Artificial Island Finalists Face Off in Tense Meeting

By Suzanne Herel

Four companies vying for a contract to address stability problems at Artificial Island squared off in a tense PJM Transmission Expansion Advisory Committee meeting Dec. 9 before an unexpected crowd that required organizers to employ an overflow room.

The meeting had the atmosphere of a political debate as representatives from Transource Energy, LS Power and Dominion Resources delivered 30-minute presentations pitching their proposals. The fourth contestant, Public Service Electric & Gas, used its time to attack Dominion’s plan for using what it called untested technology.

PJM planners expect to present a final recommendation at the Jan. 8 TEAC meeting, in time for consideration by the Board of Managers in February, said Steve Herling, vice president for planning.

All of the potential solutions involve new transmission lines connecting Artificial Island, home to the Salem-Hope Creek nuclear complex, to Delaware.

LS Power and Transource are proposing a southern crossing of the Delaware River. Dominion and PSE&G are proposing a northern route with an overhead crossing. Both paths are expected to face permitting challenges, according to Paul McGlynn, general manager of system planning.

LS Power’s proposal includes both overhead and submarine options for the river crossing, each of which would carry a binding cost cap of $146 million.

“We are the only company that has offered PJM a significant cost cap,” LS Power Vice President Sharon Segner said. “We are taking on risks associated with real-estate costs, environmental mitigation costs, overhead/submarine river crossing costs and routing costs.”

She also touted her project’s proposed timeline of 42 months.

Transource emphasized its 50-50 partnership with Pepco Holdings Inc. and said its submarine proposal will have the easiest time obtaining permitting.

While it has not agreed to a cost cap, the company would forego 50% of any return-on-equity incentives on costs from $203 million to $255.3 million and all such incentives on any costs exceeding $255.3 million.

Ronnie Bailey, manager of transmission planning for Dominion, emphasized among his proposal’s advantages a 36- to 48-month turnaround time. The project’s cost of $164 million to $174 million also carries the least risk of cost overrun, he said.

Dominion’s solution combines thyristor controlled series compensation (TCSC) technology with static VAR compensators (SVCs) to ensure stability.

While a third-party study commissioned by PJM concluded Dominion’s model “proved stable for all critical faults,” according to McGlynn, the technology was widely challenged at the meeting.

PSE&G led the attack. Instead of speaking on their own proposal, PSE&G representatives used their half-hour to deliver a 25-slide presentation bashing Dominion’s plan as untested and unsafe.

PSE&G also cited criticism by its sister company, PSEG Nuclear, the operator of the Salem and Hope Creek plants.

“The use of the second-largest nuclear site in the U.S. as a test bed for a first-of-its-kind transmission design is problematic and presents potentially dire consequences,” PSEG Nuclear Vice President Christopher Schwarz said in written comments. “The potential consequences arising from a failure of the proposed design to provide both stability and SSR (sub-synchronous resonance) protection when called upon are simply unacceptable from a nuclear safety perspective.”

Dominion’s Bailey called such comments “misinformation” based on the performance of conventional capacitors, not the modern devices Dominion would use.

“The bottom line is these things work, and it’s been vetted by PJM,” he said. “TCSC is now an option to mitigate SSR, and it’s nothing to be afraid of.”

For its part, PSE&G has agreed to a cost cap of $221 million for its proposal, which faces siting hurdles in crossing protected wetland and wildlife areas in New Jersey. (See Two of Four Artificial Island Finalists Offer Cost Caps.)

PJM planners had recommended PSE&G’s selection for the project but re-engaged the other three companies after being widely criticized this summer by environmentalists, New Jersey officials and spurned bidders. (See PJM Puts the Brakes on Artificial Island Selection.)

The project is PJM’s first under the Federal Energy Regulatory Commission’s Order 1000, which opens up transmission line projects to non-incumbent companies.

December 16, 2014June 15, 2023

Federal Briefs

Despite the hype, solar power still accounts for a fraction of U.S. electricity production, according a recent report by the Energy Information Administration.

The December 2014 Short-Term Energy Outlook estimates solar generation will make up only 0.6% of electricity generation in 2015. “While solar growth has historically been concentrated in customer-sited distributed generation installations, utility-scale solar capacity slightly more than doubled in 2013,” the EIA said.

“EIA expects that utility-scale solar capacity will nearly double again between the end of 2013 and the end of 2015, with about two-thirds of this new capacity being built in California.”

More: Fierce Energy

NRC Inspectors Find Radiation Monitoring Problems at Entergy’s Palisades Plant

Nuclear Regulatory Commission inspectors cited Entergy’s Palisades nuclear plant in Michigan for using an improper methodology to measure radiation levels that workers received during a refueling outage earlier this year.

An NRC spokesperson said no workers were overexposed, but proper procedures were not followed, constituting a safety violation. An Entergy spokesman said the company tried to use a new monitoring technology, but it was improperly implemented. The violation could result in increased oversight.

More: MLive

Midwest Railroad Coal Delivery Topic of FERC Panel Discussion

The Federal Energy Regulatory Commission will discuss concerns about the coming winter, coal stockpiles and railroad congestion at its meeting on Thursday.

Competition with shale-oil producers for railroad capacity has put pressure on timely deliveries of coal, causing worries that Midwest power plants may have trouble securing adequate coal deliveries this winter.

The meeting will feature a panel discussion with staffers from FERC and the Surface Transportation Board, as well as representatives from Minnesota Power, BNSF Railway and MISO.

More: FERC

Senate Confirms 2 New TVA Directors

The Senate voted 86-12 to confirm Democrats Ron Walter and Virginia Lodge to the Tennessee Valley Authority board. They will serve five-year terms on the nine-member board that oversees the TVA.

Walter, a television executive, and Lodge, a business consultant and former commissioner of the Tennessee Department of Human Services, are succeeding Barbara Haskew and Bill Sansom.

Walter and Lodge pledged to recuse themselves from any decisions involving TVA’s unfinished Bellefone Nuclear Plant. Both appointees had previous contacts with Chattanooga businessman Franklin Haney, who is advocating a private financing plan to complete the two-reactor plant in Alabama.

More: Chattanooga Times Free Press

Department of Energy Issues $12.5B Nuclear Loan Program

The Department of Energy is offering $12.5 billion in loan guarantees for advanced nuclear energy projects that would reduce, avoid or sequester greenhouse gas emissions.

“This solicitation will help the U.S. build the next generation of safe and secure nuclear energy projects by providing the critical financing needed for innovations that have not been widely deployed at commercial scale in this country,” Energy Secretary Ernest Moniz said.

The Advanced Nuclear Energy Projects solicitation is one of four loan programs totaling $40 billion aimed at boosting low-carbon technologies. The other programs include $8 billion for fossil energy projects, $4 billion for renewable- and energy-efficiency projects and $16 billion for vehicle manufacturing.

More: Department of Energy

FERC Gets High Rankings in Employee Satisfaction

The Federal Energy Regulatory Commission ranked fifth out of 25 mid-sized federal agencies in employee satisfaction and commitment, according to a survey of government agencies.

The nonprofit Partnership for Public Service gave FERC a 73.3 out of 100 in employee satisfaction and commitment, and a 77.5 in work-life balance. Only the Federal Deposit Insurance Corp., Government Accountability Office, Smithsonian Institution and Federal Trade Commission scored higher in the “2014 Best Places to Work in the Federal Government” survey.

FERC’s Office of General Counsel won the No. 1 spot among agency divisions with an 88.8.

More: FERC; The Best Places to Work in the Federal Government

December 16, 2014June 15, 2023

PJM Market Monitor: Bar Generators from Cost Development Rulemaking

By Rich Heidorn Jr.

PJM Market Monitor Joe Bowring said last week that the RTO should exclude supply-side stakeholders from participating in the drafting of cost development guidelines that determine generator compensation.

Bowring, speaking at PJM’s annual Market Monitoring Unit Advisory Committee meeting Friday, said he is contemplating a filing with the Federal Energy Regulatory Commission in 2015 to push for the change.

“It’s an accretion of things that have built up,” he said. “We are pretty unhappy [with the current rules]. We’re saying generators shouldn’t have an effective veto right” regarding changes.

The cost development guidelines, which govern compensation for generators receiving cost-based rates, are contained in PJM Manual 15.

Bowring acknowledged that the manual is subject to sector-weighted voting at the Markets and Reliability Committee and must also win approval from PJM’s Board of Managers — the only manual on which the board votes.

But he said the primary motion brought before the MRC is the result of a skewed process at the Cost Development Subcommittee, at which there is no sector-weighting and where generator representatives can overwhelm other stakeholder factions.

The MRC considers as a “primary” motion the proposed solution that receives the highest vote total at lower committees. Proposals that receive at least 50% support at the lower committee may be offered as secondary proposals if the primary proposal fails to win a two-thirds sector-weighted vote.

Bowring said he would attempt to win support for the change through the stakeholder process but wasn’t optimistic about the chances of success. He said a FERC filing would not come before the middle of 2015 because of other pressing matters, including a FERC filing on proposed changes to the calculation of lost opportunity costs, expected in January. (See p. 21 of the State of the Market report for the third quarter of 2014.)

Bowring’s proposal found no immediate support among stakeholders in attendance. “I can’t see changing the voting approaches without disenfranchising somebody somewhere,” said Dan Griffiths, executive director of the Consumer Advocates of PJM States.

John Horstmann of Dayton Power and Light noted that the Cost Development Subcommittee hasn’t held a meeting since October 2013. “I’m not sure I see the problem to the extent that you see it,” he said.

Disclosure of Market-Sensitive Information

Earlier in the meeting, Jeffrey Mayes, the Monitor’s general counsel, made a pitch for stakeholder support for protections against disclosure of confidential market-sensitive data through discovery in mergers and litigation.

Mayes said the Monitor had fought for tight restrictions on who could see data in the Exelon-Constellation merger and quashed a subpoena in a challenge to New Jersey’s Long Term Capacity Agreement Pilot program.

“If we hadn’t taken those steps [in the merger] almost everyone’s market information would have been made pretty public,” Bowring said.

Mayes said the Monitor’s position would be enhanced by explicit backing of PJM stakeholders.

“I would have been in a far better position if I could have a set of rules that had been worked out in advance and that members of the industry were behind,” Mayes said.

Mayes said PJM’s current rules “have a lot of process but not a lot of substance.” He said ISO-NE has a better definition than PJM of member confidentiality.

This proposal found a better reception among the members in attendance. “It certainly seems like something worth investigating,” said Dave Pratzon of GT Power Group, which represents generators.

December 16, 2014

States File New ROE Complaint vs. BGE, Pepco

State regulators and public advocates last week filed a new complaint in their nearly two-year effort to force a reduction in the formula transmission rates for Baltimore Gas and Electric and Pepco Holdings Inc. utilities.

Officials in Delaware, Maryland, New Jersey and D.C. said they opened the new docket (EL15-27) to introduce an updated rate analysis that takes into account updated financial market data and the Federal Energy Regulatory Commission’s June order revising the method for calculating base returns on equity. (See FERC Splits over ROE.)

The complainants asked that the case be consolidated with their 2013 complaint (EL13-48). That case is scheduled to go to hearing next July, after settlement talks reached an impasse last month.

The new complaint seeks to reduce the companies’ base ROE to 8.8%. The companies are currently receiving ROEs of 10.8% on facilities placed in service before Jan. 1, 2006, and 11.3% on facilities added afterward.

PHI affiliates affected are Potomac Electric Power Co. (PEPCO), Delmarva Power & Light and Atlantic City Electric.

December 16, 2014June 15, 2023

State Briefs

Low Oil Prices not Expected to Slow Fracking Next Year

Despite a drop in oil prices brought on in part by increased U.S. production, oil and gas exploration is still expected to begin in southern Illinois, according to industry officials.

“We are going to continue with our evaluation in Illinois even at these prices,” said Mark Sooter, business development manager of Woolsey Operating. The company’s sister corporation, Woolsey Energy, is a leading holder of oil and gas leases in the New Albany Shale formation.

Fracking was approved by the state this year, and permitting is beginning. Pending any legal blocks, the first wells could be drilled by the middle of next year.

More: Southern Business Journal

ComEd, Ameren Illinois Rate Hikes Gain ICC Approval

The Commerce Commission last week approved overall rate increases of 11% for Commonwealth Edison and 17.4% for Ameren Illinois, increasing annual revenue about $245 million for ComEd and about $137 million for Ameren.

The rates were set using a formula that is based in part on the companies’ investment in infrastructure, such as smart meters and smart grid technology. “The power grid is evolving and it is my belief that these investments will result in positive changes and new innovative energy services for customers,” ICC Chairman Doug Scott said.

The Citizens Utility Board, an advocacy group, said it would appeal the rulings.

More: Associated Press

IOWA

State May Look to Hydro for Next Energy Boon After Wind

With the state ranking third in the U.S. in wind energy production, a legislator says it is time to look at increasing hydropower resources.

State Rep. Dan Kelley plans to ask for the state to put aside money to study hydro power. “The state of Iowa has become a national leader in wind energy, and that shows we have the wherewithal and the interest to pursue renewables to a great extent,” Kelley said. “There’s no reason we can’t do the same with hydropower.”

A 2012 U.S. Department of Energy study estimated that the state has 427 MW of untapped hydro power – quadruple its current capacity, but only a tenth of its 5,000 MW of wind capacity. Wind power currently accounts for 27% of the state’s electricity.

More: Midwest Energy News

MINNESOTA

Coal Supplies Already Low at Some Midwest Power Plants

A transportation official told lawmakers that rail congestion and cold weather have already limited coal supplies at some Midwest power plants, but a warm up may allow stockpiles to be rebuilt before winter really arrives.

“We are at the whim of Mother Nature at this point,” said Dave Christianson of the Department of Transportation. He told the Legislative Energy Commission that some plants saw their stockpiles drop to 10% of capacity earlier this year, and supplies now average 30 to 40%.

Railroad officials said a sudden increase in coal shipping demands last year was one cause of rail line congestion. But incoming chairman of the House jobs and energy committee, Republican Rep. Pat Garofalo, said trains are too busy hauling oil from the Bakken oilfield to transport coal and crops. Garofalo supports more pipeline construction.

More: Pioneer Press

NORTH CAROLINA

AG: Utilities Should Pass on Savings from Corporate Tax Cut

Attorney General Roy Cooper is appealing a decision of the Utilities Commission that allowed utilities to keep proceeds from corporate state income tax cuts rather than passing them on to customers.

The lower corporate tax rate was approved in 2013 by the General Assembly, which also raised the taxes paid by customers on their utility bills. This fall, the commission reversed an earlier ruling and said it couldn’t lower customer rates to reflect the lower corporate taxes.

“Utility shareholders were allowed to pocket the cost savings associated with the reduced state corporate income taxes while most customer bills increased from the combined effect of the other tax changes,” according to the attorney general’s filing with the state Court of Appeals last week.

More: WRAL

Duke Plan to Repair Leaking Pipe at Charlotte Coal Ash Dump Gets OK

State environmental officials approved a Duke Energy plan to empty contaminated wastewater from a coal ash dump at its Marshall Steam Station near Charlotte to fix a leaking drainage pipe.

The leaking pipe was discovered about six months ago after a similar pipe collapsed at the company’s Dan River plant, contaminating 70 miles of river and sparking an investigation into all of Duke’s coal ash lagoons. State Dam Safety Engineer Steve McEvoy said it has received requests for permits to conduct repairs at 18 of the company’s 32 coal ash sites throughout the state.

More: Associated Press

PENNSYLVANIA

Wolf Appoints Former PUC, DEP Chief to Planning Post

Governor-elect Tom Wolf named John Hanger, the former Department of Environmental Protection secretary who oversaw the massive growth of the state’s shale-gas industry, as his planning and policy secretary.

Hanger, who ran for governor this year but endorsed Wolf after dropping out, served on the Public Utility Commission from 1993 to 1998 under Gov. Robert Casey and was former Gov. Ed Rendell’s DEP secretary from 2008 to 2011. He will work alongside another former gubernatorial challenger, Katie McGinty, whom Wolf named as his chief of staff last month. McGinty was also Hanger’s predecessor as secretary at DEP.

More: StateImpact

WEST VIRGINIA

Permits Issued for Fracking Under Ohio River by State

West Virginia has approved three permits to drill for oil and gas under the Ohio River.

The state, which controls the rights beneath most of the land underlying the river, says the money earned from leasing the acreage and any royalties earned from production will be put in the state parks budget. With horizontal drilling techniques, production companies can access the deep shale formation from well sites on the river banks.

The drilling companies must still obtain state Department of Environmental Protection permits before beginning. Josh Jarrell, deputy security and general counsel of the state Department of Commerce, said the state has adequate protections in place to ensure water quality is not hurt by drilling under a body of water. Drilling beneath bodies of water is a common practice in other states.

More: The Columbus Dispatch

WISCONSIN

PSC Hears Plan for Xcel, ATC $540M Tx Line

The Public Service Commission will hold hearings throughout the state to examine a plan by Xcel Energy and American Transmission Co. to build what would be the most expensive transmission line in state history.

The 345-kV Badger-Coulee line would run about 180 miles from Madison to Lacrosse and cost between $540 million and $580 million, funded by rate increases to Xcel and ATC customers. The line, first proposed in 2010, is designed to bring increased renewable power production, mostly wind energy, into the MISO system.

More: Badger Herald

December 16, 2014January 21, 2024

Hydro, Natural Gas Interconnections Increase in MTEP 14

By Chris O’Malley

(Click to Zoom)

MISO’s Board of Directors last week approved a $2.5 billion transmission expansion plan funding 369 projects, including a 500-kV line to carry Canadian hydropower to Minnesota Power customers.

The $676 million Great Northern Transmission Line is the single most expensive project in MISO’s 2014 Transmission Expansion Plan, the product of 18 months of work by MISO stakeholders. The line, which will connect the Manitoba border to the Minnesota Iron Range, is set for completion around 2020.

The plan also includes 50 baseline reliability projects totaling $269.5 million, six generator interconnections totaling $38 million and 312 “other” projects totaling $1.5 billion, including those supporting lower-voltage transmission systems.

The plan will allow for the interconnection of 726 MW of new wind generation and import of 883 MW of hydroelectric power from Manitoba, said Jennifer Curran, MISO’s vice president of system planning and seams coordination, in a memo to the board.

Interconnection requests are shifting from predominately wind to a mix of natural gas and wind, as gas-fired generation steps in to replace coal plants forced to retire or switch fuels because of federal environmental rules, MISO said. Natural gas interconnection requests in MISO soared to 9,424 MW this year, from 1,994 MW in 2011.

There also have been about 810 MW of new solar request interconnections in 2014. “This could be the result of recent federal energy legislation and the economic stimulus package, and the lower price of solar photovoltaic modules,” the MISO plan states.

MTEP 14 was the first planning cycle that included full participation of MISO’s south region in economic and reliability planning.

The south region is targeted to receive about $359 million in transmission investments, including two of the largest projects in MTEP 14: a $60 million, 115-kV line by Entergy in Mississippi, and a $56.3 million, 230-kV line in Louisiana.

Since MTEP ‘03 about $19 billion of transmission project investment has been identified, with roughly 40% of it completed. MTEP 14 covers projects expected to be completed by 2023.

December 16, 2014June 15, 2023

MISO Ponders Larger DR Role Despite Legal Uncertainty

By Chris O’Malley and Rich Heidorn Jr.

If you want to know why many think that demand response hasn’t fulfilled its potential in MISO, talk to Brian Helms.

Helms, the director of energy services at new MISO member Century Aluminum, said that when he attended a MISO workshop he was unable to get an answer about what form of approval would be needed to register his plant as a Load- Modifying Resource. And when he asked his local utility how to sign up, it told him it wasn’t interested.

“The path to providing those resources is kind of tortuous and murky,” Helms recounted at the MISO Advisory Committee’s “hot topic” discussion on demand response last week.

The committee sought stakeholder input on how to make the most of demand response programs, and whether MISO should take any action while waiting for final word on whether last May’s appellate court ruling voiding the Federal Energy Regulatory Commission’s Order 745 will stand.

Unlike PJM, most of MISO’s demand response assets are administered through state programs. While that means less disruption if the D.C. Circuit Court of Appeals ruling in the Electric Power Supply Association v. FERC case stands, stakeholders told the committee the disparate state rules make it more of a challenge for the RTO to maximize such resources. (The D.C. Circuit yesterday granted the U.S. Solicitor General’s request for more time to seek a Supreme Court rehearing of the case.)

Representing end-use customers, DeWayne Todd, energy services manager at Alcoa in Newburgh, Ind., said that MISO has done a good job of integrating available Load-Modifying Resources through legacy interruptible electric service rates.

Demand Response Resources ‘Untapped’

But Demand Response Resources are largely untapped in the energy and ancillary services markets due to retailers’ restrictions on participation and compensation, the End-Use Sector said. They cited the Independent Market Monitor’s State of the Market report, which shows there are just 75 MW of controllable Demand Response Resources — all attributable to Alcoa, which often interrupts production when electric price signals rise. (See chart.)

“I think there’s a huge opportunity, and not just [in] smelting, but other customers and consumers, as well,” Todd said.

The Environmental Sector agreed, saying MISO’s minimum threshold of 5 MW for participation in energy and ancillary services markets is too high. PJM’s threshold, they noted, is 100 kW.

The Environmental Sector recommended MISO employ demand response as a “transmission-like resource” in its planning, saying DR resources could help maintain reliability at lower cost than System Support Resources while longer-term transmission or generation solutions are implemented. “DR can also reduce or eliminate the need for costly transmission upgrades, or be paired with a transmission upgrade or voltage support to help eliminate potential reliability issues,” it said.

Aggregators ‘Frozen Out’

The environmentalists lamented that third-party providers, which play a big role in PJM, are “largely frozen out” of MISO’s markets. Among MISO states, only Illinois permits aggregators of retail customers (ARC) to participate, they said.

The Organization of MISO States said MISO “has done an adequate job of meeting FERC requirements for DR, while balancing stakeholder desires for sometimes conflicting market parameters.”

It urged the RTO to work with market participants to accommodate new demand response technologies and remove barriers to participation. OMS cited methods of directly controlling customer-owned electric water heaters to support grid reliability. Participants “would like to develop programs to offer this DR in MISO’s ancillary services market, however current MISO protocols, relating to metering and zonal boundaries, may be prohibiting participation,” OMS said.

The Transmission-Dependent Utilities Sector said MISO has allowed DR fair access to its markets and said load-serving entities should continue to have the option to operate their DR programs at the retail level, without offering it as a wholesale product.

Reliability Benefits

The Public Consumer Group acknowledged that the state-by-state variation in demand response programs is a challenge for MISO but that the RTO should nonetheless make increasing DR a top priority, saying such resources could aid reliability and reduce rates.

During last winter’s polar vortex, the group said, MISO did not even consider calling on DR resources, unlike PJM. “As a result, capacity margins were unnecessarily tight, and prices, which were ultimately passed on to consumers, were likely higher than necessary,” it said. “In addition to paying higher prices when DR is not called upon in near-emergency circumstances, end-use consumers in MISO are not getting appropriate use of DR resources for which they are paying in their rates. … Because DR is so rarely called upon, customers are not enjoying the full value of these resources.”

IPPs: Demand Response Has No Place on Supply Side

MISO’s independent power producers took a position similar to that of generators in PJM and ISO-NE, citing the EPSA ruling in arguing that demand response has no place in the supply side of wholesale markets. “MISO will need to establish parameters for load-serving entities and state regulators in order to use these assets focusing on their primary function: load modification, also known as load shaving,” they said.

“There’s a lot of uncertainty, but it’s pretty clear if you look at ISO New England and PJM, they’re being very proactive in what they’re doing with DR and moving it back over to where it traditionally was prior to the advent of organized wholesale markets,” Mark Volpe, senior director of regulatory affairs for Dynegy, told the committee.

Advisory Committee Vice Chairman Kevin Murray said that’s problematic.

“You could take an approach as Mark suggested and force all the demand response back on to the load side of things,” he said. “The problem with that, as MISO has observed, [is] it produces a result where it’s not integrated into MISO’s market when it’s dispatched, [and] it has the effect of reducing load, [depressing] prices during a point in time when the system is stressed during an emergency.”

A number of commenters noted that DR programs among the states differ widely, with some going back decades.

Directors Judy Walsh and Michael Curran said MISO might consider offering incentives to replace the many differing utility contracts with a model that would be easier for MISO to manage.

“I wonder if there’s a way to structure a new opportunity for these players where they would opt-in to some other opportunity to participate in the market where in fact [they] get paid for participating,” Walsh said. “Perhaps we could move out of these old contracts.”

December 16, 2014

FERC to Hold Technical Conferences on EPA Clean Power Plan

By Michael Brooks

The Federal Energy Regulatory Commission will hold four technical conferences next year to discuss the effects of the Environmental Protection Agency’s Clean Power Plan on reliability and wholesale electricity markets.

FERC announced the conferences in response to a request from three Republican lawmakers, including Alaska Sen. Lisa Murkowski, who will likely become the chair of the Energy and Natural Resources Committee when Republicans take control of the Senate in January. The Republicans said in a letter to FERC that the EPA “lacks the mission and the expertise to determine what is necessary to maintain the reliability of the nation’s electric grid.”

The first conference will be held on Feb. 19, with a “National Overview” session led by the commission itself. It will be a part of FERC’s monthly open meeting, which will start an hour earlier to accommodate the conference. Staff will conduct three more regional conferences in D.C., St. Louis and Denver on dates to be announced.

Participants in the first conference will discuss whether state regulators “have the appropriate tools to identify reliability and/or market issues that may arise” as a result of compliance with the plan, as well as how to coordinate with RTOs on how to comply.

“The commission clearly has a role to play in ensuring that the nation’s energy markets and infrastructure adapt to support compliance with the proposed Clean Power Plan,” FERC Chairman Cheryl LaFleur said. “These technical conferences will be an opportunity for the commission to hear from a wide range of stakeholders across the country on issues related to reliability, market operations and energy infrastructure.”

Murkowski said she appreciated FERC announcing the conferences. The conferences are “no substitute for EPA’s failure to engage FERC and [the Department of Energy] in a formal, documented process to address the impact on electric reliability of EPA’s series of major rulemakings in recent years,” she said.

“I remain hopeful, however, that the conferences will be useful to develop a better public record on these crucial questions, and I will remain as vigilant on this issue as I have been since 2011.”

Republicans have made blunting the EPA’s Clean Power Plan a top priority for when they take full control of Congress, following a wave of Republican victories in Senate elections in November. (See GOP Election Victories Unlikely to Thwart EPA Carbon Plan.) One of the casualties was Sen. Mary Landrieu (D-La.), the current chair of the Energy Committee. (See related story, Honorable Clears Senate Energy Committee.)

December 16, 2014

PJM Files Capacity Performance Plan

PJM on Friday filed its long-awaited Capacity Performance proposal with the Federal Energy Regulatory Commission, a two-docket, 1,275-page capacity market overhaul that it hopes will prevent a repeat of last January’s poor generator performance.

EL15-29, filed under sections 205 and 206 of the Federal Power Act, contains proposed changes to PJM’s Operating Agreement and Tariff “to correct present deficiencies in those agreements on matters of resource performance, and excuses for resource performance, in the wholesale markets administered by PJM.”

ER15-623, filed under section 205, proposes changes to the Reliability Pricing Model rules in the Tariff and Reliability Assurance Agreement.

PJM asked FERC to allow an extended, one-month comment period ending Jan. 12. PJM requested that the changes go into effect on April 1, 2015. (See What You Need to Know about PJM’s Capacity Performance Proposal.)

December 10, 2014

PJM Board to Seek $1,800 Offer Cap

By Suzanne Herel

PJM will ask the Federal Energy Regulation Commission this week to raise the cost-based energy offer cap to $1,800/MWh through March 2015, CEO Terry Boston said in a letter to members Tuesday.

The proposal, authorized by the Board of Managers, would let offers up to $1,800 set clearing prices. Generators could recover “justifiable costs” above $1,800 through make-whole payments, but such offers would not set prices for other market participants.

The Section 206 filing comes after stakeholders failed over eight months to reach consensus on changes to the current $1,000/MWh cap.

The issue resulted from the spike in gas prices last January, which pushed some generators’ costs above $1,000. FERC granted PJM’s request for a waiver from the cap to allow some gas-fired generators to cover their costs.

“We believe this action is prudent preparation for the possibility of high fuel costs that could result in generating sources not recovering their costs despite producing power when most needed to meet high demand,” Boston wrote.

Although PJM is not expecting the same weather extremes this winter, Boston wrote, “seeking approval for a higher cap through this winter [allows PJM] to avoid any possibility of having to scramble to submit waivers that seek FERC decisions in 24 hours.”

Boston noted that the concept of allowing cost-based offers in the energy market to set prices up to $1,800/MWh mirrors the proposal presented at the Nov. 20 Members Committee. Old Dominion Electric Cooperative’s Ed Tatum — who negotiated the proposal with Gabel Associates’ Mike Borgatti — withdrew it after it became clear it had little support from members representing load. (See Last Ditch Effort to Break PJM Offer Cap Deadlock Fails.)

Boston said PJM limited its proposed change to the coming winter “in anticipation of FERC developing a longer-term solution to offer cap issues from a national perspective over the next year.”