EEI's 'Transmission Projects

Transmission Projects: At A Glance

Prepared by: Edison Electric Institute

MARCH 2012 © 2012 by the Edison Electric Institute (EEI). All rights reserved. Published 2012. Printed in the United States of America. No part of this publication may be reproduced or transmitted in any form or by any means, electronic or mechanical, including photocopying, recording, or any information storage or retrieval system or method, now known or hereinafter invented or adopted, without the express prior written permission of the Edison Electric Institute.

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The views and opinions expressed in this work do not necessarily reflect those of EEI or any member of EEI. This material and its production, reproduction and distribution by EEI does not imply endorsement of the material.

Note: The status of the projects listed in this report was current when submitted to EEI but may have since changed between the time information was initially submitted and date this report was published.

Published by: Edison Electric Institute 701 Pennsylvania Avenue, N.W. Washington, D.C. 20004-2696 Phone: 202-508-5000 Web site: www.eei.org Executive Summary

This sixth annual publication of EEI’s Transmission Projects: At A Glance report showcases a cross-section of transmission projects that EEI’s members completed, or expected to complete, in 2011, have planned for the next ten years, and highlights EEI members’ continuing focus on needed transmission investment. This report is not a comprehensive compilation of all projects that are being undertaken by EEI’s members, but the sampling of projects described captures a wide variety of project types currently under construction or planned.

Investing in Needed Transmission In response to various needs, such as reliability and generator interconnection, investment in our nation’s transmission infrastructure has increased over the past several years. The increasing demands for new transmission and system upgrades will continue to drive transmission investment in the long-term. However, near-term planned transmission investment is impacted by current economic conditions indicated by lower rate of demand growth. Coupled with the recent completion and/or delay of major transmission projects, EEI currently projects a flattening or possible decrease in transmission investment through 2014, as compared to the projected 2012 level. Nevertheless, these projected 2011-2014 figures are significantly higher than the actual 2010 transmission investment level, and are a sign of a continuing increase in transmission investment by EEI’s members. As explained below, the ability of EEI members to make transmission investments that are beneficial to customers is supported by effective Federal Energy Regulatory Commission (“FERC”) policies. EEI member companies’ are also continuing their efforts to modernize the transmission system through individual funding and the use of Smart Grid Investment Grants (“SGIGs”) for certain projects selected by the United States Department of Energy (“DOE”), which augment existing EEI member grid modernization efforts. In addition, there are emerging factors that affect transmission investment, including recent United States Environmental Protection Agency (“EPA”) requirements on generation resources. EEI members’ investment in needed transmission is significant and reflects a commitment to reliability, preparation for future customer needs and public policy objectives. From 2001-2010, EEI members invested approximately $77 billion in transmission infrastructure enhancements to meet these needs.1 Over 100 transmission projects are highlighted in this report, totaling approximately $64 billion (nominal dollars) in expected future transmission system improvements from 2011 through 2022. This investment is only a portion of the total transmission investment anticipated through 2022 by EEI’s members.

The Value of Transmission It is important to remember that transmission projects provide an array of benefits, including maintaining the high levels of reliable electricity service that customers expect; providing congestion relief, reducing system losses, integrating generation resources; and deploying advanced monitoring systems to enhance

Edison Electric Institute iii Transmission Projects: At A Glance — Executive Summary

situational awareness, regardless of the initial development intention. At the same time, all transmission projects must be properly integrated with local systems to maintain the paramount objective of reliable operation of the national grid. In accordance with FERC’s 2009-2014 Strategic Plan, transmission projects are developed “through the use of open and transparent processes that include analysis and consideration on a comparable basis of proposed solutions involving any generation, transmission, and demand resource.”2

Policies Supporting Transmission Investment Investment in needed transmission is supported, in part, by several landmark developments in federal and state policies affecting transmission infrastructure. Among these are, notably, the Energy Policy Act of 2005 (“EPAct 2005”) and federal transmission pricing policies being implemented by FERC. In recognition of the benefits of a robust transmission network, the risks of transmission development, and the challenges of raising adequate capital to invest in transmission given other capital requirements, Congress required the adoption of a new transmission pricing policy in EPAct 2005. FERC implemented this mandate in 2006, issuing its transmission incentives rate final rule. Properly balancing the benefits of transmission with the cost to ratepayers, FERC executes its incentives policy with rigorous thresholds and requires detailed demonstrations by applicants as part of the prudency review. This pricing policy is working to assist in sustaining the needed levels of investment in transmission infrastructure improvements, and the deployment of advanced technologies, which, in addition to enhancing reliability and integrating diverse generation, removes barriers to electricity trading between and among regions and markets. The transmission grid is dynamic and ever expanding to better serve electricity customers. As showcased in this report, there is a continued need for transmission investment, which presents risks and challenges that have not diminished. As mentioned above, Congress recognized these risks and challenges. FERC’s balanced and effective incentives policy aids to address these risks and challenges, and regulatory certainty is critical to assure the timely development of needed transmission. There are also new federal developments that may assist in transmission siting, one of the major challenges to expanding, upgrading and modernizing our nation’s transmission network. The DOE and nine other federal agencies, are working together with the goal of improving the overall quality and timeliness of transmission permitting and review by federal agencies.3 These efforts could not come at a more opportune time. A robust transmission system can ensure the reliability of the grid and will assist in the industry’s efforts to comply with new EPA rules, as well as additional state environmental requirements.4

Report Scope In addition to the total transmission system investment included in this year’s report, several sub-categories are broken out and discussed in greater detail: Interstate Transmission Projects, Transmission Supporting the Integration of Renewable Resources, Transmission Projects Required for System Reliability, and Transmission Projects Developed by Multiple Project Partners. Large interstate transmission projects span multiple states and account for approximately 9,500 miles of transmission representing a $42.5 billion (nominal dollars) investment and face significant challenges for siting, permitting, cost allocation and cost recovery.

iv Edison Electric Institute Transmission Projects: At A Glance — Executive Summary

Transmission projects needed to address the integration of renewable resources that will accommodate the expected off-peak production represent the transmission upgrades of approximately 12,000 miles with an accompanying investment of approximately $47.5 billion (nominal dollars).5 Finally, transmission projects where EEI’s members have partnered with other utilities, including non-EEI members, to leverage their expertise in building needed and beneficial transmission represent a cost of approximately $42 billion (nominal dollars).

1 The historic investment total of approximately $77 billion for the 2001 through 2010 period is in real 2010 dollars. Sources: EEI’s Annual Property & Plant Capital Investment Survey for actual transmission investment and EEI’s Electric Transmission Capital Budget & Forecast Survey for planned transmission investment. 2 Federal Energy Regulatory Commission, The Strategic Plan - FY 2009-2014 at 24 (Oct. 2009) available at http://www.ferc.gov/about/strat-docs/FY-09-14- strat-plan-pringt.pdf 3 The nine participating federal agencies are DOE, FERC, Department of Interior, Department of Defense, Department of Agriculture, Environmental Protec- tion Agency, Department of Commerce, Council on Environmental Quality and the Advisory Council on Historic Preservation. 4 EPA rules include, among others: Cross-State Air Pollution Rule ("CSAPR") and Mercury and Air Toxics Standards ("MATS"). 5 There is no transmission project that will facilitate the delivery of renewable power only - apart from sources connected radially - given that wind generally use the line only 30-40 percent of the time and mainly during off-peak periods.

Edison Electric Institute v Introduction

Transmission Benefits EEI’s members are dedicated to prudently investing in needed transmission and using advanced technologies to modernize our nation’s grid. Transmission projects provide an array of benefits, including maintaining the high levels of reliable electricity service that customers expect; providing congestion relief, reducing system losses, integrating generation resources; and deploying advanced monitoring systems to enhance situational awareness. A robust transmission network provides grid operators needed flexibility to move electricity among regions, and at the same time, all transmission projects are integrated with local systems to maintain the paramount objective of reliable operation of the national grid. In accordance with FERC’s 2009-2014 Strategic Plan, transmission projects are developed “through the use of open and transparent processes that include analysis and consideration on a comparable basis of proposed solutions involving any generation, transmission, and demand resource.”1 EEI’s members will continue to support reliable operations as the electricity industry works to comply with recent United States Environmental Protection Agency (“EPA”) rules, as well as additional state environmental requirements.2 Evaluation of transmission needs to facilitate compliance with these new requirements is ongoing, and includes investment to facilitate public policy objectives.

Investment in Needed Transmission EEI’s members investment in our nation’s transmission infrastructure has increased over the past several years. Increasing demands on the transmission system have driven this investment, including ensuring reliability and facilitating generator interconnections, and will continue to drive transmission investment in the long-term. However, near-term transmission investment is not resistant to current economic conditions and slow demand growth. Coupled with the recent completion and/or delay of major transmission projects, EEI forecasts a flattening or possible decrease in transmission investment through 2014, as compared to the projected 2012 level. Nevertheless, these projected 2011-2014 figures are significantly higher than the actual 2010 transmission investment level and demonstrate the ever-increasing investment in transmission by EEI’s members. EEI member companies are also continuing their efforts to modernize the transmission system through individual funding and the use of Smart Grid Investment Grants (“SGIGs”) for certain projects selected by the DOE. These Smart Grid projects augment existing EEI member grid modernization efforts.

Support for Transmission Development Investment in needed transmission is supported by several landmark developments in federal and state policies affecting transmission infrastructure. These include the Energy Policy Act of 2005 (“EPAct 2005”), state renewable portfolio standards (“RPS”), federal initiatives promoting transmission Smart Grid

vi Edison Electric Institute Transmission Projects: At A Glance — INTRODUCTION development under the American Recovery and Reinvestment Act (“ARRA”), and appropriate and equitable transmission pricing policies, including the Federal Energy Regulatory Commission’s (“FERC”) incentives rate policy. Effectively embracing the statutory requirement to implement a transmission incentives rate policy, FERC works to balance the benefits of transmission with the cost to ratepayers. Accordingly, FERC requires several demonstrations by an applicant requesting incentives to ensure the incentives sought are tailored to the project-specific risks and challenges. This transmission pricing policy is working, and provides regulatory certainty for needed transmission investment. As demonstrated by this report, investment in our nation’s transmission network is not complete. Moreover, the risks and challenges of transmission investment are no less than when the FERC incentives policy began. FERC must continue to provide regulatory certainty and support for investment in needed transmission infrastructure. This report captures some of the most substantial transmission investments of EEI’s members. All of the projects in this report will provide a number of benefits and cost savings, including congestion relief, market facilitation, job creation, reliable service and support for a diverse generation portfolio. Incentives have been granted for certain of these projects that pose a higher level of risks and challenges, however, incentives are not sought for the majority of transmission investments by EEI’s members. When granted, incentives are tailored to address project-specific risks and challenges to ensure rates remain compensatory, and just and reasonable. Consumers receive considerable benefits from transmission projects, while utilities recover these investments over the facility’s useful life (typically 40 years).3 Moreover, each year the rate impact to consumers from a particular transmission project decreases.4 In addition, recent efforts by the United States Department of Energy (“DOE”) related to the coordination of the transmission siting and authorization process of nine federal agencies for qualifying interstate transmission projects means that more developments are on the horizon. Also, the Rapid Response Team for Transmission aims to improve the overall quality and timeliness of transmission permitting and review by federal agencies. This recognition by federal agencies of the difficulties in permitting and siting transmission facilities, and the resulting coordination efforts, will help address a major challenge in the effort to expand, upgrade and modernize the United States transmission network.

Transmission Planning Current local and regional transmission planning seek the most cost-effective and efficient solution to meet the electricity needs of the planning region. Recently, FERC released Order No. 1000, which contained reforms aimed at enhancing current regional and interregional planning procedures. These reforms can be broken down into three broad categories: i) planning, ii) cost allocation, and iii) non-incumbent developer opportunities. The industry is in the midst of developing compliance proposals to implement those reforms.

Edison Electric Institute vii Transmission Projects: At A Glance — INTRODUCTION

At the same time, EEI members are actively planning transmission projects to, among other things, address the need to integrate renewable resources where, and as, appropriate. The integration of renewable resources such as wind, solar, and geothermal generation presents special challenges. While fossil-fuel generators have some flexibility to site in close proximity to the existing transmission grid and existing load centers, siting of renewable resources is largely dictated by nature. Transmission investments to meet these challenges are being addressed by EEI’s members through various processes across the United States. Those processes recognize renewable resource locational constraints and identify the transmission investment needed to interconnect renewable projects. There are also initiatives being pursued to broaden the scope of transmission planning activities. One such effort is the Eastern Interconnection Planning Collaborative (“EIPC”) where transmission studies are being coordinated by planning authorities in the Eastern Interconnection. EIPC released its final Phase I report at the end of 2011, and building on those results, Phase II will look at opportunities for potential transmission enhancements to regional expansion plans.5 EIPC uniquely allows for a dialog between many stakeholder groups on interconnection-wide transmission planning and analysis. Other coordinated transmission expansion efforts are underway in ERCOT through the Long Term System Assessment performed in conjunction with the Electric System Constraints and Needs study that provides a 10-year assessment of system reliability needs. In the Western Interconnection, WECC’s Transmission Expansion Planning Policy Committee (“TEPPC”) has developed a 10-year regional transmission plan framework and is looking to develop 10-year and 20-year transmission expansion plans. These experiences and analysis will assist in efficiently advancing the industry.

Report Scope It is against this backdrop that EEI developed this report of member company transmission projects. Contained herein is a broad, though not comprehensive, perspective on the variety of transmission projects being built in the United States to support a number of needs and objectives. This report includes EEI members’ projects that are a cross-section of various project-investment category types. Included are lines of significant length, reliability, economic, resource access (conventional and renewable), multi-state, multi- entity (i.e., collaborative projects involving Investor Owned Utilities (“IOU”) and Public Power entities), and non-transmission line projects. Over 100 projects are highlighted in this report, totaling approximately $64 billion (nominal dollars) in future transmission system investments through the year 2022. This investment is only a portion of the total transmission investment anticipated through 2022 by EEI’s members. Although several of the projects in this report are in the proposal stages and subject to additional review of costs and benefits, including assessment of alternative projects, they are indicative of new transmission investments being made in the electric industry. Transmission investment highlighted in this report may include new lines, line rearrangements, voltage conversions, and line reconductoring projects. These investments may also include system improvements that, while not adding circuit miles, may improve transmission reliability and/or add transfer capability.

viii Edison Electric Institute Transmission Projects: At A Glance — INTRODUCTION

Such improvements include new transmission line technologies and improved transmission operational protocols that have been, or will be, applied. Examples of such projects include: substation modernization projects; equipment replacements, such as transformers, wave traps, or phase-shifters; and the addition of reactive compensation, such as Static VAR Compensators (“SVC”) or dynamic reactive sources. The substantial research and development efforts that support these projects are not included within this report. Included within the broad spectrum of Transmission System Improvement projects are Smart Grid related projects that EEI’s members selected to showcase. Smart Grid projects highlighted in this report are primarily transmission-related projects that use digital technology to improve reliability, security, and efficiency (both economic and energy) of the electric system. Examples of these projects include communication improvements such as Optical Fiber Composite Overhead Ground Wire projects, control center improvements, integration of EMS/SCADA systems to area and regional control systems; time- synchronized, high quality measurements from phasor measurement units (“PMUs”); dynamic line ratings, transformer online monitoring systems and the associated measurement equipment; smart-grid-enabled distributed controls and diagnostic tools helping the transmission system to respond to imbalances and limiting their propagation; transmission automation; and transmission substation automation. This report also emphasizes several broad categories of transmission investments that are subcategories of the total Transmission System Investments highlighted in this report: 1. Interstate Transmission Projects. 2. Transmission Supporting the Integration of Renewable Resources. 3. Transmission Required for System Reliability Needs. 4. Transmission Projects Developed by Multiple Project Partners While the focus in this report is presenting targeted projects within these broad categories, it is important to remember that transmission projects address an array of needs and deliver a number of benefits such as congestion relief, enhanced regional reliability, reduced system losses, integration of resources, and deployment of advanced monitoring systems to enhance situational awareness. Keeping that in mind, most projects in this report are multifaceted; that is, they are not developed solely to meet any one specific purpose, rather, they fall into more than one transmission investment category.

Interstate Transmission Projects Interstate transmission projects are transmission line improvements that physically span two or more states. These interstate projects often present additional challenges for siting, permitting, cost allocation and cost recovery.

Edison Electric Institute ix Transmission Projects: At A Glance — INTRODUCTION

Transmission Supporting the Integration of Renewable Resources Renewable resources transmission projects, whether transmission line or non-transmission line, are projects that support the integration of a renewable resource. A renewable energy resource is defined as any energy resource generated from natural resources such as sunlight, wind, rain, tides and geothermal heat that is replaced rapidly by natural processes. Renewable energy technologies include: solar power, wind power, hydroelectricity, geothermal, biomass and biofuels.

Transmission Projects Required for System Reliability Needs Transmission projects supporting reliability needs are projects where the predominant driver has been identified as the need to meet either NERC reliability standards e.g.( , NERC Transmission Planning TPL standards) and/or local Transmission Owner reliability criteria. These projects maintain the operational integrity of the interconnected Bulk Electric System and will be developed regardless of state RPS goals or economic incentives to open new market avenues or access more economic energy alternatives.

Transmission Projects Developed by Multiple Project Partners Given the unique risks and challenges of developing transmission, among other things, several EEI member companies are partnering with other utilities, including non-EEI members, to develop large-scale transmission projects. This collaboration allows entities to spread the investment risks while also leveraging each other’s experience in developing needed and beneficial transmission.

Transmission Project Inclusion Criteria A minimum project investment threshold of $50 million for transmission system projects was applied to the selection of projects contained in this report. However, a lower threshold of $20 million was applied for transmission supporting the integration of renewable resources and a $10 million investment threshold was applied to any Smart Grid projects that an EEI member selected to showcase. The report focuses on projects completed, or expected to be completed, in 2011 through 2022 (this represents a 1 year back-looking and 10 year forward-looking window).

A brief profile of each company is included along with the representative projects it submitted.

Highlighted Projects Recently Completed Several projects highlighted in this report were placed in service in 2011: • Bell County East – TNP One 345 kV Transmission Line Project • Chicago Southern Business District Fisk 345 kV Project • Dundee – Intercession City 230 kV Rebuild and Add 2nd Unit • Loblolly to Hammond Project • M29 Transmission Project

x Edison Electric Institute Transmission Projects: At A Glance — INTRODUCTION

• McAdams Area Upgrade Project • METC SCADA Redirection Program • Midway – Watertown 345 kV Transmission Line • Richmond Plant-Ft. Bragg Woodruff St. 230 kV Transmission Line Project • Static Var Compensation • Trans-Allegheny Interstate Line (TRAIL) Project In 2010, a total investment of $10.2 billion was made by EEI members. EEI member companies plan to invest an additional approximately $54 billion in the transmission system from 2012 to 2014.6

Figure 1: Transmission Investment ($ millions)

($ Millions [Real $2010]) 24,000 22,000 20,000 18,000 Advent of EPAct 2005 and 16,000 FERC Pricing Policies 14,000 12,000 10,000 8,000 6,000 4,000 2,000 0

2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011p 2012p 2013p 2014p 2015p 2016p 2017p 2018p 2019p 2020p 2021p 2022p Actual Planned

Edison Electric Institute xi Transmission Projects: At A Glance — INTRODUCTION

Some General Observations The overall breakdown of transmission investments included in this report and total new or reconductored transmission circuit miles by interconnection is shown in the diagram below.

Figure 2: Representative Project Investment Totals and Added/Reconducted Circuit Miles by Interconnect

xii Edison Electric Institute Transmission Projects: At A Glance — INTRODUCTION

Large interstate projects highlighted in this report spanning more than one state and involving numerous entities at the federal, state, and local levels account for approximately 9,500 miles of transmission representing a $42.5 billion (nominal dollars) investment.

Figure 3: Representative Project Interstate vs. Non-Interstate Investment Percentage

Non-Interstate Interstate 33% 67%

Highlighted projects that facilitate the integration of renewable resources reflect the addition or upgrade of 9,500 miles of transmission with an accompanying transmission investment cost of approximately $47.5 billion (nominal dollars).

Figure 4: Representative Project Renewable vs. Non-Renewable Investment Percentage

Non-Renewable Renewable 26% 74%

Edison Electric Institute xiii Transmission Projects: At A Glance — Introduction

Highlighted projects that were multiple utilities have collaborated, in order to leverage experience and expertise developing large-scale transmission, represent a cost of approximately $42 billion (nominal dollars).

Figure 5: Representative Project With Partners vs. Projects With No Partners

No Partners Project Partners 35% 65%

The projects presented in this report also include a number of non-transmission line projects. These projects span the range of phase angle regulators, step-down transformers, Static VAR Compensators (“SVC”), static capacitors, and control system improvements. Included in this category are other transmission grid modernization efforts by EEI members related to ongoing investments in Smart Grid related projects. While not adding to the overall line mileage, these projects provide tangible benefits to the transmission system through the creation of additional transfer capability, added system awareness, and strengthening the overall transmission system. Non-transmission line projects highlighted in this report include the NYISO Transmission Smart Grid Project, the PJM Synchrophasor Smart Grid Project, and the Wide-Area Situation Awareness System project. In summary, EEI’s members remain committed to the development of this needed infrastructure, the modernization of the transmission system, and the integration of renewable resources into our national grid. These efforts are currently supported by equitable transmission pricing policies and may be aided by recent federal coordination efforts for transmission siting.

1 Federal Energy Regulatory Commission, The Strategic Plan - FY 2009-2014 at 24 (Oct. 2009) available at http://www.ferc.gov/about/strat-docs/FY-09- 14-strat-plan-pringt.pdf 2 EPA rules include, among others: Cross-State Air Pollution Rule ("CSAPR") and Mercury and Air Toxics Standards ("MATS"). 3 For example, it appears that the $1 billion TrAIL project entering service in 2011, along with other transmission improvements across the PJM footprint, will reduce congestion costs by about $1 billion in year 2013. See, Figure 13.2 of the 2010 RTEP Plan, available at http://www.pjm.com/documents/re ports/rtep-report/~/media/documents/reports/2010-rtep/2010-section13.ashx. 4 The rate impact of transmission projects and any project-specific incentive ROE will decrease every year as transmission plant balance depreciates. 5 EIPC represents 90 percent of all load in the Eastern Interconnection and the principal participants are: Entergy, ISO-New England MAPPCOR, MISO, New York ISO, PJM Interconnection, Southern Company and Tennessee Valley Authority. The Phase I Report is available at http://www.eipconline.com/ uploads/Phase_1_Report_Final_12-23-2011.pdf. 6 Data represents both vertically integrated and stand-alone transmission companies. Planned total industry expenditures are preliminary and estimated from responses to EEI’s Electric Transmission Capital Budget & Forecast Survey. Actual expenditures are from EEI’s Annual Property & Plant Capital Invest- ment Survey & FERC Form 1s. The trend line for 2001 through 2005 is based on a linear approximation of the reported expenditures for that period. The trend line for estimated expenditures beyond 2005 is based on a linear approximation of actual and planned industry expenditures for 2006 through 2014. xiv Edison Electric Institute Table of Contents

Executive Summary...... iii Introduction...... vi AMEREN TRANSMISSION Company (ATX)...... 1 • Grand Rivers Projects...... 1 American Electric Power (AEP)...... 3 • Midwest Power Transmission...... 4 • Pioneer Transmission, LLC...... 4 • Prairie Wind Transmission, LLC...... 5 • RITELine Transmission...... 6 Potomac – Appalachian Transmission Highline (PATH) Project...... 7 • PATH 765 kV Project...... 7 American Transmission Company (ATC)...... 9 • Badger Coulee...... 9 • Barnhart - Branch River...... 10 • Cardinal Bluffs...... 11 • Pleasant Prairie - Zion Energy Center...... 11 • Rockdale - Cardinal...... 12 • Smart Grid Investment Grant Projects...... 13 • Straits Flow Control...... 13 Duke-American Transmission Company (DATC)...... 14 • DATC Project 1...... 14 • DATC Project 2...... 15 • DATC Project 3...... 15 • DATC Project 4...... 16 • DATC Project 5...... 16 • DATC Project 6...... 17 • DATC Project 7...... 17 • Zephyr Power Transmission Project...... 18 Arizona Public Service (APS)...... 19 • Palo Verde Hub - North Gila 500 kV Project...... 19 • Palo Verde Substation - Delaney Substation - Sun Valley Substation - Morgan Substation - Pinnacle Peak Substation 500 kV Projects...... 20 Baltimore Gas and Electric (BGE)...... 21 • Graceton - Raphael Road 230 kV Circuit...... 21 • Emory Grove 500/230 kV Station...... 22

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COMED...... 23 • Chicago Southern Business District Fisk 345 kV Project...... 23 • Chicago Southern Business District Burnham-Taylor 345 kV Project...... 24 Consolidated Edison, Inc. (Con Edison)...... 25 • NYISO Smart Grid Project...... 25 • PJM SynchroPhasor Smart Grid Project...... 26 • M29 Transmission Project...... 27 Entergy Corporation ...... 28 • Holland Bottoms 500 kV Project...... 28 • SELA Project Phase 2 and Phase 3...... 29 • Ouachita Projects...... 29 • Acadiana Load Pocket Project...... 30 • Orange County Project...... 30 • Loblolly to Hammond Project...... 31 • McAdams Area Upgrade Project...... 31 FIRSTEnergy...... 32 Potomac – Appalachian Transmission Highline (PATH) Project...... 32 • PATH 765 kV Project...... 33 Trans – Allegheny Interstate Line Company (TrAILCo)...... 34 • Trans – Allegheny Interstate Line (TRAIL) Project...... 34 ITC Holdings Corp...... 35 Green Power Express LP...... 35 • Green Power Express...... 35 ITC Great Plains...... 37 • Kansas V-Plan...... 37 • KETA Project...... 38 • Oklahoma Hugo - Valliant Project...... 39 ITC Midwest...... 40 • Salem-Hazleton Line ...... 40 ITC Transmission...... 41 • Michigan Thumb Loop Transmission Project...... 41 Michigan Electric Transmission Company (METC)...... 42 • G905 Generator Interconnection...... 42 Kansas City Power & Light (KCP&L)...... 43 • Iatan - Nashua 345 kV Transmission Line...... 43 • Sibley - Nebraska City 345 kV Transmission Line...... 44 MIDAMERICAN ENERGY HOLDINGS COMPANY...... 45 MidAmerican Energy Company...... 45 • MidAmerican Energy Expansion Projects...... 45

xvi Edison Electric Institute Transmission Projects: At A Glance — TABLE OF CONTENTS

MidAmerican Transmission, LLC...... 46 • Prairie Wind Transmission, LLC...... 47 • Midwest Power Transmission...... 47 PacifiCorp...... 48 • Energy Gateway...... 48 Minnesota Power...... 50 • CAPX2020 Transmission Plan...... 50 • Transmission to Serve Essar Steel Minnesota ...... 52 National Grid...... 53 • Northeast Energy Link...... 53 • New England East - West Solutions (NEEWS)...... 54 • NEEWS - Interstate Reliability Project (IRP)...... 54 • NEEWS - Rhode Island Reliability Project (RIRP)...... 55 Northeast Utilities (NU)...... 56 • The Northern Pass Transmission Line (NPT Line)...... 56 • New England East - West Solution Projects (NEEWS)...... 57 • Greater Springfield Reliability Project (GSRP)...... 57 • Interstate Reliability Project (IRP)...... 58 • Central Connecticut Reliability Project (CCRP)...... 59 • Pittsfield-Greenfield Area Solution...... 60 NorthWestern Energy...... 61 • 500 kV Upgrade Project...... 61 • Montana Renewable Collector System (MT-RCS)...... 62 • Mountain States Transmission Intertie (MSTI)...... 63 NV Energy...... 65 • One Nevada 500 kV Transmission Intertie (NVES & NVEN)...... 65 • Renewable Energy Transmission Initiative (RTI)...... 66 OGE Energy Corp. (OGE)...... 67 • Hitchland – Woodward 345 kV Line...... 67 • Seminole – Muskogee 345 kV Line...... 68 • Sooner – Cleveland 345 kV Line...... 68 • Sooner – Rose Hill 345 kV Line...... 69 • Sunnyside – Hugo 345 kV Line...... 69 • Woodward – Kansas 345 kV Line...... 70 • Woodward – Tuco 345 kV Line...... 70 Oncor Electric Delivery Company, LLC (Oncor)...... 71 • Bell County East – TNP One 345 kV Transmission Line Project...... 71 • Dynamic Line Ratings...... 72 • Fiber Optical Cable Use...... 73

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• Oncor CREZ Development...... 73 • Phasor Measurement...... 74 • Static Var Compensation...... 75 Otter Tail Power Company (OTP)...... 76 • CapX2020 Transmission Plan...... 76 • Big Stone South to Brookings Project...... 77 • Big Stone South to Ellendale Project...... 78 Pacific Gas and Electric (PG&E)...... 79 • Central Valley 500 kV Study...... 79 PEPCO Holdings, Inc. (PHI)...... 81 • Benning Transmission Project...... 81 • Mid-Atlantic Power Pathway (MAPP) Project...... 82 • PJM N-1-1 Projects (Southern Delmarva)...... 83 Progress Energy...... 84 • Central Florida - 500/230 kV Capacity Increase...... 84 • Harris Plant - RTP 230 kV Transmission Line Project...... 85 • Richmond Plant - Ft. Bragg Woodruff St. 230 kV Transmission Line Project...... 85 Public Service Electric and Gas Company (PSE&G)...... 86 • Burlington - Camden 230 kV Network Reinforcement Project...... 86 • Northeast Grid Reliability Transmission Project (formerly Roseland - Hudson 230 kV Conversion Baseline Transmission Project)...... 87 • Susquehanna - Roseland 500 kV Transmission Line Project...... 88 • North-Central Reliability Project (formerly the West Orange 230kV Project)...... 89 • Mickleton-Gloucester-Camden Reinforcement Project ...... 90 SOUTHERN CALIFORNIA EDISON (SCE)...... 91 • Eldorado – Ivanpah Transmission Project (EITP)...... 91 • San Joaquin Cross Valley Loop (SJXVL)...... 92 • Tehachapi Renewable Transmission Project (TRTP)...... 93 • South of Kramer (SOK)...... 95 • West of Devers (WOD)...... 96 • Centralized Remedial Action Schemes (CRAS)...... 96 • Wide-Area Situation Awareness System (WASAS)...... 97 Southern Company...... 98 • East Pelham 230/115 kV Transmission Substation Project...... 98 • Holmes Creek - Highland City 230 kV Transmission Line Project...... 99 • Kemper County IGCC Plant...... 99 • Mobile Area Network Project...... 100 • Plant Smith - Laguna Beach - Santa Rosa 230 kV Transmission Line Project...... 100 • Plant Vogtle Network Improvement Project...... 101

xviii Edison Electric Institute Transmission Projects: At A Glance — TABLE OF CONTENTS

• South Tuscaloosa - Eutaw Area Network Project...... 101 • Douglas - Pine Grove Primary 230kV Line Project...... 102 Vermont Electric Power Company (VELCO)...... 103 • Central Vermont Upgrade...... 103 • Connecticut River Valley Upgrades...... 104 • Substations Additions and Upgrades...... 104 Westar Energy, Inc...... 105 • Rose Hill - Sooner 345 kV Transmission Line...... 105 Prairie Wind Transmission, LLC...... 106 • Wichita - Medicine Lodge - Woodward 345 kV Transmission Line...... 106 Xcel Energy Inc...... 107 Northern States Power Companies (NSP Companies)...... 107 • CapX2020 Transmission Plan...... 108 • MISO Multi Value Project Portfolio...... 109 • Pleasant Valley Transmission Project...... 110 Public Service of Colorado (PSCo)...... 111 CO Senate Bill 100 Plan Projects...... 111 • Ault - Cherokee 230 kV Transmission Line ...... 111 • Midway - Waterton 345 kV Transmission Line...... 112 • Missile Site 345 kV Switching Station...... 112 • Pawnee - Daniels Park 345 kV Transmission Line...... 113 • Pawnee - Smoky Hill 345 kV Transmission Project...... 113 • San Luis - Calumet - Comanche Line...... 114 Southwestern Public Service (SPS)...... 115 • Hitchland - Woodward 345 kV Transmission Line...... 115 • Tuco - Woodward District 345 kV Transmission Line...... 116 • San Luis - Calumet - Comanche Line...... 114 Southwestern Public Service (SPS)...... 115 • Hitchland - Woodward 345 kV Transmission Line...... 115 • Tuco - Woodward District 345 kV Transmission Line...... 116 Interstate Transmission Projects ...... 117 Transmission Supporting the Integration of Renewable Resources...... 118 Transmission Projects Developed by Multiple Project Partners...... 119

Edison Electric Institute xix Transmission Projects: At A Glance — Table of Contents

xx Edison Electric Institute AMEREN TRANSMISSION Company (ATX)

Company Background: • Ameren Transmission Company (ATX) is the transmission development subsidiary of Ameren Corporation in St. Louis, Missouri. ATX was formed in July 2010 and is dedicated to electric transmission infrastructure investment and expanding Ameren’s transmission system. • Ameren Corporation serves 2.4 million electric customers and 900,000 natural gas customers across 64,000 square miles in Illinois and Missouri.

Transmission Related Smart Grid Initiatives: • The Ameren Transmission Owning Companies, along with MISO and other MISO Transmission Owners, are deploying SynchroPhasor technology across the MISO footprint.

Grand Rivers Projects Project Description: The Grand Rivers Proj- ects consist of three new transmission projects in Illinois and Missouri consisting of over 490 miles of 345 kilovolt transmission lines. These projects are named Illinois Rivers, Mark Twain and Spoon River. The Illinois Rivers project consists of over 330 miles of 345 kilovolt transmission from northeastern Missouri, crossing the Mississippi River and continuing east across Illinois to the Indiana Border. The Mark Twain project is approximately 90 miles of 345 kilovolt transmission from the Missouri-Iowa border in northeast Missouri connecting to the Missouri terminus of the Illinois River project. The Spoon River project consists of 70 miles of 345 kilovolt transmission in Northwest Illinois. (A portion of the Spoon River project may be built by another MISO transmission owner in accordance with the MISO Transmission Owners Agreement.)

Project Cost: Over $1.2 billion.

Edison Electric Institute 1 Transmission Projects: At A Glance — AMEREN TRANSMISSION Company (ATX)

Project Status: The Grand Rivers Projects were designated as Multi-Value Projects (MVPs) as part of the $6 billion of transmission investment included in the 2011 Midwest Independent Transmis- sion System Operator, Inc. (MISO) Transmission Expansion Plan which was approved by the MISO Board of Directors on December 8, 2011. The Illinois Rivers Project was also awarded Federal Energy Regulatory Commission incentive ratemaking treatment, including Construction Work in Progress (CWIP), use of a hypothetical capital structure during construction, and future recovery of abandonment costs.

Project Investment Partners: None.

Project Benefits: Collectively, with the other MISO-approved MVPs, these projects will enable the Integration of wind and other renewable energy resources into the MISO system to meet the MISO member renewable energy standards and goals. They enhance the reliability of the system and improve the MISO market efficiency by reducing energy production costs. They also provide the system with flexibility and resiliency as the generators in MISO implement their plans for environmental compliance, including generation plant closures.

2 Edison Electric Institute American Electric Power (AEP)

Company Background: • AEP is one of the largest electric utilities in the United States, delivering electricity to more than five million customers in 11 states. • AEP’s service territory covers approximately 200,000 square- miles in Arkansas, Indiana, Kentucky, Louisiana, Michigan, Ohio, Oklahoma, Tennessee, Texas, Virginia and West Virginia. • System-wide there are more than 39,000 circuit miles of transmission lines, including over 2,100 circuit miles of 765 kV transmission. • Customer service is provided through AEP’s seven regional utilities: AEP Ohio; AEP Texas; Appalachian Power; Indiana Michigan Power; Kentucky Power; Public Service Company of Oklahoma; and Southwestern Electric Power Company. • AEP is continuing its efforts to develop an extra high-voltage (EHV) interstate transmission superhighway. In furtherance of this effort, AEP is increasing on-system investment through the establishment of service territory focused Transmission Companies (Transcos) as well as maintaining a focus on the formation of joint ventures with several utilities to build transmission in regions across the country: • Potomac - Appalachian Transmission Highline, LLC (PATH): A joint venture with Allegheny Energy, Inc. to build a 765 kV transmission line within PJM extending from West Virginia to Maryland; • Electric Transmission Texas, LLC (ETT): A joint venture with a subsidiary of MidAmerican Energy Holdings Company established to invest in transmission within the Electric Reliability Council of Texas (ERCOT); • Electric Transmission America, LLC (ETA): A second joint venture with a subsidiary of MidAmerican Energy Holdings Company to identify and invest in high-voltage transmission projects (345 kV or higher) located in North America outside of ERCOT. • ETA has established joint ventures with Westar Energy to build EHV transmission in the Southwest Power Pool (SPP) and with Exelon Corporation to build EHV transmission in the PJM region; • RITELine Transmission Development, LLC: A joint venture established between AEP, Electric Transmission America and Exelon to develop high-voltage transmission projects in the PJM region (Illinois and Indiana); and • Pioneer Transmission, LLC: AEP and Duke Energy formed a joint venture to build a 765 kV transmission line in Indiana. • Between 2001 and 2010 AEP has invested approximately $3.9 billion into its transmission system.

Edison Electric Institute 3 Transmission Projects: At A Glance — American Electric Power (AEP)

Midwest Power Transmission Planning Category: (Public Policy) Project intended to provide reliability, economic and public policy benefits.

Project Description: The Midwest Power Trans- mission Project will extend approximately 270-miles from the Kewanee substation in Illinois and west to the Adair substation. An alternative route is also being considered, it will extend approximately 235-miles from the Kewanee substation in Illinois and northwest to the Black Hawk substation.

Project Cost: The total project cost is estimated to be approximately $650 million at 765 kV. Ameri- can Electric Power will invest $162.5 million with MidAmerican Energy Company investing $487.5 million.

Project Status: Economic and reliability studies are underway.

Project Construction Timeframe: MPT is currently anticipated to be placed in service in 2019.

States Served/Number of Circuit Miles in each State: Illinois (71-miles), Iowa (199-miles)

Project Investment Partners: American Electric Power and MidAmerican Energy Company.

Project Benefits: The large amount of wind generation being installed in MISO is causing operational problems in some states. New transmission will enable the system to operate reliably while integrating the renewable generation required by state law and possible changes in the generation fleet. The Midwest Power Transmission Project will improve overall system reliability and reduce congestion in Illinois and Iowa while also establishing the network required to enable states in the region to meet state mandated renewable portfolio standards while maintaining reliability.

Pioneer Transmission, LLC Planning Category: (System Reliability) Project intended to provide reliability, economic and public policy benefits.

Project Description: The Pioneer Transmission, LLC project consists of approximately 280-miles of new 765 kV transmission line linking Duke Energy’s Greentown Station (near Kokomo, Indiana) to AEP’s Rockport Station (near Evansville, Indiana). Originating at Duke Energy’s Greentown Sta- tion, the 765 kV line runs west to a new substation near Meadow Lake Wind Farm before extending southwest to AEP’s Sullivan Station southeast to Duke Energy’s Edwardsport Station and further south to AEP’s Rockport Station.

4 Edison Electric Institute Transmission Projects: At A Glance — American Electric Power (AEP)

Midwest Power Transmission Project Cost: The total project cost is estimated to be approximately $950 million at 765 kV. American Electric Planning Category: (Public Policy) Project intended to Power and Duke Energy will each invest $475 million in provide reliability, economic and public policy benefits. the project. Project Description: The Midwest Power Trans- Project Status: The 60-mile portion of the project that mission Project will extend approximately runs from Greentown to the proposed substation near 270-miles from the Kewanee substation in Illinois Meadow Lake Wind Farm is expected to be included as and west to the Adair substation. An alternative a 2011 MISO Multi-Value Project (MVP). The remain- route is also being considered, it will extend ap- ing 220-mile portion running from New Reynolds to proximately 235-miles from the Kewanee substa- Rockport station is under evaluation for inclusion in PJM’s tion in Illinois and northwest to the Black Hawk Regional Transmission Expansion Plan (RTEP). substation. Project Construction Timeframe: The anticipated in Project Cost: The total project cost is estimated to service date for the segment expected to be approved as a be approximately $650 million at 765 kV. Ameri- 2011 MISO MVP project is 2018. Anticipated in service can Electric Power will invest $162.5 million with dates for remaining segments have yet to be determined. MidAmerican Energy Company investing $487.5 million. States Served/Number of Circuit Miles in each State: Indiana (280-miles) Project Status: Economic and reliability studies are underway. Project Investment Partners: American Electric Power and Duke Energy.

Project Construction Timeframe: MPT is currently anticipated to be placed in service in 2019. Project Benefits: This project will mitigate thermal and voltage concerns, reduce transmission congestion and losses, and will add substantial transmission capacity to support both renewable and con- States Served/Number of Circuit Miles in each State: Illinois (71-miles), Iowa (199-miles) ventional generation development in Indiana, the MISO and PJM. The project has been a key line in Project Investment Partners: American Electric Power and MidAmerican Energy Company. several interregional planning studies, including the SMARTransmission Study (sponsored by ETA and several Midwest utilities) and MISO’s Regional Generator Outlet (RGOS) study. Project Benefits: The large amount of wind generation being installed in MISO is causing operational problems in some states. New transmission will enable the system to operate reliably while integrat- Prairie Wind Transmission, LLC ing the renewable generation required by state law and possible changes in the generation fleet. The Midwest Power Transmission Project will improve overall system reliability and reduce congestion in Planning Category: (Public Policy) Project intended to provide Illinois and Iowa while also establishing the network required to enable states in the region to meet reliability, economic and public policy benefits. state mandated renewable portfolio standards while maintaining reliability. Project Description: The Prairie Wind Trans- mission, LLC project consists of approximately Pioneer Transmission, LLC 110-miles of new double-circuit, EHV, 345 kV Planning Category: (System Reliability) Project intended to transmission line linking a 345 kV substation provide reliability, economic and public policy benefits. near Wichita, Kansas to a new 345 kV substation northeast of Medicine Lodge, Kansas (near Project Description: The Pioneer Transmission, LLC project consists of approximately 280-miles of the Flat Ridge Wind Farm). The line continues new 765 kV transmission line linking Duke Energy’s Greentown Station (near Kokomo, Indiana) to south from the wind farm to the Kansas-Oklaho- AEP’s Rockport Station (near Evansville, Indiana). Originating at Duke Energy’s Greentown Sta- ma border. The project is part of the SPP Priority tion, the 765 kV line runs west to a new substation near Meadow Lake Wind Farm before extending Projects Study and the SPP EHV Overlay Study. southwest to AEP’s Sullivan Station southeast to Duke Energy’s Edwardsport Station and further south to AEP’s Rockport Station.

Edison Electric Institute 5 Transmission Projects: At A Glance — American Electric Power (AEP)

Project Cost: The total project cost is estimated to be approximately $225 million at 345 kV. Westar Energy will invest $112.5 million while American Electric Power and MidAmerican Energy Com- pany will each invest $56.25 million.

Project Status: Prairie Wind Transmission is an approved SPP Priority Project having received a novated Notice to Construct in February 2011. In June 2011, the Kansas Corporation Commission approved siting for the project as filed.

Project Construction Timeframe: The anticipated in service date is 2014.

States Served/Number of Circuit Miles in each State: Kansas (110-miles)

Project Investment Partners: American Electric Power, MidAmerican Energy Company and Westar Energy.

Project Benefits: The SPP region has high wind potential and SPP is currently planning for a future 20 percent wind energy penetration for the region. Currently, many wind projects will have difficulty connecting due to lack of available transmission. The Prairie Wind project will provide interconnection for these projects and facilitate regional energy transfers that may result from large-scale wind development. This project, along with additional segments of SPP’s future EHV plans, will provide improved reliability, reduced system losses, reduced transmission congestion for the SPP electric system while enabling the development of significant sustainable energy for the region.

RITELine Transmission Planning Category: (Public Policy) Project intended to provide reliability, economic and public policy benefits.

Project Description: The Reliability Inter- regional Transmission Extension (RITE) Line consists of approximately 420-miles of 765 kV transmission line linking AEP’s proposed Blue Creek with Pioneer Transmission LLC’s stations (Greentown and a new station near Reynolds) in Ohio and Indiana with Exelon’s Pontiac, Kewanee, Collins, Nelson, and Byron stations south and west of Chicago in Illinois. The Proj- ect will include five new 765 kV substations and other applicable transmission facilities.

Project Cost: The total project cost is estimated to be approximately $1.6 billion. American Electric Power’s investment in the project will be $325 million, with MidAmerican Energy Company, Exelon Corporation and Commonwealth Edison investing $175 million, $200 million, and $900 million, respectively.

Project Status: The FERC issued an order on October 21, 2011 granting incentives for the project and accepting a formula rate. The project is currently under evaluation by PJM.

6 Edison Electric Institute Transmission Projects: At A Glance — American Electric Power (AEP)

Project Construction Timeframe: The anticipated in service date is expected to be completed in stages from 2015 - 2018.

States Served/Number of Circuit Miles in each State: Indiana (105-miles), Illinois (315-miles)

Project Investment Partners: American Electric Power, MidAmerican Energy Company, Exelon Transmission Co., and Commonwealth Edison.

Project Benefits: The project is designed to augment system reliability, enable states to meet their respective renewable portfolio standard requirements, relieve congestion, and enhance system operations.

Potomac – Appalachian Transmission Highline (PATH) Project Company Background:

• Note: On February 28, 2011, FirstEnergy and American Electric Power announced their affiliates filed to withdraw their applications for state regulatory approval of the PATH Project following an announcement by regional grid operator PJM Interconnection that the project has been suspended. • In September 2007, the former Allegheny Energy and American Electric Power (AEP) formed a joint venture to build the PATH Project to address anticipated reliability violations in the PJM Region. Most of the PATH Project in West Virginia will be owned by PATH West Virginia Transmission Company, LLC (PATH-WV) which is controlled by FirstEnergy and AEP. The remainder of the PATH Project in West Virginia will be owned by PATH Allegheny Transmission Company, LLC (PATH-Allegheny) which is controlled by FirstEnergy. In Virginia, the project will be owned by a subsidiary of PATH-Allegheny. In Maryland, the project will be owned by PATH Allegheny Maryland Transmission Company, LLC which is owned by PATH-Allegheny and The Potomac Edison Company, also a part of FirstEnergy.

PATH 765 kV Project Planning Category: (System Reliability) Project intended to provide reliability, economic and public policy benefits.

Project Description: The PATH 765 kV Proj- ect consists of approximately 275-miles of new single-circuit, 765 kV transmission line from AEP’s Amos Substation in Putnam County, West Virginia, through the new Welton Spring Substation in Hardy County, West Virginia, and continuing through Virginia to the new Kemp- town Substation in Frederick County, Maryland.

Edison Electric Institute 7 Transmission Projects: At A Glance — American Electric Power (AEP)

The project includes construction and modifications to the Amos Substation and construction of the two new substations. The project will utilize advanced control technology in substations and will enhance reliability and efficiency of the PATH Project. The Federal Energy Regulatory Commission has granted the following rate incentives for the project: an incentive return on equity for new transmission; recovery of a return on 100 percent of prudently incurred transmission related Construction Work in Progress prior to the project’s in service date; recovery of all startup business and administrative costs incurred prior to the time that rates go into effect; and authorization to recover all prudently incurred development and construction costs if the PATH Project is abandoned as a result of factors beyond the control of PATH-WV or PATH-Allegheny or their parents.

Project Cost: Based on current plans, the total project is estimated to cost approximately $2.1 billion. FirstEnergy’s investment in the project will be approximately $1.4 billion and AEP’s investment will be approximately $700 million.

Project Status: PJM directed the construction of PATH in 2007 to resolve violations of national and local standards for reliable operation of the region’s transmission system. Since then, annual studies reaffirmed the need for PATH as the recommended solution for resolving these issues. However, PJM’s latest analyses indicate that the projected need for the project has moved well into the future. PJM has requested that the company suspend further development of the project while PJM conducts a more rigorous analysis of the need for the project. In response the company has sought to withdraw its siting applications filed with the West Virginia Public Service Commission, Maryland Public Service Commission and the Virginia State Corporation Commission.

Project Construction Timeframe: The anticipated in service date is being investigated by PJM.

States Served/Number of Circuit Miles in each State: Maryland (20-miles), Virginia (31-miles), West Virginia (224-miles)

Project Investment Partners: American Electric Power and FirstEnergy.

Project Benefits: The PATH Project will maintain the reliability of the power supply system in the PJM Region, allow greater flexibility in scheduling outages for maintenance of critical transmission infrastructure, provide system loss savings and loss savings from advanced conductor will reduce energy needs in the PJM Region by 600 GWh per year offsetting over 300,000 metric tons of CO2 annually, and the project will create jobs in engineering, surveying, construction and related industries.

8 Edison Electric Institute American Transmission Company (ATC)

Company Background: • ATC started business on January 1, 2001, as the first multi-state, transmission-only utility in the United States. ATC has a single focus: transmission. ATC’s transmission system allows energy producers to transport electric power from where it’s generated to where it’s needed similar to the interstate highway system with high-voltage electricity traveling on the transmission system wires like vehicles on the highway. • ATC provides electric transmission service in an area from the Upper Peninsula of Michigan, throughout the eastern half of Wisconsin and into portions of Illinois. The 9,440 circuit miles of high-voltage transmission lines and 515 substations provide communities with access to local and regional energy sources. • ATC operates their $2.9 billion transmission system as a single entity. As a public utility whose infrastructure serves as the link in transporting electricity to millions of electricity users, ATC has duties and responsibilities to: • Operate the transmission system reliably; • Assess the ability of the system to adequately meet current and future needs; • Plan system upgrades to meet those needs in the most efficient, effective and economic ways; • Construct upgrades in time to meet those needs; and • Maintain the transmission equipment and surroundings to minimize opportunity for failures. • Between 2001 and 2010 ATC invested nearly $2.7 billion in its transmission system.

Badger Coulee Project Description: The Badger Coulee project consists of approximately 150 miles of new single- circuit, 345 kV transmission line from La Crosse into the greater Madison area of Wisconsin.

Project Cost: Approximately $425 million.

Project Status: Following public input, ATC tentatively plans to file an application with the Public Service Commission of Wisconsin (PSCW) in 2013. If approved by the PSCW, construction of the new line would begin in 2016 to meet an in service date of 2017.

Edison Electric Institute 9 Transmission Projects: At A Glance — American Transmission Company (ATC)

Project Investment Partners: None. Cost sharing as a Midwest Independent System Operator (MISO) Multi-Value Project (MVP).

Project Benefits: This project is a multiple benefits project providing economic, reliability and public policy benefits to ATC, its customers and the MISO region. Economic benefits have been observed from several varying futures that were analyzed demonstrating economic benefits in every future. Reliability benefits include second contingency voltage collapse avoidance, single contingency voltage support and thermal relief, improved generation stability response, improved import capability and potential removal of special protection schemes. Public policy benefits include allowing more import of higher capacity wind. All of these benefits have been monetized and the sum of the benefits exceeds the cost of the project in six of six futures, with MISO MVP cost sharing. MISO regional benefits include providing a regional backbone that can be utilized for allowing additional wind generation resources to be interconnected and delivered to the system.

Barnhart - Branch River Project Description: The Barnhart - Branch River project consists of constructing two new 345 kV substations (Barnhart and Branch River) in Wisconsin to provide adequate system stability due to an increase in generation and significant plant modifications at Point Beach Nuclear Plant. The two transmission line options for the project include: Converting approximately 50 miles of existing double-circuit 345/138 kV transmission line to double-circuit 345 kV transmission line in Manitowoc, Sheboygan and eastern Calumet counties and constructing approximately 18 miles of new single-circuit 138 kV transmission line in Sheboygan County, or constructing a new, approximately 40 mile, 345-kV line that links the Branch River and Barnhart facilities.

Project Cost: Approximately $173 million.

Project Status: The Generator Interconnection Agreement was executed with MISO and NextEra in July of 2010. A Certificate of Public Convenience and Ne- cessity (CPCN) from the Public Service Commission of Wisconsin (PSCW) is anticipated to be filed in fall 2012. If approved by the PSCW, construction is expected to begin in fall 2016 with an anticipated in service date of 2018.

Project Investment Partners: None.

Project Benefits: This project will address generation instability issues under outage conditions, provide a wider operating envelope for the local transmission system and the interconnected generators by permitting generating unit operation at unity power factor or under-excited conditions, provide improved maintenance and operations flexibility during planned or unplanned transmission outage conditions by tying together critical transmission elements in strategic locations, and relieve loading under base and contingency conditions on the existing 138 kV and 345 kV transmission lines running from Fox Valley area to the south by providing an additional 345 kV transmission outlet.

10 Edison Electric Institute Transmission Projects: At A Glance — American Transmission Company (ATC)

Cardinal Bluffs Project Description: The Cardinal Bluffs project consists of approximately 125 miles of new single-circuit, 345 kV transmission line from the Dubuque County, Iowa area into Dane County Wisconsin. The new line will interconnect to a new 345 kV substation in Dubuque County, Iowa and continue to the proposed Cardinal 345 kV Substation in the town of Middleton (Dane County, WI).

Project Cost: Approximately $425 million.

Project Status: This project is provisional in status with a projected in service date of 2018.

Project Investment Partners: None. Cost sharing as a Midwest Independent System Operator (MISO) Multi-Value Project (MVP).

Pleasant Prairie - Zion Energy Center Project Description: The Pleasant Prairie - Zion Energy Center project consists of approximately 5.3 miles of new single-circuit, 345 kV transmission line from ATC’s Pleas- ant Prairie Substation in Kenosha, Wisconsin to the Zion Energy Center Substation owned by Commonwealth Edison (ComEd) in northern Illinois.

Project Cost: Approximately $31 million.

Project Status: This project is “Planned” in status. Assuming regulatory approvals in Wisconsin and Illinois, construction is expected to begin in late 2013 with an anticipated in service date of early 2014.

Edison Electric Institute 11 Transmission Projects: At A Glance — American Transmission Company (ATC)

Project Investment Partners: None. Potential for cost sharing as a MISO MVP project.

Project Benefits: The project provides savings for electric utilities and their customers by helping to relieve transmission system congestion throughout the region and enables the most efficient generators to supply power to the energy market in addition to enabling utilities to buy and sell power when it is economic to do so.

The project also improves electric system reliability, locally and regionally by adding an additional high-voltage line to strengthen the interstate transmission connection between Wisconsin and Illinois and enabling better regional access to emergency sources of power generation.

The project is proposed as a MISO MVP because of its contribution in efficiently enabling renewable wind energy to be accessed by loads further east in the MISO and PJM footprints and because it provides economic savings to the MISO Energy Market footprint.

Rockdale - Cardinal Project Description: The Rockdale - Cardinal project consists of approximately 32 miles of new single-circuit, 345 kV transmission line connecting the Rockdale Substation located near Chris- tiana with the Cardinal Substation. Both substations will require some equipment upgrades to support this new line.

Project Cost: Approximately $219 million.

Project Status: This project was approved in the summer of 2009 by the PSCW. Construction is expected to begin in 2011 with an anticipated in service date of June 2013.

Project Investment Partners: None. Received MISO RECB I cost sharing as a Baseline Reliability Project.

Project Benefits: This project will improve reliability for Dane County and in the MISO region. In recent years, Dane County has experienced some of the highest growth rates in the state, both in population and electricity usage. The existing transmission system in and around Dane County brings power in from outside the county to meet the needs for electricity. However, the system is operating at its limits and additional transmission lines are needed to keep pace with growing demand.

12 Edison Electric Institute Transmission Projects: At A Glance — American Transmission Company (ATC)

Smart Grid Investment Grant Projects Project Description: The Smart Grid Investment Grant Projects consist of constructing approximately 65 miles of additional fiber optic network on ATC facilities and the installation of 48 Phasor Measurement Unit’s (PMU).

Project Cost: Approximately $25.4 million.

Project Status: ATC has negotiated a contract with the U.S. Department of Energy (DOE) that outlines reporting requirements and benefit documentation, among other metrics; the agreement was signed by the CEO in April 2010. Preliminary design work has started along with procurement of fiber optic communication equipment. The program of work is targeted to be completed by end of 2012.

Project Investment Partners: The U.S. DOE and the Department of Treasury, through the American Recovery and Reinvestment Act (ARRA).

Project Benefits: This project was developed to enhance communication reliability and data gathering capability.

Straits Flow Control Project Description: The Straits Flow Control project consists of installing flow control devices such as back-to-back HVDC controls connected in series with the Straits - McGulpin 138 kV lines in the eastern portion of the Upper Peninsula of Michigan. This alternative may require the installation of terminal equipment to connect the devices with the 138 kV circuits and provide adequate protection.

Project Cost: Approximately $90 million.

Project Status: Construction is expected to begin in 2012 with an anticipated in service date of August 2014.

Project Investment Partners: None.

Project Benefits: Power flow control in the eastern Upper Peninsula will adjust flows to more man- ageable levels, reduce system losses, improve power quality and reliability of service for local customers, and maintain reliability during maintenance work. This project is designed to protect the Upper Peninsula system from heavy flows both east to west and west to east as system flows change and new generation is developed in the Lower Peninsula. This project also has the potential to support renewable energy in the Upper Peninsula.

Edison Electric Institute 13 Duke-American Transmission Company (DATC)

Company Background • On April 13, 2011 Duke Energy and American Transmission Co. announced the creation of Duke-American Transmission Co., a joint venture that will build, own and operate new electric transmission infrastructure in North America. • DATC has proposed a portfolio of transmission projects that include seven new transmission line projects in five Midwestern states. These projects fill performance gaps in the existing transmission grid such as improved electric system reliability, market efficiency, economic benefits to local utilities and increased delivery of high-quality renewable resources.

DATC Project 1 Project Description: DATC Project 1 consists of 92 miles of 345 kV transmission lines and a 15 miles 230 kV transmission line. The project will span across western Indiana from Reynolds substation to Qualitech substation.

Project Cost: Approximately $222 million.

Project Status: DATC Project 1 is proposed and targeted for Appendix A in the 2012 MISO MTEP. An anticipated in service date of 2016 has been identified for this project.

Project Investment Partners: All DATC projects will be jointly owned by Duke Energy and American Transmission Company LLC.

Project Benefits: The project provides multiple benefits including system reliability, market efficiency, economic benefits to local utilities and it enables increased delivery of high-quality renewable resources.

14 Edison Electric Institute Transmission Projects: At A Glance — Duke-American Transmission Company (DATC)

DATC Project 2 Project Description: DATC Project 2 consists of 42 miles of 345 kV double circuit transmission lines connecting to Tazewell and Brokaw substations in Central Illinois, an 117 mile 500 kV HVDC transmission line and 2 HVDC termi- nals. The project will span from central Illinois to western Indiana.

Project Cost: Approximately $831 million.

Project Status: DATC Project 2 is proposed and targeted for Appendix B in the 2012 MISO MTEP. An anticipated in service date of 2017 has been identified for this project.

Project Investment Partners: All DATC projects will be jointly owned by Duke Energy and Ameri- can Transmission Company LLC.

Project Benefits: The project provides multiple benefits including system reliability, market efficiency, economic benefits to local utilities and it enables increased delivery of high-quality renewable resources. Furthermore, DATC Project 2 uses advanced technology for improved system control and efficiency which will create a bypass for chronically congested lines south of Chicago.

DATC Project 3 Project Description: DATC Project 3 consists of 61 miles of single circuit 345 kV transmission lines, 9 miles of double circuit 345 kV transmission lines and 1 new substation. The project will span from northeastern Illinois to the Burr Oak substation in northwestern Indiana.

Project Cost: Approximately $120 million.

Project Status: DATC Project 3 is proposed and targeted for Appendix A in the 2012 MISO MTEP. An anticipated in service date of 2016 has been identified for this project.

Project Investment Partners: All DATC projects will be jointly owned by Duke Energy and American Transmission Company LLC.

Project Benefits: The project provides multiple benefits including system reliability, market efficiency, economic benefits to local utilities and it enables increased delivery of high-quality renewable resources.

Edison Electric Institute 15 Transmission Projects: At A Glance — Duke-American Transmission Company (DATC) DATC Project 4 Project Description: DATC Project 4 consists of 147 miles of double circuit 345 kV transmission lines, 99 miles of single circuit 345 kV transmission lines, 15 miles of single circuit 161 kV transmission lines, a 435 mile 500 kV HVDC transmission line, a new HVDC terminal and 5 new AC substations. The project will span from northwestern Iowa to Central Illinois.

Project Cost: Approximately $2 billion.

Project Status: DATC Project 4 is proposed and targeted for Appendix B in the 2012 MISO MTEP. An anticipated in service date of 2018 has been identified for this project.

Project Investment Partners: All DATC projects will be jointly owned by Duke Energy and Ameri- can Transmission Company LLC.

Project Benefits: The project provides multiple benefits including system reliability, market efficiency, economic benefits to local utilities and it enables increased delivery of high-quality renewable resources. Furthermore, DATC Project 4 uses advanced technology for improved system control and efficiency.

DATC Project 5 Project Description: DATC Project will consist of 280 miles of double circuit 345 kV transmission lines, 36 miles of single circuit 345 kV transmission lines and a 765-345 kV transformer. The project will span from the Gwynneville substation in central Indiana to the Star substation in northeastern Ohio. DATC is also considering an alternative endpoint for this project at Beatty substation in Central Ohio. This option would require 145 miles of double circuit 345 kV transmission lines instead of 280 miles.

Project Cost: Approximately $766 million for the Star endpoint or $472 million dollars for the Beatty endpoint.

Project Status: DATC Project 5 is proposed and targeted for Appendix B in the 2012 MISO MTEP. An anticipated in service date of 2018 has been identified for this project.

Project Investment Partners: All DATC projects will be jointly owned by Duke Energy and Ameri- can Transmission Company LLC.

16 Edison Electric Institute Transmission Projects: At A Glance — Duke-American Transmission Company (DATC)

DATC Project 6 Project Description: DATC Project 6 will consist of 124 miles of double circuit 345 kV transmission lines and a 94 mile single circuit 345 kV transmission line. The project will span from the Cardinal substation in south-central Wiscon- sin to the new DATC HVDC terminal in central Illinois.

Project Cost: Approximately $444 million.

Project Status: DATC Project 6 is proposed and targeted for Appendix B in the 2012 MISO MTEP. The project will be completed in 2 sections with the first half scheduled to go in service in 2018 and the second half scheduled to go in service in 2021.

Project Investment Partners: All DATC projects will be jointly owned by Duke Energy and American Transmission Company LLC.

DATC Project 7 Project Description: DATC Project 7 will consist of a 55 mile single circuit 345 kV line. The project will span from near the Paddock substation in southeastern Wisconsin to the Pleasant Valley substation in northeastern Illinois.

Project Cost: Approximately $111 million.

Project Status: DATC Project 7 is proposed and targeted for Appendix A in the 2012 MISO MTEP. An anticipated in service date of 2016 has been identified for this project.

Project Investment Partners: All DATC projects will be jointly owned by Duke Energy and American Transmission Company LLC.

Edison Electric Institute 17 Transmission Projects: At A Glance — Duke-American Transmission Company (DATC)

Zephyr Power Transmission Project Project Description: The Zephyr Power Trans- mission Project is a 950-mile 500kV High-voltage direct current line. The line will have a 3,000 MW capacity. The Zephyr project would originate in Chugwater, Wyoming and would terminate In the Eldorado Valley just south of Las Vegas.

Project Cost: Approximately $3.5 billion.

Project Status: The Zephyr Power Transmission Project is proposed with an anticipated in service date of 2020.

Project Investment Partners: All DATC projects will be jointly owned by Duke Energy and Ameri- can Transmission Company LLC.

Project Benefits: DATC’s Zephyr project creates a highly efficient and strategic connection between the wind-rich areas of Wyoming and electricity load centers in California and the southwestern U.S.

18 Edison Electric Institute Arizona Public Service (APS)

Company Background: • APS delivers electricity to more than one million customers in 11 of Arizona’s 15 counties. • System-wide, there are approximately 2,649 circuit miles of 230 kV and above high-voltage transmission lines that APS operates and either wholly or partially owns. • Between 2001 and 2010 APS has invested approximately $1,094 million into its transmission system.

Palo Verde Hub - North Gila 500 kV Project Project Description: The Palo Verde Hub - North Gila 500 kV Project consists of approximately 115 miles of new single-circuit, 500 kV transmission line between the Palo Verde Hub (the area around the Palo Verde Nuclear Gen- erating Station) and the existing North Gila Substation (northeast of Yuma). The line will be built on tubular or lattice tower structures 130- 150 feet high, spaced approximately 600-1,800 feet apart.

Project Cost: Approximately $300 million.

Project Status: The Arizona Corporation Com- mission (ACC) granted APS a Certificate of En- vironmental Compatibility (CEC) on January 23, 2008 and the project has an anticipated in service date of 2015.

Project Investment Partners: None.

Project Benefits: This project will provide the electrical transmission infrastructure to import power into the high-growth Yuma area from additional generation resources around the Palo Verde Hub. The project will improve the reliability of the APS system in the Yuma area by providing an additional high-voltage transmission source to the region. The project will also provide Arizona load serving entities access to geothermal and solar renewable resources in the Imperial Valley area of California. The project will also help the development of new solar generation located along the corridor where interconnection requests have been received.

Edison Electric Institute 19 Transmission Projects: At A Glance — Arizona Public Service (APS)

Palo Verde Substation - Delaney Substation - Sun Valley Substation - Morgan Substation - Pinnacle Peak Substation 500 kV Projects Project Description: The Palo Verde Substation - Delaney Substation - Sun Valley Substation - Morgan Substation - Pinnacle Peak Substation 500 kV Projects consist of approximately 110 miles of new 500 kV transmission line connecting southwest Phoenix to northeast Phoenix. The project will consist of four segments: Palo Verde Substation to Delaney Substation; Delaney Substation to Sun Valley Substation; Sun Valley Substation to Morgan Substation; and Morgan Substation to Pinnacle Peak Substation.

Project Cost: Approximately $700 million.

Project Status: The ACC granted APS a CEC for the Palo Verde Substation to Delaney Substation to Sun Valley Substation 500 kV Transmission Project on August 17, 2005. The project is planned to be completed and operational by the summer of 2013. The Sun Valley to Morgan 500 kV Transmission Line Project is anticipated to be in service by 2016. A CEC for the Sun Valley to Morgan Project was granted by the ACC on March 17, 2009. The Morgan to Pinnacle Peak 500/230 kV Transmission Project was placed into service in October 2010 and the ACC granted APS a CEC on February 13, 2007.

Project Investment Partners: Salt River Project and Central Arizona Water Conservation District.

Project Benefits: This project will strengthen the entire Arizona and APS transmission system by providing an additional high-voltage transmission source to the Phoenix Metropolitan area, allowing the import of an additional 1,000 MWs of power from generating sources at, or around, the Palo Verde Hub. The project will connect three major transmission systems: the Navajo South system; the Palo Verde system; and the Four Corners system. The project will also strengthen the transmission system throughout the Phoenix Metropolitan area. The project will enable the development of new large-scale solar generation projects in the area.

20 Edison Electric Institute Baltimore Gas and Electric (BGE)

Company Background: • BGE is a subsidiary of Exelon Corporation serving 1.2 million customers in a 2,300 square-mile area encompassing Baltimore City and all or part of ten Central Maryland counties. • BGE is a member of the PJM Interconnection, LLC. • BGE owns and operates over 1,290 circuit miles of transmission lines. • Between 2001 and 2010 BGE has invested approximately $342 million into its transmission system.

Graceton - Raphael Road 230 kV Circuit Project Description: The Graceton - Raphael Road 230 kV Circuit project consists of rebuilding a single-circuit, 230 kV transmission line into a double-circuit transmission line in two stages: Graceton - Bagley and Bagley - Raphael Rd.

Project Cost: Approximately $57 million.

Project Status: This project is currently in the engineering and planning stage. The in service date is anticipated to be June 2015 (Graceton-Bagley) and June 2016 (Bagley- Raphael Rd).

Project Investment Partners: None.

Project Benefits: This project maintains system reliability by avoiding NERC N-1-1 reliability criteria violations.

Edison Electric Institute 21 Transmission Projects: At A Glance — Baltimore Gas and Electric (BGE)

Emory Grove 500/230 kV Station Project Description: The Emory Grove 500/230 kV Station project consists of constructing the 500/230 kV Emory Grove Station with a 500 kV double-breaker configuration by tapping the Conastone - Brighton 500 kV line and Conas- tone -Northwest 230 kV line. The project also rebuilds the line along the Emory Grove to Northwest circuits to separate pole-lines.

Project Cost: Approximately $124 million.

Project Status: This project was identified during RTEPP. It is still in the planning stages with an anticipated in service date of June 1, 2017.

Project Investment Partners: None.

Project Benefits: This project maintains system reliability by avoiding NERC N-1-1 reliability criteria violations.

22 Edison Electric Institute COMED

Company Description: • Commonwealth Edison Company, perhaps better known as ComEd, is a unit of Chicago-based Exelon Corporation (NYSE: EXC). Exelon is one of the nation’s largest electric utilities, with approximately 5.4 million customers. ComEd provides service to approximately 3.8 million customers across Northern Illinois, or 70 percent of the state’s population. • ComEd owns and operates a system of over 5000 miles of transmission lines consisting of voltages of 138 kV, 345 kV, and 765 kV, and has a peak summer load of more than 23,700 MW. • Exelon and ComEd actively participate in the Eastern Interconnection Planning Collaborative (EIPC) and the PJM Regional Transmission Planning Process

Chicago Southern Business District Fisk 345 kV Project Project Description: The Chicago South- ern Business District Fisk 345 kV Project consists of constructing a new 345 kV Gas Insulated Switchgear (GIS) station and two 345-to138 kV autotransformers at the existing Fisk Station (currently 138 kV only). In addition, approximately five miles of new overhead 345 kV transmission on existing double-circuit towers between the Crawford and Fisk substations and approximately two miles of underground 345 kV XLPE cable in existing duct packages between the Fisk and Taylor substations will be installed. Two 115 MVAr, 138 kV bus capacitor banks will also be installed at the Fisk Station.

Project Cost: Approximately $96 Million.

Project Status: The project was completed in November 2011.

Project Investment Partners: None.

Project Benefits: This project will upgrade the existing capacity the 345 kV system within the City of Chicago and enhance reliability.

FERC’s Transmission Rate Incentives Policy: None.

Edison Electric Institute 23 Transmission Projects: At A Glance — COMED

Chicago Southern Business District Burnham-Taylor 345 kV Project Project Description: The Chicago Southern Business District Burnham-Taylor 345 kV Project consists of constructing approximately six miles of 345 kV XLPE cable in new duct packages (two cables per phase) between the Garfield and Taylor substations. The existing two High Pressure Fluid Filled (HPFF) cables will be reconfigured to a single circuit and substation equipment will be upgraded to accommodate the changes.

Project Cost: Approximately $121 Million.

Project Status: Pending approval. Expected to be complete in June 2014.

Project Investment Partners: None.

Project Benefits: This project will upgrade the existing capacity the 345 kV system within the City of Chicago and enhance reliability.

FERC’s Transmission Rate Incentives Policy: None.

24 Edison Electric Institute Consolidated Edison, Inc. (Con Edison)

Company Background: • Con Edison’s regulated electric business consists of Consolidated Edison Company of New York (CECONY) and Orange & Rockland Utilities (O&R). • CECONY provides electric service to approximately 3.3 million customers in New York City and Westchester County. • O&R provides electric service to 300,000 customers in southeastern New York and adjacent areas of northern New Jersey and eastern Pennsylvania. • CECONY’s transmission infrastructure consists of approximately 720 circuit miles of underground electric transmission/sub-transmission and approximately 438 circuit miles of overhead electric transmission. • O&R’s transmission consists of approximately 456 circuit miles of overhead electric transmission and approximately 26 circuit miles of underground electric transmission. • Between 2001 and 2010 Con Edison has invested over $1.8 billion into its transmission system.

Transmission Smart Grid Initiatives:

NYISO Smart Grid Project Project Description: The New York Independent System Operator (NYISO) has been awarded funds through the American Recovery and Reinvestment Act (ARRA) to make New York’s grid smarter and more efficient through the deployment of Phasor Measurement Unit (PMU) technology and capacitor banks. The NYISO is partnering with all eight New York transmission owners to implement this statewide program. CECONY and O&R will install 14 PMUs and two capacitor banks. The PMU installation provides for the extension of CECONY’s and O&R’s existing fiber optic network to new locations to interconnect future PMU installations in their service territories.

Project Cost: NYISO’s project cost will total approximately $75 million, with $37 million awarded by the U.S. Department of Energy. CECONY and O&R have an estimated cost of $9 million for deployment of the technology.

Project Status: Through 2011 CECONY and O&R had invested $1.3 million. Con Edison’s engineering design has been completed, field construction is underway, and PMU installation is projected to be completed by the third quarter of 2012. Additionally, construction at the capacitor bank locations is underway with energization of the first capacitor location targeted for the third quarter of 2012.

Project Investment Partners: NYISO and U.S. Department of Energy.

Edison Electric Institute 25 Transmission Projects: At A Glance — Consolidated Edison, Inc. (Con Edison)

Project Benefits: The deployment of PMUs will enable faster responses to grid events and enhanced mitigation strategies of potential outages. The addition of capacitor banks will optimize the voltage profile on the power system in the vicinity of each installation, and enhance reliability by strengthening the system’s ability to withstand and recover from disturbances that result in voltage dips or low- voltage conditions. By improving the power factor at an area substation, the capacitor banks will also increase the capability of that substation to carry load, thereby allowing for load growth further into the future.

PJM SynchroPhasor Smart Grid Project Project Description: This project will deploy synchrophasor technology and PMUs throughout the PJM system. It will provide the foundational infrastructure upon which additional PMUs, PDCs, and other advanced applications can be deployed. Project participants include twelve of the PJM Trans- mission Owners, including O&R, who will install a PMU at the Mahwah substation.

Project Cost: PJM’s project cost will total almost $28 million with approximately $14 million provided by the U.S. Department of Energy’s matching grant. O&R will receive approximately $150,000 from the U.S. Department of Energy’s grant.

Project Status: O&R’s PMU has been installed. Final communications setup and testing will occur in early 2012.

Project Investment Partners: PJM and U.S. Department of Energy.

Project Benefits:PJM’s initiative will enable increased visibility and strengthen reliability on the transmission system. The project will also provide the foundational infrastructure upon which additional PMUs, PDCs, and future advanced applications may be developed.

26 Edison Electric Institute Transmission Projects: At A Glance — Consolidated Edison, Inc. (Con Edison)

M29 Transmission Project Project Description: The M29 Transmission Project consists of a new 9.5 mile underground 345 kV high-pressure fluid filled (HPFF pipe-type) transmission line from the existing Sprain Brook Substation in the City of Yonkers to the new Academy Substation in Manhattan. The feeder has been installed beneath the Harlem River via a tunnel. The new Academy Substation is an indoor, gas-insulated (GIS) type station.

Project Cost: Approximately $468 million.

Project Status: Construction of the line is complete and the line became operational in February 2011.

Project Investment Partners: None.

Project Benefits: The installation of the M29 Transmission Line and associated upgrades at the existing Sprain Brook Substation and the new Academy Substation allows CECONY to meet expected electrical load growth in the East 179th Street load area, which includes portions of the Bronx and upper Manhattan. The project also improves reliability on the Con Edison electric transmission and distribution system. Construction of the project relieves the first contingency overload conditions that were identified in CECONY’s Ten-Year Load Relief Forecast for the Sherman Creek Substation serving the Bronx and upper Manhattan. The project also provides electric system reliability benefits to portions of Westchester County within Con Edison’s Dunwoodie North load area. Additionally, the project increases Con Edison’s ability to import power into New York City by about 350 MWs, thereby allowing the increased delivery of economical power to its New York City customers.

Edison Electric Institute 27 Entergy Corporation

Company Background: • Entergy and its six Operating Companies, Entergy Arkansas, Inc., Entergy Gulf States Louisiana, LLC, Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, Inc., and Entergy Texas, Inc., deliver electricity to 2.7 million utility customers in four states. • Entergy’s service territory covers more than 114,000 square-miles in Arkansas, Louisiana, Mississippi, and Texas. • System-wide there are more than 15,800 circuit miles of transmission lines. • Between 2002 and 2010, the Entergy Operating Companies have invested approximately $1.86 billion into the transmission system. • Between 2011 and 2014, the Entergy Operating Companies expect to invest approximately $1.81 billion into the transmission system.

Holland Bottoms 500 kV Project Project Description: The Holland Bottoms 500 kV project, located northeast of Little Rock, Ar- kansas, includes the construction of a new 500- 161/115 kV substation with a 500-115 kV and a 500-161 kV autotransformer, each with a rating of 600 MVA. The project also includes the construction of a new 20-mile 161 kV transmission line rated 558 MVA.

Project Cost: Approximately $72 million.

Project Status: Phase 1 of the project, installation of a new 500-115 kV autotransformer, was completed January 6, 2012. Phase 2 of the project, which is the final phase of the project, is scheduled to be completed in the summer of 2012.

Project Investment Partners: None.

Project Benefits: This project is intended to address future load growth and reliability needs in the northeast Little Rock area.

28 Edison Electric Institute Transmission Projects: At A Glance — Entergy Corporation

SELA Project Phase 2 and Phase 3 Project Description: The SELA Project Phase 2 and Phase 3, located in southeast Louisiana, involves the construction of a new 230 kV transmission line connecting Peters Road 230 kV substation, a new Oakville 230 kV distribution substation, and Alliance substation, which is located in lower Plaquemines Parish. The project also includes the installation of a 230-115 kV autotransformer at Alliance.

Project Cost: Approximately $58 million.

Project Status: The project is currently under construction and is expected to be completed in early 2013.

Project Investment Partners: None.

Project Benefits: This project is to intended to address future load growth and reliability needs in the southeast Louisiana area.

Ouachita Projects Project Description: The Ouachita portfolio of projects, located in north Louisiana, includes the construction of multiple 115 kV transmission line upgrades and the replacement of an existing 500-115 kV 500 MVA autotransformer at Sterlington substation with a new 750 MVA autotransformer. The 500 MVA autotransformer will be relocated to the Baxter Wilson EHV substation (Vicksburg, Missis- sippi area) to provide a second 500-115 kV autotransformer source.

Project Cost: Approximately $61 million.

Project Status: The project is currently under construction and is expected to be completed in 2013.

Project Investment Partners: None.

Project Benefits: These transmission improvements are needed for the deliverability of designated network resources in north Louisiana.

Edison Electric Institute 29 Transmission Projects: At A Glance — Entergy Corporation

Acadiana Load Pocket Project Project Description: The Acadiana Load Pocket Project is a joint project between Entergy Gulf States Louisiana, LLC, Cleco Corporation, and Lafayette Utilities System to develop a new 230 kV overlay in the Acadiana area of south Loui- siana. The project includes the addition of a 500-230 kV autotransformer at the new Cleco Rork 500 kV substation, construction of a new 230 kV line from Rork to Sellers Road substation to Segura substation, and installation of a new 230-138 kV autotransformer at Segura. It also includes the addition of a second 500-230 kV autotransformer at Wells substation, construction of a new 230 kV line from Wells to Labbe substation, construction of a new 230 kV line from Labbe to Sellers Road to Meaux substation, installation of a 230-138 kV autotransformer at Meaux, and construction of a second Labbe to Bonin 230 kV line.

Project Cost: Approximately $200 million.

Project Status: Phase 1 of the project was completed in 2011. Phase 2, which is the final phase of the project, is currently under construction and projected to be completed in the summer of 2012.

Project Investment Partners: Entergy Gulf States Louisiana, LLC, Cleco Corporation, and Lafayette Utilities System.

Project Benefits: This portfolio of projects addresses both reliability and economic needs identified in the Acadiana Load Pocket of south Louisiana.

Orange County Project Project Description: The Orange County project is a long term project to be located north of the Beaumont/Port Arthur area in Texas. The project includes construction of a new 230 kV switching station referred to as Chisolm Road, construction of a new 230 kV line from Hartburg to Chisolm Road, and cutting-in of the existing McLewis to Helbig and Georgetown to Sabine 230 kV lines. The project also includes the installation of a second 500-230 kV autotransformer at Hartburg.

Project Cost: Approximately $65 million.

Project Status: The project is expected to be in service in the summer of 2017.

30 Edison Electric Institute Transmission Projects: At A Glance — Entergy Corporation

Project Investment Partners: None.

Project Benefits: This project is intended to address future load growth and reliability needs in the east Texas area north of Beaumont.

Loblolly to Hammond Project Project Description: The Loblolly to Hammond project, located to the east of Baton Rouge, Loui- siana, includes the construction of a new 230 kV transmission line from Coly to Hammond, construction of a new 69 kV transmission line from Coly to Loblolly (constructed for 230 kV), and removal of the 69 kV Coly to Loblolly Tap.

Project Cost: Approximately $45.5 million.

Project Status: Completed December 16, 2011.

Project Investment Partners: None.

Project Benefits: This project was constructed to reduce loading on the existing system and improve load serving capability north of Lake Pontchartrain and into south Mississippi.

McAdams Area Upgrade Project Project Description: The McAdams Area Upgrade Project, located in central Mississippi, included the addition of a 500-115 kV Auto- transformer at McAdams substation and an upgrade to the McAdams to Pickens 230 kV transmission line.

Project Cost: Approximately $26 million.

Project Status: Completed June 1, 2011.

Project Investment Partners: None.

Project Benefits: The additional facilities were installed to provide voltage support to the Canton and Madison regions of Mississippi and to increase the deliverability of existing network resources in the region. Additionally, the project eliminated congestion that had been prevalent on the existing McAdams 500-115 kV autotransformer.

Edison Electric Institute 31 FIRSTEnergy

Company Background: • FirstEnergy is a diversified energy company dedicated to safety, reliability and operational excellence. Headquartered in Akron, Ohio, its ten electric distribution companies comprise one of the nation’s largest investor-owned electric systems, serving six million customers in the Midwest and Mid-Atlantic regions. Its diverse generating fleet features non-emitting nuclear, scrubbed baseload coal, natural gas, and pumped-storage hydro and other renewables, and has a total generating capacity of nearly 23,000 megawatts. The company has $48 billion in assets and $16 billion in annual revenues. • FirstEnergy’s transmission operations include 20,000 miles of high-voltage lines and three regional transmission operation centers. Stretching from the Ohio-Indiana border to the New Jersey shore, the company operates a vast infrastructure of more than 194,000 miles of distribution lines. During the 2001-2010 period, FirstEnergy added $1.2 billion in transmission facilities, and about $1 billion in 2011 with the completion of the TRAIL and other projects. Potomac – Appalachian Transmission Highline (PATH) Project

Company Background: • Note: On February 28, 2011, FirstEnergy and American Electric Power announced their affiliates filed to withdraw their applications for state regulatory approval of the PATH Project following an announcement by regional grid operator PJM Interconnection that the project had been suspended. • In September 2007, the former Allegheny Energy and American Electric Power (AEP) formed a joint venture to build the PATH Project to address anticipated reliability violations in the PJM Region. Most of the PATH Project in West Virginia will be owned by PATH West Virginia Transmission Company, LLC (PATH-WV), which is controlled by FirstEnergy and AEP. The remainder of the PATH Project in West Virginia will be owned by PATH Allegheny Transmission Company, LLC (PATH-Allegheny), which is controlled by FirstEnergy. In Virginia, the project will be owned by a subsidiary of PATH-Allegheny. In Maryland, the project will be owned by PATH Allegheny Maryland Transmission Company, LLC, which is owned by PATH-Allegheny and The Potomac Edison Company, also a part of FirstEnergy.

32 Edison Electric Institute Transmission Projects: At A Glance — FIRSTEnergy

PATH 765 kV Project Project Description: The PATH 765 kV Project consists of approximately 275 miles of new single-circuit, 765 kV transmission line from AEP’s Amos Substa- tion in Putnam County, West Virginia, through the new Welton Spring Substation in Hardy County, West Virginia, and continuing through Virginia to the new Kemptown Substation in Frederick County, Maryland. The project includes construction and modifications to the Amos Substation and construction of the two new substations. The project will use advanced control technology in substations, which will enhance its reliability and efficiency.

The Federal Energy Regulatory Commission has granted the following rate incentives for the project: an incentive return on equity for new transmission; recovery of a return on 100 percent of prudently incurred transmission related Construction Work in Progress prior to the project’s in service date; recovery of all startup business and administrative costs incurred prior to the time rates go into effect; and authorization to recover all prudently incurred development and construction costs if the PATH Project is abandoned as a result of factors beyond the control of PATH-WV or PATH- Allegheny or their parents.

Project Status: While annual studies since 2007 have reaffirmed the need for the project, PJM’s latest analyses indicate the required in service date for the project has moved well into the future. PJM has requested that the company suspend further development of the project while they conduct a more rigorous analysis of the need for the project. In response, the company has filed to withdraw its siting applications filed with the West Virginia Public Service Commission, Maryland Public Service Com- mission and the Virginia State Corporation Commission.

Project Investment Partners: A EP.

Project Benefits: The PATH Project will maintain the reliability of the power supply system in the PJM Region, allow greater flexibility in scheduling outages for maintenance of critical transmission infrastructure, provide system loss savings and loss savings from advanced conductors to reduce energy needs in the PJM Region by 600 GWh per year, offsetting more than 300,000 metric tons of CO2 annually. The project also will create jobs in engineering, surveying, construction and related industries.

Edison Electric Institute 33 Transmission Projects: At A Glance — FIRSTEnergy Trans – Allegheny Interstate Line Company (TrAILCo)

Company Background: • TrAILCo is part of FirstEnergy.

Trans – Allegheny Interstate Line (TRAIL) Project Project Description: The TRAIL Project consists of 153 miles of new single-circuit, 500 kV transmission line in the former Allegheny Power Transmission Zone of PJM, from the new 502 Junction Substation in southwestern Pennsylva- nia to existing substations at Mt. Storm, West Virginia, and Middletown, Virginia, to a point 16 miles southeast of Middletown, Virginia. The line continues east for another 65 miles in the transmission zones of the former Allegheny Pow- er and Dominion Virginia Power to Dominion Virginia Power’s Loudoun Substation. Dominion Virginia Power constructed this continuation of the line, with TrAILCo and Dominion Virginia Power sharing 50 percent ownership each in approximately 30 miles of this portion of the line. The portion of the line owned by TrAILCo is known as the Trans-Allegheny Interstate Line.

Project Cost: Approximately $960 million (excludes Dominion Virginia Power portion of the line).

Project Status: The line was placed in service in May 2011.

Project Investment Partners: TrAILCo financed the portion of the line it constructed, as well as its 50 percent interest in the portion of the line constructed by Dominion Virginia Power.

Project Benefits: The project was designated for reliability purposes. The project significantly strengthens the existing PJM Transmission System infrastructure by relieving loading on several highly congested facilities, alleviating voltage and thermal limitations in the PJM Region and increasing west-to-east transfer capability, making cost-effective generation available to more consumers.

34 Edison Electric Institute ITC Holdings Corp.

Company Background: • ITC Holdings Corp. (NYSE: ITC) is the nation’s largest independent electric transmission company. Based in Novi, Mich., ITC invests in the electric transmission grid to improve system reliability, expand access to markets, lower the overall cost of delivered energy and allow new generating resources to interconnect to its transmission systems. ITC’s regulated operating subsidiaries include ITCTransmission, Michigan Electric Transmission Company (METC), ITC Midwest and ITC Great Plains. Through these subsidiaries, ITC owns and operates high-voltage transmission facilities in Michigan, Iowa, Minnesota, Illinois, Missouri and Kansas, serving a combined peak load exceeding 25,000 megawatts along 15,000 circuit miles of transmission line. Through ITC Grid Development and its subsidiaries, the company also focuses on expansion in areas where significant transmission system improvements are needed. • From the company’s inception in 2003 through Q3 2011, ITC has invested over $2.3 billion in its transmission systems. Green Power Express LP

Company Background: • Green Power Express LP was established in 2009 to plan and construct portions of the Green Power Express (GPE) project. In April 2009, the Federal Energy Regulatory Commission (FERC or Commission) approved the GPE basic rate terms, including a forward looking formula rate with FERC Order 679 incentives for the Green Power Express LP, although there are still outstanding rehearing requests.

Green Power Express Project Description: The Green Power Express is a transmission expansion concept put forward by ITC in 2009 to serve as a catalyst for advancing regional transmission that would facilitate the movement of power from the wind-abundant areas in the Dako- tas, Minnesota and Iowa to Midwest load centers.

Project Cost: Approximately $10 to $12 billion.

Project Status: The Green Power Express is expected to be developed in segments through the regional planning process. Recently, MISO evalu-

Edison Electric Institute 35 Transmission Projects: At A Glance — ITC Holdings Corp.

ated and approved several transmission lines that help to facilitate the Green Power Express concept. Approval of additional future projects will ultimately complete ITC’s vision for this regional transmission proposal.

Project Investment Partners: To be determined.

Project Benefits: The Green Power Express will provide substantial benefits both on a stand-alone basis and as a component of the coordinated development of a national high-voltage backbone transmission system. By providing efficient access to substantial amounts of wind power, in the range of 20 GWs, and permitting that power to be imported from the upper Midwest to population centers in the Midwest. The Green Power Express will support the environmental and policy objectives that are reflected in local or potential national renewable electricity standards while enhancing the competitive regional electric market by increasing supply options and reducing congestion on existing facilities. By collecting wind generation over a significant geographic area, the Green Power Express will enhance reliability by leveling the impacts of localized weather on wind generation availability. GPE is to be geographically situated so that future expansions could be made farther west into the Dakotas to access additional, even more productive wind resource areas. Finally, the Green Power Express was conceptualized as a network of transmission upgrades with appropriate redundancy so that reliability will be maintained.

36 Edison Electric Institute Transmission Projects: At A Glance — ITC Great Plains ITC Great Plains

Company Background: • ITC Great Plains, LLC is a transmission-only utility which seeks to build a more robust electric transmission system providing access to reliable, non-discriminatory, competitive and low-cost energy throughout the Southwest Power Pool region. Based in Topeka, Kansas, ITC Great Plains holds transmission-only utility status in Kansas and Oklahoma, with the authority to construct, own, operate and maintain a high-voltage transmission system. ITC Great Plains is a subsidiary of ITC Grid Development, LLC, a wholly-owned subsidiary of ITC Holdings Corp., the nation’s largest independent electric transmission company. • ITC Great Plains is a member of the Southwest Power Pool(SPP).

Kansas V-Plan Project Description: The Kansas V-Plan project consists of approximately 200 miles of new double-circuit, 345 kV transmission lines designed to connect central and western Kansas. In cooperation with Sunflower Electric Power Corporation and Mid-Kansas Electric Company, ITC Great Plains will design and construct two segments of the V-Plan project totaling approximately 120 miles, from Spearville south to the new Clark County substation, then east to the Thistle substation that ITC will construct east of Medicine Lodge. Prairie Wind Transmission will construct the third section of the line, from Medicine Lodge to a termination point outside Wichita.

Project Cost: Approximately $300 million for ITC Great Plains’ portion.

Project Status: The Kansas V-Plan was approved by the SPP Board of Directors on April 27, 2010. FERC approved the novation agreement on June 24, 2011. The Kansas Corporation Commission (KCC) approved the siting application on July 12, 2011. The project is projected to be in service by late 2014.

Project Benefits: This project will improve electric reliability and enable renewable and other energy developers to tap into the transmission grid, further establishing a competitive energy market in the state. This will contribute to a stronger transmission grid that will benefit the entire region.

Edison Electric Institute 37 Transmission Projects: At A Glance — ITC GREAT PLAINS

KETA Project Project Description: The KETA Project, also known as the Spearville-Axtell transmission line, consists of approximately 225 miles of new 345 kV transmission lines that will run from Spearville, Kansas, north to the Post Rock substation near Hays, then across the Nebraska border to Axtell. The line will be built in three segments: Spearville to Post Rock; Post Rock to the Kansas-Nebraska border; and from the Kansas-Nebraska border to Axtell. ITC will build the first two segments: Spearville to Post Rock; and Post Rock to the Kansas-Nebraska border. The Nebraska Public Power District is responsible for building the third segment, from the Kansas-Nebraska border to Axtell.

Project Cost: The estimated cost for the ITC portion of the KETA project is approximately $175 million.

Project Status: ITC Great Plains broke ground Novem- ber 4, 2010 on the first phase of the KETA project. ITC received Phase II route approval from the KCC on June 30, 2010. Rights-of-way (ROW) acquisition for Phase II of the project, from Post Rock to the Kansas-Nebraska border, is complete, and construction is underway. Phase I of the project is projected to be in service in mid-2012. Phase II is scheduled to be in service in mid-2013.

Project Benefits: The Kansas Electric Transmission Authority (KETA) identified the Spearville- Axtell transmission line as a project that would bring significant economic and reliability benefits to Kansas and the regional transmission grid. The KETA Project will provide access to more reliable, efficient and affordable electricity in Kansas and the Midwest. It will facilitate the development and export of wind generation from central and western Kansas and serve as a critical link for Kansas to regain its position as a net exporter of energy. It also will ease congestion across the transmission network, addressing the lack of high-voltage transmission lines in central and western Kansas which causes inefficiencies in the grid and does not allow power to flow in the most efficient manner.

38 Edison Electric Institute Transmission Projects: At A Glance — ITC GREAT PLAINS

Oklahoma Hugo - Valliant Project Project Description: The Oklahoma Hugo - Valliant Project consists of approximately 18 miles of a new 345 kV transmission line that will run from a new substation ITC is building near the Western Farmers Electric Co- operative Hugo Power Plant, west of Fort Towson, to an existing substation southeast of Valliant.

Project Cost: Approximately $35 million.

Project Status: Construction began in the spring of 2011 with a target in-service date of Q2 2012.

Project Investment Partners: None.

Project Benefits: This project is intended to reduce system congestion and inefficiency, meet increasing service requests for transmission and help provide access to more dependable, efficient and affordable electricity in southeastern Oklahoma and throughout the state.

Edison Electric Institute 39 Transmission Projects: At A Glance — ITC MIDWEST ITC Midwest

Company Background: • ITC Midwest, LLC is a wholly-owned subsidiary of ITC Holdings Corp., the nation’s largest independent electric transmission company. Based in Cedar Rapids, Iowa, ITC Midwest operates more than 6,800 circuit miles of transmission lines in Iowa, Minnesota, Illinois and Missouri. ITC Midwest also maintains operating locations in Dubuque, Iowa City and Perry, Iowa; and Albert Lea and Lakefield, Minnesota. • ITC Midwest is a member of the Midwest Independent Transmission System Operator (MISO).

Salem-Hazleton Line Project Description: The 345-kilovolt (kV) Salem-Hazleton line developed by ITC Midwest will address long-standing reliability and system congestion issues in northeast Iowa. The line will extend approximately 81 miles from the existing ITC Midwest Hazleton substation in Buchanan County to the company’s existing Salem substation in Dubuque County. Approximately 54 miles of the new line will be double-circuited with an existing 161 kV line west of the Hazleton substation. The Salem-Hazleton line will complete a loop of more than 300 miles of 345 kV lines in eastern Iowa to help ensure electric reliability and reduce system congestion.

Project Cost: ITC estimated the line cost and costs for upgrades at termination substations at approximately $119 million.

Project Status: Following more than three years of RTO and regulatory review and approvals, ITC Midwest has begun construction of the line and anticipates completion in the spring of 2013.

Project Benefits: The Salem-Hazleton line is needed to upgrade the electric transmission system in eastern Iowa to more reliably serve customer demand during normal operation and during times when elements of the system are unavailable due to planned or unplanned outages on the system. The Salem-Hazleton Line was studied and supported in the MISO (2006-09) Eastern Iowa Transmission Reliability Study (Eastern Iowa Study) as an efficient and cost-effective solution to correct long- standing reliability problems in eastern Iowa.

40 Edison Electric Institute Transmission Projects: At A Glance — ITC MIDWEST ITC Transmission

Company Background: • International Transmission Company (d/b/a ITCTransmission) is a wholly-owned subsidiary of ITC Holdings Corp., the nation’s largest independent electric transmission company. Based in Novi, Michigan, ITCTransmission owns, operates and maintains approximately 2,800 circuit miles of transmission line in southeast Michigan, serving a population of 5.1 million. • ITCTransmission is a member of MISO.

Michigan Thumb Loop Transmission Project Project Description: The Michigan Thumb Loop Trans- mission Project consists of approximately 140 miles of new double-circuit, 345 kV transmission lines and four new substations that will serve as a “backbone” for wind development located in Michigan’s Thumb region. Additional lines and facilities will be needed in the future as wind generators go into service and connect to the backbone system to fulfill the requirements of the state’s Renewable Portfolio Standard. The system is designed to meet the identified minimum and maximum wind energy potential of the Thumb region (2,367 and 4,236MW respectively) and is capable of supporting a maximum capacity of about 5,000 MW.

Project Cost: Approximately $510 million.

Project Status: MISO has approved the Thumb Loop project as the first Multi-Value Project (MVP) eligible for regional cost sharing as approved by FERC. ITCTransmission secured siting approval from the Michigan Public Service Commission on February 25, 2011. The project will be completed in three phases, targeting completion in 2015. Substation construction and right-of-way acquisition are currently underway. The project will be constructed in stages, with the first segment planned to enter service in late 2013. The remaining stages are targeted for completion by 2015.

Project Benefits: This project will serve as an efficient transmission “backbone” to support wind energy development in the Thumb region in support of Michigan’s Renewable Portfolio Standard. It also will improve reliability in the region.

Edison Electric Institute 41 Transmission Projects: At A Glance — michigan electric transmission company (metc) Michigan Electric Transmission Company (METC)

Company Background: • Michigan Electric Transmission Company, LLC (METC) is a wholly-owned subsidiary of ITC Holdings Corp., the nation’s largest independent electric transmission company. Based in Novi, Michigan, METC owns, operates and maintains approximately 5,500 circuit miles of transmission line in the western and northern portions of Michigan’s Lower Peninsula, serving a population of 4.9 million. • METC is a member of MISO.

G905 Generator Interconnection Project Description: METC is constructing two new substations and making system upgrades to connect a 200 MW wind farm to the transmission system. The project will be built in two phases from mid-2011 through the end of 2012 as the wind farm ramps up production.

Project Cost: Approximately $21 million.

Project Status: Phase one involves construction of a new substation to connect the wind farm to METC’s Tittaba- wassee-Begole 138,000-volt (138kV) line. This work began in June 2011 and was completed in October 2011. The second phase, to be completed by the end of 2012, will include a second new substation, reconstruction of approximately 10.7 miles of the Tittaba- wassee-Begole 138kV line to increase its capacity, and a new double-circuit 138 kV line approximately 2.4 miles long to connect the second substation with METC’s Alma-Summerton 138 kV line.

Project Benefits: The project will transmit approximately 200 megawatts of energy from the wind farm, enough to power an estimated 54,000 homes.

42 Edison Electric Institute Kansas City Power & Light (KCP&L)

Company Background: • Operating from its headquarters in Kansas City, Missouri, KCP&L is a full-service energy provider. • KCP&L services more than 800,000 customers in 47 northwestern Missouri and eastern Kansas counties; a service territory of approximately 18,000 square-miles. • KCP&L owns and operates 6,000 MWs of generating assets. • KCP&L has 2,600 circuit miles of transmission and includes 345kV, 161kV and 69kV transmission voltages. • Between 2001 and 2010 KCP&L has invested approximately $194 million into its transmission system.

Iatan - Nashua 345 kV Transmission Line Project Description: The Iatan - Nashua 345 kV Transmission Line project consists of approximately 30 miles of new 345 kV transmission line from KCP&L’s Iatan Generating Sta- tion to KCP&L’s Nashua Substation in Missouri. This project creates a 345kV connection between the Iatan Substation 345kV lines and an existing Hawthorn - St. Joseph 345kV line that is nearby the 161kV Nashua Substation. A new 345 kV ring bus will be constructed at Nashua Substa- tion.

Project Cost: Approximately $54 million.

Project Status: This project was approved in the summer of 2009 by the Southwest Power Pool (SPP) Board of Directors as part of SPP’s Balanced Portfolio project set. Routing, siting, engineering, materials, and construction processes are currently underway. This project is anticipated to be in service by June 2015.

Project Investment Partners: None.

Project Benefits: This project delivers trade and production cost benefits to the region while reducing transmission congestion constraints.

Edison Electric Institute 43 Transmission Projects: At A Glance — Kansas City Power & Light (KCP&L)

Sibley - Nebraska City 345 kV Transmission Line Project Description: The Sibley - Nebraska City 345 kV Transmission Line project consists of approximately 175 miles of new 345 kV transmission line from KCP&L’s Sibley Generat- ing Station to Omaha Public Power District’s (OPPD) Nebraska City Substation. KCP&L will construct and own 170 miles of the project and OPPD will construct and own five miles of the project. KCP&L will also install a new 345 kV Maryville Substation at a midpoint in the line.

Project Cost: Approximately $404 million, of which approximately $384 million will be KCP&L’s responsibility.

Project Status: This project was approved in June 2010 by the SPP Board of Directors as part of SPP’s Priority Project set. KCP&L and OPPD ac- cepted obligations to construct the project in September 2010. Routing, siting, engineering, materials, and construction processes are currently underway. This project is anticipated to be in service by June 2017.

Project Investment Partners: OPPD.

Project Benefits: This project delivers significant regional trade and production benefits, transmission congestion relief and provides for large-scale wind integration in northwest Missouri.

44 Edison Electric Institute MIDAMERICAN ENERGY HOLDINGS COMPANY

Company Background: • The U.S. subsidiaries of MidAmerican Energy Holdings Company—including MidAmerican Transmission, LLC, MidAmerican Energy Company and PacifiCorp—own and/or operate more than 18,000 miles of transmission and are engaged in significant transmission investment projects, both independently and through subsidiary joint ventures. MidAmerican Energy Company • MidAmerican Energy Company, based in Des Moines, Iowa, is an electric and natural gas utility serving rate- regulated retail customers in Iowa, Illinois, South Dakota and Nebraska, and competitive retail customers in the central and eastern U.S. MidAmerican Energy is a transmission-owning member of MISO and owns an extensive transmission system within the MISO footprint. Additionally, MidAmerican Energy is actively engaged in marketing wholesale electric power in various regions. • As of year-end 2011, MidAmerican Energy provided service to approximately 729,000 electric customers in a 10,600 square mile area. MidAmerican Energy had more than 7,680 megawatts of owned or contracted generating capacity, including approximately 1,878 megawatts of wind- powered generation, and a peak load of 4,752 megawatts. MidAmerican Energy is a public utility within the contemplation of the Federal Power Act, and owns or operates approximately 2,200 miles of transmission facilities.

MidAmerican Energy Expansion Projects: Descriptions of Projects: The MidAmeri- can Energy Expansion Projects are major new transmission facilities to be constructed in Iowa, Illinois and Missouri as an integral part of a portfolio of MISO projects called the 2011 Multi Value Project (MVP) Portfolio. The MidAmeri- can Energy Expansion Projects are characterized as the Obrien County – Webster Project; the Hampton – Blackhawk Project; the Oak Grove – Galesburg project; and MidAmerican Energy’s share of the Ottumwa to Adair project. MidAm- erican Energy’s share of the MidAmerican

Edison Electric Institute 45 Transmission Projects: At A Glance — MIDAMERICAN ENERGY HOLDINGS COMPANY

Energy Expansion Projects are expected to consist of roughly 240 miles of new 345-kV transmission lines and include two new 345-kV substations, significant modifications to four 345-kV substations, and one new 345-161 kV-transformer.

Total Cost of Projects: The MidAmerican Energy Expansion Projects represent approximately $532 million to $572 million in transmission investment.

Status of Projects: The MidAmerican Energy Expansion Projects were approved for construction by the MISO Board of Directors in December 2011. Initial work on the projects has begun with projected in-service dates of the projects from 2015 through 2017.

Project Benefits: The MidAmerican Energy Expansion Projects, as a part of the 2011 MISO MVP Portfolio, are a unique set of transmission projects to be constructed in order to contribute to a wide variety of benefits, including public policy needs, congestion relief and fuel savings, operating reserve margin and system planning reserve margin reductions and transmission line loss reductions. In addition, the projects will enhance wind turbine investments and allow states to meet their renewable portfolio standards.

MidAmerican Transmission, LLC • MidAmerican Transmission, LLC is a wholly owned transmission development company of MidAmerican Energy Holdings Company. MidAmerican Transmission, LLC’s subsidiary joint transmission ventures include: • Electric Transmission Texas, LLC (“ETT”): A joint venture with American Electric Power (“AEP”) established to invest in transmission within the Electric Reliability Council of Texas (“ERCOT”). • Electric Transmission America, LLC (“ETA”): A second joint venture with AEP to identify and invest in high-voltage transmission projects (345 kV or higher) located in North America outside of ERCOT.* ETA joint ventures include: • Prairie Wind Transmission, LLC: A joint venture between ETA and Westar Energy to develop high-voltage transmission in the Southwest Power Pool region. • RITELine Transmission Development, LLC: A joint venture between ETA and Exelon to develop high-voltage transmission projects in the PJM region. • Midwest Power Transmission projects: A joint venture between subsidiaries of MidAmerican Transmission, LLC and ETA to develop high-voltage transmission projects in the MISO region. * See the AEP section for additional information on these joint venture projects.

46 Edison Electric Institute Transmission Projects: At A Glance — MIDAMERICAN ENERGY HOLDINGS COMPANY

Prairie Wind Transmission, LLC R I T E L ine T ransmission

Midwest Power Transmission

Edison Electric Institute 47 Transmission Projects: At A Glance — MIDAMERICAN ENERGY HOLDINGS COMPANY PacifiCorp • PacifiCorp owns and operates one of the largest privately held transmission systems in the U.S., consisting of more than 16,000 circuit miles of transmission lines ranging from 46 kV to 500 kV. • PacifiCorp provides electric service to 1.7 million customers in 750 communities across six western states with a service territory that covers approximately 136,000 square-miles in Oregon, Washington, California, Wyoming, Utah, and Idaho. • PacifiCorp is interconnected with more than 80 generation plants and 13 adjacent control areas at approximately 150 points of interconnection. • To provide electric service to its retail customers PacifiCorp owns or has interest in generation resources directly interconnected to its transmission system, with a system peak capacity of approximately 12,131 MWs. This generation capacity includes a diverse mix of resources including coal, hydro, wind power, natural gas simple cycle and combined cycle combustion turbines, and geothermal.

Energy Gateway Project Description: PacifiCorp’s Energy Gateway transmission plan is a major transmission expansion program announced in May 2007 that will add approximately 2,000 miles of new transmission lines across the West. The project is com- prised of eight segments, the majority of which are categorized as part of Gateway West, Gateway South or Gateway Central (see Energy Gateway map for segment information). Energy Gateway is the largest and most extensive transmission project PacifiCorp has ever undertaken.

Project Cost: Energy Gateway is a multi-year project with an approximate $6 billion investment plan.

Project Status: The first complete segment of Energy Gateway, the Populus to Terminal line, was energized in two phases during 2010. Extending approximately 135 miles from southeast Idaho into northern Utah, the Populus to Terminal line adds a new double-circuit, 345 kV transmission line to the company’s transmission system, and was finished ahead of schedule and within budget. The second segment, Mona to Oquirrh, consists of approximately 100 miles of single-circuit 500 kV and double-circuit 345 kV transmission line in central Utah, and is scheduled for completion in May 2013. Outreach, siting and permitting efforts continue for several other segments of Energy Gateway, with additional segments scheduled to be in service in 2015 and beyond. See the Energy Gateway website for additional project information (www.pacificorp.com/tran/tp/eg).

48 Edison Electric Institute Transmission Projects: At A Glance — MIDAMERICAN ENERGY HOLDINGS COMPANY

Project Investment Partners: At the initiation of Energy Gateway, PacifiCorp entered into a permitting agreement with Idaho Power on the Gateway West project. PacifiCorp recently signed a permitting agreement with Idaho Power and Bonneville Power Administration on Idaho Power’s Boardman to Hemingway 500 kilovolt transmission project, and the Company is exploring joint-development opportunities on Portland General Electric’s Cascade Crossing 500 kilovolt transmission project from Boardman to the Salem, Oregon area (both depicted on the Energy Gateway map).

Project Benefits: The Energy Gateway transmission expansion program is designed to provide the company with improved infrastructure to meet its tariff requirements and reliably serve the growing needs of its customers. As an important part of the company’s integrated resource planning process, the project will strengthen the connections between PacifiCorp’s two control areas and provide more flexibility to move energy resources where they are needed, helping to maintain low-cost delivery and service reliability for all network customers. The project will also provide long-term regional benefits to the Western Interconnection by providing additional high-voltage backbone transmission for efficient, flexible and diverse resource development in resource rich areas.

Edison Electric Institute 49 Minnesota Power

Company Background: • Minnesota Power, a division of ALLETE, provides electricity in a 26,000 square-mile electric service territory located in northeastern Minnesota. Minnesota Power supplies retail electric service to 141,000 retail customers and wholesale electric service to 16 municipalities. • Transmission and distribution components include 8,866 circuit miles of lines and 169 substations. Minnesota Power’s transmission network is interconnected with the transmission grid to promote reliability and is part of a larger regional transmission organization; the Midwest ISO (MISO). • Between 2001 and 2010 Minnesota Power invested nearly $121 million for upgrades and new infrastructure to the transmission system.

Transmission Related Smart Grid Initiatives: • Minnesota Power is one of the participants in the MISO’s Smart Grid Phasor Measurement Unit (PMU) Project. The MISO Smart Grid Project was awarded funds by the U.S. Department of Energy (DOE). Minnesota Power has installed a PMU/DFR at the Forbes 500 kV Substation as well as a Phasor Data Concentrator (PDC) at the Rowe Energy Control Center. When connectivity is completed, the PDC will connect with MISO’s PDC. MISO’s PDC will in turn connect with the TVA data concentrator as part of the larger North American SynchroPhasor Initiative. Minnesota Power’s project cost is estimated to be $125 thousand. Minnesota Power’s completed its installation in March, 2011. The SynchroPhasor data will be intgrated into MISOs “Real-Time Displays” which is expected to become operational in mid-2012. The MISO grant is to be spent over three years and will be completed by early 2013.

CAPX2020 Transmission Plan Project Description: The CapX2020 Transmission Plan consists of approximately 240 miles of new single-circuit, 345 kV transmission line between Brookings County, South Dakota, and Hampton, Minnesota, plus a related 345 kV transmission line between Marshall and Granite Falls, Minnesota; approximately 240 miles of new single-circuit, 345 kV transmission line between Fargo, North Dakota, and St. Cloud and Monticello, Minnesota; approximately 125 miles of new single-circuit, 345 kV transmission line between Hampton and Rochester, Minnesota, continuing on to La Crosse, Wis- consin; and approximately 70 miles of new single-circuit, 230 kV transmission line between Bemidji and Grand Rapids, Minnesota.

50 Edison Electric Institute Transmission Projects: At A Glance — Minnesota Power

This project is a joint initiative of eleven transmission owning utilities, including Minnesota Power, in the Upper Midwest to expand the electric transmission grid to ensure continued reliable service to 2020 and beyond. Planning studies show that customer demand for electricity will increase by 4,000 to 6,000 MWs by 2020.

Of these new transmission lines, the Brookings County - Hampton Project provides access to wind generation in southwest Minnesota and eastern South Dakota. The line is expected to increase the delivery of wind generation by 700 MWs. While the other lines are driven primarily for reliability needs, they will also facilitate future wind development by providing the necessary infrastructure to support other wind-focused transmission additions.

Project Cost: The four lines will cost between $1.4 and $1.7 billion with an additional $200 million to provide for double-circuit 345 kV lines. Of this total, approximately $700 million is associated with the wind generation-supporting Brookings County-Hampton line.

Project Status: The Minnesota Public Utilities Commission (MN PUC) approved Certificate of Need applications for all four projects in 2009. Minnesota Route Permit applications were filed for three of the projects in 2008, with the fourth filed in January 2010. Filing for the North Dakota, South Dakota and Wisconsin regulatory permits were completed and filed in 2011.

Minnesota Route Permits were received in 2010 for the 230 kV Bemidji to Grand Rapids line and the 345 kV St. Cloud to Monticello line. Construction of the St. Cloud to Monticello Line started in late 2010 and this line section was placed in service on December 21, 2011. The North Dakota permits for this line were received in 2011. . Construction of the Bemidji to Boswell Line started in January 2011 and is expected to be completed by September 2012. The South Dakota permits for the Brook- ings County-Hampton line were received in 2011. The remaining permits from Wisconsin and Min- nesota for the Hampton MN to La Crosse WI Line are expected to be received in 2012.

Project Investment Partners: Minnesota Power, Central Minnesota Municipal Power Agency, Dairyland Power Cooperative, Great River Energy, Southern Minnesota Municipal Power Agency, Minnkota Power Cooperative, Missouri River Energy Services, Otter Tail Power Company, Rochester Public Utilities, WPPI Energy and Xcel Energy.

Project Benefits: The CapX Projects will alleviate emerging electric reliability issues around the Up- per Midwest and strengthen the regional transmission system. In addition, the Brookings County to Hampton line will add capacity for an additional 700 MWs of generation in southwest Minnesota and eastern South Dakota. The Brookings County to Hampton line was also included as one of 16 Multi Value Projects (MVP) the Midwest Independent System Operator’s (MISO) Board of Direc- tors approved in December 2011. These MVP transmission projects will provide broad regional benefits commensurate with costs and also supports approved state and federal energy policy mandates in the MISO region.

Edison Electric Institute 51 Transmission Projects: At A Glance — Minnesota Power

Transmission to Serve Essar Steel Minnesota Project Description: Transmission is required to supply electric power to the new Essar Steel Min- nesota mine and steel mill. The Essar Steel Min- nesota (ESM) Project will be developed in three phases with Phase I consisting of a conventional taconite plant and mining load of 145 MWs will become operational in the Spring of 2013. Phase II of the project adds a Direct Reduced Iron (DRI) facility which is scheduled to be operational in the fall of 2015 and increases total demand to approximately 200 MWs . Phase III of the project will add an Arc furnace and steel slab plant scheduled to be in service by the end of 2015. This will increase the total peak demand to nearly 390 MWs.

To serve Phase I of the Essar Steel Minnesota (EMS) project, Minnesota Power’s 230 kV Boswell to Shannon Line will be looped into the new Essar Mine Plant and Essar Steel Substations.. To serve Phase II and Phase III of the ESM Project, a new line will be constructed from the Minnesota Power Blackberry Substation to the Essar Steel Plant Substation.

Project Cost: Approximately $31 million.

Project Status: The Minnesota Public Utility Commission (MPUC) approved route permits for the lines in August 2010. The plan is to construct the transmission to serve ESM in stages to coincide with the load expansions associated with Phase 1, Phase II and Phase III of the ESM Project. The looping of Boswell-Shannon Line to provide a Boswell to Essar Mine Substation line, Essar Mine to Essar Steel Plant Substation line and an Essar Steel Plant to Shannon Substation line will be constructed first. These lines will supply Phase I of the ESM project and are expected to be placed in service by April 2013. The line between the Blackberry Substation and the Essar Steel Plant Substation will be constructed as required to meet the load increases associated with Phase II and Phase III of ESM Project. Based on ESM’s current schedule, it is anticipated these 230 kV lines will be completed and become operational in 2015.

Project Investment Partners: None.

Project Benefits: The project will provide the reliable electric service to the new ESM facilities and provide the area the economic benefits associated with mining in northern Minnesota.

52 Edison Electric Institute National Grid

Company Background: • National grid is an international electricity and gas company and one of the largest investor-owned utilities in the world. In the U.S., National Grid distributes electricity to approximately 3.4 million customers in Massachusetts, New York and Rhode Island. National Grid owns over 4,000 MWs of contracted electricity generation that provides power to over one million LIPA customers. • National Grid maintains over 10,000 circuit miles of transmission and operates 524 electricity substations in the United States. • Between 2001 and 2010 National Grid has invested approximately $1.7 billion into its transmission system.

Northeast Energy Link Project Description: The Northeast Energy Link project consists of approximately 240 miles of new 1,100 MW HVDC transmission line from Orrington, Maine to eastern Massachusetts.

Project Cost: Estimated $2 billion.

Project Status: Preliminary engineering and permitting work is underway. Economic studies and siting and routing analysis has been performed. A petition for declaratory order was filed at FERC in August 2011 and is await- ing decision. Preparations are being made to seek other regulatory approval. The project in service date is expected to be 2019.

Project Investment Partners: Bangor Hydro Electric.

Project Benefits: NEL will deliver renewable and low carbon resources from Northern New England and the Canadian Maritime to Southern New England customers, providing energy to meet RPS targets. By facilitating the development of additional renewable and low carbon resources in the region, NEL will benefit customers by lowering market clearing prices, meeting expanded renewable portfolio standard requirements, expanding fuel diversity, and improving reliability by reducing transmission congestion and thermal losses.

Edison Electric Institute 53 Transmission Projects: At A Glance — National Grid

New England East - West Solutions (NEEWS) Project Description: The New England East - West Solution (NEEWS) is a set of four projects that will upgrade the New England transmission system in Massachusetts, Connecticut and Rhode Island. The projects, developed collaboratively by National Grid and Northeast Utilities (NU), involve more than 150 circuit miles of new and/ or reconstructed 345 kV and 115 kV transmission lines, significant upgrades to several major substations, two new switching stations, and a number of related system upgrades. The four NEEWS projects are:

• Central Connecticut Reliability Project (NU); • Greater Springfield Reliability Project (NU); • Interstate Reliability Project (NU and National Grid); and • Rhode Island Reliability Project (National Grid). Project Cost: National Grid’s total capital investment in the above NEEWS projects and the associated advanced NEEWS projects that have been completed is estimated to be approximately $710 million.

NEEWS - Interstate Reliability Project (IRP) Project Description: The IRP consists of approximately 74.7 miles of new single circuit, 345 kV transmission line. National Grid will construct the Rhode Island portion of the transmission line terminating at Millbury, MA. The IRP will address east to west and west to east transmission constraints of power across Connecticut, Rhode Island and Massachusetts.

Project Status: The in-service date for the IRP is expected to be 2015.

Project Investment Partners: Northeast Utilities.

Project Benefits: The four NEEWS Projects work together to address a multitude of regional transmission needs identified by ISO-NE in its Regional System Plan, including:

• Constrained east-to-west and west-to-east power flow deliverability across New England; • Constraints in serving load across the region; • Thermal and voltage issues in the Springfield, Massachusetts area; • Interstate transfer capacity; • Limits affecting Connecticut reliability; • Constrained east-to-west power flow across Connecticut; and • Interstate transfer capacity limits and voltage concerns affecting Rhode Island reliability.

54 Edison Electric Institute Transmission Projects: At A Glance — National Grid

NEEWS - Rhode Island Reliability Project (RIRP) Project Description: The RIRP is collection of projects aimed at improving the reliability and performance of the Rhode Island transmission network. The RIRP consists of 21.4 miles of new single-circuit 345 kV and 115 kV overhead lines, further line reconductoring, substation upgrades and expansions, and terminal upgrades. The project is designed to address transmission reliability standards in Rhode Island.

Project Status: The Rhode Island Reliability portion of the project recently completed permitting and licensing activities, and commenced construction in October 2010. The Rhode Island Reliability group of projects is expected to be completed and placed in service by the 2013 timeframe.

Project Investment Partners: None.

Project Benefits: The four NEEWS Projects work together to address a multitude of regional transmission needs identified by ISO-NE in its Regional System Plan, including:

Edison Electric Institute 55 Northeast Utilities (NU)

Company Background: • NU and its four operating companies, the Connecticut Light and Power Company (CL&P), Public Service Company of New Hampshire (PSNH), Western Massachusetts Electric Company (WMECO), and Yankee Gas (YG), own and operate New England’s largest energy delivery system. • NU delivers electricity to more than 1.8 million customers through over 3,200 circuit miles of transmission line. • NU companies coordinate transmission planning with ISO New England (ISO-NE) and are making substantial investments in new transmission facilities. • Between 2001 and 2011 NU has invested approximately $3.6 billion into its transmission system. • Between 2012 and 2016 NU expects to invest $2.6 billion into transmission system upgrades.

The Northern Pass Transmission Line (NPT Line) Project Description: The NPT Line project consists of approximately 140 miles of new 300 kV HVDC transmission line, with two conductors, and associated 40 mile radial 345 kV transmission line that will interconnect Québec with the bulk power system in New Hampshire for the purpose of importing 1,200 MWs of low carbon emissions power into New England. The owner of the NPT Line is Northern Pass Transmission LLC, a joint venture between subsidiaries of Northeast Utilities and NSTAR. The U.S. portion of the HVDC line is about 140 miles in length and includes an AC/ DC HVDC converter terminal in the City of Franklin, New Hampshire. The AC radial line is about 40 miles in length, connecting the converter terminal to the Deerfield Substation in Deerfield, New Hampshire. Final line lengths will depend upon the completion of line routing and siting. The project will be participant funded via a transmission service agreement with H.Q. Hydro Renewable Energy, Inc. (HQ Renewable), a subsidiary of Hydro-Quebec.

Project Cost: The estimated capital cost for the U.S. portion of the line is approximately $1.1 billion. NU’s portion of the project is approximately $830 million.

Project Status: On May 22, 2009, FERC approved the proposed participant funding arrangement for the NPT Line (described at that time as a transaction between HQUS, NU, and NSTAR under which HQUS agreed to pay 100 percent of the costs of the project in return for usage rights over the new HVDC transmission line). On October 4, 2010, NPT and HQ Renewable signed a Transmis- sion Service Agreement, which was filed with FERC on December 15, 2010. NU received the FERC Order accepting the TSA on February 11, 2011. Construction is expected to begin in 2014. The target in service date is late 2016.

Project Investment Partners: NSTAR.

Project Benefits: This is an economic and environmental project that will provide competitively priced, reliable supply of large quantities of energy from resources that do not burn fossil fuels or rely

56 Edison Electric Institute Transmission Projects: At A Glance — Northeast Utilities (NU)

upon import oil, and are low greenhouse gas emitting sources of energy. Power sold into the New England markets by HQ Renewable would largely displace gas-fired generation in New England and greenhouse gas emissions associated with the production of electricity will be reduced by up to five million tons of CO2 per year during the term of the transaction. This will assist New England in meeting its targets under the Regional Greenhouse Gas Initiative (RGGI), which all of the New England states have signed, and under any future cap and trade program or carbon tax adopted at the federal level.

Transmission Investment: Economic.

Other Highlights: International Project, Low Carbon.

New England East - West Solution Projects (NEEWS) Project Description: The New England East - West Solution (NEEWS) is a set of four projects that will upgrade the New England transmission system in Massachusetts, Connecticut and Rhode Island. The projects, developed collaboratively by NU and Na- tional Grid, involve more than 150 circuit miles of new and/or reconstructed 345 kV and 115 kV transmission lines, significant upgrades to several major substations, two new switching stations, and a number of related system upgrades. The four NEEWS projects are:

• Greater Springfield Reliability Project (NU); • Interstate Reliability Project (NU and National Grid); • Central Connecticut Reliability Project (NU); and • Rhode Island Reliability Project (National Grid).

Greater Springfield Reliability Project (GSRP) Project Description: The GSRP consists of approximately 35 miles of new single and double-circuit, 345 kV transmission lines in Connecticut and Massachusetts and 60 circuit miles of new and reconstructed single and double-circuit, 115 kV overhead transmission lines in Massachusetts. The project also includes three major substation upgrades, two new switching stations and work on nine other switching stations and substations. The GSRP is designed to address transmission system reliability problems and meet more stringent federal and regional reliability standards.

Project Cost: The current estimate for the project is $718 million.

Project Status: Siting approvals were received in Connecticut and Massachusetts for the GSRP, and full construction has begun in both states on both substations and overhead lines.

Edison Electric Institute 57 Transmission Projects: At A Glance — Northeast Utilities (NU)

Project Investment Partners: United Illuminating is investing approximately 8.4% of the cost of the Connecticut portion of the project.

Project Benefits: The four NEEWS Projects work together to address a multitude of regional transmission needs identified by ISO-NE in its Regional System Plan, including: constrained east to west and west to east power flow deliverability across New England; constraints in serving load across the region; thermal and voltage issues in the Springfield, Massachusetts area; interstate transfer capacity limits affecting Connecticut reliability; constrained east to west power flow across Connecticut; and interstate transfer capacity limits and voltage concerns affecting Rhode Island reliability.

Interstate Reliability Project (IRP) Project Description: The IRP consists of approximately 77 miles of new single-circuit, 345 kV transmission line. The NU portion of the line consists of 37 miles of new single-circuit, 345 kV transmission line built parallel to existing 345 kV circuits in the same ROW. The line will begin at Card Street Substation in Lebanon, Connecticut, go through Lake Road and cross the Rhode Island/Connecticut border into National Grid territory, where National Grid will construct approximately 35 to 40 miles of transmission line through Rhode Island terminating at Millbury, Massachusetts. The IRP will address weaknesses in both the east to west and west to east transmission of power across Connecticut, Rhode Island and Massachusetts. Providing more direct routes between power sources and eastern Connecticut, and increasing the overall capacity of the transmission system, will mean that access to cleaner, competitively priced power will be routinely possible. The project also includes upgrades to seven substations (three each in Connecticut and Massachusetts, and one in Rhode Island), providing a stronger transmission connection between Massachusetts and Connecticut. The IRP is designed to address reliability violations associated with the movement of power both east to west AND west to east across southern New England under certain line out conditions.

Project Cost: The preliminary cost estimate is $218 million.

Project Status: The siting applications in Connecticut, Massachusetts and Rhode Island are expected to be filed in late 2011. Construction is expected to begin in late 2013 or early 2014. The project in service date for the IRP is expected to be 2015.

Project Investment Partners: National Grid will construct and own their portion of the line in Rhode Island and Massachusetts, and United Illuminating is investing approximately 8.4% of the cost of the Connecticut portion of the project.

58 Edison Electric Institute Transmission Projects: At A Glance — Northeast Utilities (NU)

Central Connecticut Reliability Project (CCRP) Project Description: The CCRP, which is currently in the early planning stage, consists of 36 miles of new single-circuit, 345 kV transmission line on existing rights-of-way (ROW) from North Bloom- field Substation in Bloomfield, Connecticut to Frost Bridge Substation in Watertown, Connecticut. The CCRP is being pursued to address specific weaknesses in the transmission system in the central and western Connecticut areas. The project is designed to increase the capability of the transmission system to move power within Connecticut. It will also provide local residents and businesses with more reliable access to cleaner, more competitively priced power.

Project Cost: The preliminary cost estimate is $301 million.

Project Status: This project is in the early planning stage. ISO-NE continues its reassessment of the need for the CCRP, and has consolidated the CCRP reassessment with the study of other reliability problems inside Connecticut. Collectively, the combined study is referred to by ISO-NE as the Greater Hartford Central Connecticut Study, or GHCC. The GHCC study is expected to conclude in late 2012. NU believes that the current project cost is an adequate placeholder for the cost of the solution that ultimately emerges from the GHCC study; however, the final solution could be along different rights-of-way in Connecticut. Currently, we anticipate the in service date to be 2017.

Project Investment Partners: United Illuminating is investing approximately 8.4% of the cost of the project.

Edison Electric Institute 59 Transmission Projects: At A Glance — Northeast Utilities (NU)

Pittsfield-Greenfield Area Solution Project Description: The Pittsfield-Greenfield Area Solution involves a family of smaller projects designed to reinforce the transmission system in western and north-central areas of Massachusetts to comply with regional and national reliability standards. The individual reinforcements include:

• Installing a 345/115-kV autotransformer; • Constructing a new 115-kV switching station; • Constructing a new one mile 115-kV line and rebuilding portions of another 115-kV line; • Adding 115-kV capacitor banks; • Re-conductoring portions of a 115-kV line; and, • Completing structure replacements to remove sag limits. Project Cost: Current estimates for the combined reinforcements total approximately $108 million excluding National Grid estimates for associated upgrades.

Project Status: The Pittsfield-Greenfield Area Solution is expected to receive formal technical approval from ISO-NE in early 2012. Detailed engineering as well as siting/permitting activities will commence in early 2012. The in service dates for these reinforcements are expected to be phased in during 2013, 2014, and 2015.

Project Investment Partners: None.

Project Benefits: The Pittsfield-Greenfield Area Solution reinforcements address reliability concerns that alleviate thermal overloads and resolve voltage issues found on the two major transmission paths in western Massachusetts.

60 Edison Electric Institute NorthWestern Energy

Company Background: • NorthWestern is an electric and natural gas utility serving the States of Montana, South Dakota, and Nebraska, as well as a small part of Wyoming. • NorthWestern’s electric operations provide transmission and distribution services to approximately 399,000 electric customers in Montana, South Dakota and Nebraska with over 8,300 circuit miles of transmission lines and associated terminal facilities (50 kV to 500 kV). • Between 2001 and 2010 Northwestern Energy has invested approximately $148 million in its transmission system.

500 kV Upgrade Project Project Description: NorthWestern, the other Colstrip Transmission System owners, and the Bonneville Power Administration have completed a technical study to increase the existing 500 kV transmission system by up to 700 MWs. This project is a series capacitor compensation upgrade to existing 500 kV transmission lines: 500 miles of double-circuit transmission line from Colstrip to Taft, MT; 81 miles of single-circuit transmission line from Taft to Bell; and 88 miles of single-circuit transmission line from Taft to Dworshak. The 500 kV transmission system extends from Col- strip in eastern Montana to the Mid C area of the Columbia River on the border between Washington and Oregon. The Montana 500 kV transmission system is used to move the existing Colstrip generation in eastern Montana to the Northwest. Ap- proximately 75 percent of the Colstrip generation capacity is exported to serve loads outside Montana. The primary path of this exported power is the two 500 kV lines that start at Colstrip and traverses NorthWestern Balancing Area from east to west to exit the state near Taft. At Taft the 500 kV lines split and continue to areas in the Northwest.

Project Cost: The cost of the project may be up to $207 million depending on the incremental capacity increase.

Project Status: The 500 kV Project planning studies will be completed in late 2012, with anticipated construction in 2012/14 and an expected in service date of fall 2014.

Project Investment Partners: The Colstrip Transmission System is co-owned by Avista Corporation, NorthWestern Energy, PacifiCorp, Portland General Electric, and Puget Sound Energy. The Colstrip

Edison Electric Institute 61 Transmission Projects: At A Glance — NorthWestern Energy

Transmission System starts at Colstrip, Montana and ends near Townsend, Montana. Ownership of the 500 kV transmission changes to the Bonneville Power Administration at Townsend.

Project Benefits: The overall benefit of the 500 kV Upgrade is to increase the transfer capability of an existing 500 kV transmission line at a low cost thereby minimizing environmental impact, to promote the development of new renewable generation in the high wind areas of Montana, and to move renewable energy to markets in the Northwest.

Montana Renewable Collector System (MT-RCS) Project Description: The proposed Montana Renewable Collector System (MT-RCS) will be potentially five generator lead lines (i.e., collector lines) that originate in the high wind areas of Montana and move renewable wind energy south to a new 500 kV substation at Townsend, Mon- tana. There may be approximately 675 circuit miles of new transmission constructed for all five collector lines, but mileage depends on number of lines and their routing. An Open Season, which has been extended to 2012, will determine the number and location of each generator lead line. The new Townsend substation will connect the generator lead lines to the existing twin 500 kV lines that traverse Montana from east to west and to NorthWestern’s proposed new 500 kV MSTI line that starts at Townsend and terminates at Midpoint, Idaho. At Midpoint, MSTI customers will have access through existing and proposed new transmission to customers in the west and southwest. The MT-RCS Project and the MSTI Project would provide a key pathway for potential Montana wind generation to be directed to demand centers in the Pacific Northwest (Northern California, Oregon, and Washington) and the Desert Southwest (Southern California, southern Nevada, and Arizona).

Project Cost: The cost for each generator lead line will be unique and determined by location and routing. It is expected that a single generator lead line may cost up to an estimated $225 million.

Project Status: The MT-RCS Project is in the planning, siting and permitting stage. NorthWestern has extended the open season to 2012 which will define the starting location, number and routing of each of the generator lead lines. Construction is expected to begin in 2014 with an expected in service date of 2016.

In September 2010 NorthWestern signed a Memorandum of Understanding with WAPA for the MT-RCS Project. Under the agreement, NorthWestern and WAPA will undertake joint planning and study work to determine how the MT-RCS Project may enhance WAPA’s Transmission Infrastructure Program’s mission of enabling renewable energy development.

Project Investment Partners: None.

62 Edison Electric Institute Transmission Projects: At A Glance — NorthWestern Energy

Project Benefits: The primary benefit of the MT-RCS is to move renewable generation from high wind areas in Montana to a new 500 kV Townsend substation on the existing 500 kV transmission lines that traverse Montana from east to west. At Townsend, renewable resources can move power to markets outside Montana over the existing 500 kV transmission lines to the Northwest or down a new 500 kV MSTI line to markets in the south and southwest.

Mountain States Transmission Intertie (MSTI) Project Description: The proposed Mountain States Trans- mission Intertie (MSTI) project would involve approximately 400 miles of new 500 kV transmission line connecting a new substation outside of Townsend, Montana to the existing Midpoint Substation near Jerome, Idaho. Addi- tional upgrades include new and upgraded substations, and a microwave system for reliable communication between the substations.

NorthWestern is currently siting MSTI in Montana and Idaho. The final route that MSTI will follow in Montana and Idaho has not been defined yet, but will be determined as the EIS process is completed. The routing will cross pri- vate and public lands.

Project Cost: Approximately $1 billion.

Project Status: The project is in the planning, siting and permitting stage. The issuance of the draft EIS has been delayed by a lawsuit that Jefferson County, MT filed against the Montana Department of Environmental Quality (MDEQ). In October 2011 the Montana Supreme Court overturned the September 2010 district court ruling that the MDEQ failed to consult adequately with Jefferson County during the review of MSTI. As a result of this decision NorthWestern currently anticipates the MDEQand BLM will issue the draft EIS by the summer of 2012. Under this schedule the final EIS could be released by the spring of 2013 and the ROD by the summer of 2013. The Federal process in Idaho is expected to be approximately the same timeframe. NorthWestern has extended the MSTI Open Season until 2012. Construction is now expected to start in 2014, and the in service date is planned for 2016.

In September 2010 NorthWestern signed an MOU with WAPA for the MSTI Project. Under the agreement, NorthWestern and WAPA will undertake joint planning and study work to determine how the MSTI Project may enhance WAPA’s Transmission Infrastructure Program’s mission of enabling renewable energy development.

Project Investment Partners: None.

Project Benefits: The primary benefit of MSTI is to relieve existing congestion between Montana and Idaho and to move a significant amount of renewable power to regional markets. Existing transmission congestion serves as a significant barrier to entry and access to regional markets for prospec- tive renewable development in Montana. The proposed MSTI Project would provide a key pathway

Edison Electric Institute 63 Transmission Projects: At A Glance — NorthWestern Energy

for potential Montana wind generation to be directed to demand centers in the Pacific Northwest (Northern California, Oregon, and Washington) and the Desert Southwest (Southern California, southern Nevada, and Arizona). The significant interest in Montana wind development is a function of both its high quality wind resources and the passage of many renewable energy development initiatives. These initiatives include western state Renewable Portfolio Standards (RPS) and the Western Governors’ Association’s initiative to develop 30 GW of clean, diversified energy from the Western Power Grid by 2015.

64 Edison Electric Institute NV Energy

Company Background: • NV Energy is an investor owned FERC jurisdictional utility. NV Energy serves approximately 1.2 million customers over a 54,500 square-mile area in southern and northern Nevada and northeastern California • System wide there are approximately 3,850 miles of FERC classified circuit mile transmission • Between 2001 and 2010 NV Energy invested approximately $750 million into its transmission system.

One Nevada 500 kV Transmission Intertie (NVES & NVEN) Project Description: NV Energy will construct an approximately 235 mile 500 kV transmission line from northern Nevada (near Ely, Nevada) to southern Nevada (NE Las Vegas) tying Nevada’s electrical grid together by creating a direct interconnection between the Northern and Southern NVE systems. The project also adds one 500/345 kV substation.

Project Cost: $510 million (in 2011 dollars).

Project Investment Partners: GBT.

Project Status: The Joint NV Energy / Great Basin One Nevada Transmission Line Project (ON Line) transmission line construction crews are currently working in Lin- coln County developing construction roads and installing below grade improvements, such as foundations. Substa- tion work started at Robinson Summit Substation in June 2011. Construction is continuing on the project (see Figure 7). ON Line had originally been expected to enter service in late 2012. At this time, the Company does not anticipate that ON Line will be placed in service until the latter half of 2013 due to on-going efforts to address wind related damage sustained by some of the tower structures erected for the project.

NV Energy is joining the Northern Nevada Sierra Pacific Power Balancing and Operating Area (BA) and the Southern Nevada Balancing and Operating Area into one NV Energy Balancing Area after completion of One Nevada Line Project. NV Energy is currently working with WECC PCC, TSS, and parties interested in the project review on consolidating the WECC ratings in both BAs. This will include re-definition of the existing path # 81 (“Centennial”) into a “Southern Nevada Transmis- sion Interface” (SNTI) and removal of the ON Line project from the three phase rating process. NV Energy is forming a new WECC Project Review Group to review this process.

Edison Electric Institute 65 Transmission Projects: At A Glance — NV Energy

Renewable Energy Transmission Initiative (RTI) • The 2009 Nevada legislature passed AB387, making transmission development to support renewable generation public policy. Assembly Bill 387 required NV Energy to identify transmission plans and cost to access RETAAC/PUCN approved renewable energy zones. In the 2010 Sierra Integrated Resource Plan (IRP) a plan to access these zones was published as the Renewable Energy Conceptual Transmission Plan (RECTP). In July of 2011 NV Energy introduced its Renewable Transmission Initiative as a customer driven process to determine market interest in developing the RETAAC Zones. More information is available at http://www.nvenergy.com/RTI. Project Cost: The project costs are confidential and available only to participating customers.

Project Status: (RTI) received a significant response. NVE received over 5000 MW of Statements of Interest in the RTI in September of 2011. Study Agreements were sent to participants in November 2011. There was sufficient interest to continue with the RTI facilities capable of delivering from Points of Receipt 1 (Dixie valley) , 2 Esmeralda region), and 3 (Armar- gosa valley) to Point of Delivery C (Eldorado substation n the Eldorado valley). Studies are expected to be completed in April of 2012. Participants may then elect to proceed into the permitting phase of RTI.

Project Investment Partners: The participants in RTI are Confidential.

Project Benefits: The project will address NV Energy’s and the State’s growing emphasis on development of renewable energy resources by improving access to electricity generated by renewable energy projects in the State. The project will be used to access over 80% of the most concentrated Renewable Energy Zones Identified in RETAAC and provide transmission access for renewable developers to reach the Desert Southwest and California.

66 Edison Electric Institute OGE Energy Corp. (OGE)

Company Background: • OGE Energy Corp., through its electric utility subsidiary OG&E Services, serves over 775,000 customers in its 30,000 square-mile service territory in Oklahoma and western Arkansas. • OGE owns over 4,500 circuit miles of transmission lines from 69 kV to 500 kV. • OGE is a member and its transmission facilities are under the operational control of the Southwest Power Pool (SPP) RTO. • Between 2001 and 2010 OGE invested over $839 million in its transmission system.

Hitchland – Woodward 345 kV Line Project Description: The Hitchland - Woodward project consists of 120 miles of new double-circuit, 3000 amp per circuit, 345 kV transmission line that will extend from OG&E’s Woodward District EHV Substation to Southwestern Public Service Company’s Hitchland Substation, and with associated upgrades to the Woodward Dis- trict EHV Substation. The OG&E portion of the Hitchland - Woodward 345 kV line is estimated to be 82 miles in length.

Project Cost: Approximately $179 million.

Project Status: Preliminary line routing has been completed and has an estimated in service date of June 30, 2014.

Project Investment Partners: None.

Project Benefits: This project was directed to be built by the SPP as a “Priority Project” to enhance the reliability of the SPP transmission system, facilitate the integration of wind resources, and enable west-east transfers across the SPP.

Edison Electric Institute 67 Transmission Projects: At A Glance — OGE Energy Corp. (OGE)

Seminole – Muskogee 345 kV Line Project Description: The Seminole - Muskogee project consists of approximately 120 miles of new single-circuit, 345 kV transmission line to be built from OG&E’s Seminole Substation to OG&E’s Muskogee Substation, as well as associated upgrades to both the Seminole and the Muskogee Substations.

Project Cost: Approximately $179 million.

Project Status: This Project is estimated to be in service by December 2013. Final line routing is under review.

Project Investment Partners: None.

Project Benefits: This project has been approved as part of the SPP Balanced Portfolio 3E projects to enable economic transfers and enhance regional transmission reliability.

Sooner – Cleveland 345 kV Line Project Description: The Sooner - Cleveland project consists of approximately 38 miles of new 345 kV transmission line to be constructed from OG&E’s Sooner Substation to the Grand River Dam Authority’s Cleveland Substation, plus associated upgrades to the Sooner Substation. OG&E will construct the entire Sooner - Cleve- land line.

Project Cost: Approximately $64 million.

Project Status: Final line design is underway and line completion is planned for March 31, 2013.

Project Investment Partners: None.

Project Benefits: This project is required for transmission service as directed by the SPP.

68 Edison Electric Institute Transmission Projects: At A Glance — OGE Energy Corp. (OGE)

Sooner – Rose Hill 345 kV Line Project Description: The Sooner - Rose Hill project consists of a approximately 88 miles of new 345 kV transmission line to be constructed from OG&E’s Sooner Substation to an interface with a Westar Energy line segment at the Oklaho- ma-Kansas state line. The OG&E portion of the Sooner- Rose Hill line is 43 miles in length. This project has been approved as part of the SPP Balanced Portfolio 3E projects.

Project Cost: Approximately $58 million.

Project Status: R/W clearing and gate installation commenced 1/24/2011. Line engineering complete 2/1/11. Substation engineering complete 6/1/11. Storm water permits received and controls being installed in conjunction with opening of R/W. R/W acquisition complete except for BIA tracts Scheduled completion date of entire project: 5/31/2012.

Project Investment Partners: Westar Energy.

Project Benefits: This project is required for transmission service, to enable economic transfers and enhance regional transmission reliability.

Sunnyside – Hugo 345 kV Line Project Description: The Sunnyside - Hugo project consists of approximately 120 miles of new 345 kV transmission line to be built from OG&E’s Sunnyside Substation to the Western Farmers Electric Cooperative’s Hugo Generation Plant Substation, as well as associated upgrades to the Sunnyside Substation.

Project Cost: This project is estimated to cost $187 million.

Project Status: Line construction began January 1, 2011. This project is estimated to be in service by May 1, 2012.

Project Investment Partners: None.

Project Benefits: This project is required for transmission service.

Edison Electric Institute 69 Transmission Projects: At A Glance — OGE Energy Corp. (OGE)

Woodward – Kansas 345 kV Line Project Description: The Woodward - Kansas project consists of 80 miles of new double-circuit, 345 kV transmission line to be built from OG&E’s Woodward District EHV Substation to the Prairie Wind LLC interception point at the Oklahoma-Kansas state line, together with associated upgrades to the Woodward District EHV Substation.

Project Cost: Approximately $134 million.

Project Status: Preliminary line route investiga- tion is set to begin in 2011, and has an estimated in service date of December 31, 2014.

Project Investment Partners: None.

Woodward – Tuco 345 kV Line Project Description: The Tuco - Woodward project consists of approximately 250 miles of new 345 kV transmission line from OG&E’s Woodward District EHV to the SPS Tuco Substation. The OG&E portion of the Tuco - Woodward project is 72 miles in length and will terminate at a reactor station to be constructed at approximately the Oklahoma- Texas state border south of Interstate 40. This 345 kV line was approved as part of the SPP Balanced Portfolio 3E Projects to enable economic transfers and enhance regional transmission reliability.

Project Cost: Approximately $120 million.

Project Status: This project is estimated to be in service by May 19, 2014.

Project Investment Partners: None.

Project Benefits: This project supports the integration of wind generation and system reliability.

70 Edison Electric Institute Oncor Electric Delivery Company, LLC (Oncor)

Company Background: • Oncor is a regulated electricity distribution and transmission business. Oncor operates and is governed as a separate and independent company from Energy Future Holdings Corporation. • Oncor operates the largest distribution and transmission system in Texas and is the sixth-largest system in the nation. The company delivers power to approximately three million homes and businesses, or about one-third of the state’s population. • Oncor operates approximately 15,000 circuit miles of transmission lines in Texas, including more than 5,000 circuit miles of 345 kV lines. • Between 2001 and 2010 Oncor invested approximately $2.7 billion into its transmission system.

Transmission Related Smart Grid Initiatives: • Oncor has consistently upgraded its transmission management and control systems with the latest smart grid technology. With more than 92 percent of transmission relays now electronic, digital fault recorders and relay records are automatically moved to a central system for rapid analysis.

Bell County East – TNP One 345 kV Transmission Line Project Project Description: The Bell County East – TNP One (Texas-New Mexico Power Company) Project consists of approximately 40 miles of new double-circuit, 345 kV transmission line between the proposed Bell County East switching station, to be located southeast of Temple, and TNP One switching station, located at the TNP One generating plant. The construction of the Bell County East – TNP One Project will achieve system upgrades that are a necessary step in improving north-south transfer capabilities and to add valuable capacity margin to the entire transmission system.

Project Cost: Approximately $50 million.

Project Status: On May 22, 2009, Oncor filed its application to amend its Certificate of Convenience and Necessity (CCN) with the Public Utility Commission of Texas (PUCT) in order to obtain approval of the project and a route for the transmission line. The CCN was approved and a Final Order issued on May 19, 2010. The project was placed in service December 2011.

Edison Electric Institute 71 Transmission Projects: At A Glance — Oncor Electric Delivery Company, LLC (Oncor)

Project Investment Partners: None.

Project Benefits: The need for the project is related to the start of operation of additional generation in the area, including the Oak Grove Plant (1,710 MW net) located at Twin Oak switching station beginning commercial operation in 2009; the Sandow Plant Unit 5 (581 MW net) becoming operational in 2009; and the Sandy Creek Plant (925 MW net) becoming operational in 2011. The addition of these plants increases the need for additional north-south transfer capacity. Contingencies result in increased power flow on the parallel 138 kV and 69 kV systems resulting in overloads. The project will alleviate these overloads by providing a 345 kV path around this bottleneck. Additionally, the project will add another exit for the Oak Grove and TNP One generation, and will provide a second and separate transmission line from TNP One. This will relieve some of the pressure on the 345 kV lines into Houston from the north reducing or eliminating contingency overloads on parallel paths into the Houston area.

Dynamic Line Ratings Project Description: Oncor is participating in the Department of Energy (DOE) SmartGrid Dem- onstration Projects program addressing the use of Dynamic Line Ratings (DLR) to improve the efficiency of the existing transmission infrastructure and to reduce congestion costs.

Project Cost: Indefinite.

Project Status: Oncor has installed primary and secondary dynamic line rating equipment on eight transmission circuits. The primary system, CAT-1 equipment, streams real-time data through the SCADA system to the Oncor Energy Management System environment. That data will be processed and dynamic ratings posted to the operations departments at Oncor and ERCOT. The secondary systems, Sagometers and Promethean RTTLMS, provide offline data for performing statistical vali- dation of the dynamic ratings and their “reach” from installation point down the transmission line to capture the characteristics of line sections rather than point locations.

Project Investment Partners: None.

Project Benefits: The project has several benefit objectives in the technical area as well as economic. Technically, the project will validate the DLR protocol and optimize the application of instrumenta- tion. The lessons learned from the project will be developed into a “guide” for future deployment of DLR systems by other utilities. Technical studies will also be designed to identify the amount of increased capacity over static ratings and its probability of occurrence and persistence to be available for different periods of time, i.e., the next 15 minutes up to 2 or 3 hours. Economic benefits will compare the impact of increased capacity to relieve congestion in the grid and for its application to identify capital investment deferments where the solution used DLR rather than physical upgrades or new construction.

72 Edison Electric Institute Transmission Projects: At A Glance — Oncor Electric Delivery Company, LLC (Oncor)

Fiber Optical Cable Use Project Description: As a smart grid tie into the CREZ initiative, Oncor will be installing fiber optic cable (OPGW) in the static wire for new CREZ 345 kV circuits.

Project Cost: Indefinite.

Project Status: In Progress.

Project Investment Partners: None.

Project Benefits: The fiber will be used to provide high speed relaying communication between termi- nals, while increasing system reliability and the opportunity to establish communication loops where higher levels of reliability are needed.

Oncor CREZ Development Project Description: In 2005, the Texas Legislature directed the PUCT to develop a transmission plan to meet the state’s increased renewable energy goals. From 2005 to 2008, the PUCT identified five Competitive Renewable Energy Zones (CREZ) to which lines would be built, adopted a transmission plan, and developed the process to select transmission companies to build the lines. The PUCT ultimately selected eight companies to build the new lines.

The PUCT awarded Oncor more than one-quarter of the total CREZ transmission project buildout, encompassing over 1,000 miles of new transmission lines.

CREZ projects are grouped into one of three categories: Default, Priority, and Subsequent projects. The Default Category, which represents 20 percent on Oncor’s CREZ spending, includes upgrades to existing station and transmission line facilities. The Priority Category, which represents 40 percent on Oncor’s CREZ spending, includes new transmission lines and stations for existing (constrained) wind that is currently installed but can’t come to market due to transmission flow constraints. The Subsequent Category, which represents 40 percent on Oncor’s CREZ spending, includes new transmission lines and stations for renewable generation to be brought to the market.

The Default Category projects include eleven stations and nine transmission lines totaling 249 miles. The Priority Projects include seven stations and nine transmission lines totaling 380 miles. The Sub- sequent Projects include eight stations and five transmission lines totaling 402 miles.

The CREZ Reactive Compensation Study was issued by ERCOT in December 2010 to outline the reactive support requirements for CREZ, accomplished through the addition of static and dynamic reactive devices, including the installation of three SVCs and series compensation equipment. Oncor has assessed the scope of work and developed revised estimates in accordance with the study results.

Edison Electric Institute 73 Transmission Projects: At A Glance — Oncor Electric Delivery Company, LLC (Oncor)

Project Cost: Approximately $2 billion.

Project Status: The Default Category projects received two CCNs. The station projects and transmission lines are 99 percent and 97 percent complete, respectively, with the vast majority completed in 2011. The Priority Category projects received seven CCNs and are currently in Engineering/Rights- of-Way (ROW) acquisition and construction. These projects are anticipated to be in service by 2012. The Subsequent Category projects have received five CCNs and are anticipated to be in service by 2013. Oncor has completed all scheduled public outreach meetings following the issuance of CCNs.

Project Investment Partners: None.

Project Benefits: The CREZ transmission project provides the infrastructure necessary to more than double Texas’ current renewable energy capacity. This will allow the state to meet increased renewable energy goals while reducing greenhouse gas emissions. CREZ will also improve ERCOT’s ability to move power within the state as energy demand increases.

Phasor Measurement Project Description: Oncor is participating in a DOE research project for the advancement and utilization of synchrophasor data measurements to improve grid reliability and market efficiency. The project will assess and verify generator performance and load modeling, investigate the impact of high wind generation penetration on the frequency response, study dynamic performance and congestion control for the ERCOT power system, as well as study state measurement integration and application.

Project Cost: Indefinite.

Project Status: To support this project, Oncor has installed sychrophasor measurement equipment at eight locations as well as a data concentrator to capture the streaming data. The captured data is then streamed to ERCOT’s data concentrator to be integrated with data from other ERCOT participants for utilization in the research project. Oncor plans are to continue the project at its current level of activity.

Project Investment Partners: None.

Project Benefits: The research project is for the advancement and utilization of synchrophasor data measurements to improve grid reliability and market efficiency.

74 Edison Electric Institute Transmission Projects: At A Glance — Oncor Electric Delivery Company, LLC (Oncor)

Static Var Compensation Project Description: Oncor has deployed the world’s largest cluster of Static Var Compensators (SVC) in the north Texas area, adding to the reliability of Oncor’s grid. This technology will maintain grid reliability in the urban environment as generators are retired and not replaced.

Project Cost: More than $50 million per site.

Project Status: The first unit was operational in Dallas in June 2009; a second unit was placed into service in December 2010 in another part of the greater Dallas/Fort Worth area, and two additional units were placed in service in early 2011, for a total of four installations in service.

Project Investment Partners: None.

Project Benefits: SVC technology will help in controlling and rapidly responding to changes in grid conditions. SVC provides the needed voltage control without the need for generation close to population centers. It will also accommodate for the future use of wind power and other forms of remote and renewable energy generation.

Edison Electric Institute 75 Otter Tail Power Company (OTP)

Company Background: • Otter Tail Power Company is an electric utility that has operations in three states (Minnesota, North Dakota, and South Dakota) serving 129,260 customers. • System-wide it has about 5,149 miles of transmission lines. • Between 2001 and 2010 Otter Tail Power has invested approximately $53 million into its transmission system.

CapX2020 Transmission Plan Project Description: The CapX2020 Transmission Plan consists of approximately 250 miles of new double- circuit, 345 kV transmission line between Brookings County, South Dakota, and Hampton, Minnesota, with a double-circuit capable line portion from Helena, Min- nesota to Hampton, Minnesota, plus a related 23 mile double-circuit capable, 345 kV transmission line between Lyon County, Minnesota and Hazel Creek, Minnesota; approximately 240 miles of new double-circuit capable, 345 kV transmission line between Fargo, North Dakota, and St. Cloud and Monticello, Minnesota; and approximately 70 miles of new single-circuit, 230 kV transmission line between Bemidji and Grand Rapids, Minnesota.

This project is a joint initiative of eleven transmission owning utilities, including Otter Tail Power Company, in the Upper Midwest to expand the electric transmission grid to ensure continued reliable service to the year 2020 and beyond.

The Brookings County - Hampton Project provides access to wind generation in southwest Minne- sota and eastern South Dakota. The line is expected to increase the delivery of wind generation by 700 MWs. While the other CapX2020 lines are driven primarily for reliability needs, they will also facilitate future generation outlet including wind development by providing the necessary infrastructure to support other wind-focused transmission additions. The Brookings County - Hampton Project was approved in December 2011 by the MISO Board of Directors as part of the Multi Value Project (MVP) Portfolio.

76 Edison Electric Institute Transmission Projects: At A Glance — Otter Tail Power Company (OTP)

Big Stone South to Brookings Project Project Description: The Big Stone - Brookings Project will consist of an approximately 70-mile long, 345 kV transmission line from a connection near Big Stone City, South Dakota to the Brookings County Substation near Brookings, South Dakota. It also will consist of two 2-mile long, 230 kV line from the Big Stone substation to a new Big Stone South substation.

Project Cost: Approximately $210 to $230 million depending on final route determination.

Project Status: This project was approved by the MISO Board of Directors in December of 2011 as a Multi-Value Project. The in service date of 2017.

Project Investment Partners: The project is being developed between Otter Tail and other utilities in the region.

Project Benefits: The Big Stone South - Brookings Project will address reliability problems in areas in portions of South Dakota and western and central Minnesota. In the MTEP process, MISO has determined that the Big Stone - Brookings Project is required for reliability in the region and designated the project as part of the MVP Portfolio of projects in Appendix A in MISO’s MTEP’11.

Edison Electric Institute 77 Transmission Projects: At A Glance — Otter Tail Power Company (OTP)

Big Stone South to Ellendale Project Project Description: The Big Stone South - Ellendale Project is an approximately 145 to 170-miles long, 345 kV transmission line between the Big Stone South Substation near Big Stone City, South Dakota and Ellendale Substa- tion near Ellendale, North Dakota.

Project Cost: Approximately $290 to $350 million depending on final route determination.

Project Status: This project is expected to be approved by the MISO Board of Directors in December of 2011 as a Multi-Value Project. The in service date of 2019.

Project Investment Partners: The project is being developed between Otter Tail and other utilities in the region.

Project Benefits: The Big Stone South – Ellendale Project will address reliability problems in areas in portions of North Dakota, South Dakota and western and central Minnesota. In the MTEP process, MISO has determined that the Big Stone – Ellendale Project is required for reliability in the region and designated the project as part of the MVP Portfolio of projects in Appendix A in MISO’s MTEP’11.

78 Edison Electric Institute Pacific Gas and Electric (PG&E)

Company Background: • PG&E serves over five million electric customers in northern California over a 74,000 square-mile service area. • PG&E owns and operates 18,500 circuit miles of electric transmission lines at voltages of 60 kV, 70 kV, 115 kV, 230 kV and 500 kV. • Between 2001 and 2010, PG&E recorded approximately $4.8 billion in electric transmission capital investment.

Central Valley 500 kV Study Project Description: The study considers the transmission needs in the Central Valley area of California including the evaluation of a new 500 kV transmission line that would run from near Bakersfield to Fresno and then north to a location west of Tracy (see map). Multiple routing alternatives are being considered to minimize impacts on land use. Elements of the project could meet the needs of other utilities in California (both CAISO members and non-CAISO members) and complement other transmission projects that have been proposed for development, sug- gesting a joint project could be attractive.

Previous studies in this area resulted in approximately $125 million of transmission upgrades either completed or in the process of being completed to maintain reliable electric service. Anticipated load growth in the Fresno area combined with new renewable energy projects in southern and central California now sug- gest a major transmission upgrade will need to be in place around the 2019 time frame. If found to be needed, the upgrades would likely be completed in phases.

Project Cost: Approximately $2 billion.

Project Status: The project is in the preliminary development stage with work focused on feasibility studies that would enable the use of existing corridors and facilities, engineering studies, and screening of potential project partners.

Project Investment Partners: None at this time.

Edison Electric Institute 79 Transmission Projects: At A Glance — Pacific Gas and Electric (PG&E)

Project Benefits: The study contemplates a multipurpose project that 1) would improve transmission reliability in the Greater Fresno Area, 2) increase the south-to-north power transfer capability in California, and 3) help meet California’s Renewables Portfolio Standard (RPS) goals by integrating renewable resources and delivering renewable power from remote locations to load centers on the grid. The project will also allow the operation of all three units in the pumping mode at Helms Pumped Storage Plant, providing incremental energy storage capability that would be increasingly valuable as more intermittent renewables are integrated into the grid.

80 Edison Electric Institute PEPCO Holdings, Inc. (PHI)

Company Background: • PHI delivers electricity to more than 1.9 million customers in Delaware, the District of Columbia, Maryland, New Jersey and Virginia. • PHI’s energy-related businesses include: • Pepco - a regulated electric utility delivering electricity to more than780,000 customers in Washington, D.C., and its Maryland suburbs; • Atlantic City Electric - a regulated electric utility serving more than 547,000 customers in southern New Jersey. • Delmarva Power - a regulated utility with more than 500,000 electric delivery customers in Delaware and the Delmarva Peninsula; and • System-wide there are approximately 3,747 circuit miles of transmission lines. • Between 2001 and 2010 PHI invested approximately $1.134 billion into its transmission system.

Transmission Related Smart Grid Initiatives: • PHI is incorporating a new DC technology, Voltage Source Convertor (VSC), into the Mid- Atlantic Power Pathway Project (MAPP) as described below.

Benning Transmission Project Project Description: The Benning Transmis- sion Project consists of two new 5.5 mile 230 kV underground transmission lines from Benning Station A, located in the northeast portion of the District of Columbia, to Pepco’s Ritchie Substa- tion, located in Seat Pleasant, Maryland. The project also includes the expansion of the 230 kV substation and the addition of a new 230/115 substation with two new 230/115 kV transformers. The project is required to resolve reliability problems arising from the retirement of Benning generating facility in District of Columbia.

Project Cost: Approximately $130 million.

Project Status: The project has received all the required regulatory approvals and permits and is currently under construction. At this time the project is approximately 50 percent completed. The estimated in service date for the project is June 1, 2012.

Project Investment Partners: None.

Edison Electric Institute 81 Transmission Projects: At A Glance — PEPCO Holdings, Inc. (PHI)

Project Benefits: The addition of this project will allow the retirement of approximately 550 MWs of ageing capacity at the Benning station. In addition, the project will maintain reliability of the electric system and ensure the continuity of electricity supply to the customers in the District of Columbia.

Mid-Atlantic Power Pathway (MAPP) Project Project Description: The MAPP Project consists of approximately 152 miles of new 500 kV extra high-voltage (EHV) transmission line, which will originate in northern Virginia, cross southern Maryland, cross under the Chesapeake Bay, travel across the Eastern Shore of Maryland, then travel into Delaware to Indian River, Delaware. In addition, PHI would add significant 230 kV support lines in Maryland to connect with the new transmission line. Most of the line would be built either on or parallel to the existing rights-of-way (ROW) and 52 miles would use existing towers. DC technology will be used to cross the Chesa- peake Bay. The DC technology will use Voltage Source Converter (VSC) technology.

Project Cost: Approximately $1.2 billion.

Project Status: As of August 2011, PJM has placed the MAPP project in abeyance with a 2019 - 2021 in-service date. Through the 2012 PJM stakeholder planning process, the in-service date will be re-evaluated

Project Investment Partners: None.

Project Benefits: This project will improve reliability for the District of Columbia, central and eastern Maryland and the Delmarva Peninsula. The project is intended to provide access to affordable generation from the south and west to supply congested areas in the Mid-Atlantic Region. It will also establish a tie to southern PJM and create multiple paths for importing power into the growing PJM regions.

82 Edison Electric Institute Transmission Projects: At A Glance — PEPCO Holdings, Inc. (PHI)

PJM N-1-1 Projects (Southern Delmarva) Project Description: The PJM N-1-1 Projects consist of constructing new and upgrading existing 138 kV and 230 kV infrastructure in the Southern Delmarva zone. Approximately 67 circuit miles of new transmission will be constructed. Additionally, 2-230/138 kV autotransformers and a 138 kV Static VAR Compen- sator (SVC) installation are part of the project. The N-1-1 efforts span the entire PHI service territory, however, an emphasis has been placed on the efforts in the Southern Delmarva zone due to the significant outage, resource, and environmental coordination which will be imperative to meet the required in service dates.

Project Cost: Approximately $151 million.

Project Status: There are many sub-projects within the overall N-1-1 initiative which will be completed over multiple years. The majority of projects which have been identified thus far have in service dates spanning from 2012-2017 and are in the engineering and regulatory approval phase. Within the state of Maryland, the requirement to procure Certificates of Public Convenience and Need (CPCN) ne- cessitate providing detailed information inclusive of the specifics of the projects well in advance of the in service date.

Project Investment Partners: None.

Project Benefits: The project will improve reliability for Maryland and the Delmarva Peninsula by placing the necessary infrastructure in place to mitigate the harmful effects of an N-1-1 event (as per NERC TPL-003 category C). Strengthening of the transmission system along the growing Delmarva Peninsula will be a beneficial outcome of the efforts. The N-1-1 projects will be complemented coin- cident with the completion of the MAPP project.

Edison Electric Institute 83 Progress Energy

Company Background: • Progress Energy’s subsidiaries serve about 3.1 million electric customers in the Carolinas and Florida. • The Carolinas service territory spans about 34,000 square- miles, and the Florida service territory spans about 20,000 square-miles in central Florida. • Progress has an 11,000 circuit mile, interconnected, power line network. • Between 2001 and 2010 Progress has invested approximately $1.9 billion into its transmission system.

Central Florida - 500/230 kV Capacity Increase Project Description: The Central Florida - 500/230 kV Capacity Increase project consists of replacing two existing 500/230 kV 750 MVA Central Florida transformers with two 500/230 kV 1120 MVA banks.

Project Cost: Approximately $50 million.

Project Status: The new facilities and materials are currently being received. This project is expected to occur in two phases. Phase I will be completed in the summer of 2012 and Phase II will be completed in the summer of 2013.

Project Investment Partners: None.

Project Benefits: This project benefits the regional transmission grid.

84 Edison Electric Institute Transmission Projects: At A Glance — Progress Energy

Harris Plant - RTP 230 kV Transmission Line Project Project Description: The Harris Plant - RTP 230 kV Transmission Line Project consists of approximately 14 miles of new 230 kV transmission line and con- verts seven miles of 115 kV transmission line to 230 kV from Harris Plant to a new RTP 230 kV Substa- tion.

Project Cost: Approximately $60 million.

Project Status: This project is under construction. The RTP 230 kV Substation and three miles of new line are in service. The remainder of the project is scheduled for completion by June 2014. All ROWs have been acquired and engineering is complete.

Project Investment Partners: None.

Project Benefits: This project benefits the regional transmission grid.

Richmond Plant - Ft. Bragg Woodruff St. 230 kV Transmission Line Project Project Description: The Richmond Plant - Ft. Bragg Woodruff St. 230 kV Transmission Line Project consists of approximately 64 miles of new 230 kV transmission line from Richmond Plant to Ft. Bragg Woodruff St. 230 kV Substation.

Project Cost: Approximately $83 million.

Project Status: This project was placed in service in May 2011. Modifications at the Ft. Bragg Woodruff St. 230 kV Substation and six miles of new line were in service in 2010.

Project Investment Partners: None.

Project Benefits: This project allows power to be delivered from the Richmond Plant and benefits the regional transmission grid.

Edison Electric Institute 85 Public Service Electric and Gas Company (PSE&G)

Company Background: • Public Service Electric and Gas Company (PSE&G) serves 2.2 million electric customers and 1.8 million gas customers in New Jersey. These residential business customers reside in a 2,600 square-mile diagonal corridor across the state from Bergen to Gloucester Counties. • System-wide there are approximately 1,400 circuit miles of transmission line. • Between 2001 and 2010 PSE&G has invested approximately $1.17 billion into its transmission system.

Transmission Related Smart Grid Initiatives: • PSE&G along with PJM and 11 other PJM Transmission Owners, with support from Quanta Technology, Electric Power Group, and Virginia Tech, are deploying SynchroPhasor technology across the PJM footprint.

Burlington - Camden 230 kV Network Reinforcement Project Project Description: The Burlington - Camden 230 kV Network Reinforcement Project consists of upgrading 37 circuit miles (30 miles of overhead and seven miles of underground) of transmission operating from 138 kV to 230 kV, constructing a new 230 kV switching station at Burlington and converting five existing stations to 230 kV operation. The upgraded stations are Levittown, Cinnaminson, Cam- den, Gloucester and Cuthbert Boulevard. This project is a proposed electric reliability transmission baseline upgrade to the PJM transmission system, extending from the Burl- ington Switching Station to the Camden Switching Station and continuing on to the Gloucester Switching Station in Southern New Jersey. PSE&G will be responsible to design, procure and construct all transmission facilities within the scope of this project. All circuits to be upgraded are located within existing rights-of-way (ROW) between Burlington and Gloucester Switching Stations.

Project Cost: Approximately $381 million.

86 Edison Electric Institute Transmission Projects: At A Glance — Public Service Electric and Gas Company (PSE&G)

Project Status: This project was approved by the PJM Board of Managers in February 2010 with an in service date of June 1, 2014. The project is currently 50% engineered and will be ready for licensing and permitting in the first quarter of 2012.

Project Investment Partners: None.

Project Benefits: The project is needed to maintain transmission system reliability by addressing several PJM-identified voltage violations that are anticipated to occur beginning in 2014. The project will prevent these violations and reinforce the transmission system in Southern New Jersey.

Northeast Grid Reliability Transmission Project (formerly Roseland - Hudson 230 kV Conversion Baseline Transmission Project) Project Description: The Northeast Grid Reli- ability Transmission Project consists of upgrading approximately 50 miles of overhead transmission circuits from 138kV to 230kV operation, constructing a new 230kV underground circuit from Bergen to Athenia Stations looping through Saddle Brook Station, constructing a new underground circuit from South Waterfront to Hudson Stations and upgrading the 230kV or converting to 230kV operation at 12 existing stations. Those stations are Roseland, West Caldwell, Cook Road, Kingsland, Turnpike, Kearny, Es- sex, Hudson, Bergen, Saddle Brook, Athenia and South Waterfront. This is a proposed electric reliability transmission baseline upgrade to the PJM transmission system. PSE&G will be responsible to design, procure and construct all transmission facilities within the scope of this project. All overhead transmission circuits to be upgraded are located within existing ROW between Hudson and Roseland Stations. The two new underground circuits may require acquisition of a new ROW as the route has not been finalized at this time.

Project Cost: Approximately $895 million.

Project Status: This project was approved by the PJM Board of Managers in October 2010. The projected in service date for this project is June 1, 2015. The project is currently in the initial engineering/ design phase. Permit applications are being prepared.

Project Investment Partners: None.

Project Benefits: This project is needed to maintain transmission system reliability by addressing several PJM-identified voltage violations that are anticipated to occur beginning in 2015. The project will prevent these violations and reinforce the transmission system in northern New Jersey.

Edison Electric Institute 87 Transmission Projects: At A Glance — Public Service Electric and Gas Company (PSE&G)

Susquehanna - Roseland 500 kV Transmission Line Project Project Description: The Susquehanna - Rose- land 500 kV Transmission Line Project consists of approximately 45 miles of new 500 kV transmission line running from the Delaware Water Gap east to the Roseland Switching Station, and two new 500 kV switching stations; one in Hopatcong and one in Roseland. This project is a proposed electric reliability transmission baseline upgrade to the PJM transmission system, extending from the Berwick area in Pennsylvania to the Roseland-East Hanover area in northern New Jersey. PSE&G will construct the New Jersey portion of the project, while PPL Electric Utili- ties will construct the Pennsylvania portion of the project. All of the circuits in New Jersey will be built along existing ROW by removing existing 230 kV circuits between Roseland, Montville, New- ton and Bushkill, Pennsylvania and building 500/230 kV tower lines in their place.

Project Cost: Approximately $1.23 billion, of which approximately $750 million will be PSE&G’s responsibility.

Project Status: This project was approved by the PJM Board of Managers in June 2007 with an in service date of June 1, 2012. The National Park Service (NPS) review of that portion of the Project to be built in the Delaware Water Gap National Park is currently anticipated to be concluded in October 2012. Based on the anticipated completion of the NPS review, the Roseland to Hopatcong portion of the Project is currently expected to be in-service by June 2014. The remainder of the Project is anticipated to be completed by June 2015.

Project Investment Partners: PPL Electric Utilities.

Project Benefits: The project is needed to maintain reliability by addressing several PJM-identified reliability criteria violations that are anticipated to occur beginning in 2012. The project will prevent overloads on existing power lines in New Jersey and Pennsylvania.

88 Edison Electric Institute Transmission Projects: At A Glance — Public Service Electric and Gas Company (PSE&G)

North-Central Reliability Project (formerly the West Orange 230kV Project) Project Description: The North-Central Reli- ability Project consists of upgrading four 138kV transmission lines and six existing stations to 230kV operation. The upgraded stations are West Orange, Marion Drive, Laurel Avenue, Fanwood, New Dover and Woodbridge. This project is a proposed electric reliability transmission baseline upgrade to the PJM transmission system, extending from the West Orange Switching Station to the Sewaren Switching Station in Central New Jersey. PSE&G will be responsible to design, procure and construct all transmission facilities within the scope of this project. All circuits to be upgraded are located within existing ROW between West Orange and Sewaren Switching Stations.

Project Cost: Approximately $390 million.

Project Status: This project was approved by the PJM Board of Managers in February of 2010 with an in service date of June 1, 2014. The project is currently in the planning and detailed engineering phase. The Project was submitted for BPU approval in May of 2011 with an anticipated response by March of 2012. Construction is scheduled to begin in the spring of 2012.

Project Investment Partners: None

Edison Electric Institute 89 Transmission Projects: At A Glance — Public Service Electric and Gas Company (PSE&G)

Mickleton-Gloucester-Camden Reinforcement Project Project Description: The Mickleton-Gloucester- Camden Reinforcement Project (referred to as Southern Reinforcement Project) scope consists of building 2 new 230-kV underground circuits from Gloucester Switch to Camden Switch looping one into Cuthbert Boulevard Substa- tion, building a second parallel overhead circuit from Gloucester Switch to Atlantic City Elec- tric’s Mickleton Station, and re-conductoring the existing Gloucester–Mickleton and Cam- den-Richmond 230kV circuit. The project will install 36 miles of transmission line, 12 miles of overhead reconductoring, 10 miles of new overhead, and 14 miles of new underground. The station upgrades will be completed at Mickleton, Thorofare, Deptford, Eagle Point, Cuthbert, Gloucester and Camden. PSE&G will be responsible to design, procure and construct all transmission facilities within the scope of this project. The required PJM project in-service date is June 2015.

Project Cost: Approximately $435 million.

Project Status: This project was approved by the PJM Board of Managers in February 2010 with an in service date of June 1, 2015. The project is currently in the planning and detailed engineering phase. Construction is scheduled to begin in the 4th quarter of 2012.

Project Investment Partners: None.

Project Benefits: The project is needed to maintain transmission system reliability by addressing several PJM-identified thermal overloads that are anticipated to occur beginning in 2015. The project will prevent these violations and reinforce the transmission system in Southern New Jersey.

90 Edison Electric Institute SOUTHERN CALIFORNIA EDISON (SCE)

Company Background: • SCE provides power to 180 cities in 50,000 square- miles encompassing 11 counties in central, coastal and Southern California serving 13 million people and nearly 300,000 businesses. • The SCE-owned transmission grid is under the operational control of the CAISO. • SCE’s system consists of over 12,000 circuit miles of transmission lines. • Between 2005 and 2010 SCE invested over $1.6 billion of capital in transmission projects. • SCE plans to invest over $4.6 billion (estimated direct costs in nominal dollars, excluding corporate overheads) of capital in transmission projects from 2011 through 2015.

Transmission Related Smart Grid Initiatives: • SCE is also making substantial investments in advanced technologies that will move SCE towards a more integrated Smart Grid. Two such projects are the Wide-Area Situation Awareness System (WASAS) and Centralized Remedial Action System (CRAS).

Eldorado – Ivanpah Transmission Project (EITP) Project Description: The EITP project consists of a new 220/115kV substation near Primm, Nevada and approximately 35 miles of new double-circuit, 220 kV transmission line that extends from the Ivanpah Dry Lake Area in southern California to Eldorado Substation in southern Nevada. EITP will provide greater access to the renewable resource rich areas of the Mojave Desert along the California - Ne- vada border around Primm, Nevada.

Project Cost: Approximately $440 million (estimated direct costs in nominal dollars, excluding corporate overheads).

Project Status: CPUC and Bureau of Land Management permitting was completed in May 2011. Construction is forecast to begin by second quarter 2012, to meet the forecast in-service date of July 2013.

Project Investment Partners: None.

Project Benefits: EITP will support renewable generation development, assisting California in meeting Renewables Portfolio Standard (RPS) goals.

Edison Electric Institute 91 Transmission Projects: At A Glance — SOUTHERN CALIFORNIA EDISON (SCE)

San Joaquin Cross Valley Loop (SJXVL) Project Description: The SJXVL project consists of approximately 23 miles of new and upgraded double-circuit, 220 kV high-voltage transmission line and associated substation facilities. SJXVL will extend from Rector Substation located in Visalia, California and traverse portions of the San Joaquin Valley to a location near Woodlake in Tulare County, California.

Project Cost: Approximately $190 million (estimated direct costs in nominal dollars, excluding corporate overheads).

Project Status: CPUC project approval based on SCE’s route alternative 2 was granted in July 2010. Land acquisition activities are in escrow or condemnation proceedings. As of October 2011, SCE engaged in the development of a Section 10 - Habitat Conservation Plan (HCP) consultation after the Army Corp of Engineering declined to accept the role as lead Federal Agency on the project. Construction activities have been separated into four work packages to allow for construction to commence in non-environmentally sensitive areas of existing right-of way in second quarter 2012. SCE is working to minimize the impacts of the HCP and keep the project on schedule for the current in service date of March 2014.

Project Investment Partners: None.

Project Benefits: This project will improve the reliability of the California transmission grid by increasing the transmission capacity between the Big Creek Hydroelectric Project and Rector Substa- tion to mitigate overload conditions; serve forecasted electrical demand in the southeastern portion of the San Joaquin Valley; reduce the need to interrupt customer electrical services under transmission line outage conditions; and minimize the need to reduce Big Creek Hydroelectric Project generation under transmission line outage conditions.

92 Edison Electric Institute Transmission Projects: At A Glance — SOUTHERN CALIFORNIA EDISON (SCE)

Tehachapi Renewable Transmission Project (TRTP) Project Description: The TRTP is an 11 segment project consisting of new and upgraded 220 kV and 500 kV transmission lines and associated substations built primarily to assist the development of renewable energy generation projects in remote areas of eastern Kern County, California. Segments 1-3 consists of 83 miles of new transmission and TRTP Segments 4-11 consists of 173 miles of transmission.

TRTP Segments 1-3 are specific to theT ehachapi Wind Resource Area in southern Kern County and Los Angeles County, and include:

• Segment 1: 26.5 miles of 500 kV transmission line from Santa Clarita to Lancaster; • Segment 2: 21 miles of new 500 kV and 220 kV transmission lines and modifications at the Vincent Substation to Lancaster; • Segment 3a: 25.6 miles of 500 kV and 220 kV transmission lines connecting SCE’s Antelope Substation in Lancaster to a new substation west of Mojave in Kern County; and • Segment 3b: 9.6 miles of 220 kV transmission line from Mojave to east of Tehachapi. • TRTP Segments 4-11 are specific to new and upgraded electric transmission lines and substations between eastern Kern County and San Bernardino County, and include: • Segment 4: Construction of the new 15-mile 500 kV transmission line from Whirlwind Substation to Vincent Substation. Construction would be in a new ROW, parallel to the existing ROW; • Segment 5: Construction of a new 18 mile 500 kV transmission line that would connect SCE’s existing Antelope Substation with SCE’s existing Vincent Substation near Acton. This new line would be built next to an identical existing 500 kV line and would replace two 220 kV lines that would be removed. An existing ROW would be utilized. This new line would be initially energized at 220 kV; • Segment 6: Replacement of approximately 16 miles of an existing 220 kV transmission line that runs from SCE’s existing Vincent Substation to the southern edge of the Angeles National Forest (ANF) near the city of Duarte with a new 500 kV transmission line that would initially be energized at 220 kV. An existing ROW would be utilized. Replacement of approximately five miles of an existing SCE 220 kV transmission line between Vincent Substation and the northern border of the ANF with a new 500 kV transmission line; • Segment 7: Replacement of 15 miles of the existing 220 kV line from the ANF border near the city of Duarte south to SCE’s existing Rio Hondo Substation in the city of Irwindale and then continuing southwest across various San Gabriel Valley cities toward SCE’s existing Mesa Substation in the Monterey Park/Montebello area with a double-circuit, 500 kV transmission line.

Edison Electric Institute 93 Transmission Projects: At A Glance — SOUTHERN CALIFORNIA EDISON (SCE)

Existing ROWs would be utilized and various lower-voltage subtransmission lines between the Rio Hondo and Mesa Substations would require relocation within existing ROW or public ROW; • Segment 8: Replacement of existing single-circuit, 220 kV line that runs from the existing Mesa Substation area to the Chino Substation area and existing double-circuit, 220 kV line from Chino Substation to the existing Mira Loma Substation with a 33 mile double-circuit, 500 kV line. Replacement of approximately seven miles of existing 220 kV line that run from SCE’s Chino Substation to its Mira Loma Substation located in the city of Ontario with a double-circuit, 220 kV line. Existing ROWs would be utilized except for where approximately three miles of new ROW would be required in limited areas. Various lower-voltage sub-transmission lines in the Chino area would require relocation within existing ROW or public ROW; • Segment 9: Installation of equipment and upgrades at Antelope, Vincent, Windhub and Whirlwind Substations to connect new 220 kV and 500 kV transmission lines to facilitate interconnection of renewable resources; • Segment 10: Construction of 17 miles of new single-circuit, 500 kV transmission line to connect the proposed Whirlwind Substation (Segment 4) with the Windhub2 Collector substation. New ROW would be required; and • Segment 11: Replacement of approximately 20 miles of 220 kV transmission line between the existing Vincent Substation and Gould Substation near La Cañada Flintridge with 17 miles of new single-circuit, 500 kV transmission line. Installation of a second 220 kV transmission line on the currently empty side of the transmission towers that already extend from the area of Gould Substation across various San Gabriel Valley cities to the area of Mesa Substation in Monterey Park. An existing ROW would be utilized.

Project Cost: Approximately $2.5 billion (estimated direct costs in nominal dollars, excluding corporate overheads).

Project Status: Regulatory approvals granted for Tehachapi Segments 4-11 including: CPUC CPCN in December 2009, US Forest Service Biological Opinion in July 2010, US Forest Service Record of Deci- sion (ROD) in October 2010, US Army Corp of Engineers ROD in February 2011, and Angeles National Forest Special Use Permit in September 2011. Construction on segments 4-11 began in 2010. SCE filed a Petition for Modification with the CPUC in October 2011 and a decision is still pending. Segments 1-3a and Windhub substation are in service. Whirlwind and Highwind substations and several segments are in construction. Forecast in service dates range from 2012 through 2015.

Project Investment Partners: None.

Project Benefits: TRTP will support interconnection of up to 4,500 MWs of generation, most of which are expected to be renewable resources. This will assist California to meet its RPS goals; improve the reliability of the California transmission grid by enabling the expansion of the transfer capability of Path 26; serve load growth in the Antelope Valley; and ease transmission constraints in the Los Angeles basin.

94 Edison Electric Institute Transmission Projects: At A Glance — SOUTHERN CALIFORNIA EDISON (SCE)

South of Kramer (SOK) Project Description: The South of Kramer project consists of approximately 63 miles of primarily double-circuit, 220 kV transmission line between SCE’s existing Coolwater 220/115 kV Substation in Daggett, through a new Jasper 220kV Substation which will be a new point of interconnection for new renewable generation, and SCE’s existing Lugo 500/220 kV Substation in Hesperia, California. In addition, the project involves siting of a future 500/220 kV Desert View Substation between the new Jasper Substa- tion and SCE’s existing Lugo Substation, and 16 miles of transmission line between Desert View & Lugo substations, consisting of 500 kV single circuit transmission line and towers, initially energized at 220 kV until the future Desert View Substa- tion becomes operational.

Project Cost: Approximately $500 million(estimated direct costs in nominal dollars, excluding corporate overheads).

Project Status: The SOK project is in the early development stage. Site and route evaluation, com- munity and agency outreach and other pre-licensing activities are underway. SCE is targeting to file a CPCN with the CPUC in 2013 with a forecast in service date of April 2018.

Project Investment Partners: None.

Project Benefits: Construction of SOK will remedy the reliability and congestion problems that would result from the development and interconnection of over 2,400 MWs of renewable solar and wind generation in the Mojave Desert region of southern California.

Edison Electric Institute 95 Transmission Projects: At A Glance — SOUTHERN CALIFORNIA EDISON (SCE)

West of Devers (WOD) Project Description: The proposed West of De- vers facilities will be located in San Bernardino and Riverside Counties in Southern California. WOD entails the removal and rebuilding of five existing 220 kV lines (Devers-Vista #1 and #2 Devers-San Bernardino, Devers-El Casco, and El Casco-San Bernardino. The upgraded 220 kV lines are needed to allow full delivery of multiple generation projects interconnecting at SCE’s new Colorado River and Red Bluff Substations.

Project Cost: Approximately $600 million (estimated direct costs in nominal dollars, excluding corporate overheads).

Project Status: The WOD project is in the early development stage. Site and route evaluation, com- munity and agency outreach and other pre-licensing activities are underway. SCE is targeting to file a CPCN with the CPUC in 2012 with a forecast in service date of December 2017.

Project Investment Partners: None.

Project Benefits: Construction of West of Devers will increase the transfer capability of the existing WOD corridor and provide for the full delivery of new renewable solar generation being developed in California.

Centralized Remedial Action Schemes (CRAS) Project Description: The Centralized Remedial Action Schemes (CRAS) project will centralize control and operation of SCE’s special protection systems on the SCE transmission grid. The CRAS will transition existing special protection systems from an Intelligent Electronic Device (IED) at substations to a redundant and highly secure centralized processing system. The CRAS will accommodate complex special protection systems that would not be possible with individual IED systems.

Project Cost: Approximately $20 million (estimated direct costs in nominal dollars, excluding corporate overheads).

Project Status: Preliminary design completed and evaluating responses to Request for Proposal.

Project Investment Partners: None.

Project Benefits: The CRAS will 1) enhance coordination and effectiveness of existing special protection technology; 2) enhance ability to build new schemes to enable a more efficient generator interconnection process; and 3) improve efficiency of managing and maintaining existing and new special protection systems.

96 Edison Electric Institute Transmission Projects: At A Glance — SOUTHERN CALIFORNIA EDISON (SCE)

Wide-Area Situation Awareness System (WASAS) Project Description: WASAS involves the installation of combined Digital Fault Recorder/Phasor Measurement Unit (DFR/PMU) devices to enable SCE 500 kV and 220 kV transmission substations to have SynchroPhasor measurement capability. WASAS will be able to exchange SynchroPhasor data with other Western Electricity Coordinating Council (WECC) utilities and system operators through the Western Interconnection Synchrophasor Program (WISP).

Project Cost: Approximately $40 million (estimated direct costs in nominal dollars, excluding corporate overheads).

Project Status: A pilot of the DFR/PMU devices, vendor selection, and engineering and design standards are completed. The system is forecast to be in service in 2013.

Project Investment Partners: None.

Project Benefits: WASAS will provide SCE with information regarding events within and outside of SCE’s service territory that could negatively impact customers. WASAS will also enable SCE to col- laborate with the CAISO and WECC to proactively address issues that may put the electrical grid at risk of undue stress.

Edison Electric Institute 97 Southern Company

Company Background: • With 4.4 million customers, Southern Company utilities serve a 120,000 square-mile service territory spanning most of Georgia and Alabama, southeastern Mississippi, and the panhandle region of Florida. • Southern Company owns four regulated retail electric utilities: Alabama Power; Georgia Power; Gulf Power; and Mississippi Power. • System-wide there are approximately 27,000 circuit miles of transmission line. • Between 2001 and 2010 Southern Company invested over $3.8 billion of capital into its transmission system.

Transmission Related Smart Grid Initiatives: • Southern Company has been utilizing Smart Grid technologies for a number of years through its robust communication network and data acquisition and outage management tools that optimize system performance and reliability. Southern Company is proposing to invest over $140 million through 2013 by installing Smart Grid technologies that advance Smart Substation applications, Transmission Line Automation and Phasor Measurement Unit’s (PMU).

East Pelham 230/115 kV Transmission Substation Project Project Description: The East Pelham 230/115 kV Transmission Substation project includes approximately one mile of new single-circuit, 230 kV transmission line; 33.5 miles of new single- circuit, 115 kV transmission line; upgraded structures on approximately 18 miles of single-circuit, 230 kV transmission line; constructs a new 400 MVA, 230/115 kV substation on a 26 acre site; and constructs two new 115 kV switching stations (Alabaster and Westover).

Project Cost: Approximately $57 million.

Project Status: This project is currently scheduled to be in service the summer of 2014.

Project Investment Partners: None.

Project Benefits: This project will meet load growth in the Birmingham, Alabama area. This project will also alleviate thermal overloads and reduce transmission losses in the Birmingham, Alabama area.

98 Edison Electric Institute Transmission Projects: At A Glance — Southern Company

Holmes Creek - Highland City 230 kV Transmission Line Project Project Description: The Holmes Creek - Highland City 230 kV Transmission Line Project consists of approximately 73 miles of new single-circuit, 230 kV transmission line from the Holmes Creek Substation to the Highland City Substation (in the northeastern area of the Florida Pan- handle).

Project Cost: Approximately $120 million.

Project Status: This project is currently scheduled to be in service the summer of 2015.

Project Investment Partners: None.

Project Benefits: This project is for load growth and reliability in the central Panhandle, Panama City, and Destin areas of Florida.

Kemper County IGCC Plant Project Description: The Kemper County IGCC Plant project consists of a new 600 MW IGCC plant constructed by Mississippi Power Com- pany. Transmission improvements associated with this plant consist of a 230 kV switchyard and collector bus; two new 230 kV switching stations; a new 230/115 kV substation in Meridian, MS; approximately 55 miles of new 230 kV transmission line; ten miles of new 115 kV transmission line; and upgrades to 24 miles of existing 115 kV transmission line in Kemper County and Merid- ian areas of Mississippi.

Project Cost: Approximately $120 million.

Project Status: This project is currently scheduled to be in service the summer of 2014.

Project Investment Partners: None.

Project Benefits: The new generation and transmission improvements will meet the future network resource requirements for Mississippi Power Company.

Edison Electric Institute 99 Transmission Projects: At A Glance — Southern Company

M obile Area Network Project Project Description: The Mobile Area Network Project consists of constructing a 115 kV six terminal switching station at North Crichton; approximately 14 miles of new single- circuit, 115 kV transmission line; reconductoring 28 miles of existing single and double-circuit, 115 kV transmission line; and installing associated network switches and distance relaying.

Project Cost: Approximately $65 million.

Project Status: This project is currently scheduled to be in service the summer of 2016.

Project Investment Partners: None.

Project Benefits: This project is for infrastructure reliability and operational flexibility in the Mobile Metropolitan area of Mobile County, Alabama.

Plant Smith - Laguna Beach - Santa Rosa 230 kV Transmission Line Project Project Description: The Plant Smith - Laguna Beach - Santa Rosa 230 kV Transmission Line Project consists of converting 14 miles of existing single-circuit, 115 kV line to 230 kV operation between Plant Smith and Laguna Beach Sub- stations; a second 230 kV Autobank at Laguna Beach Substation; converting 21 miles of existing single-circuit, 115 kV transmission line to two 230 kV transmission lines between Laguna Beach and Santa Rosa Substations; and a new Santa Rosa 230 kV Substation with two, 400 MVA transformer banks (in the Central Florida Panhandle, Destin, and Panama City Beach areas).

Project Cost: Approximately $80 million.

Project Status: This project is currently scheduled to be in service the summer of 2015.

Project Investment Partners: None.

Project Benefits: This project is for load growth and reliability in the Panama City and Destin areas of the Florida Panhandle.

100 Edison Electric Institute Transmission Projects: At A Glance — Southern Company

Plant Vogtle Network Improvement Project Project Description: The Plant Vogtle Network Improvement Project consists of approximately 50 miles of new single-circuit, 500 kV transmission line between Vogtle and Thomson 500/230 kV Substations, and expanding the 500 kV switchyard at Plant Vogtle.

Project Cost: Approximately $123 million.

Project Status: This project is currently scheduled to be in service the summer of 2016.

Project Investment Partners: None.

Project Benefits: This project will address generator stability issues related to the expansion of the existing Plant Vogtle facility.

South Tuscaloosa - Eutaw Area Network Project Project Description: The South Tuscaloosa - Eutaw Area Network Project consists of 23 miles of new single-circuit, 115 kV transmission line from Epes Substation to the Eutaw Substation; a new 230/115 kV substation at South Duncanville; a new 115 kV three terminal switching station at Epes Substation; approximately 50 miles of new single- circuit, 115 kV transmission line; reconductoring 15 miles of existing single-circuit, 115 kV transmission line; converting two 46 kV substations to 115 kV operation; and approximately 25 miles of new single-circuit, 115 kV transmission line on existing 46 kV rights-of-way (ROW).

Project Cost: Approximately $110 million.

Project Status: This project is currently scheduled to be in service the summer of 2015.

Project Investment Partners: None.

Project Benefits: This project is for infrastructure reliability and operational flexibility in the Tuscaloosa County and Greene County areas of Alabama.

Edison Electric Institute 101 Transmission Projects: At A Glance — Southern Company

Douglas - Pine Grove Primary 230kV Line Project Project Description: The Douglas - Pine Grove 230kV line project consists of approximately 53 miles of new single-circuit, 230kV transmission line between Douglas 230/115kV and Pine Grove Primary 230/115 kV Substa- tions.

Project Cost: Approximately $71 million.

Project Status: This project is currently scheduled to be in service the summer of 2019.

Project Investment Partners: None.

Project Benefits: This project is for infrastructure reliability in the Tifton and Valdosta areas of Georgia.

102 Edison Electric Institute Vermont Electric Power Company (VELCO)

Company Background: • VELCO was formed in 1956 when local utilities joined together to create the nation’s first statewide, “transmission only” company in order to provide access to clean hydro power and build and maintain the state’s high-voltage transmission grid. • VELCO manages a system that includes 712 circuit miles of transmission lines and 51 substations. • Between 2006 and 2011, VELCO has invested approximately $600 million into its transmission system and have approximately $480M of planned transmission upgrades in the next 5 years. • VELCO is also the managing entity for the statewide Smart Grid deployment program with all the state’s distribution utilities. The program of work is estimated at $138M for which the Vermont Electric Utilities were awarded approximately $69M in ARRA funds.

Central Vermont Upgrade Project Description: This project involves building approximately 27.1 miles of new 345 kV transmission lines between Coolidge and W. Rutland Substations in Central Vermont. This project also includes the expansion of the existing Coolidge and W. Rutland Substations to accommodate this new Line.

Project Cost: Approximately $157 million.

Project Status: The project is under planning review with a projected in service date end of 2016.

Project Investment Partners: None.

Project Benefits: This project addresses load growth in central Vermont as well as voltage violations and transmission facilities overload as identified in the company’s Long Range Transmission Plan. Accordingly the existing W. Rutland and Coolidge substations will be modified to accommodate this new line to meet present and future system needs.

Edison Electric Institute 103 Transmission Projects: At A Glance — Vermont Electric Power Company (VELCO)

Connecticut River Valley Upgrades Project Description: The project involves the addition of a second 17.2 mile, 345 kV transmission line operated at 115kV from VELCO’s Coolidge Substation to Ascutney Substation. The project includes the expansion of Coolidge and Ascutney Substations to accommodate the new line.

Project Cost: Approximately $93 million.

Project Status: This project is under permitting development and is scheduled to be put in service in summer of 2016.

Project Investment Partners: None.

Project Benefits: This project addresses a western/eastern New England load area system deficiency between Vermont, western Massachusetts, Connecticut and New Hampshire, Maine, Eastern Mas- sachusetts and Rhode Island. The overload is affected by power transfer between these regions. The project as designed will address these areas of concern and meet present and future system needs.

Substations Additions and Upgrades Project Description: The project involves building a new 115kV substation, the refurbishment of a HVDC controls and cooling system’s converter station, and rebuilding three 115kV substations interconnecting the transmission and sub-transmission networks. The three stations rebuilt will be in a ring configuration to meet reliability needs as identified by the planning studies. They interconnect the 115kV, 46kV systems. The substations are located in Georgia, Ascutney and Bennington townships. The new substation in Jay town- ship interconnects the 115kV and 46kV systems. The refurbishment of the controls and cooling system of the HVDC Back to Back converter station interconnecting VELCO and HQ TransEnergie transmission network is located in the town of Highgate.

Project Cost: Approximately $120 million.

Project Status: These substations are under construction and final permitting and are scheduled to be put in service between fall 2012 and spring 2013.

Project Investment Partners: None.

Project Benefits: This project addresses system deficiency of large load area of VELCO’s transmission network. The substations as designed improve the reliability of the 115kV transmission network and it interconnection to the sub-transmission system.

104 Edison Electric Institute Westar Energy, Inc.

Company Background: • Westar Energy is an investor-owned, vertically integrated electric utility serving 686,000 retail customers in Kansas. Westar has served Kansas for more than 100 years and is the state’s largest electric utility. • Westar Energy has about 7,100 MWs of electric generation capacity. • System-wide there are approximately 4,388 circuit miles of 69 kV and above transmission line. • Westar Energy is a member of the Southwest Power Pool (SPP). • Between 2001 and 2010 Westar Energy has invested almost $656 million into its transmission system.

Rose Hill - Sooner 345 kV Transmission Line Project Description: The Rose Hill - Sooner 345 kV Transmission Line project consists of approximately 49 miles of new 345 kV transmission line from Rose Hill Substation to the Kansas-Oklahoma border, constructed by Westar Energy. Oklahoma Gas and Electric (OG&E) will build the line from the Kansas-Oklahoma border to the Sooner Substation.

Project Cost: Westar Energy’s cost is approximately $80.2 million.

Project Status: This project has been approved as part of a SPP transmission service request and will enable additional economic transfers and enhance regional transmission reliability. Westar Line construction is 100% complete and the project is estimated to be in service by April 2012.

Project Investment Partners: OG&E.

Project Benefits: This project is required for transmission service and will also enable additional transfer capability for the region.

Edison Electric Institute 105 Transmission Projects: At A Glance — Westar Energy, Inc. Prairie Wind Transmission, LLC

Company Background: • Prairie Wind Transmission, LLC., is a joint venture formed by Westar Energy and Electric Transmission America (ETA), a joint venture of subsidiaries of American Electric Power (AEP) and MidAmerican Energy Holdings Company, to build and own new electric transmission assets in Kansas.

Wichita - Medicine Lodge - Woodward 345 kV Transmission Line Project Description: The Wichita - Medicine Lodge - Woodward 345 kV Transmission Line project consists of approximately 110 miles of new double-circuit, high-voltage, 345 kV transmission line linking a new 345 kV substation near Wichita, Kansas to a new 345 kV substation northeast of Medicine Lodge, Kansas, near the new Flat Ridge Wind Farm jointly owned by Westar Energy and BP Alternative, and then south to the Kansas-Oklahoma border. OG&E will build the line from the border to Woodward Substation.

Project Cost: Prairie Wind Transmission’s cost is approximately $225 million.

Project Status: SPP has approved the project as a 345 kV double-circuit. The final route selection was approved by the Kansas Corporation Commission in June 2011. Land acquisition is in progress and line construction is scheduled to begin in summer of 2012. The project is estimated to be in service by late 2014.

Project Investment Partners: Westar Energy and ETA.

Project Benefits: The project will enhance electricity transport capabilities across SPP and Kansas and will support expansion of renewable electricity generation in the region.

106 Edison Electric Institute Xcel Energy Inc.

Company Background: • Xcel Energy Inc. has operations in ten western and midwestern states (Colorado, Kansas, Michigan, Minnesota, New Mexico, North Dakota, Oklahoma, South Dakota, Texas and Wisconsin) serving 3.3 million electric customers. • Northern States Power (NSP) Companies, Public Service of Colorado (PSCo) and Southwestern Public Service (SPS) are subsidiaries of Xcel Energy Inc. • System-wide there are approximately 18,100 circuit miles of transmission line. • Between 2001 and 2010, Xcel Energy invested over $2.5 billion into the transmission systems of the Xcel Energy Operating Companies.

Transmission Related Smart Grid Initiatives: • Xcel Energy launched its SmartGridCityTM Project in Boulder, CO in 2008. It is the nation’s first comprehensive demonstration and test of Smart Grid technologies. Xcel Energy has brought together a consortium of leading technologists, engineering firms, business leaders and IT experts to create a much-improved grid for the digital age. Northern States Power Companies (NSP Companies)

Company Background: • Northern States Power Company (NSPM), a Minnesota corporation, and Northern States Power Company (NSPW), a Wisconsin corporation (jointly NSP Companies), operate an integrated system in Minnesota, North Dakota and South Dakota, and Wisconsin and the Michigan Upper Peninsula. • The NSP Companies have approximately 1.4 million retail and wholesale customers, and operate approximately 7,210 circuit miles of transmission.

Transmission Related Smart Grid Initiatives: • NSP is participating in the Midwest ISO’s SynchroPhasor Project installing equipment at power plants to track the relative phase angle of generators on the grid.

Edison Electric Institute 107 Transmission Projects: At A Glance — Xcel Energy Inc.

CapX2020 Transmission Plan Project Description: The CapX2020 Transmission Plan consists of approximately 240 miles of new double-circuit, 345 kV transmission line between Brookings County, South Dakota, and Hampton, Minnesota, with a single-circuit line portion from Lake Marion, Minnesota to Hampton, Minnesota, plus a related 23 mile double-circuit, 345 kV transmission line between Lyon County, Minnesota and Hazel Creek, Minnesota; approximately 240 miles of new single-circuit, 345 kV transmission line between Fargo, North Dakota, and St. Cloud and Monticello, Minnesota; approximately 150 miles of new single- circuit, 345 kV transmission line between Hampton and Rochester, Minnesota, continuing to La Crosse, Wisconsin; and approximately 70 miles of new single- circuit, 230 kV transmission line between Bemidji and Grand Rapids, Minnesota.

This project is a joint initiative of eleven transmission owning utilities, including the NSP Companies, in the Upper Midwest to expand the electric transmission grid to ensure continued reliable service to 2020 and beyond.

The Brookings County - Hampton Project provides access to wind generation in southwest Minne- sota and eastern South Dakota. The line is expected to increase the delivery of wind generation by 700 MWs. While the other lines are driven primarily for reliability needs, they will also facilitate future wind development by providing the necessary infrastructure to support other wind-focused transmission additions. In addition, the Brookings County-Hampton Project is part of the Multi Value Project (MVP) Portfolio up for approval by the MISO Board of Directors.

Project Cost: The four lines will cost approximately $1.7 billion with an additional $200 million to provide for double-circuit 345 kV lines. Of this total, approximately $775million is associated with the wind generation supporting Brookings County - Hampton Project. The Brookings County- Hampton project will be subject to the newly established MVP Portfolio cost allocation methodology. The MVP cost allocation spreads the cost of the project over the entire MISO footprint on the energy usage basis. NSP will pay approximately 9.1% of the total cost for all the MVP projects while maintaining the original CapX ownership arrangements.

Project Status: The MN PUC approved Certificate of Need applications for the CAPX2020 projects in 2009. Minnesota Route Permit applications have been filed for all of the projects. The MN PUC approved a Route Permit application for the Monticello - St. Cloud segment in July 2010 and for the Bemidji - Grand Rapids project in October 2010. Additionally, the MN PUC approved approximately 165 miles of the Brookings County - Hampton project’s 240 mile route in July 2010. The remaining 65 mile segment has been sent back to an administrative law judge for further review. North Dakota, South Dakota and Wisconsin regulatory permits will be filed in 2010. The MISO Board of

108 Edison Electric Institute Transmission Projects: At A Glance — Xcel Energy Inc.

Directors gave conditional approval to the Brookings County-Hampton project in June of 2011. Full portfolio approval is before the Board of Directors in December of 2011.

Project Investment Partners: Central Minnesota Municipal Power Agency (CMMPA), Dairyland Power Cooperative, Great River Energy, Southern Minnesota Municipal Power Agency, Minnesota Power, Minnkota Power Cooperative, Missouri River Energy Services, Otter Tail Power Company, Rochester Public Utilities, Xcel Energy, and WPPI Energy.

Project Benefits: This project will alleviate emerging electric reliability issues around the Upper Mid- west and strengthen the regional transmission system. In addition, the Brookings County - Hampton line will add capacity for an additional 700 MWs of generation in southwest Minnesota and eastern South Dakota. The project will also provide the foundation for future transmission projects from wind-rich regions of western Minnesota and North and South Dakota.

MISO Multi Value Project Portfolio Project Description: The MISO Multi Value Project Portfolio consists of 17 individual 345 kV and above projects in the entire MISO footprint. The NSP Companies will have partial ownership of 3 of the 17 projects. The three projects are 240 miles of new double-circuit, 345 kV transmission line between Brookings County, South Dakota, and Hampton, Minnesota, with a single-circuit line portion from Lake Marion, Minnesota to Hampton, Minnesota, plus a related 23 mile double-circuit, 345 kV transmission line between Lyon County, Minnesota and Hazel Creek, Minnesota; approximately 130 miles of new single-circuit, 345 kV transmission line between La Crosse, Wisconsin and Madison, Wisconsin; approximately 100 miles of new single-circuit, 345 kV transmission line between Brook- ings County, South Dakota and Big Stone, South Dakota.

This project is part of a regional plan to fulfill the Renewable Portfolio Standards of all States in the MISO footprint. The projects, approved as a complete portfolio, will enable enough wind integration into the MISO footprint to fulfill RPS goals through at least 2026.

Project Cost: The MVP portfolio will cost approximately $5.2 billion. The entire total is associated with the integration of wind generation into the MISO footprint. The MVP cost allocation spreads the cost of the project over the entire MISO footprint on the energy usage basis. NSP will pay approximately 9.1% of the total cost for all the MVP projects while maintaining the original CapX ownership arrangements for Brookings County - Hampton and 50% ownership in the Big Stone - Brookings County and La Crosse - Madison projects.

Project Status: The MISO Board of Directors gave conditional approval to the Brookings County - Hampton project in June of 2011. Full portfolio approval is before the Board of Directors in Decem- ber of 2011.

Project Investment Partners: The entire MISO footprint will share costs based on annual energy consumption.

Project Benefits: The portfolio of projects allows the MISO footprint to fully meet the RPS goals of all the States in the MISO footprint, provides significant cost savings through better generation dispatch, and provides improved system stability and voltage support to the major load centers.

Edison Electric Institute 109 Transmission Projects: At A Glance — Xcel Energy Inc.

Pleasant Valley Transmission Project Project Description: The Pleasant Valley Transmission Project consists of approximately 45 miles of new and upgraded 161 kV transmission line. The first line, Pleasant Valley - Byron, consists of approximately 22 miles of new single-circuit, 161 kV line in Olmstead County connecting the Pleasant Valley Substation and the Byron Substation east of Rochester; and the second line, Pleasant Valley - Willow Creek, consists of approximately 20 miles of new single-circuit, 161 kV line in Olmstead County connecting the Pleasant Valley Substation to the Willow Creek Substation on the south side of Rochester (the Willow Creek line application to be filed when generation outlet triggers the need). The project also consists of the Pleasant Valley Transformer, a 345/161 kV, 500 MVA transformer #2 that will be added to the Pleasant Valley Substation located southeast of Rochester, and a new 115 kV St. Bridget Substation south of Rochester. This project will provide deliverability for more than 700 MWs of wind resources including the Grand Meadows and Wapsipinicon from the Pleasant Val- ley substation. This capability was developed in response to the state of Minnesota’s 2007 RES and supports NSPM and other utilities in meeting their 2010 and 2012 renewable targets. In addition to wind outlet, there is a load serving benefit to the city of Rochester.

Project Cost: Approximately $41 million.

Project Status: NSPM filed Certificate of Need and Route Permit applications in late 2009 with the MN PUC for Byron line. The MN PUC is expected to issue its order in February 2011. The Willow Creek line application will be filed when generation outlet triggers the need for the line.

Project Investment Partners: Rochester Public Utilities, Great River Energy, and Southern Minne- sota Municipal Power Agency.

Project Benefits: In addition to facilitating the development of wind generation in southeast Min- nesota, the improvements will strengthen the transmission system and provide more reliable electrical service to the city of Rochester and the surrounding local communities and customers.

110 Edison Electric Institute Public Service of Colorado (PSCo)

Company Background: • PSCo operates in Colorado, and owns approximately 4,360 circuit miles of transmission lines 44 kV and above. PSCo has approximately 1.4 million retail and wholesale customers in Colorado. CO Senate Bill 100 Plan Projects

Ault - Cherokee 230 kV Transmission Line Project Description: The Ault - Cherokee 230 kV Transmission Line Project consists of approximately 59 miles of new 230 kV transmission line from Ault Substation to a location near the PSCo Ft. Lupton Substation. From this point, the existing 115 kV line from Ft. Lupton to Cherokee Station will be rebuilt so that one circuit continues to operate at 115 kV and serve the Tri-State Generation and Transmission Association (Tri- State) load. The other circuit will operate as a 26 mile, double-circuit, 230 kV transmission line completing the circuit from Ault to Cherokee Substation. The project will allow approximately 300-600 MWs of additional generation from northern central and northeastern Colorado, interconnected at or near the Ault Substation.

Project Cost: Approximately $77 million.

Project Status: This is a potential project with an expected in service date of 2016.

Project Investment Partners: To be determined.

Project Benefits: This project will help facilitate the development of wind generation in northern central and northeastern Colorado in Colorado and increase the transfer capability of TOT 7.

Edison Electric Institute 111 Transmission Projects: At A Glance — Public Service of Colorado (PSCo)

Midway - Waterton 345 kV Transmission Line Project Description: The Midway - Waterton 345 kV Transmission Line Project consisted of approximately 82 miles of new 345 kV transmission line between the Midway Substation, near Colorado Springs, and the Waterton Substation, south of the Denver metro area.

For this project 72 miles of existing 230 kV transmission line were reenergized at 345 kV, while 10 miles were rebuilt to double circuit 345 kV. The project included 345 kV switchyard additions at Midway and Waterton Substations. It also included other changes at Waterton: replacement of two 230/115 kV autotransformers; expansion and capacity upgrades to the 230 kV yard; and capacity upgrades to the 115 kV yard.

Project Cost: Approximately $42.5 million.

Project Status: This project received a Certificate of Public Convenience and Necessity (CPCN) in May 2009. The project was placed in service in May 2011.

Project Investment Partners: None.

Project Benefits: This project will allow 300-500 MWs of additional generation. The project will also facilitate potential generation resources in southern central and southeastern Colorado while improving system reliability.

Missile Site 345 kV Switching Station Project Description: The Missile Site 345 kV Switching Station project consists of a new 345 kV substation expansion being constructed jointly with the Pawnee - Smoky Hill 345 kV transmission project.

Project Cost: Approximately $14.8 million.

Project Status: This project has received a CPCN with an expected in service date of Janu- ary 2013.

Project Investment Partners: None.

Project Benefits: The project also will facilitate potential generation resources in eastern Colorado.

112 Edison Electric Institute Transmission Projects: At A Glance — Public Service of Colorado (PSCo)

Pawnee - Daniels Park 345 kV Transmission Line Project Description: The Pawnee - Daniels Park 345 kV Transmission Line project consists of approximately 110 miles of double-circuit, 345 kV transmission line from PSCo’s Pawnee Substa- tion in northeastern Colorado to its Daniels Park Substation south of the Denver metro area.

The first 95 miles of the project will expand the planned Pawnee - Smoky Hill 345 kV transmission line to a double-circuit, 345 kV transmission line between Pawnee and Smoky Hill Substa- tions. One circuit is the Pawnee - Smoky Hill 345 kV line, and the second circuit is one section of the Pawnee - Daniels Park 345 kV line.

For the remaining 29 miles between PSCo’s Smoky Hill and Daniels Park Substations, a new double-circuit, 345 kV transmission line will be constructed. One of the two circuits will be the second portion of the Pawnee - Daniels Park 345 kV line. The second circuit will create a new 345 kV transmission line between PSCo’s Smoky Hill and Daniels Park Substations.

Project Cost: Approximately $79 million.

Project Status: This is a potential project with an expected in service date of 2018.

Project Investment Partners: None.

Project Benefits: This project is expected to accommodate approximately 300-500 MWs of resources, interconnecting at or near the Pawnee Substation in north central and northeastern Colorado.

Pawnee - Smoky Hill 345 kV Transmission Project Project Description: The Pawnee - Smoky Hill 345 kV Transmission Project is a new, double- circuit capable, 345 kV transmission line to connect PSCo’s existing Pawnee Substation near Brush, Colorado, to PSCo’s Smoky Hill Substa- tion near Aurora, Colorado.

The project consists of three sections. The first section is approximately 79 miles of new 345 kV transmission line extending from PSCo’s existing Pawnee Substation to a point east of PSCo’s existing Brick Center Substation, south of Bennett, Colorado. The second section, or center section,

Edison Electric Institute 113 Transmission Projects: At A Glance — Public Service of Colorado (PSCo)

existing Brick Center Substation, south of Bennett, Colorado. The second section, or center section, consists of rebuilding approximately 15 miles of existing 230 kV wood pole structures to double-circuit, 345 kV capable, steel pole transmission. The third section is the last mile of transmission into the Smoky Hill Substation and consists of approximately one mile of new 345 kV transmission line. The last section also will be built to allow for double-circuit, 345 kV capability.

Project Cost: Approximately $144 million.

Project Status: PSCo filed the project CPCN in October 2007, which was approved by the Colorado Public Utilities Commission in February 2009. This project is in progress with an expected in service date of 2013.

Project Investment Partners: None.

Project Benefits: The line will accommodate additional electric generation in northeast Colorado, particularly wind energy, and ensure reliable delivery of power to customers. The project will allow 300-500 MWs of additional generation.

San Luis - Calumet - Comanche Line Project Description: Tri-State and PSCo have jointly proposed to construct, own and operate the San Luis Valley - Calumet - Comanche transmission line project. The project consists of approximately 95 miles of new double-circuit, 230 kV transmission line from the existing San Luis Valley Substation, north of Alamosa, to a new Calumet Substation near Walsenburg; a new 230/345 kV Calumet Substation on property currently owned by Tri-State located six miles north of Walsenburg and expansion of three existing substations; approximately 45 miles of new double-circuit, 345 kV transmission line between the proposed Calumet Substation and the existing Comanche Substation near Pueblo; approximately six miles of new 230 kV transmission line between the proposed Calumet Substation and the existing Walsenburg Substation; and proposed communication facilities to support operation and maintenance of the transmission lines.

Project Cost: Approximately $105 million.

Project Status: PSCo submitted the project’s CPCN with the Colorado Public Utilities Commission in May 2009, with final approval granted on September 13, 2011. This Commission decisions, ap- proving this project, have been appealed to District Court. The recently filed 2011 Electric Resource Plan (October 31, 2011) had significant changes in many of the resource planning assumptions from the previous 2007 filing. These changes call into question PSCo’s participation in this project. Low- er peak demand, and reduced need for new generation, lower natural gas prices and other factors have caused Public Service to reevaluate its continue participation in this project.

114 Edison Electric Institute Transmission Projects: At A Glance — southwestern public service (SPS)

Project Investment Partners: Tri-State.

Project Benefits: This project, if constructed as proposed, could enable efforts for the development of 700-1,400 MWs of renewable energy, and provide for better electric reliability on both Tri State’s and PSCo’s systems. The project could facilitate the development of wind and solar generation resources in the San Luis Valley and south central Colorado.

Southwestern Public Service (SPS)

Company Background: • SPS operates transmission facilities in Texas, New Mexico, Kansas and Oklahoma. • SPS has approximately 400,000 retail and wholesale customers. • SPS operates approximately 6,520 circuit miles of transmission lines.

Hitchland - Woodward 345 kV Transmission Line Project Description: The Hitchland - Wood- ward 345 kV Transmission Line project consists of approximately 121 miles of new 345 kV transmission line from Hitchland Substation to the OGE interception point from the Wood- ward District EHV Substation. This project was approved as one of the Southwest Power Pool (SPP) Priority Projects providing multiple benefits including reliability and additional generation outlet including renewable resources.

Project Cost: Approximately $226 million, of which approximately $48 million will be SPS’ responsibility.

Project Status: In service date of 2014.

Project Investment Partners: OGE.

Project Benefits: This project is a Priority Project under the SPP Transmission Tariff providing multiple benefits including reliability and additional generation outlet including renewable resources.

Edison Electric Institute 115 Transmission Projects: At A Glance — southwestern public service (SPS)

Tuco - Woodward District 345 kV Transmission Line Project Description: The Tuco - Woodward District 345 kV Transmission Line project consists of approximately 183 miles of new 345 kV transmission line from Tuco Substation to the OGE interception around the Texas-Oklahoma state line. This project was approved as part of the SPP Balanced Portfolio 3E Projects to enable economic transfers and enhance regional transmission reliability.

Project Cost: Approximately $319 million, of which approximately $158 million will be SPS’ responsibility.

Project Status: In service date of 2014.

Project Investment Partners: OGE.

Project Benefits: This project is a Balanced Portfolio Project under SPP Transmission Tariff and will enable economic transfers and enhance regional transmission reliability.

116 Edison Electric Institute Transmission Projects: At A Glance — Interstate transmission projects Interstate Transmission Projects

Interstate transmission projects are transmission line improvements that physically span two or more states. These interstate projects often present additional challenges for siting, permitting, cost allocation and cost recovery.

Non-Interstate Interstate 33% 67%

• ATC Smart Grid Investment • KETA Project • RITELine Transmission Grant • Mid-Atlantic Power Pathway • Rosehill - Sooner 345 kV Line • Benning Transmission Project Project • Salem-Hazelton Line • Cardinal Bluffs • Midwest Power Transmission • Sibley - Nebraska City 345 kV • CapX2020 Brookings County • Mountain States Transmission Transmission Line - Hampton 345 kV Project Intertie • Sooner - Rose Hill 345 kV Line • CapX2020 Fargo - • New England East - West • Susquehanna - Roseland 500 kV Monticello 345 kV Project Solutions (NEEWS) Transmission Line Project • CapX2020 Hampton - • Northeast Energy Link • TUCO to Texas/Oklahoma Rochester - La Crosse 345 kV • NorthWestern Energy 500 kV Interconnection Project Upgrade Project • The Northern Pass Transmission • DATC Midwest Portfolio • PacifiCorp Energy Gateway Line • Eldorado - Ivanpah • PATH Project • TrAILCo Transmission Project (EITP) • PJM N-1-1 Projects (Southern • Wichita - Medicine Lodge - • Green Power Express Delmarva) Woodward 345 kV line • Illinois River Project • Pleasant Prairie - Zion Energy • Zephr Power Transmission Center

EdisonEdison El Eleectricctric I nstitutInstitute e 117 Transmission Projects: At A Glance — transmissionPublic Service su ofpp Coroloradoting the (P intSCo)egration of renewable resources Transmission Supporting the Integration of Renewable Resources

Renewable resources transmission projects are projects that support the integration of a renewable resource. A renewable energy resource is defined as any energy resource generated from natural resources such as sunlight, wind, rain, tides and geothermal heat that is replaced rapidly by natural processes. Renewable energy technologies include: solar power, wind power, hydroelectricity, geothermal, biomass and biofuels.

Non-Renewable Renewable 26% 74%

• Ault - Cherokee 230 kV • Kansas V Plan • Pawnee - Daniels Park 345 kV Transmission Line • KETA Project Transmission Line • Badger - Coulee • Mark Twain Project • Pawnee - Smoky Hill 345 kV • CapX2020 Big Stone South Transmission Project - Brookings County 345 kV • Michigan Thumb Loop Project • Pleasant Prairie - Zion Energy Project • MidAmerican Energy Center • CapX2020 Brookings County Expansion Projects • Pleasant Valley - Byron 161 kV - Hampton 345 kV Project • Midway - Waterton 345 kV Project • CapX2020 Fargo - Transmission Line • Prairie Wind Transmission Monticello 345 kV Project • Midwest Power Transmission • RITELine Transmission • CapX2020 Hampton - • Montana Renewable Collector • San Luis - Calumet - Comanche Rochester - La Crosse 345 kV System Line Project • Mountain States Transmission • CapX2020 Bemidji - Grand Intertie • Sibley - Nebraska City 345 kV Rapids 230 kV Project Transmission Line • Northeast Energy Link • Spoon River Project • Cardinal Bluffs • NorthWestern Energy 500 kV • Central Valley 500 kV Study Upgrade Project • South of Kramer • TUCO to Texas/Oklahoma • DATC Midwest Portfolio • Oncor CREZ Development Interconnect • Devers - Colorado River • One Nevada 500 kV and Devers - Valley No. 2 Transmission Intertie (NVES & • Tehachapi Renewable Transmission Project NVEN) Transmission Project (TRTP) • The Northern Pass Transmission • Eldorado - Ivanpah • PacifiCorp Energy Gateway Line Transmission Project (EITP) • Palo Verde Hub - North Gila • G905 Generator 500 kV Project • West of Devers Interconnection • Palo Verde Substation - Delany • Wichita - Medicine Lodge - • Green Power Express Substation - Sun Valley Woodward 345 kV line Substation - Morgan Substation • Woodward - Kansas 345 kV Line • Hitchland - Woodward 345 - Pinnacle Peak Substation 500 kV Transmission Line kV Projects • Zephr Power Transmission • Illinois River Project

118 EdisonEdison El Eleectricctric I nstitutInstitutee Transmission Projects: At A Glance — transmission projects developed by multiple project partners Transmission Projects Developed by Multiple Project Partners

Given the unique risks and challenges of developing transmission, among other things, several EEI member companies are partnering with other utilities, including non-EEI members, to develop large-scale transmission projects. This collaboration allows entities to spread the investment risks while also leveraging each other’s experience in developing needed and beneficial transmission.

No Partners Project Partners 35% 65%

• Acadiana Load Pocket Project • MidAmerican Energy • RITELine Transmission Expansion Projects • DATC Midwest Portfolio • Rosehill - Sooner 345 kV Line • Midwest Power Transmission • CapX2020 Big Stone South • San Luis - Calumet - Comanche - Brookings County 345 kV • New England East - West Line Project Solutions (NEEWS) • Sooner - Rose Hill 345 kV Line • CapX2020 Brookings County • NorthWestern Energy 500 kV • Susquehanna - Roseland 500 kV - Hampton 345 kV Project Upgrade Project Transmission Line Project • CapX2020 Fargo - • One Nevada 500 kV • The Northern Pass Transmission Monticello 345 kV Project Transmission Intertie (NVES & Line • CapX2020 Hampton - NVEN) • TrAILCo Rochester - La Crosse 345 kV • PacifiCorp Energy Gateway Project • TUCO to Texas/Oklahoma • Palo Verde Substation - Delany Interconnection • CapX2020 Bemidji - Grand Substation - Sun Valley Rapids 230 kV Project Substation - Morgan Substation • Wichita - Medicine Lodge - Woodward 345 kV line • Green Power Express - Pinnacle Peak Substation 500 kV Projects • Zephr Power Transmission • Hitchland - Woodward 345 kV Transmission Line • PATH Project • Kansas V Plan • Pioneer Transmission, LLC • KETA Project • Prairie Wind Transmission

EdisonEdison El Eleectricctric I nstitutInstitutEe 119