Today New Mexico Commissioner of Public Lands Stephanie Garcia Richard executed a pair of long-term leases for projects on state lands. One was awarded to EDF Renewables to develop a wind energy project on 23,840 acres in Grant County; a second lease was awarded to Innergex Renewable Energy for a wind project on 12,192 acres in Hidalgo County.

When it’s finished, the EDF project is expected to generate around 400 MW of wind energy, making it the second-largest wind project on New Mexico state lands, trailing only Pattern Energy’s massive Western Spirit Wind, which has 1,050 MW of installed capacity encompassing four sites in Central New Mexico. Garcia Richard signed off on that project as well, in 2020.

Innergex’s new wind farm is expected to put out about 150 MW. Bids for each lease were unsealed at public auctions at the State Land Office building in Santa Fe, per Garcia Richard.

“We are continuing to help the renewable energy sector grow with each major wind or solar deal on state lands. The fact that there were multiple qualified bidders on both of these leases shows that companies are taking us seriously when we say we are open for business,” Commissioner Garcia Richard said. “New Mexico is blessed with plenty of wind and sun, as well as nine million acres of state lands, making us well-positioned to expand our renewable portfolio even more. These wind projects will provide real, long-term revenue to help make a difference in New Mexico’s classrooms.”

Commissioner Garcia Richard created the first-ever Office of Renewable Energy within the Commercial Resources Division at the State Land Office intending to triple renewable energy leasing and production on state trust lands. The Office has exceeded initial expectations, as renewable energy on New Mexico state lands has increased more than six-fold since its inception- growing from 400 MW when Commissioner Garcia Richard assumed office to about 2.5 GW of wind and solar energy under lease today.

Here comes the Sun(Zia)

According to the American Clean Power Associations’s Clean Power Quarterly for Q1 2024, New Mexico had installed the second-most wind power capacity in the country year to date, trailing only Wyoming.

Texas and California were the top two states for under-construction projects, with 18.9 GW and 8.6 GW, respectively. New Mexico (5.2 GW), Wyoming (5.1 GW), and Arizona (4.7 GW) round out the top five states for under-construction clean power capacity, per ACP’s report.

We can expect to see New Mexico remain near the top as Pattern constructs its game-changing SunZia Wind and Transmission project; both new wind lease areas intersect its transmission line.

Wind lease areas EW-0111 (left) and EW-0113 (right) are shown shaded in red. The Southline Transmission Line is indicated in black, the SunZia Transmission Line in blue. Courtesy: New Mexico State Land Office

SunZia Transmission is a 550-mile ± 525 kV high-voltage direct current transmission line between central New Mexico and south-central Arizona with the capacity to transport clean power all the way out to California. It will utilize Pattern’s 3.5 GW SunZia Wind project, the largest wind project in the Western Hemisphere, which will be simultaneously constructed alongside SunZia Transmission. Pattern Energy recently announced that the projects are expected to generate $20.5 billion in total economic benefit, including more than $8 billion in direct capital investment, at no added cost to ratepayers, according to the results of an independent study conducted by the research firm Energy, Economic & Environment Consultants LLC. 

Pattern Energy broke ground on the project last September, and it’s expected to come online in 2026. In June, a U.S. district judge dismissed claims by Native American tribes and environmentalists who sought to halt construction along part of the $10 billion energy line, asserting the plaintiffs were years too late in bringing their challenge.

Fund V will invest in power and energy infrastructure assets, platforms, and companies, LS Power said.

“Demand for electricity in the United States is growing at the fastest rate in decades, driven by electrification, data center proliferation, and an American manufacturing renaissance.,” Paul Segal, CEO of LS Power, said. “Our portfolio of assets and businesses—which spans generation, transmission, and decarbonization solutions—is designed to ensure the reliability and affordability of electricity while accelerating the energy transition. We look forward to investing this capital to help meet the historic challenges facing the U.S. energy sector.”

Since its inception, LS Power has raised $60 billion in debt and equity capital and developed and acquired more than 47 GW and 160 power generation projects to support North American energy infrastructure. In addition, LS Power Grid has developed 16 transmission projects, including 6 utilities in operation across 5 ISO/RTOs that serve 185 million people. These projects include 780+ miles of high voltage transmission, beyond which LS Power Grid has another 350+ miles in development. 

LS Power said it will leverage its market knowledge, industry network, and in-house expertise to invest Fund V’s capital. To date, Fund V has invested or committed approximately $1.6 billion across renewable and gas-fired generation, renewable fuels, and green hydrogen, with an extensive pipeline of additional opportunities. Recent investments include the announced acquisition of Algonquin Power & Utilities Corp.’s North American renewable energy business, comprised of 3 GW of operating projects and an 8 GW development pipeline spanning 12 states, 4 provinces, and 5 U.S. power markets.

“Over the past thirty years, LS Power has built a platform to meet this moment in the energy transition,” said Darpan Kapadia, Chief Operating Officer of LS Power. “The success of this fundraise is a testament to our team’s deep expertise and strong track record through multiple market cycles. We are grateful to our investors, both new and long-standing, for their partnership.”

CPV Rogue’s Wind would join the CPV Maple Hill Solar and the CPV Fairview Energy Center projects in Cambria County. The project would consist of 19 Vestas V-162 wind turbines.

CPV Rogue’s Wind is expected to come online in 2026. The project is part of the company’s 10 GW pipeline of renewable and dispatchable generation projects, including utility-scale power generation with carbon capture.

CPV Rogue’s Wind is the first project tied to the company’s recent partnership announcement with investment management firm Harrison Street. The partnership, in which Harrison Street acquired one-third of CPV Renewables, will support an accelerated build out of the 4 GW renewable development pipeline.

COLUMBIA, S.C. (AP) — The South Carolina Senate on Thursday started its homework assignment of coming up with a comprehensive bill to guide energy policy in a rapidly growing state and amid a quickly changing power- generation world.

The Special Committee on South Carolina’s Energy Future plans several meetings through October. On Thursday, the committee heard from the leaders of the state’s three major utilities. Future meetings will bring in regular ratepayers, environmentalists, business leaders and experts on the latest technology to make electricity,

The Senate took this task upon itself. They put the brakes a massive 80-plus page energy overhaul bill that passed the House in March in less than six weeks, and the bill died at the end of the session.

Many senators said the process earlier this year was rushed. They remembered the last time they trusted an overhaul bill backed by utilities.

State-owned Santee Cooper and private South Carolina Electric & Gas used those rules passed 15 years ago to put ratepayers on the hook for billions of dollars spent on two new nuclear reactors that never generated a watt of power before construction was abandoned because of rising costs.

But those dire memories are being mixed with dire predictions of a state running out of power.

Unusually cold weather on Christmas Eve 2022 along with problems at a generating facility nearly led to rolling blackouts in South Carolina. Demand from advanced manufacturing and data centers is rising. If electric cars grow in popularity, more power is needed. And a state that added 1.3 million people since 2000 has a lot more air conditioners, washing machines and charges for devices, the utility leaders said.

Senators stopped Duke Energy’s president in South Carolina, Mike Callahan, in middle of his presentation after he told them his utility’s most recent predictions for growth in electricity usage over the rest of this decade were eight times more than they were just two years ago.

“Growth is here, and much more is coming. We need clear energy policy to plan for that growth,” Callahan said,

The utility leaders told senators their companies need to know what kind of sources of power — natural gas, solar, nuclear, wind or others — the state wants to emphasize. They would like to have a stable rules from regulators on how they operate.

“A quick no is a lot better to us than a long-term maybe,” Santee Cooper CEO Jimmy Staton said.

Another complicating factor are federal rules that may require utilities to shut down power plants that use coal before there are replacements with different sources online, Staton said.

Others aren’t so sure the state needs a rapid increase in power generation. Environmentalists have suggested the 2022 problems that led to blackouts were made worse because power plants were nowhere near capacity and better cooperation in the grid would allow electricity to get to where its needed easier.

Those less bullish on the overhaul also are urging the state not to lock in on one source of power over another because technology could leave South Carolina with too much power generation in inefficient ways.

There will likely be plenty of discussion of data centers that use a lot of electricity without the number of jobs, property taxes or other benefits a manufacturer provides.

Staton estimated about 70% of Santee Cooper’s increased demand is from data centers.

“We clearly need them. I don’t want to go back in time,” committee chairman Republican Senate Majority Leader Shane Massey said. “What I’m trying to get at is a better understanding, a better handle on how much of the projected growth is based on data centers or on everything else.”

Massey has been hard on Dominion Energy, which bought South Carolina Electric & Gas after the abandoned nuclear project at the V.C. Summer Nuclear Station. But Dominion Energy South Carolina President Keller Kissam said it is important that all options, including a new nuclear plant, remain on the table.

“Everybody thinks if we build anything that we’re going to absolutely repeat what we did with V.C. Summer” Kissam said. “Well, I promise you, that ain’t gonna happen. OK? I’ll pack up and leave.”

Massey said he appreciated Kissam’s candor and felt he was a straight shooter, but there are a lot of other people involved in the failed project who lied and hid problems.

“I can’t put that behind me. And I don’t think a lot of people can put that behind them,” Massey said.

Massey’s goal is to have a bill ready by the time the 2025 session starts in January.

Vineyard Wind said it has obtained federal approval to resume construction of the wind farm – work that was suspended following the partial collapse of a previously installed turbine blade on July 13.

A press release issued at 7 a.m. Tuesday morning said the Bureau of Safety and Environmental Enforcement had given the developers of the wind farm permission to resume the installation of towers and nacelles (which sit atop the tower and convert wind energy into electricity), but a suspension remains in effect for turbine blades and power generation.

Vineyard Wind is a 62-turbine project and only 24 had been completed at the time of the accident. Work is resuming on the remaining 38 turbines but blades cannot be installed nor power produced under the terms of the revised suspension order. Of the 24 completed turbines, 11 were generating electricity at the time of the incident and 13, including the one that broke, were undergoing testing.

In a joint press release, Vineyard Wind and GE Vernova, the manufacturer of the wind turbines, said a barge departed the New Bedford Marine Commerce Terminal Tuesday morning for the wind farm carrying turbine components, including several tower sections and one nacelle.

“The vessel will also carry a rack of three blades solely for the purpose of ensuring safe and balanced composition for the transport,” the press release said, adding that the blades will not be installed and will be returned to New Bedford later in the week.  

The press release said the Bureau of Safety and Environmental Enforcement revised its suspension order after examining records and a structural load analysis conducted by a third party. The federal agency had no mention of a revised suspension order on its website Tuesday morning.

Vineyard Wind and GE Vernova also said “a substantial amount” of what remained of the damaged blade was cut away on Sunday and Monday.

“During the operations, Vineyard Wind and GE Vernova mobilized maritime crews on multiple vessels nearby to secure as much debris as possible for immediate containment and removal as well as land-based crews managing debris recovery,” the press release said. ”Vineyard Wind and GE Vernova are currently assessing next steps to complete any additional cutting necessary at the earliest opportunity, secure and remove the debris on the turbine platform, remove the blade root, and address the debris on the seabed.”

The blade incident at Vineyard Wind, a joint venture of Avangrid and Vineyard Offshore, has been a major setback for the first industrial scale wind farm in the United States. Foam and fiberglass from the turbine has washed up on Nantucket and other beaches on the Cape and Martha’s Vineyard and raised questions about wind energy at a time when the industry is trying to ramp up production.

A preliminary investigation by GE Vernova has suggested the blade breakdown was caused by a “manufacturing deviation” – specifically insufficient bonding of the blade materials. The company has indicated no problems with the design of the Haliade-X blade, which is 853 feet tall.

It was unclear when Nantucket officials were notified about the resumption of construction of the wind farm. Updates posted on the town website indicated the Select Board was aware of the efforts beginning on Sunday to remove more of the damaged turbine blade.

During an executive session on Thursday, the Select Board met to discuss “strategy with respect to potential litigation in connection with Vineyard Wind,” according to the agenda.

This article first appeared on CommonWealth Beacon and is republished here under a Creative Commons license.

U.S. wind installations produced 45.9 gigawatt hours (GWh) of electricity in March 2024, eclipsing the 38.4 GWh generated by coal-fired power plants. The following month, coal-fired generation dropped to 37.2 GWh while wind generation blew away its previous high mark, churning out 47.7 GWh.

EIA included this lovely chart which demonstrates the steady growth of wind generation and the slow decline of our reliance on coal:

Installed wind power generating capacity has grown from 2.4 GW in 2000 to 150.1 GW in April 2024, according to the EIA. By contrast, many coal plants have retired over the past 25 years, and coal capacity has been roughly cut in half, from 315.1 GW in 2000 to 177.1 GW by April 2024. 22.3 GW of U.S. coal-fired electric generating capacity has been retired over the past two years, and operators plan to retire 2.8 GW more in 2024, data from EIA’s July Monthly Energy Review show.

Other sources of electricity generation have also increased as coal-fired generation has declined, notes the EIA. Since 2000, electricity from solar power has increased by 99.1 GWh, and generation from natural gas, which is often more price competitive than coal in electricity market dispatch, has gone up by 287.6 GWh.

And all good things, they say, never last

Wind power typically produces the most electricity in the springtime in the United States, so it’s not likely wind will permanently remain ahead of coal generation (at least not yet). During the first four months of 2024, coal-fired generation was 15% greater than wind generation in the United States.

You may recall something like this happening last year- when U.S. wind generation exceeded coal-fired generation for the first time in April 2023. It took 11 months later for that to happen again. But if you’re searching for silver linings, this spring marks the first time U.S. wind generation has exceeded coal-fired generation for two months in a row.

And there’s more capacity on the way. Operators expect 7.1 GW of wind capacity to come online in the United States in 2024, according to EIA’s July Monthly Energy Review. That’s a substantial amount, albeit a far cry from the 14 GW+ added in both 2020 and 2021, which were record years for growth in the industry.

And finally- a parting gift for those who either didn’t get the headline or understood the reference and now have that Prince slow jam stuck in their heads:

“We are pleased to announce this important transaction with LS Power, which is the result of a highly competitive strategic sale process,” said Chris Huskilson, CEO of AQN. “This major milestone, coupled with our previously announced agreement to support the sale of our Atlantica shares, delivers on our plan to transform AQN into a pure play regulated utility, optimize our regulated business activities, strengthen our balance sheet, and enhance our quality of earnings. We are confident that our path towards a pure play regulated utility supports our objective to create long term value for our customers and shareholders.”

The sale is subject to the satisfaction of customary closing conditions, including the approval of the U.S. Federal Energy Regulatory Commission and approval under applicable competition laws. The Company expects the transaction to close in the fourth quarter of 2024 or the first quarter of 2025 and to receive estimated cash proceeds of approximately $1.6 billion (excluding the earn out) after repaying construction financing, and net of taxes, transaction fees, and other closing adjustments.

Algonquin Power & Utilities isn’t the only company to shed its utility-scale renewables business lately. Last year, Brookfield Renewable announced it would buy Duke Energy’s utility-scale renewable energy business for $2.8 billion.

Duke began shopping its renewables division in September 2022 as it sought to focus on the growth of its regulated businesses. The sale agreement included more than 3,400 MWac of utility-scale solar, wind, and battery storage across the U.S., net of joint venture partners ownership, in addition to operations, new project development, and current projects under construction.

Also last year, RWE AG finalized its $6.8 billion acquisition of all shares in Con Edison Clean Energy Businesses. The transaction made the newly dubbed RWE Clean Energy one of the five largest renewable energy companies in the U.S. and the country’s second-largest solar owner and operator.

The acquisition included a portfolio of 8 GW of renewable energy projects and a development platform of more than 24 GW. Around 60% of the portfolio is onshore wind and 40% solar. Con Edison said it continues to invest in clean energy transmission projects, building electrification, energy efficiency, electric vehicle infrastructure, battery storage, and other technologies. The utility said it also wants to invest in and operate renewable generation in New York.

Originally published in Renewable Energy World.

Top officials at GE Vernova said they believe a “manufacturing deviation” at a facility in Canada is the likely cause of a turbine blade breakdown at Vineyard Wind 1 that resulted in foam and fiberglass washing up on Nantucket.

Scott Strazik, the CEO of GE Vernova, said there is no indication of an engineering design flaw with the turbine blade. He said the company is re-inspecting all of the 150 blades that have been manufactured at a plant in Gaspe, Canada, to see if the problem occurred with other blades.

Strazik said the deviation — later identified as a “insufficient bonding” — should have been caught during the company’s quality assurance process. He said the re-inspection process will rely on ultrasound and other techniques to identify any problems. The Vineyard Wind 1 project will remain on pause while the investigation of what went wrong with the blade is conducted.

“I have a high degree of confidence we can do this,” Strazik said in a call with financial analysts in connection with the company’s second quarter earnings release. “We’re not going to talk about the timeline today. We have work to do.”

Strazik added: “We are going to be thorough instead of rushed.”

In a filing with the Securities and Exchange Commission, GE Vernova appeared to take full responsibility for the situation and the suspension of construction at Vineyard Wind 1 ordered by the US Bureau of Safety and Environmental Enforcement, or BSEE.

“We do not have an indication as to when BSEE will modify or lift its suspension order,” the filing states. “Under our contractual arrangement with the developer of Vineyard Wind, we may receive claims for damages, including liquidated damages for delayed completion, and other incremental or remedial costs. These amounts could be significant and adversely affect our cash collection timelines and contract profitability. We are currently unable to reasonably estimate what impact the event, any potential claims, or the related BSEE order would have on our financial position, results of operations, and cash flows.”

Strazik said the Cambridge-based company is continuing to install turbines at the Dogger Bank wind farm in the United Kingdom, which is using the same 13-megawatt Haliade-X turbines as Vineyard Wind 1. Previously, one of the blades there broke but that was blamed on a faulty installation.

The Nantucket Select Board met in executive session on Tuesday to discuss a legal strategy going forward with GE Vernova, the manufacturer of the turbines, and the wind farm developers, Avangrid and Copenhagen Infrastructure Partners. The board is expected to hold a public meeting where the situation will be discussed Wednesday evening.

This article first appeared on CommonWealth Beacon and is republished here under a Creative Commons license.

On Friday, the CPUC proposed an initial need determination of up to 7.6 GW of offshore wind, up to 1 GW of enhanced geothermal systems, up to 1 GW of multi-day long-duration energy storage (LDES), and up to 1 GW of LDES with a discharge period of at least 12 hours.

This proposal stems from provisions of Assembly Bill 1373 (Stats. 2023, Ch.367), signed by Governor Gavin Newsom in 2023. AB 1373 authorizes the CPUC to request that the Department of Water Resources (DWR) conduct centralized procurement of certain eligible long lead-time (LLT) resources on behalf of customers of all load-serving entities (LSEs) under the Commission’s integrated resource planning (IRP) purview. Those long lead-time resources include offshore wind.

The plan will be heard, at the earliest, at the Commission’s meeting on August 22, 2024. By September 1, the Commission is required to make an initial need determination for procurement using a centralized procurement mechanism. If a need is found, within six months the Commission may then request DWR to exercise the centralized procurement mechanism.

The amounts selected are maximum amounts, according to the CPUC. Once a procurement request is made, DWR will conduct solicitations and evaluate the quality of bids received, including costs and ratepayer risk provisions, and may procure anywhere between zero and the upper limits included in this decision. This flexibility will facilitate cost containment and minimize ratepayer risks.

The resources selected by CPUC will help California achieve its greenhouse gas (GHG) emissions reduction goals for 2045 and represent emerging technologies that need to achieve economies of scale to bring costs down, the Commission says. However, the cost of these investments will ultimately impact electricity bills. In its proposal, CPUC maintains all possible efforts should be made to contain costs, reduce ratepayer risk, and seek other sources of funding to reduce development costs and share in the long-term costs and benefits.

This proposal also requests that, for this LLT procurement, DWR convene a procurement group that includes representatives from LSEs. In addition, the decision sets a tentative schedule of solicitations, asking DWR to conduct two rounds of solicitations for LDES and EGS, beginning in 2026, and three rounds of solicitations for OSW beginning in 2027. The Commission will reevaluate the need determination for additional LLT resources in every IRP cycle when considering a Preferred System Plan portfolio. In the next IRP cycle, the Commission will specifically evaluate LSE progress toward LLT procurement requirements in D.21-06-035, and consider whether an additional need determination for conventional geothermal resources for CPE procurement is necessary.

Earlier this month, the California Energy Commission (CEC) adopted a comprehensive strategic plan guiding the development of offshore wind. The plan outlines analysis and strategies to deploy floating turbines off the state’s central and northern coasts with a goal of 25,000 MW of capacity by 2045, enough to power 25 million homes. There are nearly 35 GW of renewable resources on California’s grid today, but the state is believed to need an additional 148 GW to reach its 2045 goal, likely requiring ocean development.

I&M submitted the following plans to the Michigan Public Service Commission (MPSC):

• Elkhart County: Solar, 100 MW
• Hoosier Line: Solar, 180 MW
• Meadow Lake: Wind, 100 MW
• Lawrenceburg: Natural Gas. 143 MW

Lawrenceburg will serve as a capacity-only agreement, which enables I&M to buy capacity and not the energy produced. 143 MW represents a Michigan-specific contract value. Plans for these projects were also submitted by I&M to the Indiana Utility Regulatory Commission (IURC) in June 2024.

I&M will purchase the power generated from the independently operated wind and solar power plants. Both solar generation plants will be built by private developers.

Previously announced in 2022, the Elkhart County Solar Plant details have been updated for the 2024 filing. Plans before the MPSC would also provide I&M the ability to include 143 MW of generation capacity from an existing natural gas facility in Dearborn County, near Lawrenceburg, Ind.

“I&M is committed to fully supplying the energy needs of our customers now and into the future,” said Steve Baker, I&M president and chief operating officer. “Our goal is to develop and reliably operate a robust energy portfolio, with a focus on resource adequacy, affordability and environmental sustainability.”

I&M said it is in the process of a “major” generation transformation. If approved, these resources would complement I&M’s current clean-energy generation, which includes five solar power plants; wind power from four plants; six hydro-electric plants; and the Cook Nuclear Plant. I&M also continues the development of two additional solar facilities, totaling 469 MW, previously approved by both the IURC and MPSC. I&M’s coal-fueled plant in Rockport, Ind., will be fully retired in 2028. More than 85% of energy I&M generated in 2023 was carbon-emission free.