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Blackstone Acquires Natural Gas Plant In Virginia’S Data Center Alley
POWER Engineering
Blackstone Acquires Natural Gas Plant In Virginia’S Data Center AlleyBlackstone Energy Transition Partners have agreed to acquire a natural-gas plant in Virginia’s “Data Center Alley,” the latest example of private investment at the intersection of power generation digital infrastructure. The Potomac Energy Center is a 774 MW natural gas-fired power plant in Loudoun County, Virginia. The northern area of the state represents approximately 25 percent of U.S. data center capacity, and the Potomac plant is located close to over 130 data centers – with significant further growth expected.“We are particularly excited about this investment given the opportunity to supply reliable, baseload power to the region,” said Mark Zhu, Managing Director at Blackstone Energy Transition Partners. “Potomac is one of the most efficient gas power plants in the region and has the potential to integrate a hydrogen fuel blend in the future, which could provide future environmental benefits.” After years of flat load growth on the U.S. grid, electricity demand has increased due to several factors – notably industrial onshoring, widespread electrification and the adoption of AI data centers. Data centers are perhaps the largest driver of this growth, as demand for computing power, fueled by artificial intelligence and other new technologies, requires enormous amounts of power.  According to some estimates, data centers are projected to consume 5% to 9% of U.S. electricity generation annually by 2030, up from 4% today. This surging growth is providing more opportunities for investors, especially in natural gas-fired generation. “Many independent power producers (IPPs) and private equity funds are looking to gain exposure to gas fired generation portfolios with the belief that growing power demand will improve their economics,” according to Scott Wilmot, Vice President of Power & Renewables at Enverus. Blackstone is the largest data center investor in the world, with major investments in Northern Virginia and beyond. The firm recently made major investments in AI companies CoreWeave and DDN. Terms of the transaction to acquire the Potomac plant were not disclosed. Santander and Jefferies LLC served as M&A advisors to Blackstone on this transaction.
powerplant
Jan 24, 2025
Nerc Warns Of “Severe Threats” To Electric Reliability In Northeast Us
POWER Engineering
Nerc Warns Of “Severe Threats” To Electric Reliability In Northeast UsThe North American Electric Reliability Corporation (NERC) this week said a recent study of the natural gas system in the northeast U.S. highlights “severe threats” to electric reliability in the region. The study by the Northeast Power Coordinating Council (NPCC), initiated in 2023, focused on gas supply and pipeline constraints during extreme winter weather in New York and New England across three forecast periods: 2024-25, 2027-28 and 2032-33. Both ISO-NE and NYISO expect to be dependent on natural gas for electric grid reliability over the study period. While gas generators may be burned less often as renewables and energy storage increasingly come online, the region’s fleet of gas-only and dual fuel generation resources will be relied on to both ramp and cycle to ensure grid reliability. The region’s natural gas infrastructure is nearly fully utilized during extreme cold weather, limiting gas availability and increasing reliance on oil-fired generation to ensure electric reliability, the NPCC study found. During milder weather, pipelines can accommodate ramping needs. However, certain events, like pipeline disruptions and protracted extreme weather, could pose major threats to reliability. LNG from terminals Constellation EMT and Repsol Saint John plays a critical role in supplementing gas supplies during harsh conditions, but their contributions are not interchangeable due to location-specific benefits, NPCC said. The retirement of oil plants and the potential loss of Constellation EMT could create reliability challenges in New England, necessitating capacity deficiency actions, the study found. Further, LNG scheduling flexibility is hindered by insufficient financial incentives for generators and import facilities to secure supply contracts in advance of extreme weather. Structural reforms by ISO-NE could address this issue by improving market signals to enhance grid resilience, according to study findings. In New York, dual-fuel generation is more common, and oil is heavily relied upon during cold weather contingencies, given gas infrastructure limitations. Electrification of heating and transportation will further increase gas demand, stressing both gas and electric systems in the long term. Uncertainty around renewable energy deployment, especially offshore wind, could heighten performance demands on thermal generation, NPCC said. The council said both ISO-NE and NYISO must balance grid resilience, decarbonization goals and incentives for gas and dual-fuel generators to maintain operational flexibility. “NPCC’s report is a sobering assessment and yet another call to action in a region that is running close to the edge,” said Jim Robb, NERC president and CEO. “During winter extremes, the electric system in the Northeast is dependent upon reliable natural gas supply. When rare, but well-observed contingencies occur, reliability is gravely threatened. This untenable situation cannot be mitigated solely by electric system operators, calling out the urgent need for tight operational and planning coordination between the two sectors.”  NCPP also noted that despite growing dependence on natural gas, pipeline expansions in the region have been minimal, leading to persistent winter bottlenecks and frequent critical notices from pipelines. Local distribution companies primarily hold firm transportation entitlements, the council said, while generators rely on third-party contracts or non-firm capacity. The study emphasized the impact of gas scheduling restrictions on generation availability during peak heating season disruptions. Read NCPP’s full study here.
powerplant
Jan 24, 2025
Novel Solar Project Sprawling Old Subsurface Mine To Tap Into Domestic Supply Chain
POWER Engineering
Novel Solar Project Sprawling Old Subsurface Mine To Tap Into Domestic Supply ChainThe United States is confronting an “energy emergency” spurred by the proliferation of data centers and mass electrification. To meet increasingly steep power demand projections, it will be imperative for the U.S. to leverage as many generation sources as possible. Considering wind development is (at least temporarily) off the table, those seeking to harness carbon-free power will have to lean on solar PV and energy storage projects. One problem- plenty of locals don’t want them in their communities. Some believe utility-scale solar sites are encroaching upon valuable farmland; others worry about potential lithium battery fires like the one in Moss Landing, California last week. Non-lithium storage solutions offer a workaround to the latter concern, and the former can be addressed by constructing projects in places nobody else wants to build stuff, like on top of an abandoned mine. And that’s exactly what a Washington, D.C.-based clean energy company is doing in a plan to provide clean power to nearly 34,000 Illinois homes. Sol Systems has reached the financial close of and started construction on the Tilden Solar Project in Randolph County, Illinois. The $345 million, 182-megawatt (MW) solar farm is being built on a 1,050-acre historic subsurface mine that has been derelict for roughly 30 years, part of an 840,000-acre swath of such sites running through Southern Illinois that make surface land development particularly challenging. It is the largest known solar project being built on reclaimed mine land. “This project represents what Sol Systems is all about- bringing renewable energy solutions to the most challenging and impactful sites,” noted Yuri Horwitz, the company’s CEO. Sol Systems is operating, building, and managing more than 7 gigawatts (GW) of projects across 38 states. “The Tilden project is a blueprint for how we believe clean energy development should be done,” he added.” Historical mining operations helped advance economic development in the area for decades, but once the mines were depleted of resources and shut down in the 1990s, the surrounding communities bore the brunt of the financial impact. Sol Systems believes it can reinvigorate those blue-collar communities not only by cleaning up an abandoned brownfield but also by contributing to the local tax base. On top of millions of dollars in estimated tax revenues, the project will deploy at least 20 years of ongoing investments in local workforce development, community partnerships, and environmental stewardship initiatives to ensure that the benefits of clean energy extend beyond the project itself. Additionally, the Tilden Solar project is creating approximately 300 construction jobs, with the majority being local hires in collaboration with area unions, including carpenters, operators, and electricians. Sol Systems collaborated with experts in mine engineering and reclamation to overcome challenges associated with the underground mining operation and burdened surface rights. The developer is also conferring with conservation partners to implement ecosystem restoration initiatives, including efforts to promote and preserve native species and pollinator habitats on-site. “Building this project on a subsurface mine requires innovation, precision, and a commitment to doing things safely,” noted Andy Poirot, vice president of the Tilden Solar project construction for McCarthy Building Companies, the project’s engineering, procurement, and construction (EPC) contractor. “This is a prime example of how renewable energy projects can create new opportunities within our industry and for the communities where projects are being built while preserving the environment for future generations.” The Sol Systems team partnered with Nextracker on developing a safe and effective tracker and foundation design, ultimately securing 147 surface waivers from unique entities, demonstrating the project’s complexity and Sol Systems’ commitment to making it work. Nextracker, which delivered its first 100% domestic solar trackers in December, will supply U.S.-manufactured racking systems for the Tilden Solar Project. “Nextracker is proud to be working with Sol Systems and McCarthy Building Companies on the Tilden Solar Project which will be using American-made steel components,” said Dan Shugar, Nextracker founder and CEO. “Together, we’re collaborating to deliver best-in-class tracker and foundation solutions, purpose-built to meet the project’s unique geotechnical and sustainability requirements- both above and below ground- using the best of American innovation.” Nextracker isn’t the only company providing made-in-the-USA components, either- Qcells will supply the project with domestically manufactured solar modules. “At Qcells, we are proud to be a part of a project that not only advances renewable energy but also strengthens the U.S. manufacturing supply chain,” said Mr. IP Kim, Qcells GES President. “The Tilden project highlights the importance of using domestically produced modules to meet the nation’s clean energy goals, while also delivering economic benefits to American workers. We’re excited to partner with Sol Systems to make this innovative project a reality.” If the idea of turning abandoned mines into carbon-free generation projects rings a bell, it may be because global energy company RWE recently announced a partnership with Peabody Energy, a coal mining company, to repurpose reclaimed land previously used for mining in Indiana and Illinois. The tandem will build out a 5.5 GW pipeline of 10 potential projects that could power more than 850,000 homes across the region. They also maintain existing agricultural lands, according to RWE, ensuring that rural areas benefit from economic growth. Originally published in Renewable Energy World.
powerplant
Jan 23, 2025
Epcs Chosen For Tva’S Clinch River Smr Project
POWER Engineering
Epcs Chosen For Tva’S Clinch River Smr ProjectFollowing a “rigorous selection process,” the Tennessee Valley Authority (TVA) announced that it will be working with Bechtel and Sargent & Lundy, along with GE Hitachi (GEH), to support initial planning and evaluation for the first small modular reactor (SMR) at TVA’s Clinch River Nuclear site in Oak Ridge, Tennessee. TVA noted that its contractors will work with GEH and TVA as a “highly integrated” project team to plan, design, and potentially procure, construct and commission Clinch River Unit 1. It argues that using an integrated project delivery (IPD) approach to contracting is “significantly different” from traditional project delivery methods that is intended to align all parties in a unified plan. “The integrated project delivery model is the preferred method that will make our project a true team effort,” said Bob Deacy, TVA Clinch River Project, Senior Vice President. “We will actively work together toward a target budget and schedule – creating a significant advantage to drive nuclear innovation, share risks and reduce costs. This collaboration will provide our region affordable, reliable and increasingly clean power and improve America’s energy security.” TVA’s technology collaboration partner Ontario Power Generation (OPG) has also utilized the IPD model successfully for generation projects and is using the IPD model for its SMR at Darlington in Ontario, Canada.   Bechtel and TVA have worked together on other nuclear projects over the years, most recently in completing construction of Watts Bar Unit 2 in 2016. Through the IPD, Bechtel will provide insights from its experience in constructing nuclear facilities.  “Bechtel is honored to be selected by TVA for this important work and is proud to be at the forefront of new nuclear power generation,” said Ahmet Tokpinar, general manager of Bechtel’s Nuclear Power business unit. “We are committed to leveraging our extensive experience and expertise, utilizing new tools and innovations, to construct this project. We look forward to continuing our partnership with TVA to deliver new, clean energy.” TVA is already working with GE Hitachi, OPG and Synthos Green Energy through a technology collaboration agreement that will develop the standard design for the BWRX-300. As TVA continues to prepare for a potential SMR at the Clinch River site, Sargent & Lundy will lead the design for the site-specific implementation of the BWRX-300 at the Clinch River Nuclear site. The BWRX-300 is a 300 MWe water-cooled, natural circulation reactor with passive safety systems that leverage the design and licensing basis of GEH’s ESBWR boiling water reactor. It leverages a unique combination of existing fuel that is currently used in operating reactors (and does not require HALEU), plant simplifications, proven components and a design based on already licensed reactor technology.  TVA ultimately may consider constructing one or more SMR units. The IPD team scope will also provide preliminary plans with estimated cost reduction forecast as it relates to constructing multiple SMRs to identify innovations and to provide a progression of cost reduction for additional reactors. “TVA is building a highly skilled and experienced project team to lead the way for the deployment of the BWRX-300 at Clinch River,” said Sean Sexstone, Executive Vice President, Advanced Nuclear, GE Hitachi Nuclear Energy. “Together, we bring decades of expertise in the nuclear industry and major projects, and we are excited to collaborate in supporting TVA’s mission to meet the increasing demand for reliable and secure energy.” TVA’s team is currently beginning the validation phase. During this phase TVA will collaborate with Bechtel, Sargent & Lundy and GE-Hitachi to jointly develop the potential Clinch River SMR’s cost estimate and schedule. A future multi-party agreement is contemplated under which incentives and arrangements will be negotiated to help ensure those estimates are achieved. The validation phase is anticipated to be completed within 1-2 years. TVA and a broad coalition of electric utilities, EPCs, technology providers and other companies have applied for federal funding that, if awarded, would accelerate the deployment of multiple BWRX-300 SMRs. This includes TVA’s plans at the Clinch River site. The award would move up the SMR project’s commercial operation date by two years, from 2035 to 2033, the federal utility said. TVA’s Board has not yet voted to approve an SMR at the nuclear site, however. TVA’s structured planning process “carefully” advances the Clinch River Project in phases at which the TVA Board will evaluate and consider approving any next steps.
powerplant
Jan 23, 2025
With Trump Pivot Back To Pro-Oil And Gas Policies, One Renewable Energy Finds Favor
POWER Engineering
With Trump Pivot Back To Pro-Oil And Gas Policies, One Renewable Energy Finds FavorBy JENNIFER McDERMOTT Associated Press As promised, President Donald Trump began reversing the country’s energy policies his first day in office with a spate of orders largely favoring oil, gas and coal. But there is one renewable energy that did find favor: geothermal. Energy experts say that makes sense — geothermal energy makes electricity 24/7. Many people working in the field came from the oil and gas industry and they use much of the same technology for drilling wells. Trump strongly supports and gets support from the oil and gas industry. And there’s bipartisan support in Congress for geothermal. “The embrace of advanced geothermal under this new administration, I’d say is not a giant surprise,” said Alex Kania, a managing director at Marathon Capital. “It’s reliable, it’s efficient, and frankly their ties to the more conventional forms of energy production, I think, is probably not lost on some people.” Geothermal creates electricity cleanly by making steam from the Earth’s natural heat and using that steam to spin a turbine. It’s a climate solution because it reduces the need for traditional power plants that burn fossil fuels and cause climate change. Trump declared an energy emergency on Monday, and included geothermal heat as one of the domestic energy resources that could help ensure a reliable, diversified and affordable supply of energy. Solar, wind and battery storage were omitted, and wind was singled out in a separate order with measures intended to slow it down. “Geothermal is heating up and the Trump administration is going to empower the industry over the next four years to achieve its potential,” said Bryant Jones, executive director of the geothermal trade association, Geothermal Rising. It’s a vibrant business right now. New geothermal companies are adapting technology and practices from oil and gas to create steam from ubiquitous hot rock. That would make this kind of electricity possible in many more places. The Energy Department estimates the next generation of geothermal projects could provide some 90 gigawatts in the U.S. by 2050 — enough to power 65 million homes or more. Former Energy Secretary Jennifer Granholm supported geothermal as a climate solution. Trump’s pick for energy secretary, Chris Wright, is a fossil fuel executive who values geothermal, too. His company, Denver-based Liberty Energy, invested in Fervo Energy, a Houston-based geothermal company. Wright said at his confirmation hearing that he’s excited about geothermal as an “an enormous, abundant energy resource below everyone’s feet.” Wright’s appointment is a clear signal that this administration will support geothermal, said Terra Rogers, a program director who focuses on the technology at the nonprofit Clean Air Task Force. “He’s well-informed of its risks and opportunities, and continues to be a strong advocate for what it could be,” Rogers said. The United States is a world leader in electricity made from geothermal energy, but it still accounts for less than half a percent of the nation’s total large-scale generation, according to the U.S. Energy Information Administration. The big states are California, Nevada, Utah, Hawaii, Oregon, Idaho and New Mexico, where reservoirs of steam, or very hot water, lie close to the surface. In its first actions this week, the new administration also indicated support for nuclear power and removing obstacles to mining uranium, which can be refined into nuclear fuel. Like geothermal, nuclear power does not cause climate change. The executive order also backs hydropower. Solar is the fastest-growing source of electricity generation in the United States. Trump wants to increase production of oil and gas in order for the U.S. to have the lowest-cost energy and electricity of any nation in the world, he says. He took aim at wind energy, temporarily halting offshore wind lease sales in federal waters and pausing federal approvals, permits and loans for projects both onshore and offshore. Trump says wind turbines are horrible, only work with subsidies and are “many, many times” more expensive than natural gas. Offshore wind is one of the most expensive sources of new power generation, but onshore wind is cheaper than new natural gas plants, according to estimates from the Energy Information Administration. Jones, at Geothermal Rising, said the industry hopes the support for geothermal energy will lead to streamlined permitting, more federal research and tax credits to promote innovation. Sage Geosystems in Houston is a geothermal company launched by former executives at oil and gas giant Shell. CEO Cindy Taff said it’s exciting to see more momentum building for geothermal. She hopes it will spur investment in large projects, including those that meet surging demand for electricity from data centers and artificial intelligence, and projects to make military facilities energy resilient. If geothermal projects could multiply fast across the country, she said, it would bring the cost down, and that would be good for everyone. “This could be the decade of geothermal,” Taff said.
powerplant
Jan 23, 2025
Locals Request Total Shutdown Of Moss Landing As California Governor Calls For Investigation Into Battery Storage Fire
POWER Engineering
Locals Request Total Shutdown Of Moss Landing As California Governor Calls For Investigation Into Battery Storage FireCalifornia Governor Gavin Newsom is calling for an investigation into the fire that engulfed the first phase of Vistra Energy’s Moss Landing Energy Storage Facility last week. A spokesperson for Gov. Gavin Newsom said Vistra and the California Public Utilities Commission (CPUC) should conduct separate fact-finding missions to determine the cause of the fire and outline potential steps that can be taken to make similar facilities safer. The CPUC’s Safety and Enforcement Division is scheduled to meet with Vistra today. Moss Landing, located about 77 miles south of San Francisco, houses tens of thousands of lithium batteries produced by LG Energy Solution Ltd. housed in three separate concrete enclosures. Last Thursday at around 3 pm PT, a fire was reported in the 300-megawatt (MW) Phase I building. The property was promptly evacuated, and all employees and fire personnel have since been confirmed safe. Smoke pours from a smoldering fire at Vistra Corp.’s Moss Landing battery storage facility in Moss Landing, California, US, on Friday, Jan. 17, 2025. A fire broke out at Vistra Corp.’s Moss Landing complex in California, one of the world’s biggest battery storage facilities,… pic.twitter.com/fSKXcdPXXa Thousands of people were instructed to leave the area, several roads were shut down including Highway 1, and some schools and businesses had to close Friday as the plant continued to burn. The fire did not escape its enclosure and spread to other areas of the facility. It was mostly out by the weekend, although pockets continued to smolder days later, hampering Vistra’s ability to start an investigation. Texas-based Vistra celebrated an expansion of the battery power plant in August 2023, which pushed its total capacity to 750 MW/3,000 MWh, making it the largest battery energy storage system (BESS) in the world at the time (now the second-largest). Last week’s fire was the latest in a string of incidents at Moss Landing. In September 2021 a purported software programming error caused a heat suppression system to activate and douse three 100 MW racks of batteries. A second, nearly identical snafu involving the early detection safety system occurred in February 2022 in the 100 MW Phase II building next door. While the foundations of an investigation are laid, some concerned locals are making the request that companies operating the BESS on and adjacent to the Moss Landing site completely shut them down until officials can determine what sparked the blaze and how it may have been prevented. The Monterey County Board of Supervisors voted 5-0 in an emergency meeting Tuesday to approve a local state emergency over the fire. The board is also asking Vistra to cease operations on the rest of the 750 MW facility and recommend utility Pacific Gas & Electric (PG&E) do the same at their nearby 182 MW Moss Landing Elkhorn Battery, which was not impacted by the fire at Vistra’s facility. At the meeting, Monterey County Supervisor Glenn Church suggested lithium-based battery energy storage technology has evolved too quickly for the government to properly regulate it or for companies like Vistra to be able to safely utilize it. “This process we are now in, which is learning as we go, just doesn’t work,” Church declared. “It jeopardizes communities.” Other community members voiced worries over air pollution and its impact on nearby farmland. Current best practice dictates lithium battery fires be allowed to burn out on their own, which was the course of action for the Moss Landing fire. “We all had a metallic taste in our mouth, burning eyes, burning throat, and yellow residue all over our things,” reported Michelle Clary, a resident of nearby Royal Oaks. I wonder what percentage of the country depends on the crops currently getting toxic lithium fallout rained down upon them from the fire at Vistra Power Plant in Moss Landing, CA pic.twitter.com/TNKgGNXMJh “I’m very skeptical that there’s zero contaminants in the material, in the building, or what may have settled on the ground and on the crops. We have people who have organic farmers who are concerned,” added Ed Mitchell of the Moss Landing Fire Community Recovery Group. The Environmental Protection Agency (EPA) set up air monitors the night the fire started and has not yet seen indications of dangerous levels of particulate matter. At Tuesday’s meeting, the director of environmental health for Monterey County confirmed no amount of soot or hydrogen fluoride has been detected above state health guidelines. “Air monitoring conducted by the Environmental Protection Agency and independent third-party air quality experts continues to demonstrate the site and surrounding area is safe and does not pose a risk for the public,” confirmed Vistra in a statement. It is unknown how long the Moss Landing facility will be out of operation. Originally published in Renewable Energy World.
powerplant
Jan 22, 2025
1,350-Mw Texas Combined Cycle Plant To Begin Construction Soon After Receiving Air Permit
POWER Engineering
1,350-Mw Texas Combined Cycle Plant To Begin Construction Soon After Receiving Air PermitThe Texas Commission on Environmental Quality (TCEQ) has issued the air permit for Competitive Power Ventures’ (CPV) planned 1,350 MW combined-cycle natural gas power plant currently in advanced stages of development, with financing expected late in the second quarter of this year. The CPV Basin Ranch Energy Center is being designed with the option to include a carbon capture system. The permit authorizes the construction and operation of the plant near Barstow, Ward County, Texas, in the Permian Basin. Issuance of the permit is the latest milestone for the project over the last 12 months, in addition to advancing in the Texas Energy Fund (TEF) loan program and finalizing a tax abatement agreement with local officials in Ward County.     Construction is expected to begin late in the second quarter 2025, and commercial operations are expected to start in 2028.  “For the last three years, our company has been diligently working on the development of CPV Basin Ranch. We are proud of the work to date and will remain laser focused as we move through the final steps of development. We thank the TCEQ for its assistance through the extensive air permit process,” said Peter Podurgiel, CPV’s President of Low Carbon Generation. “The Texas Energy Fund is proving to be an excellent tool to help bring needed development of reliable energy resources to the state.”    In a move CPV argues is meant to address a key concern across the state in recent years regarding reliability during extreme weather situations, CPV Basin Ranch will include connections to multiple sources of natural gas supply to maximize the facility’s performance during “critical situations.” Last August, the Public Utility Commission of Texas advanced CPV Basin Ranch’s application to the due diligence phase of review for a low-interest loan under the Texas Energy Fund (TEF) program. CPV claims this is the largest project to advance under the program and one of the first expected to be built with the option for carbon capture.    “This is a win-win for the State of Texas and the communities in the Permian Basin. We need to bring baseload dispatchable generation online that will strengthen our grid and serve Texans. We have an urgent need to build gas-fired baseload projects in the Permian to support the continued growth of oil and gas production. The location of CPV Basin Ranch is an example of the TEF complementing our efforts to show the opportunities in West Texas and attracting companies to our region,” said state Sen. Kevin Sparks.   Ward County commissioners in September 2024 approved a partial 10-year property tax abatement for the project.  “We’re excited about this project for Ward County. CPV Basin Ranch will not only be a great asset to the state’s energy grid but will have an enormous impact on our local economy. We will see job growth both during construction and into operation along with a long-term tax benefit,” said Ward County Judge Greg M. Holly. “CPV has shown an openness to work with our region, and we feel strongly this will create a positive ripple locally and beyond.”
powerplant
Jan 22, 2025
Partially Built And Abandoned Nuclear Project In South Carolina Could See New Life
POWER Engineering
Partially Built And Abandoned Nuclear Project In South Carolina Could See New LifeA partially constructed and abandoned nuclear project in South Carolina could have a future, after all. The state-owned utility Santee Cooper has launched a process seeking proposals to acquire and complete, or propose alternatives, for two partially constructed nuclear generating units at the V.C. Summer Station in Jenkinsville, South Carolina. The utility has no plans to own the units. Factors contributing to the utility’s decision to launch an RFP process include a need for new generating capacity, driven by rapid growth of data centers, the onshoring of manufacturing and the retirement of fossil-fired plants. Santee Cooper also cited significant interest in repowering closed or canceled nuclear units to shorten project timelines, as well as federal incentives for these projects. “Considering the long timelines required to bring new nuclear units online, Santee Cooper has a unique opportunity to explore options for Summer Units 2 and 3 and their related assets that could allow someone to generate reliable, carbon emissions-free electricity on a meaningfully shortened timeline,” said utility president and CEO Jimmy Staton. This could be the first abandoned nuclear construction project to be finished in response to the need for more clean, firm electrons on the grid. Holtec International plans to revive the previously retired 800 MW Palisades plant in Michigan. Constellation’s Three Mile Island Unit 1 in Pennsylvania could also be returned to life following a PPA signed with Microsoft. Santee Cooper also touted V.C. Summer’s “unique position” as the only site in the U.S. that could deliver 2,200 MW of nuclear capacity “on an accelerated timeline.” The utility notes that Unit 2 “was significantly progressed” when the project was canceled, another possible incentive for a buyer. There is also room for more possible units at the site. Santee Cooper and South Carolina Electric & Gas Co. (SCE&G) spent more than $9 billion before abandoning construction on the reactors at V.C. Summer in 2017. The utility partners concluded that completing the two units would be “prohibitively expensive.” The decision to abandon came after the bankruptcy filing of Westinghouse Electric, the project’s contractor. At the time, Westinghouse said it had over $6 billion in debt. Majority owner SCE&G (now Dominion Energy South Carolina) transferred its interest in the assets to Santee Cooper in 2018. A total of four utility executives were charged and sentenced in connection with the failed project. Santee Cooper has engaged Centerview Partners LLC to conduct the RFP, seeking parties interested in acquiring the project and related assets, and potentially completing one or both units or pursuing alternative uses of the assets. Responses to the RFP are due on May 5, 2025.
powerplant
Jan 22, 2025
Data Center Executives Pivot Toward Onsite Power, Per New Report
POWER Engineering
Data Center Executives Pivot Toward Onsite Power, Per New ReportOnsite turbines, reciprocating engines and fuel cells will increasingly power data centers, according to a survey by fuel cell manufacturer Bloom Energy. In April and November 2024, Bloom surveyed a range of managers to C-suite executives from hyperscaler and colocation developer companies. The 100 data center leaders make decisions about power systems architecture. Historically, data centers have used onsite power mostly for backup purposes. The shift toward onsite power generation as a primary source of power comes in response to data centers facing grid connection delays. Leveraging onsite power could also ease pressure on the nation’s aging electric grid. In November, data center leaders said they expected approximately 30% of all data center sites to use some onsite power as a primary energy source supplemental to the grid by 2030, 2.3 times more than just seven months earlier. The report noted there were more data center announcements featuring onsite power in 2024 than the previous four years combined. “We were surprised by the pace of change and the growing expectation that onsite power generation will play a greater role in powering data center projects,” reads the Bloom Energy report. Data center leaders also expect power availability to get worse. In the U.S., 55 GW of data center IT capacity is expected to come online in the next five years, according to the report. An additional 35 GW of data center capacity is expected to be announced during that time. Data centers, while not the only reason for load growth in the U.S., are the largest driver. Data centers by 2030 could require 8-12% of the total U.S. demand, compared to 3-4% today, according to the report. As new data center projects struggle to get timely access to power, data center leaders are seeing value differently. Time to power is playing an increasingly important role in this equation. Save the date for DTECH Data Centers and AI from May 27-29, 2025 in San Jose, CA! This new event brings utilities, data center operators and other stakeholders together to discuss the strategies necessary to navigate power constraints, project delays, and the increasing demand for sustainable, flexible solutions. Bloom Energy predicts that their decisions will go beyond traditional factors, like reliability and cost. The company’s report found that leaders are now ready to invest 50% more than seven months ago if that means they can access power faster for upcoming data center projects. “This shift underscores an important insight: being online ahead of competitors is a strategic advantage, particularly for AI data centers,” reads the report. “Leaders recognize that accelerating power access is key to securing a leading position in this rapidly evolving landscape.” Combined-cycle gas turbines (CCGT) are primarily being used in large AI training data centers that require 500 MW or more capacity. Smaller inferencing data centers – focused on the application of trained models – are more often relying on simple cycle turbines, sometimes paired with batteries. While these turbine technologies are currently the most common onsite power solutions, long supply chain lead times and higher carbon dioxide emissions are limiting factors in their adoption. Fuel cells, which convert natural gas or hydrogen into electricity, are gaining popularity in data center projects because they are quick to deploy and produce fewer emissions and less pollution than natural gas-fired turbines. While fuel cells can be more expensive than some other solutions, the Bloom Energy report noted that data center leaders often prioritize them for their faster deployment, easier permitting and greater power density. In November, we reported that AEP agreed to secure up to 1 gigawatt (GW) of Bloom Energy solid oxide fuel cells for data centers and other large energy users who need to quickly power their operations while the grid is still being built out to accommodate demand. Data center leaders are also optimistic about emerging technologies such as geothermal power, small modular reactors (SMRs) and gas generation with carbon capture and sequestration (CCS). Bloom Energy is seeing these technologies appear in data center companies’ long-term roadmaps. The company said recent announcements related to these technologies focus on data centers that are expected to go online after 2030, due to the technologies’ early stage of development.
powerplant
Jan 22, 2025
What Waste? Reclaimed Wastewater Will Cool A Florida Natural Gas Plant
POWER Engineering
What Waste? Reclaimed Wastewater Will Cool A Florida Natural Gas PlantA partnership between Florida Power & Light (FPL) and Miami-Dade County has brought “one of the largest” reclaimed water projects in the state online, which will treat up to 15 million gallons of reclaimed wastewater per day to cool the natural gas plant at FPL’s Turkey Point Clean Energy Center. The clean water recovery process begins when reclaimed water travels through an 8.5-mile pipeline into the Biological Nutrient Removal (BNR) basin at the new Clean Water Recovery Center (CWRC). Different treatment zones within the BNR basin remove ammonia and condition solids, which are then clarified. During clarification, phosphorus is removed before the water is chlorinated and stored in two 500,000-gallon tanks. The treated water is ultimately used to supply cooling towers, reducing the need for Floridan aquifer groundwater. In addition to cooling the gas plant, the project is meant to help Miami-Dade County meet reuse requirements under Florida’s Ocean Outfall Legislation, and provide a cost-effective way to reuse treated wastewater which would have likely been discarded otherwise. The Ocean Outfall Legislation requires utilities in Southeast Florida to eliminate the normal use of the ocean outfall, or stop feeding treated wastewater into the ocean, by the end of 2025. Additionally, Florida has its own standards for the amount of treated wastewater that local governments must reuse, the Miami Herald reports. The CWRC project was originally intended to help cool FPL’s two nuclear reactors at the Turkey Point site, but those plans changed before the project’s launch, per the Miami Herald. “There was, in the planning stages, an idea of having it assist, as needed, a backup to the Turkey Point nuclear cooling canals,” an FPL spokesperson told the Miami Herald. “The decision was made not to do that.” FPL and Miami-Dade County have partnered on clean energy projects since 2018, including the Miami-Dade Solar Energy Center, dozens of solar arrays, battery storage projects, shore power for PortMiami, a microgrid at Florida International University (FIU) and a growing electric vehicle charging network. Last September, the U.S. Nuclear Regulatory Commission (NRC) approved the subsequent license renewal for FPL’s Turkey Point Nuclear Power Plant Units 3 and 4, enabling the continued operation of these units through 2052 and 2053, respectively. Turkey Point Unit 3 began commercial operation in 1972, followed by Unit 4 in 1973. Located 25 miles south of Miami, the site sits on 11,000 acres of land. In December 2019, Turkey Point became the first nuclear plant in the United States to receive subsequent license renewal approval for an additional 20 years; however, in 2022, the NRC concluded that its general environmental review under the National Environmental Policy Act required additional information and, consequently, resetting the previous operating license expiration dates of 2032 and 2033.
powerplant
Jan 21, 2025
Trump Temporarily Halts Leasing And Permitting For Wind Energy Projects
POWER Engineering
Trump Temporarily Halts Leasing And Permitting For Wind Energy ProjectsBy JENNIFER McDERMOTT Associated Press President Donald Trump signed an executive order Monday temporarily halting offshore wind lease sales in federal waters and pausing the issuance of approvals, permits and loans for both onshore and offshore wind projects. The interior secretary will review wind leasing and permitting practices for federal waters and lands. The assessment will consider the environmental impact of wind projects on wildlife, the economic costs associated with the intermittent generation of electricity and the effect of subsidies on the viability of the wind industry, the order states. Trump wants to increase drilling for oil and gas and has been hostile to renewable energy, particularly offshore wind. Trump’s pick for interior secretary, Doug Burgum, was asked during his confirmation hearing whether he would commit to continuing with offshore wind leases that have been issued. Burgum said projects that make sense and are already in law will continue. Wind power currently provides about 10% of the electricity generated in the United States, making it the nation’s largest source of renewable energy. There is 73 gigawatts of offshore wind capacity under development in the U.S., enough to power 30 million homes, according to the American Clean Power Association. The order also temporarily prohibits Magic Valley Energy from continuing to develop the Lava Ridge Wind Project in Idaho. The federal government approved a scaled-down plan for the wind farm in December over local opposition, including from groups concerned about its proximity to a historic site where Japanese Americans were incarcerated during World War II. On the campaign trail, Trump vowed to end the offshore wind industry as soon as he returned to the White House. He wants to boost production of fossil fuels such as oil, natural gas and coal, which cause climate change, in order for the U.S. to have the lowest-cost energy and electricity of any nation in the world, he says. It’s unclear how much authority he has to stop wind projects, particularly those that have their federal permits. His order will likely be challenged in court, much like an executive order President Joe Biden signed soon after taking office in 2021 that suspended new oil and gas lease sales was challenged. Soon after his election, Trump tasked a New Jersey congressman and vocal critic of offshore wind, Republican Rep. Jeff Van Drew, with drafting an executive order on offshore wind he could issue early in his term. Van Drew said he quickly sent the draft to Burgum. Van Drew views the executive order as a first step toward an eventual moratorium on offshore wind development. By including onshore wind projects too, Monday’s order is far broader than what Van Drew proposed. Trump says wind turbines are horrible, only work with subsidies and are “many, many times” more expensive than natural gas. Offshore wind is among the sources of new power generation that will cost the most, at about $100 per megawatt hour for new projects connecting to the grid in 2028, according to estimates from the Energy Information Administration. That includes tax credits under the Inflation Reduction Act, which reduces the cost of renewable technologies. But onshore wind is one of the cheapest sources, at about $31 on average for new projects. New natural gas plants are expected to produce electricity at nearly $43 per megawatt hour, according to the estimates. The EIA said in addition to price, it’s important to consider the reliability of the grid — natural gas power plants can be operated at any time throughout the day, unlike solar or wind. Robin Shaffer, president of Protect Our Coast NJ, one of the most vocal groups opposing offshore wind on the East Coast, said the new executive order is only the first step toward the U.S. moving away from offshore wind, a “harmful technology,” and toward more promising, sustainable energy sources. But Kit Kennedy, managing director for power at the Natural Resources Defense Council, said the Trump administration is putting dirty fossil fuels front and center while delaying progress on renewable energy projects. This is not only bad for clean air, public health and national security, it cuts short a promising source of additional power at a time when the grid needs it most, Kennedy said in a statement. The Biden administration sought to ramp up offshore wind as a climate change solution, setting national goals to deploy offshore wind energy, holding lease sales and approving nearly a dozen commercial-scale offshore wind energy projects. The nation’s first commercial-scale offshore wind farm opened in March, a 12-turbine wind farm called South Fork Wind 35 miles (56 kilometers) east of Montauk Point, New York.
powerplant
Jan 21, 2025
Tva, Aep, Duke Seek Federal Funding To Accelerate Small Modular Reactor Projects
POWER Engineering
Tva, Aep, Duke Seek Federal Funding To Accelerate Small Modular Reactor ProjectsEditor’s Note: This is an updated story that was originally published January 17. A broad coalition of electric utilities, EPCs, technology providers and other companies have applied for federal funding that, if awarded, would accelerate the deployment of multiple small modular reactors (SMRs). Last week we reported that the Tennessee Valley Authority (TVA) is applying for $800 million in funding that would help the federal utility speed up deployment of a BWRX-300 SMR at TVA’s Clinch River Project in Oak Ridge, Tennessee. The funding is through the U.S. Department of Energy’s Generation III+ Small Modular Reactor (SMR) Program, launched in 2024. The award would move up the SMR’s commercial operation date by two years, from 2035 to 2033, TVA said. The broad coalition of partners includes Bechtel, BWX Technologies (BWXT), Duke Energy, Electric Power Research Institute (EPRI), GE Hitachi (GEH), Indiana Michigan Power, Oak Ridge Associated Universities, Sargent & Lundy, Scot Forge and North American Forgemasters, the State of Tennessee and other utilities and advanced nuclear project developers. At this time, TVA’s board of directors has not voted to approve an SMR at the Clinch River site. Should the board approve an SMR, the availability of DOE funding would help accelerate the early activities of the project. TVA is planning for the potential deployment of up to four SMRs at the Clinch River site. Multiple deployments would stimulate the supply chain for BWRX-300 reactors in the coming decades, TVA said. The BWRX-300 is a 300 MWe water-cooled, natural circulation reactor with passive safety systems that leverage the design and licensing basis of GEH’s ESBWR boiling water reactor. The reactor leverages a unique combination of existing fuel that is currently used in operating reactors (and does not require HALEU), plant simplifications, proven components and a design based on already licensed reactor technology.  American Electric Power announced Friday that its subsidiary, Indiana Michigan Power (I&M), applied as a subrecipient under TVA’s application. The utility is eyeing two potential SMR sites for a BWRX-300: The Rockport Plant in Spencer County, Indiana, and the Joshua Falls property in Campbell County, Virginia, which is under AEP subsidiary Appalachian Power. I&M is seeking $50 million to begin the early stages of SMR development at the Rockport Plant site. If awarded funds, I&M will conduct ESP activities, as well as a Preliminary Safety Analysis Report, which is required for a potential future Construction Permit, at the site utilizing the GEH BWRX-300 technology. Last year, Spencer County officials approved an ordinance supporting new generation at the Rockport Plant site, including the use of SMRs. In November 2024, Appalachian Power announced that it was beginning exploration to see if the Joshua Falls site was suitable for an SMR. On Friday, Appalachian Power submitted a grant proposal requesting $35 million to offset the costs of the work necessary for the early site permit. Duke Energy also issued its own announcement that it would pursue funding through the Generation III+ SMR Program. Duke has also has entered into an agreement with GE Hitachi to invest in activities to advance the standard design and licensing of the BWRX-300. This would allow Duke Energy to share insights and best practices with TVA and other partners as they adopt GE Hitachi’s SMR technology. Utilities everywhere are projecting increased demand due to the proliferation of data centers, onshoring of manufacturing and economy-wide electrification. TVA and AEP territories are no exception. According to TVA projections from August 2024, the region’s population is growing three times faster than the national average. To address the need for more electricity, TVA is investing nearly $16 billion through FY27 to build new generation and infrastructure and enhance the reliability of existing assets.
powerplant
Jan 21, 2025