PJM officials last week defended their practice of creating interfaces to capture operator actions in response to voltage problems, saying they can’t guarantee the constraints will be modeled in Financial Transmission Right auctions.
In the last year, PJM has created “closed loop” interfaces in at least four locations so that operator actions — such as sub-zonal dispatch of demand response — are captured in Locational Marginal Prices rather than uplift. PJM said it must use the interfaces to set prices because its modeling software can only set prices for thermal constraints, not voltage problems.
But in its effort to reduce uplift, PJM is exacerbating FTR underfunding, DC Energy’s Bruce Bleiweis told the Market Implementation Committee during a discussion last week.
PJM has promised to provide notice of any new interfaces at least one day before implementing them. But that’s not enough time for FTR holders to react, said Bleiweis, who noted that the RTO requires 90 days’ notice before implementing special protective schemes (SPS).
He proposed PJM provide notice of the potential need for a new constraint as soon as it has identified one and discuss the results of their analysis at the next meeting of the MIC or Markets and Reliability Committee. Interfaces should be announced prior to the next FTR or Balance of Planning Period auction and not implemented until the beginning of the next month, Bleiweis said.
PJM “shouldn’t be in the position of choosing who will gain and who will lose,” he said.
PJM officials said Bleiweis’ proposal was unworkable.
“A lot of those things come up quicker than the time that Bruce would want,” said Adam Keech, director of wholesale market operations. “We might know two days before we need it, not 45 days. Forty-five days later we may not need it. We’re just printing uplift in between.”
Vivint Solar, an upstart business in the home security and automation fields, is planning an initial public offering for its solar segment, according to sources. Vivint’s IPO could come out as soon as September.
Vivint is the second biggest residential solar installation company in the U.S., behind SolarCity, which went public in December 2012 at $8 per share. Solar City shares closed Friday at $70.14.
Sunoco Logistics, still finalizing its first cross-state pipeline in Pennsylvania to transport Marcellus Shale gas liquids, has already signed up a customer for a second pipeline. Austrian chemical company Borealis signed a 10-year agreement to buy ethane produced in the Marcellus and Utica shale fields. Ethane is used in plastics production.
The new agreement would go into effect in 2016. Sunoco is in the final stages of constructing its first line, Mariner East. It is scheduled to go into operation later this year. That project generated controversy among residents of the areas the pipeline crossed. Sunoco has been asking the state Public Utility Commission to designate the pipeline a public utility, which would ease the process of gaining rights of way. So far, it has been unsuccessful.
Unit 2 at Exelon’s LaSalle Nuclear Generating Station went into automatic shutdown last Tuesday when one of the station’s steam valves closed. The shutdown went according to plan, and no damage or impact on customers occurred, a station spokesperson said. The company is looking into the cause.
The Tennessee Valley Authority said last week that it will accomplish most of its 2,000 job reductions through attrition, retirements and voluntary resignations, avoiding the need for massive firings. The cuts are TVA’s largest in 20 years.
TVA began the year with about 12,500 employees. This is down from 51,000 employees in 1981. TVA President Bill Johnson said the employee reductions are necessary in order to cut down on expenses and to keep electricity rates competitive in the region.
Labor unions are concerned that the layoffs merely mean that TVA is hiring more contractors. “As TVA is laying off some of our workers, they are filling some of that work with contractors or selecting managers or others to do the work from outside of our bargaining unit. Those are our major concerns,” said Faye Headrick, senior international representative for the Office and Professional Employees International union. The union represented 3,000 TVA employees 40 years ago but only about 600 now.
Workers at FirstEnergy’s Harrison Power Station in Haywood, W.Va., have been given their first contract. The Utility Workers Union of America, which has been negotiating since 2010, announced the contract last week. The coal-fired plant employs 184 workers. They’ve been fighting for a contract since they voted to unionize in September 2010. The 3.5-year collective bargaining agreement covers wages, benefits and working conditions. The plant was owned by Allegheny Energy and became part of FE’s fleet through a merger in February 2011.
PSEG Nuclear is close to filing a draft environmental impact study on its plan to build a new nuclear station on Artificial Island. The company would need to complete a land swap of 631 acres with the U.S. Army Corps of Engineers on the island in order to go forward. Other studies, including a storm surge study, are also necessary. The environmental impact study could be filed as soon as September. Final action could come late next year, with a separate decision on technologies, design and construction to follow.
FirstEnergy, Duke Energy, NRG Energy, Dynegy and AES all announced second-quarter earnings last week with FirstEnergy capturing headlines for its decision to exit most retail sales and AES saying it won’t sell Dayton Power and Light after all.
FirstEnergy Announces Retail Exit as Earnings Rebound
FE executives said that price volatility due to extreme weather and a “fundamental” change in retail markets has made the company decide to exit retail.
“We intend to exit the medium commercial and industrial, or MCI, and mass-market retail channels as existing contracts expire, but we will continue to serve strategic large industrial and commercial customers as well as our governmental aggregation in [provider of last resort] channels as appropriate,” FirstEnergy CEO Anthony Alexander said last week.
Volatility, eroding price stability and the need to swallow costs on fixed-rate offers translated into too much risk, Chief Financial Officer James Pearson said. “We were already taking steps to be more selective in our sales to the large and medium-sized commercial and industrial customers during the second quarter,” Pearson said.
The company reported earnings of 16 cents per share in the second quarter on earnings of $64 million and revenue of nearly $3.5 billion, compared to a loss of $164 million, or 39 cents per share, with revenue of more than $3.5 billion for the same period the year before.
Pearson said operating earnings were driven by a lower commodity margin, higher investment income and lower operating and maintenance costs.
Meanwhile, the four Pennsylvania subsidiaries of FE last week filed rate-increase requests to help pay for infrastructure enhancements.
Under the proposals, residential customers who use 1,000 kWh a month would see their bills increase by 11.8% for Penn Power, 14.7% for West Penn Power, 16.3% for Penelec and 17.8% for Met-Ed. A company spokesman said the new rates would allow the company to use technology to reduce the number of outages and the number of customers affected when outages occur.
The utilities want the state Public Utility Commission to approve the rates effective Oct. 3.
AES, parent of DPL, has changed its mind about the company again. Three months after saying it was seeking buyers for DPL, parent of Dayton Power and Light, AES said the company is off the block.
The offers received “were not attractive relative to the long-term value to AES,” Chief Financial Officer Tom O’Flynn said during a conference call last week. “We therefore decided not to sell.”
Dayton Power and Light owns 2,897 MW of capacity, most of it coal-fired. DPL subsidiary DPL Energy owns 556 MW of peaking capacity in Ohio and Indiana. AES bought DPL in November 2011 for $3.5 billion, saying it wanted to increase its presence in the Midwest, where it already owned Indianapolis Power & Light.
At its first-quarter earnings call in March, however, O’Flynn told analysts AES would “explore all potential options to optimize” DPL, including a sale.
An improving wholesale energy market is one of the things that convinced AES to hang on to DPL, for the time being.
“The market is still higher than what we were projecting at the start of the year,” O’Flynn said. “Second, we saw an improvement in PJM [capacity] prices, which doubled, albeit from low level at the last auction, and outstanding proposals to provide additional improvement.”
He also cited a plan to improve generation plant performance and its multiyear commercial hedging strategy.
AES reported second-quarter earnings of 28 cents a share on revenue of $340 million, compared to 35 cents per share on revenue of $289 million for the same period last year.
Duke Earnings up 80%
Second-quarter earnings for Duke rose 80% over the same period last year, fueled in part by higher customer rates in the Carolinas from 2013 rates cases, warmer-than-usual weather and higher PJM capacity prices.
The company reported earnings per share of 86 cents on $609 million in profit and revenue of $5.17 billion, compared to 48 cents/$339 million/$4.83 billion for the same period last year. The company also credited lower taxes and lower operational costs.
In a conference call, Duke CEO Lynn Good highlighted the company’s five-year growth plan through 2018, in which it will spend $18 billion to $20 billion on investments. These include $1.9 billion in three large natural gas-fired generation plants in Florida, and $600 million for a 750-MW plant in South Carolina.
This is on top of the company’s recent announcement that it was buying out North Carolina Eastern Municipal Power Agency’s ownership of 700 MW at Duke Energy Progress plants for $1.2 billion.
Good spent a significant amount of time on the call addressing the company’s Dan River coal ash spill and cleanup. Good said cleanup expenses were about $20 million through June and that she did not expect total costs to be material.
“We are cooperating with and defending the company in ongoing investigations resulting from the Dan River accident,” she said. Good noted that there have been legislative moves to require Duke to clean up some, or all, of the company’s remaining coal ash ponds. North Carolina’s legislature adjourned without approving a bill, and Good would not say what the total cost could be. But she said that depending on legislative and regulatory action, some or all of Duke’s costs could be covered.
“We believe the recoverability of coal ash based in closure cost will be determined by the Carolina’s Commission.”
NRG Posts Loss
NRG saw a downturn in the second quarter, posting a loss of $97 million, or 30 cents a share, compared with a profit of $124 million, or 37 cents a share, for the same period last year. Its retail operations posted a loss, but its wholesale businesses all posted profits for the quarter.
CEO David W. Crane said the past two quarters prove NRG’s move to diversify away from strictly wholesale generation was a good one.
“Never before in my 11 years at NRG do I recall a first half of the year where we were so whipsawed by the weather,” he said. “A severely cold winter followed by a summer, which, to date, through the second quarter and so far into the third quarter, has been completely devoid of extreme weather in any of our core markets.
“Fortunately, to some degree, our diversification away from being exclusively a wholesale generator, first, into retail and then into clean energy, has increased the resilience of our earnings in the face of mild weather and tepid wholesale electricity demand.”
Perhaps the biggest news out of NRG is its decision to reorganize its business units. The three business units will be NRG Business, holding the wholesale generation business; NRG Home, which includes retail operations such as residential solar; and NRG Renew, its large-scale solar, wind and other renewables business.
Crane acknowledged on the conference call that yet another reorganization may be confusing for some investors but said it makes sense nonetheless.
“The way we’re organized going forward allows senior executives of the team to sort of focus in their area and win in their area because each area is pretty distinct,” he said. “I mean they’re mutually reinforcing, but each has different competitors.”
Dynegy Revenue up, Earnings Down
Dynegy reported a loss of $123 million, or $1.23 a share, compared to a loss of $145 million, or $1.45 a share, for the same period last year. Revenue for the second quarter rose to $521 million from $301 million a year ago, a 73% jump.
Dynegy has narrowed its losses since coming out of bankruptcy in 2012. Its second-quarter operating loss in its coal-fired generation business was $5 million, compared to a $49 million loss for the same period in 2013. Its gas segment shows a similar story, with a second-quarter loss of $2 million, compared to a loss of $36 million for the same period last year.
Dynegy President and CEO Robert Flexon is taking a long-term view.
“The underlying fundamentals continue to indicate improving capacity prices and higher energy prices and volatility,” he said. “These improvements are driven by a market expectation of reduced supply as a result of plant retirements, the majority of which will occur in the 2015-2016 timeframe.”
After nearly four years of investigation, the Federal Energy Regulatory Commission Tuesday publicly accused an energy trading firm of market manipulation in a case that dogged FERC enforcement chief Norman Bay through his confirmation as commissioner.
The staff “notice of alleged violations” accuses Houlian (Alan) Chen and the Powhatan Energy Fund LLC of engaging in “manipulative” up-to-congestion trades in PJM in 2010.
Norman Bay, with Richard Gates looking on, responds to questions during his Senate confirmation hearing in May.
The notice was issued the day after Bay was sworn in as a FERC commissioner and his deputy at the commission’s Office of Enforcement, Larry Gasteiger, was named acting director. Bay’s handling of the Powhatan case was cited during his Senate confirmation hearing in May as evidence of what critics said was his unit’s harsh and unfair tactics.
[Editor’s Note: An earlier version of this article inaccurately stated that FERC had “charged” Powhatan. The notice is merely a public disclosure of a previously non-public investigation.]
Powhatan, based in West Chester, Pa., is a private investment fund headed by portfolio manager Kevin Gates and his twin brother Rich. FERC staff says Powhatan and a predecessor fund netted $4.7 million in profits in 2010 by taking advantage of a loophole for making low-risk up-to-congestion trades to profit from line loss refunds.
The investigation was disclosed under a policy approved by FERC in December 2009 to balance “the need to protect the subject’s confidentiality in the early stages of an investigation with the public interest of promoting additional transparency during investigations.” It allows the Director of Enforcement to authorize a Preliminary Notice of Violations “after the subject of the investigation has had the opportunity to respond to staff’s preliminary findings letter.”
“In our experience, once staff provides its preliminary conclusions to a subject, the existence of the investigation is likely to become public in any event, through a negotiated settlement, an order to show cause, or, in the case of a publicly traded company, a securities filing,” the commission said in approving the policy. “The absence of disclosure means that a greater amount of time passes before the public becomes aware of potential violations that enforcement staff is investigating.”
Kevin Gates on Tuesday issued a statement vowing to fight the allegations. “We’ve read it and it makes no sense. We will aggressively fight their allegations. We can only speculate on FERC’s motives,” he wrote. “When a regulator is not concerned with the facts or the law, then traders can become easy targets if it has a political agenda.”
It is unclear what, if anything, FERC will do next. FERC staff advised Powhatan of its preliminary findings in August 2013 and Powhatan responded with its rebuttal in October. Powhatan said it has rejected an earlier settlement offer from enforcement staff.
“This is an acknowledgement that an investigation is going on,” FERC spokeswoman Mary O’Driscoll said today. “This is not an indication of whether the commission is going to go to court. There is no other step at this point.”
The case has drawn widespread attention and was highlighted in a Wall Street Journal op-ed penned by former FERC general counsel William Scherman. In it, Scherman accused Bay of driving Wall Street banks out of energy trading with heavy-handed enforcement tactics.
Republicans grilled Bay on the case and his management of the enforcement unit during his confirmation hearing. Bay declined to comment on the Powhatan case, which was then “non-public,” but dismissed Scherman’s allegations of due process violations as untrue.
FERC’s Larry Gasteiger answers questions about FERC enforcement as Michael Spofford of Bingham McCutchen (R) listens at an Energy Bar Association panel discussion in April.
Gasteiger responded to charges that FERC was unfairly targeting traders during a panel discussion at an Energy Bar Association conference earlier this year. “We take these cases extremely seriously, whether it’s individuals or companies,” he said. “We won’t take on a case unless we think we have an extremely solid case to present to the commission and if necessary to take it to a hearing before an [administrative law judge] or a district court proceeding.”
Tuesday’s notice alleges that Chen, trading on Powhatan’s behalf, placed “millions of megawatt hours of offsetting trades between the same two trading points, in the same volumes and the same hours — an intentional effort to cancel out the financial consequences from any spread between the two trading points while capturing large amounts of MLSA [Marginal Loss Surplus Allocation] payments.” FERC charges this was “wash trading,” which is illegal.
The Gates brothers said it was savvy trading and legal until the “loophole” was closed later in 2010.
After being under investigation by Bay’s enforcement unit for more than three years with no charges filed against them, the Gates brothers went on the offensive. In March, they released documents they say prove they have been unfairly hounded. The fund enlisted testimonials from an all-star team, including Susan J. Court, Bay’s predecessor as enforcement chief, Harvard professor William Hogan and John N. Estes III, a prominent defense attorney. (See PJM Trader Calls FERC on Manipulation Probe.)
The Gates brothers filed a Freedom of Information Act lawsuit to obtain agency records relevant to their case, lobbied the Senate to block Bay’s confirmation and lurked behind Bay during his confirmation hearing. In a letter to the editor published in The News Journal days before Bay’s confirmation hearing, Richard Gates said they were offered a settlement by FERC.
“While that would have been the easier and cheaper thing to do, Powhatan declined,” he wrote. “Instead, we planned for protracted litigation against the federal government.”
The Federal Energy Regulatory Commission last week gave its OK to a Texas liquefied natural gas export terminal to be located near Freeport, Texas. The Freeport Liquefaction Project would be built on the site of an existing import terminal. The decision adopts a recommendation by the commission’s environmental staff requiring the company follow more than 80 environmental remediation plans. The U.S. Department of Energy has conditionally approved the Freeport project already.
This is the third LNG export project to receive FERC approval. Ten LNG export projects have applications pending before the commission.
The Energy Department also approved an LNG terminal to be built near the mouth of the Columbia River in Oregon. The authorization — conditional upon final approval from FERC — will allow the terminal to export LNG to countries without a free trade agreement with the U.S., such as Japan, China and India. Other local, state and federal approvals are needed before the project can break ground.
DOE Renewable Official Cites Dominion’s Wind Plans
David Danielson, the Department of Energy’s assistant secretary of energy efficiency and renewable energy, pointed to Dominion Resources’ offshore turbine project as a sign of things to come. “This will be Virginia pioneering something nationally,” he said during a local Hampton Roads Chamber of Commerce luncheon over the weekend.
Dominion is gathering offshore wind power data with two 550-foot tall turbines, funded in part with a $47 million federal grant.
Xcel Energy CEO Ben Fowke has appealed to the to help unclog rail deliveries of coal, saying carrier BNSF Railway’s slowed deliveries threaten to shut down a 2,500-MW plant.
The Sherco plant, about 45 miles northwest of Minneapolis, provides about 25% of the power for Xcel customers in a five-state region. Fowke said the plant is short about 810,000 tons of coal.
Other utilities in North Dakota, Arkansas and Kansas have reported similar problems. La Crosse-based Dairyland Power Cooperative said it could run out of coal at one of its plants by January if BNSF doesn’t speed up its deliveries. Some critics say the shortage is because rail carriers have experienced a huge rise in crude oil shipments from northern regions, but BNSF denies it. The carrier said it has added more equipment and personnel to its lines and is working through the backlog.
A security violation seen during a Nuclear Regulatory Commission inspection at Exelon’s Peach Bottom Atomic Power Station in Delta, Pa., has the commission considering remedial action for the plant operators. NRC spokesman Neil Sheehan said the violation was due to a flaw in the plant’s security program, but for security reasons he wouldn’t elaborate.
Letters from the NRC to Exelon Nuclear identified the problem as a piece of security equipment at the plant’s dry cask storage area, an exterior site where spent fuel is stored in concrete vaults. A plant spokeswoman said that the problem has since been fixed.
President Obama nominated two energy experts to fill slots that will soon be open at the Nuclear Regulatory Commission.
Jeff Baran, aide to Rep. Henry Waxman (D-Calif.), was named to replace Bill Magwood, who has accepted a position with the Paris-based Nuclear Energy Agency. Baran would finish Magwood’s term, which expires June 30, 2015.
Former NRC general counsel Stephen Burns would replace George Apostolakis, who left June 30 after the White House did not re-nominate him. If confirmed by the Senate, Burns’ term would run through June 30, 2019.
West Virginia Gov. Earl Ray Tomblin joined miners from his state, Pennsylvania Gov. Tom Corbett and Ohio Lt. Gov. Mary Taylor in a “Rally to Support American Energy” last week. The rally was held in Pittsburgh, one of the sites of a public hearing on the Environmental Protection Agency’s proposed carbon emission rule.
“Today’s rally gives us an opportunity to come together and explain the EPA should be working with us toward energy independence, not mandating unilateral restrictions on our nation’s energy production,” Tomblin said. “That’s why our state is joining the fight against the EPA’s proposed rules to establish unreasonable restrictions on carbon dioxide emissions.”
Twelve states, including West Virginia, Ohio and Kentucky, filed suit Friday to block the Environmental Protection Agency’s proposed rule on carbon emissions from power plants. West Virginia Attorney General Patrick Morrisey said the suit was an effort to prevent regulation “that will have devastating effects on West Virginia’s jobs and its economy.”
The suit was filed in the U.S. Court of Appeals for the D.C. Circuit. The other plaintiffs are Alabama, Indiana, Kansas, Louisiana, Nebraska, Oklahoma, South Carolina, South Dakota and Wyoming. The states said a U.S. Supreme Court ruling prohibits the EPA from issuing power-plant rules under one section of the Clean Air Act, known as 111(d), when it has already regulated them under a separate section.
David Doniger, a lawyer at the Natural Resources Defense Council, called the suit “laughable.” Lawyer Scott Segal, an opponent of the rule, said the suit was likely the first of several challenges. “I wouldn’t be surprised if one gets kicked to the Supreme Court,” he said. (See related story, FERC Split on Reliability Analysis on EPA Rule.)
Researchers mapped almost 6,000 natural gas leaks across 1,500 road miles in D.C., finding large leaks east of the U.S. Capitol but few over the National Mall, where natural gas pipelines are less common. (Source: Robert B. Jackson, et al., “Natural Gas Pipeline Leaks Across Washington, DC,” Environmental Science and Technology.)
Federal officials should do more to reduce leaks in natural gas distribution pipelines that are costing consumers and undercutting efforts to combat climate change, the Environmental Protection Agency’s Inspector General said in a report last week.
The report estimates that about $200 million worth of natural gas escapes from distribution lines annually because of a lack of coordination between EPA and federal pipeline regulators and a lack of financial incentives for utilities.
Methane is responsible for 9% of U.S. gas emissions and has a global warming potential that is more than 20 times that of carbon dioxide. About 10% of methane emissions are from distribution pipelines with leaks most likely on older pipelines made of cast iron, wrought iron and unprotected steel. Such pipelines account for about 8% of the 1.2 million miles of distribution mains in the U.S.
Seven PJM states — Ohio, Pennsylvania, New Jersey, Michigan, West Virginia, Illinois and Maryland — rank in the top 10 for the most miles of cast/wrought iron or unprotected steel pipelines, the IG said.
President Obama’s 2013 Climate Action Plan called for the EPA and other federal agencies to develop a strategy to address methane emissions. But the EPA does not regulate methane emissions from the distribution sector and the Department of Transportation’s Pipeline and Hazardous Materials Safety Administration, which regulates pipeline safety, requires local distribution companies (LDCs) to fix only those leaking pipelines that represent safety risks.
Only 22 states (or utilities within the states) have adopted initiatives to replace cast iron or unprotected steel pipelines, the report said.
Leaks can be fixed by inserting flexible plastic liners inside existing lines or using composite wrap to repair defects such as dents and corrosion. Some LDCs run regular inspection and maintenance programs.
But LDCs often have no incentive to fix leaks because they are allowed to pass on to customers the costs of lost gas while the benefits of reduced fuel costs are also passed on to consumers. “Thus, there is a financial disincentive for LDCs to proactively locate and repair leaks,” the report said. “The cost of the product lost is easy for LDCs to recover while the costs to repair, replace or retrofit pipelines poses more of a cost recovery challenge.”
The report recommends that the EPA work with the PHMSA to toughen regulations and partner with state utility regulators to develop ratemaking models that incent LDCs to proactively repair leaks.
PJM and the Independent Market Monitor warned last week that they will refer traders who improperly arbitrage price differences between PJM and other regions to the Federal Energy Regulatory Commission for enforcement action.
PJM and the IMM said they will target traders who schedule interchange trades for the last 15 minutes of an hour based on price differentials in the first portion of the hour, a scheme known as “slamming the close.”
Although PJM settles trades based on hourly average prices, it posts prices on a five-minute basis. “Historically we have seen traders submit significant megawatt volumes of transactions only for the last 15 minutes of an hour once they have seen the five-minute prices for the first 20 minutes,” PJM spokeswoman Paula DuPont-Kidd explained.
The PJM-IMM notice said that such “transactions provide no value by way of enhanced market efficiencies or operational benefit and could constitute manipulative, harmful or inappropriate market behavior.”
It also said they would refer to FERC interchange transactions between PJM and external balancing authorities that began at 45 minutes past the hour and end at the top of the next hour, as well as transactions “that would result in the same or similar settlement.”
The notice cited the following examples:
Modifying the volume of an existing schedule for the last 15 minutes of the hour.
Scheduling a transaction that begins at 45 minutes past the hour and continues into the next hour but is partially offset by another transaction in the opposite direction that begins at the top of the hour. This would include trades by corporate affiliates.
Transactions that are scheduled to begin at 45 minutes past the hour and stop at 15 minutes past the top of the next hour if officials believe they were submitted to exploit PJM’s hourly integrated settlements.
2008 Rule
PJM and MISO implemented rules in 2008 to prevent such trading, with PJM requiring that that interchange transactions have a minimum duration of 45 minutes.
But FERC ruled in April that PJM’s minimum duration was inconsistent with Order 764, which required 15-minute energy scheduling intervals with 20-minute notifications. (See FERC Rejects PJM Schedule Rules.) Order 764, issued in 2012, is intended to remove barriers to variable generation sources such as wind.
In 2007, MISO and its Independent Market Monitor determined that nearly 60% of intra-hour schedules between MISO and PJM occurred in the final 15 minutes of the hour. PJM said this resulted in interchange spikes of up to 1,000 MW — increasing uplift charges because of the need to call on combustion turbines to balance the generation swings.
Partial Path Scheduling
PJM and the IMM said they also may refer traders that submit external interchange schedules that appear to have been designed to exploit price differentials and do not result in physical energy flow: “For example, multiple interchange schedules, each of which represents a partial schedule that does not reflect the full physical energy path, or schedules that are in the opposite direction of a portion of a larger transaction that involves multiple Balancing Authorities so as to ‘cancel out’ the physical flow that would otherwise be caused by a portion of the larger transaction.”
Traders who believe they have “a bona fide commercial rationale” for any prohibited transactions should discuss the issue with PJM and the IMM beforehand, they said.
The Markets and Reliability Committee last week heard first reading on proposed deadline changes recommended by the Market Settlement Subcommittee. Assuming they clear the Market Implementation Committee Wednesday, the issues will be brought to an MRC vote at its next meeting Aug. 21.
Power Meter and InSchedule Deadlines
More than two-thirds of Market Settlement Subcommittee members polled supported the following changes:
o Extending the deadlines for electric distribution companies (EDCs) to submit Power Meter and InSchedule data to address problems with reporting output for non-utility generators. The delay will allow a higher percentage of actual load data to be reported in InSchedule, particularly for EDCs with smart meters, and reduce the reconciliation adjustments.
Power Meter deadlines would be extended by an hour effective Oct. 1.
o Monday – Thursday Operating Days: Next business day @ 4 p.m. Eastern Prevailing Time (EPT)
o Extending meter correction data deadlines by one month. The change would allow more time for generators and EDCs to gather data, improving accuracy of submitted corrections and reducing or eliminating later bilateral adjustments. PJM also would gain additional time to process and include the meter corrections in the bill.
o Allowing load reconciliation data to be considered in balancing operating reserve (BOR) for deviation calculations, effective Jan. 1, 2015. The change will affect all participants with BOR deviations. Load reconciliation billing would be performed under the current 60-day schedule.
Capacity Charge Reconciliation
About 78% of Market Settlement Subcommittee members polled indicated support for a change to provide relief for Pennsylvania EDCs squeezed by PJM and Pennsylvania Public Utility Commission deadlines.
PJM requires EDCs to upload their Peak Load Contribution (PLC) and Network Service Peak Load (NSPL) data to eRPM 36 hours prior to the operating day. The Pennsylvania PUC issued an order in April requiring that EDCs switch customers to new energy suppliers within three business days of notification of the switch. Under the PUC’s previous rules, it took 11 to 40 days to switch electric suppliers.
The new rule gives EDCs only one day to update their records to recognize the change and correct the PLC and NSPL values, raising the possibility of retail suppliers receiving inaccurate capacity charges.
The subcommittee proposal would retain PJM’s 36-hour advance submission deadline but allow corrections to be made until noon the next business day.
State Creates Green Fund to Spur Solar Installations
The Department of Natural Resources and Environmental Control and the Sustainable Energy Utility are combining efforts in a Joint Green Energy Fund to help residents, businesses and nonprofits install solar and geothermal technology.
The SEU, a non-profit organization created by the state, has committed $1.5 million for each of the next two years to buy solar renewable energy credits at a price of $0.45/watt for the first 20 years of solar production. The program is open to systems of up to 50 kW in size, regardless of the customer’s electric provider. The state’s original Green Energy Fund was open only to those in the Delmarva Power & Light service territory.
SEU also agreed to put up $2 million over two years to commercial and non-profit geothermal and solar water heating systems. SEU funds come in part from the Regional Greenhouse Gas Initiative.
The Public Service Commission has started public hearings on Pepco’s plan to put 21 of its most troubled feeder lines underground. Pepco said the first leg of the project, which could take up to 10 years, would cost about $434 million.
A Pepco official, Caryn Bacon, said placing feeders underground won’t solve all problems. “It is true when you place a feeder underground it is more difficult to locate the fault,” Bacon said, but she added that the plan calls for redundancies to reduce extended outages. The PSC is expected to rule on the Pepco plan in October.
Court: Regulators Can Force Consumers to Buy ‘Clean Coal’
Illinois consumers could be forced to purchase electricity from the troubled FutureGen 2.0 project as a way to guarantee continued financing for it, a state appellate court has ruled. The ruling upheld an Illinois Commerce Commission ruling.
Illinois has a “Clean Coal Portfolio Standard” mandating that a portion of the state’s energy come from clean coal projects. The FutureGen project, which would retrofit a coal-fired plant and then sequester its carbon dioxide underground, has been languishing while waiting for various court rulings.
The plant could be ready to burn Illinois coal and sequester the carbon dioxide by 2017. With the ruling, Illinois customers could be forced to pay an extra $1 to $1.40 a month for power from the project. Some power suppliers have vowed to appeal the ruling to the state Supreme Court.
The Public Service Commission approved a plan to convert Kentucky Power’s Big Sandy plant in Lawrence County from coal to natural gas.
Kentucky Power said the only way the 278-MW unit could meet air quality standards was to switch to natural gas.
The PSC said Friday that the plan to switch to gas “preserves a viable generating plant operating within the commonwealth, thus retaining some of the current employees and supporting the local tax base.” The retrofit is expected to cost $50 million.
A wind farm proposed for Maryland’s Eastern Shore could be held up by U.S. Sen. Barbara Mikulski, who added language to the defense appropriation bill mandating that no agreement between the developers and the U.S. Navy could be signed until a further study is completed. One of the things the study is researching is the effects of wind farm towers on the radar system at the Patuxent Naval Air Station.
The study isn’t due to be completed until next summer and developer Pioneer Green Energy said the delay could kill the project.
State lawmakers have introduced a package of bills tackling energy pricing, energy efficiency and technology and renewables. Called “Energy Freedom” by the bipartisan group that introduced it, the package addresses net metering, microgrids, fair-value pricing and renewable energy.
The bills have been referred to the House Committee on Energy and Technology. “I just want to make sure we do everything we can to promote renewables and clean-energy development in Michigan,” said state Rep. Jeff Irwin, a southeast Democrat and one of the sponsors.
A law passed two years ago to smooth out volatility in the solar market has resulted in a stable market and new growth in the solar industry, according to a Board of Public Utilities report. “New Jersey’s solar market is sound,’’ BPU President Dianne Solomon said.
The 2012 law was passed after an increase in solar capacity caused a drop in the price of solar credits. The report was required as part of the law, which led to a rebound in the price of solar credits and a corresponding increase in solar installation activity.
State legislators went home last week without producing a law addressing the state’s toxic coal ash sites. The issue became a priority after a spill earlier this year of up to 39,000 tons of ash from a Duke Energy site.
Both the House and the Senate traded bills, but a final bill was never acted on. Senate leaders blamed House members for hobbling a compromise bill with late provisions.
Environmentalists were dismayed by the General Assembly’s lack of action. “This is a multilayered failure of leadership. Both chambers failed to offer the comprehensive cleanup plan they promised at the outset of session,” said Donna Lisenby of the Waterkeeper Alliance.
While lawmakers failed to act, Gov. Pat McCrory did, by issuing an executive order directing the Department of Environment and Natural Resources to start groundwater tests at all of Duke’s ash ponds.
Report: State Officials Lax in Gas Industry Oversight
A report from the state Auditor General issued last week said the Department of Environmental Protection is unable to keep up with the demands presented by the shale gas drilling boom in the state.
Auditor General Eugene DePasquale said the department has failed to address many public complaints about air and water contamination. He also found that the department failed to make gas companies provide drinking water in 14 of 15 contamination cases.
DEP Secretary E. Christopher Abruzzo took issue with the report. “DEP has found that working with operators to obtain voluntary compliance with the law is often a more effective and expeditious method of restoring water supplies,” he wrote.
In an initial ruling, the Public Utility Commission has found that Sunoco’s proposed Mariner East pipeline does not qualify as a utility and therefore is not exempt from local zoning laws.
The company asked the commission for the utility status to help it with the permitting and construction of pumping stations it wants to build for the pipeline. The pipeline is planned to run from the shale gas region in the west of the state to a terminal at Marcus Hook on the Delaware River.
Under state law, utilities are exempt from some local zoning laws.
A “Southern accent reduction” class offered at the Oak Ridge National Laboratory has been cancelled after Southern-bred employees complained. The class, at the U.S. Department of Energy’s largest research facility, was to be taught by a Knoxville speech pathologist, Lisa Scott. She said many businesses offer “accent neutralization” services for foreign employees and those with strong regional American accents, especially ones from New York, Boston and Philadelphia. But Scott said the course was described in an email “in such a way that some people interpreted it that their Southern accent was a problem.”
Quarterly earnings calls aren’t only about the numbers. They are often platforms companies use to highlight other news.
Calpine last week announced plans for a new 760-MW plant in PJM, while PPL said it had proposed a 725-mile transmission line through New York, New Jersey, Pennsylvania and Maryland at a cost of $4 billion to $6 billion.
Exelon, which announced its acquisition of Pepco in its first-quarter earnings call in April, used its second-quarter earnings call to continue its push for state support for its Illinois nuclear plants.
EXELON
Exelon reported net income of $522 million, or 60 cents per share, for the second quarter this year, compared to $490 million, or 57 cents a share, for the same period last year. The 6.5% increase was due in large part to increased capacity prices in PJM, the company said.
The company — which has previously said that some of its Illinois nuclear plants are unprofitable and at risk of closing down — hopes to win state incentives for the plants’ contribution to the economy and their role in helping the state comply with the Environmental Protection Agency’s proposed carbon emissions rule.
“State agencies are drafting a number of reports that will look at the economic value of the units to the local communities, jobs, the value of the energy produced, the value of the low carbon resources,” said Joseph Dominguez, Exelon’s senior vice president of government and regulatory affairs. He said he expected to see the reports in November or December.
“It’s pretty clear that if you lose nuclear plants, your ability to comply with any carbon regime going forward is going to be jeopardized,” CEO Chris Crane said.
PPL
PPL reported earnings of $229 million, or 34 cents per share, compared to $405 million, or 63 cents per share, last year. That included a special charge of $128 million, or 19 cents per share, related primarily to the anticipated spinoff of PPL Energy Supply.
“Strong performance at each of our regulated utilities with stronger margins from our competitive Energy Supply business led to very solid results through the first half of the year,” CEO William H. Spence said.
Route of PPL’s proposed transmission line.
Spence announced that PPL has submitted to PJM a proposal to build a 725-mile, 500-kV transmission line that would run from Western Pennsylvania into New York and New Jersey, with another spur running south into Maryland. Spence estimated the cost for the project at between $4 billion and $6 billion. He said if construction begins by 2017, the project would be completed by 2023 to 2025.
PPL said the line would address both reliability and congestion as well as move power expected to be produced by new generators fueled by shale gas in northern Pennsylvania. Spokesman Paul Wirth said it would address reliability problems on three 230-kV lines: Lackawanna-North Meshoppen, Montour-Sunbury and Siegfried-Frackville.
CALPINE
Calpine reported a profit of $139 million, or 33 cents per share. During the same period last year, it showed a loss of $70 million, or 16 cents per share. Operating revenues drove most of the improvement, as they climbed from $1.57 billion to $1.94 billion, an increase of about 23%.
Calpine signaled its confidence in the PJM market by announcing a new 760-MW generator at its York Energy Center near Delta, Pa. It is to be built on the site of its existing 565-MW combined-cycle plant. Using existing infrastructure will result in construction savings, and its location will allow it to take advantage of shale gas from Pennsylvania fields, according to CEO Thad Hill.
PEPCO
Pepco Holdings Inc. reported adjusted net income of $71 million, or 28 cents a share, compared to $53 million, or 21 cents per share, last year. The company credited higher electric distribution and transmission revenue and lower operation and maintenance expense for the uptick.
Pepco reported that applications for approval of its acquisition by Exelon have been filed with the Federal Energy Regulatory Commission, the Virginia State Corporation Commission, the Delaware Public Service Commission, the D.C. Public Service Commission and the New Jersey Board of Public Utilities.
Filings with the Maryland Public Service Commission are expected in the coming quarter.
DOMINION
Dominion Resources reported earnings of $159 million, or 27 cents per share, compared to $202 million, or 35 cents per share, last year, a decline of 21%. The company attributed the dip to milder weather, and a one-time charge resulting from Virginia legislation that permitted the company to recover 70% of the costs previously deferred or capitalized relating to the development of a third nuclear unit at North Anna and offshore wind facilities. Revenue declined to $2.81 billion from $2.98 billion, or 5.6%.
Thomas F. Farrell II, Dominion’s chairman, president and CEO, noted on a conference call that the company recently received an environment assessment approval from FERC for its Cove Point LNG facility in Maryland. Farrell also noted the company’s acquisition of two solar projects in Tennessee and an agreement to acquire its seventh in California, bringing its total solar projects in operation or development to 232 MW.
AEP
American Electric Power reported earnings of $390 million, or 80 cents per share, compared to $338 million, or 69 cents per share, last year, an increase of about 15%.
CEO Nicholas K. Akins said the company’s regulated transmission business brought in 10 cents per share for the quarter, up from 4 cents for the same period last year. It is a part of the business AEP is counting on.
“The additional $300 million that we’ve allocated to our transmission business in 2014 brings our total transmission capital investment to approximately $1.9 billion, which will support future earnings growth,” Akins said.
PSEG
Public Service Electric Enterprise Group reported a profit of $212 million, or 42 cents a share, compared to $333 million, or 66 cents a share, for the second quarter, a drop of 36%.
An extended outage of its Salem nuclear station’s Unit 2 was the cause of some of the decline. PSEG Power, the company’s generation arm, showed a 74% drop in net income, from $210 million in the second quarter of last year to $54 million for the same period this year.
The company’s regulated utility business reported a 25% rise in profit — $151 million on revenue of $1.435 billion this year, from $121 million on $1.423 billion last year.
“The primary driver of growth — increased investment in transmission in our utility PSE&G — remained strong in the second quarter, offsetting the impact from mixed operating conditions,” PSEG Chief Executive Ralph Izzo said.
PJM officials last week defended their practice of creating interfaces to capture operator actions in response to voltage problems, saying they can’t guarantee the constraints will be modeled in Financial Transmission Right auctions.
