Local Transmission Plan

Transcription

1 Local Transmission Plan Idaho Power Delivery Planning Final Report December Idaho Power

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3 Idaho Power Company TABLE OF CONTENTS Table of Contents... i List of Tables... ii List of Figures... ii List of Appendices... iii 1. Introduction Local Planning Regional and Interconnection-Wide Coordination Planning Process and Time Line Transmission System Plan Inputs and Components Idaho Power s Transmission System Load Forecast Western Load Area Treasure Valley Load Area Southern Load Area Eastern Load Area Forecasted Resources Transmission Use Forecast Area Planning Economic studies System Conditions Studied Scenarios Studied Transmission System Model Reliability Evaluation Transmission System Analysis Heavy Summer Study Results Light Summer Study Results Heavy Winter Study Results...18 Page i

4 Idaho Power Company Production Cost Case Results Heavy Summer Study Results Summary and Conclusions...19 LIST OF TABLES Table 1 Meeting dates and descriptions...2 Table 2. Load forecasts for areas of Idaho Power...4 Table IRP Preferred Portfolio...8 Table 4 Modeled loads in 2032 power flow case...16 Table 5 Summary of performance criteria issues...18 Table B-1 Projects planned for 1-5 year horizon...25 Table B-2 Projects planned for 5-10 year horizon...26 Table B-3 Projects planned for year horizon...28 LIST OF FIGURES Figure 1 Planning cycle schedule...2 Figure 2 Idaho Power transmission system...3 Figure 3 Idaho Power load areas...4 Figure 4 Western load area...5 Page ii

5 Idaho Power Company Figure 5 Treasure Valley load area...6 Figure 6 Southern load area...7 Figure 7 Eastern load area...7 Figure 8 Future IRP and generation interconnection resources...9 Figure 9 Treasure Valley electrical plan...10 Figure 10 Magic Valley electrical plan...11 Figure 11 Wood River Valley electrical plan...11 Figure 12 Eastern Idaho electrical plan...12 Figure 13 Western Treasure Valley electrical plan...13 Figure 14 Eastern Treasure Valley electrical plan Ada County...14 Figure 15 Eastern Treasure Valley electrical plan Elmore County...15 LIST OF APPENDICES Appendix A Community Advisory Committee Process...21 Appendix B Twenty-year project list...25 Page iii

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7 Idaho Power Company 1. INTRODUCTION The 2013 Local Transmission Plan is the culmination of the local transmission planning process as described in Idaho Power s Open Access Transmission Tariff (OATT) Attachment K. The plan includes all transmissions system facility improvements identified through this planning process. A power flow reliability assessment of the plan was performed which demonstrated that the planned facility additions will meet NERC and WECC reliability standards. Idaho Power s OATT is located on its Open Access Same-time Information System (OASIS) at Additional information regarding Transmission Planning is located in the Transmission Planning folder on Idaho Power s OASIS. Unless otherwise specified, capitalized terms used herein are defined in either Section 1 of Idaho Power s OATT or Section 1 of Idaho Power s OATT Attachment K Local Planning This Local Transmission Plan (LTP) has been prepared within the two-year process as defined in Idaho Power s OATT Attachment K. The LTP identifies the Transmission System facility additions required to reliably interconnect forecasted generation resources and serve the forecasted Network Customers load, Native Load Customers load, and Point-to-Point Transmission Customers requirements, including both grandfathered, non-oatt agreements and rollover rights, over a twenty (20) year planning horizon. Additionally, the LTP incorporates any stakeholders requested economic congestion studies results. Links to documents related to the LTP are located in the Local Transmission Plan folder on Idaho Power s OASIS site Regional and Interconnection-Wide Coordination Idaho Power coordinates its planning processes with other transmission providers through membership in Northern Tier Transmission Group (NTTG) and the Western Electric Coordinating Council (WECC). Idaho Power uses the NTTG process for regional planning, coordination with adjacent sub-regional groups and other planning entities, and development of proposals to WECC for interconnection-wide planning. Additional regional coordination information is located in Idaho Power s OATT Attachment K and on the NTTG s website at Page 1

8 Idaho Power Company 2. PLANNING PROCESS AND TIME LINE This plan is for the planning cycle. The planning cycle schedule is shown below in Figure 1. Figure 1 Planning cycle schedule Idaho Power holds webinar meetings throughout the planning cycle to keep stakeholders and interested parties informed. The following table lists the meeting dates. Table 1 Meeting dates and descriptions Date Meeting Meeting Description 3/21/ st Quarter Idaho Power Local Transmission Plan Request for Information 6/20/ nd Quarter Idaho Power Local Transmission Plan Presentation of assumptions 9/19/ rd Quarter Idaho Power Local Transmission Plan Initial analysis results 12/19/ th Quarter Idaho Power Local Transmission Plan Analysis results 3/20/ th Quarter Idaho Power Local Transmission Plan Draft study results 6/19/ th Quarter Idaho Power Local Transmission Plan Draft report 9/18/ th Quarter Idaho Power Local Transmission Plan Draft report with 2013 IRP resource updates 12/18/ th Quarter Idaho Power Local Transmission Plan Final report Page 2

9 Idaho Power Company 3. TRANSMISSION SYSTEM PLAN INPUTS AND COMPONENTS 3.1. Idaho Power s Transmission System Idaho Power s transmission system exists mostly in southern Idaho and eastern Oregon. The system extends north into Montana to Northwestern Energy s Mill Creek substation, east into Wyoming to the Jim Bridger power plant, south to Wells, Nevada, and west to LaGrande, Oregon as shown in Figure 2. Figure 2 Idaho Power transmission system 3.2. Load Forecast Idaho Power produces a forecast of native and network loads for its balancing area. This forecast includes Idaho Power s twenty-year load forecast and a 20 year network customer load forecast based on Bonneville Power Administration s ten-year forecast and PacifiCorp s ten-year forecast. The load forecasts include expected energy efficiency and demand response reductions. Page 3

10 Idaho Power Company Table 2, below, lists the load forecasts for the Western and Treasure Valley, Southern and Eastern load areas based on load forecasts established during quarter 1 of the process. Idaho Power generally divides its service territory into four load areas; however the load forecast reporting for the Western and Treasure Valley load areas are combined as their geographic areas overlap. Table 2. Load forecasts for areas of Idaho Power Area Description Load Level Western and Treasure Valley Idaho Power s system west of Mountain Home 3,006 MW Southern Idaho Power s system bounded by Mountain Home on the west and American falls on the east. 1,359 MW Eastern Idaho Power s system east of American Falls 665 MW A transmission map with the load areas presented in Table 2 is shown below in Figure 3. Eastern ONTARIO Western CALDWELL BOISE Treasure Valley MOUNTAIN HOME BLACKFOOT POCATELLO Legend Operating Voltage 138kV 161kV 230kV 345kV 500kV TWIN FALLS Southern Figure 3 Idaho Power load areas Page 4

11 Idaho Power Company The following sub-sections will present further information on Idaho Power load areas Western Load Area The Western Load Area includes Malheur County in Oregon and Payette, Valley, and Washington counties in Idaho. The area also includes the Brownlee East (Path 55) and Idaho to Northwest (Path 14) WECC transmission paths. The Western load area, including the area substations, generation facilities and transmission paths is shown in Figure 4. Figure 4 Western load area Treasure Valley Load Area The Treasure Valley Load Area includes the Idaho counties of Ada, Boise, Canyon, Elmore, and Gem. The Treasure Valley load area, including the area substations, generation facilities and transmission paths is shown in Figure 5. Page 5

12 Idaho Power Company Figure 5 Treasure Valley load area Southern Load Area The Southern Load Area includes the Idaho counties of Blaine, Cassia, Gooding, Jerome, Lincoln, Minidoka, and Twin Falls. The area also includes the Idaho to Sierra (Path 16) WECC rated transmission path and the Midpoint West internally monitored transmission path. The Southern load area, including the area substations, generation facilities and transmission paths is shown in Figure 6. Page 6

13 Idaho Power Company Figure 6 Southern load area Eastern Load Area The Eastern Load Area includes the Idaho counties of Bannock, Bingham, and Power. The area also includes the Borah West (Path 17) WECC rated transmission path. The Eastern load area, including the area substations and transmission paths is shown in Figure 7. Figure 7 Eastern load area Page 7

14 Idaho Power Company 3.3. Forecasted Resources The generation resource forecast is comprised of the resources identified in the Idaho Power 2013 Integrated Resource Plan (IRP), a total of 1,601 MW, and the projects in the Idaho Power generator interconnection queue with executed power sales agreements as of the end of the 1 st quarter of the LTP process. Table 3 contains the preferred 10 year resource portfolios for the next 20 years as presented in Idaho Power s 2013 IRP. Table IRP Preferred Portfolio Date Resource Capacity Demand Response Up to 150 MW 2018 Boardman to Hemingway 500 MW Transfer Capacity Summer 2024 Demand Response Up to 370 MW in 50 MW Increments Figure 8 depicts the 2013 IRP resources and interconnection queue generation resources by location and resource type. Page 8

15 Idaho Power Company Figure 8 Future IRP and generation interconnection resources 3.4. Transmission Use Forecast Forecasted use of the transmission system by others was modeled by scheduling the transfer of 2,000 MW of generation in Eastern Idaho and Wyoming across the Idaho Power system to the Pacific Northwest Area Planning Idaho Power develops long-term local area transmission plans with regional community advisory committees. These committees consist of jurisdictional planners; mayors; council members; commissioners; and large industry, commercial, residential, and environmental representatives. The plans identify the transmission and substation infrastructure required through the full development or build-out of the local area. The Treasure Valley, western Treasure Valley, eastern Treasure Valley, Magic Valley, Wood River Valley, and eastern Idaho electrical have been completed. Figures 9 through 15 present the future transmission infrastructure plans for Page 9

16 Idaho Power Company each of the fore mentioned electrical plans. A description of the community advisory committee process can be found in Appendix A. More information about electrical plans can be found on the Idaho Power website at: Figure 9 Treasure Valley electrical plan Page 10

17 Idaho Power Company Figure 10 Magic Valley electrical plan Figure 11 Wood River Valley electrical plan Page 11

18 Idaho Power Company Figure 12 Eastern Idaho electrical plan Page 12

19 Idaho Power Company Figure 13 Western Treasure Valley electrical plan Page 13

20 Idaho Power Company Figure 14 Eastern Treasure Valley electrical plan Ada County Page 14

21 Idaho Power Company Figure 15 Eastern Treasure Valley electrical plan Elmore County 3.6. Economic studies Eligible customers or stakeholders may submit an economic congestion study request during either quarter 1 or quarter 5 of the planning cycle. Idaho Power did not receive any study requests during quarter 1 or quarter 5 of the planning cycle Scenarios Studied 4. SYSTEM CONDITIONS STUDIED Idaho Power uses scenario planning to evaluate the performance of the transmission system for different load and generation dispatch patterns in the future. A 20 year heavy summer load study case was evaluated as the primary study scenario. A five year heavy load scenario, a 10 year light load scenario and a 10 year heavy load scenario were studied. The five and 10 year cases were selected to assess future system adequacy and performance under different load and generation patterns (seasonal conditions). Further, a 10 year production cost case was also evaluated to determine if any unusual flow pattern exists that is not represented in the selected seasonal cases. Ultimately, an autumn Page 15

22 Idaho Power Company condition with heavy east to west transfers across Idaho Power s system was selected and evaluated in the same manner as the five, 10 and 20 year scenarios Transmission System Model The 20 year power flow case was based on the WECC 2019 HS1 base case, approved by WECC on June 10, Load levels in the 20 year case were increased to approximate Idaho Power s forecasted control area load in the year The total Idaho Power control area load was modeled at 5,030 MW. This is roughly a 1,600 MW increase in load from Idaho Power s historical peak load of 3,407 MW, which occurred on July 2, The loads in the case were increased to achieve the following distribution across the Idaho Power s system: Table 4 Modeled loads in 2032 power flow case Area Description Load Level Western and Treasure Valley Idaho Power s system west of Mountain Home(approximately 50 miles east of Boise) Southern Idaho Power s system bounded by Mountain Home on the west and American falls on the east. 3,006 MW 1,359 MW Eastern Idaho Power s system east of American Falls 665 MW The 20 year power flow case was also modified to reflect the expected 500 kv transmission improvements for the Gateway West and Boardman to Hemingway (B2H) transmission projects. Lower voltage transmission modeling detail was added to the Idaho Power service territory that was not originally modeled in the WECC base case. Transmission growth and reliability driven projects that have been planned for the next 20 years have also been added to the case. A list of projects scheduled for the next 20 years can be found in Appendix B. The five year and ten year scenarios utilized WECC approved power flow cases. Idaho Power also evaluated the same cases as part of its 2012 NERC TPL compliance reliability evaluation. The following three WECC cases were utilized: 2017 Heavy Summer case (17hs1a1), approved 10/7/ Heavy Winter case (22hw1a1), approved 03/14/ Light Summer case (22ls1sa), approved 12/6/12 The load, resource dispatch and path flow data modeled in the WECC base cases for the five and ten year cases were not modified from the WECC published cases. The 2022 production cost case utilized the WECC TEPPC production cost model (PC1). The TEPPC 2022 PC1 model is a security constrained economic-commitment-and-dispatch model based on forecasted loads and resources for the year 2022 that were submitted from all WECC balancing authorities. The balancing authorities supply monthly peak and energy forecasts. The forecasts are then dispersed into hourly load demands. Page 16

23 Idaho Power Company After reviewing the hourly 2022 PC1 data, the model data from November 6, hour 10:00 was extracted into a PowerWorld power flow model. The case was selected for Idaho Power s LTP analysis because it contained high east-to-west transfers across the Idaho Power system. This same case was utilized by Northern Tier Transmission Group (NTTG) for its Planning process. The extracted case was selected by the NTTG Planning group because it represented the maximum NTTG footprint export condition. 5. RELIABILITY EVALUATION 5.1. Transmission System Analysis PowerWorld power flow software was utilized to perform contingency analysis on the 10 year production cost case and the 20 year planning power flow case. POM software was used to perform contingency analysis on the five and ten year cases. A total of 410 single element outage (N-1) contingencies were evaluated based on single transmission line or single transformer outages on the 138 kv, 161 kv, 230 kv, 345 kv and 500 kv systems. Thirty-six credible N-2 contingencies were evaluated. Idaho Power s Common Corridor analysis was the basis for a list of credible two element outage (N-2) contingencies. The power-flow simulation results are measured against North American Electric Reliability Council (NERC) and WECC reliability criteria. Specifically, the NERC Reliability Standards TPL-001 and TPL-002 b require that transmission facilities maintain operation within normal and emergency limits. The WECC business practice TPL-001-WECC-RBP-2 establishes the voltage-violation threshold for N-1 contingencies. Additionally, Idaho Power files its reliability criteria via FERC Form No. 715, part IV Reliability Criteria for System Planning. Combined, the NERC, WECC and Idaho Power criteria formed the criterion for which every N-1 and N-2 contingency was screened. Every N-1 contingency was screened for thermal overloads and voltage issues. Thermal overloads over 100% of equipment emergency ratings were reported. Voltage deviations greater than 5% were reported. Per Idaho Power s Reliability Criteria for System Planning, post-outage deviations greater than 5% are acceptable if minimum voltage remains above nominal of 0.90 per unit and distribution bus voltage is within ANSI Emergency Range. Regardless, 5% deviations were flagged as part of the screening process. A low voltage screening threshold was set for 0.93 PU and a high voltage threshold was set for 1.10 PU. Thus, any contingency that resulted in a voltage below 0.93 or greater than 1.10 was reported, regardless of the amount of voltage deviation. Flagged contingencies were then reviewed further to determine if the reported issue was a reliability criteria violation. A summary of results can be found below in Table 5 and the results are discussed further in the following sections. The system improvements identified for the next 20 years are presented in Appendix B. Page 17

24 Idaho Power Company Table 5 Summary of performance criteria issues Case Number of Flagged Contingencies Thermal Issues Voltage Issues 2017 Heavy Summer Light Summer Heavy Winter PC1-Nov, 6 Hour Heavy Summer Heavy Summer Study Results The N-1 contingency analysis resulted in six thermal issues and two different line outages scenarios that resulted in voltage deviation issues. Each of the thermal issues were a result of a 230/138 kv transformer outage causing an overload of the parallel 230/138 kv transformer. Two of the locations, Locust and Adelaide, are a result of modeling the study case. The 138 kv system is not modeled in detail in this study case so the 138 kv aggregations are causing overloads that would not occur if the system were modeled in detail. The transformer thermal overload at Ontario is a legitimate issue. A project has been proposed to address the overload issue and is included in the project list in Appendix B. The Wood River Midpoint 138-kV line outage resulted in a voltage deviation greater than 5% and post-contingency voltage less than 0.95 per unit. The study results are more drastic than they appear because the modeling in the 17 HS case has all of the load buses on the 138 kv lines between Midpoint-Wood River-138 kv aggregated and modeled as one large load at the Wood River bus. In real life, if either of the lines opens, load tapped off the line would be disconnected. If the contingency is modeled with the expected load dropping, the voltage performance improves to an acceptable level. No thermal or voltage issues resulted from the N-2 contingency analysis Light Summer Study Results No thermal or voltage issues resulted from the N-1 and N-2 contingency analysis Heavy Winter Study Results Four N-1 contingencies were flagged in the long-term 2022 heavy winter case. The outage of Ontario-Weiser 138-kV line resulted in voltage deviation greater than 5%, but the performance is acceptable in this case because the post contingency voltage remained above 0.95 per unit. Three outages; King-Wood River-138 kv line, Midpoint-Wood River-138 kv line and Midpoint 230/138 kv transformer, resulted in voltage deviations greater than 5% at Wood River 138-kV Page 18

25 Idaho Power Company bus. The Midpoint-Wood River-138 kv line outage also resulted in thermal overload of the King-Wood River 138 kv line. As noted above for other study cases, the results are not as drastic as they appear because the modeling in the case has all of the load buses on the 138 kv lines between King-Wood River-138 kv and Midpoint-Wood River-138 kv aggregated and modeled as one large load at Wood River. In real life, if either of the lines opens, load tapped off the lines would be disconnected. If either line outage is modeled with the expected load dropping the voltage performance improves to acceptable levels. No thermal or voltage issues resulted from the N-2 contingency analysis Production Cost Case Results No thermal or voltage issues of concern resulted from the N-1 and N-2 contingency analysis Heavy Summer Study Results The N-1 contingency analysis resulted in no thermal overloads and three different line outages that resulted in voltage issues. Each of the three outages resulted in voltage deviations greater than 5%. However, in each instance, the post-contingency voltage was between 0.95 per unit and 1.05 per unit so the contingency results were acceptable. No thermal or voltage issues of concern resulted from the N-1 and N-2 contingency analysis. 6. SUMMARY AND CONCLUSIONS Idaho Power s Local Transmission Plan has been prepared as part of the two-year process defined in Idaho Power s OATT Attachment K. The Plan has identified the transmission system facility additions required to reliably interconnect forecasted generation resources, serve Native Customer and Network Customer forecasted load and Point-to-Point Transmission Customers requirements over a twenty (20) year planning horizon. A list of such facility additions and upgrades can be found in Appendix B. A power flow reliability assessment was performed on cases modeling system conditions 5, 10 and 20 years into the future. The results of the power flow analysis indicate that the planned system performs reliably for the forecasted loads, generation resources and transmission services over the planning horizon. Page 19

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27 Idaho Power Company Appendix A Appendix A Community Advisory Committee Process 1. Background The process develops a plan to meet needs through buildout, regardless of when that occurs. The process is possible due to an effective collaboration driven by significant commitment from both Idaho Power and the specific area community. Idaho Power dedicates significant skilled staff resources through the integral participation of planners and engineers to support the technical needs of the process. The unique community needs, interests and goals are represented through the Community Advisory Committee; a broad-based participation of elected officials, businesses, landowners, planners, agencies and other key stakeholders. The result is an effective blend of technical and non-technical input, combined to develop an electrical plan that is both technically sound and sensitive to each area s needs. 2. Purpose of the Electrical Plan Process To create a clear and documented electrical energy supply plan to serve the load needs of the area from now through buildout. The public process is the starting point of all electrical supply plans and any resulting transmission rights-of-way and substation siting requirements 3. The Planning Process The planning process follows a specific outline of steps, divided into three basic components; education, infrastructure siting and plan implementation. The overall process typically involves 9 to 12 months beginning with education, followed by development of community criteria and alternatives, to a committee consensus decision for the final plan. Committee input is focused on two primary areas; where to, and where not to locate new infrastructure such as transmission lines, substations, etc. to be acceptable to the community, and recommendations for related delivery, conservation and demand-side management programs to support desired implementation of electrical service in the area. In general, the planning process does not address recommendations for electrical generation or future high voltage (500kV) transmission lines to move electricity into and through the region. 4. Typical Planning Steps Meeting 1: Bus Tour Committee orientation and ground rules Idaho Power introduction and overview Electric Power 101 Meeting 2: Education Generation Idaho Power voltage levels Transmission including Gateway West, etc. Substation Page 21

28 Appendix A Idaho Power Company Meeting 3: Education (continued) Meeting 4: Education (continued) Meeting 5: Infrastructure Mapping Meeting 6: Mapping and Evaluation Meeting 7: Preferred Alternatives Rates and regulatory Demand side management (energy efficiency) Planning area existing electrical system conditions Begin developing community criteria Confirm community criteria Future electrical buildout needs Transmission & related components to meet buildout needs Initial alternative discussion Review of community criteria Mapping/alternatives development orientation Small group mapping exercises Mapping/alternatives development review and feedback Resume mapping exercises if needed Evaluation/scoring matrix orientation Alternatives evaluation and scoring process Identify preferred alternatives for each of the planning areas Meeting 8: Plan Consensus Verify/confirm preferred alternative(s) and ranking Meeting 9: Plan Document and Next Steps Develop implementation plan Discuss local plans coordination Review draft plan Comments Plan rollout discussion 5. The Community Advisory Committee The Community Advisory Committee for each of the Electrical Plans includes individuals, representing a broad cross section of elected officials, local governments, businesses, community development organizations, planning entities, landowners, affected agencies, environmental organizations, and other key stakeholders. Together, they provide both individual and regional perspective regarding the key issues and concerns that are important to the specific area residents when meeting the long-term electrical needs for that area Advisory Committee Purpose Develop consensus support and lend credibility for identified electrical energy supply improvements necessary to serve the area. Page 22

29 Idaho Power Company Appendix A Advisory Committee Role Propose ideas and solutions to Idaho Power s load serving needs that meet the area through buildout. 6. Benefits and Uses of the Plan The development of the Electrical Plans provide two primary benefits; First, the completed document outlines a specific plan based on community goals, with a range of acceptable alternatives for Idaho Power to follow as it implements specific infrastructure projects to meet the area s electrical needs through buildout. Second, the planning process develops significant community awareness and support that is critical to successful project development that is acceptable to community residents. In addition to its use by Idaho Power, the plan is also intended for use by local jurisdictions, governments and affected agencies through incorporation into local planning documents. The plan is also a key tool for use by economic development organizations in support of existing and potential new businesses to the region. Finally, it is important to note that the plan is intended to be a living document, that can be adjusted with additional advisory committee and community input to respond to significant changes in electrical needs of the area. 7. Summary of Community Plans Electrical Plans Year Completed Updates Year Updated Treasure Valley Electric Plan 2006 Revised for Birds of Prey Area 2007 Wood River Electric Plan 2007 Ongoing Magic Valley Electric Plan 2008 Planned for 2118 Eastern Idaho Electric Plan 2009 Planned for 2019 Western Treasure Valley Electrical Plan 2011 Planned for 2021 Eastern Treasure Valley Electrical Plan 2012 Planned for 2022 Page 23

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31 Idaho Power Company Appendix B Appendix B Twenty-year project list Table B-1 Projects planned for 1-5 year horizon Region Time Frame Project Title Project Scope Treasure Valley 5 year Install 138 kv series reactor on the Mountain Home Junction 1 - Lower Malad line Treasure Valley 5 year Add 138 kv series reactor on the Dram-Lucky Peak line Treasure Valley 5 year Add 138kV series reactor on the Mountain Home Junction -Upper Salmon 1&2 line Install a 138 kv series reactor on the Mountain Home Junction 1-Lower Malad 138 kv transmission line. Install a 138 kv series reactor at Dram on the Dram- Lucky Peak transmission line. Install a 138 kv series reactor at Mountain Home Junction on the Mountain Home Junction -Upper Salmon 1&2 transmission line. Treasure Valley 5 year Build new 138 kv line from Bowmont to Happy Valley Build new 138 kv Bowmont to Happy Valley line to improve reliability and integrate B2H project into the Treasure Valley. Southern 5 year Build new 138 kv transmission line and new 138 kv distribution station to serve Buhl Build new 138 kv distribution station east of Buhl and construct a new 138 kv transmission line to meet future load growth. Southern 5 year Rebuild 138 kv line from King to Moonstone Rebuild existing 138 kv line between King substation and Moonstone substation to improve reliability and performance to the Wood River loop. Southern 5 year Build 138 kv line from Wood River to Ketchum Build a 2 nd 138 kv line into Ketchum substation to improve reliability in the Ketchum area Treasure Valley 5 year Add circuit breakers at Chestnut substation Install circuit breakers at Chestnut substation to increase reliability in the Nampa area Eastern 5 year Rebuild Goshen-Big Grassy 161 kv line Rebuild existing 70+ year old 161 kv line Treasure Valley 5 year Build new Lakeshore distribution substation Construct new kv distribution substation south of Nampa near Lake Lowell. Treasure Valley 5 year Build new 138 kv line from Lowell Junction to new Lakeshore substation Build a 138 kv transmission line to serve the new Lakeshore substation south of Nampa near Lake Lowell. Page 25

32 Appendix B Idaho Power Company Table B-2 Projects planned for 5-10 year horizon Region Time Frame Project Title Project Scope NTTG 10 year Boardman to Hemingway 500 kv Line Build a new 500 kv transmission line from Boardman, Oregon area to Idaho Power s Hemingway substation. Treasure Valley 10 year Hemingway-Bowmont Build 230 kv line Add the second 230 kv line circuit on existing structures from Hemingway to Bowmont to integrate B2H project into Treasure Valley. Treasure Valley 10 year Hubbard-Bowmont Build 230 kv line This project uprates the existing 138 kv line from Bowmont-Hubbard to 230 kv to integrate B2H project into Treasure Valley. Treasure Valley 10 year Add T MVA 230/138 kv tie transformer at BOMT Add a second 300 MVA 230/138 kv transformer t at Bowmont to integrate B2H project into the Treasure Valley Treasure Valley 10 year Hubbard-Hemingway 230kV Line Terminal Install a 230 kv line terminal at Hubbard to integrate B2H project into Treasure Valley. Treasure Valley 10 year Kuna-Bowmont Build 138 kv line Build new 7 mile 138 kv line from Kuna Tap to Bowmont to serve Kuna after the existing 138 kv line between Bowmont and Mora/Hubbard is converted to 230 kv. Treasure Valley 10 year Willis-Star Build 11 mile 138 kv line Build a new approximately 11 mile 138 kv transmission line between Willis and Star to improve reliability in the area. Southern 10 year Add 200 MVA 230:138 kv transformer at Midpoint Add a 200 MVA 230:138 kv transformer at Midpoint to relieve overload concerns. Treasure Valley 10 year Gem-Houston Rebuild 6.5 miles to 138 kv Rebuild Gem-Houston 69 kv line to 138 kv. Treasure Valley 10 year Add 230/138 kv capability at Cloverdale Add a 230 kv line terminal and T /138 kv 300 MVA transformer in the north side of the station. Treasure Valley 10 year Add Cloverdale 230 kv terminal Add a 230 kv terminal for the new line to Cloverdale substation. Western 10 year Parma-Nyssa Rebuild 9 miles Rebuild 9 miles of existing Parma-Nyssa 69 kv transmission with 138 kv insulation. NTTG 10 year Gateway West 500 kv Line Bridger to Populus Build a new 500 kv transmission line from Jim Page 26

33 Idaho Power Company Appendix B Region Time Frame Project Title Project Scope Bridger station in Wyoming to Populus station in Southeastern Idaho. NTTG 10 year Gateway West 500 kv Line Populus to Hemingway Build a new 500 kv transmission line from Populus Station in Southeastern Idaho to Hemingway Station in Southwestern Idaho. Treasure Valley 10 year Build 138 kv line from Zilog substation to new Cherry substation Obtain ROW and build about 2.2 miles 138 kv transmission line from Zilog tap to the new Cherry substation. Treasure Valley 10 year Build new Cherry distribution substation Construct new kv distribution substation at the SE corner of Cherry Lane and Can-Ada in Nampa. Western 10 year Parma-Wilder Build 8 miles Build 8 miles from Parma to Wilder to operate at 69 kv. Western 10 year Relieve N-1 overload on Ontario tie bank Add 3 rd tie bank or upgrade existing tie banks at Ontario. Treasure Valley 10 year Relieve N-1 overload on Locust tie bank (per 2012 TPL-002 Study Results) Construct a new 138 kv line between Blackcat and Zilog substations. Eastern 10 year Build 138 kv line between Kramer and Pingree Build a new 138 kv transmission line between Kramer substation and Pingree substation to provide a second source to the 46 kv system served out of Pingree Treasure Valley 10 year Build new Wagner distribution substation Construct new kv distribution substation in the area of Farmway and Purple Sage Road Treasure Valley 10 year Build new 138 kv line between existing Willis substation and new Wagner substation Construct a new 138 kv circuit from existing Willis substation to the new Wagner substation. Page 27

34 Appendix B Idaho Power Company Table B-3 Projects planned for year horizon Region Time Frame Project Title Project Scope Treasure Valley 20 year Build new Beacon Light Substation Build new Beacon Light distribution substation in the area northwest of Eagle. Treasure Valley 20 year Star-Beacon Light Build new 138 kv line Extend 138 kv line approximately 2 miles to new Beacon Light substation. Treasure Valley 20 year Build Eagle loop 138 kv line Build new approx 5 mile 138 kv transmission line from the Locust 230 kv station to the corner of Linder Rd and State St. This line will improve reliability to customers in the area. Western 20 year Parma-Caldwell Rebuild 16 miles to 138kV Rebuild 16 miles of 69 kv transmission between Parma-Caldwell with 138 kv insulation. Western 20 year Parma-Nyssa Rebuild 9 miles to 138kV Rebuild 9 miles of 69 kv transmission between Parma-Nyssa with 138 kv insulation. Southern 20 year New 138 kv switching station south of Jerome Build a 138 kv switching station south of Jerome to break up Dale-Hunt, Upper Salmon 1&2-Cliff and Midpoint-Twin Falls lines. Southern 20 year Poleline-Filer Build 6 new 6 mile 138 kv line Build 6 miles of new 138 kv transmission line from Poleline substation to Filer substation. Convert Filer from 46 kv to 138 kv. Western 20 year Rebuild 10 miles from Emmett to Montour Rebuild 69 kv line from Emmett to Montour station. Construct at 138 kv. Treasure Valley 20 year Build new Amity distribution substation Construct new kv distribution substation at Amity and Ten Mile Roads. Treasure Valley 20 year Build 138 kv 4.5 mile line from Happy Valley to new Amity substation Southern 20 year Add 230 kv and 138 kv capability at Cedar Hill Build a new 138 kv transmission line from the Happy Valley station to the new Amity distribution substation at Amity and Ten Mile Roads. Add tie bank(s) at the proposed Cedar Hill substation to serve the Magic Valley area loads. Southern 20 year Build 138 kv line from Cedar Hill to Artesian Build a new 138 kv line from the Cedar Hill station to Artesian substation. Page 28

35 Idaho Power Company Appendix B Region Time Frame Project Title Project Scope Southern 20 year Build new 4 mile 138 kv line to serve South Park substation at 138 kv. Build new 4 mile 138 kv transmission line between Twin Falls substation and South Park substation. Southern 20 year Build 138 kv line from Hydra to Flat Top Build a new 138 kv line from Hydra substation to Flat Top substation. Southern 20 year Build 138 kv line from Flat Top to Midpoint Build a new 138 kv line from Flat Top to substation Midpoint substation. Treasure Valley 20 year Build Garden City Substation Construct new Garden City substation. The station will be sourced off a tap on the existing Ustick Boise 138 kv line. Southern 20 year Upgrade Shoshone station to 138 kv Convert Shoshone station from 46 kv to 138 kv Western 20 year Emmett-Lake Fork Build 90 miles 138 kv line Build new 138 kv transmission line and remove the existing 69 kv line between Emmet and Lake Fork. Treasure Valley 20 year Build Dry Creek 230 kv hub station Construct new Dry Creek 230/138 kv station to provide a source to the north side of the Treasure Valley Treasure Valley 20 year Build 230 kv double circuit to Dry Creek 230 kv station Southern 20 year Connect Hagerman to the Lower Malad-King 138 kv line Connect new 230 kv Dry Creek substation to existing Brownlee-Boise Bench 230 kv line Connect Hagerman to the Lower Malad-King 138 kv line Treasure Valley 20 year Boise Bench-Blacks Creek Rebuild 8 miles to 138kV Rebuild the existing 69 kv Boise Bench - Blacks Creek line to 138 kv. Treasure Valley 20 year Blacks Creek-Orchard Rebuild 10 miles to 138kV Rebuild the existing 69 kv Blacks Creek-Orchard line to 138 kv. Treasure Valley 20 year Orchard-Elmore Rebuild 8 miles to138kv Rebuild the existing 69 kv Orchard-Elmore line to 138 kv. Treasure Valley 20 year Add second 230 kv line terminal at Nampa and convert 230 kv tap into in/out Add 230 kv line terminal and convert Nampa to an in/out station on the existing HBRD-NMPA-CDWL 230 kv line. Page 29

36 Idaho Power Company Thank you for your interest. Page 30