FERC Orders MISO to Change Auction Rules

By Amanda Durish Cook

FERC has ordered MISO to change the way it conducts capacity auctions beginning with the 2016/17 auction in April as it continues to investigate allegations of market manipulation against Dynegy (EL15-70).

While the commission didn’t rule on the issue of consumer refunds, several parties to the case predict such relief might be in the works.

“We find that the record shows that certain of the Tariff provisions governing market mitigation measures are no longer just and reasonable,” FERC wrote in its determination.

According to the commission, MISO stumbled on two fronts: The $155.79/MW-day maximum bid was too high for a “vibrant market” and needed to be set closer to $25, and MISO didn’t accurately gauge power exports. FERC said MISO’s current approach to determining capacity import limits doesn’t take into account counter-flows created by neighboring RTOs.

MISO has 30 days to file revised capacity import limits and set the initial reference level for capacity at $0/MW-day and 90 days to file Tariff revisions to develop default technology-specific avoidable costs ahead of the 2017/18 auction. The $0 default will replace MISO’s current practice of allowing offers based on the estimated opportunity cost of exporting capacity.

More Rulings to Come

More is to come on the matter, however, as the Dec. 31 order only addressed parts of the complaints brought forward by Public Citizen, Illinois Attorney General Lisa Madigan, the Illinois Industrial Energy Consumers and Southwestern Electric Cooperative that deal with Tariff provisions on the auction “given the limited amount of actionable time prior to the 2016/17 auction,” according to the commission. FERC is continuing its non-public investigation into the matter. (See FERC Launches Probe into MISO Capacity Auction.)

Public Citizen, the consumer advocacy group that filed the first complaint in May, called the ruling a “partial victory.” The group alleged that Houston-based Dynegy manipulated the April capacity auction by withholding capacity, resulting in prices clearing at $150/MW-day for the Zone 4 portion of Illinois, up to 40 times greater than clearing prices elsewhere in the footprint. The spike represented a nine-fold price increase in the zone compared with the year before and prompted FERC to call an October technical conference. (See MISO Stakeholder Process Under Scrutiny.)

Dynegy said it is “looking forward to working with MISO” to implement the changes mandated by FERC.

Spokesman Micah Hirschfield said it is “imperative” that the market construct in Zone 4 work with Southern Illinois’ competitive structure to avoid future retirements.

“Generators in Southern Illinois rely on the markets for revenues, unlike the traditionally regulated utilities in the neighboring states that embed their costs into their rates. Generation has, and will continue to, retire in Southern Illinois unless the market design reflects the competitive nature of the market, which has delivered lower costs to consumers than many of the neighboring states,” Hirschfield said.

Dynegy continues to maintain that it offered all of its megawatts into the April capacity auction “with no physical or economic withholding” and followed MISO’s Tariff.

MISO to Weigh Rehearing

FERC’s order that MISO set offers to a zero default elicited a critical reaction from MISO Independent Market Monitor David Patton, who said entering offers at $0 makes little economic sense. “I can’t imagine what the economic theory is behind that,” he said.

“We’re weighing whether to file for rehearing. I don’t know that we will because we argued all of this at the technical conference,” Patton said. He added that FERC and MISO seem to be employing separate economic principles, and that he will reach out to MISO to see how the Tariff will have to be revised to comply with the order.

“I think they recognize a problem, but at this point, [FERC is] unwilling to address it,” Patton said of FERC’s decision.

Refunds to Come?

The ruling has some groups anticipating refunds, and FERC has allowed for a refund effective date of May 28, 2015, the date of Public Citizen’s initial complaint.

“If FERC follows the logic of its New Year’s Eve ruling, and regardless of whether the commission finds Dynegy manipulated the market, then Illinois consumers will be in line for tens of millions of dollars in refunds,” Tyson Slocum, director of Public Citizen’s energy program, said in a statement.

Madigan also said refunds are in order. “It’s great news that FERC has acknowledged downstate electric customers deserve relief from an inflated and absurd pricing process. I am pleased with FERC’s decision to fix the auction rules, but FERC still needs to order refunds to consumers for the outrageously high prices,” she said in a press release.

FERC’s Ruling Limited

FERC stated in the order that MISO is under no obligation to modify zones or combine Zones 4 and 5. “Nevertheless, we encourage MISO to continue to work with its stakeholders to ensure its zonal boundaries reflect the physical realities of the transmission system,” the commission wrote.

FERC also determined that use of a sloped demand curve would not be addressed, as it falls outside of FERC’s response to the complaint. “We will not address potential revisions to MISO’s capacity construct, including a sloped demand curve, longer forward period and a minimum offer price rule, here because they are beyond the scope of these proceedings.

“However, we recognize that MISO is working with stakeholders to explore potential revisions to the capacity construct, including concerns specific to Zone 4, and we encourage them to continue doing so,” FERC wrote.

January 5, 2016

LS Power’s Artificial Island Rate Filing Challenged

By Suzanne Herel

The Delaware Public Service Commission, the Delaware Municipal Electric Corp. and American Municipal Power are protesting the formula rates proposed by LS Power’s Northeast Transmission Development for the Artificial Island project (ER16-453).

Northeast Transmission “has failed to demonstrate that its proposed return on equity [ROE], formula rate protocols, process for using a projected transmission revenue requirement, capital structure approach, depreciation rates or incentives are just and reasonable,” the PSC wrote.

The protesters asked FERC to suspend Northeast Transmission’s filing for the maximum of five months and conduct an evidentiary hearing on the matter.

Northeast Transmission is a subsidiary of LS Power, which PJM chose to build a stability fix for the the Salem and Hope Creek nuclear reactors in New Jersey. (See PJM Board OKs LS Power’s Artificial Island Project Despite Objections.)

In its 810-page, Dec. 2 filing, the company requested that FERC approve its annual transmission revenue requirement and five categories of transmission rate incentives — including 100 basis points in adders for participation in PJM and “the increased risks and challenges” of the project — effective Feb. 1. It asked to replicate the rate and incentives for future projects conducted by yet-to-be-formed affiliates.

In its protest, the Delaware Municipal Electric Corp. took issue in part with the proposed 10.5% base ROE, which it called “unjustified and inconsistent with commission precedent.” It also criticized the company’s request for a 50-basis-point adder for participation in PJM as unwarranted. If awarded, the adder should not take effect until the project goes into service, expected to be June 1, 2019, it said.

AMP also challenged Northeast Transmission’s proposed ROE and depreciation rates. It asked that FERC issue a delinquency filing requiring the company to provide additional information supporting its income tax calculations and post-employment benefits expense and said it would participate in any settlement judge procedures.

The project will consist of a new 230-kV transmission line between the Salem substation in New Jersey and the 230-kV Red Lion-Cartanza and Red Lion-Cedar Creek transmission lines in Delaware by way of the newly constructed Silver Run substation. Northeast Transmission will construct the river crossing, with Public Service Electric & Gas and Pepco Holdings Inc. doing related substation and connection work.

PJM’s proposed cost allocation, which would bill nearly all of the $146 million price tag to consumers in Maryland and Delaware, will be the subject of a Jan. 12 FERC technical conference. The conference will “explore both whether there is a definable category of reliability projects within PJM for which the solution-based FERC Questions Fairness of Artificial Island Cost Allocation.)

January 5, 2016

SPP Report Shows 16% Decrease in Coal Generation

SPP has seen a 16% drop in coal-fired generation over the last two years, thanks in no small part to consistently low gas prices.

The SPP Market Monitoring Unit’s quarterly market report for September-November said coal-fired resources accounted for 52.1% of generation in the fall of 2015, compared to 62.7% in 2013, the last few months of SPP’s energy imbalance services market.

spp The Monitor noted the decline in coal generation has been offset by increases in wind (up 3.7%), nuclear (up 3.4%) and combined cycle generation (up 3.3%). Hydro generation increased 2.1% over the two-year period, primarily because of the addition of the Western Area Power Administration-Upper Great Plains.

According to the report, Panhandle Hub gas costs averaged $2/MMBtu in November. Average gas prices for the fall were $2.25/MMBtu, compared to $3.76/MMBtu in 2014.

Average LMPs for both the real-time balancing market and the day-ahead market also saw significant declines. Real-time LMPs averaged $20.73/MWh (-$8.84 from fall 2014) and day-ahead LMPs averaged $19.98/MWh (-$8.19).

Lower prices were “prevalent in the north due to less expensive generation” and in the west-central due to the area’s “abundant low-cost wind,” the report said.

The MMU said SPP is experiencing divergence between day-ahead and real-time prices, partially because of “significant price volatility” in the real-time market.

— Tom Kleckner

January 5, 2016

FERC Asked to Toss Huntley RMR Agreement

The New York Public Service Commission staff on Dec. 28 asked FERC to throw out a proposal to keep a doomed coal-fired power plant operating for several months at above-market rates (ER16-81).

The PSC said FERC should reject the proposal made by NRG Energy to keep the 380-MW Huntley plant in Tonawanda, N.Y., going past March 1. NRG is seeking a cost of service agreement for reliability-must-run service that could keep Huntley running for an additional three months or longer. (See NRG Seeks Change on Huntley Reliability Contract.)

NRG had apparently pinned its hopes on concerns that the area would need voltage support until National Grid completes transmission upgrades. Even that justification for Huntley’s operation has fallen away.

“NYISO and National Grid recently exchanged correspondence which demonstrates conclusively that even without the transmission projects (including its capacitor banks and reactors), facility deactivation will not give rise to any local or bulk system reliability need on or after the proposed March 1, 2016, retirement date,” the state commission wrote. “Consequently, there is no basis to consider — much less approve — an RMR agreement that would subsidize facility operation after the proposed retirement date.”

NRG spokesman David Gaier said the company would be willing to negotiate an RMR agreement with NYISO and National Grid, but he seemed resigned. “At this moment … the Huntley station will retire as previously announced on March 1,” he said.

— William Opalka

January 5, 2016

Federal Briefs

Tennessee Gas Pipeline took strong issue with Massachusetts Attorney General Maura Healey’s contention that the proposed Northeast Energy Direct pipeline is unneeded in a 503-page response to questions posed by FERC and other interested parties about the natural gas pipeline.

The pipeline company said Healey’s study ignores important information and doesn’t fully take into account the amount of baseload generation that is being retired in the Northeast, and the resulting need for more fuel for gas-fired generation.

In addition to addressing issues such as its use of protected land and possible greenhouse gas emissions, the company also rejected assertions that the pipeline would be partially funded by ratepayer tariffs. “The proposed project is not relying on subsidies to be built,” Tennessee Gas wrote.

More: The Recorder

FERC Begins Review of PennEast Pipeline Project

FERC has begun an environmental impact study of the PennEast Pipeline, a proposed 114-mile project that would deliver natural gas from the Marcellus Shale formation in Pennsylvania to markets mostly in New Jersey.

The commission has asked EPA, the U.S. Army Corps of Engineers and the U.S. Fish and Wildlife Service to participate in the study. A draft of the study will be made available for public review, and comments from the public will be incorporated. PennEast has said it wants to begin construction in early 2017.

More: The Morning Call

Texas Joins States in Challenge to EPA Ozone Rule

Texas last week announced it would join eight states that are contesting EPA’s ozone rule, which would cut power plant and industry ozone release from 75 parts per billion to 70 ppb. Texas Attorney General Ken Paxton said the new rule would “impose a serious financial burden on the Texas economy for dubious public health benefit.”

“The EPA’s new ozone rule is not supported by scientific data,” Paxton said. “Areas of the country that fail to comply with these impossible standards will be subject to costly new regulations that will harm our economy and kill jobs.”

The environmental agency finalized the National Ambient Air Quality Standards for ozone on Oct. 1. Arizona, Arkansas, Kentucky, New Mexico, North Dakota, Oklahoma, Utah and Wisconsin have announced they would challenge the new standards.

More: Power Magazine

DOE Launches Spent Nuclear Fuel Initiative

The Energy Department has launched an initiative to develop an alternative repository for spent nuclear fuel to the failed proposal to build the Yucca Mountain site in Nevada. The new effort will concentrate on developing a site with the consent of a local community.

“The launch of our consent-based siting initiative represents an important step toward addressing this nuclear waste management challenge, so that we can continue to benefit from nuclear technologies,” Lynn Orr, the deputy secretary for science and energy, wrote in a blog post last week.

More: The Hill

FERC Agrees to Allow Missouri Hydro Project to Move Forward

FERC has granted a permit allowing a three-year study on the feasibility of an 8-MW hydro project at an existing dam near Hannibal in Ralls County, Mo.

Energy Resources USA wants to build a new, 770-foot-long intake area at the Mississippi River Lock and Dam No. 22, which is owned by the federal government. The project would funnel water to a concrete powerhouse containing four hydro turbines. FERC’s approval means the company can move forward with the study and start to prepare a license application.

More: HydroWorld

South Carolina: DOE Owes $1 Million Daily for MOx Plant Failures

South Carolina says it is beginning to tally a $1 million/day tab against the Energy Department for failing to fulfill a promise to get its trouble-plagued mixed-oxide fuel fabrication facility operating by the end of 2015.

The MOx facility was supposed to be disposing of 34 metric tons of weapons-grade plutonium by Dec. 31 under a 2003 agreement between the department and South Carolina. Gov. Nikki Haley wrote to Energy Secretary Ernest Moniz informing him that the state intended to start imposing the fine for the missed milestone. “Promises made must be promises kept,” she said in the letter.

Moniz has not yet responded.

More: Aiken Standard

January 5, 2016

MISO to Tackle Capacity, Queue, Caps and CPP in 2016

By Amanda Durish Cook

It’s been 15 years since FERC approved MISO as an RTO and, like a teenager, MISO is experiencing a growth spurt.

Last month, the board approved an annual Transmission Expansion Plan consisting of 345 projects valued at $2.75 billion. With the exception of 2011, the plan represents the footprint’s largest expansion since the annual process began in 2003.

This year’s spending plan includes a $31 million capital budget and a $225 million operating budget, a 3% increase over 2015.

Busy Year Ahead

MISO expects a busy 2016.

In January, it will begin selecting a developer for its first competitively bid transmission project under FERC Order 1000, southern Indiana’s Duff-Coleman 345-kV project.

In February, design review will begin on MISO’s proposed two-season capacity market construct. Under a draft proposal, the RTO would obtain capacity based on a June-September summer season and an October-May winter, with separate seasonal resource accreditations, reserve margins and capacity import/export limits. (See MISO Proposes Two-Season Capacity Market.) FERC filings are expected in March.

MISO capacity auctions still won’t be mandatory, as FERC struck down the RTO’s request for compulsory capacity auction participation in November.

Resource adequacy will continue its presence on MISO agendas in 2016. In the first six months, the RTO will consider recommendations from a task team appointed by its Supply Adequacy Working Group on how to accommodate merchant generators in Illinois’ Zone 4, where retail choice is permitted. The move followed an October FERC technical conference and two policy sessions of the Illinois Commerce Commission on problems in the area.

“I think what’s been identified in Illinois is a gap,” Jeff Bladen, MISO’s executive director of market design, said in early December. “It is a very targeted, surgical matter that needs to be tackled.” (See Stakeholders to ICC: MISO Resource Adequacy Fine — for now.)

MISO also will continue its modeling of the potential impacts of the Clean Power Plan. According to initial results released last month, compliance costs could vary widely in the footprint, with the price of natural gas a major variable. (See MISO: Coal Retirements, Gas Prices, Flexibility Key to CPP Compliance Costs.)

MISO’s new interconnection queue rules will begin Feb. 20. Following a transition, projects will move through a reformed queue that includes a non-refundable $5,000 study deposit and two “off-ramps” where owners can choose to withdraw projects for a refund. (See MISO Unveils Queue Reform Transition as Wind Advocates Seek Delay.)

SPP Dispute Settled

In October, MISO settled a grid-use dispute with neighboring SPP regarding the 1,000-MW transfer limit in their joint operating agreement. The settlement replaced the RTOs’ operations reliability coordination agreement and the resulting $9.57/MWh hurdle rate that had been in place since 2014. (See SPP, MISO Reach Deal to End Transmission Dispute.)

Late 2015 also saw the adoption of a new stakeholder redesign. The changes, which include closing out completed task forces, merging redundant groups, emphasizing joint meetings and re-evaluating meeting schedules, will take effect over the next three months. (See MISO Stakeholders OK Redesign, Begin Implementation.)

The redesign absorbed or consolidated seven groups. The RTO’s Advisory and Steering Committees will oversee the transition.

Michelle Bloodworth, executive director of external affairs, said the redesign was “a great step to making sure stakeholders are well positioned to address the big challenges our region faces.”

Meanwhile, a mild winter so far has made it easy to live with MISO’s October decision to delay raising its energy offer cap. Instead, the RTO asked FERC to approve another waiver allowing recovery of generators’ costs above $1,000/MWh through uplift payments. MISO says it plans to put together a “permanent solution” in time for next winter. (See MISO: No Change to Energy Offer Cap this Winter.)

January 5, 2016April 22, 2024

State Briefs

These Power Bill Savings Aren’t Chicken Scratch

The Delmarva Poultry Industry predicts that its new energy-buying group will save chicken producers more than $1 million over the next three years.

Poultry producers began seeing those savings in December’s electric bills. The group said more than 200 members will pay 7.78 cents/kWh under a fixed-price electric supply contract with WGL Energy.

More: Associated Press

ILLINOIS

Commission Blocks Landowners’ Appeal of Grain Belt Express

The Commerce Commission has declined to reconsider its approval of the Grain Belt Express, a $2 billion HVDC transmission line that would move power from Kansas wind farms to Indiana.

The commission, which approved the project in a 3-2 vote in November, rejected appeals from landowners who argued that project developer Clean Line Energy Partners of Houston failed to meet expedited approval standards. Opponents of the project include the Pike and Scott County Farm Bureaus, which are considering a court appeal of the ICC’s approval.

Regulators in Kansas and Indiana have also approved the 780-mile overhead transmission line, while the Missouri Public Service Commission has balked.

More: The State Journal–Register

INDIANA

NIPSCO’s Planned Tx Lines Find Little Opposition

Northern Indiana Public Service Co. is backing construction of two transmission lines in the state to deliver power from Midwestern wind farms to markets on the East Coast.

NIPSCO will build a 100-mile line from Reynolds to Topeka in early spring that will cost from $250 million to $300 million. The company also formed a 50-50 partnership with Pioneer Transmission to build a 70-mile line from Greentown to Reynolds that is set to break ground early this year. That line will cost up to $400 million.

Unlike other transmission projects, the two proposed lines have attracted little opposition. NIPSCO spokesman Nick Meyer credited the company’s success with local landowners to the long timelines set by the utility for public meetings. He said that as generation switches from coal to wind and other sources, more transmission projects will need to be built.

More: The Times of Northwest Indiana

MISSOURI

Empire District’s Sale Rumors Leave City of Monett in Lurch

Leaders of the Monett municipal utility say they are taking a wait-and-see approach to news that Empire District Electric, the city’s power supplier, plans to explore strategic alternatives.

Monett is three years into a 10-year contract with Empire, an investor-owned utility. “Empire is really a small fish compared to other power companies,” Monett Utilities Superintendent Skip Schaller said. “They may think they’d be better off being bigger. We could even see lower rates.”

The dynamics of the electricity business for the area changed when Empire joined SPP in March, and the region became integrated into the RTO’s markets.

More: The Monett Times

NEW MEXICO

Commission Grants Rehearing on Renewable Charge

Large-scale electric customers have won a new chance to convince state regulators to let them keep fuel savings they currently receive as a result of Public Service Company of New Mexico’s investments in renewable energy.

The Public Regulation Commission voted 5-0 on Dec. 23 to vacate an earlier decision that would have forced industrial and governmental energy users to repay those savings to PNM. The issue will be reheard on Jan. 13 by the full commission, which could still decide to uphold its original order from November.

Industrial consumers and the Albuquerque Bernalillo County Water Utility Authority filed motions opposing the PRC’s November decision, which ordered about two dozen industrial users, including the water authority and the University of New Mexico, to pay a combined total of about $2 million in annual fuel savings back to PNM.

More: Albuquerque Journal

Navajo Energy Pursuing Ownership in Four Corners Power Plant

The Navajo Transitional Energy Co. has received the green light from its board of directors to pursue acquiring an ownership interest in the Four Corners Power Plant.

NTEC officials said they are reviewing the possibility of obtaining the 7% interest held by El Paso Electric in Units 4 and 5. NTEC notified Arizona Public Service, the power plant’s majority owner, about plans to exercise the option to purchase that interest.

APS owns 63% of the generation from Units 4 and 5, followed by the Public Service Company of New Mexico with 13%, the Salt River Project with 10% and Tucson Electric Power and EPE with 7% each. EPE entered into an asset purchase agreement in February to sell its entire interest to APS.

More: Farmington Daily Times

Town Agrees to Solar Agreement with Florida Firm

Construction on a $2 million solar farm will start in January after the Aztec City Commission approved agreements with a Florida developer.

The commissioners approved the deal to enter into a wholesale power agreement and build a solar energy facility on city property with Guzman Energy of Coral Gables, Fla.. The 1-MW facility will be located south of the city.

More: Farmington Daily Times

NEW YORK

Power Marketer Agrees to Refunds

An independent supplier of electricity and gas for residential customers has agreed to refund nearly $1 million to resolve complaints about its billing practices. Ambit Energy issued $950,700 in refunds to 1,566 customers following an investigation by the state’s Department of Public Service’s consumer advocate.

The state investigation was launched following complaints about Ambit’s customer disclosure statements and renewal notices, particularly for customers who were moved from a guaranteed-savings plan into a variable rate plan charging significantly more.

More: Syracuse.com

State Reallocates $6 Million of Solar Fund

The state has reallocated $6 million in its solar incentive program, which will be available to new applicants.

Gov. Andrew Cuomo’s $1 billion NY Sun program includes block grants in each region of the state that run out after a certain amount of money is spent. The reallocation comes after the cancellation of some projects.

More: Times Union

NORTH DAKOTA

SPP Membership Sets Up Company to Become Major Energy Player

A 25-year-old electric cooperative has joined SPP, allowing it to make a bigger mark on the region’s energy map.

Mountrail-Williams Electric Cooperative said that joining the RTO will give it access to export power to other regions, something it has been unable to do before. SPP will also help Mountrail-Williams optimize its transmission system.

Dale Haugen, manager of Mountrail-Williams, said that SPP membership “will position us in the future for wind generation and even natural gas generation and everything else. It puts us into the marketplace.”

More: Williston Herald

Transmission Authority Faces Challenge in Solutions to CPP

The Transmission Authority, which plans and oversees transmission buildout in the coal-dependent state, is facing new challenges to comply with the federal Clean Power Plan.

Authority Director Tyler Hamman said “no one really knows what to do” about the CPP yet. Any solutions that involve constructing more wind power will also require additional transmission infrastructure.

More: The Bismarck Tribune

County Approves Wind Farm, Despite Opposition

The Stark County Commission and its Planning and Zoning Board approved a conditional-use permit for a controversial wind farm to be erected by NextEra Energy Resources.

The public bodies were divided on the issue, reflecting a split in the community over the $250 million, 87-turbine project.

More: The Dickinson Press

OHIO

Dominion East Customers Get a Break on Natural Gas

Dominion East Ohio customers can expect to pay lower natural gas bills this winter, as abundant supply has driven down the price of the fuel and forecasters predict a milder winter compared with the past two years that will reduce demand, the company said.

Under the current rate, the average residential customer will receive a December bill of about $66.12, nearly 40% less than in the same period a year ago.

“One of the major drivers of our supply security is increasing natural gas production right here in Ohio,” said Jeff Murphy, vice president and general manager.

More: Dominion East Ohio

TEXAS

PUC Recommends Reducing EPE Rate Request

El Paso Electric’s proposed rate increase for customers should be reduced by about $17 million, or 24% less than the utility requested, the Public Utility Commission staff recommended.

The state regulatory agency staff recommended EPE’s rate-increase request be decreased from $71.5 million to $54.3 million, according to documents filed Dec. 18 with the PUCT as part of the review process. The City of El Paso thinks the utility should receive only a $23.5 million increase.

The PUC staff recommended approving the utility’s request to create a new rate class for residential customers with rooftop solar systems, which would increase those customers’ electric rates more than regular residential customers. That proposal is being fought by solar installers, homeowners with rooftop solar and others.

More: El Paso Times

VIRGINIA

Governor Pledges to Increase Solar Power

The state government will work toward deriving at least 8% of its electricity from solar power over the next three years, Gov. Terry McAuliffe has pledged.

That’s about 110 MW, about seven times more solar power than is installed across the state.

The initiative grew out of a study by McAuliffe’s Climate Change and Resiliency Commission.

More: Richmond Times-Dispatch

WEST VIRGINIA

FirstEnergy Cos. Win Rate Increases

The Public Service Commission has approved rate increases for two FirstEnergy subsidiaries, allowing them to recover $96.9 million, including expenses for beefed-up tree trimming programs and higher fuel and purchased power costs.

Typical residential customers of Mon Power and Potomac Edison can expect to see a monthly increase of about $9 in their January bills.

Since the PSC approved the companies’ vegetation management program in April 2014, tree trimming has taken place along 7,000 miles of transmission lines.

More: Associated Press

WISCONSIN

Republicans Trying Again to Lift State Nuclear Ban

GOP leaders in the state are pushing ahead with two bills that would lift the state’s 32-year-old ban on new nuclear generation.

Three previous legislative efforts in the last decade failed to lift the ban, but last month the State Assembly’s Committee on Energy and Utilities voted 13-0 in favor of reopening debate on ending the moratorium. The Assembly will vote on its bill in January, while the Senate’s bill hasn’t been scheduled for a hearing date yet.

Michael Corradini, a University of Wisconsin-Madison professor of engineering physics, said even though nuclear plants are being retired today for economic reasons, plans for smaller, more inexpensive nuclear plants are being developed and could be put in service within the decade.

More: The Chippewa Herald

January 5, 2016

Stakeholder Soapbox: Most Important Energy Numbers from 2015

By Aaron Tinjum

There were a number of major energy developments in 2015, including historically low oil prices, record levels of natural gas in storage, major policy and regulatory changes, and a groundbreaking international climate agreement.

We’ve assembled some of the most telling energy statistics to help highlight some of the year’s biggest energy trends. Here are the top energy numbers from 2015.

Near 4 Tcf

US Breaks Gas Storage Record

The U.S. Energy Information Administration reported that the country’s working natural gas in storage as of Oct. 30 matched the all-time record of 3,929 billion cubic feet (Bcf).

A few weeks later, U.S. working natural gas in storage broke the all-time record with 3,978 Bcf, just shy of 4 trillion cubic feet.

What conditions helped contribute to a record year for natural gas storage? Record levels of natural gas production — marketed production hit a record high of 81.1 Bcf/day in September — and an exceedingly mild winter in key consumption regions, especially the Northeast.

$49/barrel

Oil Prices Tumble

It was a tumultuous year for global crude oil prices.

According to estimates from EIA, the average price per barrel of West Texas Intermediate crude oil fell to $49.08 in 2015, a drastic decrease from $93.17 in 2014 and $97.98 in 2013.

It was a similar story for Brent crude oil, which averaged $52.93, down from $98.89 in 2014 and $108.56 in 2013.

What helps explain the dramatic drop in oil prices? The decrease is largely due to sustained growth in global production, which has outpaced consumption growth since August 2014, resulting in a surplus in global inventories.

EIA expects crude prices to increase slightly in 2016.

2 Degrees Celsius

Climate Agreement Reached in Paris

On Dec. 12, 2015, 195 countries reached an unprecedented climate change agreement at the 21st session of the U.N. Framework Convention on Climate Change’s Conference of the Parties in Paris.

The new treaty — which was the product of a four-year round of negotiations — aims to halt the global temperature increase well below 2 degrees Celsius above preindustrial levels, with a stretch goal of 1.5 degrees Celsius above preindustrial levels.

By U.N. estimates, halting the increase at 2 degrees Celsius alone will require a total emissions reduction of 40 gigatonnes, which will be no easy feat given that current proposals in aggregate would only keep emissions under 3 degrees Celsius.

So, how can the ambitious target be met? Natural gas, renewable energy resources and increased energy efficiency are all expected to play major roles worldwide.

32% by 2030

Obama Unveils the Clean Power Plan

In August, President Obama unveiled the final version of EPA’s Clean Power Plan.

The highly anticipated plan targets a 32% emissions reduction in the electric power sector — the largest source of carbon pollution in the U.S. — by 2030. The new rule is an increase from the initial proposal of 30% and is projected to cut carbon pollution by 870 million tons below 2005 levels.

Among the plan’s key provisions are flexible compliance options for states and utilities, safeguards for reliability, and an extended compliance period that doesn’t begin until Jan. 1, 2022.

20 Years

Power Sector Emissions Drop to Lowest Levels Since 1995

While the Clean Power Plan was a major development in 2015, a less-covered story was that carbon emissions from the U.S. power sector have already decreased significantly in recent years.

According to an analysis conducted by the Sierra Club, annual carbon emissions produced by the U.S. power sector will total 1,983 million metric tons (MMT) by the end of 2015, which is the lowest level since 1995.

What explains the decrease? Unprecedented coal retirements have played a major role, with 2015 retirements equaling the amount of capacity retired from 1990-2009.

+1%

Total Energy-Related Emissions Rose 1% in 2014

While carbon emissions from the U.S. power sector were projected to decrease in 2015, final analyses indicated that total U.S. energy-related emissions increased in 2014.

According to EIA, emissions rose 1% in 2014 due to increased energy consumption in the transportation, commercial and residential sectors.

Altogether, U.S. energy-related carbon dioxide emissions were 5,406 MMT in 2014, 1% more than their 2013 level. In the transportation sector, CO₂ emissions were 24 MMT higher than the 2013 level. Commercial sector emissions rose by 19 MMT and residential sector emissions by 18 MMT.

Fortunately, compressed natural gas transportation solutions, cutting-edge building analytics and improved household energy efficiency all offer clear ways to reduce overall energy-related emissions.

5,000,000 Homes

Installed Solar Capacity Tops 24 GW

In 2015, U.S. total installed solar capacity topped 24.1 GW in the third quarter — enough to power 5 million U.S. homes.

With the extension of the investment tax credit (ITC) for solar systems, solar installations are expected to continue to grow. However, the bigger story might be that businesses are coming to fully recognize the inherent, long-term value of solar systems.

69,783 MW

ERCOT Shatters Demand Record

In August, ERCOT shattered its all-time peak demand record.

Demand for electricity reached 69,000 MW for the first time in the grid operator’s history. Electricity demand soared to 69,408 MW between 3 and 4 p.m. on Aug. 10 and rose to a record high of 69,783 MW between 4 and 5 p.m.

How did ERCOT meet the heightened demand? Through a combination of renewable resources — especially wind — and demand response.

$7.3 Billion

Capacity Performance Will Cost Consumers $7.3 Billion

In 2015, grid reliability became more expensive for many customers.

A report produced by the American Public Power Association found that PJM’s Capacity Performance model — which was opposed and challenged by Direct Energy — will cost consumers a staggering $7.3 billion over the next three delivery years.

PJM made the changes to its capacity market structure in response to the polar vortex of 2014, when 22% of the RTO’s generation resources were knocked offline.

While the changes were aimed at ensuring greater reliability during extreme weather events, it’s clear the plan will have an inverse effect on the region’s consumers and businesses.

Aaron Tinjum is Senior Writer for Direct Energy Business.

January 5, 2016

Infrastructure Moves to Forefront in New England

By William Opalka

Winter reliability, the forward capacity market and infrastructure expansion have been the dominant themes in New England in recent years, and 2016 appears to be no different.

Record warmth this winter has kept power prices tame and new reliability incentive programs are expected to ensure adequate fuel supplies. Capacity prices may also moderate due to the addition of new generating resources.

Capacity Prices Expected to Drop

Forward Capacity Auction revenues have almost quadrupled over the past two auctions, from just more than $1 billion in 2013 to $3 billion in 2014 and $4 billion last year. About 1,000 MW of new generation entered the market for the 2018/19 capacity commitment period.

Morningstar says it expects 750 MW of dual-switching capability to be added for winter 2015/16 and 1,000 MW more by winter 2016/17. (See ISO-NE: Little Room for Error in Winter.)

A lingering controversy to be cleared up before the coming auction is how solar resources should be calculated. (See Generators Dispute ISO-NE on Solar Capacity.)

Moving Toward Renewable Energy

Massachusetts is expected to reconsider its net metering cap early this year after proposals to raise it got bogged down in the legislature in 2015. Utilities there are closing in on the 1,600-MW limit.

Massachusetts, Connecticut and Rhode Island have embarked on a joint effort to procure clean energy more cost-effectively. Bids on prospective projects are due at the end of January.

The shift to renewable energy is progressing, as New England continues to lose its nuclear generation fleet. Entergy last year announced its 680-MW Pilgrim nuclear station will close no later than mid-2019, but the final date is expected to be announced by the middle of this year.

Key Milestones

Meanwhile, several proposals for new transmission lines and two natural gas pipelines reached key milestones last year, with more significant decisions on their fates due by the end of 2016.

Spectra Energy’s Algonquin Gas Transmission asked FERC in November for a pre-filing review of the proposed Access Northeast pipeline. The company expects to file a formal application in about a year and hopes to put the first phase of the project in service by November 2018. (See Algonquin Submits Pre-Filing Request for Access Northeast Pipeline.)

Also in November, developers of the Northeast Energy Direct pipeline through Massachusetts and southern New Hampshire filed certificates of need with FERC. The Kinder Morgan project would transport Marcellus shale gas from Pennsylvania. The developers hope for FERC approval in the fourth quarter. (See Northeast Energy Direct Files for FERC Certificate.)

Hydropower Plans Move Forward

Two competing proposals to import Canadian hydropower into the region also advanced last year.

Northern Pass Transmission received its draft environmental impact statement from the U.S. Energy Department. The New Hampshire Site Evaluation Committee is expected to rule by the end of the year on the 192-mile transmission line to move 1,090 MW of hydropower from Quebec. (See Committee Rules Northern Pass Application Complete.)

TDI New England’s Clean Power Link received its final environmental impact statement, which recommended approval of a presidential permit. The cross-border project would transmit 1,000 MW of Canadian hydropower under Lake Champlain.

The first phase of the project’s open season in December received expressions of interest from seven utilities on both sides of the border seeking 3,200 MW of capacity. Negotiation of the agreements will continue through this year.

January 5, 2016

After Year of Change, PJM Faces Questions

By Suzanne Herel

2015 was a year of change for PJM, which said goodbye to CEO Terry Boston, ushered in its new Capacity Performance product and awarded its first competitively bid transmission projects under FERC Order 1000.

Capacity Performance undoubtedly will be in the headlines again in 2016 under new CEO Andy Ott, previously executive vice president of markets. The new year also will see policymakers dealing with cost allocation for new transmission, the future of demand response and potential FERC rulings on financial trading and transmission planning.

That work will take place against the backdrop of a continuing fuel shift. For the first time in 2015, natural gas passed coal as the fuel used to generate the most electricity, thanks to the cheap bounty uncapped in the Marcellus Shale.

Morningstar analyst Jordan Grimes says the RTO, which retired 9.8 GW of coal-fired generation last year, could see as much as 18.5 GW of gas-fired combined cycle units come online through 2019.

Grimes said the new generation will have some of the lowest prices in the PJM dispatch stack after wind, nuclear and hydro and is unlikely to set marginal prices often during on-peak hours. “The combined cycles will displace some coal generation, but at the margin it will be displacing less efficient gas units. This gas-on-gas competition means coal will actually be on the margin more often,” Grimes wrote. “Coal plants amortizing costs over a shorter time period, MATS compliance and less energy revenue should encourage coal plants to raise offers with their new pricing power on the margin.”

Effective March 31, PJM will move its deadline for day-ahead energy offers up 90 minutes to 10:30 a.m. ET to ensure gas units have time to procure fuel before the revised 2 p.m. ET timely nomination deadline for gas. (See PJM, NYISO, ISO-NE Gas Scheduling Filings OK’d.)

After a long debate, PJM members voted to raise the energy market offer cap to $2,000 to ensure that gas-fired generators can recover their costs when prices spike during extreme conditions, like those seen during the 2014 polar vortex. (See PJM Members OK $2,000/MWh Energy Market Offer Cap.)

Capacity Performance

It was unusually high generator outages during the polar vortex that also gave rise to the controversial new Capacity Performance model, designed to strengthen reliability by giving bonuses to over-performing generators and assessing heavy penalties on those that fail to perform.

The new year will bring PJM its first operational experience under the new rules. PJM will have about 95 GW of Capacity Performance resources for the 2016/17 delivery year beginning June 1.

Transition auctions to add the upgraded product cleared at $134/MW-day (2016/17) and almost $152 (2017/18). (See PJM Transition Auction Means Reprieve for Exelon Nukes.)

The 2018/19 Base Residual Auction — the first BRA to include the product — saw prices rise 37% to $165/MW-day in most of the RTO, while the ComEd zone broke out at $215 and Eastern MAAC hit $225.

UBS predicts prices will dip to about $100/MW-day for the 2019/20 delivery year and $153/MW-day for 2020/21. The analysts said changes to PJM’s load forecasting methodology — aimed at correcting several years of overly bullish projections — “largely [undo] the upside” from CP. (See “Load Forecast to Include Distributed Solar” in PJM Markets and Reliability Committee Briefs.)

pjm

Bidding behavior could be affected by FERC rulings on PJM’s market rules.

Last month, PJM asked FERC to rule by Feb. 1 on its Capacity Performance compliance filings and outstanding rehearing requests (ER15-623, EL15-29). PJM said it is trying to avoid “operational challenges” that could result from uncertainty over when PJM’s dispatch decisions will result in a capacity market seller being exposed to non-performance charges.

“Some resource owners have told PJM they will turn to self-scheduling (or self-dispatching) and operate at maximum output to avoid non-performance charges,” PJM wrote. “This clearly is an anomalous result which is contrary to the goals of Capacity Performance as a tool to enhance operational performance and system reliability.”

Changes also could result from a problem statement approved by stakeholders in December to consider widening force majeure rules and expanding ways for generators to minimize underperformance penalties by netting them against over-performing generators. (See “Ways to Mitigate Risk in CP Market to be Studied” in PJM Markets and Reliability Committee Briefs.)

Despite the increase in prices under Capacity Performance, FirstEnergy and American Electric Power have asked Ohio regulators to approve proposals to essentially reregulate 6,300 MW of their generation. PJM filed testimony last week expressing concerns over the impact of the proposals on the wholesale markets. (See PJM Seeks Changes to AEP, FirstEnergy PPAs.)

Order 1000 Projects

The PJM Board of Managers ended the year by approving $490 million in transmission projects proposed in response to FERC Order 1000 competitive solicitations.

In July, it finally greenlighted its first Order 1000 project, a stability fix for the Salem and Hope Creek nuclear reactors on New Jersey’s Artificial Island. The approval of the project, which followed a controversial two-year selection process, almost immediately spawned a new dispute as officials in Maryland and Delaware complained that they were being billed for virtually all of the $146 million price tag. The cost allocation issue will be the focus of a FERC technical conference scheduled for Jan. 12. (See FERC Questions Fairness of Artificial Island Cost Allocation.)

Transmission Planning, UTCs, FTRs

PJM stakeholders will be spending a lot of time with FERC in 2016:

Reply comments are due Jan. 15 in FERC’s inquiry into PJM’s local transmission planning process, the subject of a technical conference in November. (See PJM TOs Defend Jurisdiction at FERC Conference.)
PJM traders are awaiting a FERC order telling them whether up-to-congestion trades will be charged uplift and made subject to PJM’s financial transmission rights (FTR) forfeiture rule (EL14-37). In opening the Section 206 docket in 2014, the commission said it would rule within five months after it receives comments following a technical conference. The conference was held Jan. 7 and comments were due May 29. That put FERC on schedule for a ruling by the end of October, but there has been no word from the commission so far. (See Monitor at Odds with PJM, Marketer over FTR Forfeiture Rule.)
Last week, the commission ordered a technical conference on PJM’s proposed changes to its FTR allocation rules. (See related story, FERC Orders Technical Conference on PJM FTR Rule Changes.)
2016 also could see action by FERC to address issues over PJM’s seam with MISO. In February, the commission said it was considering intervening and ordered the RTOs to provide status reports on eight unresolved seams issues (AD14-3). (See Impatient FERC Hints at Action on PJM-MISO Seams Disputes.) Commission staff have attended three PJM/MISO joint stakeholder meetings since.

PJM stakeholders also are anxiously awaiting the Supreme Court’s ruling on an appellate court order that voided FERC’s jurisdiction over DR. With one justice having recused himself, the court could split 4-4, leaving the ruling standing and PJM scrambling to adjust to the impact on its capacity market. (See FERC Jurisdiction over DR in Peril as Supreme Court Splits.)

The court also will review lower court rulings throwing out state-issued contracts Competitive Power Ventures won to build combined cycle plants in Maryland and New Jersey. (See SCOTUS Agrees to Hear Md., NJ-FERC Subsidy Case.)

New Faces and Retirements

In addition to the departure of Boston, the RTO also said goodbye to board member William Mayben, who retired after eight years. South Carolina engineer Terry Blackwell was elected to serve out the remainder of Mayben’s term. Going forward, the board announced, members will be ineligible for re-election once they either turn 75 or have served five terms. (See New PJM Board Member Elected, Re-election Eligibility Changed.)