Page 1469 – RTO Insider

March 21, 2016

FERC: Cheap Gas Drove down Electricity Prices in 2015

By Michael Brooks

WASHINGTON — On-peak day-ahead electricity prices in the U.S. were down 27 to 35% in 2015 compared to 2014 largely because of cheap natural gas, FERC staff said in its State of the Markets presentation Thursday. LMPs in New York hit a 15-year low.

FERC: 2014 a Record-Breaking Year for Natural Gas.)

The increase in supply has led to the addition of 51 Bcf/d in new pipelines in the last five years, with an additional 49 Bcf/d planned or proposed to come online by 2018. Demand for gas, however, grew only 1.3% last year as a result of a mild winter.

As a result of the low prices, gas-fired generation surpassed coal-fired on a monthly basis for the first time in April 2015, and beat coal in six of 11 months through November, according to the Energy Information Administration. Each provided about one-third of all electricity generation.

EIA predicted last week that natural gas will provide 33% of generation in 2016 while coal’s share falls to 32%. Bowring Urges Return to ‘Fundamentals’.)

FERC staff said they expect the trend of lower gas prices to continue into 2016 but that production has likely plateaued and will decline in the long run, as the low prices begin to push higher-cost producers out of the market.

About one-sixth of U.S. natural gas is a byproduct of oil production, which suffered as prices fell 66% between June 2014 and December 2015. According to the U.S. Bureau of Labor Statistics, the oil and gas industry shed about 17,000 jobs last year, while the U.S. oil rig count dropped by 61%.

“Long-term demand growth for U.S. natural gas will likely come from increased gas-fired electric generation, particularly in the Southeast, growing industrial demand, LNG exports and pipeline exports to Mexico,” staff said.

The price of LNG, which was exported for the first time from Cheniere Energy’s Sabine Pass terminal on the Texas-Louisiana border to Mexico last month, is indexed to oil in most long-term contracts.

LMPs down, Capacity Prices up

The fall in electricity prices was in sharp contrast to 2014, when prices rose across the country, in part due to the severe winter in the Northeast and Midwest.

While LMPs fell, capacity prices rose in PJM and ISO-NE, as the lower gas prices drove out coal-fired and nuclear generators and forced other nuclear plants to rely on capacity auctions for revenue. FERC noted that the clearing price for the Rest of RTO zone in PJM has risen 152.6% since 2013 and more than 200% in ISO-NE for the same period.

“These lower LMPs and higher capacity prices in PJM have resulted in the ‘all-in’ costs of energy, capacity, transmission and ancillary services to increase by 5% between 2013 and 2015,” FERC staff said.

“As the markets are calling for new resources, we’re seeing significant increases in the capacity markets, really stress testing the markets, and … I think ancillary services are going to get a lot more important in the future [to] balance all the interruptible resources,” Commissioner Cheryl LaFleur said.

Electricity demand fell by 1.1% in 2015 as a result of low economic growth and increased efficiency in appliances. Electricity use fell in the industrial sector, while residential and commercial customers showed little or no growth.

DER and Renewable Growth Continues

While the net generation of power plants nationwide has increased 1.2% since 2011, the total electricity sold back by net metering customers has increased by nearly 500%, FERC staff said. Demand response revenues, meanwhile, have also increased through the capacity markets in PJM and ISO-NE for the past three years, a trend FERC expects to continue as a result of the Supreme Court’s decision on Order 745, upholding FERC’s jurisdiction over DR.

Wind continues to be the dominant renewable energy resource in the U.S., rising to 4.6% of total generation. While solar rose to only 1% of total generation in the country, it makes up 13% of installed capacity in California, home to half of the country’s utility-scale solar.

March 21, 2016

FERC Declines Rehearing in Decade-Old MISO Pricing Dispute

By Amanda Durish Cook

FERC last week declined MISO’s request to reconsider a 2008 refund order stemming from transmission pricing complaints filed by the city of Holland, Mich., and DTE Energy Trading more than a decade ago (EL05-55-003, EL05-63-005).

Proceedings for the case go back to early 2005, when FERC found that MISO had violated its Tariff by charging the Holland Board of Public Works and DTE a higher hourly non-firm point-to-point transmission rate in instances when the utilities redirected the receipt point for their firm point-to-point service within the same transmission pricing zone — but on a non-firm basis. The commission ordered MISO to issue refunds with interest for the difference between the two hourly service rates. The RTO was also required to file accompanying refund reports for Holland, DTE and “other similarly situated customers,” effectively extending refund eligibility to other market participants incurring similar charges.

In May 2008, after conditionally accepting MISO’s 2005 and 2006 refund reports, FERC further ordered the grid operator to refund overcharges for ancillary services associated with customers’ redirect service.

In its rehearing request, MISO contested the ancillary services refund along with aspects of FERC’s earlier decisions. The RTO argued that FERC’s rulings had violated the Federal Power Act on two counts.

First, by directing MISO to refund the charges related to ancillary services, the commission had corrected its order outside the timeframe permitted under the FPA, namely before an appeal had been filed or in advance of the deadline for petitioning for judicial review. MISO also said FERC sought to exploit ambiguities in its refund order by rewriting the methodology associated with the refunds.

Second, FERC’s order directing MISO to issue refunds dating back to 2002 violated an FPA provision barring refunds for periods preceding a complaint filing, MISO said.

MISO further contended that any refunds should be limited to the original complainants, and that calculating and issuing refunds to all affected customers during the period in question will be “time-consuming and costly.” FERC has stipulated a refund period of February 2002 to January 2009.

In denying the rehearing, FERC reiterated that the commission has “authority to go back to the date that the violation first occurred” and its seven-year refund period was “consistent with the refunds previously provided and accepted in these proceedings.”

FERC also said that ancillary services are needed to maintain reliability for transmission service and should be priced accordingly.

“Because these ancillary services were necessary to accomplish transmission service, they are part of any transmission service, including redirect service, and should be priced consistent with the service being provided,” FERC said. “The commission’s general policy is to order refunds for overcharges and for violations of the filed rate.”

March 21, 2016

FERC: Entergy Can Exclude Above-Market PPAs from Bandwidth Calculation

By Amanda Durish Cook

FERC last week granted Entergy permission to exclude from its system-wide “bandwidth” calculation the above-market portion of the price paid for electricity under two power purchase agreements with generators certified under the Public Utility Regulatory Policies Act and Louisiana’s Renewable Energy Pilot Program (ER14-1640).

FERC, Entergy — Rain CII’s calcining Plant in Sulphur, LA *(Source: Rain CII)*

The March 17 ruling came despite a protest from the Louisiana Public Service Commission, which contended it was excluded from the settlement agreement.

The decision does not alter the actual value of Entergy Gulf States Louisiana’s PPAs with the Rain CII Carbon calcined petroleum coke facility in Sulphur and the Agrilectric rice hull-fueled power plant in Lake Charles. Rather, the commission is allowing Entergy to internally “re-price” the contracts to accommodate the “bandwidth” process the company uses to ensure that none of its subsidiaries have production costs 11% above or below the company average.

Supporters of Entergy’s position said the company’s re-pricing approach prevents the costs of local and state policy initiatives — such as renewable mandates — from being exported to other jurisdictions. However, the Louisiana PSC called the re-pricing practice “unduly discriminatory” to Entergy Gulf States Louisiana and its customers, which will incur increased costs to cover the entire above-market portion of the contract prices.

The PSC also called the settlement procedure an “abuse” because it only included parties that agreed with Entergy’s original 2014 filing.

FERC disagreed.

“We note that the settlement, and the proposed revision it approves, establishes a policy that is applicable to all similar renewable energy PPAs entered into by any of the participating Entergy operating companies,” FERC said. The commission added that Entergy entered into the PPAs “to meet the requirements of the [Renewable Energy Pilot] Program for the benefit of Entergy Gulf States Louisiana’s customers, rather than for the benefit of the Entergy system as a whole.”

March 21, 2016

FERC OKs Wisconsin Utilities’ Asset Transfer

FERC last week gave the go-ahead for American Transmission Co. and Wisconsin Power & Light to swap a combined $830,000 worth of assets (EC16-61).

ATC Substation, WP&L, FERC, MISO — ATC Substation *(Source: ATC)*

Under the agreement, WPL will acquire five ATC substations valued at $458,820 in exchange for $370,863 in transmission-related equipment, which include a power transformer, storage batteries, 138-kV line frames and foundations, poles and historical air brake switches. The Wisconsin-based companies said the move will better “align ownership of the relevant facilities by function,” providing WPL new distribution facilities while handing ATC more transmission assets, which will be turned over to the operational control of MISO.

Both companies will pay current net book value for all facilities in cash without an acquisition adjustment. ATC said the transaction will have “virtually no effect on transmission rates,” noting that the difference in value between the assets being exchanged is only a “tiny fraction” of the company’s total net utility plant of $3.4 billion. WPL receives nearly all of its transmission services from ATC.

— Amanda Durish Cook

March 21, 2016

Louisiana City Allowed RTO Tx Adder

The city of Alexandria, La., is entitled to collect a MISO-related adder of 50 basis points on top of its authorized rate of return on equity without having to make a request to federal regulators, FERC ruled last week (EL15-75).

Alexandria, Louisiana in MISO (FERC) — Alexandria, Louisiana Skyline

The commission said Alexandria’s petition to implement the RTO membership adder was unnecessary because the city was already eligible to do so under MISO’s municipal generic template, a formula municipal transmission owners can use to derive their revenue requirements. FERC last June directed the RTO to include the adder, which became effective immediately (ER15-1067).

The commission also granted Alexandria’s request to defer adder collection until after a decision on an ongoing complaint against MISO transmission owners (EL14-12). In that proceeding, MISO transmission customers argue that the current 12.38% base return on equity earned by owners should be decreased to 9.15%.

— Amanda Durish Cook

March 14, 2016

FERC Upholds MISO Cancellation of GIA

By Amanda Durish Cook

FERC has accepted MISO’s request to terminate a generator interconnection agreement (GIA) with EDF Renewable Energy’s 150-MW Merricourt wind project in North Dakota, eliminating the prospect the facility would be granted additional time in the interconnection queue before completing construction.

FERC said MISO’s interconnection policy is clear in denying such extensions unless a project’s development has been hindered by another project in the queue.

“No such circumstances are presented here, and, even if such circumstances were present, Merricourt could not extend its [commercial operation date more than] three years beyond the original COD,” the commission wrote (ER16-471).

Commissioner Cheryl LaFleur was the sole dissenter in the 3-1 ruling, citing worries that the decision could create barriers for other wind projects.

MISO revoked Merricourt’s GIA after the facility failed to meet a Dec. 1 deadline to begin commercial operations, despite a request to extend the term until Sept. 30, 2017. Merricourt maintained the project was eligible for such treatment because it had completed a significant amount of construction and was close to securing a long-term power purchase agreement. Development hit a snag in 2011 when Xcel Energy withdrew its PPA for the project, but Merricourt said it could bring the wind farm online by the end of this year.

FERC’s ruling pivoted on a narrow reading of the text within MISO’s GIA with Merricourt, particularly a provision permitting the developer to extend the in-service date after demonstrating “significant steps to maintain or restore operational readiness.” The commission ultimately agreed with MISO’s interpretation that the language only applies to a facility that has already begun — and then ceased — operating.

FERC added that keeping the wind project active could be unfair to other projects in the queue.

In her dissent, LaFleur focused instead on Merricourt’s progress with the project, which she said was so advanced that it would not cause harm to other project developers.

“In my view, our precedent provides the commission with clear authority to determine whether a COD extension is appropriate in a given case,” LaFleur wrote. “Here, I believe that Merricourt has both demonstrated meaningful progress towards reaching commercial operation in a reasonable timeframe … and effectively rebutted concerns expressed by MISO that the Merricourt project is speculative and potentially harmful to other customers in the queue.”

MISO has said that Merricourt is free to continue work on the project, which has so far cost about $20 million according to the developer. That will require it to re-enter the queue and obtain a new GIA.

March 14, 2016

Cost Estimate of PSEG Portion of Artificial Island Fix Doubles to $272M

By Suzanne Herel

VALLEY FORGE, Pa. — The estimated cost for Public Service Electric & Gas’ portion of the Artificial Island stability fix has nearly doubled, from $137 million to $272 million, PJM told the Transmission Expansion Advisory Committee on Thursday.

“We certainly were surprised when we first saw the numbers,” Steve Herling, PJM vice president of planning, told RTO Insider. “In retrospect, we wish we’d had more foresight. We’re going to have to take a real hard look at what this tells us about our process going forward. We don’t like making an estimate that’s this far off.”

PJM stands by its selection of the project, which involves building a new 230-kV transmission line from the nuclear complex in New Jersey to Delaware.

“Based on what we have seen so far, we still believe we have the right project,” Herling said. “There are elements of the design that we continue to discuss, and we’re looking for opportunities to further optimize it and mitigate costs, but at this point we still believe we have the right project.”

LS Power was chosen to build the line, with PSE&G and Pepco Holdings Inc. assigned to construct the necessary connection facilities. LS Power won the deal in large part because it committed to limiting construction costs to $146 million. (See PJM Staff Picks LS Power for Artificial Island Stability Fix; Dominion Loses Out.)

“LS Power’s cost cap commitment has not changed, and LS Power continues to focus on successful development of its portion of the Artificial Island project,” company Vice President Sharon Segner said.

Paul McGlynn, PJM general manager of system planning, said the cost allocation of the project would remain the same, with the bulk of the price tag being designated to customers on the Delmarva Peninsula.

After Delaware and Maryland regulators and consumer advocates complained about the seemingly disproportionate cost assignment, FERC suspended PJM’s Tariff changes involving the project’s cost allocation pending additional review (EL15-95).

At a Jan. 12 technical conference ordered by the commission, stakeholders debated cost allocation based on the solution-based distribution factor (DFAX) method. (See related story, Commenters: DFAX Cost Allocation Inappropriate for Some Projects.)

So, how did PJM planners miss the mark so widely?

Herling said the Artificial Island project is unique and there was little to compare it to.

“This is the first time we’ve had to deal with so much work inside of a nuclear station,” he said. “We did our best to add substantial adders … but in some areas they weren’t big enough,” he said. “I don’t know how PJM could have done better with that other than doing more extensive detail design work,” which would be expensive and time-consuming, he said. “We will be talking about that, as far as how to do things differently moving forward.”

The Board of Managers, which approved the Artificial Island project, reviews cost increases but does not need to approve them unless the scope of the project is altered, Herling said.

“We review all significant changes with the board. They will ask us questions. They will ask us to get more information. They may suggest alternatives that we should be looking at. At the end of the day, we will do everything they ask us to do, and hopefully they will be satisfied with the information.” But, Herling said, “If the project continues in the [Regional Transmission Expansion Plan], the board does not have to approve revised costs.”

The board could decide to switch to another project, but that’s not likely, Herling said.

PSE&G’s portion of the project consists of three main elements: installing a static VAR compensator (SVC) at the New Freedom substation; putting in optical ground wire (OPGW) for high-speed relaying; and expanding the Salem substation. Herling noted that the SVC and OPGW work were common to all proposals and that any vendor likely would have run into the same cost issues.

The SVC work, which PJM estimated at $38 million, is expected to cost $43 million more, according to PSE&G, in part because of additional site work including wetland mitigation, storm water management and the relocation of a helicopter pad and several buildings. PSE&G also ran into higher vendor cost estimates, McGlynn said.

Additional site work for the OPGW installation increased PJM’s estimate of $25 million by $14 million.

The Salem expansion, estimated at $74 million, will cost an additional $78 million, in part because of the cost differential for security and access requirements needed to work in a nuclear facility.

“We understood that working in Salem would be more challenging than working at a 500-kV substation in the middle of a cornfield someplace,” McGlynn said. “What we’re trying to look at and consider and get a better understanding of is the difference in cost.”

A number of committee members were incredulous.

“Percentage-wise, this is a big miss as far as what we thought we were looking at,” said Dave Mabry, representing the PJM Industrial Customer Coalition, noting that there are no cost commitments involved in the PSE&G work, all of which is considered an upgrade as opposed to a greenfield project.

“We were at $250 million … now we’re up to $350 million,” Mabry said. “The concern here is, is there another shoe that’s going to drop?”

March 14, 2016

EBA 2016 Midwest Chapter Annual Meeting

INDIANAPOLIS — The Clean Power Plan, Order 1000, FERC enforcement and distributed generation were favorite topics at last week’s annual meeting of the Energy Bar Association’s Midwest chapter. Here’s a sampling of what we heard.

Energy Bar Association, Commissioner Colette Honorable, FERC — Honorable *© RTO Insider*

“Let’s not talk about how the stay will halt work” on the Clean Power Plan, FERC Commissioner Colette Honorable said. “The industry was moving toward a more renewable future long before the Clean Power Plan came along. Let’s continue our work regardless of the stay. It’s a stay. It’s not a decision on the ultimate merits of the plan.”

Honorable also asked the Energy Bar Association for feedback on whether Order 1000 could be improved. “I know it’s not perfect. … We know that the sticky part is interregional planning. I want Order 1000 to aid in the development of these very important interregional projects and not be a barrier.”

Steve Allen, IURC — Allen *© RTO Insider*

Steve Allen, pipeline safety director at the Indiana Utility Regulatory Commission, commented on the trend of electric utilities acquiring gas businesses to feed their gas turbines. “You can have a good safety culture without having a good pipeline safety management system in place, but you can’t have a good pipeline safety management system without a good safety culture.”

John Tsoukalis The Brattle Group — Tsoukalis *© RTO Insider*

John Tsoukalis, an associate with The Brattle Group, said if FERC prohibits virtual trades at nodes with financial transmission rights in order to stop participants from taking losses on virtuals to increase the value of their FTRs, it would also end legitimate trading and harm the market. “FERC is growing aggressive on how they [prove intent],” he said. “But that’s still a question: How heavily does intent versus economic evidence weigh in FERC’s investigation?”

John Parsons, MIT Sloan School of Management — Parsons *© RTO Insider*

John Parsons, of the MIT Sloan School of Management, discussed the bidding strategy that landed J.P. Morgan in FERC’s crosshairs for market manipulation in California and Michigan in 2013. “From 10 to 11 p.m., their bid price was negative $30/MWh; from 1 to 2 a.m., their bid price was $999/MWh. What they were trying to do was exploit a seam in the algorithm. [The unit] got paid $999/MWh for the two to three hours it took to ramp down,” he said.

Jim Cater, director of economic and financial policy for the American Public Power Association, questioned the appeal of customer-owned distributed energy resources such as rooftop solar. “There’s a notion that somehow there’s a customer groundswell of this, but I don’t know that many people who are involved with this at home,” he said. “I don’t want to be perceived as a naysayer … but this has got momentum behind it that could benefit from a bit of cost-benefit analysis.”

Donna Attanasio, GWU Law School — Attanasio *© RTO Insider*

Donna M. Attanasio, senior advisor for energy law programs at George Washington University Law School, talked about the genesis of the e21 Initiative, which the university launched in 2014 along with the Great Plains Institute, Xcel Energy and others to plot a new regulatory model in Minnesota. “Customers want green power; they want more flexibility. If the utilities aren’t going to provide these, customers are going out and getting it themselves. This is where the e21 Initiative started.”

Stacy Stotts, Stinson Leonard Street — Stotts *© RTO Insider*

Stacy Stotts, a partner and member of the environmental and natural resources division at Stinson Leonard Street, commented on the Supreme Court’s stay of the Clean Power Plan. “To say the stay is unprecedented is an understatement. The biggest argument [against the CPP] is that utilities are already regulated under the Clean Air Act. If this argument prevails, the rule is gone, it’s going to be vacated … I think that’s a strong argument. Now, what if the rule is vacated? An important thing to remember is the EPA [still] has to regulate emissions — the Supreme Court told them to in Massachusetts v. EPA.”

Stotts also predicted President Obama’s effort to win Senate approval of a replacement for Justice Antonin Scalia “will be a brutal appointment process.”

– Amanda Durish Cook

March 14, 2016

Company Briefs

Duke Energy has appealed a $6.8 million fine levied by North Carolina for the catastrophic Dan River coal ash spill, calling the penalty “entirely arbitrary and capricious.”

The company said the state Department of Environmental Quality raised the fine “to a newsworthy amount” after the Dan River spill attracted media attention. The appeal alleged the state improperly used admissions the company made in a federal action that resulted in $102 million in fines. And it said the punishment violates precedents that established DEQ cannot penalize a party multiple times for a single violation.

Frank Holleman, an attorney with the Southern Environmental Law Center, scoffed at Duke’s appeal. “Since Duke committed crimes that led to the Dan River spill and Duke caused such harm to the state and its citizens, you would think Duke would have the humility to pay a relatively modest fine and ask forgiveness from the people of the state,” he said.

More: Charlotte Business Journal

Whole Foods Inks Solar Deal with NRG, SolarCity

nrg Whole Foods Market Inc. has announced separate deals with NRG Energy and SolarCity to install solar systems on the roofs of many of its U.S. stores. The grocery store chain, known for selling natural foods and products, already has solar installations on 25 of its stores. With the new deals, 100 more stores will get solar panels installed.

More: The Wall Street Journal (subscription required)

Lack of NY Timbering Permits Forces Constitution Delay

The developers of the proposed Constitution Pipeline delayed the completion date of the 124-mile natural gas pipeline for six months after New York state regulators failed to approve permits in time for it to clear trees before the migratory bird season commences.

The pipeline developer, Williams Co., notified FERC that the New York Department of Environmental Conservation had not issued the permits in time for the project to comply with U.S. Fish and Wildlife Service recommendations to complete tree cutting by March 31 to mitigate impacts on migratory birds and the northern long-eared bat. Constitution said it is pushing back the completion date of the $750 million pipeline from the end of 2016 to the second half of 2017.

The pipeline, which received FERC approval in December, would deliver 650,000 dekatherms of Marcellus Shale natural gas to the Iroquois Gas Transmission and Tennessee Gas Pipeline systems, which serve New England.

More: Times Union

Michigan Speedway Wins $29K Incentive from Consumers Energy

Consumers Energy has given the Michigan International Speedway a $29,460 energy efficiency incentive check to use toward the racetrack’s efforts to become the “greenest” NASCAR track in the country.

The utility’s incentive comes after the racetrack transitioned to LED lighting in its pedestrian tunnel and outside its administration building last year. The racetrack also installed a system to automatically control the temperature in the air conditioning system of its infield suites based on occupancy settings. The speedway said it saves an annual $60,835 in natural gas, electricity and maintenance bills through energy efficiency efforts.

Garrick Rochow, Consumers Energy’s vice president and chief customer officer, said the speedway’s projects achieve the same carbon-reduction effect as planting 796 trees each year.

More: Energy Manager Today

Great River Energy Lobbyist Retires After 34 Years

Great River Energy lobbyist Bob Ambrose has announced his retirement after 34 years of service to the Minnesota company.

“Bob has always represented us effectively with grace and dignity, and we are grateful for his 34 years of service. We will miss him,” said Great River Energy vice president and general counsel Eric Olsen.

Ambrose, a Brown University graduate, briefly pursued medical and social work degrees and taught at a public school before becoming involved in energy policy. More recently, Ambrose had been taking trips to Germany to study renewable energy, a topic he thinks should gain more traction stateside.

More: Midwest Energy News

ATC: Sales to Illinois Drive Need For New High-Voltage Line

Just two years after it opened a 345-kV transmission line in the same area, American Transmission Co. proposed a new line near the Illinois-Wisconsin border to serve higher-than-expected forecasted power demand.

ATC is trying to sell ratepayers and regulators on a $52 million to $63 million line that would run from a new substation in Wadsworth, Ill., to the nearby transmission system owned by Commonwealth Edison. ATC says it will file applications with Illinois and Wisconsin regulators this year.

The need for more transmission persists even after a $36 million line was put into service in late 2013. “Market conditions have continued to change in Wisconsin and Illinois, leading to unanticipated congestion in the Wisconsin-Illinois electrical interface,” said Luella Dooley-Menet, an ATC spokeswoman. “This project is needed to resolve that.”

More: Milwaukee Journal Sentinel

Developers Break Ground on Carbon-Sequestration Gas Plant

Construction has begun on a 25-MW natural gas-fired plant near Houston that will sequester its carbon dioxide emissions for use in industrial purposes or enhanced oil recovery.

The zero-emission pilot project is being developed by Net Power, a collaboration between Exelon, CB&I and 8 Rivers Capital. Exelon and CB&I are leading the funding for the $140 million project.

If successful, the developers plan to build larger, 295-MW power plants that would represent the next generation of cleaner-burning natural gas plants. The pilot project is expected to come online in 2017.

More: FuelFix Blog

Bloomberg Sources Say Westar Exploring Sale

Westar Energy is said to be in the early stages of exploring strategic options that could lead to a sale. According to Bloomberg News sources, the company is talking with potential financial advisers as it evaluates its options.

Several possible buyers have been contacted to gauge interest in Westar, one source said. Westar hasn’t yet formally hired an adviser and may still decide to remain independent, according to the sources.

A Westar spokeswoman said the company doesn’t comment on merger and acquisition activity. Westar CEO Mark Ruelle fanned takeover speculation in November when he indicated the company would be open to a sale.

More: Bloomberg News

Cleco Seeks LPSC Rehearing On Investors’ Purchase Bid

Cleco has asked Louisiana state regulators to revisit their decision to reject a coalition of Australian and Canadian investors’ purchase of the utility for $4.9 billion.

The five-member Public Service Commission said representatives of Cleco, Macquarie Infrastructure and Real Assets have contacted them about reconsidering the PSC’s Feb. 24 decision rejecting the sale.

The $4.9 billion deal would have given Cleco shareholders a 15% premium. The new company would be privately held.

More: The Advocate

PNM Proposing $87M Program To Install Smart Meters

Public Service Company of New Mexico filed a request last month with the New Mexico Public Regulation Commission to install advanced meters for its 500,000 customers. The $87 million proposal could eventually lead to the layoffs of 125 employees and a customer charge of about $5 a year starting in 2020.

The wireless advanced meters would be cost-effective and provide significant benefits for customers, including eventual savings on electric bills, PNM said. The utility contends the smart meters will save customers nearly $81 million over 20 years.

PNM asked the commission to approve the proposal in nine months so it can begin testing.

More: Albuquerque Journal

Arch Coal Abandons Plans For Controversial Montana Mine

Arch Coal, which filed for bankruptcy protection two months ago, announced it has halted plans to open a new surface coal mine in the grasslands of southeastern Montana, blaming “capital constraints, near-term weakness in coal markets and an extended and uncertain permitting outlook.”

The proposed Otter Creek mine would have been in the Powder River Basin, home to some of the most productive coal mines in the country. Although many people in the region supported the proposal, the plans have also drawn strong opposition from environmental groups, ranchers and some Native American tribes, including the Northern Cheyenne, whose reservation is nearby.

More: Los Angeles Times

FirstEnergy Coal Plant Idled For First Time in 17 Years

FirstEnergy said it idled the 2,500-MW Bruce Mansfield coal plant in Shippingport, Pa., last month because of sustained low energy prices. The last time all three units at the site were shut off was in 1999.

No restart date is planned, and no FirstEnergy workers have been laid off.

More: Pittsburgh Post-Gazette

Dominion Forges Ahead with Plans to Close Ash Ponds

Dominion Virginia Power is preparing to close its 11 coal ash ponds and discharge the treated wastewater into state rivers, despite pressure from environmental activists.

The millions of gallons of water set to flow into the James River — which was used to saturate the coal ash to keep it from becoming airborne — will be cleaner than the state requires, the company said.

The wastewater will be tested three times a week, with the results posted on the utility’s website. Any failed test will require Dominion to stop releasing water.

More: Richmond Times-Dispatch

Dan Eggers Moves to Exelon As SVP of Investor Relations

Former Credit Suisse managing director Daniel L. Eggers has joined Exelon as senior vice president of investor relations. Eggers also will be part of the company’s executive committee.

Eggers spent 18 years at Credit Suisse, where he was in the equity research department, and also served as co-head of U.S. energy research. He also had positions with the bank covering oilfield service and equipment sectors, and as an associate on the integrated oils and independent refiners group.

“Dan brings a distinguished track record of covering the power sector for a top investment bank,” said Jack Thayer, Exelon’s senior executive vice president and CFO. “His expertise in the electric utilities industry, as well as his long-standing relationships in the financial arena, will strengthen Exelon’s investor relations program and provide valuable insights for our senior management team.”

More: Exelon

Wisconsin Wind Tower Firm Gets $28 Million Order

Wisconsin-based Broadwind Energy announced it closed an order from an unnamed domestic turbine manufacturer to build $28 million worth of steel turbine towers.

Broadwind has built more than 2,000 turbine towers since 2008. The latest order should fill out its 2016 manufacturing capacity. The company’s interim CEO, Stephanie Kushner, said the extension of the federal production tax credit would bring stability to an industry that has seen fitful starts and stops.

“It caused developers to start and stop commercial activities based not on underlying project economics, but based on legislation toggling back and forth from full speed ahead to a dead stop,” she said. “And those of us in the supply chain were whipsawed even more, with capacity demand shifting from maximum to idle and back again and with little good planning certainty.”

More: Milwaukee Journal Sentinel

March 14, 2016

MISO Touts $2.6 Billion in Member Benefits

By Amanda Durish Cook

CARMEL, Ind. — MISO provided members about $2.6 billion in economic benefits during 2015, compared with membership costs of $267 million, according to the RTO’s most recent “value proposition” study.

The benefit figure represents an average of MISO’s estimated $2.1 billion to $3.1 billion in member savings last year, which is in line with the range for 2014. MISO estimates it has generated $14.5 billion in cumulative net benefits for market participants since it began calculating the financial impact of its services in 2007. (See Year 1 Judged a Success for MISO South; Gains Limited by SPP Dispute.)

The study examined RTO services such as improving coordination with neighboring systems and helping members assess the impact of environmental regulations. Benefits are assessed across nine subject areas, which include reliability, market commitment and dispatch, wind integration, compliance efforts and generation investment deferral. MISO excludes hard-to-quantify benefits like seams management and does not calculate individual member savings.

Other highlights of the report:

The diversity of MISO’s 15-state footprint helped delay generation investments through capacity sharing across zones with different peak seasons, resulting in savings of $1.6 billion. The South region alone saved between $559 million and $753 million.
Improved unit commitment through five-minute dispatch saved members $147 million, while broader sharing of regulation and spinning reserves — along with the centralization of FERC, NERC and North American Energy Standards Board compliance responsibilities — yielded an additional $208 million.
Reliability and demand response technology improvements saved an average of $181 million and $112 million, respectively.
Wind integration efforts in the North and Central regions produced 787 MW of additional wind generation, translating into savings of $347 million. MISO credits its regional planning for resulting in more economical placement of wind resources. MISO also said improvements in generator availability incentives in those regions delayed the need for 1,694 MW of new capacity construction, saving market participants between $213 million and $263 million.

“By centrally managing the transmission system as a large region, MISO is able to deliver reliable service and provide billions in economic value,” MISO CEO John Bear said in a press release.