285,414.23 285,903.90 286,498.42 286,649.97 288,777.99 289,851.28 290,969.23 291,373.85 291,464.52 291,833.10 296,203.34 297,895.03 298,412.77 298,903.19 299,923.25 302,606.91 302,732.50 302,936.86 303,431.23 305,079.13 307,934.29 308,912.30 309,127.29 309,158.31 313,670.99 315,692.26 316,666.00 317,445.22 318,277.98 318,464.85 325,091.83 326,072.43 328,113.04 329,327.10 330,838.31 331,419.16 332,148.39 332,332.53 333,887.50 335,677.81 336,133.23 336,244.65 336,605.94 338,702.00 339,057.98 339,064.72 339,782.26 340,519.85 345,583.26 345,654.63 347,551.22 347,620.46 347,986.08 348,792.80 349,187.21 350,350.28 350,774.11 351,421.00 354,173.65 355,625.70 357,444.05 357,504.86 01/01/2011 - 12/31/2013 276.69 1,168.55 7,568.67 406.09 3,097.00 2,634.90 941.30 3,124.94 2,578.71 12,299.00 3,220.90 3,350.85 12,435.80 11,013.96 2,823.28 3,155.17 6,618.06 1,773.83 1,693.08 1,638.06 461.18 4,908.32 18,803.93 1,718.71 1,889.75 429.85 4,593.34 5,499.68 443.32 3,014.81 8,131.87 12,935.17 12,836.48 942.04 16,506.35 1,387.61 43.52 89.82 4,259.28 932.41 976.06 8,076.69 1,928.98 4,465.62 14,671.53 8,130.55 499.48 1,401.10 2,331.13 315.19 6,042.87 6,483.92 0.01 15.87 3,170.44 1,091.84 560.46 166.80 4,964.67 2,108.69 AFUDC Debt 331.90 1,396.26 9,315.58 497.72 3,715.06 3,262.56 1,142.59 3,822.57 3,093.33 14,941.17 3,874.11 4,226.79 15,775.97 13,060.43 3,453.58 3,859.55 8,588.47 2,280.04 2,133.28 1,979.59 561.09 5,887.86 22,976.41 2,102.42 2,372.38 515.60 6,001.85 6,731.65 592.18 3,775.22 9,722.47 16,399.80 16,353.98 1,133.89 19,727.69 1,714.06 53.25 116.52 5,413.91 1,140.57 1,176.22 9,803.88 2,287.35 5,756.99 18,597.64 9,866.28 642.02 1,800.94 2,851.54 400.86 7,256.35 7,777.90 (0.02) 19.47 3,879.81 1,324.29 685.55 207.42 6,495.33 2,478.33 AFUDC Equity (264,146.00) (302.00) - CIAC (22,438.95) (34,007.79) (287,000.00) - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 7 of 13 Page 263 of 273 Work Order COB91Z8CMM Total 0000190672 Total 0010003393 Total M000025951 Total 0000194197 Total 0010002377 Total 9819617101 Total 0010003300 Total LR511QELR2 Total COG14MBS13 Total 0000192507 Total HACNS22000 Total 0000192398 Total 0000192635 Total COC47QECPR Total TL832LXTRN Total 3000158008 Total M000035942 Total 0010002752 Total M000048447 Total 9830695001 Total TL658LPLVH Total 3000021289 Total HACSU02094 Total 0000192372 Total TSB86DVSUB Total COC44QEMTW Total 9825223601 Total 9833002601 Total M000029720 Total 9827657301 Total COD48EECMM Total 3000061409 Total 0010002763 Total LP110PPLPA Total 3000132058 Total 0010003299 Total 9830694601 Total 9831038401 Total DS305YTBBF Total 0010002645 Total M000036329 Total M000035755 Total DS708ARSUB Total 9830706101 Total 0000179430 Total TS932CJCML Total 0000182498 Total 0010002825 Total 0010001981 Total 3000024131 Total LR380QPTAX Total 9831663501 Total 0000186699 Total 9828063401 Total 9829805701 Total 9826845301 Total 0010001820 Total 9831663901 Total 0010002633 Total 9825250301 Total COA19MBSPV Total DS709ZKSUB Total 9827760601 Total 0000193126 Total 0010002249 Total Work Order Description APEX MW BY-PASS OC3 RING CC - 215 BELTWAY DECATUR TO N. COAL FUEL MGT SYSTEM-NPC CABLE INJECTION - KELL STRATTON 35 Upgrade Elevators 3/4 2010 RG4 BOILER SUPERHEATER SECTION SAN Storg Mgmt Sftwr-NVES 2012 ENTI MICROWAVE & MOBILE RADIO Sub Security Install 2013 CLV-ENVIRON ENHANCE. S.D. HACCP - SITE PREPARATION LEWIS SUB SWITCHGEAR UPGRADE HARMON & POLARIS FEEDER ADJUST ON-LINE: New Site Copper MT KIDWELL 1202 NESC CLEARANCE SWITCH COMMUNICATIONS NAP 8 FE RETRENCH @ 4383 DEL SANTOS DR Construction Projects< 150,000 RETRENCH/PRIMM NV LZ CT COMPRESSOR BLEED AIR MOD LAS VEGAS CITY HALL OH RELOC MI 1203 OH MAINTENANCE HACCP - BFP X-Y Probe 1-215 AIRPORT CONNECTOR INTERC VEA Interconnection at NW 230 ON Line New Site Mt Wilson SH1 LTMP (LONG TERM MAINTENAN RG4 REBAG 4 BAG HOUSE COMPARTM AR 1211 PHASE B OH REBUILD R02 PROPORTIONING DAMPER BIFUR Ethernet Remote Access for Rel NLV 1203 OH REBUILD ACD Exp & Backup Phase 2-2011 STRATEGIC LANDS ACQUISITIONS FLAMINGO DIVERSION S. BUFFALO Intel Srvr Evrgrn-NVES 2012 RG1-4 EMERGENCY EVACUATION SYS HA GIATRONICS SYSTEM INSTALLAT Beltway Bank #3 and 1213/1214 NPC-Prism Contract Settlement CABLE INJECTION - FALCON RIDGE AR 1206 OH REBUILD ARTESIAN INSTALL PERM CAP BANK HA LUBE OIL STORAGE BUILDING-M SILVER FLAG ALPHA RANGE 63A Michael Way Cap Sys Addn -2011 RIDGEVIEW INDUSTRIAL PARK Elevator Upgrade 5 & 6 BI Resource Procurement Garces 1202 Switch Installatio ON LINE CWIP PROPERTY TAX RG PLANT HAND HELD RADIO SYSTE DOVER PLACE RG4 CONDENSER ISOLATION VALVES SILVERHAWK CTA/CTB INSULATION R01 1B BALL MILL END CASTING & Sub Trans RestorationSch-Haven ADMIN BUILDG FIRE PROTECT INST Online Customer Transfers NVES RG1-3, MESA POWER, INSTALL Sub Security Install 2011 KEEHN SUBSTATION OFFSITES RG2 EXPANSION JOINT, REPLACE CC - TROPICANA WASH SD Sub Oil Containment Program Posting Date 276,091.73 328,602.03 311,384.07 383,355.26 231,927.41 375,541.23 255,012.53 388,514.36 395,993.85 421,185.59 407,621.33 433,016.33 408,275.49 434,144.72 422,813.18 405,667.46 210,505.72 01/01/2011 - 05/31/2011 82,373.99 362,347.91 365,783.22 38,377.29 55,724.21 (16,240.00) 368,793.08 368,969.37 369,033.22 370,491.23 139,684.81 (2,443.71) 375,752.83 121,002.04 377,663.66 380,990.30 382,349.02 393,395.36 395,837.82 397,886.27 399,355.31 399,536.37 400,416.88 400,826.74 401,511.88 401,534.04 401,963.94 403,449.75 404,643.90 16,393.03 10,574.15 410,393.91 411,039.28 413,014.17 413,469.83 413,949.39 414,169.47 414,852.87 417,979.75 (2,131.57) 424,682.03 18,180.46 430,411.47 430,473.88 431,273.08 433,178.12 804.83 434,400.10 26,710.50 435,795.67 435,834.06 436,316.14 437,230.13 437,237.81 441,520.38 443,281.58 9,602.77 444,387.48 446,080.81 449,022.43 27,695.74 451,678.40 451,771.89 47,516.05 453,953.60 244,628.87 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 358,465.72 362,347.91 365,783.22 366,979.32 367,108.28 367,115.26 368,793.08 368,969.37 369,033.22 370,491.23 371,612.22 373,097.52 375,752.83 376,014.57 377,663.66 380,990.30 382,349.02 393,395.36 395,837.82 397,886.27 399,355.31 399,536.37 400,416.88 400,826.74 401,511.88 401,534.04 401,963.94 403,449.75 404,643.90 404,907.39 406,568.00 410,393.91 411,039.28 413,014.17 413,469.83 413,949.39 414,169.47 414,852.87 417,979.75 419,054.02 424,682.03 425,801.79 430,411.47 430,473.88 431,273.08 433,178.12 433,821.16 434,400.10 434,985.99 435,795.67 435,834.06 436,316.14 437,230.13 437,237.81 441,520.38 443,281.58 443,747.49 444,387.48 446,080.81 449,022.43 450,508.92 451,678.40 451,771.89 453,183.51 453,953.60 455,134.59 01/01/2011 - 12/31/2013 285.10 11,786.16 7,874.49 7,011.39 13,656.62 2,631.55 38,918.54 3,226.02 1,664.27 91,964.55 1,616.61 15,892.92 3,520.66 1,257.08 2,338.29 5,754.82 516.18 4,268.75 1,577.90 1,063.93 4,020.73 2,273.98 16,151.56 5,028.62 1,165.00 382.00 2,027.89 1,951.36 35,274.62 248.49 2,166.88 1,894.74 5,662.97 33,044.76 9,724.06 1,453.27 2,712.11 4,307.74 9,785.01 3,742.58 4,616.06 1,543.25 31,578.15 310.16 12,675.99 2,742.62 21,207.48 4,425.70 1,766.16 1,876.09 6,704.27 5,665.30 2,872.13 6,573.24 665.29 9,449.17 873.78 4,684.62 268.94 AFUDC Debt 348.76 14,357.03 9,660.97 8,240.39 17,298.95 3,156.72 47,731.42 4,223.35 1,968.40 113,281.85 1,963.93 20,180.68 4,225.95 1,541.07 2,808.92 7,039.58 693.28 5,369.43 1,911.76 1,276.26 4,838.02 2,728.02 20,578.09 6,534.00 1,425.13 467.28 2,439.74 2,386.97 42,532.66 298.08 2,599.31 2,272.86 7,173.55 26,714.28 11,867.20 1,768.55 3,317.57 5,331.36 11,813.13 4,554.03 5,808.74 1,887.78 37,980.94 379.39 16,242.59 3,430.56 26,077.34 5,351.29 2,118.64 2,275.07 8,183.52 7,356.94 3,505.60 7,898.63 813.78 11,335.88 1,063.97 5,656.08 316.07 AFUDC Equity (85,220.00) (184,332.00) (8,605.00) - CIAC (503.00) 378,826.17 (1,079.00) (1,236,494.00) - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 8 of 13 Page 264 of 273 Work Order 9830584601 Total 0010003275 Total 0000189490 Total TL848NKTRN Total 9825587101 Total 9827153101 Total 9832172301 Total 0010004264 Total 9827657101 Total 9827152901 Total 0000080012 Total 0010003081 Total 0010003325 Total HACNS20000 Total 9833326501 Total M000045687 Total 9830706001 Total 9827153001 Total 9830412501 Total 0010002927 Total 9825035501 Total 9827394301 Total 9823945601 Total 9829370601 Total DS547Y7CYN Total TS551Q9PCG Total 9829370701 Total TL837DVTRN Total 0010002729 Total 9827853001 Total TS730MUNVE Total 3000218664 Total M000031900 Total 9830697901 Total 0010002881 Total 0010002635 Total 9828873101 Total 0010003298 Total 0010003382 Total 9830310201 Total M000029032 Total 0010003324 Total 0010002799 Total 0010002513 Total 3000367724 Total M000029028 Total LINELOCATE Total 3000065020 Total 0010003401 Total TSB03CBSUB Total 3000057175 Total HACSU02091 Total TL588TRGHW Total 9826400001 Total 9829560301 Total 3000114400 Total 0010003652 Total HACAD03000 Total 9826418701 Total CPUNS19000 Total 0000185397 Total 0010003543 Total 9830694501 Total 0010003297 Total 0010002504 Total 9824164601 Total Work Order Description RC14 WATER LAB RENOVATION SOA EntApps-NVES 2012 SWITCH NAP 7 FEEDER 5 Project NEON Hwy 95 Crossing RC13 RESCUE BUILDING, RENOVATE R03 CEMS INSTALL WHCC GENERATOR 89 DISCONNECT, EWAM ENHANCEMENTS - 2013 R01 PROPORTIONING DAMPER BIFUR R01 CEMS, REPLACEMENT BWO MULTIFAMILY UG SERVICES EWAM Application Enhancements Move EWAM to Beltway HACCP - INFORMATION TECHNOLOGY LZ LUBE OIL STORAGE BUILDING, 2013 NEW LAP TOPS HA ENGINEER AND INSTALL PLATFO R02 CEMS INSTALL RG4 MILL RIBBON CONVEYOR, REPL AIX Server Evergreen - S 2011 HACCP STG fire protection per HIGGINS ACCESS STAIRS/PLATFORM 040600 SA-14 DPE System LNZ PB1 ST MAJOR OUTAGE SILVER FLAG 138/12KV SUB SINATRA 230/138 KV SUB (ARDEN) SH CTB MAJOR OUTAGE VEA Interconnection at NW Comm Battery & Chrg Repl- 2011 LZ AUX TRANSFORMER BLASTWALLS NVE LAUGHLIN IMPROV COST 14% CABLE INJECTION - LA MADRE WAY MA 1215 PHASE A OH REBUILD RG4 ELEVATOR, REPLACE AIX Deduplication/Tape Library QAS Integration Banner 2 NVE-S SUNRISE PHYSICAL SECURITY SYST AIX Srvr Evrgrn-NVES 2012 Purchase Spare 500kV Breaker RG1-3 TRIPPER DECK WASH DOWN S CABLE INJECTION - WALNUT CANYO Electric Vehicle Charging St NW Sub Ligtning Mast NAV COM-GNRTR STEP UP TRANS CABLE INJECTION - LOS PRADOS CABLE INJECTION - GLEN OAK Line Locates Capitalization Lewis 404/Shadow 401 Feeder Ti Crystal S-Repl Obsolete PLC Co CAPACITOR SYSTEM ADDNS TRANS CA 1215 OH REBUILD HACCP Security System Upgrade COH (WEST) GALLERIA Half St RG1 HEATER 4/5, RETUBE RGS BIRD DETERRENT SYSTEM FOR CABLE INJECTION - SLIVERCREST Pearson Carpet Replacement HACCP - LEGAL RG13 E&I SHOP, REFURBISH Clark, Gas System Upgrades CC - PARADISE ROAD IMPR 3A PowerPlan - NVE(S) 2012 RG4 COOLING TOWER FIRE SYSTEM, AIX Disk Evrgrn-NVES 2012 Spare 12/16/20kV MVATransforme HACCP - PERMANENT PLANT EQUIPM Posting Date 319,638.93 395,091.19 81,046.17 319,047.15 480,019.64 457,267.84 (116,010.86) 541,825.94 527,486.74 444,221.10 344,668.16 604,171.07 613,258.44 449,341.69 532,654.70 533,404.48 284,091.83 626,345.35 387,872.37 01/01/2011 - 05/31/2011 455,216.91 456,553.38 137,211.00 464,317.23 465,731.18 466,654.02 472,674.09 473,151.73 78,114.56 474,304.02 394,569.72 478,619.18 479,342.06 161,441.53 486,552.70 487,201.32 489,833.84 493,849.01 494,370.78 500,379.58 23,902.52 47,411.90 507,066.93 508,650.51 508,887.03 629,479.09 517,518.24 517,947.05 520,627.09 (16,698.36) 537,366.14 93,218.10 538,218.77 540,208.01 543,314.18 201,799.25 547,379.84 548,898.80 554,246.08 (48,581.81) 556,207.33 561,279.15 (48,764.13) 564,965.00 565,456.39 118,617.00 573,979.32 577,699.17 579,925.11 585,917.09 586,761.69 587,305.24 58,003.80 593,072.37 594,663.30 596,660.50 68,162.93 608,984.95 612,022.65 332,648.05 620,847.13 622,500.89 625,748.99 240,424.16 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 455,216.91 456,553.38 456,849.93 464,317.23 465,731.18 466,654.02 472,674.09 473,151.73 473,205.75 474,304.02 475,615.89 478,619.18 479,342.06 480,488.68 486,552.70 487,201.32 489,833.84 493,849.01 494,370.78 500,379.58 503,922.16 504,679.74 507,066.93 508,650.51 508,887.03 513,468.23 517,518.24 517,947.05 520,627.09 525,127.58 527,486.74 537,366.14 537,439.20 538,218.77 540,208.01 543,314.18 546,467.41 547,379.84 548,898.80 554,246.08 555,589.26 556,207.33 561,279.15 564,494.31 564,965.00 565,456.39 567,958.69 573,979.32 577,699.17 579,925.11 585,917.09 586,761.69 587,305.24 590,658.50 593,072.37 594,663.30 596,660.50 601,567.41 608,984.95 612,022.65 616,739.88 620,847.13 622,500.89 625,748.99 626,345.35 628,296.53 01/01/2011 - 12/31/2013 4,945.09 5,889.41 548.22 9,506.39 2,654.35 3,608.00 6,511.03 1,155.11 1,381.81 17,572.41 21,188.12 3,738.15 1,414.02 37.86 5,614.60 1,291.86 517.15 1,943.28 5,623.28 3,014.20 23,002.64 44.32 58,857.95 1,980.02 7,562.08 4,835.49 5,237.21 834.70 0.01 5,511.78 1,603.62 9,895.93 128.51 499.07 2,446.49 9,386.64 18,657.99 6,636.37 1,955.99 4,259.84 (24,037.63) 3,787.06 8,322.97 5,053.50 627.50 11,750.16 2,163.67 5,990.21 8,133.06 20,724.46 35,785.41 3,152.25 9.96 0.00 3,954.49 2,036.69 4,794.01 1,157.67 4,149.68 AFUDC Debt 5,931.99 7,064.72 671.96 11,544.05 3,234.15 4,631.36 8,513.47 1,412.32 1,688.09 21,383.61 26,864.44 4,512.33 1,877.06 48.66 7,066.74 1,578.10 620.37 2,377.12 6,882.75 3,646.47 28,338.35 53.16 73,934.29 0.01 2,375.17 9,075.13 5,914.97 6,411.30 1,021.04 (0.02) 6,933.46 1,961.62 12,050.09 157.20 598.68 2,934.73 11,772.77 24,083.63 8,059.28 2,298.86 5,617.89 (30,056.38) 4,719.33 10,469.80 6,084.71 762.99 14,162.19 2,641.25 7,185.64 9,756.16 26,704.10 43,673.43 3,854.08 12.69 0.01 4,743.67 2,443.15 5,750.73 1,413.75 4,997.38 AFUDC Equity 513,468.22 - CIAC (1,118,272.25) (1,240.00) 586,559.11 - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 9 of 13 Page 265 of 273 Work Order Work Order Description 0000193348 Total DURANGO RD IMPROV. CONFLICT #4 3000061662 Total WA 1208 OH REBUILD 9827658101 Total R02 SELECT WATERWALL & HOPPER 9814947401 Total RG 1-3 4A POND CLOSURE 0010001233 Total EWAM - Systems Implementation 3000010526 Total CNLV - LV WASH CHANNEL / TRAIL TL429QPNDC Total ONLine Non-reimb Develop Costs LR638QEENV Total E NV Microwave & Mob Radio ENV 9834151201 Total RG4 COOLING TOWER FILL, REPLAC 9831395301 Total RG4 CIRC WATER PUMP REFURBISHM 0010003239 Total Garetcom Swtch Replc-2012 NVES 9828428401 Total RG1-4 ELECTRIC FIRE PUMP, REPL 9832404201 Total LZ - REBUILD (2) MAIN STEAM NO 0000080015 Total BWO INSTALL TEMP POWER 0010002025 Total Demnd Rspnse Bus Intelligence 9832888501 Total LZ WATER TREATMENT AREA CONTAI 0010002126 Total NAV COM - PLANT PIPING REPL TSA76PCSUB Total Pabco 69kV Interconnection 9827657701 Total R01 SELECT WATERWALL & HOPPER M000035760 Total BURNT HILLS CABLE REP PHASE A 9830443701 Total RG3 COAL SILO & TRIPPER DECK S COD61EECM2 Total Ethernet Remote Access 2012 0000194243 Total REID GARDNER MESA POND FEEDER 0010001591 Total Craig Sub Inst Auto XFMR Resto 0000192338 Total CLV-LV WASH MIDDLE BRANCH DECA COD59X4EDG Total MOBILE RADIO SYSTEM MIGRATION 9827852901 Total LZ ADMIN BUILDING INSTALL 0000193899 Total SW1201/04 DISTRIBUTION FEEDERS COC36QEPHG Total ON Line New Sight Pahranagat HACNS13000 Total HACCP - TELECOMMUNICATIONS 0010003245 Total eServices - NVES 2012 3000074004 Total CABLE INJECTION - MANZANITA 0000193944 Total CLV F STREET REOPENING 9832375501 Total RG CLOSE POND F & RETIRE 9830047601 Total HA HARVEY WELL SECURITY SYSTEM 0010002989 Total Lowest Guaranteed Rate-S 2011 9830717801 Total RG1-4 COAL CHUTES, REPLACE TL429QPGBT Total GBT 25% cost billed to NVE LF138P9LF1 Total NPD147-16-212(1) 9831451801 Total RG4 GENERATOR DESIGN BETTERMEN 3000189799 Total CABLE INJECTION - REDBUTTE 9830585001 Total LZ PHYSICAL SECURITY SYSTEM IN 9830717501 Total RG4 REBAG 8 BAG HOUSE COMPARTM 3000000285 Total NDOT: I -15 DESIGN/BUILD SOUTH M000036341 Total CABLE INJECTION - SISTER CITY 9826400301 Total RG2 BALL MILL ISOLATION DAMPER 9826571001 Total LZ BLOWDOWN SYSTEM REDESIGN 0000189883 Total CNLV WATER RECLAMATION NELLIS 3000182100 Total CABLE INJECTION - ROBINCREST 3000112984 Total CABLE INJECTION - MOSS RIDGE 9830022601 Total RG4 BALL MILL ISOLATION DAMPER 9830731501 Total LZ MAINTENANCE SHOP MODIFICATI 0010002119 Total NAV COM - MAIN PIPING REPL U3 9830412601 Total RG4 BOILER PARTITION WALL, REP 9829741001 Total CLARK POND NETTING INSTALLATIO LR380QPEEC Total ONLINE TRANS COST FROM EEC 9826400201 Total RG1 BALL MILL ISOLATION DAMPER 0000192245 Total CC CAREY AVE STORM DRAIN EEC_TRAN_CREDIT Total SPPC 20% COST ALLOCATION 9828437301 Total LENZIE GE HMI LIFECYCLE REPLAC COD58X4AGG Total MOBILE RADIO SYSTEM AGGRIGATOR 0010002280 Total Online Customer Moves TSD34MXSUB Total Gypsum PV Co 106 0000080009 Total BWO OVERHEAD SERVICES 0000193171 Total NDOT I-15 S. DESIGN BUILD-RUSS 0000182992 Total VILLAGE @ QUEENSRIDGE PHASE 1 Posting Date 628,557.82 580,812.06 646,258.57 95,502.49 677,523.47 691,827.31 555,783.95 756,638.47 723,142.56 737,602.22 676,340.11 (260,075.30) 728,262.57 801,630.37 983,949.45 875,113.31 737,640.66 903,789.21 144,054.28 844,673.37 01/01/2011 - 05/31/2011 (0.00) 628,862.36 48,326.28 641,572.75 (273.26) 646,209.06 648,010.77 648,882.22 656,491.20 657,397.96 666,772.99 667,853.52 668,667.98 579,022.16 6,897.76 688,415.85 699,388.96 146,878.86 706,090.21 714,610.33 716,502.71 (38,846.02) (0.00) 726,637.79 731,700.46 736,934.89 738,509.64 64,397.60 744,518.41 756,977.09 763,660.92 768,381.35 769,826.87 771,007.30 777,228.42 777,615.93 1,049,018.15 789,123.02 799,886.13 805,673.93 812,971.58 816,286.03 821,479.79 95,162.04 30,632.81 (146,304.62) 853,069.70 856,680.21 859,858.57 867,439.22 879,266.11 883,790.69 884,406.81 148,704.81 895,500.11 896,748.84 903,826.22 906,737.05 3,717.74 911,564.84 774,873.61 920,012.80 89,978.65 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 628,557.82 628,862.36 629,138.34 641,572.75 645,985.31 646,209.06 648,010.77 648,882.22 656,491.20 657,397.96 666,772.99 667,853.52 668,667.98 674,524.65 684,421.23 688,415.85 691,827.31 699,388.96 702,662.81 706,090.21 714,610.33 716,502.71 717,792.45 723,142.56 726,637.79 731,700.46 736,934.89 737,602.22 738,509.64 740,737.71 744,518.41 756,977.09 763,660.92 768,381.35 769,826.87 771,007.30 777,228.42 777,615.93 788,942.85 789,123.02 799,886.13 805,673.93 812,971.58 816,286.03 821,479.79 823,424.61 832,263.18 837,644.83 853,069.70 856,680.21 859,858.57 867,439.22 875,113.31 879,266.11 883,790.69 884,406.81 886,345.47 895,500.11 896,748.84 903,826.22 906,737.05 907,506.95 911,564.84 918,927.89 920,012.80 934,652.02 01/01/2011 - 12/31/2013 221.15 15,437.40 2,087.96 8,814.81 46,451.69 29,037.98 701.27 2,094.91 2,244.47 37,044.17 5,761.06 34,280.20 10,307.75 2,188.49 4,324.27 1,598.34 8,065.87 653.33 31,712.26 849.11 8,376.30 14,418.47 30,184.59 24,518.29 9,186.49 8,407.63 9,486.56 925.39 11,234.13 28,399.07 11,046.00 30,285.77 274.39 10,774.67 3,477.91 13,982.99 3,331.97 7,802.55 8,633.93 15,225.68 14,394.45 1,804.31 51,767.46 2,514.88 515.28 118,721.91 2,851.57 4,127.26 2,619.05 4,364.16 12,054.72 8,395.29 1,735.43 2,798.91 AFUDC Debt 271.31 19,185.05 2,554.09 10,729.05 57,671.28 36,690.08 941.87 2,512.98 2,692.40 44,262.47 7,570.61 41,019.11 12,966.15 2,677.73 5,286.01 1,917.32 9,675.54 790.57 37,934.22 1,006.70 10,047.92 17,384.44 38,186.71 29,395.89 11,104.16 10,085.51 11,974.14 1,189.47 14,177.38 35,126.57 13,971.90 38,595.86 329.15 13,651.66 4,171.99 16,786.76 4,060.92 9,493.09 10,758.71 18,264.21 17,267.11 2,164.38 61,951.85 3,016.75 618.12 144,649.34 3,473.28 4,993.46 3,143.36 5,338.45 14,169.44 10,787.85 2,097.02 3,382.74 AFUDC Equity 785,369.79 (246,219.00) (10,187.00) (337,107.00) CIAC 739,404.00 (1,179,502.54) 1,500.00 - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 10 of 13 Page 266 of 273 Work Order 9825633801 Total ASDSYSPRT1 Total COD66EECM3 Total 9830251601 Total TL821EQTRN Total TS960P6PV2 Total 0000183446 Total 0010004061 Total M000027269 Total 0010001982 Total NVSR717274 Total 9827214801 Total 9827214901 Total 0000175451 Total 0010002925 Total 9832888101 Total 0010001864 Total 9830491401 Total 9827995401 Total 9828995701 Total 9826528301 Total 9830698101 Total 0010003296 Total M000028983 Total 9827995001 Total 3000068890 Total 3000055635 Total 0000194057 Total 9826617401 Total 3000189663 Total 0010001673 Total 0010003639 Total 3000213916 Total 9832063101 Total DS726XSRPX Total 9825041401 Total TL728KDTRN Total 0001003576 Total 0010002328 Total 0010002926 Total 9832787801 Total 9826418601 Total M000031342 Total LR922NUNAV Total 3000367851 Total 9826180401 Total 9826495301 Total 3000115100 Total 9827704201 Total 9828241201 Total M000036330 Total CO713QPSWA Total 9826180801 Total MOHSWYDIMP Total 0000190895 Total 0010002217 Total 0010003068 Total 9828240901 Total 3000114159 Total 3000356464 Total 9827704101 Total 0000165393 Total 3000057094 Total 3000055627 Total 0010001735 Total 9829370801 Total Work Order Description RG1-3, MESA POND AREA FENCE, I ASD System Portal South Ethernet Remote Access 2013 RG4 BOILER DIVISION PANEL TUBE EQUESTRIAN-LINDQUIST 69KV LINE Silver State PV Solar GEN 230 SUNSET RD. IMPROVEMENTS Network Infrastructure -NVE(S) CABLE INJECTION - MADIGAN COUR RAS ReStructure Phase II Navajo Shunt Reactor Replace LZ GT1 LTSA CAPITAL PORTION 20 LZ GT2 LTSA CAPITAL PORTION 20 DECATUR ROAD IMPROVEMENTS Netwrk Infrstrcture South-2011 SH CT FIRE SUPPRESSION IMPROVE NAV COM - NE 1 POND REFURBISHM HRSG HPSH3 TUBE REPLACEMENT RG2 COAL SILO STRUCTURAL, UPGR LNZ PB2 STEAM TURBINE MAJOR OU RG1-3, SCRUBBER COLLECTION SYS RG4 TURBINE BLDG FIRE PROTECTI Network Infrstrctr-NVES 2012 CABLE INJECTION - ECHO RIDGE RG1 COAL SILO STRUCTURAL, UPGR LAKE MEAD CABLE REP PH-A CENTER CABLE REP PHASE A CLV - VALLEY VIEW/CORRIDOR IMP LZ ARC VALVES REPLACE CABLE INJECTION - WOLF CREEK Lewis Switchgear Replacement Trench Bushing Replace 2012 CABLE INJECTION - EMERALD ISLE LZ CT GENERATORS FIRE PROTECTI COMMERCE XFMRS REPAIRS R04 SECONDARY AIR HEATER BASKE NLV AIRPORT TRAN/DIST (FRA) BWO Unbillable Claims-Capital OUTAGE MANAGEMENT SCHEDUL SYS AIX Disk Evergreen-S 2011 SHS 2012 CTA COMBUSTION INSPEC RG14 RAIL CAR UNLOADER CONTROL STEWART CABLE REPLACEMENT A NAVAJO-CRYSTAL RENEWAL CABLE INJECTION - BIG TIMBER RG2 SCRUBBER LINING, REPLACE RG1-3, PONDS M5 & M7 AERATION CABLE INJECTION - MOONRISE WAY R02 TWIP SYSTEM, INSTALL HIGGINS CT2 ROW 2 BLADE REPLAC CABLE INJECTION - MAGIC MOMENT ENTI ROBINSON TO HA 500 KV FIB RG1 SCRUBBER LINING, REPLACE Mohave Switchyard Improvements CNLV-TROPICAL PKWY STORM DRAIN Batch Performance Project NVE-S Resource Opt Models HIGGINS CT1 ROW 2 BLADE REPLAC CABLE INJECTION - TETON PINES CABLE INJECTION - GOLDEN EAGLE R01 TWIP SYSTEM, INSTALL BWO COMMERCIAL SERVICES CENTER CABLE REP PHASE B LAKE MEAD CABLE REP PH-B NAV COM - RTROFT LNB/SOFA UN1 SHS ST MAJOR OUTAGE Posting Date 916,348.40 604,099.73 980,315.68 980,315.68 1,006,107.10 1,002,573.36 1,011,506.08 1,169,419.33 1,249,979.16 1,131,372.39 1,157,837.04 1,219,058.50 95,166.81 1,250,010.10 1,147,151.74 1,345,721.31 1,396,628.81 1,920,018.15 1,404,691.53 1,429,798.43 1,402,385.42 1,279,854.47 1,520,375.39 1,529,290.32 593,914.88 1,538,005.40 1,602,797.26 326,229.78 1,597,622.57 - 01/01/2011 - 05/31/2011 20,952.83 939,967.51 953,609.77 958,351.97 961,161.73 967,106.34 363,167.45 971,203.92 971,309.74 971,879.18 976,412.06 1,050,753.77 1,064,018.05 1,066,947.01 1,091,452.82 105,537.95 1,111,951.87 101,516.90 1,119,039.58 1,137,927.87 1,150,554.97 (8,826.66) 1,166,505.04 1,191,925.38 1,215,353.34 (15,519.06) 1,246,377.86 126,553.79 1,280,857.26 1,293,148.26 1,298,619.61 154,737.71 1,325,300.93 108,532.52 1,234,829.65 125,620.49 1,377,085.36 1,388,645.08 267,303.35 71,699.02 1,424,426.35 1,426,359.31 33,759.41 (489,201.06) 1,441,889.33 76,417.22 55,746.43 91,808.15 1,514,918.37 243,928.57 4,791.70 940,576.62 1,580,521.59 44,013.75 1,617,350.83 1,626,169.52 32,376.63 1,311,355.68 1,638,833.18 1,643,155.80 45,858.98 1,664,753.59 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 937,301.23 939,967.51 953,609.77 958,351.97 961,161.73 967,106.34 967,267.18 971,203.92 971,309.74 971,879.18 976,412.06 980,315.68 980,315.68 1,006,107.10 1,050,753.77 1,064,018.05 1,066,947.01 1,091,452.82 1,108,111.31 1,111,951.87 1,113,022.98 1,119,039.58 1,137,927.87 1,150,554.97 1,160,592.67 1,166,505.04 1,191,925.38 1,215,353.34 1,234,460.10 1,246,377.86 1,257,926.18 1,280,857.26 1,293,148.26 1,298,619.61 1,312,574.75 1,325,300.93 1,327,591.02 1,329,996.46 1,375,630.59 1,377,085.36 1,388,645.08 1,414,455.09 1,417,420.33 1,424,426.35 1,426,359.31 1,430,388.22 1,430,817.09 1,441,889.33 1,481,108.75 1,485,544.86 1,494,193.57 1,514,918.37 1,523,783.04 1,525,167.09 1,529,290.32 1,534,491.50 1,580,521.59 1,582,019.15 1,617,350.83 1,626,169.52 1,635,173.89 1,637,585.46 1,638,833.18 1,643,155.80 1,643,481.55 1,664,753.59 01/01/2011 - 12/31/2013 7,706.44 18,216.42 11,237.81 3,308.42 8,177.33 3,168.34 (187.82) 12,363.71 39,395.17 42,687.09 9,279.96 6,168.18 55,432.34 15,981.08 1,622.65 1,554.91 5,259.06 4,470.14 11,651.49 1,590.30 18,572.50 4,933.56 13,342.51 15,879.29 1,863.53 29,586.87 7,267.38 481.38 11,392.64 627.09 11,109.91 42,719.02 231.17 16,139.72 9,248.19 7,161.34 5,801.49 19,506.93 12,812.39 3,682.47 7,087.25 101,047.89 3,489.56 2,918.67 44,523.08 53,408.73 16,287.57 2,578.71 34,129.09 13,634.94 2,972.38 19,189.27 25,425.96 17,120.89 8,367.82 AFUDC Debt 9,057.29 22,151.53 14,704.29 3,970.01 10,219.49 3,875.67 (251.04) 16,163.40 47,148.94 51,468.97 11,351.66 8,011.67 67,130.80 19,699.17 1,985.71 1,902.04 6,392.78 5,362.23 13,976.76 1,945.94 23,030.79 5,920.39 16,575.53 19,390.05 2,235.42 35,742.30 8,874.67 577.44 14,387.89 767.09 13,327.06 50,737.30 282.78 19,500.93 11,210.11 9,457.88 7,054.57 23,758.60 15,369.31 4,497.67 8,675.56 125,588.83 4,242.84 3,570.25 52,611.69 64,716.79 19,656.47 3,160.51 40,941.81 17,846.60 3,629.05 24,075.12 32,168.53 20,660.39 10,037.77 AFUDC Equity (277,555.00) - CIAC (816,707.62) 1,456,992.42 (270.00) - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 11 of 13 Page 267 of 273 Work Order M000036338 Total MCCG7CBRPL Total 9830456801 Total 0010001736 Total 9832944701 Total M000031733 Total 0000080014 Total 0010003588 Total 9829088001 Total 9829607601 Total TS592Q9PCH Total 3000198777 Total 3000313095 Total CO714QPSWB Total 3000188911 Total CO921VZESC Total 3000072703 Total M000035764 Total 9831058801 Total 9827215101 Total LR380QPLR2 Total 9830077801 Total 9827855201 Total 0000080020 Total 0010002786 Total 9825250201 Total DS366LJL15 Total 9827215001 Total 9830342701 Total 9827111001 Total TS596QRHAS Total 9823774001 Total 0010002409 Total 9828940101 Total 0000080002 Total SOUTHMETER Total 0001001532 Total 9825411101 Total 9826094601 Total TSC44QSBNK Total 9832615401 Total 9825472601 Total LR332Q9LR2 Total 9828940001 Total 9827214601 Total 9827214701 Total TGB1PHASE2 Total HACNS12000 Total 9832690901 Total HACAD04000 Total 9816967401 Total ARO Total 9830077701 Total 9831508601 Total 9823852701 Total 9823851801 Total 9831508501 Total DS726XSSUB Total TSD29XJSUB Total ASDSYSRNI1 Total 9821855101 Total HACNS11000 Total HACSU01010 Total ASDSY1MDM1 Total 9830256801 Total 0000080013 Total Work Order Description CABLE INJECTION - BLACKBERRY McCullough Circ Brkr Replace RG4 TURBINE VALVE UPGRADE NAV COM - RTROFT LNB/SOFA UN2 RIED GARDNER PHYSICAL SERCURIT STEWART CABLE REPLACEMENT B BWO U/G SERVCS RES <5 UNIT MAXIMO UPGRADE WH1-2 HRSG AMMONIA INJECTION 2011 LTMP CTA CAPITAL PORTION SINATRA 230KV SUBSTATION CABANA CABLE REPLACEMENT CABLE INJECTION - QUAIL RIDGE ON LINE EN-BRTS MICRO RADIO SY WYOMING CABLE REPLACEMENT EMS MOVE TO SOUTHWEST SERVICE CABLE INJECTION - ASPEN KNOLL BURNT HILLS CABLE REP PHASE B 2012 LTMP CTB CAPITAL PORTION LZ GT4 LTSA CAPITAL PORTION 20 ENTI - ROBINSON SUMMIT TO HARR RG4 FGD ISOLATION DAMPER, INST RG4 COAL DUST CONTROL FOR OSHA BWO Smart Meters PeopleSoft Upgrade 9.1 NVE-S RG1-3, MESA CONVEY PIPING, INS IRON MTN OFFSITE IMP & LANDSCP LZ GT3 LTSA CAPITAL PORTION 20 RG4 EXCITER - VOLTAGE REGULATO RC14 DUST SUPPRESSION AT TRANS ENTI HA 500KV TERMINAL ADDITIO RG1-3, EFPS, INSTALL GarcesSub-Purchase new 125MVA HIGGINS CI OUTAGE (CT2) BWO METERS ASD Meter Install - South CAPITALIZATION OF PROPERTY TAX HACCP-OPERATIONS PERSONNEL RC13 TRIPPER AND RECLAIM WET C Sinatra Bank #5 Install FLEET, GENERATION M&D CENTER N WH 1 & 2 GENERATORS, REWIND SINATRA 230KV TRANS/TELECOMM HIGGINS CI OUTAGE (CT1) HIGGINS CT1 LTMA CAPITAL PORTI HIGGINS CT2 LTMA CAPITAL PORTI ASD TGB PHASE 2 Install South HACCP - OWNERS ENGINEERING SS SUNRISE UTILITY RELOCATION HACCP - PROPERTY TAX RG1-3, MESA BLM LAND GRANT Asset Retirement Costs RG4 FGD REBUILD - ABSORBER CT2 MAJOR OUTAGE 2013 RG2 BOILER TUBES, REPLACE PM RG1 BOILER TUBES, REPLACE PM CT1 - MAJOR OUTAGE 2013 COMMERCE SUB REPAIR & REPLACE REPLACE FAILED AT-3 AT CRYSTAL ASD AMI/RNI System South RG1-3, M7 MESA POND, INSTALL HACCP - PROJECT MANAGEMENT HACCP - FUEL PURCHASE ASD METER DATA MANAGEMNT-SOUTH LZ PB2 GE PSA CAPITAL PORTION BWO UG SERVCS RES >5 UNIT Posting Date 70,741.41 1,772,774.05 1,453,323.32 169,317.26 (600,391.70) 2,295,571.57 2,796,131.68 2,103,746.94 2,465,767.79 2,704,688.44 2,796,131.70 2,203,952.94 3,149,320.04 3,482,984.55 2,363,095.94 946,255.20 4,301,444.35 3,272,272.09 (10.54) 3,861,667.47 1,768,767.61 1,768,767.61 5,014,992.41 5,556,045.53 4,942,012.35 6,081,161.20 5,573,259.36 7,133,426.24 8,320,788.79 8,455,522.84 8,036,208.65 8,728,665.90 1,371,539.72 01/01/2011 - 05/31/2011 1,627,814.80 1,707,620.96 1,720,554.79 1,791,483.61 410,545.60 1,734,881.56 1,924,637.08 1,927,076.96 1,943,433.07 2,548,375.00 2,119,941.53 2,122,820.74 2,161,468.10 2,210,956.38 1,189.07 2,303,792.93 2,313,363.64 2,332,215.37 (400,000.00) 2,400,069.97 2,425,735.78 506,927.39 2,614,211.65 2,649,407.34 228,743.93 771.98 2,849,540.03 651,882.42 3,167,393.41 154,781.14 113.22 3,506,243.65 1,281,251.65 3,656,803.87 3,001,731.26 (263,035.79) 865,714.14 4,170,167.50 4,226,242.34 4,309,484.40 459,353.15 4,532,225.35 2,862,683.88 2,862,683.88 4,736,696.01 142,051.47 5,491,222.28 (45,202.77) 604,478.83 (303,934.78) 5,989,519.75 5,997,466.86 448,882.80 (1,063,381.98) 6,108,868.72 (1,801,180.31) 7,312,712.99 7,530,281.13 (377,928.21) 234,907.63 (31,816.42) 8,722,817.92 8,918,828.70 7,737,062.25 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 1,698,556.21 1,707,620.96 1,720,554.79 1,772,774.05 1,791,483.61 1,863,868.92 1,904,198.82 1,924,637.08 1,927,076.96 1,943,433.07 1,947,983.30 2,119,941.53 2,122,820.74 2,161,468.10 2,210,956.38 2,296,760.64 2,303,792.93 2,313,363.64 2,332,215.37 2,396,131.68 2,400,069.97 2,425,735.78 2,610,674.33 2,614,211.65 2,649,407.34 2,694,511.72 2,705,460.42 2,796,131.70 2,849,540.03 2,855,835.36 3,167,393.41 3,304,101.18 3,483,097.77 3,506,243.65 3,644,347.59 3,656,803.87 3,947,986.46 4,038,408.56 4,137,986.23 4,170,167.50 4,226,242.34 4,309,473.86 4,321,020.62 4,532,225.35 4,631,451.49 4,631,451.49 4,736,696.01 5,157,043.88 5,491,222.28 5,510,842.76 5,546,491.18 5,777,226.42 5,989,519.75 5,997,466.86 6,022,142.16 6,070,044.26 6,108,868.72 6,519,608.48 7,312,712.99 7,530,281.13 8,077,594.63 8,271,116.28 8,696,849.48 8,722,817.92 8,918,828.70 9,108,601.97 01/01/2011 - 12/31/2013 21,980.55 1,456.86 77,816.59 10,724.84 9,997.43 27,212.16 1,261.36 2,886.13 (0.00) 9,773.31 19,216.05 191,535.46 9,433.65 107,240.73 65,968.80 21,309.74 230,963.98 9,779.43 7,461.07 28,957.31 18,582.32 130,099.76 75,027.65 24,643.01 132,357.06 70,666.47 26,849.96 37,220.78 71,774.30 32,321.42 22,559.88 75,617.85 51,983.70 97,870.60 265,900.34 127,606.42 95,378.24 2,145.17 10,913.34 62,028.62 75,922.70 94,355.40 71,867.95 52,251.72 208,287.76 264,880.54 182,223.82 291,688.23 14,985.05 344,114.38 - AFUDC Debt 26,718.23 1,747.59 92,599.40 13,906.55 12,156.28 33,240.77 1,523.36 3,530.45 (0.03) 12,887.67 25,177.79 235,957.71 12,460.91 128,171.68 79,358.08 26,331.36 283,166.74 11,731.13 9,128.31 35,421.90 22,404.22 152,326.58 91,785.74 30,081.02 167,265.89 84,656.30 32,825.09 44,916.68 86,213.17 39,248.01 27,596.37 98,197.81 62,817.68 115,865.19 318,804.22 153,048.72 114,069.85 2,625.22 13,094.58 79,729.85 90,877.22 113,476.48 92,377.06 63,857.57 258,429.37 319,615.13 218,380.32 350,593.92 18,330.41 415,716.27 - AFUDC Equity (384,394.00) 1,934,518.21 (326,544.31) (1,912,940.00) CIAC 3,987.00 2,552,198.21 (677,250.59) (4,187,025.71) (3,195,590.01) (2,500,000.00) (4,020,442.09) (5,768,592.31) - Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 12 of 13 Page 268 of 273 Work Order LR637QPENV Total 9831664601 Total 0010002346 Total 9823847001 Total 9825650201 Total TL973QPWIV Total HACMC02030 Total TS594QOSWE Total HACAD01000 Total HACMC01040 Total 0010004483 Total ASDMETER01 Total TL429QPSWC Total HACMC01010 Total GRCHACCIRB Total HACMC02000 Total Grand Total Work Order Description Robinson Summit to HA - Env LZ PB1 GE PSA CAPITAL PORTION Data Center at Beltway 2010 RG1-4, LANDFILL EXPAND, INSTAL RG1-3, M5 MESA POND, INSTALL Wind Indc Vibration RS/HA 500 HACCP - BOP Water Treatment ENTI ROBINSON 500/345 KV SWTCH HACCP - Sales Tax & Duties HACCP - HRSG RG4 Acquisition Costs ASD Meter Install - South ENTI - ROBINSON SUMMIT to HA HACCP - TURBINES GRC HA CWIP in Rate Base HACCP - ECP Posting Date 8,532,400.78 9,856,197.09 16,698,424.45 23,928,639.83 40,855,764.46 17,211,851.55 76,331,345.46 115,726,056.25 399,420,760.63 902,840,194.13 01/01/2011 - 05/31/2011 9,346,878.01 9,398,585.70 1,176,278.26 10,267,574.36 1,317,240.40 14,848,164.54 (98,308.45) 23,025,951.77 (619,272.00) (490,095.39) 42,665,035.41 42,758,402.57 74,966,258.01 (908,695.39) (4,439,239.12) 579,468,087.22 06/01/2011 - 12/31/2013 NEVADA POWER COMPANY MDR 106 ATTACHMENT Electric Additions Greater Than $100K 01/01/2011 to 12/31/2013 9,346,878.01 9,398,585.70 9,708,679.04 10,267,574.36 11,173,437.49 14,848,164.54 16,600,116.00 23,025,951.77 23,309,367.83 40,365,669.07 42,665,035.41 59,970,254.12 74,966,258.01 75,422,650.07 115,726,056.25 394,981,521.51 1,482,308,281.35 01/01/2011 - 12/31/2013 409,739.71 14,354.94 100,337.58 315,578.65 147,637.28 66,024.19 44,218.43 1,242,705.05 841,159.50 2,440,249.34 4,763,937.68 6,382,041.42 21,134,837.60 45,192,988.33 AFUDC Debt 514,020.39 17,219.70 122,014.70 384,404.23 176,094.13 86,460.38 54,090.02 1,555,821.74 1,003,277.39 2,923,620.45 5,943,600.31 7,769,178.76 25,282,459.78 54,716,689.19 AFUDC Equity (4,719,658.20) CIAC (64,889,611.36) (86,234,036.31) Non-Taxable CIAC Docket No. 14-05XXX; MDR 106 Attach 01 Page 13 of 13 Nevada Power Company d/b/a NV Energy RESPONSE TO INFORMATION REQUEST DOCKET NO.: 14-05XXX REQUEST NO.: MDR 107 REQUESTER: REQUEST DATE: 2/4/2014 RESPONDER: Ortwein, Patricia REQUEST: Provide a list, preferably in a computer file or files, of all line extension agreements entered into since the end of the immediately preceding test period, or three years, whichever is less, through the end of the test period. Provide dates and dollar amounts received under the extension, and the related work order identification number. For companies with Nevada jurisdictional gross operating revenue that is: (a) less than $100 million dollars, the response may be limited to extension agreements equal to or exceeding $50,000 dollars; or (b) greater than $100 million dollars, the response may be limited to extension agreements equal to or exceeding $100,000 dollars. RESPONSE CONFIDENTIAL (yes or no): No ATTACHMENTS CONFIDENTIAL (yes or no): No TOTAL NUMBER OF ATTACHMENTS: One RESPONSE: See attached for entries for the period January1, 2011 through December 31, 2013. Page 269 of 273 Description 189615 THE SHOPPES OF SUMMERLIN CENTER 3000019599 CLV Infrastructure Replacements 187672 RITCHIE BROTHERS AUTIONEERS 179430 SILVER FLAG ALPHA RANGE 63A 3000148423 Linq Feeder Wire Pull 193126 CC - TROPICANA WASH SD 193792 CLV-STEWART AVENUE 185874 LVCVA - BACK UP FEEDER 3000099729 FAA ATCT/Tracon Bldg, McCarran Airport 2 Pri Feeder 3000205970 HORIZON GIBSON NORTH 194463 NDOT - NEON/ US-95 Crossing 3000042085 LINQ RDE Alley & Switch Yard Relocation 3000292523 Summerlin Village 23B Addendum #1 3000063966 LAS VEGAS DATA CENTER 3000318300 V23B FAR HILLS/FOX HILL ADDENDUM #2 FEEDER 3000041908 LINQ North Parking Area 187721 MPSUMM CENTER- ADDEN 1, PH #1 194444 NLV NATIONAL GUARD READINESS C 3000389207 Summerlin VIllage 16A Addendum #1 189491 SWITCH NAP 7 FEEDER 6 185373 Summ Vill 16 EJ&K PH II 188357 UNEV PIPELINE (KAPEX) 3000193132 SRDH SIENA CAMPUS TOWER ADDITION 3000163085 WHITNEY MESA PH1 194362 UNLV CENTRAL SUB - CONVERSION 3000234615 BOULDER RANCH PHASE1 3000115722 MAVERIK STORE #451 193084 Canyon Falls Estates 3000327590 FED EX EXECUTIVE AIRPORT DR - RELOCATIONS 193919 SUNSET PARK PHASE 2 RELOCATION 3000240947 INSPIRADA POD 2-3 PH2 (184597) 3000274864 BUFFALO RANCH PH 5 3000061362 MCDONALD HIGHLANDS PA20 Ph 1 188477 LAUGHLIN HERITAGE TRAIL 3000152648 Town Center 44/50 3000164745 HIGHLANDS RANCH 6 PH 1,B,C,D,E 3000240054 BUFFALO RANCH IV 3000205795 HORIZON GIBSON SOUTH 3000209727 CCSD - SEWER MAIN INSTALLATION 3000256989 ELDORADO RCL 25 PHASE I 194151 Ann/Grand Canyon Sub 3000318386 V23B ALTA DR ADDENDUM #3 FEEDER 3000000427 Village of Avellino, Unit 3 3000249629 Silver leaf phase 2 3000007112 Addendum 1- Summ Village 23A Unit I MP 3000288884 WOODBRIDGE 2 NORTH EAST 3000249597 SUTTER POINT/HILLS PH 1B 3000220457 180920 - Cliffs Edge Pod 205 3000240087 WHITNEY MESA PH 2 3000256981 ELDORADO RCL 25 PH II 3000282208 THE ORCHARDS UNIT 3 3000032184 DUNHILL @RHODES RANCH PARCEL 17 PH 2 & 3 3000012921 V23A Parcel L-Andalusia 3000241633 ESPERANZA #1 3000007540 Mountains Edge Pod 219 Phase 1 3000002910 Talavera-Mountain's Edge Pods 224 & 225 unit 1 3000020861 EVAPS Law Office Project ID 7/19/2013 8/19/2013 1/24/2011 10/14/2011 8/15/2012 10/16/2012 2/13/2013 11/22/2011 5/13/2013 2/1/2013 5/6/2013 4/27/2012 12/9/2013 9/25/2012 12/30/2013 6/18/2012 7/23/2013 12/19/2012 12/30/2013 3/23/2012 3/17/2011 6/7/2011 11/6/2013 1/18/2013 4/6/2011 4/24/2013 3/22/2012 3/22/2011 12/9/2013 3/1/2011 2/26/2013 8/30/2013 2/2/2012 6/7/2011 8/3/2012 1/7/2013 4/17/2013 4/4/2013 10/16/2012 6/25/2013 5/3/2012 12/9/2013 3/11/2011 3/14/2013 10/7/2011 8/30/2013 7/15/2013 12/17/2012 4/11/2013 7/12/2013 8/6/2013 3/9/2012 9/30/2011 5/14/2013 8/4/2011 6/2/2011 1/8/2013 Executed 7/19/2018 8/19/2018 1/24/2016 10/14/2016 8/15/2017 10/16/2017 2/13/2018 11/22/2016 5/13/2018 2/1/2018 5/6/2018 4/27/2017 6/25/2023 9/25/2017 6/25/2023 6/18/2017 6/4/2023 12/19/2017 11/4/2023 3/23/2017 3/17/2016 6/7/2016 11/6/2020 1/18/2018 4/6/2016 4/24/2018 3/22/2017 3/22/2016 12/9/2018 3/1/2016 2/26/2018 8/30/2018 2/2/2017 6/7/2016 8/3/2017 1/7/2018 4/17/2018 4/4/2018 10/16/2017 6/25/2018 5/3/2017 6/25/2023 3/11/2016 3/14/2018 8/27/2013 8/30/2018 7/15/2018 12/17/2017 4/11/2018 7/12/2018 8/6/2018 3/9/2017 9/30/2016 5/14/2018 8/4/2016 6/2/2016 1/8/2018 $6,439,281 $2,734,243 $1,325,491 $739,096 $1,803,155 $1,545,165 $1,040,643 $995,802 $270,021 $834,990 $856,194 $765,925 $649,671 $1,360,859 $549,524 $554,892 $529,931 $516,806 $414,612 $419,682 $611,062 $482,892 $472,673 $388,286 $424,536 $397,412 $373,070 $492,701 $317,947 $367,358 $304,255 $385,700 $392,506 $375,021 $327,233 $322,343 $309,441 $310,741 $264,609 $292,358 $262,655 $247,859 $371,062 $303,304 $296,713 $307,561 $282,053 $242,846 $276,781 $274,519 $258,559 $280,784 $317,114 $258,365 $342,713 $329,995 $255,563 Expiration Total Cost Est $6,354,027 $2,734,243 $1,325,491 $2,094,537 $1,803,155 $1,285,833 $1,040,643 $995,802 $270,021 $834,990 $856,194 $765,925 $649,671 $1,360,859 $549,524 $554,892 $529,931 $489,875 $414,612 $419,682 $611,062 $482,892 $472,673 $388,286 $424,536 $397,412 $373,070 $430,914 $317,947 $367,358 $304,255 $385,700 $392,506 $375,021 $327,233 $322,343 $309,441 $310,741 $264,609 $292,358 $194,073 $247,859 $371,062 $303,304 $296,713 $307,561 $282,053 $242,846 $276,781 $274,519 $258,559 $280,784 $317,114 $258,365 $342,713 $329,995 $255,563 Customer Cost Est. $0 $2,227,652 $52,209 $7,478 $0 $1,285,833 $1,040,643 $995,802 $0 $2,571 $828,250 $765,925 $0 $10,596 $0 $489,434 $0 $0 $0 $419,682 $0 $0 $11,499 $0 $424,536 $0 $266,855 $827 $317,947 $367,358 $648 $0 $2,463 $0 $3,300 $0 $8,105 $0 $264,609 $0 $690 $0 $0 $0 $0 $0 $0 $0 $3,124 $0 $0 $0 $0 $0 $1,939 $0 $220,426 NonRefundable CIAC $85,254 $0 $0 $1,854,426 $0 $259,332 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $26,931 $0 $0 $0 $0 $0 $0 $0 $0 $0 $61,787 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $112,282 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 NVE Responsibility $115,463 $77,703 $0 $0 $0 $0 $0 $0 $3,387 $36,439 $0 $14,570 $29,641 $34,372 $38,270 $32,978 $11,565 $13,585 $26,664 $0 $0 $0 $11,869 $18,861 $0 $20,130 $6,942 $0 $33,208 $0 $12,941 $15,066 $0 $0 $19,367 $9,793 $23,225 $11,413 $12,171 $12,424 $0 $17,641 $0 $15,964 $0 $10,048 $11,831 $11,224 $12,736 $12,099 $13,799 $13,639 $0 $9,071 $0 $0 $3,083 Trench Tax $839,845 $430,120 $610,415 $0 $282,568 $0 $0 $0 $138,742 $121,535 $0 $61,209 $108,495 $100,714 $91,771 $80,841 $88,498 $76,903 $69,240 $70,507 $0 $0 $62,454 $57,676 $0 $55,862 $55,754 $0 $49,210 $0 $50,359 $49,479 $61,801 $0 $44,444 $45,485 $42,421 $44,529 $42,480 $43,718 $78,407 $41,392 $0 $40,538 $0 $40,942 $40,524 $40,555 $39,808 $39,560 $39,252 $38,758 $0 $37,653 $0 $0 $35,253 Tax Advance $2,536,373 $0 $0 $0 $0 $0 $0 $10,176 $2,100 $2,800 $0 $1,500 $3,600 $3,000 $3,500 $1,500 $0 $2,100 $3,600 $0 $9,464 $0 $3,000 $1,700 $3,600 $2,000 $1,500 $1,700 $1,500 $0 $2,800 $2,000 $1,700 $0 $2,000 $2,000 $2,000 $1,700 $0 $1,700 $3,000 $3,600 $1,700 $2,000 $3,000 $1,700 $1,700 $0 $1,700 $1,700 $1,700 $2,000 $1,700 $1,700 $2,800 $2,000 $2,100 DIA Advance $3,447,949 $3,083,388 $2,346,608 $2,050,522 $1,964,523 $1,285,833 $1,039,487 $978,176 $970,820 $885,502 $854,985 $811,066 $784,207 $736,079 $676,065 $635,889 $629,994 $548,887 $506,916 $490,189 $461,307 $466,317 $445,298 $420,200 $417,751 $408,493 $408,877 $399,678 $398,865 $367,358 $362,049 $358,825 $356,384 $348,495 $329,659 $325,642 $321,932 $320,884 $319,259 $316,224 $310,884 $303,292 $301,886 $297,243 $293,713 $294,451 $293,313 $294,625 $289,859 $286,846 $286,390 $281,101 $276,019 $270,492 $267,865 $268,608 $268,269 Contract Advance $5,984,322 $3,083,388 $2,346,608 $2,050,522 $1,964,523 $1,285,833 $1,039,487 $988,352 $972,920 $888,302 $854,985 $812,566 $787,807 $739,079 $679,565 $637,389 $629,994 $550,987 $510,516 $490,189 $470,771 $466,317 $448,298 $421,900 $421,351 $410,493 $410,377 $401,378 $400,365 $367,358 $364,849 $360,825 $358,084 $348,495 $331,659 $327,642 $323,932 $322,584 $319,259 $317,924 $313,884 $306,892 $303,586 $299,243 $296,713 $296,151 $295,013 $294,625 $291,559 $288,546 $288,090 $283,101 $277,719 $272,192 $270,665 $270,608 $270,369 Total Cash Advance 14-05XXX; MDR 107 Attach 01 Page 270 of 273 SUTTER RANCH- ESTATES PH I 9/8/2011 CCDC NORTH TOWER RENOVATION-NO UPGRADE 1/29/2013 BUFFALO RANCH PHASE 3 8/22/2012 MGM Festival Lots 6/26/2013 SUMMERLIN WATER PARK 10/3/2012 BOULDER RANCH PHASE 2 9/17/2013 INDIAN SPRINGS WASTE WATER UPG 2/25/2011 MADISON GROVE 3 6/25/2013 REPUBLIC SERVICES OH TO UG 7/2/2013 181451- PRESIDIO HEIGHTS 10/25/2013 WINDMILL APARTMENTS 7/13/2012 HIGHLANDS RANCH UNIT 6 PH 2 8/30/2013 SUMMERLIN VILLAGE 23A UNIT NO 2 PARCEL 1 5/23/2013 SILVER LEAF PH 3 3/20/2013 TOSCANA 12/20/2012 DR HORTON INC EDNA & VAN ALLEN 7/15/2013 HORIZON TERRACE 11/22/2013 Buffalo Ranch Phase II 11/17/2011 PA20 PHASE 3 12/26/2013 CATALINA COVE 11/6/2013 WOODBRIDGE I 8/21/2013 DR HORTON INC ANN & HUALAPAI 4/24/2013 SWITCH NAP 7 FEEDER 8 4/17/2013 SUNRISE HIGHLANDS, UNIT 60-4 11/16/2012 COH-LAKE MEAD TRAIL & WETLANDS TRAIL PH II LIGHTING 12/11/2012 DESERT BLUE-Phase I Tower 10/11/2013 RHODES RANCH MP 3 ADDENDUM 2 4/11/2013 RANCHO BELLA 11/12/2013 Maximo Upgrade Sanity Test 2/17/2013 BILL'S GAMBLIN' HALL 10/3/2013 WARM SPRINGS AND JONES UNIT 1 10/3/2013 RHODES RANCH PARCEL19 UNIT 5-1 3/20/2013 SNRHA PERRY PLAZA 2/17/2011 ELDORADO RCL NO 24 PH 1 7/26/2011 LANTERN GARDENS 2 4/2/2013 EAGLE RANCH 1&2 10/10/2013 ELDORADO RCL 23 PHASE 2 9/11/2013 RUSSELL PEARLITE 11/7/2013 VA SATELLITE OUTPATIENT CLINIC 5/19/2011 SUNSET AND FORT APACHE 11/6/2013 THE ORCHARDS UNIT 2 8/6/2013 LANTERN GARDENS UNIT 1 1/16/2013 LEGAL AID CENTER OF SOUTHERN NV 5/2/2012 CLV - CLIFF SHADOWS SWITCH RELOCATION 11/29/2012 DR HORTON GILES & STARR 1/11/2013 PROVIDENCE POD 307, PH 2 12/4/2012 CC RTE 215 WOODBURRY (SRV) 4/27/2012 White Horse West 3/8/2011 I.C.E BUILDING US IMMIGRATION & CUSTOMS ENFORCEMENT 6/29/2012 CLV - MLK BLVD - ALTA TO DISCOVERY 12/26/2013 THE ORCHARDS PH 1 4/17/2013 SANTALUZ AT SUMMERLIN VILLAGE 23A 9/5/2013 DUNHILL HOMES @ RHODES RANCH SOUTH PH1 9/6/2013 EVERETT CONDOMINIUMS 2/3/2011 GRIFFIN PARK 10/8/2013 MESA CANYON TROPICAL & JONES 4/25/2013 FORT APACHE AND FORD UNIT 1 & 2 PH 1 11/4/2013 3000057708 3000140547 3000120608 3000281606 3000057714 3000234657 191995 3000231155 3000102734 3000375030 3000114050 3000348972 3000178012 3000249752 3000212371 3000249769 3000360756 3000035195 3000410484 3000249550 191089 3000249849 189489 194044 3000082327 3000249266 191893 3000377088 3000288696 3000221371 3000260142 191302 194068 180785 3000231176 3000293887 3000333837 3000233301 193838 3000396085 3000282205 3000173283 3000100398 3000052606 3000170473 3000149097 181957 3000002479 3000050891 193613 3000249764 3000272766 3000221385 194274 3000350412 183143 3000325089 Executed Description Project ID 9/8/2016 1/29/2018 8/22/2017 6/26/2018 10/3/2017 9/17/2018 2/25/2016 6/25/2018 7/2/2018 10/25/2018 7/13/2017 8/30/2018 5/23/2018 3/20/2018 12/20/2017 7/15/2018 11/22/2018 11/17/2016 12/26/2018 11/6/2018 8/21/2018 4/24/2018 4/17/2018 11/16/2017 12/11/2017 10/11/2020 5/6/2014 11/12/2018 2/17/2018 10/3/2018 10/3/2018 3/20/2018 2/17/2016 7/26/2016 4/2/2018 10/10/2018 9/11/2018 11/7/2018 5/19/2016 11/6/2018 8/6/2018 1/16/2018 5/2/2017 11/29/2017 1/11/2018 12/4/2017 4/27/2017 3/8/2016 6/29/2017 12/26/2018 4/17/2018 9/5/2018 9/6/2018 2/3/2016 10/8/2018 4/25/2018 11/4/2018 $332,679 $245,879 $268,982 $247,465 $318,392 $345,953 $177,923 $245,766 $226,611 $241,502 $311,321 $274,071 $238,744 $240,928 $241,589 $234,872 $247,560 $287,931 $227,479 $253,576 $267,554 $144,071 $254,006 $196,641 $186,774 $187,572 $185,235 $219,768 $173,818 $252,296 $240,630 $288,100 $264,926 $167,076 $193,990 $218,780 $175,651 $183,683 $223,404 $220,455 $165,193 $179,419 $189,810 $194,311 $173,364 $180,309 $166,479 $189,328 $173,206 $179,831 $160,444 $190,416 $220,407 $160,217 $209,923 $168,793 $198,803 Expiration Total Cost Est $332,679 $245,879 $268,982 $247,465 $318,392 $345,953 $177,923 $245,766 $226,611 $241,502 $311,321 $274,071 $238,744 $240,928 $241,589 $234,872 $247,560 $287,931 $227,479 $253,576 $247,298 $144,071 $254,006 $196,641 $186,774 $187,572 $185,235 $219,768 $173,818 $252,296 $240,630 $182,377 $264,926 $167,076 $193,990 $218,780 $175,651 $183,683 $223,404 $220,455 $165,193 $179,419 $189,810 $194,311 $173,364 $180,309 $166,479 $189,328 $173,206 $179,831 $160,444 $190,416 $220,407 $155,637 $209,923 $168,793 $198,803 Customer Cost Est. $0 $241,109 $0 $47,237 $2,571 $0 $0 $0 $226,611 $1,318 $0 $0 $0 $0 $633 $0 $25,246 $0 $0 $836 $0 $0 $254,006 $0 $10,420 $0 $10,283 $6,526 $0 $38,914 $2,594 $0 $1,395 $0 $0 $599 $15,864 $28,455 $151,195 $0 $0 $0 $96,152 $194,311 $15,783 $0 $1,917 $7,459 $72,085 $179,831 $0 $0 $0 $0 $0 $1,866 $0 NonRefundable CIAC $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $20,256 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $105,723 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $4,580 $0 $0 $0 NVE Responsibility $0 $1,009 $11,161 $10,157 $17,526 $15,160 $53,121 $9,597 $4,865 $21,308 $9,700 $8,378 $10,696 $10,523 $11,251 $11,499 $13,005 $0 $9,189 $10,294 $9,683 $69,182 $13,108 $4,581 $22,595 $1,562 $4,426 $7,607 $9,014 $4,614 $10,469 $14,883 $0 $0 $7,659 $8,160 $6,661 $5,873 $0 $10,718 $5,482 $7,501 $659 $0 $7,195 $2,244 $9,089 $0 $5,617 $0 $8,246 $8,884 $11,823 $11,211 $8,553 $11,708 $9,719 Trench Tax $0 $38,446 $36,770 $34,380 $35,262 $35,956 $53,944 $35,937 $24,138 $33,295 $35,061 $35,070 $33,881 $33,460 $33,170 $32,645 $30,305 $0 $31,757 $30,731 $30,596 $21,900 $29,922 $31,072 $28,077 $31,325 $29,217 $29,192 $28,831 $27,260 $27,796 $27,518 $0 $0 $26,897 $26,713 $26,684 $23,399 $0 $25,837 $26,212 $25,054 $21,654 $0 $24,338 $25,595 $24,188 $0 $23,195 $0 $24,143 $23,752 $23,177 $41,784 $23,427 $22,941 $23,076 Tax Advance $2,000 $0 $1,700 $1,500 $3,000 $2,800 $0 $1,700 $1,500 $1,700 $3,600 $1,700 $1,700 $1,700 $1,700 $1,700 $1,700 $2,000 $1,700 $1,700 $0 $1,700 $0 $1,700 $0 $3,600 $0 $1,700 $1,500 $3,000 $1,700 $3,000 $1,500 $0 $1,700 $1,700 $1,700 $1,700 $1,500 $1,700 $1,700 $1,700 $29,384 $0 $1,700 $1,700 $0 $1,700 $2,100 $0 $1,700 $1,700 $1,700 $2,100 $1,700 $0 $2,800 DIA Advance $268,355 $269,669 $266,410 $265,054 $263,507 $263,619 $261,633 $259,024 $253,134 $252,273 $249,856 $251,749 $245,756 $242,640 $241,970 $237,921 $237,599 $232,426 $229,405 $223,342 $223,486 $220,517 $222,203 $220,010 $221,638 $216,859 $218,879 $215,552 $208,987 $204,892 $205,605 $204,182 $195,376 $196,190 $193,918 $193,733 $191,901 $190,927 $190,636 $189,570 $186,955 $180,878 $152,323 $181,235 $179,459 $179,400 $178,757 $176,457 $176,052 $177,596 $175,258 $173,162 $172,087 $170,619 $170,563 $172,023 $168,176 Contract Advance $270,355 $269,669 $268,110 $266,554 $266,507 $266,419 $261,633 $260,724 $254,634 $253,973 $253,456 $253,449 $247,456 $244,340 $243,670 $239,621 $239,299 $234,426 $231,105 $225,042 $223,486 $222,217 $222,203 $221,710 $221,638 $220,459 $218,879 $217,252 $210,487 $207,892 $207,305 $207,182 $196,876 $196,190 $195,618 $195,433 $193,601 $192,627 $192,136 $191,270 $188,655 $182,578 $181,707 $181,235 $181,159 $181,100 $178,757 $178,157 $178,152 $177,596 $176,958 $174,862 $173,787 $172,719 $172,263 $172,023 $170,976 Total Cash Advance 14-05XXX; MDR 107 Attach 01 Page 271 of 273 DUNHILL HOMES @ RHODES RANCH PARCEL 20 UNIT 2 PH 5/9/2013 2 CANCUN ESTATES 1/18/2013 PYLE APARTMENTS 7/19/2011 Woodbridge II Mustang Spring East Ph 2 12/6/2012 SUTTER RANCH ESTATES PH 2 8/19/2013 ALLORA II INTERNATIONAL VILLAG 3/1/2011 Tierra Vista Phase 2 @ Mountains Edge 8/23/2012 HORIZON 10 9/10/2012 SWITCH COMMUNICATIONS NAP 8 FEEDER 1 12/4/2012 Dunhill@ Rhodes Ranch Parcel 17 7/12/2011 TUSCANY PARCEL II PH 1 12/13/2012 179411-POD215@MOUNTAINS EDGE UNIT 2 10/24/2013 Adelina Parcel P at Summerlin 9/20/2011 D.R.HORTON INC FORT APACHE AND MAULE 8/6/2013 WIGWAM APARTMENTS 5/23/2012 Winco Foods Henderson 10/13/2011 DURANGO RANCH II PH II 7/13/2012 MIXED INCOME LLC 11/29/2012 SWITCH NAP 8 FEEDER TIE PH1 8/28/2013 QUARTERHORSE 7/18/2013 PN69436 USARC LAS VEGAS 7/24/2012 DOLLAR GENERAL NELLIS & LAKE MEAD 1/4/2013 JASMINE FALLS 2 5/9/2013 ELDORADO RCL 23 PHASE 3 9/13/2013 Helena Estates 1/25/2013 CATALINA PH1 5/20/2013 Rainbow & Mardon Shopping Center 3/7/2012 WILLIAM LYON HOMES INC ANN & GRAND CANYON UNIT 36/28/2013 LLAMA LOT (AKA AMBASSADOR PARKING & EVENTS) 10/17/2013 WOODBRIDGE II MUSTANG SPRING EAST PH 1 4/10/2012 PLANET MAZDA-SAHARA 2/26/2013 TROPICAL DURANGO PHASE II 9/12/2012 DORADO SKIES UNIT 1 9/19/2013 PROVIDENCE POD 307 PHASE 1 8/16/2011 RICHMOND AMERICAN SUMMER HILL 7/24/2013 KB HOME PODS 224 & 225 U-5 @ MOUNTAINS EDGE 10/30/2013 SOMERSET ACADEMY ELKHORN PH I 7/2/2013 Sanmarcello 1 9/28/2011 TIERRA VISTA PH 3B 6/13/2013 TROPHY HILLS RESIDENCE 6/4/2012 Versante Phase 1 6/2/2011 Tierra Vista ph 1 6/15/2011 COH HERITAGE PARK 6/2/2011 VA SATELLITE OUTPATIENT CLINIC 5/11/2011 SKYVUE OBSERVATION WHEEL POLE REMOVAL 2/8/2012 CLV - ANN ROAD CHANNELL W RAINBOW 11/26/2012 LADY LUCK CENTRAL PLANT 12/19/2011 DUNHILL HOMES MELROSE PLACE PH 1 2/22/2013 VANTAGE APARTMENTS 12/11/2013 BRIGHTON & KENSINGTON U-3 6/20/2013 PARK TERRACE 7/15/2013 RHODES RANCH PARCEL 33 10/30/2013 LANTERN GARDENS 3 10/10/2013 CLIFFS EDGE POD 201 & 203 U-5 5/17/2013 CNLV-SIMMONS:CAREY TO CHEYENNE 9/29/2011 SWITCH NAP 7 FEEDER 5 5/10/2011 LORENZI PARK PHASE II PART 2 10/5/2012 3000077295 3000217175 194131 3000164799 3000282268 193490 3000040962 3000158464 3000158008 3000002382 3000184587 3000381181 3000014307 3000321925 3000097731 3000035582 3000142721 3000140449 3000181193 3000214550 3000042922 3000192574 3000251606 3000334090 3000199457 3000241629 3000047845 3000267037 3000292264 3000087403 3000208144 3000015922 3000351394 3000015176 3000325584 3000342511 3000235856 3000007565 3000225530 3000043939 3000007032 3000013346 193067 193849 3000072342 3000014636 194449 3000077356 3000416868 3000249867 3000325082 3000329342 3000327564 3000276093 193912 189490 3000065066 Executed Description Project ID 5/9/2018 1/18/2018 7/19/2016 12/6/2017 8/19/2018 3/1/2016 8/23/2017 9/10/2017 12/4/2017 7/12/2016 12/13/2017 10/24/2018 9/20/2016 8/6/2018 5/23/2017 10/13/2016 7/13/2017 11/29/2017 8/28/2018 7/18/2018 7/24/2017 1/4/2018 5/9/2018 9/13/2018 1/25/2018 5/20/2018 3/7/2017 6/28/2018 10/17/2018 4/10/2017 2/26/2018 9/12/2017 9/19/2018 8/16/2016 7/24/2018 10/30/2018 7/2/2018 9/28/2016 6/13/2018 6/4/2017 6/2/2016 6/15/2016 6/2/2016 5/11/2016 2/8/2017 11/26/2017 12/19/2016 2/22/2018 12/11/2018 6/20/2018 7/15/2018 10/30/2018 10/10/2018 5/17/2018 9/29/2016 5/10/2016 10/5/2017 $145,296 $148,800 $289,751 $136,735 $167,494 $123,595 $163,578 $162,476 $380,339 $203,667 $156,375 $150,980 $187,759 $164,274 $347,644 $235,160 $135,763 $166,623 $129,206 $136,428 $154,281 $135,405 $166,138 $153,408 $127,140 $146,202 $186,197 $133,653 $124,116 $125,129 $148,121 $120,647 $168,228 $164,240 $132,773 $157,600 $116,703 $193,602 $135,463 $125,059 $162,905 $164,209 $148,838 $165,851 $116,107 $126,721 $132,155 $135,959 $179,201 $133,587 $124,674 $158,250 $163,559 $131,188 $128,884 $469,655 $147,939 Expiration Total Cost Est $145,296 $148,800 $289,751 $136,735 $167,494 $116,797 $163,578 $162,476 $380,339 $203,667 $156,375 $150,980 $187,759 $164,274 $347,644 $235,160 $135,763 $166,623 $129,206 $136,428 $154,281 $135,405 $166,138 $153,408 $127,140 $146,202 $186,197 $133,653 $124,116 $125,129 $148,121 $120,647 $168,228 $164,240 $132,773 $157,600 $116,703 $167,054 $135,463 $125,059 $162,905 $164,209 $148,838 $165,851 $116,107 $126,721 $132,155 $135,959 $179,201 $133,587 $124,674 $158,250 $163,559 $131,188 $128,884 $469,655 $147,939 Customer Cost Est. $0 $1,800 $17,637 $0 $0 $0 $0 $8,412 $0 $0 $0 $7,561 $0 $0 $0 $19,306 $0 $88,193 $129,206 $3,703 $0 $84,098 $0 $0 $17,715 $0 $0 $0 $70,548 $0 $883 $120,647 $0 $0 $0 $0 $0 $0 $0 $10,087 $0 $0 $0 $46,803 $116,107 $126,721 $497 $0 $0 $0 $0 $0 $0 $0 $128,884 $0 $5,498 NonRefundable CIAC $0 $0 $0 $0 $0 $6,798 $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 $26,548 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 NVE Responsibility $19,408 $11,454 $0 $5,585 $6,299 $0 $7,877 $7,387 $49,965 $0 $9,262 $6,148 $0 $7,651 $14,756 $0 $6,988 $7,773 $0 $4,377 $13,961 $3,246 $6,937 $5,332 $15,189 $6,318 $0 $8,164 $4,547 $9,040 $5,841 $5,032 $9,233 $0 $5,937 $4,855 $13,388 $0 $5,828 $2,431 $0 $0 $0 $0 $83 $5,670 $0 $9,732 $0 $5,111 $5,330 $8,166 $6,849 $6,741 $0 $0 $7,132 Trench Tax $21,122 $21,996 $0 $22,835 $22,669 $0 $22,542 $21,310 $15,995 $0 $21,401 $21,683 $0 $21,248 $20,191 $0 $20,833 $19,189 $21,577 $20,300 $19,461 $18,525 $20,184 $20,409 $17,060 $20,095 $0 $19,669 $17,910 $19,343 $19,516 $19,630 $19,023 $0 $19,129 $18,876 $17,460 $0 $18,498 $17,881 $0 $0 $0 $0 $16,677 $0 $0 $17,403 $18,725 $17,988 $17,875 $17,403 $17,545 $17,490 $0 $0 $17,253 Tax Advance $1,700 $1,700 $3,600 $1,700 $1,700 $1,700 $1,700 $1,700 $3,000 $2,800 $1,700 $1,700 $1,700 $1,700 $3,600 $2,100 $1,700 $3,000 $1,500 $1,700 $0 $1,500 $1,700 $1,700 $1,700 $1,700 $2,100 $1,700 $1,500 $1,700 $1,500 $1,500 $1,700 $1,700 $1,700 $1,700 $1,500 $2,000 $1,700 $1,000 $1,700 $1,700 $0 $1,500 $1,500 $0 $3,600 $1,700 $3,000 $1,700 $1,700 $1,700 $1,700 $1,700 $0 $0 $0 DIA Advance $165,310 $165,264 $162,372 $163,455 $163,010 $162,982 $162,897 $162,001 $158,736 $157,944 $157,114 $155,968 $155,485 $154,430 $151,529 $151,605 $150,124 $148,185 $149,283 $147,651 $149,264 $147,134 $146,284 $146,249 $145,660 $145,045 $143,716 $143,911 $142,402 $141,817 $141,603 $141,144 $140,464 $138,433 $137,912 $135,061 $133,901 $133,304 $133,395 $133,778 $132,981 $131,933 $133,157 $131,237 $131,103 $132,391 $128,555 $129,644 $127,851 $129,114 $128,541 $128,079 $127,753 $127,260 $128,884 $127,871 $127,694 Contract Advance $167,010 $166,964 $165,972 $165,155 $164,710 $164,682 $164,597 $163,701 $161,736 $160,744 $158,814 $157,668 $157,185 $156,130 $155,129 $153,705 $151,824 $151,185 $150,783 $149,351 $149,264 $148,634 $147,984 $147,949 $147,360 $146,745 $145,816 $145,611 $143,902 $143,517 $143,103 $142,644 $142,164 $140,133 $139,612 $136,761 $135,401 $135,304 $135,095 $134,778 $134,681 $133,633 $133,157 $132,737 $132,603 $132,391 $132,155 $131,344 $130,851 $130,814 $130,241 $129,779 $129,453 $128,960 $128,884 $127,871 $127,694 Total Cash Advance 14-05XXX; MDR 107 Attach 01 Page 272 of 273 GALLAGHER CREST ELECTRICAL RELOCATION 3/29/2012 SYMPHONY PARK PH 2A 1/3/2013 RHAPSODY NORTH 4/25/2013 Torino & Tomsik 12/12/2013 TALAVERA POD 224 & 225 @ MOUNTAINS EDGE UNIT 4 7/5/2013 180575 LORETO BAY AKA LADERA VILLAS 10/22/2012 AMPAC APARTMENTS 6/7/2012 HORIZON 88, UNIT 2 9/27/2013 NPS COTTONWOOD COVE ENTRY STAT 8/22/2011 TACINGA RIDGE 10/23/2013 CORNERSTONE PARK 1/10/2012 TUSCANY PARCEL 11 PHASE 2 7/11/2013 PARDEE HOMES ELDORADO RCL 24 PH 3 10/15/2012 DURANGO RANCH I 1/20/2012 STETSON TRAILS 9/6/2013 Talavera-Mtn's Edge Pod 244& 225 UNIT 3 11/15/2012 DUNHILL HOMES MELROSE PLACE-PHASE2 11/15/2013 BLUE DIAMOND / VALLEY VIEW CENTER 3/27/2013 Eldorado RCL No.24 PH2 2/3/2012 CNLV-LAS VEGAS WASH TRAIL BRID 6/25/2013 CAPELLA UNIT 3 5/30/2013 COLDWATER CREEK @ MOUNTAINS EDGE 9/14/2011 DURANGO TRAIL 9/10/2013 SILVERADO RANCH APT PH 1 AND PH 2 10/4/2013 HORIZON 88 PHASE 1 5/6/2013 FAIRFIELD 7/15/2013 DOLLAR GENERAL MARYLAND & RENO 1/7/2013 DESPERADO ESTATES 9/23/2013 SUMMERLIN VILLAGE 23A UNIT NO 1, PARCEL 0 PHASE II 9/19/2013 MARVELLA PH 2 9/6/2012 CALGARY CROSSING 6/6/2011 MACDONALD HIGHLANDS PA20 PH2 4/24/2013 SONATA IV 8/30/2013 178864-FREMONT STREET LOFTS 2/1/2013 Bonanza Springs Resort Homes 11/22/2013 DESERT FOOTHILLS 2 9/23/2013 ARCO AM/PM AT WARM SPRINGS & FT APACHE 4/19/2012 STORYBOOK @ HACIENDA & BUFFALO 1/19/2012 VERSANTE UNIT 2 2/2/2012 BERMUDA VILLAS II 3/4/2013 LINQ SOUTH PARKING AREA 4/27/2012 LAMAR ADVERTISING HWY 163 & 95 6/4/2012 SUMMERLIN VILLAGE 23A PARCEL J- BARCELONA U2 5/4/2011 BRENNAN RESIDENCES 10/24/2013 SALERNO ESTATES 6/17/2013 DR HORTON INC TROPICAL & 215 U-2 7/19/2013 Civil Support Team WMD 4/24/2012 HARMONY HOMES MEPOD 135 PH II 7/22/2013 DR HORTON FARM & GAREHIME 7/17/2013 STONEWATER 3/9/2011 MATERIALS CRUSHER ADDITION 2/16/2011 HIGHLANDS RANCH 8 PH1 9/23/2013 LINQ CARNIVAL COURT DEMO 4/25/2012 HORIZON RIDGE PROFESSIONAL PARK EAST 10/22/2012 CANYON ESTATES III 10/3/2013 3000080921 3000085111 194640 3000388491 3000279624 3000168008 3000104231 3000330437 192169 3000395647 194404 3000311857 3000159210 3000082896 3000327452 3000154431 3000087319 3000141843 3000109022 194229 3000268856 3000032630 3000237127 3000262029 3000015211 3000273087 3000196436 3000366401 3000271889 3000134368 189542 3000062218 3000328035 3000226907 3000250966 3000251597 3000096767 194486 3000104264 3000133924 3000041749 193643 3000009259 3000213168 3000279531 3000321905 3000005221 3000327243 3000282211 183264 194370 3000288824 3000107598 3000174499 3000399263 Executed Description Project ID 3/29/2017 1/3/2018 4/25/2018 12/12/2018 7/5/2018 10/22/2017 6/7/2017 9/27/2018 8/22/2016 10/23/2018 1/10/2017 7/11/2018 10/15/2017 1/20/2017 9/6/2018 11/15/2017 11/15/2018 3/27/2018 2/3/2017 6/25/2018 5/30/2018 9/14/2016 9/10/2018 10/4/2018 5/6/2018 7/15/2018 1/7/2018 9/23/2018 9/19/2018 9/6/2017 6/6/2016 4/24/2018 8/30/2018 2/1/2018 11/22/2018 9/23/2018 4/19/2017 1/19/2017 2/2/2017 3/4/2018 4/27/2017 6/4/2017 5/4/2016 10/24/2018 6/17/2018 7/19/2018 4/24/2017 7/22/2018 7/17/2018 3/9/2016 2/16/2016 9/23/2018 4/25/2017 10/22/2017 10/3/2018 $175,062 $76,895 $129,825 $101,991 $124,738 $114,889 $158,975 $137,241 $124,524 $148,173 $141,010 $125,514 $118,342 $131,535 $146,360 $124,869 $159,728 $146,204 $320,765 $103,936 $119,302 $146,702 $124,243 $312,024 $403,916 $112,394 $109,060 $119,277 $122,920 $112,057 $120,840 $97,867 $120,890 $67,519 $166,047 $134,699 $106,679 $131,684 $129,734 $123,182 $93,264 $89,972 $124,567 $91,182 $96,454 $95,588 $102,592 $100,595 $92,200 $89,359 $125,688 $119,333 $91,053 $110,550 $114,930 Expiration Total Cost Est $166,662 $76,895 $129,825 $101,991 $124,738 $114,889 $158,975 $137,241 $124,524 $148,173 $141,010 $125,514 $118,342 $131,535 $146,360 $124,869 $159,728 $146,204 $143,520 $103,936 $119,302 $146,702 $124,243 $312,024 $108,792 $112,394 $109,060 $119,277 $122,920 $112,057 $120,840 $97,867 $120,890 $67,519 $166,047 $134,699 $106,679 $131,684 $129,734 $123,182 $93,264 $89,972 $124,567 $91,182 $96,454 $95,588 $102,592 $100,595 $92,200 $89,359 $102,238 $119,333 $91,053 $110,550 $114,283 Customer Cost Est. $6,387 $0 $2,925 $0 $0 $5,276 $363 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $1,011 $0 $103,936 $0 $0 $0 $0 $0 $0 $54,132 $411 $0 $0 $0 $0 $0 $0 $2,414 $0 $60,400 $656 $0 $725 $92,171 $0 $0 $2,684 $266 $0 $589 $0 $0 $0 $1,855 $2,055 $91,053 $0 $0 NonRefundable CIAC $8,400 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $177,245 $0 $0 $0 $0 $0 $295,124 $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 $23,450 $0 $0 $0 $647 NVE Responsibility $3,711 $45,445 $6,064 $4,365 $4,676 $13,749 $14,509 $5,265 $0 $8,206 $0 $7,514 $3,435 $0 $7,685 $5,020 $9,412 $10,081 $0 $0 $7,660 $0 $5,657 $32,011 $5,852 $5,034 $1,916 $5,887 $6,298 $5,082 $0 $3,095 $5,172 $0 $6,674 $5,782 $5,050 $0 $0 $10,166 $4,315 $16,915 $0 $13,435 $3,556 $2,852 $8,345 $4,355 $4,292 $0 $4,449 $4,575 $0 $7,100 $6,486 Trench Tax $17,075 $11,664 $16,872 $17,471 $17,296 $15,992 $15,806 $17,058 $0 $16,372 $0 $16,444 $17,014 $0 $16,069 $16,336 $15,649 $15,454 $0 $15,632 $15,406 $0 $15,632 $11,832 $15,553 $15,628 $14,664 $15,385 $15,317 $15,277 $0 $15,067 $14,699 $17,210 $13,980 $14,447 $14,582 $0 $0 $13,635 $13,276 $12,746 $0 $12,624 $14,296 $14,392 $13,377 $13,952 $13,826 $0 $24,874 $13,445 $14,195 $13,344 $13,411 Tax Advance $4,000 $1,500 $1,700 $1,700 $1,700 $1,700 $3,000 $1,700 $75,381 $1,700 $0 $1,700 $1,700 $1,700 $1,700 $1,700 $1,700 $2,100 $0 $0 $1,700 $1,700 $1,700 $3,600 $1,700 $1,700 $1,500 $1,700 $1,700 $1,700 $3,600 $1,700 $1,700 $1,700 $1,700 $1,700 $1,500 $1,500 $1,700 $2,100 $1,500 $1,500 $1,700 $1,000 $1,700 $1,700 $0 $1,700 $1,700 $0 $2,100 $1,700 $1,500 $1,500 $1,700 DIA Advance $122,962 $125,452 $125,193 $124,752 $123,842 $123,803 $121,762 $122,764 $47,523 $120,911 $122,515 $120,724 $120,627 $118,664 $118,274 $117,477 $117,069 $115,976 $117,650 $116,929 $113,620 $113,252 $113,192 $111,091 $112,839 $112,540 $112,592 $112,109 $111,635 $110,137 $107,832 $106,686 $106,191 $105,383 $105,072 $105,038 $104,930 $104,919 $104,514 $104,075 $104,066 $104,029 $102,877 $103,333 $102,022 $101,724 $101,935 $100,151 $99,210 $100,638 $98,496 $98,828 $98,882 $98,849 $98,500 Contract Advance $126,962 $126,952 $126,893 $126,452 $125,542 $125,503 $124,762 $124,464 $122,904 $122,611 $122,515 $122,424 $122,327 $120,364 $119,974 $119,177 $118,769 $118,076 $117,650 $116,929 $115,320 $114,952 $114,892 $114,691 $114,539 $114,240 $114,092 $113,809 $113,335 $111,837 $111,432 $108,386 $107,891 $107,083 $106,772 $106,738 $106,430 $106,419 $106,214 $106,175 $105,566 $105,529 $104,577 $104,333 $103,722 $103,424 $101,935 $101,851 $100,910 $100,638 $100,596 $100,528 $100,382 $100,349 $100,200 $66,504,845 Total Cash Advance 14-05XXX; MDR 107 Attach 01 Page 273 of 273