FERC last week approved a revised generation interconnection agreement proposed by MISO to link the Hoopeston wind project in rural Illinois to Ameren’s transmission.
Hoopeston’s first turbine in 2014 (Source: Hoopeston Wind)
FERC accepted MISO’s option A GIA, which proposed a 12.28% fixed charge rate on network upgrades, and rejected option B, which proposed a 12.82% rate. The restated GIA bears an Aug. 15, 2013, effective date.
The order (ER13-2157) approved in part MISO’s December 2014 compliance filing and denied Ameren’s October 2014 rehearing request.
Apex Clean Energy’s Hoopeston Wind consists of 49 wind turbines spread across east-central Illinois farmland. The wind company disputed Ameren’s proposed cost recovery for network upgrades, which stipulated that upgrade costs be subject to participant funding only if an interconnection customer offers up-front funding for the work.
MISO presented the two GIA options in response to an order directing the RTO to revise the restated Hoopeston GIA “so that the self-fund option does not include the recovery of costs other than the return of and on the capital costs of the network upgrades.”
FERC last week granted Entergy permission to use a one-time load adjustment in the transfer of transmission facilities in New Orleans’ 15th Ward, Algiers, from Entergy Louisiana to Entergy New Orleans.
The order (ER15-1922) grants a limited waiver to include an estimate for the Algiers load in the historical Entergy New Orleans calculation and subsequent removal from the Entergy Louisiana calculation to avoid discrepancies. Without the waiver, the transfer would require a responsibility ratio calculation and a phase-in period that would occur over a year, the company said. Responsibility ratios, used to allocate costs in the Entergy intra-system bill, are calculated as a rolling 12-month average.
Algiers, New Orleans 15th ward, is the only part of the city on the west bank of the Mississippi River.
Entergy said the Algiers asset transfer required immediate, not gradual, cost allocation and asked for a “one-time reset of the Entergy New Orleans and Entergy Louisiana responsibility ratios to complete the Algiers asset transfer.”
Entergy sought the asset transfer in December 2014 because Entergy Louisiana had been subject to retail jurisdiction of the New Orleans City Council in addition to the Louisiana Public Service Commission. Entergy Louisiana serviced Algiers as well as customers outside the city. Entergy New Orleans delivered electricity to all of the city except Algiers.
In April 2015, FERC approved the transfer, and in September, approximately 8.3 miles of 115-kV and 230-kV transmission lines and two transmission substations were passed to Entergy New Orleans, ending Entergy Louisiana’s dual jurisdictions. As a result, 1.84% of the capacity from Entergy Louisiana’s existing generation portfolio moved to Entergy New Orleans.
The commission determined that the historical load estimate Entergy developed was thorough, relying on “load research sample interval data, sample and total class billing kilowatt-hours, sample strata weighting factors and monthly Entergy system peak demand times.”
NiSource earned $64.4 million ($0.20/share) from continuing operations in the fourth quarter of 2015, below the $79.5 million ($0.25/share) reported for the last three months of 2014. NiSource’s full-year earnings totaled $198.6 million ($0.63/share), compared with $256.2 million ($0.81/share) during 2014.
The company split from Columbia Pipeline Group through a distribution of its stock to its shareholders during the third quarter of 2015.
“Now in our first full year as a pure utility company, we’re deeply committed to leadership in safety and service to our customers and communities as core drivers of sustained and growing value,” CEO Joseph Hamrock told shareholders.
The Merrillville, Ind., company invested a record $1.37 billion in 2015 in its gas and electric utilities in the seven states it serves. NiSource pledged to spend another $1.4 billion on system upgrades in 2016. Hamrock said NiSource replaced 361 miles of pipeline in 2015 and continued or began modernization programs at its subsidiaries in Virginia, Massachusetts and Ohio. The company also installed automated meter reading devices for 4 million customers.
NiSource pointed to successful rate settlements last year in Massachusetts, Pennsylvania and Virginia, along with the Indiana Utility Regulatory Commission’s approval of a settlement between , its large industrial customers and the Indiana Office of Utility Consumer Counselor over NIPSCO’s seven-year electric infrastructure modernization plan. Under the settlement, NIPSCO had to refund just under $1 million. The company refiled the plan request, asking for $1.33 billion and rate hikes over the next seven years to improve its infrastructure.
In a separate case, NIPSCO is seeking the IURC’s approval to increase monthly residential charge from $11 to $20. NiSource said the increase would “update rates to reflect the current costs of generating and distributing power, plus ongoing investments which are delivering substantial benefits to customers, including programs that have reduced the duration of power outages by 40%.”
DTE Energy and Wisconsin Power and Light are looking for buyers of their closed power plants near Cassville in southwest Wisconsin.
DTE Energy is selling its Stoneman biomass plant, which closed in November, while WPL is listening to proposals for its shuttered coal-fired Nelson Dewey Generating Station, which closed at the end of 2015. The closures eliminated about 85 jobs in the area.
A DTE spokesperson said the company plans to demolish Stoneman in 2017. A local commerce group wants the WPL plant, located on 130 acres of Mississippi River waterfront, developed into a port facility. WPL’s parent company, Alliant Energy, has hired a consulting firm to come up with a marketing plan for future uses. The site will require environmental cleanup before it is redeveloped.
Talen Energy has sold the 399-MW C.P. Crane power plant in Maryland to an affiliate of investment firm Avenue Capital Group. Terms of the sale were not released.
The coal-fired plant, near Baltimore, is the second plant sold by Talen recently to satisfy a FERC-mandated plan to mitigate the market effects of the company’s creation from PPL and Riverstone Holdings last year.
Talen says it plans to sell two Pennsylvania hydro plants before the end of the first quarter to satisfy the FERC divestiture requirements: Holtwood, on the Susquehanna River in Lancaster County, and Lake Wallenpaupack in Wayne County.
Hawaiian Electric Cancels Contracts with Troubled SunEdison
SunEdison, once a high-flying solar developer, absorbed another blow when Hawaiian Electric canceled a contract to purchase 148 MW of output because of construction delays.
In a regulatory filing about the contract cancellation, Hawaiian cited SunEdison’s “apparently precarious financial condition” as a cause for numerous missed deadlines. The company’s stock has fallen 92% in the past year.
“SunEdison missed multiple deadlines throughout the process, did not provide adequate assurances that it could secure financing to develop these projects and did not propose viable options to address the significant risks to our customers of not securing lower cost renewable energy,” a Hawaiian Electric spokesman said.
Duke Energy’s nuclear fleet ran at 94.2% of capacity last year, the company reported, noting that its Oconee Nuclear Station in South Carolina turned in a 98% capacity factor for 2015. The national average for 2015 was 91.2%.
Duke, like Exelon, continues to tout nuclear generation as a carbon-free power source, an important consideration as federal emissions mandates get stiffer. In addition to having plans to build the new, $12 billion Lee Nuclear Station in Gaffney, S.C., Duke intends to seek license extensions ranging from 20 to 40 years for its other plants.
Duke operates 11 nuclear generating stations. Its fleet has operated at better than 90% capacity for 17 consecutive years.
Oncor Bidders Defend Their Plan from Critics Who Fear a Windfall
The group trying to buy Oncor said its plan to restructure Texas’ largest utility could save electricity customers hundreds of millions of dollars, but critics of the plan say it doesn’t take into account a tax-related windfall that could send $250 million a year to the buyers.
Dallas billionaire Ray L. Hunt leads the group that is seeking to buy Oncor and help take it out of bankruptcy. The group filed a detailed response to the Public Utility Commission of Texas on Feb. 19 that addresses objections raised by several parties, including PUCT staff, former Gov. Rick Perry, the current Oncor chief executive and AARP.
The commission is expected to indicate whether it will approve the Hunt group’s plan at its March 3 meeting. The group wants to put up $18 billion for the business and split it into two new companies.
Sierra Club Files Suit Against 3 Companies over Earthquakes
The Sierra Club filed suit in U.S. District Court against three oil and gas exploration companies, charging that their wastewater disposal in deep injection wells is triggering earthquakes in Oklahoma and Kansas. The suit names Chesapeake Energy, New Dominion and Devon Energy for contributing to a staggering increase of seismic activity.
The suit says the companies “contributed and continue to contribute to the increased seismicity triggered by the waste handling, transport and disposal activities at the injection wells owned or operated by the defendants throughout the state of Oklahoma and southern Kansas.”
The suit asks a judge to curtail the number of gallons of drilling waste being injected into deep rock layers and that the companies pay to protect buildings from earthquake damage. “The oil industry is on its knees, the business models are busted,” said Bloomberg Intelligence Analyst Peter Pulikkan. “And now you have this threat of disposal wells being linked to earthquakes that could put companies with material exposure permanently out to pasture.”
FirstEnergy last week reported fourth-quarter operating earnings of $0.58/share, compared with $0.80/share for the same period in 2014, citing greater planned operating expenses, higher tax rates and lower distribution deliveries.
Those factors were tempered by increased transmission revenue, a greater commodity margin for its competitive business and resolved rate cases in West Virginia, New Jersey and Pennsylvania, the company said.
“This year, we will continue to focus on regulated growth through our Energizing the Future transmission initiative, while strengthening our utilities business and managing risk across the company,” CEO Charles Jones said. “We also look forward to resolving our Ohio Electric Security Plan, which will shape our longer-term strategic outlook.”
On a non-adjusted basis, the Akron, Ohio, company reported a net loss for the quarter of $226 million ($0.53/share) on revenue of $3.5 billion, compared with a net loss of $306 million ($0.73/share) on equal revenue for the same quarter in 2014.
Operating earnings for the full year were $2.71/share, compared with $2.56/share for 2014.
Jones provided first-quarter 2016 guidance of 75 to 85 cents/share. He said in a call with analysts that he would not provide guidance for the full year until the Public Utilities Commission of Ohio rules on a proposed power purchase agreement proposal designed to shore up FirstEnergy’s Davis-Besse Nuclear Power Station and the Sammis Plant. He expects a decision in March. (See Next up in Ohio PPA Battle: Dynegy Weighs in.)
Peppered with questions from analysts regarding the potential effects on the company if PUCO denies the agreement, Jones and Chief Legal Officer Leila Vespoli said they were optimistic and declined to prognosticate.
“What I’ve said is we will deal with that outcome when we have it, and we will communicate at that time what our earnings guidance for 2016 is, what our future growth plans for the utilities are, what our future equity needs might be, if anything, to support that growth.” Jones said. “I’ve consistently said I think that generation, transmission and distribution are all critical assets in terms of serving customers, and right now I don’t see any strategic change there for us.”
Opponent of the plan have asked FERC to weigh in, and Vespoli said she expects the commission to do so before PJM’s Base Residual Auction in May.
FERC last week approved a separate initiative in which FirstEnergy plans to spin off the transmission assets of Jersey Central Power & Light, Metropolitan Edison and Pennsylvania Electric into a new subsidiary. (See FERC OKs FirstEnergy’s Tx Spin-off; N.J., Pa. Approval Still Needed.) The deal also needs the approval of regulators in Pennsylvania and New Jersey, which Jones said he expects by mid-year.
Fourth-quarter profits of $99.6 million ($0.56/share) weren’t enough to offset Energy’s losses for the year, the company reported last week.
Entergy lost $176.6 million (-$0.99/share) in 2015, compared to $940.7 million in earnings in 2014. Much of the loss was driven by its wholesale electricity business, Entergy Wholesale Commodities (EWC), which experienced a 46% drop in operational earnings.
Entergy CEO Leo Denault noted that the company’s results are “reflecting the changes in strategic direction for the EWC business.” Those changes included deciding to shut down the Vermont Yankee, Pilgrim and FitzPatrick nuclear stations. Vermont Yankee closed at the end of 2014, while the company announced late last year it would close the other two.
“The most significant factor was lower wholesale prices,” CFO Drew Marsh said. “The nuclear fleet revenue was $44/MWh this quarter, down from $54 in 2014, excluding Vermont Yankee. Closure of VY contributed 5 cents to the decline.”
“We took steps to reduce volatility and gain clarity on the future of the business. Closing Pilgrim and FitzPatrick was not the path we wanted to take,” Denault said. “After pursuing many alternatives, they ultimately were the only options remaining for us. We know they are tough decisions for those involved and we are committed to supporting our employees who work at these plants and their communities throughout this difficult transition.”
Denault said the company has yet to commit to a mid-year refueling at Pilgrim, which will have a large effect on future costs and generation output there, and possibly the closing date.
He also said the company is committed to building new natural gas-fired generation, including a 980-MW plant in Montz, La., as well as the purchase of the Union Power Station, a 1,980-MW near El Dorado, Ark.
Ameren last week reported fourth-quarter earnings of $29 million ($0.12/share), down from $48 million ($0.20/share) in the same period of 2014. Ameren’s 2015 net income totaled $630 million ($2.59/share) compared with 2014’s $586 million ($2.40/share).
Operating revenues for the fourth quarter came to about $1.3 billion, compared with almost $1.4 billion in the same period a year earlier. For the full year, operating revenues were up about $45 million to $6 billion.
The St. Louis-based utility said earnings fell in the quarter because of mild winter temperatures, which lowered retail electric and natural gas sales. The earnings drop was partially offset by the company’s large investments in electric transmission and delivery, Ameren said. Earnings were also helped by the 18-month staggering of nuclear refueling and maintenance outages at the Callaway Energy Center, which kept the center running through 2015, the company said.
“We delivered strong earnings growth in 2015,” Ameren CEO Warner Baxter said in a statement. “Despite some challenges, including very mild fourth-quarter weather, we were able to achieve this growth through the continued execution of our strategy, which includes allocating capital to jurisdictions with modern, constructive regulatory frameworks and managing costs in a disciplined manner.”
In 2016, Baxter said, the company would work with key stakeholders to “modernize Missouri’s regulatory framework to better support investment in that state’s aging energy infrastructure for the long-term benefit of our customers and the state of Missouri.”
Ameren offered a less sunny outlook for 2016 diluted earnings per share, projecting between $2.40 and $2.60, and the company cautioned that decreased sales to Noranda Aluminum, Ameren Missouri’s largest customer, could cut shares by 13 cents this year. Ameren is currently working with lawmakers to save the Southeast Missouri smelter from closure while it seeks near-automatic rate increases for itself. Looking beyond the year, however, Ameren expects diluted earnings per share to grow 5 to 8% annually to 2020. Earlier in February, Ameren’s board of directors declared a quarterly cash dividend of about $0.43/share.
Public Service Enterprise Group (PSEG) on Friday reported that fourth-quarter earnings dropped to $309 million ($0.60/share) from $476 million ($0.94/share) for the same period in 2014, as the company dealt with unseasonably mild weather.
Operating earnings for the period — which exclude one-time costs — rose to $255 million ($0.50/share), from $247 million ($0.49/share) the previous year.
Earnings for all of 2015 were $1.7 billion ($3.30/share), up from $1.5 billion ($2.99/share) a year earlier.
Operating earnings for the year were $1.5 billion ($2.91/share), compared with $1.4 billion ($2.76/share) in 2014.
“Our results reflect the benefits of excellent performance and robust organic growth, which offset the impact of low energy prices on earnings,” CEO Ralph Izzo said on a call with analysts.
Izzo noted that in 2015, Public Service Electric & Gas invested about $2.7 billion in enhancing the system’s resiliency and its reliability. It placed into service key transmission upgrades, including the Susquehanna-Roseland line and the Mickleton-Gloucester-Camden line.
Meanwhile, PSEG Power plans to invest $2 billion over the next three to four years to add an estimated 1,800 MW of combined cycle, gas-fired turbine capacity, he said.
“And, after clearing the most recent capacity auction in New England, Power will construct a new 485-MW combined cycle unit at its existing Bridgeport Harbor station site, giving us an enviable and growing position in both energy and capacity markets in Southwestern Connecticut,” Izzo said.
PJM’s first 2016 proposal window for reliability projects opened Feb. 16 and will close March 17.
A PJM study found Dominion’s Carson–Rogers Rd. 500-kV line will be overloaded if the Carson–Rawlings 500-kV circuit is lost.
The RTO is looking to address problems on Dominion Resources’ Carson-Rogers Rd 500-kV and Chesterfield-Messer Rd-Charles City Rd 230-kV lines and the replacement of facilities meeting the transmission owner’s local criteria for end-of-life facilities.
The violations, which were identified in the 2020 generator deliverability and common mode outage analyses, were presented at the February meeting of the Transmission Expansion Advisory Committee.
The documentation necessary to participate is password-protected. Instructions on how to register for the proposal window are posted on PJM’s website. Also posted are the problem statement and requirements.
This is the first window for which a new proposal fee will apply for upgrades and greenfield projects. There is no fee for proposed projects below $20 million. A $5,000 fee will be assessed for projects up to $100 million. Proposals with a projected cost of more than $100 million must be accompanied by a $30,000 fee.
DTE Energy and Wisconsin Power and Light are looking for buyers of their closed power plants near Cassville in southwest Wisconsin.
Talen Energy has sold the 399-MW C.P. Crane power plant in Maryland to an affiliate of investment firm Avenue Capital Group. Terms of the sale were not released.
SunEdison, once a high-flying solar developer, absorbed another blow when Hawaiian Electric canceled a contract to purchase 148 MW of output because of construction delays.
Duke Energy’s nuclear fleet ran at 94.2% of capacity last year, the company reported, noting that its Oconee Nuclear Station in South Carolina turned in a 98% capacity factor for 2015. The national average for 2015 was 91.2%.
The Sierra Club filed suit in U.S. District Court against three oil and gas exploration companies, charging that their wastewater disposal in deep injection wells is triggering earthquakes in Oklahoma and Kansas. The suit names Chesapeake Energy, New Dominion and Devon Energy for contributing to a staggering increase of seismic activity.
