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2010 Update to 2009Biennial Transmission
Expansion Plan
Approved by the ColumbiaGridBoard of Directors onFebruary 17, 2010
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Photos provided by: Bonneville Power Administration, Grant County PUD, NW Power and Conservation Council, Seattle City Light, Chelan County PUD, iStock Photo
February 2010
Copies of this report are available from: ColumbiaGrid8338 NE Alderwood Rd Suite 140Portland, OR 97220503.943.4940www.columbiagrid.org
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AcknowledgementsColumbiaGrid Members & ParticipantsAvista CorporationBonneville Power AdministrationChelan County PUDCowlitz County PUDDouglas County PUDGrant County PUDPuget Sound EnergySeattle City LightSnohomish County PUD Tacoma Power
Other ContributorsIdaho Power CompanyNorthern Tier Transmission GroupNorthwest Power and Conservation CouncilNorthwest Power PoolNorthwestern EnergyPacifiCorpPortland General Electric
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Table of ContentsExecutive Summary
Introduction
Ten Year Plan
Study Team Reports Puget Sound Area Study Team Northern Middle Columbia Study Team Wind Integration Study Team Cross Cascades Study Team Olympic Peninsula Study Team
Potential Major Transmission Projects
Interfaces with Neighboring Regions
Internal Northwest Transmission Paths
Study Assumptions and Methodology Load Generation Transmission Methodology
Study Results Facility Loading Performance System Voltage Performance Wind Generation Sensitivity Studies
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Disclaimer: The data and analysis contained in this report are not warranteed by ColumbiaGrid or any other party. Any reliance on this data or analysis is done so at the user’s own risk.
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Table of Contents continued...Figures Figure 1: ColumbiaGrid Ten-Year Plan Figure 2: Northern Mid C Preferred Plan Figure 3: Cross Cascades Transmission Issues Figure 4: Regional Projects Figure 5A: British Columbia - Northwest Figure 5B: Montana - Northwest Figure 5C: Idaho - Northwest Figure 5D: California-Oregon Interties Figure 5E: Pacific DC Intertie Figure 5F: Alturas Figure 5G: North of John Day Figure 5H: South of Allston Figure 5I: West of Cascades North Figure 5J: West of Cascades South Figure 5K: West of McNary Figure 5L: West of Hatwai Figure 6: Wind Resources Figure 7: Five-Year Winter Basecase Conditions Figure 8: Five-Year Summer Basecase Conditions Figure 9: Ten-Year Winter Basecase Conditions Figure 10: Ten-Year Summer Basecase ConditionsTables Table 1: ColumbiaGrid Ten Year Plan Table 2: Basecase Summary - numbers in MW Table 3: Projects Recently Energized Table 4: Firm Transmission Projects included in the System Assessment Basecases Table 5: Potential Transmission Owner Identified Mitigation Projects Table 6: Potential Reactive Mitigation Projects
Attachments Attachment A: Transmission Expansion Projects
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Executive Summary
The 2010 update to the 2009 Biennial Transmission Expansion Plan (Plan Update) described in this document
is an update Biennial Transmission Expansion Plan adopted by the ColumbiaGrid Board of Directors in February of 2009. As with the original plan, this Plan Update looks out over a ten-year planning horizon (2010 - 2020) and identifies the transmission facility additions necessary to ensure that the ColumbiaGrid Planning and Expansion Functional Agreement (PEFA) parties can meet their commitments to serve load and provide transmission service.
Since the adoption of the 2009 Biennial Transmission Expansion Plan, the following information has become available and is incorporated into this Plan Update:
• Throughout 2009, work has continued in two study teams focused on transmission issues in specific areas of the system. The Puget Sound Area Study Team has been analyzing the effect that potential projects could have on local area reliability and on
the ability of the system to support required transfers of power between the northwest and Canada. The Northern Mid Columbia Study Team has developed a transmission expansion plan to address transmission issues in that area of the system. A detailed discussion on the activities of these two study teams is provided in this report.
• In early 2009 a need was identified to form a new study team focused on several wind generation integration issues. Recognizing that these issues were also of interest to the members of the Northern Tier Transmission Group (NTTG), a joint ColumbiaGrid/NTTG Wind Integration Study Team (WIST) was formed. The WIST is addressing a number of topics including setting the technical limits on dynamic scheduling on the major northwest paths. In addition, the group is addressing the question of whether the costs for new transmission facilities required to access remote wind areas like Wyoming are justified based on benefits provided such as increased
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wind generation diversity and improved wind generation capacity factors. An update on the activities of this study team is provided in this report.
• In July of 2009, ColumbiaGrid staff completed its 2009 System Assessment which highlighted areas of the system where there may be deficiencies in meeting reliability standards adopted by the North American Electric Reliability Corporation (NERC), the Western Electricity Coordinating Council (WECC), and by individual transmission system owners. Some of these reliability issues were identified in the prior System Assessment and some are new. The results of this assessment are documented in this report.
• As a follow-up to the 2009 System Assessment, sensitivity studies have been completed to examine the effect of increasing the assumed amount of wind generation in operation. These studies are documented in this report.
• The 2009 System Assessment also identified the need to form two new study teams. One of the study teams is focused on the need to reinforce the transmission paths across the Cascades, which are projected to reach their limits within the planning horizon due primarily to increased imports of renewable energy from the east. The other new study team was formed to address local reliability issues on the Olympic Peninsula. A discussion on the need behind forming these study teams is provided in this report.
• There are a large number of potential major transmission projects that will affect the northwest transmission system. These projects have evolved over the last year
and updated information is provided in this report.
ColumbiaGrid has documented all of the above in this Plan Update which has been reviewed by the various study teams and other interested stakeholders. With the completion of this Plan Update, ColumbiaGrid will initiate its next System Assessment cycle. The completion of the 2010 System Assessment is scheduled for June of 2010, and the completion of the next Biennial Transmission Expansion Plan is scheduled for December of 2010.
Resolution to adopt the 2010 Update to the 2009 Transmission Expansion Plan
WHEREAS, a purpose of ColumbiaGrid is carrying out the ColumbiaGrid Planning and Expansion Functional Agreement (“PEFA”), which is intended to support and facilitate multi-system planning through a coordinated, open, and transparent process and is intended to facilitate transmission expansion based upon such planning; and
WHEREAS, pursuant to Article 2.1 of the PEFA, each Planning Cycle, ColumbiaGrid shall develop and review a Draft Biennial Plan and shall adopt, by majority vote of the ColumbiaGrid Board of Directors, a Biennial Plan; and
WHEREAS, pursuant to Article 2.4 of the PEFA, if, at any time ColumbiaGrid determines that changes in planning assumptions or other conditions make a Plan Update appropriate, Staff shall develop and the Board shall consider for adoption, a Plan Update of the then current Plan; and
WHEREAS, ColumbiaGrid has prepared the 2010 Update to the 2009 Biennial Transmission Expansion Plan based on the ColumbiaGrid planning process and posted said Plan Update for public review and comment on December 23, 2009; NOW, THEREFORE, BE IT RESOLVED that, based upon the ColumbiaGrid Board of Directors’ review of the 2010 Update to the 2009 Biennial Transmission Expansion Plan on its technical merits, the consistency of the Projects listed in the Transmission Expansion Plan with the PEFA, and considering comments and information provided during the review process, the ColumbiaGrid Board of Directors hereby adopts the 2010 Update to the 2009 Biennial Transmission Expansion Plan.
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Introduction
ColumbiaGrid was formed with seven founding members in 2006 to improve the operational efficiency,
reliability, and planned expansion of the Northwest transmission grid. Ten parties have signed ColumbiaGrid’s Planning and Expansion Functional Agreement (PEFA) to support and facilitate multisystem transmission planning through an open and transparent process. ColumbiaGrid’s primary grid-planning activity under PEFA is to develop a biennial transmission expansion plan that looks out over a ten-year planning horizon and identifies projected long-term firm transmission needs on the systems
of parties to the agreement. A significant feature of the transmission expansion plan is its single-utility planning approach. It has been developed as if the region’s transmission grid were owned and operated by a single entity. This approach results in a more comprehensive, efficient, and coordinated plan than would otherwise be developed if each transmission owner completed a separate independent analysis. In the years between the production of biennial plans, ColumbiaGrid may produce an update to the biennial plan such as is provided in this report.
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Ten-year Plan
The projects in the ten-year plan fill a variety of needs such as serving load, integrating new resources,
or facilitating economic transfers. To be included in the plan, the projects need to be committed projects that are in the permitting, design, or construction phases. The projects in the plan may have been generated in any of a variety of forums such as the 2009 System Assessment, analysis completed by the study teams, or individual planning participant studies. ColumbiaGrid’s Ten Year Plan is shown in Figure 1 and Table 1. More detailed information for each of the projects is provided in the last appendix of this report.
The ColumbiaGrid ten-year plan has been coordinated directly with other subregional planning groups (e.g., the Northern Tier Transmission Group) and with the overall region through the Western Electricity Coordination Council (WECC). During 2010 and 2011, WECC will be developing an overall plan for the western interconnection. The ColumbiaGrid ten-year plan will be part of the foundation for this interconnection-wide plan.
The projects in the ten-year plan primarily address issues that occur in the first five years of the ten-year planning horizon. Additional projects will be required to meet the needs in the latter part of the ten-year planning horizon. These additional projects are still being developed as there is sufficient time to study these areas and develop projects to resolve those needs. Several of the long-term needs that may generate additional transmission projects are described below:
1. West of Cascades North and SouthSeveral projects have been identified to
reinforce these two paths to meet load growth and transfer east side resources to the west side load areas. These projects include:
a. Puget Sound Energy IP line – Puget Sound Energy has identified upgrades to its line between Kittitas and Lake Tradition Substations to increase capacity on the West of Cascades North path.
b. Series capacitors at Schultz - Bonneville is analyzing the need for additional series capacitors on the Schultz-Raver #3 and #4 500 kV lines to increase capacity on the West of Cascades North path.
c. If the smaller reinforcements listed above are insufficient, an additional 500 kV line may be needed across the West of Cascades North path.
d. Station K - Additional capacity on the West of Cascades South path could be obtained by the development of a new substation in the Maupin area in central
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Project Name Sponsor Date1 Olympic Peninsula Reinforcement (Satsop-Shelton 230 kV line) Bonneville Power 2009
2 Rogue SVC (South Oregon Coast) Bonneville Power 2010
3 Mid Columbia Area Reinforcement (Vantage - Midway 230 kV line upgrade)
Bonneville Power 2011
4 Second 230/115 kV transformer at Redmond Bonneville Power 2011
5 Sandpiper Substation connecting into the existing Ashe - Marion 500 kV line and the new McNary - John Day 500 kV line
Bonneville Power 2012
6 Bakeoven Series Capacitors plus other shunt caps and line upgrades (COI Upgrade)
Bonneville Power 2012
7 John Day - McNary 500 kV Line Bonneville Power 2013
8Big Eddy - Knight (formerly Station Z) 500 kV line looping into the new Knight Substation on the existing Wautoma - Ostrander 500 kV line
Bonneville Power 2013
9Central Ferry - Lower Monumental 500 kV line and connection to existing Lower Granite - Lower Monumental 500 kV lines at the new Central Ferry Substation
Bonneville Power 2013
10Castle Rock - Troutdale 500 kV line (I-5 Corridor Reinforcement Project) connected to the Paul-Allston line at the new Castle Rock Substation
Bonneville Power 2015
11 Lower Valley Reinforcement (SE Idaho) Bonneville Power/others
2012
12 Retermination of lines into Andrew York Substation Chelan 201013 Relocation/upgrade of the McKenzie - Wenatchee Tap 115 kV line Chelan 201214 Wenatchee-McKenzie 115 kV line uprate from 50 - 75 degree C Chelan 2011
15 Cowlitz PUD conversion from 69 kV to 115 kV (Longview - Cowlitz #2, Longview - Lexington #2, Longview - Lexington - Cardwell)
Cowlitz PUD 2011-2014
16 Rapids - South Nile 115 kV line Douglas 201017 Douglas - Rapids 230 kV line and Rapids 230/115 kV Substation Douglas 201318 Columbia - Larson 230 kV line Grant 201419 Hemingway - Boardman 500 kV line Idaho Power 201520 Vantage - Pomona Heights 230 kV line (Yakima area) PacifiCorp 2012
21 New Lookingglass Substation on the Reston - Dixonville 230 kV line (Roseburg area)
PacifiCorp <2013
22 Parish Gap 230/115 kV substation connecting to Bethel - Fry 230 kV line (Albany area)
PacifiCorp 2012
23 Wallula-McNary 230kV line PacifiCorp 201224 White City 230/115 kV transformer addition (Medford) PacifiCorp 2012
25 Keeler - Horizon 230 kV line with 230/115 kV transformers at Horizon Portland General Electric
2012
26 South of Sedro Capacity Increase (Sedro - Horse Ranch 230 kV line) Puget Sound Energy 2010
27 230/115 kV transformer at Alderton Substation in south Puget Sound area
Puget Sound Energy 2011
28 Thurston County Transformer Capacity (St. Claire Substation ) Puget Sound Energy 2012
29 Lake Tradition 230/115 kV transformer fed via Maple Valley - Sammamish 230 kV line
Puget Sound Energy 2012
30 230/115 kV transformer addition at Sedro Woolley Substation (#2) in north Puget Sound area
Puget Sound Energy 2013
31 Beverly Park 230-115kV transformer (North Puget Sound) Snohomish PUD 201232 Cowlitz 230 kV transformer replacement (second bank) Tacoma Power 201133 Canyon Substation (Tacoma area) Tacoma Power 201134 Rapids - Columbia 230 kV line (Mid-Columbia area) undetermined 2013
Table 1: ColumbiaGrid Ten Year Plan
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Oregon with series capacitors. e. Portland General Electric’s Cascade Crossing Project – This project includes a Boardman-Juniper Flats-Bethell 500 kV line into the Salem area.
2. Colstrip UpgradesSeries capacitor additions and other additions are being considered to upgrade the Montana to Northwest path by 500 to 700 MW.
3. North King County Capacity Increase: A 230 kV line between Sammamish Substation in north King County and Talbot Substation in central King County is being considered to support growing loads in that area and to increase the capacity of the Monroe-Echo Lake cutplane.
4. Pearl-Sherwood UpgradesBonneville and Portland General Electric are
planning to separate the terminations for the existing Pearl-Sherwood 230 kV lines to provide additional capacity during outages to meet load growth in the southwest Portland area.
5.Shelton-Fairmount-Port Angeles supportA new 60 mile 230 kV line from Shelton to Fairmount is envisioned by Bonneville to support the Port Angeles/Port Townsend area of the Olympic Peninsula to meet growing loads. Other options include developing a 230 kV bus at Port Angeles Substation and capacitors at Happy Valley Substation.
6. North Downtown SeattleSeattle City Light is planning a new substation in the area north of downtown Seattle to serve load growth. This project would involve the installation of underground 230 kV transmission lines from East Pine and Massachusetts Substations to a new substation
Table 1: ColumbiaGrid Ten Year Plan
Figure 1: Projects added to the Ten Year Plan
Legend
New/Upgraded 115/230 kV lines
Substations
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with a 230 kV/115 kV autotransformer. The project construction would also include new 115 kV transmission lines from Canal and Broad Street Substations to the new substation. This project was studied last year and approved by the ColumbiaGrid Board but load growth in the area has subsided and the project has been delayed.
7. Lakeside 230/115 kV transformerPuget Sound Energy is planning a 230/115 kV transformer at Lake Tradition but they are also exploring Lakeside Substation in the Bellevue Washington area as an alternative in the near term. PSE will need both transformers eventually and plans to add both transformers in the ten-year planning horizon.
8. Mid Columbia Area Reinforcement Phase 2Grant County PUD is contemplating additional reinforcements between the Wanapum and Midway 230 kV Substations in central Washington.
9. Spokane Area 230 kV ReinforcementAdditional transformation is envisioned by Avista at Sunset Substation with new 230 kV lines to Westside, Beacon and/or Boulder Substations in south Spokane to meet growing loads.
10. Moscow Transformer AdditionsAn increase of 230/115 kV transformer capacity in the Moscow, Idaho area is needed to meet growing Avista loads.
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11. Lewiston ReinforcementsA second Lolo-Hatwai 230 kV line is one solution to increase capacity for Avista load growth and operational flexibility.
12. Walla Walla-Wallula 230 kV lineThis extension of the planned Wallula-McNary project may be needed by PacifiCorp in the future to meet transmission service requests for wind generation.
13. Springerville-Horizon 230 kV lineA new 230 kV line from the Trojan-St. Mary’s line is planned by Portland General Electric to meet growing loads in the west Portland area.
14. Chemawa 230/115 kV transformer additionsAdditional transformation is expected to be necessary in the north Salem area to meet growing Bonneville loads.
15. Blue Lake-Gresham 230 kV linePortland General Electric is planning this project, or an alternative, to provide support for load growth in the east Portland area.
16. Kalama EnergyA new 230 kV line from Kalama to Longview is being studied by Cowlitz PUD to connect
a 680 MW gas fired generation plant to the system and provide for load growth in the area.
17. Trojan-Horizon 230 kV lineThis new line would provide additional capacity on the South of Allston path to assist in delivering Beaver and Port Westward generation to Portland General Electric loads in the west Portland area.
18. Pilot Butte area transformationA 500/230 kV transformer addition is being investigated by Bonneville in the Ponderosa/Pilot Butte area to meet growing loads in the Bend/Redmond area in central Oregon.
19. Additional 500/230 kV transformation in South Puget Sound areaLimitations in 500/230 KV transformation in the south Puget Sound Area will require additional transformation, possibly at Maple Valley, Covington, Tacoma or Olympia. Depending upon the location selected, additional transmission lines may be required.
As alternatives to meet these long range needs mature into committed plans, they will be incorporated into future ColumbiaGrid Ten-year Plans.
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.Study Team Reports
The 2009 System Assessment identified two planning areas with needs that require multiple utility
studies during this planning cycle: the Cross Cascades transmission paths and the Olympic Peninsula. These areas involve load service issues with impacts to ColumbiaGrid participants. Projects that come about as a result of further study would typically be characterized as Existing Obligation Projects under PEFA. To investigate these planning issues two new study teams were formed. These study teams are in addition to the three study teams that have been active over the last year. The following sections of this report describe the activities of each of these study teams.
a. Puget Sound Area Study Teamb. N. Middle Columbia Area Study Teamc. Wind Integration Study Teamd. Cross Cascades Transmission Paths Study Teame. Olympic Peninsula Study Team
a. Puget Sound Area Study TeamThe Puget Sound Area Study Team tackled several important issues over the last year, including: reviewing the seasonal operating limit studies, examining the effect of several potential projects on transfer capability between the Northwest and Canada, and providing the WECC forum to analyze an increase in the south-to-north rating on the Northern Intertie. Each of these efforts is described below.
Reviewing System Operating LimitsThe Puget Sound Area Study Team reviewed the operating limits (nomograms) developed by Bonneville for the Northern Intertie. In addition to informing all the
interested entities about the latest study results, this analysis is useful in giving planners an opportunity to observe general trends on the system. As in the prior year, the studies reviewed this year indicate the general trend of increasing loads in the Puget Sound area and projected generation operation leading to a general decrease in transfer capability between the Northwest and Canada.
Examining the Effect of Potential Projects on Transfer Capability between the Northwest and CanadaA variety of projects are being considered in the Puget Sound area to meet various needs, including service to loads and increasing transmission capability across the Cascade Mountains. While these projects are not intended to affect the transfer capability between the Northwest and Canada, they may have inadvertent impacts on this capability.
To assess the effect on transfer capability, the Puget Sound Area Study Team has applied the methodology used in present-day system operations (e.g., the development of operating nomograms, as discussed in the prior section) in the planning timeframe.
Operating nomograms have been completed for future years with and without each of the potential projects in service. By examining changes in the nomograms that result from the addition of the projects, planners can more accurately determine their potential effect. These nomograms assess a much wider range of system conditions than is normally considered in system planning and provide additional insight into the benefits and impacts of transmission projects.
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To develop a baseline for determining any effects on transfer capability between the Northwest and Canada, the 44 operating nomograms for the Puget Sound area system were restudied for the 2018 timeframe, without any potential new projects in service. These studies were then repeated, placing each of the potential projects in service one at a time. The nomograms can then be compared to determine if there is any impact. From this analysis, the impact of a project on the operation of parallel systems and the Northern Intertie was determined. The results of this study are documented in a report that is available on the ColumbiaGrid website.
British Columbia-Northwest South-to-North Path Rating StudiesBritish Columbia Transmission Corporation (BCTC) and Bonneville, which jointly operate the Northwest-British Columbia interconnection, are completing WECC
rating studies to increase the south-to-north rating of the Northern Intertie from 2,000 MW to approximately 3,000 MW. They are using the Puget Sound Area Study Team to coordinate these studies.
For the British Columbia side of this interconnection, BCTC plans to increase conductor-to-ground clearance of the 500 kV transmission lines from Ingledow Substation to the border. BCTC is also considering installing conductor temperature monitoring to permit higher transfers until conductors can be raised. Any facilities required on the U.S. side to support this higher rating are expected to be identified during the path rating studies.
b. Northern Middle Columbia Area Study TeamThe Northern Middle Columbia Area Study Team is developing a one-utility plan to resolve the system deficiencies in the greater
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Wenatchee area. These deficiencies were identified in the 2008 ColumbiaGrid System Assessment and individual utility studies for high generation scenarios during summer conditions. These plans have also been tested during other seasons and with potential wind development in the Central Washington area.
The primary focus area for the Northern Middle Columbia Study is the area from
Wanapum/Vantage Substation north through Wenatchee to Wells Dam. The region is shown in Figure 2. The problems in this area are a combination of load growth in the Middle Columbia area, compounded by the wide range of generation patterns from the middle and upper Columbia hydro resources that cause north to south transfers throughout the area. The area problems are most acute in the warm summer season when the capacity of facilities is lowest and local
Figure 2: Northern Mid C Preferred Plan
Legend Substations Dams 115kV Lines 230kV Lines 345kV Lines 500kV Lines Existing Transformer Proposed Lines Proposed Transformer
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generation is high. Chelan County PUD loads are growing and Alcoa is planning to increase production with an additional pot line at Valhalla. Douglas County PUD loads are also growing and there is a new server farm that could add a large new load in the Pangborn Airport area.
The Chelan County PUD and Douglas County PUD systems are electrically in parallel in this area. Several other utilities also have facilities in the area, including: Bonneville, Grant County PUD, Puget Sound Energy and Avista. All of these utilities participated in this study along with Bonneville Power Administration Power Services and the Grand Coulee Project Hydroelectric Authority.
In addition to the existing hydro and wind generation, there is wind generation under construction or planned in the area. Generation north of Columbia Substation will aggravate the identified issues. Generation south of Columbia Substation will reduce the problems.
To meet the expected load growth in the area, the utilities are planning to add several facilities. Douglas County PUD is planning to build a new 230/115 kV substation and associated lines in the Pangborn area to support load growth. Chelan County PUD has plans to re-terminate several transmission lines in the Andrew York area in the north end of Wenatchee to improve outage performance. They are also upgrading the capacity of the McKenzie-Wenatchee Tap 115 kV line that feeds the Wenatchee area from the south. Grant County PUD has plans to add a 230 kV line from Columbia Substation, south of Wenatchee, to a substation called Larson in the Moses Lake area. While these projects work well to solve the project specific problems, when grouped together there are remaining system problems in the
area that will require mitigation.
Seven alternative plans were developed by the study team to resolve the remaining transmission issues in the area. These alternatives included new 230 kV lines, new 115 kV lines, upgrades of existing lines and combinations of the above. Outages required by the Planning Standards were run for these alternatives, cost estimates were developed and several sensitivity studies were performed. These results were compared and the study team agreed that the plan to build a Rapids-Columbia 230 kV line and rely on manual generation adjustments to control the remaining flows on the 115 kV system for low probability outages would be the best single utility plan for the area.
Although the Study Team has agreed on the best plan for the area, the construction, ownership and cost responsibility of these additional facilities has not been determined at this time. In the next few months, the utilities will be working together to resolve these issues.
c. Wind Integration Study TeamThe Northern Tier Transmission Group and ColumbiaGrid formed the Wind Integration Study Team (WIST) to facilitate the integration of Renewable Generation into the northwest transmission grid. The current focus of the group is to support the technical study needs of existing subregional and regional initiatives by addressing the following two issues:
•Technical evaluation of system constraints on the increased use of dynamic scheduling – One of the primary products of the WestConnect/NTTG/ColumbiaGrid Joint Initiative (http://www.columbiagrid.org/ji-nttg-wc-overview.cfm) is the increased utilization of dynamic scheduling. However, there may
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be technical constraints on the various scheduling paths that limit the acceptable magnitude or rate of these schedule changes. This issue was highlighted recently on the Northern Intertie where it was determined that voltage support issues limited the amount of dynamic schedules that could be accommodated.
•Action Items from the Northwest Wind Integration Action Plan – The WIST will address the following two action items from the Northwest Wind Integration Action Plan: 1) the development of a transmission planning methodology that seeks a balance between the cost
of transmission capacity and the value of delivered wind energy; and, 2) apply this new transmission planning methodology to regional transmission planning.
WIST has held several meetings during 2009 and has made substantial progress on the above efforts. The results of the dynamic scheduling study are projected to be complete by the summer of 2010. These efforts are being closely coordinated with other subregional groups and WECC.
d. Cross Cascades Study TeamThe 2009 System Assessment identified outages associated with two paths, West
Figure 3: Cross Cascades Transmission Issues
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of Cascades North and West of Cascades South, as possible reliability concerns in the ten-year winter planning case. The location of these two paths is shown in Figure 3. These paths deliver remote resources from east of the Cascade Mountains of Oregon and Washington to the west side load areas. If critical outages on these paths were to occur during winter cold snaps in the latter part of the planning horizon, voltage stability limitations could result. Although these problems are just beginning to manifest themselves in the ten-year studies, it is possible that major transmission line construction would be needed to resolve these issue and those types of additions could take 7 to 10 years to complete. The construction lead time requires that these issues be addressed at this time.
The West of Cascades North path consists of the Chief Joe-Monroe, Schultz-Raver #1, #3 and #4 and the Schultz-Echo Lake 500 kV lines; the Chief Joe-Snohomish #3 and #4 and Rocky Reach-Maple Valley 345 kV lines; the Coulee-Olympia 300 kV line; and the Rocky Reach-White River and Columbia-Covington 230 kV lines. The transfer limit of this path is about 10,000 MW and is voltage stability limited.
The West of Cascades South path consists of the Big Eddy-Ostrander, Ashe Marion, Buckley-Marion, Wautoma-Ostrander and John Day-Marion 500 kV lines; McNary-Ross 345 kV line; Big Eddy-McLoughlin, Big Eddy-Chemawa, Midway-North Bonneville, Jones Canyon-Santiam, Big Eddy-Troutdale and Round Butte-Bethel 230 kV lines. The transfer limit of this path is about 7,000 MW and is also voltage stability limited.
Although these two paths are separated by a couple of hundred miles, they interact with each other. Additions to one path will
not only add capability to that path but also divert some of the power from the other path. This issue was identified as a multi-system, multi-member concern.
These paths are not scheduled but typically load most heavily during abnormally cold weather events. The paths are usually loaded well below their limits for the rest of the time (refer to path loading diagram Figures 5i & 5j ). The most recent cold weather event occurred in December 2008. In the past, local generation is typically running during cold weather events and area loads increase. This reduces flows on the paths. Operation with new wind resources could also aggravate these problems. Many utilities are planning to deal with the uncertainty of wind generation by shutting down west side gas and hydro resources when the wind generation is being produced and relying on this generation when the wind is not blowing. Although we have found that wind generation is unlikely during winter and summer peak load events, it is not a certainty.
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If the wind generators are producing power and the west side resources are shut down, there will be increased flows across the two paths.
To work toward resolving these issues, a ColumbiaGrid study team was formed with ColumbiaGrid participants and other interested parties.
The purpose of this study is to investigate the extent of the system problems and the performance and interaction of potential projects on the problems identified on these paths. Potential plans will be identified and compared.
e. Olympic Peninsula Study TeamSeveral issues were identified in the 2009 System Assessment concerning the transmission on the Olympic Peninsula in northwestern Washington. The transmission deficiencies include:
1. Northern Olympic Peninsula: Voltage instaility in the Fairmount and Port Angeles area may occur for loss of either the Shelton-Fairmount 230 kV #1 or #2 line (on double circuit towers).
2. Olympic Peninsula: The loss of the Olympia-Shelton 230 kV #3 and #4 lines (on double circuit towers) may cause voltage instability and overload the Olympia-Shelton 230 kV line #5.
3. Olympia Area: Voltage instability may occur for the outage of the Paul-Olympia 500 kV line and for breaker failure outages at Paul that trip the Olympia-Paul and Paul-Tono lines. This latter outage also overloads the Olympia-Satsop 230 kV line. Voltage instability may occur for the common mode outage of the Paul-Satsop and Paul-Olympia 500 kV lines and overload the Olympia-Chehalis 230 kV line. Also, the Cosmopolis-Aberdeen 115kV line is overloaded with no contingency during abnormal cold weather conditions.
To work toward resolving these issues, a ColumbiaGrid Study Team is planned to start in early 2010 with Bonneville and Puget Sound Energy to determined the extent of the problems in the area, discuss the current utility efforts to resolve those issues and determine what efforts ColumbiaGrid should undertake in the area.
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Potential Major Transmission ProjectsSeveral large transmission projects have been proposed in the region to integrate new resources and accommodate economy transfers to access lower cost resources. See Figure 4 for a map of these projects. Some are being proposed by or sponsored by ColumbiaGrid members. All of the projects are electrically in parallel with ColumbiaGrid member facilities and could have impacts to the existing system. Many of them are in the WECC Path Rating Process.
At this point, there are firm commitments by sponsors to build four of these projects; John Day-McNary, Big Eddy-Knight, Hemmingway-Boardman and the I-5 Corridor Reinforcement. These projects
were included in the assessment cases but the projects without firm commitments were not (since the I-5 Corridor Reinforcement Project is not expected to be completed until 2015 it was only included in the ten-year studies). This approach avoids masking problems on the transmission systems that would need to be addressed if the more speculative projects are not built. Analysis of impacts that these major projects might have on the load service and firm transmission service commitments of the PEFA parties will be addressed by the ColumbiaGrid study teams tasked with studying the areas that could be affected by these potential projects.
Figure 4: Regional Projects
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a. West of McNary Area Reinforcement ProjectThis Bonneville project includes two line projects; a McNary-John Day 500 kV line and a Big Eddy-Knight 500 kV line. The project in its entirety includes about 110 miles of new line construction and is proposed to increase the capacity of the West of McNary, West of Slatt, West of John Day and West of Cascades South transmission paths. This project would provide additional transmission capability to accommodate transmission service that is being requested in the Bonneville Network Open Season process. The McNary-John Day line is expected to be completed in 2012 and the Big Eddy-Knight project in 2013.
ColumbiaGrid conducted the WECC regional planning process for this project, which concluded in February 2008. Bonneville has indicated that its financial analysis determined that the project is justified under the rules of its Network Open Season. Bonneville has completed the environmental review for the John Day-McNary 500 kV line and has initiated construction of the project. The environmental review for the Big Eddy-Knight 500 kV line is underway.
b. I-5 Corridor Reinforcement ProjectThe I-5 Corridor Reinforcement project consists of a 70 mile 500 kV line north from Troutdale Substation east of Portland to the new Castle Rock Substation north of Longview. The project is scheduled to be energized in 2015.
ColumbiaGrid conducted the WECC regional planning process for this project, which was concluded in March 2008. WECC rating studies are currently being conducted through the ad hoc Transmission Coordination Work Group.
Bonneville has indicated that the financial analysis it has done shows that the project is justified under the rules of its Network Open Season but the decision on whether to build the I-5 Corridor Reinforcement project will depend on the outcome of the NEPA review which is underway.
c. Cascade Crossing ProjectThe Portland General Electric Cascade Crossing project is a 200 mile line from Portland General Electric’s Coyote Springs generation plant in the town of Boardman, Oregon west to Portland General Electric’s Bethel Substation in Salem, Oregon where the line will be terminated into a new 500/230 kV transformer bank (other west-side terminations are also being considered).
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The new line will also interconnect with a new substation 72 miles east of Salem called Juniper Flat which will be the point of interconnection for new wind generation projects. The project will also interconnect at the existing Boardman Substation. The proposed rating of the single circuit 500 kV line project is 1,500 MW. The project is scheduled to be energized in 2015.
WECC regional planning and rating studies are now being conducted through the ad hoc Transmission Coordination Work Group.
d. Gateway West Project Idaho Power and PacifiCorp are proposing a joint project that includes a 500 kV line from Jim Bridger (Wyoming) to Hemingway Substation in the Boise area. This project is being planned with a 1,500 MW capacity. The proposed in-service date is 2013. This project may be expanded to a double circuit line with 3,000 MW capacity.
WECC regional planning was initiated in August 2007 and the planning report has been submitted to WECC. WECC rating studies are being conducted now through the ad hoc Transmission Coordination Work Group.
e. Hemingway to Captain Jack ProjectIn conjunction with the Gateway West project, PacifiCorp is proposing to build a new 375-mile 500 kV line from Hemingway Substation in the Boise area to Captain Jack Substation in southern Oregon. This line is expected to add 1,500 MW of capacity to support west side load growth and increase east-to-west transfer capability between Idaho and the Northwest. The proposed in-service date is 2014. WECC rating studies are being conducted in the ad hoc Transmission Coordination Work Group.
f. Hemingway to Boardman ProjectIdaho Power is planning a line from Hemingway Substation near Boise, Idaho to the existing Boardman Substation in northeastern Oregon. This 300-mile project is intended to provide 1,300 MW of capacity in the west-to-east direction and 1,400 MW in the east-to-west direction between the Northwest and Idaho. The proposed in-service date is 2015. The WECC regional planning process for this project started in August, 2007. WECC rating studies are in process now through the ad hoc Transmission Coordination Work Group.
g. Canada-Pacific Northwest to Northern California ProjectPacific Gas and Electric Company (PG&E) is proposing a series compensated 500 kV double circuit AC line from Selkirk Substation in southeast British Columbia to a new substation in northeast Oregon near Boardman Substation called NEO, along with a high-voltage DC line from the new
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substation to the San Francisco Bay area. This 1,000+ mile long project is planned to have a capacity of 3,000 MW. The projected cost is between $3 billion and $7 billion, not including local system upgrades. Avista is participating in the project, with a proposed interconnection at Devils Gap Substation, which is located west of Spokane. The Devils Gap portion of the project was studied separately. The proposed in-service date is 2015.
The WECC regional planning process for this project was initiated in August 2006. The Phase 1 rating process was initiated October 31, 2007, with PG&E, BCTC, Avista, and PacifiCorp as project sponsors. WECC rating studies are under way in the ad hoc Transmission Coordination Work Group.
i. Northern Lights ProjectThe Northern Lights project is a 970-mile high-voltage DC line (+/- 500 kV) beginning at Edmonton, Alberta and ending at a new substation near the existing Buckley Substation in north central Oregon. The estimated cost of the line is $1.7 billion. At least one intermediate terminal is planned in a location south of Calgary, near Alberta’s largest wind development region. The
project is planned to have bidirectional capacity as high as 3,000 MW. This project takes advantage of the diversities in load and generation between the two areas. It is scheduled for energization in 2014.
WECC regional planning was initiated on July 11, 2006. Corridor location, preliminary engineering, and tower design are well advanced. Discussions regarding project approval and participation are ongoing with other utilities and governmental agencies in both Canada and the Northwest. WECC rating studies are under way in the ad hoc Transmission Coordination Work Group.
j. Juan de Fuca Cable #1 ProjectSea Breeze Pacific is proposing an underwater 550 MW high-voltage DC cable across the Strait of Juan de Fuca from Vancouver Island to the Port Angeles, Washington area. This project rating is planned to be bidirectional. The project will also require existing system reinforcements, including 230 kV line additions from Olympia to Fairmount Substations. This project was granted Phase 2 rating status on June 29, 2007.
k. Juan de Fuca Cable #2 ProjectSea Breeze Pacific is proposing an underwater 1,100 MW high-voltage DC cable (+/- 300 kV) across the Strait of Juan de Fuca from north of Vancouver, British Columbia to Shelton Substation on the Olympic Peninsula. The 1100 MW project rating is planned to be bidirectional.
l. West Coast Cable ProjectSea Breeze Pacific is proposing an underwater high-voltage DC cable from Allston Substation in northwest Oregon near Rainier to the San Francisco Bay area. This project has a planned rating of 1,600 MW. This project is intended to bring renewable resources from the Northwest to California.
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Interfaces with Neighboring Regions
Oregon and Washington are electrically interconnected to Canada, Montana, Idaho,
Nevada, and California. The historical use of these interconnections has been high and of benefit to the Northwest and others. Transmission service requests submitted to transmission owners and proposals for generation resources within and outside the Northwest suggest that demands on these interconnections in the future will exceed their present-day capabilities. The following sections discuss each of the major interfaces, recent historical usage, and potential projects to increase their capabilities.
a. Northwest to British ColumbiaThe Northwest to British Columbia path consists of two 500 kV lines (Ingledow-Custer #1 & #2) and two 230 kV lines (Nelway-Boundary and Waneta-Boundary, which is normally open). The path is rated
3,150 MW north-to-south and 2,000 MW south-to-north.
The historical loading on this path is shown in Figure 5a. As can be seen, this interface is used in both directions, although the predominant flow is south to north. Generally, the path flows are in the south-to-north direction in the fall and winter, when the return of the downstream benefit of U.S. dams to Canada is the predominant influence. In the spring and summer, Canada typically is exporting large amounts of power to the Northwest and California, and the flows are in the north-to-south direction. Depending on the relative generation development plans in the United States and Canada, increased utilization in either or both transfer directions could occur.
Five projects are currently in the planning and/or permitting phase that could increase the capability of this interface.
Figure 5a: Northwest to British Columbia
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Juan de Fuca Cable #1 Project: This project is described in detail in the Major Regional Projects section of this report. The intent of the proposed 550 MW undersea cable between Vancouver Island and Port Angeles, Washington and associated system reinforcements is to export potential future wind generation development on Vancouver Island to the United States. Transfers into Canada from the Northwest are also possible. The sponsor is Sea Breeze Pacific.
Juan de Fuca Cable #2 Project: This project is described in detail in the Major Regional Projects section of this report. The intent of the proposed 1,100 MW undersea cable between Vancouver, British Columbia and Shelton Substation on the Olympic Peninsula and associated system reinforcements is to export potential future wind generation development in British Columbia to the United States. Transfers into Canada from the Northwest are also possible. The sponsor is Sea Breeze Pacific.
Northern Lights Project: This project is described in detail in the Major Transmission Projects section of this report. The intent of this proposed 3,000 MW DC transmission line from Alberta to Oregon is to export wind and other types of generation to the Northwest and also to import Northwest resources to Alberta. The sponsor is TransCanada. The Canada-Pacific Northwest-Northern California Transmission Line Project: This project is described in detail in the Major Transmission Projects section of this report. The project would add 3,000 MW of transmission capability between Canada, the Northwest, and California. The primary purpose of the project is to provide California with access to Canadian renewable resources. The project also includes connections to the Northwest that will provide access to these same resources.
Figure 5b: Montana to Northwest
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Northern Intertie South-to-North Rating Increase Project: In addition to the above projects, it may be possible to obtain additional south-to-north capability (from 2,000 to 3,000 MW) from the existing Canada to Northwest Intertie with relatively minor upgrades. This rating increase is currently under study by Bonneville and BCTC. The study results are being coordinated through the ColumbiaGrid Puget Sound Area Study Team.
b. Montana to the NorthwestThe Montana to the Northwest path consists primarily of the Broadview-Garrison #1 & #2 500 kV lines. In addition, the path contains four 230 kV lines, three 115 kV lines, and a 230/161 kV transformer. The path has an east-to-west rating of 2,200 MW and a west-to-east rating of 1,350 MW. The historical loading on this path is shown in Figure 5b. As can be seen, this interface only reaches its maximum capability in the east-to-west direction, as the primary purpose of
the path is to deliver major resources, such as the Colstrip Power Plant, to the Northwest. During peak load periods, the loading on this path can be lower in response to loads in Montana consuming more of the available resources. Several proposals for additional resources in Montana indicate that the transmission loadings on this path can be expected to increase.
Two projects are in the planning phase to increase the transmission capability of this path.
Series Capacitor Increase Project: An increase in the existing Montana to Northwest capability (upwards of 700 MW) may be possible through the addition of series capacitors and other equipment on the existing Intertie lines. Montana to the Northwest Project: This project would most likely consist of a new 500 kV line from Broadview, Montana to eastern Washington. Bonneville and NorthWestern
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Energy completed a study to accommodate several open access transmission requests for added transfer capability. The study concluded that a new transmission line was needed at a cost exceeding $1 billion. In addition, NorthWestern Energy has received an economic study request for a new line between Montana and the Middle Columbia in Washington.
c. Idaho to the NorthwestThe Idaho to the Northwest path consists of the Midpoint-Summer Lake 500 kV line, the Imnaha-Lolo 230 kV line, the Hells Canyon-Enterprise 230 kV line, the Quartz Tap-LaGrande 230 kV line, and the Hines-Harney 115 kV line. The path has an east-to-west rating of 2,400 MW and a west-to-east rating of 1,200 MW.
The historical loading on this path is shown in Figure 5c. As shown, this path generally delivers power to the Northwest during the fall and winter, and delivers Northwest power to Idaho during the spring and summer.
Two potential improvements are planned for this path.
Hemingway-Captain Jack: The Hemingway-Captain Jack 500 kV line from near Boise to southern Oregon has been proposed by PacifiCorp to increase transfer capability for new wind generation and other resources planned in Idaho and Montana.
Hemingway-Boardman: The Hemingway-Boardman 500 kV line has been proposed by Idaho Power primarily to increase the ability to import power from the Northwest into Idaho.
Both of these lines are discussed further in the Major Regional Projects section of this report.
d. Northwest to CaliforniaThere are two major connections between the Northwest and California: the California - Oregon Interties (COI) and the Pacific DC Intertie. The COI consists of the two Malin-Round Mountain 500 kV lines (the Pacific AC Intertie) and the Captain Jack-Olinda 500 kV line (the California-Oregon Transmission Project). The COI is rated at 4,800 MW north-to-south and 3,675 MW from south-
Figure 5c: Idaho to Northwest
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to-north. The Pacific DC Intertie is a +/- 500 kV bipole DC line between The Dalles, Oregon and Los Angeles, California. The Pacific DC Intertie is rated 3,100 MW in both directions.
The historical loading on these paths is shown in Figures 5d and 5e. As shown, this interface frequently operates at its maximum capability in the north-to-south direction, but does not reach its capability
in the south-to-north direction. Loadings are highest in the north–to-south direction in the spring and summer when Northwest and Canadian generation is being delivered to loads in California. During the winter, flows tend to be in the south-to-north direction as California resources help the Northwest meet its peak loads. A trend toward increasing north-to-south transfers is expected as a result of California entities purchasing several Northwest wind generation plants.
Figure 5d: COI
Figure 5e: PDCI
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Four projects are currently in the planning phase to increase the capability of this interface.
California-Oregon Interties Upgrade Project: Bonneville is implementing a project that includes the addition of shunt and series capacitors to enable this interface to be utilized at its full capability more often. This project will not increase the existing rating but will improve the availability of the full rating, which currently is rarely available to operations.
Increase the California-Oregon Interties North-to-South Rating from 4,800 to 5,100: With relatively modest transmission improvements, the California portion of the Intertie can be upgraded to 5,100 MW. It is uncertain what upgrades would be required in the Northwest. This rating increase is currently under study.
West Coast Cable Project: The intent of this proposed 1,600 MW undersea cable between Oregon and California is to export
potential future wind development in the Northwest to California. The sponsor is Sea Breeze Pacific. This project starts at Allston Substation in northwest Oregon and extends to Newark Substation in the San Francisco Bay area.
The Canada/Pacific Northwest to Northern California Project: As described previously, this project would add 3,000 MW of transmission capability between Canada, the Northwest, and California. The primary purpose of this project is to provide California with access to Canadian and Northwest renewable resources.
e. Northwest to Nevada (Alturas tie to Sierra): The Alturas line is a 300 MW bidirectional path between southern Oregon and the Reno, Nevada area and is typically used to transfer Northwest resources to Nevada. The flows on this path are included in the California-Oregon Interties transfers, but are also shown below inn Figure 5f. There are no plans to upgrade this path.
Figure 5f: Alturas
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Internal InterfacesThe flows between the northwest and other sub-regions in combination with the internal northwest generation and loads, determines the flow on the northwest’s internal transmission system. Several internal interfaces have been defined in critical parts of the systems for monitoring and operation of the system. These internal interfaces include North of John Day, South of Allston, West of McNary, West of Cascades North, West of Cascades South and West of Hatwai. This section discusses these interfaces, recent historical usage and potential projects to increase their capabilities.
a. North of John DayThe North of John Day path consists of six 500 kV lines; Raver-Paul, Wautoma-Ostrander, Wautoma-John Day, Ashe-Marion, Ashe-Slatt and Lower Monumental-McNary. This path shows the stress on the system when less generation is running on the lower Columbia
area system due to spill (when this generation is replaced by more remote generation, additional stress is placed on the system). This path helps determine the total export capability to California. The maximum rating of this path is 8400 MW.
The flows on this path are shown in Figure 5g. This path loads most heavily in spring and summer when water is being spilled over the lower Columbia dams for fish migration and power is being exported to California. Its use is much reduced in fall and winter when spill is minimal and northwest resources are used to meet northwest loads.
There are some proposed projects that would upgrade this path including: Bonneville’s I-5 Corridor Reinforcement project, TransCanada’s Northern Lights Project and PG&E’s Canada-Pacific Northwest to Northern California Project.
Figure 5g: North of John Day
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b. South of AllstonThe South of Allston Path consists of the Allston-Keeler 500 kV line, the Allston-Rainier 115 kV line, the Astoria Tap-Seaside 115 kV line, the Merwin-View 115 kV line, the Trojan-Rivergate 230 kV line, the Trojan-St Mary’s 230 kV line and the Woodland Tap-Ross 230 kV line. This path is rated at approximately 2900 MW (the actual rating is determined by seasonal OTC studies and system conditions). This path is limiting in summertime when northwest hydro generation is limited and exports to California are supplied with imports from
Canada and west side gas resources. Flows on this path are much lower in other seasons. The 2007 flows on this path are shown in Figure 5h.
Bonneville’s I-5 Corridor Reinforcement project would substantially increase the capability of this path. Portland General Electric is also considering a new 230 kV line from Trojan to the west side of Portland (Horizon Substation by Keeler) which could provide an increase in capability south of Trojan.
Figure 5h: South of Allston
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c. West of Cascades NorthThe West of Cascades North Path consists of the Chief Joseph-Monroe 500 kV line, the Schultz-Raver # 1, #3, and #4 500 lines, the Chief Joe-Snohomish 345 kV #3 and #4 lines, the Rocky Reach-Maple Valley 345 kV line, the Coulee-Olympia 300 kV line, the Rocky Reach-White River 230 kV line, the Columbia-Covington 230 kV line and the Schultz-Echo Lake 500 kV line. This path is rated at 10,200 MW.
This path is most limiting in the winter when temperatures are low and loads are high in the northwest, especially if local west side generation is unavailable and/or exports to Canada are high. Loading on this path is typically not critical in other seasons. Recent loading on this path is shown in Figure 5i.
Proposed projects that would upgrade this path include Puget Sound Energy’s IP Line Upgrade and Bonneville’s series capacitors at Schultz.
Figure 5i: West of Cascades North
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d. West of Cascades SouthThis path consists of the Big Eddy-Ostrander 500 kV line, the Ashe-Marion 500 kV line, the Buckley-Marion 500 kV line, the Wautoma-Ostrander 500 kV line, the John Day-Marion 500 kV line, the McNary-Ross 345 kV line, the Big Eddy-McLoughlin 230 kV line, the Big Eddy-Chemawa 230 kV line, the Midway-N. Bonneville 230 kV line, the McNary-Santiam 230 kV line, the Big Eddy-Troutdale 230 kV line and the Round Butte-Bethel 230 kV line. This path is rated at approximately 7000 MW.
This path is most limiting in the winter when temperatures are low and loads are high in the northwest, especially if local west side generation is unavailable. Loading on this path is typically not critical in other seasons. Recent loading on this path is shown in Figure 5j.
Projects proposed that would upgrade this path, or add parallel capacity, include Bonneville’s Big Eddy-Knight project which is part of the West of McNary Area Reinforcement and Portland General Electric’s Cascade Crossing Project.
Figure 5j: West of Cascades South
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e. West of McNaryThe West of McNary path consists of the following lines; Coyote-Slatt 500 kV line, McNary-Ross 345-kV line, McNary-Horse Heaven 230 kV line and the Boardman 230 kV line. The purpose of this path is to measure the stress on the system when there is heavy generation in the McNary area and transfers to the west. The rating of this path is 2870 MW.
This path is most limiting in the spring of the year. Path flows typically recede under summer and winter conditions. Recent loading on this path is shown in Figure 5k.
Projects proposed that would upgrade this path, or add parallel capacity, include Bonneville’s West of McNary Area Reinforcement Project and Portland General Electric’s Cascade Crossing Project.
Figure 5k: West of McNary
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f. West of HatwaiThe West of Hatwai path consists of the following lines; Hatwai - Lower Granite 500 kV, Bell - Coulee 230 kV #3 and #5, Westside – Grand Coulee 230 kV, Dry Creek -Walla Walla 230 kV, Bell - Creston 115 kV, North Lewiston - Tucannon River 115 kV, Harrington Odessa 115 kV, Lind - Roxboro 115 kV, Dry Gulch 115/69 kV transformer and Bell – Grand Coulee 500kV. This path is rated at 4277 MW.
The purpose of this path is to measure the stress on the system when there is heavy generation in Montana and Northern Idaho and transfers through eastern Washington to the west. This path is most limiting in the spring of the year. Path flows are typically lower under summer and winter conditions. Recent loading on this path is shown in Figure 5l.
This project was recently upgraded with the Bell-Coulee 500 kV line and several other line upgrades. No other new projects are proposed to upgrade this path. Upgrades to the Montana to Northwest path would increase the loading on this path.
Figure 5l: West of Hatwai
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Study Assumptions and Methodology
The Northwest transmission grid is interconnected and as result, it was necessary for all Northwest entities
to participate in the development of this Plan Update whether or not they are parties to the ColumbiaGrid PEFA. Major transmission owners in the Northwest were notified individually and encouraged to participate in the planning process. All participants who provided input to the study or helped to screen results had access to the same information whether or not they were parties to PEFA.
The major assumptions that form the basis of this Plan Update are load, generation, external path flows, and planned transmission additions. The approach to developing each of these assumptions and the study methodology that was used to complete the studies described in this Plan Update are summarized below.
Basecase DevelopmentTo cover the ten-year planning horizon, ColumbiaGrid developed five and ten-year basecases for winter peak load, winter extreme peak load, and summer peak load conditions. Once the basecases were established, the Basecase transmission system, with no outages, was analyzed to ensure it met planning standards. Deficient areas were noted and corrections or updates were made as appropriate.
To create the five-year cases, approved WECC basecases were used as a starting point. After surveying the available cases, the recent 2014 Heavy Winter case (14HW1) and the 2013 Heavy Summer case (13HS1) were chosen. Corrections and updates were made to these cases to ensure that they would be as accurate as possible. Ten- year planning cases were not available from WECC when the System Assessment was completed. The ten-year cases in the system assessment were
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created by modifying the five-year cases to model projected ten-year system conditions. However, since the completion of the System Assessment, new approved ten-year cases became available from WECC and the ten-year analysis in the System Assessment was redone. The results presented in this report reflect this updated analysis. The ten-year WECC planning cases used were the 2019 Heavy Summer (19HS1) and 2019 Heavy Winter (19HW1). These cases were then modified to reflect 2020 Heavy Summer and 2020-21 Heavy Winter conditions. Updates and corrections received from participants were incorporated into the models.
All of the basecase assumptions, such as the load levels modeled, the generation pattern modeled, and the transmission configuration, were selected by the ColumbiaGrid Planning group during open meetings.
Load Modeling AssumptionsAs required in the NERC Reliability Standards, the transmission system is planned for expected peak load conditions. In addition, some study participants have planning criteria that requires their system to be capable of meeting abnormally cold weather loads. This additional requirement is a result of the prevalence of electric heat in the region, particularly in the west side load areas. Normal summer and winter peak loads were based on a probability of 50 percent not to exceed the target load peak.
Participants reviewed the loads in the 13HS1 and 14HW1 cases. These cases, although recently approved, were developed prior to the recent economic downturn. Participants expect a slowing on load growth in the short term and felt that these two cases would be representative of the five-year time horizon without any change to the loads modeled. Given these assumptions, the total winter
peak load for the Northwest system is expected to be 33,023 MW in the five-year case. The forecast summer peak loads for the five-year case is lower than winter at 26,490 MW. While the Northwest system as a whole peaks in the winter, this does not mean that summer conditions require less attention. The capacity of electrical equipment is often limited by high temperatures, which means the equipment has lower capacity in summer than in winter. Also, lower loads near generation can cause line loading to be higher as this generation is transferred to remote loads rather than used locally. As a result, it is possible that a lower summer load can be more limiting than a higher winter load due to the ambient temperature differences and the impact on equipment.
The total winter peak load for the Northwest system is modeled at 35,004 MW in the ten-year case. The forecasted summer peak load for the ten-year case is 28,898 MW.
Extreme peak loads for abnormal winter conditions were based on a probability of 95 percent not to exceed the target load peak. The abnormal winter peak cases assumed cold weather in the Pacific Northwest footprint only (primarily Oregon, Washington and Northern Idaho). British Columbia, southern Idaho, Montana, Wyoming, and Utah were modeled with normal winter peak loads and, due to the physical separation of these systems, it was determined that this assumption would not impact the performance of the transmission system within the Pacific Northwest footprint. The main impact of this assumption would be resource availability from neighboring regions and not transmission system performance.
To represent the abnormal winter condition, load increases of about 12% have been used
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in the past based on analysis completed by Battelle NW. This increase is very similar to the 12.9% increase in the ten-year case, so 12.9% was used for the five-year abnormal winter case. The 14HW1 case was modified to represent an abnormal winter load condition by increasing the loads by 12.9%, only the real component of the load was increased. The extreme winter peak load forecast total for the Northwest in the five-year case is 36,804 MW. The Northwest extreme peak load modeled in the ten-year case studied in the System Assessment was 39,017 MW.
Resource Modeling AssumptionsResource additions ten years into the future are much more difficult to forecast than loads. Although there are numerous potential generating projects in the region in various stages of development, there is much uncertainty for a variety of reasons about whether and when they will come into service. Many of the variables are outside the control of transmission providers. Adding to the complexity, these resource assumptions are particularly important. Depending upon
their location, some resources can mask transmission problems while others can create new problems. While the existing northwest resources are adequate to meet summer loads, they are not adequate to meet winter peak loads. Northwest utilities rely on seasonal diversity in resource needs with other regions to meet winter load obligations by importing from California and the Southwest.
Several combustion turbine projects have been built recently in the Northwest that do not have firm transmission commitments, including Big Hanaford and Grays Harbor. Both projects are located in Washington State. Big Hanaford is located in the Chehalis area and Grays Harbor is located near Aberdeen. In addition, there are many indicators, including the number of requests for interconnection that transmission providers have received in recent years, to suggest that other resources will be developed in the region during this ten-year planning horizon. The addition of proposed generation projects, especially thermal projects on the west side of the
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Cascades, could have a significant impact on the performance of the transmission system and reduce the reliance on California imports that was assumed in the winter cases. Planned transmission projects will be reviewed periodically to determine whether changes in resource additions would impact the need for, or scope of, these projects.
The high load level in the extra-heavy winter basecase resulted in significant low voltages in the Centralia/Olympic Peninsula area, a sign of system problems. To proceed with the study, shunt capacitors were added to the model (two 300 MVAR banks on the Allston 500 kV bus and two 300 MVAR banks on the Allston 230kV bus). The West of Cascades flows in this case were also near or above the present-day operating transfer capability (OTC) limit, which could be the cause of the depressed voltages. The two existing resources mentioned above that
do not have firm transmission contracts, Big Hanaford and Grays Harbor, were assumed to be operating during both normal and extra-heavy winter conditions.
There is a significant amount of new wind generation proposed in the ColumbiaGrid footprint. Figure 6 shows the existing wind resources, along with projects under construction and projects proposed as of May 2009. Although there are several thousand megawatts of wind generation in the Northwest, zero wind generation was assumed during the peak load conditions in the System Assessment. Historical operation has shown there is often little wind generation during either winter or summer peak load conditions. Operation without wind generation results in increased reliance on local gas generation and/or increased imports from California and the southwest. To assess system performance with higher
Figure 6: Wind Resources
Wind GrowthLegend
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levels of wind generation, ColumbiaGrid performed sensitivity studies as discussed later in this report.
Although there is significant wind generation potential in eastern Washington and Oregon, there is much more potential in Idaho, Montana, and Wyoming. The required transmission additions to serve those remote resources are much greater, however, very limited new transmission capability is planned to enable these wind resources to reach the Northwest. In the five-year normal winter case, ColumbiaGrid assumed 743 MW was imported into the Northwest over the Pacific DC Intertie and the California-Oregon Interties. In the extra-heavy winter case, the import over these facilities increased to 4,614 MW, an assumption that results in high stress to the transmission system and shows the upper bound of the transmission system needs. For the ten-year normal winter study, ColumbiaGrid assumed 2,972 MW was imported into the Northwest on the combined southern interties.
No retirement of existing resources has been identified or included in the basecases. A list of the resources used in each Basecase is included in Attachment A of the 2009 System Assessment.
Transmission Modeling AssumptionsAs required by the NERC Reliability Standards and PEFA, it was necessary to model firm transmission service commitments when developing the Transmission Expansion Plan. PEFA requires that plans need to be developed to address any projected inability of the PEFA planning parties’ systems to serve the existing long-term firm transmission service commitments during the planning horizon, consistent with the planning criteria.
The NERC Reliability Standards do not allow any loss of firm load or curtailed firm transfers for Level B contingencies (single elements) and allow only planned and controlled loss of demand or curtailment of firm transfers for Level C contingencies (multiple elements).
The ColumbiaGrid planning process assumes that all ColumbiaGrid members’ transmission service and native load customer obligations represented in WECC and ColumbiaGrid basecases are firm, unless specifically identified otherwise (such as interruptible loads).
The firm transmission service commitments between the Northwest and areas outside the Northwest are scheduled on specific transmission paths (e.g., British Columbia-Northwest, Montana-Northwest, Idaho-Northwest, California-Oregon Interties, and Pacific DC Intertie). These external paths were modeled at loading levels at least as high as their known firm transmission service commitments.
Of the external paths, the British Columbia-Northwest and the two California Interties are most crucial during peak load conditions. These paths are bi-directional and there are often different stresses during winter and summer conditions. The Montana-Northwest and Idaho-Northwest paths are stressed more during off-peak load conditions and are less important during peak load conditions. The adequacy of these latter paths is verified annually through operational studies.
Conversely, the transmission paths internal to the Northwest are not scheduled. The flows on internal paths are a result of flows on the external paths, internal resource dispatch, internal load level, and the transmission facilities that are in service.
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The path flows modeled in the System Assessment are shown in Table 2. These path flows were within their limits, with a few exceptions. The West of Cascades South path exceeded its posted OTC by over 400 MW during the extreme winter condition in the five-year case and in nearly 1,500 MW in the ten-year case. The West of Cascades North path was near its posted OTC during this same ten-year extreme winter condition. The South of Allston path was near its limit in the five-year summer case. The Castle Rock - Troutdale project included in the ten-year cases will increase the capacity of this cutplane substantially. The assessment provided an indication of upgrades that might be needed on these paths to accommodate these flow levels. The West of Hatwai and West of McNary flows are quite low in these cases but that is expected, as these paths typically experience stress during off-peak conditions.
The background for the specific existing firm transmission service commitments on members’ paths that were modeled in the Transmission Expansion Plan is as follows:
1. Canada to Northwest PathThe capacity of this path in the north-to-south
Table 2: Basecase Summary - Path Flows in MW
Basecase
5 year normal winter
5 year extreme winter
5 year summer
10 year normal winter
10 year extreme winter
10 year summer
Total Northwest Load 33,023 36,804 26,490 35,004 39,017 28,898Total Northwest Generation 33,337 33,279 32,777 32,938 33,407 35,332British Columbia - Northwest Pathflow -1,805 -1,802 2,589 -1,801 -1,800 2,601Montana - Northwest Pathflow 1,327 1,402 1,007 1,260 1,344 829Idaho - Northwest Pathflow 702 847 -851 921 1,048 -499PDCI Pathflow -294 -2,248 3,101 -882 -2,973 3,099COI Pathflow -449 -2366 4608 -2,090 -3,655 4,618North of John Day Pathflow 1,316 -306 7,469 661 -940 8,487West of Hatwai Pathflow 548 299 377 396 293 446South of Allston Pathflow 1,237 739 3,157 1,047 481 4,031West of Cascades North Pathflow 8,579 9,546 3,591 9,009 9,964 4,054West of Cascades South Pathflow 6,149 7,444 3,836 6,909 8,478 4,210
direction is 2,850 MW on the west side and 400 MW on the east side for a total transfer capability of 3,150 MW. The total capacity of the path in the south-to-north direction is 2,000 MW, with a limit of 400 MW on the east side. Both of these directional flows can impact the ability of the system to serve loads in the Puget Sound area.
South to North The Canadian Entitlement return is the predominant south-to-north commitment on this path and is critical during winter conditions. Although the total amount of commitment varies somewhat, 1,350 MW of firm transmission service commitments is projected for the 2020 studies. Puget Sound Energy also has a 200 MW share at full transfer capability into British Columbia, which translates to a 130 MW allocation at the 1,350 MW level. Bonneville has committed to maintaining this pro-rata share of the Intertie above its firm transmission service commitments. Both of these firm transmission service commitments are on the west side of the path. To model them in the winter case, the British Columbia-Northwest path was scheduled at 1,800 MW into Canada on the west side. No flow was modeled on the
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2. Montana to Northwest PathThis path is rated at 2,200 MW east-to-west and 1,350 MW west to east. The predominant flow direction is east-to-west. The path can only reach its east–to-west rating during light load conditions. Imports into Montana usually only occur when the Colstrip Power Plant facilities are out of service.
The firm commitments on this path exceed 1,400 MW east to west. There are also some counter-schedules that reduce the actual flows on the system. For the five-year studies, flow was modeled as 1,327 MW in normal winter, 1,402 MW in extra-heavy winter, and 1,007 MW in summer. Flows are similar but slightly lower in the ten-year case.
3. Northwest to California/Nevada PathThe combined COI and Pacific DC Intertie are rated at 7,900 MW in the north-to-south direction, although there are some limitations to operation due to the North of John Day nomogram. The COI is individually rated at 4,800 MW and the Pacific DC Intertie is rated at 3,100 MW. The 300 MW Alturas tie from Southern Oregon into Nevada utilizes a portion of the 4,800 MW COI capacity. In the south-to-north direction, the COI is rated at 3,675 MW and the Pacific DC Intertie is rated at 3,100 MW.
Table 2: Basecase Summary - Path Flows in MW
east side portion of the British Columbia-Northwest path.
North to SouthWith reduced loads in the Puget Sound area in the summer, the return of the Canadian Entitlement is not typically a problem. The most significant stressed condition in the summer is north-to-south flows of Canadian resources to meet loads south of the border when the thermal capacity of the electrical facilities in the area is reduced.
Powerex has long-term firm rights for about 242 MW for their Skagit contract, plus 193 MW to Big Eddy and 450 MW to John Day, for a total of 885 MW in the north–to-south direction. Powerex also owns the reassignment for the Cherry Point rights (200 MW) which is just south of the Canadian border and can be reassigned to the border. Puget Sound Energy has long-term firm contracts for 150 MW, and Snohomish County PUD has firm contracts for 100 MW. In addition to this 1,335 MW of long-term firm commitments, significant amounts of short-term firm transmission service are typically purchased for additional transfers. These short-term firm transmission service commitments last only 11 months; however, they can be repurchased depending upon availability. This study assumes that this level of transmission service commitments will continue in the foreseeable future.
To cover all firm transmission service commitments, both long and short-term, the British Columbia-Northwest path was scheduled to 2,600 MW in the summer all on the west side. The 2008 System Assessment placed 300 MW of this transfer on the eastside of the path but no system problems were noted for that condition. For the 2009 System Assessment, the entire loading was modeled on the west side path which is equally plausible.
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Bonneville is planning upgrades to these paths to increase the potential to use these paths at their full capability. After these upgrades, the long-term firm transmission service commitments on these paths are expected to total about 7,700 MW, which is what was modeled in the summer case used in the System Assessment.
There are some firm transmission service commitments on this path in the south–to-north direction but not a significant amount.
Non-firm sales are relied on by many parties in the winter, especially during very cold weather, when there are insufficient resources within the Northwest to meet the load level. For the basecases, Northwest resources were dispatched first, and firm transmission service commitments were modeled on all other external paths. Then additional resources needed to meet the remaining load obligations in the Northwest were imported from the south on the COI and Pacific DC Intertie.
In the five-year heavy winter Basecase, the combination path was loaded to 743 MW into the Northwest with 449 MW on the COI and 294 MW on the Pacific DC Intertie. For the extra-heavy five-year winter Basecase, the total path was loaded to 4614 MW with 2,366 MW on the COI and 2248 MW on the PDCI. In the ten-year normal winter case, the combined imports were 2,972 MW and increased to 6,630 MW for the extra heavy 10 year case. The five-year summer case has a total of 7,709 MW on the combined path while the ten- year summer case flows are 7,717 MW.
4. Idaho to Northwest PathThe Idaho to Northwest path is rated at 2,400 MW east-to-west and 1,200 MW west-to-east. This path has about 300 MW of firm
schedules into Idaho to meet firm transfer loads, in addition to a 100 MW point-to-point service contract. Summer conditions with flows at these levels are typical as there are few surplus resources to export from the east. In the winter, these transfer loads are reduced, and PacifiCorp typically exports its east side resources into the Northwest to meet its west side load obligations. Due to the nature of the flows from Idaho, they are not expected to cause significant system problems during peak load periods.
The new Hemingway-Boardman line was added in all cases and assumed to be part of the Idaho to Northwest path. For the five-year winter cases, 702 MW is modeled flowing into the Northwest. In the extra-heavy winter case, 847 MW is modeled. In summer, 851 MW was modeled flowing into Idaho. Flows in the ten-year cases were 921 MW and 1048 MW into the Northwest in the winter cases and 499 MW into Idaho in the summer.
5. West of Hatwai PathThe West of Hatwai path is rated at 4,277 MW in the east-to-west direction but it is not a scheduled path. This path is stressed most during light-load conditions when eastern loads are down and the excess resources from the east flow into Washington. This path is not expected to cause problems during peak load conditions. This path is loaded to 377 MW in the summer, 548 MW in winter, and 299 MW in extra-heavy winter. In the ten-year cases, the respective flows on the West of Hatwai path are 446 MW, 396 MW and 293 MW. 6. West of Cascades North and South PathsThe West of Cascades North path is rated at 10,200 MW and the West of Cascades South path is rated at 7,000 MW, both in the east-to-west direction (the impacts of the new
45Big Eddy-Knight 500 kV line was included in the south path although its rating was not increased). These paths are not scheduled paths but transfer east side resources to the west side loads. These paths are most stressed during winter load conditions, especially when west side generation is low. The north path was loaded to 3,591 MW in the five-year summer basecase, 8,579 MW in the winter basecase, and 9,546 MW in the extra-heavy winter basecase. These loadings increase to 4,054MW, 9010 MW 9964 MW, respectively, in the ten-year cases. The south path in the five-year cases was loaded to 3,836 MW in the summer basecase, 6,149 MW in the winter basecase, and 7,444 MW in the extra-heavy winter basecase. These
loadings increase to 4,210 MW, 6,909 MW and 8,478 MW, respectively, in the ten-year cases.
The flows modeled for winter and summer peak conditions in the five and ten-year cases are shown in Figures 7, 8, 9 and 10. The red circles in the figures represent the load levels in the identified areas; the load level is proportional to the area of the circle. The Seattle-Tacoma area includes the area west of the cascades from the Canadian border south through Tacoma. The Longview/Centralia bubble includes the areas south of Tacoma through Longview and west to include the Olympic Peninsula. The Portland/Eugene area includes the Willamette Valley and Vancouver, Washington area. The two major
Figure 7: Five-Year Winter Basecase Conditions
Five-Year Winter Basecase Conditions
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west side load areas, Seattle/Tacoma and Portland/Eugene, each have approximately 10,000 MW of load in winter. The Southern/Central Oregon bubble includes the Roseburg area down to the California border and east to the Bend-Redmond area. The Middle Columbia Area includes load in the Washington area east of the Cascades, west of Spokane, south of the Canadian border and north of the Columbia River. The Lower Columbia bubble includes loads to the south of Middle Columbia to Central Oregon. The Spokane area includes loads to the east in Western Montana, north to the Canadian border and south to the Oregon border. The Lower Snake bubble includes the major generation in the area.
The area of the green circles represents the amount of generation in that area. The Seattle/Tacoma and Portland/Eugene load areas have more load than generation and rely on other areas to supply the load resource balance. The Middle Columbia, Lower Columbia and Lower Snake areas have surplus generation that is used in other areas. The Middle Columbia area has about 11-12,000 MW of generation represented in the cases. The load/resource ratios in the Spokane, Central/Southern Oregon and Longview/Centralia areas have greater balance.
The dark blue lines between the areas represent the major paths that connect
Figure 8: Five-Year Summer Basecase Conditions
Five-Year Summer Basecase Conditions
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the areas. The width of the dark blue lines represents the relative capacity of the paths. For example, the West of Cascades North path is rated at 10,200 MW. The light blue lines within these paths represent the capacity that is used in the studies. In the winter cases, the West of Cascades paths are heavily used to meet the load levels in the west side areas while the North of John Day and West of Hatwai paths are lightly loaded. The external paths to Canada, Montana and Idaho are loaded to the firm obligations on each path as discussed earlier. The downstream benefit return loads the Canada to Northwest paths to nearly their limits. Power is imported from California to provide overall load resource balance in the northwest.
The load levels are typically lower in summer than in winter, especially in the west side areas, and are shown here with proportionally smaller bubbles. Central/Southern Oregon is an exception as its summer load level exceeds the winter. Also note that the Portland/Eugene area load level is greater than Seattle/Tacoma in the summer. The two areas had similar load levels in the winter case. This difference is due to a greater use of air conditioning. The Middle Columbia and Lower Columbia areas have higher levels of generation in the summer as compared to the winter.
The path usage levels change significantly between summer and winter. In the summer, Canadian hydro generation exceeds the
Figure 9: Ten-Year Winter Basecase Conditions
Ten-Year Winter Basecase Conditions
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internal loads and excess generation is exported to the northwest and California. The northwest load levels are also lower in summer and there are available resources to export to the south. All of the north-to-south paths load much heavier in the summer due to these flows. The loading on the west of Cascades paths is reduced in summer due to the reduced load level in the west side. The ties to Idaho are mostly floating with little power moving on that path.
Special Protection System AssumptionsAt the transfer levels modeled in the basecases, existing Special Protection Systems are relied on for reliable operation of the transmission system. Some of these
Special Protection Systems will effectuate tripping or ramping of generation (some of which have firm transmission rights) for specified single and double line outages. This Special Protection System generation dropping relies on the use of operating reserves to meet firm transfer requirements (no schedule adjustments are made until the next scheduling period and no firm transfers are curtailed). If the outages are permanent, firm transfers might then need to be curtailed during the next scheduling period to meet the new operating conditions. Firm transmission service commitments are met with this use of Special Protection Systems consistent with NERC and WECC standards.
Figure 10: Ten-Year Summer Basecase Conditions
Ten-Year Summer Basecase Conditions
49Transmission Additions ModeledBetween the 2008 and 2009 System Assessments, the projects shown in Table 3 have been placed in service. All of these transmission additions were modeled in the basecases used in the 2009 System Assessment.
Since adding conceptual projects to the assessment could mask future system problems, potential projects were not included in the basecases. The only future projects that were included in the assessment were those where the sponsoring companies had made a firm commitment to build the project within the next five years. These are typically projects that are under construction or that at least have budget approval. By
including only projects that utilities are actively pursuing, the next level of needs can easily be identified and prioritized for resolution.
Table 4 (on the following page) lists the future projects that were included in the System Assessment. These projects are more fully described in Attachment A entitled Transmission Expansion Projects.
The North Downtown Seattle Project was not included in the basecases. Although this need was demonstrated in the 2008 System Assessment, projections of load growth in the north downtown area have decreased considerably. For that reason, the 2009 System Assessment was performed with the
Projects Recently Energized SponsorOlympic Peninsula Reinforcement (Satsop-Shelton 230 kV line) Bonneville Power AdministrationLibby - Troy 115 kV line rebuild Bonneville Power AdministrationRogue SVC (South Oregon Coast) Bonneville Power AdministrationLarson-Stratford 115 kV line GrantWine Country 230/115 kV substation (Yakima area) PacifiCorpNorth Seattle 115 kV transmission line upgrade Seattle City LightBoundary 230/115 kV transformer replacement Seattle City Light/BPANovelty 230/115 transformer fed from the existing Monroe-Sammamish 230 kV line in the north Seattle area PSE
Covington - Berrydale 230 kV line in the south Puget Sound area PSE
Rocky Reach - Andrew York 230 kV line and Andrew York 230/115 kV substation north of Wenatchee Chelan
Columbia - Quincy 115 kV line reconductoring in central Washington Grant
Benewah - Shawnee 230 kV line in eastern Washington AvistaDry Creek - North Lewiston 230 kV line reconductoring in central Washington Avista
Carver - McLoughlin 230 kV line in the southest Portland area PGETambark Junction - Clearview 115 kV line in the north Puget Sound area Snohomish
Rocky Ford 230/115 transformer in the middle Columbia area GrantSherwood - Murrayhill 230 kV line in the southwest Portland area PGESedro - Bellingham #3 115 kV Reconductor PSE
Table 3: Projects Recently Energized
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Project Name Sponsor DateOlympic Peninsula Reinforcement (Satsop-Shelton 230 kV line) Bonneville Power 2009
Libby - Troy 115 kV line rebuild Bonneville Power 2009Rogue SVC (South Oregon Coast) Bonneville Power 2009Mid Columbia Area Reinforcement (Vantage - Midway 230 kV line upgrade) Bonneville Power 2011Second 230/115 kV transformer at Redmond Bonneville Power 2011Sandpiper Substation connecting into the existing Ashe - Marion 500 kV line and the new McNary - John Day 500 kV line
Bonneville Power 2012
Bakeoven Series Capacitors plus other shunt caps and line upgrades (COI Upgrade)
Bonneville Power 2012
John Day - McNary 500 kV Line Bonneville Power 2013Big Eddy - Knight (formerly Station Z) 500 kV line looping into the new Knight Substation on the existing Wautoma - Ostrander 500 kV line
Bonneville Power 2013
Central Ferry - Lower Monumental 500 kV line and connection to existing Lower Granite - Lower Monumental 500 kV lines at the new Central Ferry Substation
Bonneville Power 2013
Castle Rock - Troutdale 500 kV line (I-5 Corridor Reinforcement Project) connected to the Paul-Allston line at the new Castle Rock Substation
Bonneville Power 2015
Lower Valley Reinforcement (SE Idaho) Bonneville Power/others
2010
Retermination of lines into Andrew York Substation Chelan 2010Relocation/upgrade of the McKenzie - Wenatchee Tap 115 kV line Chelan 2012New Rapids - South Nile 115 kV line Douglas 2010Columbia - Palisades 115 kV line Douglas 2011Douglas - Rapids 230 kV line and Rapids 230/115 kV substation Douglas 2012Columbia - Larson 230 kV line Grant 2012Hemingway - Boardman 500 kV line Idaho Power 2013 Wine Country 230/115 kV substation (formerly Vintage Valley) PacifiCorp 2009Vantage - Pomona Heights 230 kV line (Yakima area) PacifiCorp 2012New Lookingglass Substation on the Reston - Dixonville 230 kV line (Albany area)
PacifiCorp <2013
Parish Gap 230/115 kV substation connecting to Bethel - Fry 230 kV line (Albany area)
PacifiCorp <2013
Keeler - Sunset 230 kV line with 230/115 kV transformers at Sunset Portland General Electric
<2013
Springville Substation connecting to Trojan - St. Marys 230 kV line (west Portland)
Portland General Electric
<2013
South of Sedro Capacity Increase (Sedro - Horse Ranch 230 kV line) Puget Sound Energy 2011230/115 kV transformer at Alderton Substation in south Puget Sound area Puget Sound Energy 2011Thurston County Transformer Capacity (St. Claire Substation ) Puget Sound Energy 2012Lake Tradition 230/115 kV transformer fed via Maple Valley - Sammamish 230 kV line
Puget Sound Energy 2012
North Cross Cascades Improvement (115 kV IP line upgraded to 230 kV) Puget Sound Energy 2015North Seattle 115 kV transmission line upgrade Seattle City Light 2009
Boundary 230/115 kV transformer replacement Seattle City Light/BPA 2009Beverly Park 230-115kV transformer Snohomish PUD 2012Cowlitz 230 kV transformer replacement Tacoma Power 2010Canyon Substation (Tacoma area) Tacoma Power 2012Rapids - Columbia 230 kV line undetermined <2013Cowlitz PUD conversion from 69 kV to 115 kV (Longview - Cowlitz #2, Longview - Lexington #2, Longview - Lexington - Cardwell)
Cowlitz 2011-2014
Table 4: Firm Transmission Projects included in the System Assessment Basecases
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new load forecasts and without the North Downtown Seattle project to review the need for, and timing of, this project.
Several of the larger projects that were included in the basecases are discussed below:
Major Additions in the Five-Year CaseWest of McNary Area Reinforcement Project: This Bonneville project includes two new lines; a McNary-John Day 500 kV line and a Big Eddy-Knight 500 kV line. The project in its entirety includes about 110 miles of new line construction and is proposed to increase the capacity of the West of McNary, West of Slatt, West of John Day and West of Cascades South transmission paths. This would provide additional transmission capability to accommodate transmission service requests in eastern Oregon that are being addressed in the Bonneville Network Open Season process. The McNary-John Day line is expected to be completed in 2012 and the Big Eddy-Knight project in 2013.
Sandpiper 500/230 kV Project: This Bonneville project would create a new 500/230 kV Substation connected into the existing Ashe-Marion and the new McNary-John Day 500 kV lines. The 230 kV side would essentially provide a collector system for generation projects (primarily wind generation). This project is expected to be completed in 2012.
Central Ferry - Lower Monumental 500 kV line: This Bonneville project has been proposed to integrate wind generation projects into the system. The new Central Ferry Substation is located between Little Goose and Lower Monumental Dams and includes a new forty-mile 500 kV line from Central Ferry to Lower Monumental.
Mid Columbia Area Reinforcements: The transmission plan for the Mid Columbia area that was developed in the Northwest Power Pool study was included in the assessment. This includes reconductoring the Bonneville Vantage/Wanapum - Midway 230 kV line and constructing a new Vantage-Pomona 230 kV line (PacifiCorp). The preliminary plan for the Northern Middle Columbia area that has been developed over the last year in the ColumbiaGrid Study Team was also included. It includes a Grant County PUD Columbia-Larson line; the Douglas County PUD Douglas-Rapids 230 kV line, Rapids Substation and 230/115 kV transformer; the Rapids-Columbia 230 kV line (the sponsor of this project has not been determined at this time); a bus sectionalizing breaker at Bonneville’s Columbia Substation; upgrades to the Chelan County PUD’s McKenzie-Wenatchee Tap line and line re-terminations at Chelan County PUD’s Andrew York Substation.
Hemmingway - Boardman 500 kV Project: This Idaho Power project includes a 300 mile 500 kV line from the Boise Idaho area to Boardman Substation. This project is intended to provide 1,300 MW of capacity in the west to east directions and 1,400 MW in the east-to-west direction. The proposed in-service date has recently been delayed until 2015 to accommodate the siting process.
Major Additions in the Ten-year CasesIn addition to the projects included in the five-year cases, the following project was included in the ten-year cases. This project was added because of Bonneville’s commitment through its Network Open Season and expected construction schedule.
I-5 Corridor Reinforcement Project: This Bonneville project consists of a 70-mile 500 kV line from a new Castle Rock Substation
Table 4: Firm Transmission Projects included in the System Assessment Basecases
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north of Longview to Troutdale Substation east of Portland. The project is scheduled to be energized in 2015 and is planned to remove the most limiting bottleneck along the I-5 corridor.
All transmission facility ratings included in this study were determined by the owner of the facility.
Study MethodologyThe basecase system was analyzed without outages (N-0 conditions) and tuned to be within required facility loading and voltage limits. Any violations that could not be resolved through this tuning were noted.
Participants in the studies provided ColumbiaGrid with information on the contingencies that they wanted addressed. These included common mode outages, which are plausible outages of multiple facilities caused by a single event, also called NERC Category C events. Included in the studies were inadvertent breaker openings, which are especially important on multi-terminal lines. All single element (N-1 or NERC Category B) outages down to 115 kV were studied on eachbasecase along with the common mode outages. Also included, were the automatic and manual actions associated with each contingency.
All outages that resulted in loadings or voltages outside of criteria were listed in spreadsheets and individually reviewed. Some of the more severe outages did not converge during the initial AC power flow simulations. Unsolved solutions are an indicator that the voltage stability limit may be exceeded. Alternative approaches such as making the loads voltage sensitive (the effective load drops with a drop in voltage placing less strain on the transmission system) were used to obtain solutions.
The abnormal winter load cases were studied as risk assessments. Basecases were developed and checked to ensure that all facilities were within normal limits. The same outages were studied and overloads and undervoltages were noted. However, since these studies are beyond the requirements of the NERC Reliability Standards, mitigation of violations for outages is not mandatory.
Participants were not only asked to review outages of their facilities that caused problems, but also to review any violation of limits on their facilities that were caused by any owner’s outage. ColumbiaGrid staff also reviewed the results and participants were allowed to provide a peer review of the results.
Although the focus of this assessment is facilities of the PEFA planning parties, the interconnected nature of the system requires that neighboring facilities also be factored in to determine if there are any interactions between the systems. As mentioned earlier, ColumbiaGrid invited the owners of systems neighboring PEFA parties to participate in the system assessment.
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Study ResultsFacility Loading Performance
Thermal overloads were discussed with the owners of the affected facilities and, where available,
potential transmission owner projects were added to correct system deficiencies. These projects are listed in Table 5. The remaining overloading conditions were each reviewed by the planning participants. If an area of concern did not involve multiple utilities, it was considered to be a single-system issue and remained the responsibility of the individual owner. The only obligation in this instance is for the owner to report back to the ColumbiaGrid process on the measures they have planned to mitigate the single-system issue. ColumbiaGrid will then use these mitigation plans to update its future basecases.
Areas of concern affecting multiple systems are the primary focus of ColumbiaGrid’s planning efforts. These areas of concern resulted when multiple planning parties had outages that caused overloads and/or had
facilities that overloaded as a result of such outages. ColumbiaGrid organizes study teams to resolve these system deficiencies between ColumbiaGrid members. The following areas were identified in the system assessment that involve more than one system and will require further study in study teams to determine the extent of the system problems and develop mitigation.
1. Olympic Peninsula: Three major problem areas in the Olympic Peninsula will require further study. These include:
•Voltage instability in the Fairmont and Port Angeles area may occur for loss of either the Shelton-Fairmount 230-kV #1 or #2 line.
•The loss of the Olympia-Shelton 230 kV #3 and #4 lines (on double circuit towers) may cause voltage instability and overload the Olympia-Shelton 230 kV line #5.
Table 5: Potential Transmission Owner Identified Mitigation Projects
Project NamePotential Mitigation
Proposed by:Port Angeles 230 kV bus development Bonneville Power20 Mvar, 230 kV shunt capacitor addition at Happy Valley Bonneville PowerTrip industrial loads at Port Angeles and Fairmount for critical outages
Bonneville Power
Remove jumpers on the Raver - Tacoma 500 kV double circuit line to de-energize the middle circuit between the other Raver - Tacoma line and the Raver - Covington line.
Bonneville Power
Blue Lake - Gresham 230 kV line project Portland General ElectricInstall Individual breakers on all four Pearl - Sherwood 230 kV lines Portland General/BonnevilleUpgrade the Agate - Port Madison - Lomo Tap 115 kV line Puget Sound EnergyUpgrade the Glade - Luhr Beach - Hawks Pr - St. Clair 115 kV line to 75 degrees Celcius
Puget Sound Energy
Upgrade the Monroe Tap - Horse Ranch Tap 230 kV lines as part of South of Sedro Capacity Increase Project
Puget Sound Energy
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•Voltage instability may occur for the common mode outage of the Paul-Satsop and Paul-Olympia 500 kV lines and overload the Olympia-Chehalis 230 kV line. Voltage instability may occur for the outage of the Paul-Olympia 500 kV line and for breaker failure outages at Paul that trip the Olympia-Paul and Paul-Tono lines and overloads the Olympia-Satsop 230 kV line. Also, the Cosmopolis-Aberdeen 115kV line is overloaded with no contingency during abnormal cold weather conditions.
2. Puget Sound Area 500/230 kV Transformer: The BPA Tacoma transformer overloads for the N-2 outage of both Raver-
Covington 500 kV lines (adjacent circuits).
3. The West of Cascades Paths: The system assessment studies indicate that these paths are projected to be very heavily utilized within the planning horizon and may need to be reinforced. N-2 outages of Cross Cascades lines could result in voltage instability during winter peak load conditions especially if wind generation is operating (see later section on wind generation sensitivities).
The Olympic Peninsula issues led to the formation of the Olympic Peninsula Study Team. The Puget Sound area 500/230 kV transformer) are being addressed by the existing Puget Sound Area Study Team. The West of Cascades Paths, will be addressed by the newly formed Cross Cascades Study Team.
In addition to the overloads listed above, there are a number of potential 115 kV line sections that may become overloaded during various outage conditions where mitigation was not identified. It was assumed that these line sections could be rerated, reconductored, or rebuilt as mitigation and these types of projects are considered “placeholder” projects until more thorough reviews can be completed by the affected parties and specific transmission projects can be identified.
System Voltage PerformanceVoltage problems were addressed similarly to overloading issues except that the interim corrective action was assumed to be capacitor additions rather than rerating, reconductoring, or rebuilding lines. In identifying the need for capacitor additions, the standard WECC criteria of no more than a 5% voltage drop following a credible Category B (single) contingency or 10% voltage drop following a credible Category
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C (multiple) contingency was used. In many areas of the system a less stringent criteria is applied so this approach results in more capacitor additions than will probably be necessary to meet specific system criteria.
The reactive additions necessary to mitigate voltage problems at the 230 kV and 500 kV voltage levels for the ten-year planning horizon total 630 MVARs of shunt capacitance in 12 different locations. All of the capacitors would be located at the 230 kV voltage level. These additions are listed in Table 6. These results will be used as the basis for further transmission owner or study team technical studies. Only voltage violations on facilities 230 kV and above were addressed with capacitor additions since these systems usually impact multiple transmission systems. Correcting voltage issues on lower voltage transmission facilities was left to the individual transmission owners, as there is ample time to identify and implement these additions.
Wind Generation Sensitivity StudiesBased on historical operation, where there has been little wind generation during peak load
periods, a decision was made to not model any wind generation in the system assessment basecases. Since the system assessment has been completed, ColumbiaGrid has conducted sensitivity studies of several levels of wind generation to cover the possibility of significant wind output during peak conditions for both winter and summer. This study also included likely redispatch of other generation in response to available wind generation.
With high levels of wind generation, there are two major types of generation re-dispatch that are expected to maintain load/resource balance; hydro generation and local gas-fired generation. Of these two types, changes in hydro generation will likely be located in similar geographic locations as the wind. The gas generation however would more likely be in the load areas, far from the wind generation. While it is expected that the hydro re-dispatch would have little impact to the system, redispatch with local gas-fired generation would be expected to have a major impact. The critical aspect for the bulk system during this type of operation is
Name of Substation Max Mvar OwnerHat Rock 80 PacifiCorp - WestPonderosa 90 PacifiCorp - WestDixonville 60 PacifiCorp - WestTroutdale 110 PacifiCorp - WestChiloquin 30 PacifiCorp - WestTRS 20 Energy NorthwestLaGrande 30 Bonneville Power AdministrationHorse Heaven 30 Bonneville Power AdministrationSantiam 90 Bonneville Power AdministrationMartin Creek 20 Bonneville Power AdministrationEast Omak 50 Bonneville Power AdministrationClatsop 20 Bonneville Power Administration
Total 630
Table 6: Potential Reactive Mitigation Projects
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expected to be the West of Cascades North and South paths which transfer the remote resources to the west side load areas.
The ten-year WECC cases model about 6,500 MW of wind generation in the Northwest area but all of this wind was modeled as out of service in the initial study results. To test the affect of wind generation on the performance of the system, the level of wind generation was increased while monitoring system limits. All of the wind generation was increased proportionally based on generator nameplate capacity. West side gas generation was turned off unit by unit in sequence determined by heat rate data from the TEPPC study process (higher cost units were the first to be shut down). There was only 4,500 MW of displaceable west side gas generation so to test the full 6,500 MW of wind generation, the remaining 2,000 MW of generation displacement was modeled in Canada (summer case only).
Winter ResultsSome local transmission limitations in the Crescent City load area, Southern Oregon coast load area, and the Olympic Peninsula load area were mitigated by adding local area voltage support so that the study could determine the main grid system limits. The most limiting contingency in the Puget Sound area was found to be the loss of the Schultz-Raver and Schultz-Echo Lake 500 kV lines. With this outage, the main grid system limit was calculated at about 1,100 MW (i.e., 2000 MW of wind generation was added and 2000 MW of west side gas generation was shut down) before the system had insufficient voltage support to operate properly. Only static VAR compensators and generator voltage control were allowed to operate after the contingency. The weak points on the system were found to be in the vicinity of Snoking and Maple Valley Substations which supply a large percentage of the power in the Puget Sound area. One interesting result is the critical voltage in these studies, the point just before voltage collapse, is in the normal operating range which means that the mitigation may need to be more extensive than large shunt capacitor banks (e.g. series capacitors, continuous shunt reactive, or new lines).
The most severe contingency for the Portland area is the Mercer Ranch - Marion/Buckley - Marion outage which is a portion of the double circuit line that extends from the Hanford area to Salem, Oregon. This limit occurs at about the 2,300 MW generation shift level. The critical voltage for this outage is below the operating range, which will allow a larger range of mitigation measures such as large capacitors banks in the load area instead of expensive transmission lines across the mountains.
57
Summer ResultsThis same analysis was run for summer conditions and was run successfully at the full 6500 MW wind generation level. No main grid voltage stability limits were exceeded. This was expected since the cross cascades transmission is loaded more lightly during summer conditions.
58
Olympic Peninsula Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other Notes
Changes from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Olympic Peninsula Reinforcement
Construct 14 miles of new double circuit 230 kV line from Olympia to Shelton. Loop-in the Olympia-Kitsap 230 kV line into Shelton. Remove the Olympia-Shelton No.1 115 kV line. The project also includes miscellaneous substation work at Shelton and Olympia.
BPA PSE Completed $26-million
Load growth and correct bus sectionalizing breaker issue
Project completed Existing Obligation Project
Olympia 230/115 kV Transformer Bank No.3
Add a new 230/115 kV Transformer at Olympia substation
BPA Conceptual Project for future need
2017 $7 million
Load Growth Project schedule changed from 2016 to 2017
Single System Project with possible impacts
Shelton-Fairmount-Port Angeles Area
Shelton-Fairmount 230 kV line No. 4 & 5 Construct a new double circuit 230 kV line (approximately 60 miles) between Shelton and Fairmount Substations
BPA Conceptual Project for future need
2022 $21.5 million
Load Growth Plan of service changed to double circuit and project schedule changed from 2016 to 2022
Single System Project
Olympic Peninsula Study Team
Olympic Peninsula Projects
59
Olympic Peninsula Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other Notes
Changes from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Olympic Peninsula Reinforcement
Construct 14 miles of new double circuit 230 kV line from Olympia to Shelton. Loop-in the Olympia-Kitsap 230 kV line into Shelton. Remove the Olympia-Shelton No.1 115 kV line. The project also includes miscellaneous substation work at Shelton and Olympia.
BPA PSE Completed $26-million
Load growth and correct bus sectionalizing breaker issue
Project completed Existing Obligation Project
Olympia 230/115 kV Transformer Bank No.3
Add a new 230/115 kV Transformer at Olympia substation
BPA Conceptual Project for future need
2017 $7 million
Load Growth Project schedule changed from 2016 to 2017
Single System Project with possible impacts
Shelton-Fairmount-Port Angeles Area
Shelton-Fairmount 230 kV line No. 4 & 5 Construct a new double circuit 230 kV line (approximately 60 miles) between Shelton and Fairmount Substations
BPA Conceptual Project for future need
2022 $21.5 million
Load Growth Plan of service changed to double circuit and project schedule changed from 2016 to 2022
Single System Project
Olympic Peninsula Study Team
60
Puget Sound ProjectsPuget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Cowlitz Substation 230 kV Line Re-termination Project.
This project involves the re-termination of Bonneville’s South Tacoma-Cowlitz (#1) 230-kV line from Tacoma Power's Cowlitz 230-kV Bus into TPWR’s Southwest (#4) line. It also includes the re-termination of TPWR’s Cowlitz-Southwest (#3) and Cowlitz-Tacoma (#2) 230-kV lines to create a new Southwest-Tacoma 230 kV line.
Tacoma Power
Bonneville Study completed by Bonneville in June 2008
2011-2012 $750K to $1M
Reliability improvement Single System Project, possible impacts
Puget Sound Area Study Team
Pierce County transformer capacity.
A new 230/115kV transformer at Alderton substation in central Pierce County with several options being considered for the 230kV source.
PSE Included in sponsor's budget
2011 Additional transformation capacity for Pierce and south King Counties to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Team
Thurston County transformer capacity.
A new 230/115kV transformer at Saint Clair or Spurgen Creek substations in Southern Thurston County with several options being considered for the 230kV source.
PSE Project identified as future need
2012 Additional transformation capacity for Thurston Counties to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Team
North Downtown Seattle Substation
Proposed to build a new 200 MVA substation in the north of downtown area to serve load growth. Install underground 230kV transmission lines from East Pine and Massachusetts Substations to New Substation and add 230kV/115kV autotransformer. Construct new 115kV transmission lines from Canal and Broad Street Substations to New Substation.
Seattle City Light
Conceptual Project for future need
Project identified as future need
2018 $40 to $200M
Load growth in North Seattle area has slowed since late 2008. SCL is reviewing load forecasts and transmission plans for the north downtown area.
Existing Obligation Project
Puget Sound Area Study Team
South of Sedro Capacity Increase
Rebuild a 115kV line to become a second 230kV line between Sedro Woolley and Horse Ranch Substations. Includes reconductoring sections of the Sedro Woolley-Horse Ranch-Bothell 230kV line, adding 2 breakers at Horse Ranch, and uprating the Horse Ranch-HR Tap of Monroe-Snohomish 230 kV line
PSE in parallel w/Bonneville & Snohomish PUD w/ impacts to the Westside Northern Intertie
Under Construction
2010 Increase capacity for native load and transmission service
Capacity Increase Project
Puget Sound Area Study Team
Southwest substation 230 kV Bus Reliability Improvement Project
Modify Bus section breaker arrangement at Southwest substation to eliminate single point of failure of bus section breaker.
Tacoma Power
2015-16 The purpose of this project is to improve system reliability by preventing any bus fault or a “stuck breaker” on one of the 230 kV buses from resulting in total loss of service to the substation.
Single System Project
Puget Sound Area Study Team
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Beverly Park 230-115 kV Capacity Addition
Expand the existing 115 kV switching station and add two 230-115 kV 300 MVA transformers. The 230 kV source will be from the BPA Snohomish Substation. An existing 115 kV line from BPA Snohomish to the Glenwood Tap will be converted to 230 kV. The 115 kV line serving the Glenwood Tap will then be configured to be served from the Beverly Park 115 kV bus.
Snohomish PUD No. 1
Additional Bonneville Snohomish 230kV bus positions are required
Project is in the design and construction Phase
2012 November
Load Growth and expected local reliability deficiency in Paine Field and Everett areas requires capacity increases to meet District level of service guidelines
Single System Project, possible impacts
Puget Sound Area Study Team
Canyon substation Canyon is a 230/110 kV substation to be located in the southern part of Tacoma Power’s service territory. Tacoma Power proposed to interconnect this new substation to Bonneville’s South Tacoma Substation. A single 230/110 kV step down transformer will be installed at this substation in the near term with provisions made for a future second transformer.
Tacoma Power
BPA Study completed by BPA in 2008
High 2011 The addition of this substation is intended to improve system reliability, operational flexibility, and at the same time, provide more system capacity to accommodate load growth in the area.
Single System Project, possible impacts
Puget Sound Area Study Team
IP line conversion to 230 kV
Convert PSE's 115kV "IP" line to 230kV between Kittitas substation and Lake Tradition substation in King County to increase cross-Cascade capacity and interconnect Kittitas County wind projects
PSE Puget Sound Utilities
Conceptual Project for future need
2013 to 2015 Load growth in Puget Sound and generation integration, related to North Cross Cascades Improvements
Single System Project, possible impacts
West of Cascades Study Team
North Cross Cascades Reinforcement
Alternatives include 500 kV series capacitors to the Schultz-Raver 500 kV lines No.3 & 4, and/or additional 500 kV shunt capacitors in the area, construction of a new 500 kV line across the Northern Cascades to serve loads in the Puget Sound area
BPA Puget Sound Utilities
2014-2016 Load growth in Puget Sound and Transmission Service Requests
Plan of service options updated
Existing Obligation Project
West of Cascades Study Team
Seattle Area 500/230 kV Transformer Bank
Add a new 500/230 kV transformer bank in the Seattle vicinity to serve loads in the Puget Sound area.
BPA PSE, Tacoma 2019 Load growth in Puget Sound area Project schedule changed from 2016 to 2019
Existing Obligation Project
Puget Sound Area Study Team
North King County Capacity Increase
A 230kV line between Sammamish Substation in North King County to Talbot substation in central King County. The project would involve rebuilding an existing 115kV line to 230kV.
PSE In parallel w/ Bonneville & SCL w/impacts to the Westside Northern Intertie
Conceptual Project for future need
2015 to 2017 Increased capacity across the Monroe-Echo Lake cutplane for native load and transmission service.
Existing Obligation Project
Puget Sound Area Study Team
61
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Cowlitz Substation 230 kV Line Re-termination Project.
This project involves the re-termination of Bonneville’s South Tacoma-Cowlitz (#1) 230-kV line from Tacoma Power's Cowlitz 230-kV Bus into TPWR’s Southwest (#4) line. It also includes the re-termination of TPWR’s Cowlitz-Southwest (#3) and Cowlitz-Tacoma (#2) 230-kV lines to create a new Southwest-Tacoma 230 kV line.
Tacoma Power
Bonneville Study completed by Bonneville in June 2008
2011-2012 $750K to $1M
Reliability improvement Single System Project, possible impacts
Puget Sound Area Study Team
Pierce County transformer capacity.
A new 230/115kV transformer at Alderton substation in central Pierce County with several options being considered for the 230kV source.
PSE Included in sponsor's budget
2011 Additional transformation capacity for Pierce and south King Counties to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Team
Thurston County transformer capacity.
A new 230/115kV transformer at Saint Clair or Spurgen Creek substations in Southern Thurston County with several options being considered for the 230kV source.
PSE Project identified as future need
2012 Additional transformation capacity for Thurston Counties to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Team
North Downtown Seattle Substation
Proposed to build a new 200 MVA substation in the north of downtown area to serve load growth. Install underground 230kV transmission lines from East Pine and Massachusetts Substations to New Substation and add 230kV/115kV autotransformer. Construct new 115kV transmission lines from Canal and Broad Street Substations to New Substation.
Seattle City Light
Conceptual Project for future need
Project identified as future need
2018 $40 to $200M
Load growth in North Seattle area has slowed since late 2008. SCL is reviewing load forecasts and transmission plans for the north downtown area.
Existing Obligation Project
Puget Sound Area Study Team
South of Sedro Capacity Increase
Rebuild a 115kV line to become a second 230kV line between Sedro Woolley and Horse Ranch Substations. Includes reconductoring sections of the Sedro Woolley-Horse Ranch-Bothell 230kV line, adding 2 breakers at Horse Ranch, and uprating the Horse Ranch-HR Tap of Monroe-Snohomish 230 kV line
PSE in parallel w/Bonneville & Snohomish PUD w/ impacts to the Westside Northern Intertie
Under Construction
2010 Increase capacity for native load and transmission service
Capacity Increase Project
Puget Sound Area Study Team
Southwest substation 230 kV Bus Reliability Improvement Project
Modify Bus section breaker arrangement at Southwest substation to eliminate single point of failure of bus section breaker.
Tacoma Power
2015-16 The purpose of this project is to improve system reliability by preventing any bus fault or a “stuck breaker” on one of the 230 kV buses from resulting in total loss of service to the substation.
Single System Project
Puget Sound Area Study Team
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Beverly Park 230-115 kV Capacity Addition
Expand the existing 115 kV switching station and add two 230-115 kV 300 MVA transformers. The 230 kV source will be from the BPA Snohomish Substation. An existing 115 kV line from BPA Snohomish to the Glenwood Tap will be converted to 230 kV. The 115 kV line serving the Glenwood Tap will then be configured to be served from the Beverly Park 115 kV bus.
Snohomish PUD No. 1
Additional Bonneville Snohomish 230kV bus positions are required
Project is in the design and construction Phase
2012 November
Load Growth and expected local reliability deficiency in Paine Field and Everett areas requires capacity increases to meet District level of service guidelines
Single System Project, possible impacts
Puget Sound Area Study Team
Canyon substation Canyon is a 230/110 kV substation to be located in the southern part of Tacoma Power’s service territory. Tacoma Power proposed to interconnect this new substation to Bonneville’s South Tacoma Substation. A single 230/110 kV step down transformer will be installed at this substation in the near term with provisions made for a future second transformer.
Tacoma Power
BPA Study completed by BPA in 2008
High 2011 The addition of this substation is intended to improve system reliability, operational flexibility, and at the same time, provide more system capacity to accommodate load growth in the area.
Single System Project, possible impacts
Puget Sound Area Study Team
IP line conversion to 230 kV
Convert PSE's 115kV "IP" line to 230kV between Kittitas substation and Lake Tradition substation in King County to increase cross-Cascade capacity and interconnect Kittitas County wind projects
PSE Puget Sound Utilities
Conceptual Project for future need
2013 to 2015 Load growth in Puget Sound and generation integration, related to North Cross Cascades Improvements
Single System Project, possible impacts
West of Cascades Study Team
North Cross Cascades Reinforcement
Alternatives include 500 kV series capacitors to the Schultz-Raver 500 kV lines No.3 & 4, and/or additional 500 kV shunt capacitors in the area, construction of a new 500 kV line across the Northern Cascades to serve loads in the Puget Sound area
BPA Puget Sound Utilities
2014-2016 Load growth in Puget Sound and Transmission Service Requests
Plan of service options updated
Existing Obligation Project
West of Cascades Study Team
Seattle Area 500/230 kV Transformer Bank
Add a new 500/230 kV transformer bank in the Seattle vicinity to serve loads in the Puget Sound area.
BPA PSE, Tacoma 2019 Load growth in Puget Sound area Project schedule changed from 2016 to 2019
Existing Obligation Project
Puget Sound Area Study Team
North King County Capacity Increase
A 230kV line between Sammamish Substation in North King County to Talbot substation in central King County. The project would involve rebuilding an existing 115kV line to 230kV.
PSE In parallel w/ Bonneville & SCL w/impacts to the Westside Northern Intertie
Conceptual Project for future need
2015 to 2017 Increased capacity across the Monroe-Echo Lake cutplane for native load and transmission service.
Existing Obligation Project
Puget Sound Area Study Team
62
Puget Sound Projects continued
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
115kV North Seattle Transmission Lines upgrade
Uprate 115kV transmission lines in the north end of Seattle to 100 degree C conductor temperature. Remaining tasks include completion of the Bothell-Shoreline #1 by summer 2009 and removing obstructions below the Bothell-Canal 115 kV lines.
Seattle City Light
BPA, NI Completed Increase North Seattle 115kV Transmission line capacity and to improve transmission reliability.
Single System Project
Cowlitz substation 230 kV Bus Reliability Improvement Project.
Modify Bus section breaker arrangement at Cowlitz substation to eliminate single point of failure of bus section breaker. This project will be implemented at the same time as the 230 kV Transformer Replacement project at Cowlitz.
Tacoma Power
Final study will be performed in the near future in anticipation of budget approval in 2011-2012.
2013-14 The purpose of this project is to increase system reliability and operational flexibility
Single System Project
Cowlitz 230 kV Transformer Replacement
Replace the two 250 MVA transformers at Cowlitz with two 400 MVA, 230/115 kV, autotransformers. instead of 500 MVA as previously reported.)
Tacoma Power
Study completed. 1st transformer purchased in 2008 and 2nd transformer will be purchased in 2009.
First trfmr replace in Nov 2009, Second trfmr to be replaced in 2011
The two 250 MVA transformers at Cowlitz were installed in the mid-60s. The new transformers will provide more capacity to accommodate system load growth. They will also provide better operational flexibility and higher reliability by allowing N-1-1 operation when one of them is taken out of service for maintenance.
Single System Project
Swamp Creek 115 kV switching station
Construct a six 115 kV breaker switching station with a ring bus arrangement using GIS technology (four breakers only needed for phase one work). Future construction will include one 115 kV line position will terminate a new 115 kV line from the Paine Field Area and one new 115 kV termination of a 230kV / 115 kV transformer. This switching station will terminate 115 kV lines from SnoKing (2 Lines), Halls Lake (1 line) and from Beverly Park (1 line).
Snohomish PUD No. 1
Project under study
2021 November
South County area load growth and expected reliability deficiencies will require capacity increases to meet District level of service guidelines. This construction work is also part of a multi-project effort to provide three 115 kV ties between Bonneville SnoKing and Bonneville Snohomish substations.
Single System Project
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Cowlitz Substation 230 kV Line Re-termination Project.
This project involves the re-termination of Bonneville’s South Tacoma-Cowlitz (#1) 230-kV line from Tacoma Power's Cowlitz 230-kV Bus into TPWR’s Southwest (#4) line. It also includes the re-termination of TPWR’s Cowlitz-Southwest (#3) and Cowlitz-Tacoma (#2) 230-kV lines to create a new Southwest-Tacoma 230 kV line.
Tacoma Power
Bonneville Study completed by Bonneville in June 2008
2011-2012 $750K to $1M
Reliability improvement Single System Project, possible impacts
Puget Sound Area Study Team
Pierce County transformer capacity.
A new 230/115kV transformer at Alderton substation in central Pierce County with several options being considered for the 230kV source.
PSE Included in sponsor's budget
2011 Additional transformation capacity for Pierce and south King Counties to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Team
Thurston County transformer capacity.
A new 230/115kV transformer at Saint Clair or Spurgen Creek substations in Southern Thurston County with several options being considered for the 230kV source.
PSE Project identified as future need
2012 Additional transformation capacity for Thurston Counties to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Team
North Downtown Seattle Substation
Proposed to build a new 200 MVA substation in the north of downtown area to serve load growth. Install underground 230kV transmission lines from East Pine and Massachusetts Substations to New Substation and add 230kV/115kV autotransformer. Construct new 115kV transmission lines from Canal and Broad Street Substations to New Substation.
Seattle City Light
Conceptual Project for future need
Project identified as future need
2018 $40 to $200M
Load growth in North Seattle area has slowed since late 2008. SCL is reviewing load forecasts and transmission plans for the north downtown area.
Existing Obligation Project
Puget Sound Area Study Team
South of Sedro Capacity Increase
Rebuild a 115kV line to become a second 230kV line between Sedro Woolley and Horse Ranch Substations. Includes reconductoring sections of the Sedro Woolley-Horse Ranch-Bothell 230kV line, adding 2 breakers at Horse Ranch, and uprating the Horse Ranch-HR Tap of Monroe-Snohomish 230 kV line
PSE in parallel w/Bonneville & Snohomish PUD w/ impacts to the Westside Northern Intertie
Under Construction
2010 Increase capacity for native load and transmission service
Capacity Increase Project
Puget Sound Area Study Team
Southwest substation 230 kV Bus Reliability Improvement Project
Modify Bus section breaker arrangement at Southwest substation to eliminate single point of failure of bus section breaker.
Tacoma Power
2015-16 The purpose of this project is to improve system reliability by preventing any bus fault or a “stuck breaker” on one of the 230 kV buses from resulting in total loss of service to the substation.
Single System Project
Puget Sound Area Study Team
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Beverly Park 230-115 kV Capacity Addition
Expand the existing 115 kV switching station and add two 230-115 kV 300 MVA transformers. The 230 kV source will be from the BPA Snohomish Substation. An existing 115 kV line from BPA Snohomish to the Glenwood Tap will be converted to 230 kV. The 115 kV line serving the Glenwood Tap will then be configured to be served from the Beverly Park 115 kV bus.
Snohomish PUD No. 1
Additional Bonneville Snohomish 230kV bus positions are required
Project is in the design and construction Phase
2012 November
Load Growth and expected local reliability deficiency in Paine Field and Everett areas requires capacity increases to meet District level of service guidelines
Single System Project, possible impacts
Puget Sound Area Study Team
Canyon substation Canyon is a 230/110 kV substation to be located in the southern part of Tacoma Power’s service territory. Tacoma Power proposed to interconnect this new substation to Bonneville’s South Tacoma Substation. A single 230/110 kV step down transformer will be installed at this substation in the near term with provisions made for a future second transformer.
Tacoma Power
BPA Study completed by BPA in 2008
High 2011 The addition of this substation is intended to improve system reliability, operational flexibility, and at the same time, provide more system capacity to accommodate load growth in the area.
Single System Project, possible impacts
Puget Sound Area Study Team
IP line conversion to 230 kV
Convert PSE's 115kV "IP" line to 230kV between Kittitas substation and Lake Tradition substation in King County to increase cross-Cascade capacity and interconnect Kittitas County wind projects
PSE Puget Sound Utilities
Conceptual Project for future need
2013 to 2015 Load growth in Puget Sound and generation integration, related to North Cross Cascades Improvements
Single System Project, possible impacts
West of Cascades Study Team
North Cross Cascades Reinforcement
Alternatives include 500 kV series capacitors to the Schultz-Raver 500 kV lines No.3 & 4, and/or additional 500 kV shunt capacitors in the area, construction of a new 500 kV line across the Northern Cascades to serve loads in the Puget Sound area
BPA Puget Sound Utilities
2014-2016 Load growth in Puget Sound and Transmission Service Requests
Plan of service options updated
Existing Obligation Project
West of Cascades Study Team
Seattle Area 500/230 kV Transformer Bank
Add a new 500/230 kV transformer bank in the Seattle vicinity to serve loads in the Puget Sound area.
BPA PSE, Tacoma 2019 Load growth in Puget Sound area Project schedule changed from 2016 to 2019
Existing Obligation Project
Puget Sound Area Study Team
North King County Capacity Increase
A 230kV line between Sammamish Substation in North King County to Talbot substation in central King County. The project would involve rebuilding an existing 115kV line to 230kV.
PSE In parallel w/ Bonneville & SCL w/impacts to the Westside Northern Intertie
Conceptual Project for future need
2015 to 2017 Increased capacity across the Monroe-Echo Lake cutplane for native load and transmission service.
Existing Obligation Project
Puget Sound Area Study Team
63
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Beverly Park 230-115 kV Capacity Addition
Expand the existing 115 kV switching station and add two 230-115 kV 300 MVA transformers. The 230 kV source will be from the BPA Snohomish Substation. An existing 115 kV line from BPA Snohomish to the Glenwood Tap will be converted to 230 kV. The 115 kV line serving the Glenwood Tap will then be configured to be served from the Beverly Park 115 kV bus.
Snohomish PUD No. 1
Additional Bonneville Snohomish 230kV bus positions are required
Project is in the design and construction Phase
2012 November
Load Growth and expected local reliability deficiency in Paine Field and Everett areas requires capacity increases to meet District level of service guidelines
Single System Project, possible impacts
Puget Sound Area Study Team
Canyon substation Canyon is a 230/110 kV substation to be located in the southern part of Tacoma Power’s service territory. Tacoma Power proposed to interconnect this new substation to Bonneville’s South Tacoma Substation. A single 230/110 kV step down transformer will be installed at this substation in the near term with provisions made for a future second transformer.
Tacoma Power
BPA Study completed by BPA in 2008
High 2011 The addition of this substation is intended to improve system reliability, operational flexibility, and at the same time, provide more system capacity to accommodate load growth in the area.
Single System Project, possible impacts
Puget Sound Area Study Team
IP line conversion to 230 kV
Convert PSE's 115kV "IP" line to 230kV between Kittitas substation and Lake Tradition substation in King County to increase cross-Cascade capacity and interconnect Kittitas County wind projects
PSE Puget Sound Utilities
Conceptual Project for future need
2013 to 2015 Load growth in Puget Sound and generation integration, related to North Cross Cascades Improvements
Single System Project, possible impacts
West of Cascades Study Team
North Cross Cascades Reinforcement
Alternatives include 500 kV series capacitors to the Schultz-Raver 500 kV lines No.3 & 4, and/or additional 500 kV shunt capacitors in the area, construction of a new 500 kV line across the Northern Cascades to serve loads in the Puget Sound area
BPA Puget Sound Utilities
2014-2016 Load growth in Puget Sound and Transmission Service Requests
Plan of service options updated
Existing Obligation Project
West of Cascades Study Team
Seattle Area 500/230 kV Transformer Bank
Add a new 500/230 kV transformer bank in the Seattle vicinity to serve loads in the Puget Sound area.
BPA PSE, Tacoma 2019 Load growth in Puget Sound area Project schedule changed from 2016 to 2019
Existing Obligation Project
Puget Sound Area Study Team
North King County Capacity Increase
A 230kV line between Sammamish Substation in North King County to Talbot substation in central King County. The project would involve rebuilding an existing 115kV line to 230kV.
PSE In parallel w/ Bonneville & SCL w/impacts to the Westside Northern Intertie
Conceptual Project for future need
2015 to 2017 Increased capacity across the Monroe-Echo Lake cutplane for native load and transmission service.
Existing Obligation Project
Puget Sound Area Study Team
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
115kV North Seattle Transmission Lines upgrade
Uprate 115kV transmission lines in the north end of Seattle to 100 degree C conductor temperature. Remaining tasks include completion of the Bothell-Shoreline #1 by summer 2009 and removing obstructions below the Bothell-Canal 115 kV lines.
Seattle City Light
BPA, NI Completed Increase North Seattle 115kV Transmission line capacity and to improve transmission reliability.
Single System Project
Cowlitz substation 230 kV Bus Reliability Improvement Project.
Modify Bus section breaker arrangement at Cowlitz substation to eliminate single point of failure of bus section breaker. This project will be implemented at the same time as the 230 kV Transformer Replacement project at Cowlitz.
Tacoma Power
Final study will be performed in the near future in anticipation of budget approval in 2011-2012.
2013-14 The purpose of this project is to increase system reliability and operational flexibility
Single System Project
Cowlitz 230 kV Transformer Replacement
Replace the two 250 MVA transformers at Cowlitz with two 400 MVA, 230/115 kV, autotransformers. instead of 500 MVA as previously reported.)
Tacoma Power
Study completed. 1st transformer purchased in 2008 and 2nd transformer will be purchased in 2009.
First trfmr replace in Nov 2009, Second trfmr to be replaced in 2011
The two 250 MVA transformers at Cowlitz were installed in the mid-60s. The new transformers will provide more capacity to accommodate system load growth. They will also provide better operational flexibility and higher reliability by allowing N-1-1 operation when one of them is taken out of service for maintenance.
Single System Project
Swamp Creek 115 kV switching station
Construct a six 115 kV breaker switching station with a ring bus arrangement using GIS technology (four breakers only needed for phase one work). Future construction will include one 115 kV line position will terminate a new 115 kV line from the Paine Field Area and one new 115 kV termination of a 230kV / 115 kV transformer. This switching station will terminate 115 kV lines from SnoKing (2 Lines), Halls Lake (1 line) and from Beverly Park (1 line).
Snohomish PUD No. 1
Project under study
2021 November
South County area load growth and expected reliability deficiencies will require capacity increases to meet District level of service guidelines. This construction work is also part of a multi-project effort to provide three 115 kV ties between Bonneville SnoKing and Bonneville Snohomish substations.
Single System Project
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Cowlitz Substation 230 kV Line Re-termination Project.
This project involves the re-termination of Bonneville’s South Tacoma-Cowlitz (#1) 230-kV line from Tacoma Power's Cowlitz 230-kV Bus into TPWR’s Southwest (#4) line. It also includes the re-termination of TPWR’s Cowlitz-Southwest (#3) and Cowlitz-Tacoma (#2) 230-kV lines to create a new Southwest-Tacoma 230 kV line.
Tacoma Power
Bonneville Study completed by Bonneville in June 2008
2011-2012 $750K to $1M
Reliability improvement Single System Project, possible impacts
Puget Sound Area Study Team
Pierce County transformer capacity.
A new 230/115kV transformer at Alderton substation in central Pierce County with several options being considered for the 230kV source.
PSE Included in sponsor's budget
2011 Additional transformation capacity for Pierce and south King Counties to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Team
Thurston County transformer capacity.
A new 230/115kV transformer at Saint Clair or Spurgen Creek substations in Southern Thurston County with several options being considered for the 230kV source.
PSE Project identified as future need
2012 Additional transformation capacity for Thurston Counties to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Team
North Downtown Seattle Substation
Proposed to build a new 200 MVA substation in the north of downtown area to serve load growth. Install underground 230kV transmission lines from East Pine and Massachusetts Substations to New Substation and add 230kV/115kV autotransformer. Construct new 115kV transmission lines from Canal and Broad Street Substations to New Substation.
Seattle City Light
Conceptual Project for future need
Project identified as future need
2018 $40 to $200M
Load growth in North Seattle area has slowed since late 2008. SCL is reviewing load forecasts and transmission plans for the north downtown area.
Existing Obligation Project
Puget Sound Area Study Team
South of Sedro Capacity Increase
Rebuild a 115kV line to become a second 230kV line between Sedro Woolley and Horse Ranch Substations. Includes reconductoring sections of the Sedro Woolley-Horse Ranch-Bothell 230kV line, adding 2 breakers at Horse Ranch, and uprating the Horse Ranch-HR Tap of Monroe-Snohomish 230 kV line
PSE in parallel w/Bonneville & Snohomish PUD w/ impacts to the Westside Northern Intertie
Under Construction
2010 Increase capacity for native load and transmission service
Capacity Increase Project
Puget Sound Area Study Team
Southwest substation 230 kV Bus Reliability Improvement Project
Modify Bus section breaker arrangement at Southwest substation to eliminate single point of failure of bus section breaker.
Tacoma Power
2015-16 The purpose of this project is to improve system reliability by preventing any bus fault or a “stuck breaker” on one of the 230 kV buses from resulting in total loss of service to the substation.
Single System Project
Puget Sound Area Study Team
West of Cascades Study Team
64
Puget Sound Projects continuedPuget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Paine Field 115 kV Switching Station
This capital expansion includes design and construction of a six 115 kV breaker ring bus adjacent to the existing Paine Field Substation. The existing Paine Field Substation will have a station bus looped through from the new adjacent ring bus and the Paine Field to Boeing 115 kV Line. When completed, the switching station will terminate lines from Mukilteo, Olivia Park, Boeing, Gibson, Beverly Park via Casino (new), and Swamp Creek via Picnic Point tap (new).
Snohomish PUD No. 1
Project under study
2021 November
South County area load growth and expected reliability deficiencies will require capacity increases to meet District level of service guidelines. This construction work is also part of a multi-project effort to provide three 115 kV ties between BPA SnoKing and BPA Snohomish Substations.
Single System Project
Swamp Creek to Picnic Point Tap 115 kV Line
This capital expansion includes design and construction of a 115 kV line (2.9 miles) with 1272 kCM conductor from Swamp Creek to the Picnic Point tap. A new 115 kV line position and breaker will be added to the Swamp Creek 115 kV Switching Station. This new 115 kV line will be configured (closed loop network connection) with the Paine Field 115 kV Switching Station. The Picnic Point Tap to the Picnic Point Substation 115 kV Line will be operated normally opened.
Snohomish PUD No. 1
Project under study
November 2020
South County area load growth and expected reliability deficiencies will require capacity increases to meet District level of service guidelines. This construction work is also part of a multi-project effort to provide three 115 kV ties between BPA SnoKing and BPA Snohomish Substations.
Single System Project
Marysville 230-115kV Substation
Construct a new 230 – 115 kV 300 MVA Transformation Substation in the Marysville, Washington area. This new transmission substation will be connected (looped) to the existing BPA Murray to BPA Snohomish 230 kV line. The new substation will consist of four 115 kV line positions and connect to the existing area 115 kV network and the Stimson Crossing 115 kV Switching Station.
Snohomish PUD No. 1
BPA Project under study
November 2025
Marysville area load growth and expected North County reliability deficiencies will require capacity increases to meet District level of service guidelines
Single System Project, possible impacts
Beverly Park and South Snohomish County 115 kV Expansion
Addition of several 115 kV line capacity additions in the South Everett Area: Beverly Park to Everett 115 kV Line (2012) , Beverly Park to Boeing (reconductor) 115 kV line (2012).
Snohomish PUD No. 1
Projects are in the design and construction phase
November 2012
Beverly Park and South Everett area load growth and expected local reliability deficiencies will require capacity increases to meet District level of service guidelines
Single System Project
Chehalis-Centralia Rebuild
Rebuild both of the Chehalis-Centralia 69 kV lines No.1 and 2 with higher capacity conductor using H-frame structures, and 115 kV spacing and insulation. The lines will be operated initially at 69 kV.
BPA Completed Load growth in Chehalis and Centralia areas
Project compoleted Single System Project
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
East King County transformer capacity
This project involves looping the Maple Valley-Sammamish #1 230kV line into PSE's Lake Tradition Substation and installing a new 230/115kV transformer.
PSE 2012 Additional transformation capacity for east King County to meet load growth.
Single System Project, possible impacts
Puget Sound and Northern Mid-C Area Study Teams
Skagit County transformer capacity
This project involves installing an additional 230/115kV transformer into PSE's Sedro Woolley Substation.
PSE Project identified as future need
2013 Additional transformation capacity for Skagit County to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Team
Lakeside transformer addition
This project involves looping the Maple Valley-Bothell 230kV line into PSE's Lakeside Substation and installing a new 230/115kV transformer.
PSE Project identified as future need
2015-20 Additional transformation capacity to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Teams
65
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Paine Field 115 kV Switching Station
This capital expansion includes design and construction of a six 115 kV breaker ring bus adjacent to the existing Paine Field Substation. The existing Paine Field Substation will have a station bus looped through from the new adjacent ring bus and the Paine Field to Boeing 115 kV Line. When completed, the switching station will terminate lines from Mukilteo, Olivia Park, Boeing, Gibson, Beverly Park via Casino (new), and Swamp Creek via Picnic Point tap (new).
Snohomish PUD No. 1
Project under study
2021 November
South County area load growth and expected reliability deficiencies will require capacity increases to meet District level of service guidelines. This construction work is also part of a multi-project effort to provide three 115 kV ties between BPA SnoKing and BPA Snohomish Substations.
Single System Project
Swamp Creek to Picnic Point Tap 115 kV Line
This capital expansion includes design and construction of a 115 kV line (2.9 miles) with 1272 kCM conductor from Swamp Creek to the Picnic Point tap. A new 115 kV line position and breaker will be added to the Swamp Creek 115 kV Switching Station. This new 115 kV line will be configured (closed loop network connection) with the Paine Field 115 kV Switching Station. The Picnic Point Tap to the Picnic Point Substation 115 kV Line will be operated normally opened.
Snohomish PUD No. 1
Project under study
November 2020
South County area load growth and expected reliability deficiencies will require capacity increases to meet District level of service guidelines. This construction work is also part of a multi-project effort to provide three 115 kV ties between BPA SnoKing and BPA Snohomish Substations.
Single System Project
Marysville 230-115kV Substation
Construct a new 230 – 115 kV 300 MVA Transformation Substation in the Marysville, Washington area. This new transmission substation will be connected (looped) to the existing BPA Murray to BPA Snohomish 230 kV line. The new substation will consist of four 115 kV line positions and connect to the existing area 115 kV network and the Stimson Crossing 115 kV Switching Station.
Snohomish PUD No. 1
BPA Project under study
November 2025
Marysville area load growth and expected North County reliability deficiencies will require capacity increases to meet District level of service guidelines
Single System Project, possible impacts
Beverly Park and South Snohomish County 115 kV Expansion
Addition of several 115 kV line capacity additions in the South Everett Area: Beverly Park to Everett 115 kV Line (2012) , Beverly Park to Boeing (reconductor) 115 kV line (2012).
Snohomish PUD No. 1
Projects are in the design and construction phase
November 2012
Beverly Park and South Everett area load growth and expected local reliability deficiencies will require capacity increases to meet District level of service guidelines
Single System Project
Chehalis-Centralia Rebuild
Rebuild both of the Chehalis-Centralia 69 kV lines No.1 and 2 with higher capacity conductor using H-frame structures, and 115 kV spacing and insulation. The lines will be operated initially at 69 kV.
BPA Completed Load growth in Chehalis and Centralia areas
Project compoleted Single System Project
Puget Sound Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
East King County transformer capacity
This project involves looping the Maple Valley-Sammamish #1 230kV line into PSE's Lake Tradition Substation and installing a new 230/115kV transformer.
PSE 2012 Additional transformation capacity for east King County to meet load growth.
Single System Project, possible impacts
Puget Sound and Northern Mid-C Area Study Teams
Skagit County transformer capacity
This project involves installing an additional 230/115kV transformer into PSE's Sedro Woolley Substation.
PSE Project identified as future need
2013 Additional transformation capacity for Skagit County to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Team
Lakeside transformer addition
This project involves looping the Maple Valley-Bothell 230kV line into PSE's Lakeside Substation and installing a new 230/115kV transformer.
PSE Project identified as future need
2015-20 Additional transformation capacity to meet load growth.
Single System Project, possible impacts
Puget Sound Area Study Teams
66
Central Washington ProjectsCentral Washington Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost EstimateProject Need/Driver & Other Notes
Changes from Previous PlanPlan cross tribal lands
Type of Project Study Team(s)
Mid-Columbia Area Reinforcement
Rebuild 9 miles of the Vantage-Midway 230 kV line (about 10 miles is already rebuilt) in Central WA. Add sectionalizing breaker at Vantage substation.
BPA PAC & Grant Plan of Service Determined
Funding approved by sponsor
2011 $14 million Load growth in Mid C area and transfers of generation out of the area
Existing Obligation Project
NTAC
Mid-Columbia Area Reinforcement
Wanapum-Pomona Heights 230-kV #2 Line in the Yakima area.
PAC BPA, Grant 2012 Load growth in Yakima area External Project NTAC
Northern Mid-C Area Support
Douglas-Rapids 230 kV line, Douglas 230/115 kV transformer, Rapids 115 substation with terminations for Pangborn, South Nile and Hanna 115 kV lines
Douglas Douglas, Chelan, BPA, Grant, PSE
Plan of Service Determined
sponsor committed
2013 $16M Project needed to meet load growth
No Existing Obligation Project
Northern Mid-C Study Group
Northern Mid-C Area Support
Andrew York 115kV Bus Arrangement: change the line termination bus arrangement at Andrew York Switchyard
Chelan County PUD
Plan of Service Determined
Included in Sponsors Budget
Fall 2010 $750k Project needed to match line capacities for bus segment outage
Single System Project
Northern Mid-C Study Group
Northern Mid-C Area Support
Rebuild McKenzie to Wenatchee Tap 115 kV line Chelan County PUD
Plan of Service Determined
Committed Fall 2012 $6M This project is needed to provide a higher rating and mitigate reliability criteria violations.
Single System Project
Northern Mid-C Study Group
Northern Mid-C Area Support
Upgrade Wenatchee-McKenzie 115 kV line from 50 to 75 degrees Celsius
Chelan County PUD
Plan of Service Determined
Committed Fall 2011 $500k Load Growth New Project Single System Project
Northern Mid-C Study Group
Northern Mid-C Area Support
Build new Rapids-Columbia 230 kV line unknown Douglas, Chelan, BPA, Grant, PSE
Plan of Service under Study
Project identified as need
2013 Project needed to meet load growth and transfers
New Project No Existing Obligation Project
Northern Mid-C Study Group
Mid-Columbia Area Reinforcement, Phase 2
Upgrade Wanapum-Midway 230-kV line in central WA,
Grant County PUD
Project identified as future need -
2015 Load growth, new wind generation plants and transfers of generation out of the area
Existing Obligation Project
Columbia - Larson 230 kV Line
Construct a new 230 kV line from Rocky Ford to Columbia, connect to existing Rocky Ford-Larson 230 kV line to form Columbia-Rocky Ford line.
Grant County PUD
Interconnect w/BPA at Columbia Sub
2014 $40 million Meet load growth, increase transmission system reliability and improve voltage stability performance.
Single System Project with possible parallel impacts
Northern Mid-C Study Group
Entiat 115kV Switching Station
Construct 3 breaker ring style 115kV switching station near Entiat. The existing Rocky Reach to Chelan Falls 115kV transmission line will be tapped with a new 115kV transmission line to serve Entiat Valley load area.
Chelan County PUD
Conceptual Project for Future Need
Project identified as future need -
Fall 2014 $2-3 million Load Growth Single System Project
Larson - Stratford 115 kV Line
Upgrade 16.14 miles of the Larson – Stratford 115 kV line.
Grant County PUD
Complete In service This project is needed to provide a higher rating and mitigate reliability criteria violations with the increasing load in the area.
Single System Project
Anderson Canyon Undervoltage Relay
Installation of undervoltage relay at Anderson Canyon
Chelan County PUD
Construction Included in Sponsors Budget
Fall 2009 $100k Safety net for BSBF contingency at Andrew York
Single System Project
Central Washington Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost EstimateProject Need/Driver & Other Notes
Changes from Previous PlanPlan cross tribal lands
Type of Project Study Team(s)
Wine Country 230/115 kV Transformer
Add substation and 230/115 kV Transformer tapping Midway-Mabton 230 line and serving the Sunnyside and Grandview areas
PAC Complete In service Load Growth Single System Project
67
Central Washington Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost EstimateProject Need/Driver & Other Notes
Changes from Previous PlanPlan cross tribal lands
Type of Project Study Team(s)
Mid-Columbia Area Reinforcement
Rebuild 9 miles of the Vantage-Midway 230 kV line (about 10 miles is already rebuilt) in Central WA. Add sectionalizing breaker at Vantage substation.
BPA PAC & Grant Plan of Service Determined
Funding approved by sponsor
2011 $14 million Load growth in Mid C area and transfers of generation out of the area
Existing Obligation Project
NTAC
Mid-Columbia Area Reinforcement
Wanapum-Pomona Heights 230-kV #2 Line in the Yakima area.
PAC BPA, Grant 2012 Load growth in Yakima area External Project NTAC
Northern Mid-C Area Support
Douglas-Rapids 230 kV line, Douglas 230/115 kV transformer, Rapids 115 substation with terminations for Pangborn, South Nile and Hanna 115 kV lines
Douglas Douglas, Chelan, BPA, Grant, PSE
Plan of Service Determined
sponsor committed
2013 $16M Project needed to meet load growth
No Existing Obligation Project
Northern Mid-C Study Group
Northern Mid-C Area Support
Andrew York 115kV Bus Arrangement: change the line termination bus arrangement at Andrew York Switchyard
Chelan County PUD
Plan of Service Determined
Included in Sponsors Budget
Fall 2010 $750k Project needed to match line capacities for bus segment outage
Single System Project
Northern Mid-C Study Group
Northern Mid-C Area Support
Rebuild McKenzie to Wenatchee Tap 115 kV line Chelan County PUD
Plan of Service Determined
Committed Fall 2012 $6M This project is needed to provide a higher rating and mitigate reliability criteria violations.
Single System Project
Northern Mid-C Study Group
Northern Mid-C Area Support
Upgrade Wenatchee-McKenzie 115 kV line from 50 to 75 degrees Celsius
Chelan County PUD
Plan of Service Determined
Committed Fall 2011 $500k Load Growth New Project Single System Project
Northern Mid-C Study Group
Northern Mid-C Area Support
Build new Rapids-Columbia 230 kV line unknown Douglas, Chelan, BPA, Grant, PSE
Plan of Service under Study
Project identified as need
2013 Project needed to meet load growth and transfers
New Project No Existing Obligation Project
Northern Mid-C Study Group
Mid-Columbia Area Reinforcement, Phase 2
Upgrade Wanapum-Midway 230-kV line in central WA,
Grant County PUD
Project identified as future need -
2015 Load growth, new wind generation plants and transfers of generation out of the area
Existing Obligation Project
Columbia - Larson 230 kV Line
Construct a new 230 kV line from Rocky Ford to Columbia, connect to existing Rocky Ford-Larson 230 kV line to form Columbia-Rocky Ford line.
Grant County PUD
Interconnect w/BPA at Columbia Sub
2014 $40 million Meet load growth, increase transmission system reliability and improve voltage stability performance.
Single System Project with possible parallel impacts
Northern Mid-C Study Group
Entiat 115kV Switching Station
Construct 3 breaker ring style 115kV switching station near Entiat. The existing Rocky Reach to Chelan Falls 115kV transmission line will be tapped with a new 115kV transmission line to serve Entiat Valley load area.
Chelan County PUD
Conceptual Project for Future Need
Project identified as future need -
Fall 2014 $2-3 million Load Growth Single System Project
Larson - Stratford 115 kV Line
Upgrade 16.14 miles of the Larson – Stratford 115 kV line.
Grant County PUD
Complete In service This project is needed to provide a higher rating and mitigate reliability criteria violations with the increasing load in the area.
Single System Project
Anderson Canyon Undervoltage Relay
Installation of undervoltage relay at Anderson Canyon
Chelan County PUD
Construction Included in Sponsors Budget
Fall 2009 $100k Safety net for BSBF contingency at Andrew York
Single System Project
Central Washington Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost EstimateProject Need/Driver & Other Notes
Changes from Previous PlanPlan cross tribal lands
Type of Project Study Team(s)
Wine Country 230/115 kV Transformer
Add substation and 230/115 kV Transformer tapping Midway-Mabton 230 line and serving the Sunnyside and Grandview areas
PAC Complete In service Load Growth Single System Project
68
Northeastern ProjectsNortheastern Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Boundary Transformer replacement with connection to existing 115kV transmission line
Installation of a 230/115KV autotransformer in the Boundary Switchyard to interconnect to SCL's 115KV Boundary transmission tap line will also enhanced electric grid reliability.
Seattle City Light, BPA, Pend Oreille PUD
Completed 2009 BPA, SCL and Pend Oreille PUD have negotiated the Boundary Transformer Agreement to allow for the cost-effective delivery of Article 49 Power and tailwater encroachment compensation from the Boundary Project to the POPUD via SCL’s Boundary Tap Line and BPA’s Box Canyon Tap Line.
Project completed Existing Obligation Project
Libby (FEC)-Troy 115 kV Line Rebuild
Rebuild the Libby (FEC)-Troy 115 kV line (approximately 17 miles) with new single circuit 115 kV conductor.
BPA Completed completed $19 million
Replacement of aging line Single System Project
Spokane Area 230 kV Reinforcement
Add a 230/115 kV autotransformer in the Sunset substation area with 230-kV lines to Westside and either Beacon/Boulder 230 kV switching stations
Avista Project identified as future need -
2015 To provide capacity to meet load growth in the south Spokane area
Single System Project with possible impacts
Planned Capacitors 13.42 MVARs @ Grangeville, 13.42 MVARs @ Nez Perce, 6.7 MVARs X 3 @ Lind,
Avista 2008, 2009, 2010
Single System Project
Proposed Capacitors
15 MVARs @Coeur d'Alene, Post Falls, Kettle Falls; 20 MVARs in Pullman area (Shawnee); 30 MVARs @ Airway Heights, Hallet and White; 50 MVARs @ Francis and Cedar
Avista Projects identified as short term need
1-5 years new Single System Project
Moscow 230/115-kV Upgrade
Increase Moscow transformer capacity to 250 MVA Avista Project identified as long term need
6-10 years new Single System Project
Lewiston 10 Year Plan
Second Hatwai-Lolo 230 kV line is one solution, Long range study needed
Avista BPA, IPCO, PAC Project identified as long term need
10 years Loss of Hatwai-Lolo and Hatwai-North Lewiston 230 kV lines for heavy flows to Walla Walla and Idaho
new Needed
Tri-Cities Reinforcements
Add a 115 kV bus sectionalizing breaker at White Bluffs Substation and reterminate the Richland and DOE B3-S4 lines.
BPA Plan of service determined
Included in sponsors budget
2010 $1.4 million
Load Growth and operational flexibility
Single System Project
Tucannon-Walla Walla Line Upgrade
Rebuild the Tucannon-Walla Walla 115 kV line section with new structures and higher capacity conductor.
BPA 2011 Repair aging line Project schedule added Single System Project
Little Goose Area Reinforcement
Add 40 mile 500 kV line from new wind collection station called Central Ferry to Lower Monumental Substation
BPA Funding for NEPAand preliminary engineering is Committed under NOS
Depends upon NEPA
September 2013
$99 million
To serve requests made under 2008 Network Open Season
New Requested Service Project
Northeastern Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Wallula-McNary 230 kV line
PacifiCorp is building a 230-kV line from Wallula to McNary/Boardman/NEO area. This project may be extended to Walla Walla in the future.
PAC BPA In WECC Rating process in TCWG
2012 Transmission Service Requests Project changed from Walla Walla-McNary to Wallula-McNary
Requested Service Project
TCWG
69
Northeastern Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Boundary Transformer replacement with connection to existing 115kV transmission line
Installation of a 230/115KV autotransformer in the Boundary Switchyard to interconnect to SCL's 115KV Boundary transmission tap line will also enhanced electric grid reliability.
Seattle City Light, BPA, Pend Oreille PUD
Completed 2009 BPA, SCL and Pend Oreille PUD have negotiated the Boundary Transformer Agreement to allow for the cost-effective delivery of Article 49 Power and tailwater encroachment compensation from the Boundary Project to the POPUD via SCL’s Boundary Tap Line and BPA’s Box Canyon Tap Line.
Project completed Existing Obligation Project
Libby (FEC)-Troy 115 kV Line Rebuild
Rebuild the Libby (FEC)-Troy 115 kV line (approximately 17 miles) with new single circuit 115 kV conductor.
BPA Completed completed $19 million
Replacement of aging line Single System Project
Spokane Area 230 kV Reinforcement
Add a 230/115 kV autotransformer in the Sunset substation area with 230-kV lines to Westside and either Beacon/Boulder 230 kV switching stations
Avista Project identified as future need -
2015 To provide capacity to meet load growth in the south Spokane area
Single System Project with possible impacts
Planned Capacitors 13.42 MVARs @ Grangeville, 13.42 MVARs @ Nez Perce, 6.7 MVARs X 3 @ Lind,
Avista 2008, 2009, 2010
Single System Project
Proposed Capacitors
15 MVARs @Coeur d'Alene, Post Falls, Kettle Falls; 20 MVARs in Pullman area (Shawnee); 30 MVARs @ Airway Heights, Hallet and White; 50 MVARs @ Francis and Cedar
Avista Projects identified as short term need
1-5 years new Single System Project
Moscow 230/115-kV Upgrade
Increase Moscow transformer capacity to 250 MVA Avista Project identified as long term need
6-10 years new Single System Project
Lewiston 10 Year Plan
Second Hatwai-Lolo 230 kV line is one solution, Long range study needed
Avista BPA, IPCO, PAC Project identified as long term need
10 years Loss of Hatwai-Lolo and Hatwai-North Lewiston 230 kV lines for heavy flows to Walla Walla and Idaho
new Needed
Tri-Cities Reinforcements
Add a 115 kV bus sectionalizing breaker at White Bluffs Substation and reterminate the Richland and DOE B3-S4 lines.
BPA Plan of service determined
Included in sponsors budget
2010 $1.4 million
Load Growth and operational flexibility
Single System Project
Tucannon-Walla Walla Line Upgrade
Rebuild the Tucannon-Walla Walla 115 kV line section with new structures and higher capacity conductor.
BPA 2011 Repair aging line Project schedule added Single System Project
Little Goose Area Reinforcement
Add 40 mile 500 kV line from new wind collection station called Central Ferry to Lower Monumental Substation
BPA Funding for NEPAand preliminary engineering is Committed under NOS
Depends upon NEPA
September 2013
$99 million
To serve requests made under 2008 Network Open Season
New Requested Service Project
Northeastern Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other NotesChanges from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Wallula-McNary 230 kV line
PacifiCorp is building a 230-kV line from Wallula to McNary/Boardman/NEO area. This project may be extended to Walla Walla in the future.
PAC BPA In WECC Rating process in TCWG
2012 Transmission Service Requests Project changed from Walla Walla-McNary to Wallula-McNary
Requested Service Project
TCWG
70
Western ProjectsWestern Region Projects
Project Name DescriptionSponsor
Parties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost EstimateProject Need/Driver & Other Notes
Changes from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Lebanon Area Reinforcement
Add a 19.6 MVAR, 115 kV shunt capacitor bank at Lebanon Substation
BPA Plan of service determined
Funding approved by sponsor
2010 $3 million Load Growth Changed plan from 230/115 Transformer
Single System
I-5 Corridor (SW Washington - NW Oregon Reinforcement)
Construct a new 500 kV line (approx. 70 miles) from Troutdale Substation to the new Castle Rock substation located approximately 12 miles north of Allston Substation on the Paul-Allston No.1 500 kV line.
BPA PAC Funding for NEPA and preliminary engineering is committed under NOS
Depends upon NEPA
2015 $300 million Transmission Service Requests
Requested Service Project
I-5 Corridor Regional Planning Study Team
Pearl – Sherwood 230 kV
PGE and BPA plan to re-terminate the existing double circuit operating in parallel between BPA’s Pearl Substation and PGE’s Sherwood Substation. This will require two new circuit breakers. When the project is completed, there will be a Pearl-Sherwood #1 230-kV circuit and a Pearl-Sherwood #2 230-kV circuit.
PGE and BPA
PGE and BPA Project identified as future need
2017 Reliability and Load growth Multi-system EOP with only one ColGrid participant
Chemawa 230/115 kV Transformer Bank
Add a new 230/115 kV Transformer at Chemawa Substation
BPA Cancelled Cancelled since project need is now beyond 10-year planning horizon
Single System
Cross-Cascades South Station K development connecting Ashe-Marion, Buckley-Marion and both John Day-Grizzly lines together at a new station where the lines cross is proposed.
BPA PGE, PAC Conceptual project for future need
2020 Load Growth Project schedule added Multi-system EOP with only one ColGrid participant
West of Cascades Study Team
Springville-Horizon 230 kV line
Add second source for Horizon substation PGE BPA Conceptual project for future need
Load Growth
Horizon 230/115-kV transformer
PGE plans to install a 230/115-kV, 320 MVA auto-transformers at Horizon Substation, located in Hillsboro, Oregon. This project requires construction of a new 230-kV transmission line from Sunset Substation to Horizon (approximately 1 mile).
PGE Connection to BPA via Keeler
2012 Project modified to add transformer at new Horizon Substation instead of Sunset
External Project
Blue Lake-Gresham 230-kV Line
PGE plans to construct a transmission line from Blue Lake Substation (Troutdale, Oregon) to Gresham Substation (Gresham, Oregon). This project requires 4.2 miles of new 230-kV transmission line.
PGE BPA Project identified as future need
2017 External Project
Longview-Cowlitz 115kv #2
Create second 115kv connection between BPA Longview and BPA Cowlitz. This will be done by using existing Cowlitz 69kv circuit and converting to 115kv from BPA Longview through Washington Way and 7th ave substations and adding tap from 7th Ave to BPA Cowlitz.
Cowlitz BPA Project under Construction
2011 $5 million Reliability and Load growth Single System Project
Bakers Corner Create looped feed for Bakers Corner sub by tapping to BPA Longview to Lexington 115kv. Bakers Corner is currently radial from BPA Longview
Cowlitz BPA Project under study
2010 150000 Reliability and Load growth Single System Project
71
Western Region Projects
Project Name DescriptionSponsor
Parties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost EstimateProject Need/Driver & Other Notes
Changes from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Lebanon Area Reinforcement
Add a 19.6 MVAR, 115 kV shunt capacitor bank at Lebanon Substation
BPA Plan of service determined
Funding approved by sponsor
2010 $3 million Load Growth Changed plan from 230/115 Transformer
Single System
I-5 Corridor (SW Washington - NW Oregon Reinforcement)
Construct a new 500 kV line (approx. 70 miles) from Troutdale Substation to the new Castle Rock substation located approximately 12 miles north of Allston Substation on the Paul-Allston No.1 500 kV line.
BPA PAC Funding for NEPA and preliminary engineering is committed under NOS
Depends upon NEPA
2015 $300 million Transmission Service Requests
Requested Service Project
I-5 Corridor Regional Planning Study Team
Pearl – Sherwood 230 kV
PGE and BPA plan to re-terminate the existing double circuit operating in parallel between BPA’s Pearl Substation and PGE’s Sherwood Substation. This will require two new circuit breakers. When the project is completed, there will be a Pearl-Sherwood #1 230-kV circuit and a Pearl-Sherwood #2 230-kV circuit.
PGE and BPA
PGE and BPA Project identified as future need
2017 Reliability and Load growth Multi-system EOP with only one ColGrid participant
Chemawa 230/115 kV Transformer Bank
Add a new 230/115 kV Transformer at Chemawa Substation
BPA Cancelled Cancelled since project need is now beyond 10-year planning horizon
Single System
Cross-Cascades South Station K development connecting Ashe-Marion, Buckley-Marion and both John Day-Grizzly lines together at a new station where the lines cross is proposed.
BPA PGE, PAC Conceptual project for future need
2020 Load Growth Project schedule added Multi-system EOP with only one ColGrid participant
West of Cascades Study Team
Springville-Horizon 230 kV line
Add second source for Horizon substation PGE BPA Conceptual project for future need
Load Growth
Horizon 230/115-kV transformer
PGE plans to install a 230/115-kV, 320 MVA auto-transformers at Horizon Substation, located in Hillsboro, Oregon. This project requires construction of a new 230-kV transmission line from Sunset Substation to Horizon (approximately 1 mile).
PGE Connection to BPA via Keeler
2012 Project modified to add transformer at new Horizon Substation instead of Sunset
External Project
Blue Lake-Gresham 230-kV Line
PGE plans to construct a transmission line from Blue Lake Substation (Troutdale, Oregon) to Gresham Substation (Gresham, Oregon). This project requires 4.2 miles of new 230-kV transmission line.
PGE BPA Project identified as future need
2017 External Project
Longview-Cowlitz 115kv #2
Create second 115kv connection between BPA Longview and BPA Cowlitz. This will be done by using existing Cowlitz 69kv circuit and converting to 115kv from BPA Longview through Washington Way and 7th ave substations and adding tap from 7th Ave to BPA Cowlitz.
Cowlitz BPA Project under Construction
2011 $5 million Reliability and Load growth Single System Project
Bakers Corner Create looped feed for Bakers Corner sub by tapping to BPA Longview to Lexington 115kv. Bakers Corner is currently radial from BPA Longview
Cowlitz BPA Project under study
2010 150000 Reliability and Load growth Single System Project
72
Western Projects ContinuedWestern Region Projects
Project Name DescriptionSponsor
Parties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost EstimateProject Need/Driver & Other Notes
Changes from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Rogue SVC (South Oregon Coast)
Add a -45 to +50 MVAR, Static VAR Compensator (SVC) at Rogue Substation connected to the 115 kV bus
BPA under construction
2010 $9 million Southern Oregon Load growth - needs dynamic SVC control v. static caps.
Single System Project
South Oregon Coast Transmission Reinforcement
Construct a new 115 kV transmission line to provide a new source to the South Oregon Coast load area
BPA Project under study
2018 $30 million Load growth along southern Oregon coast
Project delayed from 2015 to 2018
Single System Project
Kalama Energy Construct new 230kv line from BPA Longview to Kalama. Line will be needed for either connection of the new Kalama Energy 680 MW gas turbine project and/or to provide for load growth in area.
Cowlitz Project under study Conceptual project for future need
2012-2018 $20 million Single System Project
Eugene-Albany Rebuild Rebuild a section of the Albany-Eugene 115 kV line with new structures and higher capacity conductor
BPA Plan of service determined
2011 To meet load growth projections and repair aging line
Single System Project
Longview-Lexington 115 kV line #2
Create a connection between BPA Longview and Lexington Substations through Cowlitz substations (Mint Farm, Olive Way, 20th and Ocean Beach and West Kelso).
Cowlitz Under Construction
2011-14 Reliability and Load growth Single System Project
Longview-Lexington-Cardwell 115 kv line
Create a connection between BPA Longview, Lexington, East Kelso and Cardwell substations through Cowlitz substations with a 115 kV connection between East and West Kelso.
Cowlitz Funding approved by sponsor
2014 Reliability and Load growth Single System Project
Trojan-Horizon 230 kV line
Provide additional capacity to move Port Westward and Beaver generation to Portland load area.
PGE Impacts to South of Allston
Project under study Waiting for requestor commitment
Transmission Service Request
Parish Gap Substation Construct a new 230/69 kV substation connected to the Bethel-Fry 230 kV line in the Albany area
PAC 2012 Reliability and Load growth Addition to Plan
White City 230/115 kV Transformer addition
Add a 230/115 kV substation in the Medford area fed from the Grants Pass-Meridian 230 kV line
PAC Project under study 2012 Reliability and Load growth Single System Project
Lookingglass substation New Lookingglass substation on Dixonville-Reston 230 kV line
PAC 2013 Reliability and Load growth
73
Western Region Projects
Project Name DescriptionSponsor
Parties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost EstimateProject Need/Driver & Other Notes
Changes from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Rogue SVC (South Oregon Coast)
Add a -45 to +50 MVAR, Static VAR Compensator (SVC) at Rogue Substation connected to the 115 kV bus
BPA under construction
2010 $9 million Southern Oregon Load growth - needs dynamic SVC control v. static caps.
Single System Project
South Oregon Coast Transmission Reinforcement
Construct a new 115 kV transmission line to provide a new source to the South Oregon Coast load area
BPA Project under study
2018 $30 million Load growth along southern Oregon coast
Project delayed from 2015 to 2018
Single System Project
Kalama Energy Construct new 230kv line from BPA Longview to Kalama. Line will be needed for either connection of the new Kalama Energy 680 MW gas turbine project and/or to provide for load growth in area.
Cowlitz Project under study Conceptual project for future need
2012-2018 $20 million Single System Project
Eugene-Albany Rebuild Rebuild a section of the Albany-Eugene 115 kV line with new structures and higher capacity conductor
BPA Plan of service determined
2011 To meet load growth projections and repair aging line
Single System Project
Longview-Lexington 115 kV line #2
Create a connection between BPA Longview and Lexington Substations through Cowlitz substations (Mint Farm, Olive Way, 20th and Ocean Beach and West Kelso).
Cowlitz Under Construction
2011-14 Reliability and Load growth Single System Project
Longview-Lexington-Cardwell 115 kv line
Create a connection between BPA Longview, Lexington, East Kelso and Cardwell substations through Cowlitz substations with a 115 kV connection between East and West Kelso.
Cowlitz Funding approved by sponsor
2014 Reliability and Load growth Single System Project
Trojan-Horizon 230 kV line
Provide additional capacity to move Port Westward and Beaver generation to Portland load area.
PGE Impacts to South of Allston
Project under study Waiting for requestor commitment
Transmission Service Request
Parish Gap Substation Construct a new 230/69 kV substation connected to the Bethel-Fry 230 kV line in the Albany area
PAC 2012 Reliability and Load growth Addition to Plan
White City 230/115 kV Transformer addition
Add a 230/115 kV substation in the Medford area fed from the Grants Pass-Meridian 230 kV line
PAC Project under study 2012 Reliability and Load growth Single System Project
Lookingglass substation New Lookingglass substation on Dixonville-Reston 230 kV line
PAC 2013 Reliability and Load growth
74
Eastern Projects Eastern Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other Notes
Changes from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Lower Valley Reinforcement (Hooper Springs)
This is a joint project with BPA, PacifiCorp, and Lower Valley Energy. PacifiCorp will construct Three Mile Knoll - a new 345/138 kV substation. The Goshen-Bridger 345 kV line will be looped-into the new substation. BPA will construct Hooper Springs - a new 138/115 kV substation. Lower Valley Energy will construct a new double circuit 115 kV line (approximately 20 miles) from Hooper Springs to Lanes Creek/Valley Substations.
BPA/ PAC/ Lower Valley Electric
construction on hold pending agreement
2013 $16 million for BPA portion
Load Growth in Eastern Idaho
Project delayed from 2012 to 2013
Multi-system EOP with only one ColGrid participant
COI Reinforcement (4800 MW)
This project includes 2-500 kV series capacitor groups added at Bakeoven; 2-500 kV shunt capacitor groups added at Captain Jack; and a 500 kV shunt capacitor group added at Slatt substation. This project also includes upgrading the John Day-Grizzly 500 kV lines No.1 & 2, and control and communications.
BPA Plan of service determined
Funding approved by sponsor
2012 $63 million
Remove nomogram limitations on COI
Capacity Increase Project
Redmond 230/115 kV Transformer Bank No.2
Add a second 230/115 kV transformer bank at Redmond substation.
BPA Plan of service determined
Funding approved by sponsor
2011 $12 million
Load growth in the area Single System Joint studies w/PAC, BPA and Central Electric Coop
McNary - John Day 500 kV line
Construct a new 500 kV line (approximately 79 miles) from McNary to John Day Substation
BPA Project Committed under Network Open Season
In permitting process
2013 $175 million
Transmission Service Requests
Requested Service Project
West of McNary Regional Planning Study Team
Big Eddy - Knight 500 kV line
Construct a new 500 kV line (approximately 29 miles) from Big Eddy to a new Knight Station, which connects to the Wautoma-Ostrander 500 kV line. (3 breaker ring bus)
BPA Funding for NEPA and preliminary Engineering is Committed under NOS
In permitting process
2013 $66 million
Transmission Service Requests
Knight Substation was formerly called Station Z.
Requested Service Project
West of McNary Regional Planning Study Team
Central Oregon 500/230 kV Transformer Bank Addition
Add a 500/230 kV transformer at Pilot Butte or Ponderosa.
BPA PAC Preliminary engineering and NEPA
Project identified as future need -
2014 Load growth and loss of the existing transformer
Transformer location could be Ponderosa or Pilot Butte
Multi-system EOP with only one ColGrid participant
Sandpiper Substation Add 500 kV Switchyard on the new John Day McNary 500 kV line where Ashe-Marion lines cross to integrate wind generation; also called Mercer Ranch
BPA Project Committed under Network Open Season
In permitting process
2014 Integrate wind generation Schedule changed from 2012 to 2014
Requested Service Project
75
Eastern Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other Notes
Changes from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Lower Valley Reinforcement (Hooper Springs)
This is a joint project with BPA, PacifiCorp, and Lower Valley Energy. PacifiCorp will construct Three Mile Knoll - a new 345/138 kV substation. The Goshen-Bridger 345 kV line will be looped-into the new substation. BPA will construct Hooper Springs - a new 138/115 kV substation. Lower Valley Energy will construct a new double circuit 115 kV line (approximately 20 miles) from Hooper Springs to Lanes Creek/Valley Substations.
BPA/ PAC/ Lower Valley Electric
construction on hold pending agreement
2013 $16 million for BPA portion
Load Growth in Eastern Idaho
Project delayed from 2012 to 2013
Multi-system EOP with only one ColGrid participant
COI Reinforcement (4800 MW)
This project includes 2-500 kV series capacitor groups added at Bakeoven; 2-500 kV shunt capacitor groups added at Captain Jack; and a 500 kV shunt capacitor group added at Slatt substation. This project also includes upgrading the John Day-Grizzly 500 kV lines No.1 & 2, and control and communications.
BPA Plan of service determined
Funding approved by sponsor
2012 $63 million
Remove nomogram limitations on COI
Capacity Increase Project
Redmond 230/115 kV Transformer Bank No.2
Add a second 230/115 kV transformer bank at Redmond substation.
BPA Plan of service determined
Funding approved by sponsor
2011 $12 million
Load growth in the area Single System Joint studies w/PAC, BPA and Central Electric Coop
McNary - John Day 500 kV line
Construct a new 500 kV line (approximately 79 miles) from McNary to John Day Substation
BPA Project Committed under Network Open Season
In permitting process
2013 $175 million
Transmission Service Requests
Requested Service Project
West of McNary Regional Planning Study Team
Big Eddy - Knight 500 kV line
Construct a new 500 kV line (approximately 29 miles) from Big Eddy to a new Knight Station, which connects to the Wautoma-Ostrander 500 kV line. (3 breaker ring bus)
BPA Funding for NEPA and preliminary Engineering is Committed under NOS
In permitting process
2013 $66 million
Transmission Service Requests
Knight Substation was formerly called Station Z.
Requested Service Project
West of McNary Regional Planning Study Team
Central Oregon 500/230 kV Transformer Bank Addition
Add a 500/230 kV transformer at Pilot Butte or Ponderosa.
BPA PAC Preliminary engineering and NEPA
Project identified as future need -
2014 Load growth and loss of the existing transformer
Transformer location could be Ponderosa or Pilot Butte
Multi-system EOP with only one ColGrid participant
Sandpiper Substation Add 500 kV Switchyard on the new John Day McNary 500 kV line where Ashe-Marion lines cross to integrate wind generation; also called Mercer Ranch
BPA Project Committed under Network Open Season
In permitting process
2014 Integrate wind generation Schedule changed from 2012 to 2014
Requested Service Project
76
Regional ProjectsRegional Projects
Project NameDescription Sponsor
Parties Impacted by Project
Link to More DetailProject Stage Project
Commitment Level
Scheduled Completion Cost Estimate
Project Need/Driver & Other Notes
Changes from Previous PlanPlan cross tribal lands
Type of Project Study Team(s)
PG&E Canada - Pacific Northwest – Northern California Transmission Line Project
PG&E is proposing an AC line from Selkirk substation in SE British Columbia to the Boardman/NEO area, along with an High Voltage DC line from the Boardman area to the Tesla/Tracy area in the San Francisco Bay area. The bi-directional capacity of this line is planned to be 3,000 MW. Interconnections to this project have been proposed at Devil's Gap, McNary and Round Mountain in Northern California.
PG&E BPA, PSE, PGE, PAC
In WECC Rating process in TCWG
2015 TCWG
Devil's Gap Interconnection to Canada - PNW – Northern California Transmission Line Project
In conjunction with the PG&E Canada-NW-Northern California Project, Avista is proposing an interconnection at Devil’s Gap west of Spokane.
Avista BPA In WECC Rating process in TCWG
2015 TCWG
Northern Lights Project Northern Lights Transmission is proposing a High Voltage Direct Current line beginning at Edmonton, Alberta and ending near Maupin, Oregon. At least one intermediate terminal is planned in a location south of Calgary, near Alberta’s largest wind development region. The project is planned to be a bi-directional line with an expected capacity of up to 3,000 MW. This project takes advantage of the diversities in load and generation between the two areas.
Northern Lights
BPA In WECC Rating process in TCWG
2014 TCWG
Juan de Fuca Cable Project #1
SeaBreeze Pacific is proposing an underwater 550 MW HVDC Light cable from Vancouver Island in BC to the Port Angeles WA area across the Strait of Juan de Fuca. This project rating is planned to be bi-directional.
SeaBreeze
BPA, PSE In WECC Rating process
TCWG
Juan de Fuca Cable Project #2
SeaBreeze Pacific is proposing an underwater HVDC cable from Prince Rupert (Northern BC) to Vancouver Island (SW BC) to Allston substation in NW Oregon near Rainier to San Francisco Bay area. This project has a planned capacity of 1600 MW.
SeaBreeze
BPA In WECC Rating process
TCWG
Wallula-McNary 230-kV line Project
PacifiCorp is building a 230-kV line from Wallula to McNary/Boardman/NEO area. This project may be extended to Walla Walla in the future.
PAC and Avista
BPA In WECC Phase 1 Rating process in TCWG
2012 Transmission Service Requests
TCWG
77
Regional Projects
Project NameDescription Sponsor
Parties Impacted by Project
Link to More DetailProject Stage Project
Commitment Level
Scheduled Completion Cost Estimate
Project Need/Driver & Other Notes
Changes from Previous PlanPlan cross tribal lands
Type of Project Study Team(s)
PG&E Canada - Pacific Northwest – Northern California Transmission Line Project
PG&E is proposing an AC line from Selkirk substation in SE British Columbia to the Boardman/NEO area, along with an High Voltage DC line from the Boardman area to the Tesla/Tracy area in the San Francisco Bay area. The bi-directional capacity of this line is planned to be 3,000 MW. Interconnections to this project have been proposed at Devil's Gap, McNary and Round Mountain in Northern California.
PG&E BPA, PSE, PGE, PAC
In WECC Rating process in TCWG
2015 TCWG
Devil's Gap Interconnection to Canada - PNW – Northern California Transmission Line Project
In conjunction with the PG&E Canada-NW-Northern California Project, Avista is proposing an interconnection at Devil’s Gap west of Spokane.
Avista BPA In WECC Rating process in TCWG
2015 TCWG
Northern Lights Project Northern Lights Transmission is proposing a High Voltage Direct Current line beginning at Edmonton, Alberta and ending near Maupin, Oregon. At least one intermediate terminal is planned in a location south of Calgary, near Alberta’s largest wind development region. The project is planned to be a bi-directional line with an expected capacity of up to 3,000 MW. This project takes advantage of the diversities in load and generation between the two areas.
Northern Lights
BPA In WECC Rating process in TCWG
2014 TCWG
Juan de Fuca Cable Project #1
SeaBreeze Pacific is proposing an underwater 550 MW HVDC Light cable from Vancouver Island in BC to the Port Angeles WA area across the Strait of Juan de Fuca. This project rating is planned to be bi-directional.
SeaBreeze
BPA, PSE In WECC Rating process
TCWG
Juan de Fuca Cable Project #2
SeaBreeze Pacific is proposing an underwater HVDC cable from Prince Rupert (Northern BC) to Vancouver Island (SW BC) to Allston substation in NW Oregon near Rainier to San Francisco Bay area. This project has a planned capacity of 1600 MW.
SeaBreeze
BPA In WECC Rating process
TCWG
Wallula-McNary 230-kV line Project
PacifiCorp is building a 230-kV line from Wallula to McNary/Boardman/NEO area. This project may be extended to Walla Walla in the future.
PAC and Avista
BPA In WECC Phase 1 Rating process in TCWG
2012 Transmission Service Requests
TCWG
78
Regional Projects continuedOlympic Peninsula Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other Notes
Changes from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Olympic Peninsula Reinforcement
Construct 14 miles of new double circuit 230 kV line from Olympia to Shelton. Loop-in the Olympia-Kitsap 230 kV line into Shelton. Remove the Olympia-Shelton No.1 115 kV line. The project also includes miscellaneous substation work at Shelton and Olympia.
BPA PSE Completed $26-million
Load growth and correct bus sectionalizing breaker issue
Project completed Existing Obligation Project
Olympia 230/115 kV Transformer Bank No.3
Add a new 230/115 kV Transformer at Olympia substation
BPA Conceptual Project for future need
2017 $7 million
Load Growth Project schedule changed from 2016 to 2017
Single System Project with possible impacts
Shelton-Fairmount-Port Angeles Area
Shelton-Fairmount 230 kV line No. 4 & 5 Construct a new double circuit 230 kV line (approximately 60 miles) between Shelton and Fairmount Substations
BPA Conceptual Project for future need
2022 $21.5 million
Load Growth Plan of service changed to double circuit and project schedule changed from 2016 to 2022
Single System Project
Olympic Peninsula Study Team
79
Olympic Peninsula Region Projects
Project Name Description SponsorParties Impacted by Project
Link to More Detail Project StageProject Commitment Level
Scheduled Completion
Cost Estimate
Project Need/Driver & Other Notes
Changes from Previous Plan
Plan cross tribal lands
Type of Project Study Team(s)
Olympic Peninsula Reinforcement
Construct 14 miles of new double circuit 230 kV line from Olympia to Shelton. Loop-in the Olympia-Kitsap 230 kV line into Shelton. Remove the Olympia-Shelton No.1 115 kV line. The project also includes miscellaneous substation work at Shelton and Olympia.
BPA PSE Completed $26-million
Load growth and correct bus sectionalizing breaker issue
Project completed Existing Obligation Project
Olympia 230/115 kV Transformer Bank No.3
Add a new 230/115 kV Transformer at Olympia substation
BPA Conceptual Project for future need
2017 $7 million
Load Growth Project schedule changed from 2016 to 2017
Single System Project with possible impacts
Shelton-Fairmount-Port Angeles Area
Shelton-Fairmount 230 kV line No. 4 & 5 Construct a new double circuit 230 kV line (approximately 60 miles) between Shelton and Fairmount Substations
BPA Conceptual Project for future need
2022 $21.5 million
Load Growth Plan of service changed to double circuit and project schedule changed from 2016 to 2022
Single System Project
Olympic Peninsula Study Team
