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December 8, 2025

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Entergy Out-of-Cycle Requests Win MISO Board OK

By Chris O’Malley

CARMEL, Ind. — Over the objections of transmission developers and independent power producers, MISO’s Board of Directors voted unanimously Thursday to approve Entergy’s request for $217 million in out-of-cycle transmission projects.

There was no discussion by the board nor comments from stakeholders on the topic.

The outcome seemed all but certain following a unanimous vote Tuesday by MISO’s Board of Directors System Planning Committee to recommend that the full board approve Entergy’s requests.

Most of the opposition centered on the largest of the Entergy projects, a $187 million project to serve additional load in the Lake Charles, La. industrial zone in the midst of an economic revival.

Opposing stakeholders have alleged the increased load is speculative, that the project is beyond what is needed for a base reliability upgrade and that there was inadequate stakeholder review.

They also wanted a shot at competing for the project.

On Tuesday MISO staff outlined a checklist of steps taken that they say conforms with tariff and business practice manual procedures.

The bulk of the controversial Lake Charles project involves adding a 500 kV tap line that will extend seven miles to a new substation in Lake Charles, where Entergy said numerous industrial customers have committed to adding facilities.

MISO studied alternatives, including upgrading a 230 kV line and providing supply from more distant sources, but concluded they were less effective, said MISO Director of Planning Jeff Webb. “This is a straightforward, and I think ideal, solution,” Webb told the committee last week.

The committee pointed to an April 2 letter from Louisiana Public Service Commissioner Eric Skrmetta that expressed dissatisfaction with the review of the projects at MISO, calling on MISO to streamline the out-of-cycle approval process.

“Nothing should be permitted to interfere with the location of significant new load in southwest Louisiana and the economic benefits it will bring to the people of this state,” wrote Skrmetta. “…The consideration of these projects has gone on long enough. Second, numerous stakeholders have expressed dissatisfaction with MISO’s out-of-cycle consideration and approval process.”

Webb told the committee that MISO had 16 OOC projects last year and seven in 2013. Director Baljit “Bal” Dail, who is not a member of the committee but sat in on Tuesday’s meeting, asked Webb why Lake Charles was so controversial.

Webb cited the size of the project and said he recalled only one other controversial project over the years — also one of substantial size.

Clearly, large projects would be more lucrative for transmission developers hoping for a competitive project. MISO staff have maintained that Lake Charles is a reliability project, which would be ineligible for competition.

Board Chairman Judy Walsh — who substituted as chair of the meeting due to a medical issue involving chair Mike Evans — said the OOC process is designed to prevent MISO from becoming a “stumbling block” to needed reliability upgrades.

“In order for this process to work it has to be fast. It has to be efficient,” she said.

Earlier this month, in response to the controversy over Entergy’s request, MISO launched discussions that could lead to refinements in its procedures for handling out-of-cycle requests. (See MISO Seeks Stakeholder Input on Out-of-Cycle Process amid Entergy Controversy.)

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MISO to Consumer Sector: No Money for You

By Chris O’Malley

CARMEL, Ind. — MISO has declined a request by the Public Consumer Advocates sector for $200,000 to help cover its legal costs in a fight over MISO transmission owners’ return on equity.

The decision was announced Wednesday at the MISO Advisory Committee.

“We don’t have a mechanism to send them money,” said MISO General Counsel Stephen Kozey, adding there was no show of stakeholder support for such funding.

The Public Consumer Advocates sector consists of both non-profit groups and government agencies that represent consumers in utility cases before state regulators.

MISOIt decided to enter the ROE battle after settlement talks ordered by the Federal Energy Regulatory Commission between industrial customers and TOs broke down last year. It is the consumer sector’s first-ever litigation in a FERC case.

The consumer sector made the request at the Advisory Committee in February, saying it lacks the deep pockets for legal costs.

Robert Mork, deputy consumer counselor for the Indiana Office of Utility Consumer Counselor, said the Consumer Advocates sector has been supportive of MISO over the years. “We have to say we’re surprised and disappointed by MISO’s decision on this,” Mork said.

He reminded the committee that FERC Order 719 was created in part to improve the responsiveness of RTOs to electric consumers.

Mork didn’t elaborate on the group’s response to the funding denial but said that the consumer sector would have further discussions with MISO, the Organization of MISO States and with FERC.

MISO industrial customers initiated the ROE dispute last year, contending that transmission operators’ current base ROE — 12.38% except for American Transmission Co., at 12.2% — is too high (EL14-12). On April 3, the consumer advocates asked FERC for approval to amend the group’s intervention by adding allies from Arkansas, Kentucky, Louisiana, Montana and Illinois. (See MISO TOs Seek Base ROE of 11.39%.)

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Federal Energy Review Calls for Billions of Dollars in Spending on Infrastructure

By Suzanne Herel

The Obama administration’s first Quadrennial Energy Review presents a roadmap for returning the U.S. to a post-World War II level of investment in infrastructure, creating 1.5 million jobs while transforming the nation’s electric grid and oil and gas pipelines, Vice President Joe Biden said Tuesday from PECO Energy headquarters in Philadelphia.

“The U.S. is in the midst of an energy transformation that will allow us to remain the energy epicenter of the world,” Biden said. “To maintain that position, we need a 21st-century infrastructure.”

President Obama ordered the review — similar to the Pentagon’s Quadrennial Defense Review, a widely followed assessment of the nation’s defense — to provide a comprehensive “multi-year roadmap” for U.S. energy policy, with an assessment of current policies and recommendations for additional executive and legislative actions, including priorities for research, development and demonstration programs to support innovation. A White House task force, headed by the president’s top science, technology and climate change advisors and including more than 20 federal agencies, took part in the project, which included public meetings with stakeholders around the country. (See Looking to Build Infrastructure, Moniz Comes to Wall Street.)

The effort is intended “to provide policymakers, industry, investors and other stakeholders with unbiased data and analysis on energy challenges, needs, requirements and barriers that will inform a range of policy options, including legislation.” Each installment of the report will focus on one part of the energy “value chain.”

The 348-page report released Tuesday focuses on the energy transmission, storage and distribution system, which is facing new challenges from climate change, environmental policies and innovations in oil and natural gas production.

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New Sources

Since 2008, solar electricity generation has increased 20-fold, Biden said, and wind energy has more than tripled. In that time, the U.S. has become the world’s No. 1 producer of natural gas, and the nation has reduced its dependency on foreign oil.

Meanwhile, new challenges have emerged regarding national security, increasingly strict clean energy standards and an aging transmission system that isn’t geographically aligned with the needs of renewable generation.

“Changes in the geography of domestic energy production stress the ability of existing infrastructures to move both liquid fuels and electricity from supply regions to demand centers,” the White House said in a fact sheet. “Congestion in the nation’s ports, waterways and rail systems affect the timing and cost of moving not just energy products, but all commodities.”

Aging Infrastructure, Need for Resiliency

Biden noted that half of the nation’s 2.6 million miles of gas pipelines were constructed in the 1950s and 60s, and it would cost about $270 billion to repair them all.

The solution, he said, includes permitting new pipelines more quickly and finding ways for companies to recover their investment without burdening ratepayers.

The system also needs to gird for events such as 2012’s Superstorm Sandy, said Biden, citing it as evidence of climate change.

Between 2003 and 2012, an estimated 679 widespread power outages occurred, he said, costing from $18 billion to $33 billion per year, depending on the nature of the event, he said.

“The threat’s real,” he said. “We’re expecting sea levels to rise by 2030.” In some places, he said, “we will need to literally raise the substation.”

The report cites estimates of billions of dollars to achieve its recommendations. Grid modernization alone is expected to run $3.5 billion annually over 10 years.

Workforce Impacts

Biden stressed the positive effect the investments will have on the workforce.

About 1 million people were employed in energy transmission, storage and distribution jobs in 2013 and over the next five years, about 15% of them will be eligible to retire. The administration says infrastructure spending could add 1.5 million additional energy sector jobs.

“These are middle-class jobs,” he said. “These are the jobs that used to exist at the turn of the 20th century.

“Investing in our infrastructure creates of a virtuous cycle of creating good-paying jobs and attracting companies.”

Accompanying the announcement were two related executive actions.

The U.S. Department of Energy has created the Partnership for Energy Sector Climate Resilience, aimed at strengthening the system against extreme weather and climate change impacts. It will kick off with an April 30 meeting with the CEOs of 17 member companies, including Exelon, Dominion Virginia Power, Pepco Holdings Inc., Public Service Electric & Gas, the New York Power Authority, the Tennessee Valley Authority, National Grid and Entergy.

In addition, the U.S. Department of Agriculture introduced a plan to spend $72 million to support six new rural electric infrastructure projects.

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Entergy Out-of-Cycle Request Wins Committee OK; Full Board Approval Likely

By Chris O’Malley

CARMEL, Ind. — MISO’s Board of Directors System Planning Committee voted unanimously Tuesday to approve Entergy’s request for $217 million in out-of-cycle transmission projects, setting up a likely approval by the full board Thursday.

The competitive transmission developer and independent power producer segments have steadfastly opposed the largest of the Entergy projects, a $187 million project to serve additional load in the Lake Charles, La. industrial zone in the midst of an economic revival.

They’ve alleged the increased load is speculative, that the project is beyond what is needed for a base reliability upgrade and that there was inadequate stakeholder review. They also would like a shot at competing for the project.

But once again, MISO staff outlined a checklist of steps taken that they say conforms with tariff and business practice manual procedures.

The bulk of the controversial Lake Charles project involves adding a 500 kV tap line that will extend seven miles to a new substation in Lake Charles, where Entergy said numerous industrial customers have committed to adding facilities.

entergy

MISO studied alternatives, including upgrading a 230 kV line and providing supply from more distant sources, but concluded they were less effective, said MISO Director of Planning Jeff Webb. “This is a straightforward, and I think ideal, solution,” Webb told the committee.

No stakeholders spoke in opposition.

The committee pointed to an April 2 letter from Louisiana Public Service Commissioner Eric Skrmetta that expressed dissatisfaction with the review of the projects at MISO, calling on MISO to streamline the out-of-cycle approval process.

“Nothing should be permitted to interfere with the location of significant new load in southwest Louisiana and the economic benefits it will bring to the people of this state,” wrote Skrmetta. “…The consideration of these projects has gone on long enough. Second, numerous stakeholders have expressed dissatisfaction with MISO’s out-of-cycle consideration and approval process.”

Webb told the committee that MISO had 16 OOC projects last year and seven in 2013. Director Baljit “Bal” Dail, who is not a member of the committee but sat in on Tuesday’s meeting, asked Webb why Lake Charles was so controversial.

Webb cited the size of the project and said he recalled only one other controversial project over the years — also one of substantial size.

Clearly, large projects would be more lucrative for transmission developers hoping for a competitive project. MISO staff have maintained that Lake Charles is a reliability project, which would be ineligible for competition.

Board Chairman Judy Walsh — who substituted as chair of the meeting due to a medical issue involving chair Mike Evans — said the OOC process is designed to prevent MISO from becoming a “stumbling block” to needed reliability upgrades.

“In order for this process to work it has to be fast. It has to be efficient,” she said.

Last week, in response to the controversy over Entergy’s request, MISO launched discussions that could lead to refinements in its procedures for handling out-of-cycle requests. (See MISO Seeks Stakeholder Input on Out-of-Cycle Process amid Entergy Controversy.)

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FERC Clarifies NYISO ICAP Market Power Mitigation Order

By William Opalka

The Federal Energy Regulatory Commission on Thursday clarified unresolved issues from a previous order on the installed capacity market in New York that have been pending for nearly three years (EL11-42).

new yorkIn it, FERC accepted NYISO’s filings in response to the June 22, 2012, order, which directed the ISO to clarify how the mitigation exemption test and offer floor calculations are implemented. The commission had found merit in a complaint by NRG Energy and several other generators that NYISO’s implementation of the buyer-side mitigation rules lacked transparency.

NYISO said the 2012 order was unclear with respect to the comparison made between the default offer floor and unit net cost of new entry in determining the offer floor. FERC said NYISO’s interpretation is correct, in that the value for unit net CONE to be used should be only the first-year value of the three-year average of annual unit net CONE.

FERC also:

  • Confirmed NYISO’s method of adjusting the offer floor for inflation.
  • Ordered NYISO to change how it adjusts unit net CONE for inflation.
  • Affirmed its finding that NYISO has justified its use of natural gas futures prices and historical prices in its net CONE calculations.
  • Ordered NYISO to incorporate language allowing the Market Monitoring Unit to consider all factors relevant to mitigation exemption and offer floor determinations in its reports reviewing whether the ISO’s mitigation and exemption determinations were conducted in accordance with its Market Administration and Control Area Services Tariff.

FERC also ruled Thursday in a case related to the ICAP, in which Astoria Generating and TC Ravenswood had alleged that NYISO’s buyer-side market mitigation provisions were improperly administered (EL11-50). The order generally denied rehearing, but it ordered the ISO to use the Astoria II plant’s actual cost of capital in its mitigation exemption determination.

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FERC Denies Rehearing Requests on NYISO Order 1000 Compliance Filing

By William Opalka

The Federal Energy Regulatory Commission accepted most of NYISO’s and New York Transmission Owners’ second compliance filing for Order 1000 while denying multiple requests for rehearing (ER13-102).

The parties have 30 days to submit a further compliance filing.

FERC denied LS Power’s request for rehearing, saying that cost-effectiveness is appropriately assessed in NYISO’s proposed evaluation process.

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NYISO transmission lines. (Click to zoom.)

The commission previously expressed concern that NYISO’s regional cost allocation method for public policy transmission projects could cause unnecessary delays for transmission developers seeking regional cost allocation. FERC accepted the ISO’s proposal that the process for deciding the cost allocation method run in parallel with state siting proceedings.

FERC also:

  • Accepted NYISO’s revisions clarifying how it will review transmission owners’ local transmission plans to determine whether alternative transmission solutions might meet reliability needs. FERC noted that NYISO and the Long Island Power Authority have agreed to tariff revisions that allow LIPA to determine whether “a proposed transmission need driven by public policy requirements requires a physical modification to transmission facilities located solely within the Long Island Transmission District, while also allowing the New York [Public Service] Commission to determine that a transmission need driven by public policy requirements identified by LIPA is a regional transmission need driven by public policy requirements.”
  • Accepted NYISO revisions on who may qualify as an approved transmission developer. A prospective transmission developer will be allowed to submit a detailed plan for financing, developing, constructing, operating and maintaining a transmission facility. The ISO may require information about transmission facilities that the prospective developer has already constructed.
  • Ordered NYISO to treat whether or not a nonincumbent developer has received its siting permits and other authorizations under New York state law as just one factor in the ISO’s selection process.
  • Ordered revisions to clarify that only disputes within the New York PSC’s sole jurisdiction may be subject to judicial review in state courts.
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Consumers Energy, Wolverine Power OK’d to Reclassify Facilities as Transmission Assets

By Chris O’Malley

The Federal Energy Regulatory Commission on Thursday approved requests by two Michigan electric utilities to reclassify a number of distribution facilities as transmission assets within MISO.

FERC granted requests by Consumers Energy (ER15-910) and Wolverine Power Supply Cooperative (ER15-976). Consumers initially filed its reclassification request with the Michigan Public Service Commission, which last October approved a settlement (U-17598) between the utilities and Michigan Electric Transmission Co. (METC). The PSC approved a settlement over Wolverine’s reclassification of the assets from “excluded transmission” to “included transmission” in January (U-17742).

Consumers transferred its transmission assets in 2001 to then-subsidiary METC. A year later, it sold METC to another company, which sold it to current owner ITC Holdings.

In 2012, however, ReliabilityFirst Corp. informed Consumers that its audit had determined that a small set of the company’s distribution facilities were actually transmission facilities.

Consumers said its own analysis confirmed RFC’s findings and identified other assets that it said were similarly misclassified.

In total, Consumers said, the facilities to be reclassified have a net value of $34 million, representing 1.32% of Consumers’ distribution plant. They include equipment in 69 substations on 138-kV transmission lines, 65 138-kV line segments and six substations connecting those lines to Consumers’ bulk power substations.

Consumers noted that FERC previously stated that the 100-kV threshold has been among the factors in determining whether an asset is part of the bulk electric system.

Consumers plans to sign the MISO Transmission Owners Agreement and will join the Michigan Joint Zone, under MISO Rate Schedule 11. FERC also ordered Wolverine to include its reclassified facilities in the Michigan Joint Zone.

Ratepayer Implications Minimal

Consumers said the reclassification will benefit consumers by placing the transmission assets under “the functional control” of MISO. Becoming a transmission owner will allow it to more fully participate in the RTO, Consumers said.

Consumers said the increased costs of the reclassification are negligible, with an incremental revenue requirement of about $50,000, or .001% of Consumers’ $3.9 billion base rate revenue.

The utility noted that some of the assets are used to provide wholesale distribution service. “To avoid a potential double recovery, Consumers will remove the applicable assets from the wholesale distribution service rate and include them instead under its forthcoming transmission rates under the MISO Tariff.”

Wolverine also said a portion of its reclassified assets are also used to provide wholesale distribution service. To avoid a double recovery, Wolverine said it will coordinate with MISO to separately submit a filing to terminate its wholesale distribution service rate with the Zeeland Board of Public Works.

Wolverine said the net plant value of its updated list of included transmission facilities is $249.91 million, or an increase of nearly $16 million.

Tom King, Wolverine’s director of regulation and policy, told RTO Insider that the co-op is still calculating the impact of the change but expects the reclassification to be positive for its members.

Consumers officials could not be reached for comment.

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Company Briefs

The Tennessee Valley Authority has purchased a 700-MW gas-fired combined-cycle plant in Ackerman, Miss., from Quantum Choctaw Power. The plant is a two-one-one configuration and is the sixth combined-cycle plant TVA has purchased or built since 2007. TVA said in February, when it announced board approval of the purchase, that it would pay $340 million for the plant. The authority is retiring many of its coal units and either building or purchasing gas-fired generation in an attempt to meet emissions mandates.

Quantum Choctaw was owned by Quantum Utility Generation, an independent power producer that has coal- and gas-fired plants in Florida, Virginia and Mississippi, a solar project in Guam, and wind energy projects in Connecticut, Pennsylvania, Maine and Minnesota.

More: The Chattanoogan

TVA Has No Plans to Restart Construction of Bellefonte

The Tennessee Valley Authority’s 20-year plan for electricity generation sees the possibility of uprates at existing, operating nuclear stations and probably more natural gas and renewable generation, but its dormant Bellefonte nuclear plant doesn’t fit into any of those plans. The authority’s draft integrated resource plan is the subject of public hearings before it goes to the TVA board for a final vote in August.

Construction of the Bellefonte plant began near Hollywood, Ala., in 1974, but was abandoned in the 1980s after an investment of about $4.5 billion. The authority voted to restart construction of the plant in 2011, but that plan was killed in the face of slumping power demand the next year. The authority decided to go ahead with plans to complete Watts Bar Unit 2, another reactor that had been started in the previous century and then stopped. It is currently scheduled to go online by the end of this year.

More: Huntsville Times

National Grid Starts Construction on Advanced-Technology Solar Project

National Grid is starting construction of a 650-kW solar facility in Massachusetts that will test advanced technology ahead of the company’s plan to build 16 MW of solar generation in 19 sites in that state. The pilot project will test the use of new inverters, a vital component of the process of feeding solar energy into the grid. The move is part of the utility’s effort to contribute to the state’s goal of having 1,600 MW of solar by 2020. Much of the company’s efforts so far have been on connecting third-party solar generation to the grid, although it has solar generating facilities in five Massachusetts towns.

More: FierceEnergy

AWEA: Wind Industry Added 23,000 Jobs in 2014

The wind industry added 23,000 jobs in 2014, raising the total to 73,000 positions, according to the American Wind Energy Association. In its 2014 report, AWEA said 12,700 MW of wind projects were under construction as this year began. “These results show that extending the Production Tax Credit for wind power in 2013 was good for business in America,” AWEA CEO Tom Kiernan said. “We’ve got a mainstream, Made-in-the-USA product that supports jobs in every state and is gaining momentum. With a more predictable policy, we can add more jobs and keep this American success story going.”

More: PennEnergy

FirstEnergy’s Beaver Valley Loses Unit to Bad Pump Bearing

One of the reactors at FirstEnergy’s Beaver Valley nuclear station near Shippingport, Pa., went offline Wednesday when a pump supplying non-radioactive water to the steam generators shut down, probably due to a bad bearing. One of the two pumps serving Unit 1 showed signs of failing, and workers shut the reactor down at about 4 a.m. Repairs will take several days, a company spokeswoman said Thursday. Company officials said the other pump could serve the reactor at only 50% capacity.

More: PennEnergy

FE Delays Bruce Mansfield Decision Because of Possible PJM Auction Delay

FirstEnergy has decided to put off a final decision on whether to invest in a dewatering facility for coal ash control at its Bruce Mansfield coal-fired power plant until it knows when PJM’s annual capacity auction will be held. The company wants to see if the plant would clear the auction before deciding whether to invest in the dewatering facility. PJM has asked FERC for permission to delay the annual action, usually held in May, pending final commission rulings on its Capacity Performance proposal. FirstEnergy says it will now make the decision sometime this summer.

More: Pittsburgh Business Times

FirstEnergy Closes 3 Ohio Coal Plants

FirstEnergy, saying it was better to retire aging coal plants than retrofit them to make them conform to emissions mandates, has closed three coal-fired plants in Ohio.

The Ashtabula plant on the shores of Lake Erie, Lake Shore and Eastlake plants, all in northern Ohio, were shuttered last week. They were part of a list of nine the company announced in 2012 it would be retiring. Six of those nine have been decommissioned already. These are the last of that original list. The retirement of the final three was delayed until improvements could be made to transmission lines to accommodate the transmission of power in the absence of those plants. That work was completed at the cost of about $263 million, company spokeswoman Stephanie Walton said.

“There will be a period of shutdown activity, then the plant will be put into a safe and environmentally secure mode,” Walton said, describing the process for the Ashtabula plant.

More: Star Beacon

PPL Retiree Loses Bid to Have NRC Review Nuke Transfer Decision

The Nuclear Regulatory Commission has denied a request made by a former PPL employee to have the commission review its decision to transfer the operating licenses for the company’s sole nuclear plant to a projected merchant generation spinoff. Douglas B. Ritter asked the commission to hear arguments on the transfer, which the commission just formally approved.

PPL and assets associated with Riverstone Holdings are spinning off and forming Talen Energy. Ritter had raised questions about the Susquehanna nuclear plant’s operation under the new ownership, and about the plant’s decommissioning funds and waste storage. The commission based its decision on the lack of “admissible contention” in Ritter’s request.

“I’m disappointed that those issues have not been addressed publicly by the NRC,” said Ritter, who worked for 34 years at PPL and lives about four miles from the plant. “I feel like we the public are being kept in the dark by the NRC, but that’s big business, I guess.”

PPL said it expects to close on the Talen arrangement by the end of the second quarter.

More: The Morning Call

PPL Montana to Sell Retired Plant, Equipment

PPL Montana announced that it wants to sell the land, buildings and equipment of its retired J.E. Corette Steam Electric Station. The 153-MW plant, on 74 acres along the Yellowstone River near Billings, was built in 1968 and shut down last month. The company said its decision to retire the plant was based on the high cost of upgrades that would have been necessary to make it comply with emissions rules.

More: Great Falls Tribune

NextEra to Build 81-MW Solar Plant in Arkansas

NextEra Energy Resources is building an 81-MW solar plant in Arkansas County, Ark. The facility, in the Grand Prairie region of the county, will be the largest solar facility in the state. Entergy Arkansas has signed a 20-year power purchase agreement to buy the plant’s electricity, and a new substation will be constructed to transmit the power to Entergy Arkansas’ system. NextEra has applied with the state Public Service Commission to gain approval for the plant. Entergy and NextEra said the plant will be operational by mid-2019.

More: Entergy

ATC Names Mike Rowe as New CEO

Mike Rowe, an expert in asset management and construction, has been named the new CEO of American Transmission Co. Rowe will be taking the position of John Procario, who has headed up ATC since 2009. Procario announced his plans to retire last year.

Rowe has been with the Pewaukee, Wis.-based company for the past eight years, where he started as the vice president of construction, and later moved on to head the Asset Management, System Operations and Transmission Planning departments. He was promoted to executive vice president and chief operating officer in 2012. Before coming to ATC, Rowe was director of Engineering & Asset Management for Kansas City Power & Light. Before that, he spent 22 years with Commonwealth Edison in Chicago.

More: American Transmission Co.

NRG Pumps More Capital into Residential Solar

While many utilities are fighting the expansion of residential solar through challenges in state legislatures, NRG Energy is doubling down on its investment in that area. Having already fielded a company that specializes in home solar installations, NRG Home Solar, the energy giant announced it is pumping yet more money into the business. The company and its investment arm, NRG Yield, have formed a partnership that will invest up to $150 million in cash into Home Solar.

“With the completion of this partnership between the companies, we initiate a new phase in the growth strategy of the NRG Home business unit and NRG Yield,” says David Crane, CEO of NRG and chairman and CEO of NRG Yield.

More: Solar Industry

MYR Group Buys Eversource’s Transmission and Distribution Co.

MYR Group is buying E.S. Boulos, Eversource Energy’s electrical contractor that specializes in transmission, distribution and substation design and construction. ESB is headquartered in Westbrook, Maine. It was purchased by Eversource in 2001 and operated as a non-regulated company. Industry reports say the Illinois-based MYR is paying $11.4 million for the company.

More: Virtual Strategy

Millstone Nuke Worker Says He Was Fired for Reporting Co-worker’s Drug Use

A worker at Dominion Resources’ Millstone nuclear station in Connecticut told Nuclear Regulatory Commission officials that he was fired in retaliation for reporting a co-worker’s narcotic use. “I got fired for bringing up a safety issue, and you, the NRC, need to support me,” Stephen Lavoie said during the agency’s annual meeting with the Connecticut Nuclear Energy Advisory Council. NRC officials promised to look into Lavoie’s allegation. But Millstone spokesman Ken Holt said Lavoie was laid off because the demand for insulation workers had dropped. An independent investigator looked into Lavoie’s claim and found nothing to substantiate it, Holt said.

More: The Day; CBS Connecticut

Dominion Boosts Solar Fleet with Purchase of 20-MW Georgia Facility

Dominion Resources has purchased a 20-MW solar facility in Georgia, bringing the total amount of solar generation in its stable to 364 MW at sites throughout the U.S. Dominion paid an undisclosed amount for the Richland Solar Center in Twiggs County, Ga., from HelioSage Energy. It also secured a 20-year power purchase agreement with Georgia Power. David A. Christian, CEO of Dominion Generation, said the company wants to have 625 MW of contracted solar generation by the end of 2016. Dominion has set a goal of developing up to 400 MW of solar generation in Virginia alone by 2020.

More: Atlanta Business Journal; Street Insider

EPRI Names Gil Quiniones New Board Chairman

The Electric Power Research Institute has elected Gil Quiniones chairman of its Board of Directors. Quiniones is president and CEO of the New York Power Authority, the nation’s largest state-owned electric utility. Current board member Patricia Vincent-Collawn, CEO of PNM Resources, was elected vice chair. Five new members were also elected: Lisa Johnson, CEO of Seminole Electric Coop.; Warner Baxter, CEO of Ameren; Mark McCullough, executive vice president of generation at American Electric Power; William Spence, CEO of PPL; and Dr. Seok Cho, CEO of Korea Hydro and Nuclear Power.

More: EPRI

Investor in McClendon Firm Settles Chesapeake Claim for $25M

Energy & Minerals Group has settled a trade secrets lawsuit by paying Chesapeake Energy $25 million. Chesapeake claimed that former CEO Aubrey McClendon stole trade secrets from Chesapeake when he left to form his own firm, American Energy Partners. EMG is a major investor in American Energy Partners.

EMG had earlier described the claims against McClendon as meritless and has invested nearly $3 billion in McClendon-directed ventures. Chesapeake claimed that the information was used to acquire Utica Shale field drilling rights. The settlement releases one of American Energy Partners’ affiliates, American Energy-Utica, harmless in exchange for the $25 million and drilling rights to 6,000 acres.

The full terms of the settlement remain confidential, but the settlement size says a lot, one expert says. “Nobody settles a lawsuit by paying $25 million and signing over 6,000 acres of valuable oil and gas leases unless they are at least a little bit troubled by what they have learned,” said Erik Gordon, a professor at the University of Michigan.

More: Reuters

Dynegy CEO Says Coal Plants Ready to Meet Emissions Regs

Dynegy CEO Robert Flexon said in an interview last week with Bloomberg News that its coal-fired generation fleet is ready to meet the looming increased emissions rules. While other companies, such as American Electric Power, are retiring aging units, Dynegy has gone on a buying spree of coal-fired generation or already retired aging plants in advance of the Environmental Protection Agency’s Mercury and Air Toxics Standards implementation.

“Coal accounts for 48% of Dynegy’s generating capacity of 25,758 MW, which is enough to power 21 million homes,” Flexon said. “All of the plants are compliant with the MATS rules and the EPA’s cross-state pollution regulations that started to get implemented this year,” he said.

He also said he expects PJM to receive approval to delay its annual capacity auction while Capacity Performance rules are finalized.

More: Bloomberg News

Compiled by Ted Caddell

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FERC Rejects Rehearing Request on SPP Order 1000 Filing

By Rich Heidorn Jr.

The Federal Energy Regulatory Commission last week rejected LS Power’s request for rehearing on SPP’s Order 1000 procedures and accepted the RTO’s December compliance filing (ER13-366).

The transmission developer had challenged the commission’s October 2014 order allowing SPP to retain tariff provisions requiring consideration of state law and rights-of-way in the early stages of its competitive bidding process. The commission had made a similar finding in a ruling on PJM last May, reversing the directive it had originally given. (See Order 1000 Reversal: Reality Check or Surrender to Incumbents?)

FERC said LS Power’s challenge “seeks to expand the reach of Order No. 1000’s reforms by prohibiting SPP from recognizing state or local laws or regulations when deciding whether SPP will hold a competitive solicitation.”

The commission noted that while Order 1000 barred any federal right of first refusal for incumbent transmission owners in commission-jurisdictional tariffs, it did not require removal of references to state or local preferences.

While recognizing that FERC lacks jurisdiction to overrule state laws, Chairman Norman Bay issued a concurring statement that seemed to invite a constitutional challenge to state laws that prohibit nonincumbent developers from winning the right to build a transmission project.

“The Constitution limits the ability of states to erect barriers to interstate commerce. State laws that discriminate against interstate commerce — that protect or favor in-state enterprise at the expense of out-of-state competition — may run afoul of the dormant commerce clause,” wrote Bay, a former law school professor. “The commission’s order today does not determine the constitutionality of any particular state right-of-first-refusal law. That determination, if it is made, lies with a different forum, whether state or federal court.”

The commission also rejected LS Power’s challenge to SPP’s process for evaluating competitive bids, saying the RTO “has sufficiently demonstrated that the proposed weighting of its evaluation criteria is not unduly discriminatory and will result in a regional transmission planning process that selects more efficient or cost-effective transmission solutions.”

While it rejected LS Power’s rehearing bid, the commission said SPP’s rights-of-way provision is vague. It ordered the RTO to revise tariff language “that refers to ‘rights-of-way where facilities exist’ to make it consistent with the commission’s finding that retention, modification or transfer of rights-of-way remain subject to relevant law or regulation granting the rights-of-way.”

The commission said the revision would address a protest by South Central MCN, a competitive transmission company that plans to partner with electric cooperatives and municipal utilities in SPP. It denied South Central’s request to schedule a technical conference on RTO competitive bidding processes under Order 1000 as outside the scope of the SPP proceeding.

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ITP10 to Include 3 Scenarios for Clean Power Plan

By Rich Heidorn Jr.

TULSA, Okla. — SPP’s next 10-year transmission plan will consider three future scenarios to assess the potential impact of the Environmental Protection Agency’s Clean Power Plan, members agreed after a lengthy debate last week.

The Markets & Operations Policy Committee decided the 2017 Integrated Transmission Planning 10-Year Assessment will include one scenario assuming regional compliance with the EPA rule and one assuming state-by-state compliance. The third scenario will be a business-as-usual case that assumes the EPA rule is abandoned — due, for example, to a legal challenge or a change in leadership at EPA after the 2016 presidential election.

clean power plan
SPP’s 2015 10-year plan compared a business-as-usual case, which projected the need for 15.3 GW of new conventional generation at 60 sites, with a decreased baseload scenario, which projected a need for 21 GW of new conventional generation at 82 sites. The latter scenario assumed the retirement of all coal units less than 200 MW and a 20% reduction in hydropower capacity due to drought.

EPA plans to issue the final rule this summer. It is intended to reduce power generation CO2 emissions by 30% from 2005 levels.

SPP this month released a study estimating the RTO could comply with the rule through a regional approach that includes a $45/ton carbon adder and 7.8 GW of additional generation, most of it wind. The study estimated an annual cost of $2.9 billion in increased energy costs and capital spending for new gas and wind generation. It did not evaluate additional transmission that may be needed, an element ITP10 will seek to quantify. (See SPP: $45/ton Adder, Wind, Gas Meets EPA Carbon Rule.)

The Economic Studies Working Group had recommended use of three futures, including one that assumed increased load growth as a result of the elimination of the Clean Power Plan. MOPC members amended that to assume normal load growth — creating a business-as-usual scenario as a comparison with the regional and state-by-state compliance schemes.

Members first rejected a proposal to include a fourth future that included an “extreme” EPA final proposal. It won only 41% support. A second vote limiting the study to the regional and state compliance scenarios but allowing the working group to seek approval of a third future, also fell short at 57%.

Fundamental Questions

The debate over the study revealed fundamental questions over the RTO’s planning strategy.

“Once again we are doing the absolute minimum and not looking at the long-term future,” said Kristine Schmidt, vice president of regulated grid development for ITC Holdings.

Board of Directors Vice Chairman Harry Skilton said the 18-month timeline for completion of the study is too long. “This is unbelievably ridiculous that it takes this long,” he said.

Lanny Nickell, vice president for engineering, said the length of the study process reflects the incorporation of stakeholder input. “We have a very open and transparent stakeholder process,” he said. “That is very valuable, but it takes time.”

The debate continued during Wednesday’s meeting of the Strategic Planning Committee, as Skilton, Board Chairman Jim Eckelberger and member Phyllis Bernard called for changes.

Eckelberger said MOPC’s debate over whether it should spend $270,000 in planning staff salaries for a fourth future was shortsighted considering the at least $8 billion the RTO expects to spend on new transmission.

“We’ve got this all backwards,” he said. We’re “trying to put the right lines in the right place. We don’t want to misspend money. We don’t want to get it wrong. We want to have as much foresight as possible. We have not built the robust capability within SPP to get this right — and it’s one of our primary responsibilities.”

Steve Gaw, representing The Wind Alliance, said SPP needs information on a variety of generation sources it may call on under the EPA plan. “You can’t get there with two futures — or with three if one of them is a business-as-usual case.”

Skilton and Bernard also called for a broader range of scenarios.

“I’m not in favor of planning too far out, but I’m in favor of planning much more broadly — casting a really wide net,” she said. “But don’t necessarily try to project it too far forward because we don’t know what’s coming.”

Skilton said the RTO also should seek a shorter planning cycle — ideally six months instead of a two years.

“People have told me six months is impossible,” he acknowledged. “We may not get to six months but we won’t be at 24.”

Nickell said he would relay the board’s thoughts to the newly formed Transmission Planning Improvement Task Force, which has been charged with producing “more progressive, forward-thinking, regional planning processes that are more responsive” to the continued growth of SPP’s transmission system and markets in response to federal and state environmental regulations and reliability rules.

“If I could boil it down,” said Nickell, “you all said you want it bigger, better, quicker… more agile.”