N-2NSPML (BW) RIRs 1-22 - Redacted
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- 1: Hardwoods 50 MW CT retired in 2022 - 2: Stephenville 50 MW CT retired in 2024 - 3: 1 x 50 MW CT added - 4: 2 x 50 MW CT added - 5: 3 x 50 MW CT added - 2: Portland Creek at 23 MW and new CCCT at 170 MW Added Beyond the evaluation of t...
AI summary The document discusses the retirement of several combustion turbines and the addition of new generation capacity, including a new CCCT. It highlights transmission planning considerations for integrating the Labrador – Island Link, including the need for a 230 kV transmission line and synchronous condensers to ensure system stability and reliability.
Date: 10-Apr-2012 Prepared by: Peter Anderson RELIABILITY & AVAILABILITY ASSESSMENT OF THE HVDC ISLAND LINK Revision
AI summary This document is a reliability and availability assessment of the HVDC Island Link, prepared by Peter Anderson on 10-Apr-2012. It appears to focus on evaluating the performance and reliability of the High Voltage Direct Current transmission system.
- 4 pole outages per year with a repair time of 21 hours per outage (FOR=0.98%) - 0.4 bipole outages per year with a repair time of 1.3 hours per outage (FOR=0.006%) The same source also provides information on the breakdown of forced ener...
AI summary The text discusses forced outages and forced energy unavailability (FEU) in converter stations, highlighting the impact of major components such as converter transformers and dc smoothing reactors. It also mentions that providing spare units improves station availability.
λ = Failure rate (1-phase) = 0.01 f/yr N = No. of Components = 6 R1 = Repair Time (replacement with spare) = 168 hrs R2 = Repair Time at Factory = 4380 hrs With no spare, Average outage time per pole = 0.01x3x4380 = 131 hrs/yr With one spa...
AI summary The text calculates the average outage time per pole for a system with and without spare components, showing that having a spare significantly reduces outage time. It also references CIGRE statistics on the impact of having spare transformer units and smoothing reactors in HVDC converter stations.
An electrode line will be provided at each converter station to connect to a remote ground electrode. These lines, under bi-pole mode, will carry only the unbalance current between the two poles of the dc line but will also be used at 150%...
AI summary The document discusses the design and reliability of electrode lines for a high-voltage direct current (HVDC) transmission system. It outlines the electrode line lengths, redundancy measures, and monitoring practices. It also provides failure rate assumptions based on CEA statistics and considers the impact of common-mode failures on system operation.
It has been shown that a linear relationship exists between these repair times and the unavailability of the Island Link. Once a target reliability has been decided on, the maximum repair time can be determined. The overall unavailability...
AI summary The text discusses the relationship between repair times and the unavailability of the Island Link, noting that repair times for submarine cables have minimal impact due to redundancy, but repair times for overhead line failures significantly affect overall unavailability. Repair times for single pole outages are estimated at 1.78 hours, while common-mode failures are assumed at 24 hours.
- 1) Nalcor Energy-Lower Churchill Project, :Basis of Design, Document LCP-PT-ED-0000-EN-RP-0001-O1. - 2) A Survey of the Reliability of HVDC Systems throughout the World during 2007 2008, M.G. Bennett, N.S.Dhaliwal, A. Leirbukt CIGRE 2010...
AI summary The document lists several references related to HVDC systems and reliability studies, including a survey of HVDC system reliability, a report on the Lower Churchill Project, and studies on iceberg risks to subsea cables in the Strait of Belle Isle.
NSPML Responses to Bates White Information Requests 1 ii. Explanation of the "software update" and why the update was needed. 11 iii. If the LIL had been able to operate at 900 MW as designed, would the timing 12 and/or duration of this ou...
AI summary NSPML responds to information requests regarding software updates and the impact of an outage on the LIL. The response clarifies that the requested relief is not related to the Muskrat Falls Generating Station or Maritime Link assets. NSPML notes that the LIL has been tested up to 900 MW and that its operability has been confirmed.
PARTIALLY CONFIDENTIAL 1 • Nova Scotians incurring 20 percent of the cost of the Lower Churchill Project to 2 secure 20 percent of the output. 3 4 NSPML reaffirms its belief that customers have received the collective contractual bargain 5...
AI summary NSPML asserts customers received the 'collective contractual bargain' post-LIL commissioning, emphasizing 35 years of renewable energy from the NS Block and its role in avoiding fossil fuel units. The NS Block's dispatchable energy supports system reliability and integration, with deferred energy fully delivered. NS Power plans increased use of dispatchability as wind capacity expands.
PARTIALLY CONFIDENTIAL 1 During this same period (May 2023 through August 2025) there was 612,500 MWh in the 2 Deferred Energy that was made up, 480,000 MWh of Supplemental Energy, and 1,480,000 3 in market energy purchased by NS Power; eq...
AI summary The document discusses energy deliveries and purchases by NS Power during May 2023 through August 2025, including Deferred Energy, Supplemental Energy, and market energy. It also references the Energy Access Agreement (EAA) and forecasts of future energy availability, noting that normalized hydrology levels are expected to increase energy deliveries beyond the 1.2 TWh average.
Page 1348 - lines 5 to 22 5 MR. OUTHOUSE: I take it that when you 6 modelled your economic analysis, you did not or did you 7 make an allowance for availability? 8 Mr. Sidebottom, can you help us with 9 that? 10 MR. SIDEBOTTOM: The model a...
AI summary The discussion revolves around the modeling of energy availability in the Maritime Link, with a focus on how interruptions are accounted for in the model. The model includes make-up provisions in contracts that compensate for unavailability, ensuring that energy is delivered at a later point in time, even if the interruption occurs in year 35.
Page 851 - lines 14 to 22 14 MR. YOUNGER: And I understand that 15 you're going to get the energy. My concern is you 16 know, we just had a fairly lengthy discussion about the 17 need to back up wind energy. And my concern is that you 18 s...
AI summary Mr. Younger expresses concern about the reliability of wind energy and the need for backup supply, emphasizing that energy shortages over short or extended periods must be addressed. Mr. Sidebottom responds by stating that the proposed Link will meet the 20 percent planning reserve and will be more reliable than the generator it replaces, citing typical forced outage rates for industry generators.
U.S. Hydropower Market Report
AI summary The U.S. Hydropower Market Report provides an overview of the hydropower sector, including industry trends, technological advancements, and regulatory considerations. It examines market dynamics, capacity utilization, and the role of hydropower in renewable energy integration.
U.S. Hydropower Market Report (January, 2021) Highlights In 2019, hydropower capacity (80.25 GW) accounted for 6.7% of installed electricity generation capacity in the United States and its generation (274 TWh) represented 6.6% of all elec...
AI summary In 2019, U.S. hydropower capacity (80.25 GW) accounted for 6.7% of total electricity generation capacity and produced 274 TWh, representing 6.6% of total U.S. electricity generation and 38% of renewable electricity generation.
U.S. hydropower capacity continues to grow through upgrades to existing plants and other types of innovative new projects. - » Hydropower capacity has increased by a net of 431 MW since 2017, with total net growth of 1,688 MW from 2010 to...
AI summary U.S. hydropower capacity grew by 431 MW since 2017, with 1,688 MW total growth from 2010-2019, driven by upgrades to existing plants, new conduit/canal projects, and non-powered dams (NPDs). As of 2019, 1,490 MW from 217 projects were in development, with 93% focused on NPDs and facility expansions.
FERC relicensing activity is set to more than double in the coming decade. » In the past decade, FERC issued 80 relicenses for 6.9 GW of hydropower capacity and 6.7 GW of PSH capacity (17% and 37% of FERC-licensed capacity, respectively)....
AI summary FERC relicensing activity is projected to more than double, with 281 facilities (4.7 GW hydropower and 9.1 GW PSH) up for relicensing between 2020-2029, compared to 80 licenses for 6.9 GW hydropower and 6.7 GW PSH issued in the past decade.
Introduction Chapter 1 — Looking Back: An Overview of Changes Across the U.S. Hydropower and PSH Fleet Chapter 2 — Looking Forward: Future U.S. Hydropower and PSH Development Pipeline Chapter 3 — U.S. Hydropower in the Global Context Chapt...
AI summary The introduction outlines a report covering U.S. hydropower and PSH (Pumped Storage Hydropower), including historical changes, future development, global context, price trends, cost metrics, supply chain trends, and new policies influencing the market.
Introduction This is the third complete edition of the U.S. Hydropower Market Report (the first two were the 2014 and 2017 Hydropower Market Report published in 2015 and 2018, respectively);1 , In intervening years between publishing the f...
AI summary This document introduces the third edition of the U.S. Hydropower Market Report, which compiles data on developments in hydropower and pumped storage hydropower (PSH) between 2017 and 2019. It highlights trends, regional differences, and updates on the U.S. and global hydropower development pipeline, as well as findings from the Department of Energy's HydroWIRES initiative.
Table ES-1. Summary of updated and new content by chapter Chapter New content 1 • Relicensing hydropower and PSH activity in the United States 3 • International comparison of hydropower permitting processes • International comparison of hy...
AI summary Table ES-1 summarizes updated and new content by chapter, focusing on topics such as relicensing hydropower, international permitting comparisons, revenue data for PSH plants, hourly ramping data, and new FERC policies influencing hydropower.
o NPDs and conduits. » Capacity added from new projects or upgrades to the existing fleet from 2010 to 2019 (2,225 MW) outweighed capacity reductions due to plant retirements or downrates (538 MW).10 5 A plant is defined as a facility cont...
AI summary From 2010–2019, U.S. hydropower capacity grew due to new projects and upgrades (2,225 MW added), exceeding losses from retirements (538 MW). In 2017–2019, 583 MW of new capacity was added, while 215 MW was lost through downrates. Wind surpassed hydropower as the largest U.S. renewable energy source in 2019 (300 TWh vs. 274 TWh).
RELICENSES AFFECT THE OPERATIONAL FLEXIBILITY OF THE U.S. HYDROPOWER FLEET A relicense extends the authorization to operate a hydropower project, subject to compliance with a set of terms and conditions agreed among the licensee and projec...
AI summary Relicensing hydropower projects can alter operational flexibility, with some requiring run-of-river operations (e.g., Claytor, Waterbury, Scotland) or turbine upgrades. While some relicenses restrict flexibility (e.g., ramping rate limits), others enhance it (e.g., Yards Creek PSH). Construction requirements often focus on environmental measures or recreational facilities.
Chapter 2 — Looking Forward: Future U.S. Hydropower and PSH Development Pipeline Figure ES-4. Hydropower project development pipeline by project type, region, size, and development stage (as of December 31, 2019) Sources: FERC eLibrary, U....
AI summary As of 2019, the U.S. hydropower development pipeline includes 217 projects totaling 1.49 GW, with significant capacity from retrofitting non-powered dams and existing facilities. 129 projects have federal authorization but no construction has started, highlighting delays in permitting and financing.
NUMBER OF PSH PROJECTS IN THE DEVELOPMENT PIPELINE INCREASED BY 31% IN 2019 – Sixty-seven new PSH projects with a total proposed capacity of 52.48 GW were in various stages of evaluation or development at the end 2019 (see Figure ES-5). Mo...
AI summary In 2019, the number of Pumped Storage Hydropower (PSH) projects in development increased by 31%, totaling 67 projects with 52.48 GW of proposed capacity. Pennsylvania, Arizona, and California led in project numbers (11, 10, and 7 respectively). Three existing projects will add 119 MW, and 21 states have at least one PSH project planned.
Chapter 3 — U.S. Hydropower in the Global Context GLOBAL HYDROPOWER CAPACITY REACHED 1,150 GW AT THE END OF 2019 — Eighty-four countries have more than 1 GW of installed hydropower capacity and the top six fleets (China, Brazil, European U...
AI summary Global hydropower capacity reached 1,150 GW by 2019, with the U.S. accounting for 7%. China leads, followed by other regions. PSH capacity is 158 GW, with the U.S. at 14%. The development pipeline includes 4,545 projects, mostly in Asia, Africa, and South America.
Chapter 5 — U.S. Hydropower Cost and Performance Metrics AFTER TWO YEARS OF HIGH DOMESTIC HYDROPOWER PRODUCTION (~300 TWH) IN 2017–2018, PRODUCTION RETURNED TO A LEVEL CLOSE TO THE 2003–2018 AVERAGE IN 2019 (274 TWH). Canadian imports cont...
AI summary U.S. hydropower production dropped to 274 TWh in 2019 after a peak of ~300 TWh in 2017–2018, with Canadian imports expected to rise due to U.S. renewable standards and new transmission capacity. Small hydropower plants (10–100 MW) had the highest O&M costs ($122/kW in 2018), which grew faster than inflation between 2016–2018. Figure ES-11 highlights O&M cost trends by plant size and age.
Chapter 6 — Trends in U.S. Hydropower Supply Chain THE U.S. HYDRAULIC TURBINE MARKET REMAINS DIVERSE AND ROBUST — Almost 12 GW of hydropower and PSH turbine capacity has been installed in the United States since 2010. Seventy-nine percent...
AI summary The U.S. hydropower turbine market has seen 12 GW of installations since 2010, with 79% focused on rehabilitating existing facilities. Five major manufacturers (American Hydro, Andritz, GE, Voith, Toshiba) dominate large turbine production, while Kaplan turbines dominate new low-head projects. The 2015–2019 trade balance was nearly neutral, with Canada and Mexico as top export destinations.
Chapter 7 — Overview of New Policies Influencing the U.S. Hydropower Market In October 2017, FERC announced a revised policy on license terms (for both original licenses and relicenses) in which the default term became 40 years. Neverthele...
AI summary In October 2017, FERC revised its license term policy to a default of 40 years, with flexibility for longer or shorter terms. The American Water Infrastructure Act of 2018 (AWIA) introduced an expedited licensing process for NPDs and PSH projects and mandated equal consideration of past and future investments in relicensing. States are increasing renewable and energy storage targets, which may boost investment in hydropower and PSH.
NSD new stream-reach development AWIA American Water Infrastructure Act of 2018 O&M operations and maintenance BA balancing authority PJM Pennsylvania–Jersey–Maryland BPA Bonneville Power Administration Interconnection CAISO California Ind...
AI summary The text outlines various acronyms and terms related to energy infrastructure and regulatory frameworks, including legislation, organizations, and technologies. It includes references to figures illustrating energy storage and hydropower capacity changes.
1.1 New Project Development and Capacity Changes (2010–2019) Hydropower capacity in the United States (excluding PSH) increased by 1,688 MW from 2010 to 2019. The net increase was primarily from capacity additions to the existing fleet, bu...
AI summary U.S. hydropower capacity (excluding PSH) increased by 1,688 MW (2010–2019), driven by 562 MW from 119 new plants and upgrades. PSH capacity rose from 20.5 GW to 21.9 GW, with upgrades at six plants, including Northfield Mountain (228 MW increase). Net gains occurred in all regions.
CALLIGAN CREEK The Calligan Creek hydropower plant started operation in 2018 in King County (Washington). The developer of this NSD, PUD No.1 of Snohomish County, submitted a license application in August 2013, and the Federal Energy Regul...
AI summary The Calligan Creek hydropower plant, a 6-MW run-of-river facility in Washington, began operation in 2018. Developed by PUD No.1 of Snohomish County, it received its FERC license in 2015 after construction started in 2014. The project includes a Pelton turbine, weir, fish ladder, and grid interconnection.
JAMES W. BRODERICK PLANT AT PUEBLO DAM In 2011, the Southeastern Colorado Water Conservancy District submitted a proposal to develop hydropower at Pueblo Dam in response to a call for applications by the U.S. Bureau of Reclamation (Reclama...
AI summary The Southeastern Colorado Water Conservancy District developed a 7.01 MW hydropower facility at Pueblo Dam after securing a lease of power privilege (LOPP) from the U.S. Bureau of Reclamation in 2017. The $20.2 million project, 85% funded by a low-interest loan, began operations in 2019 and includes 30-year power purchase agreements (PPAs) with local utilities.
RED ROCK HYDROELECTRIC PROJECT The Red Rock project in Marion County (Iowa) adds 36 MW of hydropower generation capability to the U.S. Army Corps of Engineers-owned Red Rock dam. FERC issued the license for this project to the Western Minn...
AI summary The Red Rock Hydroelectric Project in Iowa adds 36 MW of hydropower capacity to the U.S. Army Corps of Engineers' Red Rock dam. Licensed by FERC in 2011 to the Western Minnesota Municipal Power Agency, construction faced delays due to 2019 flooding but was completed in 2020, with commercial operation expected in 2021.
l fraction (7%) of the capacity added by FERC-licensed projects in the same period (see Figure 2 discussion), which indicates most of the additions were authorized through capacity license amendments. For most projects with relicenses issu...
AI summary From 2010–2019, most relicensed hydropower projects maintained their operational modes (e.g., peaking or run-of-river), though some faced mandatory changes (e.g., run-of-river operation for water quality compliance). Others, like Yards Creek PSH, gained flexibility through relicensing terms. FERC-licensed projects accounted for 7% of capacity additions during this period.
2. Looking Forward: Future U.S. Hydropower and PSH Development Pipeline This chapter presents a snapshot of the U.S. hydropower and PSH development pipeline as of the end of 2019. It describes the following pipeline attributes: regional di...
AI summary This chapter provides an overview of the U.S. hydropower and pumped storage hydropower (PSH) development pipeline as of 2019, detailing regional distribution, project types, sizes, developer types, and project development stages.
2.1. U.S. Hydropower Development Pipeline At the end of 2019, there were 217 hydropower projects with a total proposed capacity of 1.49 GW in the U.S. development pipeline. The U.S. hydropower development pipeline includes 88 NPD projects...
AI summary As of December 31, 2019, the U.S. hydropower development pipeline included 217 projects with a total proposed capacity of 1.49 GW. These projects consist of 88 non-powered dams (NPD), 109 conduit projects, 8 new site developments (NSD), and 12 capacity additions. NPD and capacity additions account for 93% of the proposed capacity, with high attrition rates in early development stages.
2.2 U.S. PSH Development Pipeline At the end of 2019, there were 67 PSH projects in the development pipeline distributed across 21 states. Three of these projects had FERC authorization; all three are in the western half of the United Stat...
AI summary As of December 31, 2019, 67 U.S. PSH projects were in development, with three FERC-authorized projects in the western U.S. and three existing plants undergoing upgrades. 80% of proposed PSH facilities are in states with renewable energy targets exceeding 50%, driven by variable renewable penetration and energy storage demand. California, Nevada, New York, New Jersey, and Virginia have set energy storage targets of at least 1,000 MW, with PSH eligible to meet these, though California imposes a 50 MW size limit.
3. U.S. Hydropower and PSH in the Global Context This chapter describes the existing global hydropower and PSH fleets and summarizes international trends in hydropower development as well as R&U to the existing fleets. This chapter serves...
AI summary This chapter provides an international context for U.S. hydropower and pumped storage hydropower (PSH) development, detailing global fleets, refurbishment/upgrades (R&U), and trends. It updates previous reports, separates hydropower and PSH metrics, and introduces new sections comparing international permitting and incentives influencing regional investment levels.
3.1 Description of the Existing Fleets The U.S. fleet represents 7% of global hydropower capacity and 14% of global PSH capacity. On average, U.S. installed capacity grew at 0.2% per year for hydropower and 0.7% for PSH in the past decade....
AI summary The text compares global hydropower and PSH (Pumped Storage Hydropower) capacity growth between the U.S. and China, noting China's significantly higher growth rates. It highlights that 70 countries have over 1 GW of hydropower capacity, with China, the EU, Brazil, the U.S., Canada, and Russia accounting for two-thirds of global hydropower capacity. Data sources include IHA (2020) and EIA.
3.2 International Trends in Hydropower and PSH Development
AI summary This section examines global developments in hydropower and pumped storage hydropower (PSH), highlighting trends, technologies, and policy frameworks influencing their adoption and integration into energy systems worldwide.
3.2.1 Development Pipeline by Region The global development pipeline by the end of 2019 includes 4,545 hydropower projects and 284 PSH projects with total capacities of 414 GW and 226 GW, respectively. Asia accounted for 75% of the combine...
AI summary The global hydropower and PSH development pipeline by 2019 included 4,545 hydropower and 284 PSH projects, with Asia accounting for 75% of potential capacity. China led in construction, while the U.S. and Canada had smaller pipelines with high attrition rates in early stages. East Asia dominated PSH development, with 104 GW in the pipeline.
Table 2. Top 20 Countries by Proposed Hydropower and PSH Capacity in the Development Pipeline Country Hydropower Proposed (MW) China 92,937 India 41,995 Nepal 30,361 Pakistan 28,860 Myanmar 25,782 Indonesia 24,227 Bhutan 19,244 Ethiopia 12...
AI summary Table 2 presents the top 20 countries by proposed hydropower and pumped storage hydropower (PSH) capacity in the development pipeline, highlighting China as the leading country in both categories, followed by India and the United States.
al hydropower expenditure and at least 20% of PSH expenditures . 19 United States and Canada and Russia are the only two regions with larger tracked expenditures for PSH than hydropower. More than 90% of global expenditures are directed to...
AI summary Global hydropower and PSH investments focus on new plant development, with over 90% of expenditures directed toward new projects. The U.S. and Canada lead in R&U spending, while IIR data highlights limited PSH tracking. Asian regions dominate hydropower expansions, and the U.S.-Canada PSH fleet is the oldest globally.
3.2.4 International Comparison of Hydropower Incentives A combination of feed-in tariffs, tax incentives, and renewable energy tradable credits support small hydropower development in many jurisdictions around the world. In recent years, d...
AI summary The text discusses international hydropower incentives, noting the use of feed-in tariffs, tax incentives, and tradable credits for small hydropower. Large projects, such as PSH, are often government-supported or receive loans in some countries, unlike in the U.S. Table 3 summarizes government support mechanisms across regions.
Table 3. Summary of National (or Regional) Incentives for New Hydropower Installations in Selected Countries (as of December 31, 2019) Country Hydropower Incentives Category Australia Feed-in tariff (≤100 kW, Victoria) Austria Feed-in tari...
AI summary Table 3 summarizes national and regional incentives for new hydropower installations in selected countries as of December 31, 2019. It includes various mechanisms such as feed-in tariffs, tax incentives, grants, and long-term capacity contracts, with specific details on eligibility and implementation at different levels (national and provincial).
The wholesale prices shown in Figure 23 represent prices being paid to other nonfederal electricity producers in the same region. The Mid-Columbia hub offers a relevant comparison with BPA's hydropower prices because it corresponds to the...
AI summary The text compares wholesale electricity prices across regions, noting similarities in price trends from 2006-2018 driven by macroeconomic factors. Key drivers include abundant low-cost natural gas and wind capacity growth in the Pacific Northwest and SPP territory. Regional differences in energy mix and hydrology influence price levels, with specific references to WAPA, SWPA, and SEPA marketing areas.
CORPORATE (AND OTHER NON-UTILITY) PPAS FOR U.S. HYDROPOWER International Renewable Energy Agency (2018) estimates that more than half of the 465 TWh of renewable electricity used by corporations worldwide comes from hydropower which is lar...
AI summary The text discusses the limited role of hydropower in current U.S. corporate PPA trends, contrasting historical industrial reliance on hydropower with recent solar/wind dominance. Examples include Microsoft's 50 MW hydropower agreement with Chelan County and Apple's 2014 acquisition of a 3 MW hydro project for a data center.
Chapter 5 U.S. Hydropower and PSH Cost and Performance Metrics
AI summary Chapter 5 focuses on U.S. hydropower and pumped storage hydropower (PSH) cost and performance metrics, referencing a figure that likely illustrates key data points. The section appears to analyze financial and operational benchmarks for these technologies.
5.1.1 Hydropower Approximately $3 billion have been invested in new hydropower plant construction since 2005. Average capital costs were in the $4,000/kW-$5,000/kW range for the various project types, but there was large variability around...
AI summary The text details $3 billion in U.S. hydropower investments since 2005, with capital costs ranging from $2,500/kW to $7,500/kW. Factors like project type, capacity, and hydraulic head influence costs. Low-head projects (avg. $5,059/kW) are more expensive than medium/large-head projects. Small facilities dominate new developments, explaining higher per-kW costs compared to global averages.
5.2 Operations and Maintenance Costs In the past two years, O&M costs grew fastest for small plants ( ≤ 10 MW), which already have by far the highest cost per kilowatt installed per year. Because it has no fuel purchase costs, hydropower h...
AI summary The text discusses operations and maintenance (O&M) costs for U.S. hydropower and pumped storage hydropower (PSH) plants, noting that small plants (≤10 MW) have the highest O&M costs per kilowatt. Hydropower's minimal variable costs are highlighted, with O&M costs typically expressed as annual fixed costs. Figure 35 illustrates trends by plant size and age, sourced from FERC Form 1 and the Bureau of Labor Statistics.
5.3.1 Hydropower Generation and Canadian Imports After two years of high domestic hydropower production (~300 TWh) in 2017–2018, production returned to a level close to the 2003–2018 average in 2019 (274 TWh). Canadian imports contributed...
AI summary Domestic hydropower production in the U.S. decreased from ~300 TWh (2017–2018) to 274 TWh in 2019, returning to the 2003–2018 average. Canadian imports contributed 35–45 TWh of hydroelectricity and are projected to rise in the 2020s due to renewable standards, new Canadian capacity, and U.S.-Canada transmission projects. Regional U.S. hydropower generation showed stability in the Northwest and Northeast but high variability in the Southwest.
5.4 Capacity Factors On average, the median nationwide capacity factor from 2005 to 2018 has been 39%. Hydrological and market conditions, as well as plant-level variables (mode of operation, outage schedule, multipurpose constraints), exp...
AI summary The median nationwide hydropower capacity factor from 2005 to 2018 was 39%, influenced by hydrological conditions, market factors, and plant-specific variables. Figure 40 illustrates annual capacity factor distributions, showing extremes linked to droughts in the Pacific Northwest and California, with 2015 experiencing the lowest capacity factor (33.9%) due to prolonged drought conditions.
forced outages over the period considered in Figure 43; for medium and large units, the trend is slight but average forced outage hours have almost doubled for small units. Figure 43. Average hydropower outage hours by outage type and unit...
AI summary The text analyzes forced outage trends in hydropower units (small, medium, large) from 2009–2018, highlighting differences in causes (e.g., generator components vs. external events like floods). WECC's hydropower units had lower availability factors compared to other NERC regions, despite higher synchronization hours. Data is sourced from NERC's GADS system.
, it does convey the idea of a large range of ramping behaviors across BAs and the very robust result of large average ramps and wider ranges, at the hourly frequency, for hydropower (including PSH) . Out of the 11 BAs with average hourly...
AI summary The text analyzes hourly ramping behaviors of hydropower across Balancing Authorities (BAs), noting that 11 BAs have average hourly ramps exceeding 5% of installed capacity. These include federal hydropower managed by PMAs and systems with PSH or irrigation-dependent hydropower, which exhibit low ramping frequencies due to seasonal water storage.
Variable renewable penetration does not help explain cross-sectional variability in average one-hour ramps across the BAs. Variable renewable energy (solar and wind) penetration is another BA attribute that is useful to investigate in rela...
AI summary The analysis finds no strong correlation between variable renewable energy penetration and cross-sectional variability in average one-hour hydropower ramps across balancing authorities (BAs). Only one of 11 BAs with high hydropower ramping has significant solar/wind penetration. Sub-hourly ramp data, critical for flexibility products, remains uncomputable with available hourly data.
5.6.3 Contribution to Provision of Ancillary Services With increasing variable renewable energy penetration, maintaining the reliability and resilience of the grid, which is underpinned by various ancillary services and dispatchable genera...
AI summary Hydropower's flexibility and ancillary service capabilities are critical for grid reliability with high renewable penetration. While hydropower offers rapid startup, black start, and voltage control, constraints like multi-purpose dams and water availability limit its operational flexibility. PJM and EIA data highlight its technical advantages but note challenges in prioritizing electricity generation.
In ISO-NE, at least two thirds of hydropower capacity receive uplift revenue and provide reserves and voltage control. Market data from ISOs/RTOs help document hydropower's versatility in the provision of grid services. Figure 53 shows how...
AI summary In ISO-NE, two-thirds of hydropower capacity receives uplift revenue for grid services like reserves and voltage control. Market data shows hydropower's role in spinning reserves, regulation, and black start capabilities, with trends linked to solar/wind penetration and NERC standard revisions. Figure 53 (FERC Electric Quarterly Report) illustrates service provision from 2008-2017.
zed reserve resources are online units that follow economic dispatch and are only partially loaded. They must be able to increase output within 10 minutes following PJM dispatcher request to an event. 85 In 2018, hydropower and PSH contrib...
AI summary The text highlights that hydropower and pumped storage hydropower (PSH) contribute significantly to PJM and CAISO's frequency regulation and reserve products, with specific percentages (7.5% in 2018, 6.8% and 5.4% in 2019) for synchronized primary reserve. Data is sourced from the PJM State of the Market Report.
lexibility is the ability of the new units in Ludington PSH to run in pumping mode for a wider range of elevations of its upper reservoir. As for examples of improvements in environmental performance: - » the new turbines for the High Rock...
AI summary The text highlights flexibility in Ludington PSH units and environmental improvements in hydropower projects, such as aeration systems, fish-friendly turbine designs, and use of assessment tools. Examples include High Rock and Center Hill plants, Chelan PUD's Rock Island, and USACE's Ice Harbor, with a 2019 study confirming reduced fish risks.
6.2 Hydropower and PSH Turbine Imports/Exports For 2015–2019, the U.S. hydraulic turbine trade balance was very close to zero ($279 million imports and $263 million exports). In the past five years, the top three countries from which the U...
AI summary The U.S. hydropower turbine trade balance between 2015–2019 was nearly balanced, with China, Canada, and Brazil as top importers and Canada/Mexico as primary exporters. The Harmonized Tariff Schedule enables detailed tracking of turbine trade, though some small hydropower equipment lacks specific classification.
Chapter 7 Overview of New Policies Influencing the U.S. Hydropower Market
AI summary Chapter 7 provides an overview of new policies influencing the U.S. hydropower market, though the specific content of the chapter is not detailed in the provided text. The chapter likely examines regulatory, legislative, or market-driven changes impacting hydropower operations and development.
7. Overview of New Policies Influencing the U.S. Hydropower Market This chapter discusses policy changes that occurred in the past three years (2017 – 2019 ) that modified the permitting processes for hydropower or / and the incentives ava...
AI summary This section outlines U.S. policy changes (2017–2019) impacting hydropower, including FERC's 40-year license term policy, the AWIA 2018, EPA's Section 401 rules, FERC's PURPA modernization proposal, and state renewable mandates. These aim to streamline permitting, enhance PSH investment, and align with clean energy goals.
Table 4. U.S. Jurisdictions with 100% Renewable or Clean Energy Mandates or Goals State Target Year Target Type Policy Document Rhode Island 2030 Renewable Energy Mandate EO 20-01 Washington D.C. 2032 Renewable Energy Mandate B22-0904 New...
AI summary This table lists U.S. states and jurisdictions with renewable or clean energy mandates or goals, including target years and policy documents. It highlights the progress toward 100% clean energy in these regions as of 2019.
Note: For states in which the mandate is set through legislation, only one of the two bills (House or Senate) is cited in the table. Seven states have adopted energy storage targets, and many others are considering introducing them. PSH is...
AI summary Seven states have adopted energy storage targets, with PSH typically eligible but sometimes excluded due to target structures. As variable renewables increase, energy storage policy support has grown, leading to mandates and targets. Massachusetts has a Clean Peak Energy Standard requiring clean peak energy certificates, with energy storage eligible if they use clean energy most of the time.
s explicitly eligible in 6 RPSs (although typically only to the extent that the energy used for pumping water to the upper reservoir is renewable) and explicitly excluded from seven RPSs (Stori, 2020) 109 In Virginia, the energy storage ma...
AI summary The text discusses energy storage targets in seven states, including Virginia's Clean Economy Act and limitations on pumped storage (PSH) eligibility. California restricts PSH to 50 MW, while other states have early target years or small targets, making PSH impractical for compliance.
Some legislation and other state-level initiatives focus on PSH. Virginia enacted HB 1760 in 2017, which encourages PSH development in its coalfield region by authorizing utilities to obtain a rate adjustment clause for cost recovery if th...
AI summary The text discusses state-level initiatives and legislation in Virginia, Oregon, and California related to pumped storage hydropower (PSH). Virginia enacted laws to encourage PSH development and support research. Oregon passed a resolution to promote closed-loop PSH. California approved a reference system portfolio requiring significant PSH and battery storage by 2026, with specific projects highlighted.
8. External Reviewer Recommendations Regarding Future Reports As in previous editions of the Hydropower Market Report, this document has benefitted from significant review and input from a diverse set of external reviewers. Not only have r...
AI summary External reviewers recommended future analyses on hydropower R&D trends, unit outage causes, operational pattern changes, hydrologic metrics, and capital expenditure drivers. These topics aim to enhance understanding of innovation, reliability, market adaptations, and investment priorities in hydropower and pumped storage.
erhard, A., and R. Naude. 2016. "The South African Renewable Energy Independent Power Producer Procurement Programme: A Review and Lessons Learned." Journal of Energy in South Africa 27, no.4: 1–14. European Small Hydropower Association. 2...
AI summary The text references studies and reports on hydropower, renewable energy programs, regulatory processes, and environmental considerations, including South African IPP procurement, European small hydropower, FERC licensing, fish passage in the Columbia River, Bonneville Power Administration's flexible assets, drought analysis, hydropower rights in Europe, and black start resources.
Front Cover Image Red Rock Hydroelectric Project, Marion County, IA (image courtesy of Missouri River Energy Services)
AI summary The front cover image displays the Red Rock Hydroelectric Project in Marion County, IA, credited to Missouri River Energy Services. The image is part of the regulatory proceeding document's introductory materials.
Figure 4.6 Setup of the WRF model simulations (The WRF4km domain is shown as the white rectangle and the two green rectangles show the two WRF500m domains) –EFLA (2021) The proposed load combinations of "Wind and Ice" and "Ice and Wind" as...
AI summary The document discusses the proposed load combinations of 'Wind and Ice' and 'Ice and Wind' used in the WRF model simulations, referencing CSA 60826-10 standards for ice load values and return periods.
Quarterly Report on Asset Performance in Support of Resource Adequacy for the Twelve Months Ended December 31, 2025 - ensure alignment with the assumptions used in the resource planning model (PLEXOS) 12 1 while - 2 appropriately reporting...
AI summary The report discusses the methodology for calculating forced outage rates for various generating units, including the use of historical data and scenario-based approaches, and outlines the planned retirement of certain units by 2030. It also mentions the impact of the Labrador Island Transmission Link (LIL) commissioning on future forced outage rate assumptions.
Table 3: DAFOR and DAUFOP Overview (%) Asset Type Measure 1-Jan-2024 to 31-Dec-2024 1-Jan-2025 to 31-Dec-2025 Near-Term Planning Analysis Value Resource Planning Analysis Value Hydraulic: Regulated DAFOR 2.07 0.36 2.50 3.03 Hydraulic: Musk...
AI summary Table 3 provides an overview of DAFOR and DAUFOP values for different asset types from 2024 to 2025, including near-term and resource planning analysis values. The data highlights variations in outage rates for hydraulic and thermal assets, such as the Muskrat Falls Facility and Happy Valley.
- 5 performance improved for the current period, when compared to the previous period. - 6 The DAUFOP performance for the Happy Valley GT and the Hardwoods and Stephenville GTs has - 7 improved for the current period, while the Holyrood CT...
AI summary Performance metrics for various generating units and the Labrador Island Transmission Link (LIL) have improved in the current period compared to the previous period, with the exception of the Holyrood CT, which saw a decline. The LIL's performance has improved, with no significant impacts to the EqFOR due to operational events.
Table 4: EqFOR Overview (%) 1-Jan-2024 to 1-Jan-2025 to Base Planning Analysis Range of Planning Analysis Asset Type Measure 31-Dec-2024 31-Dec-2025 Value Values LIL EqFOR 3.37 0.9616 5 1–10 15 The resource planning model does not differen...
AI summary Table 4 presents an overview of the Equivalent Forced Outage Rate (EqFOR) for the Labrador Island Transmission Link (LIL) from 2024 to 2025, showing a decrease in the EqFOR value from 3.37 to 0.9616, with a base planning analysis value of 5 and a range of 1–10. It notes that the resource planning model does not differentiate between DAFOR and DAUFOP.
Table 5: Hydraulic Weighted DAFOR – Regulated Hydro Maximum Continuous Unit Rating 12 Months Ended Dec 2024 12 Months Ended Dec 2025 Near-Term Analysis Value Resource Planning Analysis Value Generating Unit (MW) (%) (%) (%) (%) All Hydraul...
AI summary Table 5 presents the Hydraulic Weighted DAFOR (Derated Adjusted Forced Outage Rate) for regulated hydro units, showing the maximum continuous unit rating and outage rates for various units over different time periods, including 12 months ended December 2024 and 2025, as well as near-term and resource planning analysis values.
3 Hydraulic Unit DAFOR Performance – Muskrat Falls - 4 Detailed results for the current period and the previous period are presented in Table 6 and Chart 2. - 5 These results are compared to Hydro's near-term and resource planning analysis...
AI summary This section presents detailed results for the current and previous periods regarding the hydraulic unit DAFOR performance at Muskrat Falls. The results are compared to Hydro's near-term and resource planning analysis values for forced outage rates, as used in the 2024 Resource Plan and the November 2025 Near-Term Report. Overall, plant performance has improved, though individual units not meeting established values are discussed.
Table 6: Hydraulic Weighted DAFOR – Muskrat Falls Generating Unit Maximum Continuous Unit Rating (MW) 12 Months Ended Dec 2024 (%) 12 Months Ended Dec 2025 (%) Near-Term Analysis Value (%) Resource Planning Analysis Value (%) Muskrat Falls...
AI summary Table 6 presents the Hydraulic Weighted DAFOR (Derated Adjusted Forced Outage Rate) for Muskrat Falls generating units, showing the percentage of forced outages for different time periods and analyses. The data highlights variations in outage rates across the units and timeframes.
6.0 Thermal Unit DAFOR Performance - 7 Detailed results for the current and previous periods are presented in Table 7 and Chart 3. These results - 8 are compared to Hydro's near-term and resource planning analysis values for forced outage...
AI summary This section discusses the DAFOR (Derated Adjusted Forced Outage Rate) performance of thermal units, comparing current and previous period results to Hydro's near-term and resource planning analysis values used in the 2024 Resource Plan and the November 2025 Near-Term Report. Units exceeding established values are addressed.
10 Combustion Turbine DAUFOP Performance - 11 DAUFOP Performance for the Hardwoods, Stephenville and Happy Valley GTs, as well as the Holyrood CT - 12 for the period, are presented in the charts and tables below. - 13 The combined DAUFOP f...
AI summary The DAUFOP performance for several combustion turbines, including those at Hardwoods, Stephenville, and Happy Valley, as well as the Holyrood CT, is reported. The combined DAUFOP for Hardwoods and Stephenville GTs was 2.76%, significantly below the near-term and resource planning assumption of 30.00%.
Table 10: Holyrood CT DAUFOP CT Unit Maximum Continuous Unit Rating (MW) 12 Months Ended Dec 2024 (%) 12 Months Ended Dec 2025 (%) Near-Term Planning and Resource Planning Analysis Value (%) Holyrood 123.5 0.00 25.13 4.90
AI summary Table 10 presents the DAUFOP (Derated Adjusted Utilization Forced Outage Probability) for the Holyrood Combustion Turbine (CT) unit, showing a significant increase in the 12-month ended December 2025 from 0.00% to 25.13%, with a near-term planning and resource planning analysis value of 4.90%.
NON-CONFIDENTIAL 1 Request IR-22: 2 3 Please refer to Exhibit N-1, Attachment 1, page 35 lines 10-12. Did the Witness quantify the 4 "value" of the Muskrat Falls assets to "customers?" If so, please provide that analysis and 5 supporting w...
AI summary The request (IR-22) inquires whether the witness quantified the value of Muskrat Falls assets to customers. The response clarifies no quantitative analysis was conducted, but qualitative benefits such as fuel price stability and reduced fossil fuel exposure were highlighted as key customer advantages.
N-4NSPML (IG) RIRs 1-26 - Redacted
26 passages
NSPML Responses to Industrial Group Information Requests 1 Request IR-02: 26 for the Holdback and reconcile this with the Board's prior findings 1 regarding the realignment of benefits of the Maritime Link with costs 2 in connection with t...
AI summary NSPML responds to an information request regarding the Holdback and realignment of benefits from the Maritime Link with costs in connection with FLG2. NSPML provides a figure for 2025 and explains that FLGII refinancing costs are a reprofiling of previously incurred costs, influenced by the delayed start of the NS Block and the impact of the war in Ukraine.
This version of the pro forma Large Generator Interconnection Agreement (LGIA) reflects the following changes: Updated as of August 20, 2024 (2/15/2018) Revised Article 9.6.2.1 – Governors and Voltage Regulators New Article 9.6.4 – Primary...
AI summary This document outlines updates to the pro forma Large Generator Interconnection Agreement (LGIA), including revised articles related to governors, voltage regulation, frequency response, and technical standards for wind generating plants, as well as amendments to definitions and dispute resolution processes.
characterized by an energy source that: (1) is renewable; (2) cannot be stored by the facility owner or operator; and (3) has variability that is beyond the control of the facility owner or operator. Withdrawal Penalty shall mean the penal...
AI summary The text defines a renewable energy source with specific characteristics (renewable, non-storable, and variability beyond control) and outlines the 'Withdrawal Penalty' for interconnection customers under the Large Generator Interconnection Procedures (LGIP), referencing Section 3.7.1 for calculation details.
quipment errors or malfunctions that require the attention and/or correction by the other Party. The Party owning such equipment shall correct such error or malfunction as soon as reasonably feasible. - 8.3 No Annexation. Any and all equip...
AI summary The text outlines obligations for equipment maintenance and data provision in interconnection agreements. It specifies that equipment ownership remains with the providing party and requires Variable Energy Resource (VER) owners to supply meteorological and outage data to Transmission Providers for accurate power forecasting.
INTERCONNECTION REQUIREMENTS FOR A WIND GENERATING PLANT Appendix G sets forth requirements and provisions specific to a wind generating plant or a Generating Facility that contains a wind generating plant. All other requirements of this L...
AI summary Appendix G outlines specific interconnection requirements for wind generating plants, while other provisions of the Large Generator Interconnection Agreement (LGIA) remain applicable. This ensures comprehensive guidelines for integrating wind energy into the grid.
A. Technical Standards Applicable to a Wind Generating Plant
AI summary This section outlines technical standards applicable to wind generating plants, including compliance with regulatory requirements and industry guidelines. It references relevant organizations, acronyms, and potential topics related to grid integration and renewable energy infrastructure.
s development, more submarine power cable projects are economically viable, or even possible. New applications for submarine power cables appear while known applications are pursued on a larger scale. Submarine power cables draw the attent...
AI summary The text highlights growing interest in submarine power cables driven by offshore wind projects, new applications, and involvement from diverse stakeholders including engineers, investors, regulators, and environmental groups. Cable costs and installation challenges are critical factors, with regulators and authorities increasingly engaged due to rising permit applications.
1.3 Offshore Wind Farms Offshore wind farms (OWP) consists of a number of wind turbine generators (WTG). The distance between the WTGs is 300–800 m. A grid of submarine cables interconnects the WTG and bring the power to shore. The in-fiel...
AI summary Offshore wind farms (OWP) use wind turbine generators (WTG) spaced 300–800 m apart, connected via submarine cables. Medium-voltage cables (10–36 kV) transmit power to shore for short distances, while high-voltage (HVDC) systems are used for longer distances due to lower losses. HVDC requires offshore and onshore converter stations, which are costly but necessary for large-scale projects.
1.4 Supply of Marine Platforms Production platforms in the offshore oil and gas business have a large power demand to extract hydrocarbons from wells. Energy use covers a range of activities including driving pumps to extract hydrocarbons...
AI summary Offshore oil and gas platforms require significant power for operations, often generated via low-efficiency onboard systems. Connecting platforms to onshore grids via submarine cables is becoming viable as power demands grow, with Norway’s example highlighting CO2 reduction potential through hydropower integration.
With the Conform ® Extrusion process, shaped wires can be made without cold working resulting in better conductivity values than those for compressed round wires. The resulting profile wire conductor may have a smaller conductor than a com...
AI summary The Conform® Extrusion process allows for the production of shaped wires with better conductivity than compressed round wires. Cable purchasers prioritize resistivity over cross-sectional area, and submarine cables are often custom-made to meet specific resistance requirements, with non-standard cross-section sizes frequently used.
2.2.1 Polyethylene Polyethylene is a hydrocarbon consisting of long chains of CH3–(CH2)n–CH3 molecules. It contains nothing but carbon and hydrogen. The chains may be branched or not. The material is nonpolar and semicrystalline. It is the...
AI summary Polyethylene is a hydrocarbon with long chains of CH3–(CH2)n–CH3 molecules. It is nonpolar, semicrystalline, and thermoplastic. It is used for electric insulation in various forms, including LDPE, MDPE, and HDPE, with applications in high-voltage cables. However, its use in submarine cables is uncertain.
2.7 Two-Core Cables Two-core cables have been used for HVDC systems where two conductors naturally occur. A development of the Mollerhoj cable has two fully insulated cable cores in a common lead sheath and has been used for the Danish par...
AI summary Two-core cables are used in HVDC systems, such as the KontiSkan and NorNed links, offering advantages like magnetic field cancellation. They operate with opposing voltages or through sea electrodes. Future applications include 6-phase AC systems for offshore wind power, minimizing magnetic losses in steel armor.
t been tried yet. The reach of unrepeatered data transmission in increasing steadily. At standard data transmission rates of 5 or 10 GB/s for each fibre, repeater-less links can cover 200 km and more. In-field cables in OWP's are made as t...
AI summary The text discusses the integration of optical fibers in submarine power cables, including three-core medium-voltage cables for offshore wind parks (OWP) and single-core cables. It highlights placement methods, material considerations (e.g., stainless steel tubes, plastic sheaths), and trade-offs between fiber counts, data transmission needs, and maintenance practices.
, presented by Cigré Working Group 21 as Session Paper 21-12 at the 1986 Cigré Session, Paris, France. - 41. Elgh L et al. (1982). Repair of 400 kV ac Submarine Cable. Paper 21-05, Cigré Session 1982. - 42. Galloway S J et al. (1990). 150...
AI summary The text lists technical references discussing power transmission technologies, including submarine cables, offshore windfarm connections, and electric cable systems. These sources are cited in the context of engineering research and historical developments in electrical infrastructure.
Table 3.5 Dielectric properties of high-voltage cable insulation materials. $\tan \delta$ is depending on the temperature. A more comprehensive list is in Chap. 12. IEC 60287 Dielectric loss factor tan $\boldsymbol{\delta}$ Dielectric cons...
AI summary Table 3.5 outlines the dielectric properties of high-voltage cable insulation materials, including the dielectric loss factor (tan δ) and dielectric constant (ε_r) for materials like XLPE and oil/paper. Dielectric losses increase with voltage and are significant for high-voltage cables but can be neglected for XLPE cables under 127 kV.
3.1.3.3 Cyclic or Variable Loads Most submarine power cables are operated with varying load, which is often below the rated power transmission. These cables are under-utilized during certain periods, and the operator might be interested in...
AI summary The text discusses managing variable loads in submarine power cables, emphasizing cyclic load patterns and IEC 60853 methods for overload calculations. It highlights opportunities for higher short-term ampacity during low-load periods and smaller conductor sizes with guaranteed load patterns. Offshore wind parks (OWPs) are noted for variable loads, with thermal considerations for unburied cables lacking ambient soil thermal reserves.
3.1.4 The 2 K Criterion The prospective of a massive installation of offshore wind parks triggered a discussion of the heating of the seafloor. Environmentalists and authorities mainly in Germany advocate a limitation of the expected warmi...
AI summary The 2 K Criterion discusses environmental concerns regarding seafloor warming from offshore wind parks. German authorities and environmentalists advocate limiting temperature increases above submarine cables to 2 K. The text outlines calculation methods for steady-state conditions and cable installation configurations, referencing depth measurements (0.2 m and 0.3 m).
7.1.3 Loading and Logistics Submarine cables with short length can be handled and transported on standard or oversize drums. Most standard and all oversized drums require flatbed trailers making the onshore transport expensive. When the su...
AI summary The text discusses challenges in transporting and installing submarine cables for offshore wind parks, comparing methods like pre-cut drums versus coils. It highlights risks of damage during loading, the need for synchronized equipment, and the importance of proper cable sealing to prevent water intrusion. Logistics costs and efficiency are emphasized, particularly for long cable lengths.
7.1.7.3 Vessel Movement The next question is how different vessels react to a given wave spectrum. The response is not only depending on vessel size but also on its design and equipment. For each CLV a RAO (Response Amplitude Operator) can...
AI summary This section discusses how different vessels, particularly cable laying vessels (CLVs), respond to wave spectra, emphasizing the importance of vessel design, size, and parameters like the Response Amplitude Operator (RAO) in predicting movements. The RAO is critical for translating wave characteristics into vessel heave, pitch, and roll, which affect laying operations.
References - 1. Lawrence M (2002). Submarine Cable Industry, -Alcatel Survey Standards and Future Trends. MUC Kiel, 2002. - 2. Hoshina R (2001). Improvements in Submarine Cable System Protection, SubOptic 2001. - 3. Shapiro S, Murray J, et...
AI summary The references discuss technical aspects of submarine cables, including protection, reliability, installation, and environmental factors, citing industry standards, risk assessments, and case studies from various experts and organizations.
9.2.4.2 Windfarm Export Cable For a hypothetic OWP export cable the reliability of five different a.c. cable configurations is compared in [7]. Three-core and single-core systems have been investigated for a fictive 60 km 1000 MW power exp...
AI summary A hypothetical offshore wind park (OWP) export cable system is analyzed, comparing the reliability of five different AC cable configurations. A 275 kV single-core system with seven individual cables was found to have the lowest failure rate at 0.15 failures per year and cable.
Voltage (kV) 132 220 400 275 400 cable type 3-core 3-core 3-core SC SC No of cables for 1000 MW transmission 6 4 2 7 (1 spare) 4 (1 spare) Failures/year and cable 0.25 0.46 0.67 0.15 0.22 Table 9.3 Failure rates for different cable schemes...
AI summary Table 9.3 presents failure rates for different cable schemes used to connect a large offshore wind park (OWP) at various voltage levels. The table compares the number of cables required and their corresponding failure rates per year.
gases from the manufacturing are taken care of in the factory according to local regulations but might contribute to air toxicity. Later, during operation, no more by-products will be released into the atmosphere or water. XLPE cannot be r...
AI summary The text discusses environmental considerations of XLPE and thermoplastic polyethylene used in cable manufacturing. XLPE is non-recyclable but can be incinerated safely, while thermoplastic polyethylene offers environmental benefits like recyclability. Carbon-black filled polymers used in semiconducting layers are difficult to recycle and have no known replacements.
ergy Depletion and Global Warming, and almost on a par in Photochemical Ozone Creation. Only in the category Water Eutrophication the Cu/Pb cable is more environmentally friendly than the Al/Al cable. The radar plot of Fig. 10.1 has been e...
AI summary The text compares the environmental impact of different types of cables, noting that Cu/Pb cables are more environmentally friendly in terms of water eutrophication compared to Al/Al cables. It discusses material choices for armoring and filler materials in submarine power cables, emphasizing cost and ecological considerations. It also highlights that HVDC cables can transmit more power per unit of material compared to three-phase AC cables.
Table 10.4 ICNIRP Guidelines for magnetic fields Occupational exposure Public exposure 0 Hz (d.c. cables) 200,000 μT 40,000 μT 50 Hz (a.c. cables) 500 μT 100 μT 60 Hz (a.c. cables) 417 μT 83 μT have been raised on the impact of d.c. magnet...
AI summary The document discusses the ICNIRP guidelines for magnetic fields and mentions studies on the impact of HVDC cables on submarine organisms, particularly fish. Research by the Swedish Fishery Authority found that some fish species, including eels, are not significantly affected by the magnetic fields from HVDC cables.
1. Deschamps L et al. (1980). Development in France of High Voltage Cables with Synthetic Insulation, Paper Cigré 21–06. A Assembly time, 112 Emergency cutter, 170 Fluid-filled cable, 113, 125 Ems River, 6 Force EN 50307, 31, 129 dynamic,...
AI summary The document discusses the development of high-voltage cables with synthetic insulation in France, referencing technical details such as assembly times, cable types, environmental considerations, and various engineering terms related to cable design and performance.