Pacific DC Intertie (PDCI) Upgrade Outage / De-Rate Schedule 2014

Total Page：16

File Type：pdf, Size：1020Kb

Pacific DC Intertie (PDCI) Upgrade Outage / De-Rate Schedule 2014

Version No. Pacific DC Intertie (PDCI) Upgrade 10 POWER SYSTEM Effective Outage / De-rate Schedule 2014-2016 1/12/2016 Date: Introduction The upcoming scheduled outages due to major upgrades on the Pacific DC Intertie (PDCI) will result in reduced available capacity on the line during various periods from 2014 to 2016. Most of the upgrades are convertor station and line work by the Bonneville Power Administration (BPA) to modernize its infrastructure at the Celilo Converter Station, which is the northern terminal of the PDCI. Other work will be performed by the Los Angeles Department of Water and Power (LADWP) in conjunction with the upgrades. Scheduling MW Capacity The schedule below will be updated as outages are scheduled. Start Date End Date Direction Scheduling Capacity (MW) June 28, 2015 October 3, 2015 North – South 1956 HE21 HE3 South – North 975 October 3, 2015 January 20, 2016 North – South 0 HE4 HE24 South – North 0 January 21, 2015 North – South 29901 HE1 South – North 975 From October 3, 2015 to January 21, 2015, the Celilo‐Sylmar Pole 3 1000kV Line and Celilo‐Sylmar Pole 4 1000kV Line will be removed from service and the PDCI will not be available [0MW (N‐S) and 0MW (S‐ N)]. Version Version Revised By Date 1 Document Creation OASIS Group 09/22/2014 2 Corrected outage information OASIS Group 10/14/2014 3 Corrected outage information OASIS Group 10/15/2014 4 Updated outage information OASIS Group 10/16/2014 5 Updated outage information OASIS Group 11/03/2014 6 Updated outage information OASIS Group 12/23/2014 7 Updated outage information OASIS Group 01/09/2015 8 Updated outage information OASIS Group 08/26/2015 Updated PDCI capacity after 12/21/2015 from 3220MW to 9 OASIS Group 09/17/2015 2990MW. 10 Updated outage information OASIS Group 1/12/2016 1 At the completion of testing, the PDCI is expected to be available for 2990‐MW until further notice. A new higher number is expected following Peak RC approval and is not expected until in 2016. Page 1 of 1 .

Copy Link

Recommended publications

The History of High Voltage Direct Current Transmission*
47 The history of high voltage direct current transmission* O Peake† Power Systems Electrical Engineer, Collingwood, Victoria SUMMARY: Transmission of electricity by high voltage direct current (HVDC) has provided the electric power industry with a powerful tool to move large quantities of electricity over great distances and also to expand the capacity to transmit electricity by undersea cables. The fi rst commercial HVDC scheme connected the island of Gotland to the Swedish mainland in 1954. During the subsequent 55 years, great advances in HVDC technology and the economic opportunities for HVDC have been achieved. Because of the rapid development of HVDC technology many of the early schemes have already been upgraded, modernised or decommissioned. Very little equipment from the early schemes has survived to illustrate the engineering heritage of HVDC. Conservation of the equipment remaining from the early projects is now an urgent priority, while the conservation of more recent projects, when they are retired, is a future challenge. 1 INTRODUCTION technology for the valves to convert AC to DC and vice versa. At the beginning of the electricity supply industry there was a great battle between the proponents In the late 1920s, the mercury arc rectifi er emerged of alternating current (AC) and direct current as a potential converter technology, however, it was (DC) alternatives for electricity distribution. This not until 1954 that the mercury arc valve technology eventually played out as a win for AC, which has had matured enough for it to be used in a commercial maintained its dominance for almost all domestic, project. This pioneering development led to a industrial and commercial supplies of electricity number of successful projects.
[Show full text]
Advanced Transmission Technologies
Advanced Transmission Technologies December 2020 United States Department of Energy Washington, DC 20585 Executive Summary The high-voltage transmission electric grid is a complex, interconnected, and interdependent system that is responsible for providing safe, reliable, and cost-effective electricity to customers. In the United States, the transmission system is comprised of three distinct power grids, or “interconnections”: the Eastern Interconnection, the Western Interconnection, and a smaller grid containing most of Texas. The three systems have weak ties between them to act as power transfers, but they largely rely on independent systems to remain stable and reliable. Along with aged assets, primarily from the 1960s and 1970s, the electric power system is evolving, from consisting of predominantly reliable, dependable, and variable-output generation sources (e.g., coal, natural gas, and hydroelectric) to increasing percentages of climate- and weather- dependent intermittent power generation sources (e.g., wind and solar). All of these generation sources rely heavily on high-voltage transmission lines, substations, and the distribution grid to bring electric power to the customers. The original vertically-integrated system design was simple, following the path of generation to transmission to distribution to customer. The centralized control paradigm in which generation is dispatched to serve variable customer demands is being challenged with greater deployment of distributed energy resources (at both the transmission and distribution level), which may not follow the traditional path mentioned above. This means an electricity customer today could be a generation source tomorrow if wind or solar assets were on their privately-owned property. The fact that customers can now be power sources means that they do not have to wholly rely on their utility to serve their needs and they could sell power back to the utility.
[Show full text]
2002 ABB ELECTRIC UTILITY CONFERENCE HVDC Technologies
2002 ABB ELECTRIC UTILITY CONFERENCE PAPER IV – 3 POWER SYSTEMS HVDC Technologies – The Right Fit for the Application Michael P. Bahrman ABB Inc. 1021 Main Campus Dr. Raleigh, NC 27606 Abstract: Traditional HVDC transmission has often provided economic solutions for special transmission applications. These include long-distance, bulk-power transmission, long submarine cable crossings and asynchronous interconnections. Deregulated generation markets, open access to transmission, formation of RTO’s, regional differences in generation costs and increased difficulty in siting new transmission lines, however, have led to a renewed interest in HVDC transmission often in non-traditional applications. HVDC transmission technologies available today offer the planner increased flexibility in meeting transmission challenges. This paper describes the latest developments in conventional HVDC technology as well as in alternative HVDC transmission technologies offering supplemental system benefits. Keywords: HVDC, DC, CCC, VSC, PWM, RTO, Asynchronous, HVDC Light I. INTRODUCTION Economic signals arising from deregulation of the generation market have led developers and transmission providers alike to follow the path of least resistance much like the power flow over the network on which their mutual business interests rely. On the generation side, the developer has invoked a quick-strike strategy siting units where there is convergence of low-cost fuel supplies, relative ease of permitting, water supply, ready access to transmission and proximity to load. On the transmission side, the transmission provider has been preoccupied with cost reduction, compensation for stranded assets, potential under-utilization of assets and reacting to evolving regulatory mandates. Although such development may result in a short-term gain in new, economic power resources, the long term benefit is not all that clear.
[Show full text]
Wind Power Transmission from Energy Rich North Dakota to California Through HVDC Lines
Session 2433 A Novel Solution for California’s Energy Crisis: Wind Power Transmission from Energy Rich North Dakota to California through HVDC Lines Recayi Pecen William Leighty Electrical & Information The Leighty Foundation-Alaska Engineering Technology Program University of Northern Iowa Abstract This paper first investigates feasibility of establishing a 7,000 MW power capacity wind farm, and the conversion of the total AC electrical power of 4,000 MW to the DC in a large converter station in Olga, North Dakota. Then it includes transmission of this bulk power to Northern California through a 1,700 miles, two bipolar +500 kV, 2,000A high voltage DC (HVDC) lines. The study assumes that there exists an average AC electrical power of 4,000 MW generated through two wind farms located in Olga, ND with 10,000 MW capacity. An existing wind capacity factor (CF) of 40%, which shows actual or predicted output as a % of installed capacity, is considered for this study. Two wind farms are considered to be established at Olga 3 and Olga 5 locations with average wind data available by North Dakota Department of Commerce - Division of Community Services. The commercially available North Dakota wind resource alone is estimated at over 1,000 TWh (billion kWh) per year. Dakotas wind energy potential is very stranded allover the land. Manitoba HVDC Research Center’s PSCAD /EMTDC power system software is used for the system modeling and simulation studies of the proposed HVDC scheme. Overall, the researchers determined that it is feasible and economical to establish a total power capacity of 10,000 MW from two new wind farms including 5,000MW at Olga 3, and other 5,000MW at Olga 5 wind sites, both are located in the north east corner of North Dakota, and one large 4,000 MW AC to DC converter station in Olga 5, and to transfer this DC power to the Northern California by HVDC lines.
[Show full text]
Upgrading the Intermountain HVDC Project to Handle 480 MW Additional Wind Power
21, rue d’Artois, F-75008 PARIS B4-108 CIGRE 2012 http : //www.cigre.org Upgrading the Intermountain HVDC Project to handle 480 MW additional Wind Power Mohammed J. Beshir Hans Bjorklund Los Angeles Department of Water and Power ABB USA Sweden SUMMARY The Intermountain Power Project, Southern Transmission System (IPP STS) was built in the early 80’s and commissioned in 1986 to bring power from a 1600 MW coal-fired generating plant in Utah to Southern California. The original project comprised of one bipole with 1600 MW ±500 kV continuous rating, meeting (N-1) reliability criteria. IPP STS had a very unique short-time overload rating allowing one pole to run at 2.3 p.u. current for few seconds before ramping down to operate continuously at 1.5 p.u. current (1200 MW power) should one pole trip [1]. To achieve this large overload on one pole all redundant cooling equipment for the transformers and the valves were used. The reactive consumption increased for the overloaded pole, but the full reactive power compensation for the bipole was available for that single pole. Some of this overload capability was used in 1989 when the bipole was up-rated to 1920 MW. To advance California’s environmental policies, in 2005 Los Angeles initiated an aggressive renewable resource development program to reach a 20% renewable portfolio standard (RPS) by 2010 (which was later supplemented with 35% RPS by 2020 and 30% CO2 reduction by 2030). One possible source for additional renewable resources was the wind power potential of southern Utah.
[Show full text]
OO-\EP-\B DATE AUG 0 1 2008 the STATE of CALIFORNIA Reed
DOCKET OO-\EP-\B DATE AUG 0 1 2008 THE STATE OF CALIFORNIA REeD. AUG 0 4 2008 BEFORE THE : ••t CALIFORNIA ENERGY COMMISSION In the Matter qf: ) ) . Preparation of the ) Docket No. 08-IEP-IB 2008 Integrated Energy Policy Report ) Update and the 2009 Integrated ) Energy Policy Report ) POST WORKSHOP COMMENTS OF THE CALIFORNIA MUNICIPAL UTILITIES ASSOCIATION, IMPERIAL IRRIGATION DISTRICT, LOS ANGELES DEPARTMENT OF WATER AND POWER, AND THE SACRAMENTO MUNICIPAL UTILITY DISTRICT . Pursuant to the Notice of Staff Workshop on Transmission Issues for 33% Renewables by 2020, the California Municipal Utilities Association and certain of its member utilities, the Imperial Irrigation District ("IID"), Los Angeles Department of Water and Power ("LAPWP"), and the Sacramento Municipal Utility District ("SMUD") (collectively "Joint Commentors"), respectfully submit these Post-Workshop Comments on issues regarding transmission infrastructure development to meet renewable energy goals. CMUA is a statewide organization of local public agencies in California that provide water, gas, and electricity service to California consumers. CMUA membership includes 43 electric distribution systems and other public agencies directly involved in the electricity industry. 1 CMUA members, including those listed above, own and operate CMUA electric utility members iilclude the Cities of Alameda, Anaheim, Azusa, Banning, Burbank, Cerritos, Colton, Corona, Glendale, Healdsburg, Lodi, Lompoc, Los Angeles, Needles, Palo Alto, Pasadena, Rancho Cucamonga, Redding, Riverside, Roseville, Santa Clara, and Vernon, as well as the Imperial, Merced, Modesto, Turlock Irrigation Districts, the Northern California Power Agency, Southern California Public Power Authority, Transmission Agency of Northern California, Lassen Municipal Utility District, Power and Water Resources Pooling Authority, Sacramento Municipal Utility District, the Trinity and Truckee Donner Public Utility Districts, the Metropolitan Water District of Southern California, and the City and COlmty of San Francisco, Hetch-Hetchy.
[Show full text]
Sylmar Converter Station Turns 50
Sylmar Converter Station Turns 50 By Christy Holland Fifty years ago, LADWP celebrated the completion of the 846-mile Pacific DC Intertie (PDCI) and the launch of the Sylmar Converter Station—a state-of-the-art power transmission facility. The Sylmar Converter Station is the southern anchor of the PDCI, which is a high-voltage, direct current transmission power line that originates at the Celilo Converter Station in The Dalles, Oregon. Today, the station has not only withstood the test of time; it remains just as relevant and vital as when it received its first megawatt in 1970. “When the PDCI was first completed, it was the longest and highest voltage DC line in the United States,” said Robert Fick, Manager, Hydro & Renewable Generation/High Voltage Stations, Power Supply Operations Division. “Nothing of this magnitude had been built before, so there was a lot of risk in taking on a project of this size.” Giant thyristors at Sylmar Converter Station. Photo by Chris Corsmeier Flash forward 50 years and the PDCI is still the longest DC line in the United States and in North America. While it is no longer the highest voltage DC line, it can boast that its southern anchor, the Sylmar Converter Station, has recently increased its capacity from 3,100 megawatts (MW) to 3,220 MW following a $223 million facility upgrade. This modernization project was designed to extend the facility’s lifespan for 40 more years, ensuring continued reliability of power transmission between the two regions. Think of the PDCI as a high-voltage electric superhighway and the Sylmar Converter Station as a transfer hub.
[Show full text]
9.1.1 Topical Responses
FINAL ENVIRONMENTAL IMPACT REPORT GRAYSON REPOWERING PROJECT RESPONSE TO COMMENTS March 1, 2018 9.1.1 Topical Responses A number of comments received on the Draft EIR focused on several main issues and topics associated with the Project and the CEQA analysis of Project impacts. Because of this, the City of Glendale determined it would be appropriate, and would facilitate public review, to provide topical responses to address these comments and provide the necessary context for considering the issues raised. The main issues and topics warranting topical responses are provided in full, below, and include the following: Table 9-2 Topical Responses Topics Topical Response No. Glendale is Pursuing Both Increased Use of Renewables and Continued 1 Reliability of Electricity at Reasonable Rates Relationship between Integrated Resource Plan and Project 2 Project Need 3 Project Alternatives 4 Renewable Energy 5 Deferring the Repowering 6 Demand Management 7 Air Quality and Public Health 8 Greenhouse Gas Emissions 9 Liquefaction 10 Relationship to Biogas Project 11 Environmental Justice 12 Puente Power Project 13 LADWP Moratorium on Rebuilding of Gas Plants 14 Comments Requesting an Independent Consultant 15 Groups of Similar Comments 16 9.25 FINAL ENVIRONMENTAL IMPACT REPORT GRAYSON REPOWERING PROJECT RESPONSE TO COMMENTS March 1, 2018 9.1.1.1 Topical Response No. 1: Glendale is Pursuing Both Increased Use of Renewables and Continued Reliability of Electricity at Reasonable Rates Summary of Comments Comments were received stating that Glendale should not put “all of its eggs in one basket” by single-mindedly pursuing the construction of a large, gas-fired plant when alternative, green technologies are available and are continuing to develop.
[Show full text]
Regional Energy Deployment System (Reeds) Model Documentation
Regional Energy Deployment System (ReEDS) Model Documentation: Version 2019 Maxwell Brown, Wesley Cole, Kelly Eurek, Jon Becker, David Bielen, Ilya Chernyakhovskiy, Stuart Cohen, Will Frazier, Pieter Gagnon, Nathaniel Gates, Daniel Greer, Sai Sameera Gudladona, Jonathan Ho, Paige Jadun, Katherine Lamb, Trieu Mai, Matthew Mowers, Caitlin Murphy, Amy Rose, Anna Schleifer, Daniel Steinberg, Yinong Sun, Nina Vincent, Ella Zhou, and Matthew Zwerling National Renewable Energy Laboratory NREL is a national laboratory of the U.S. Department of Energy Technical Report Office of Energy Efficiency & Renewable Energy NREL/TP-6A20-74111 Operated by the Alliance for Sustainable Energy, LLC March 2020 This report is available at no cost from the National Renewable Energy Laboratory (NREL) at www.nrel.gov/publications. Contract No. DE-AC36-08GO28308 Regional Energy Deployment System (ReEDS) Model Documentation: Version 2019 Maxwell Brown, Wesley Cole, Kelly Eurek, Jon Becker, David Bielen, Ilya Chernyakhovskiy, Stuart Cohen, Will Frazier, Pieter Gagnon, Nathaniel Gates, Daniel Greer, SaiSameera Gudladona, Jonathan Ho, Paige Jadun, Katherine Lamb, Trieu Mai, Matthew Mowers, Caitlin Murphy, Amy Rose, Anna Schleifer, Daniel Steinberg, Yinong Sun, Nina Vincent, Ella Zhou, and Matthew Zwerling National Renewable Energy Laboratory Suggested Citation Brown, Maxwell, Wesley Cole, Kelly Eurek, Jon Becker, David Bielen, Ilya Chernyakhovskiy, Stuart Cohen et al. 2020. Regional Energy Deployment System (ReEDS) Model Documentation: Version 2019. Golden, CO: National Renewable Energy Laboratory. NREL/TP-6A20-74111. https://www.nrel.gov/docs/fy20osti/74111.pdf. NREL is a national laboratory of the U.S. Department of Energy Technical Report Office of Energy Efficiency & Renewable Energy NREL/TP-6A20-74111 Operated by the Alliance for Sustainable Energy, LLC March 2020 This report is available at no cost from the National Renewable Energy National Renewable Energy Laboratory Laboratory (NREL) at www.nrel.gov/publications.
[Show full text]
2008 Annual Report of the Western Electricity Coordinating Council's
2008 Annual Report of the Western Electricity Coordinating Council’s Transmission Expansion Planning Policy Committee ___________________ Part 3 Western Interconnection Transmission Path Utilization Study An analysis of Path Flows and Schedules on the WECC Transmission System during 2007 Historical Analysis Work Group April 2009 TABLE OF CONTENTS I. INTRODUCTION ------------------------------------------------------------------------------------ 1 II. OBJECTIVE OF STUDY -------------------------------------------------------------------------- 2 III. ANALYSIS METHODOLOGY ------------------------------------------------------------------ 2 Nomenclature ------------------------------------------------------------------------------------ 2 WECC Paths Analyzed ------------------------------------------------------------------------ 3 Methodology --------------------------------------------------------------------------------------- 6 Historical Actual Flow Data -------------------------------------------------------------------- 7 Historical Schedule Data ----------------------------------------------------------------------- 7 POR POD Mapping Process ------------------------------------------------------------------ 8 Other Historical Data ---------------------------------------------------------------------------- 9 Congestion Indices ----------------------------------------------------------------------------- 10 OTC/TTC Assumptions ------------------------------------------------------------------------ 10 WECC Scheduling and OASIS Posting
[Show full text]
Montana's Electric Transmission and Distribution Grid
Montana’s Electric Transmission and Distribution Grid The electric transmission and distribution grid serves the vital function of moving power from generating plants to customers and their electric loads (demand).49The grid reliably provides this service even when individual elements of the transmission grid are out of service. Ownership and the rights to use the transmission system are complex matters. The use is further complicated by line congestion on in-state and interstate lines. The methods by which electricity flows on the lines is changing over time. Electric transmission also faces increasing regulation at the national level, new markets at the regional level, and increasing amounts of variable generation on the system. The construction of new in state and out-of-state transmission lines to expand the capacity of the current grid and make new Montana power generation possible also provides a challenge, raising questions about property rights, economic development, and whether new lines are actually needed. Basics of the Grid • Transmission lines are high voltage lines, usually 69 kV and above, that deliver electricity over long distances. The power on these lines is usually stepped down to a lower voltage to serve demand. Distribution lines are those lines that are smaller than 69 kV and deliver power directly to cities, homes, and businesses. Transmission lines are typically seen on large metal or wooden structures high above the ground. Distribution lines are typically found in neighborhoods and along highways on much smaller wooden poles. • NorthWestern Energy runs the largest transmission balancing area in Montana. The Bonneville Power Administration operates a large system in the northwest part of the state.
[Show full text]
Major WECC Remedial Action Schemes (RAS) Used in Standard PRC-004-WECC-1 (Revised September 19, 2007)
Table Major WECC Remedial Action Schemes (RAS) Used in Standard PRC-004-WECC-1 (Revised September 19, 2007) Path Name* Path RAS 1. Alberta – British PathNumber 1 Remedial actions are required to achieve the rated Columbia transfer capability. Most involve tripping tie lines for outages in the BCTC system. East to West: For high transfers, generation tripping is required north of the SOK cutplane in Alberta. 2. Northwest – British Path 3 Generator and reactive tripping in the BCTC Columbia system to protect against the impact caused by various contingencies during transfers between British Columbia and the Northwest. 3. West of Hatwai Path 6 Generator dropping (Libby, Noxon, Lancaster, Dworshak); Reactor tripping (Garrison); Tripping of Miles City DC link. 4. Montana to Northwest Path 8 Tripping Colstrip by ATR (NWMT); Switching shunt reactors at Garrison 500 kV; Tripping the back-to-back DC tie at Miles City; Tripping Libby, and Noxon generation by WM-RAS (BPA). 5. Idaho to Northwest Path 14 Generator Runback at Hells Canyon; Jim Bridger tripping for loss of Midpoint – Summer Lake 500 kV line. 6. Midway-Los Banos Path 15 CDWR and PG&E pump load dropping north of Path 15. PG&E service area load dropping north of Path 15. PG&E service area generation dropping south of Path 15. 7. Idaho Sierra Path 16 Automatic load shedding is required when the Alturas line is open for loss of the Midpoint-Humbolt 345 kV line during high Sierra system imports. 8. Bridger West Path 19 Jim Bridger tripping for delayed clearing and multi-line faults; Addition of shunt capacitors at Jim Bridger, Kinport and Goshen and series capacitor bypassing at Burns.
[Show full text]