LITTLE ROCK, Ark. — The SPP task force updating the RTO’s planning reserve margin requirements shared its draft report on loss-of-load expectations (LOLE) with two other working groups Oct. 28, giving them a first look at a project that has caused members concern.
More than a year in the making, the study analyzed how reducing the reserve margin would affect the RTO’s ability to maintain the number of days per year for which available generating capacity is insufficient to industry standard one-day-in-10 years (0.1 day/year) LOLE.
Or, as Capacity Margin Task Force Chairman Tom Hestermann said, the study answered the question: “How low can you go?”
SPP’s Oklahoma members have expressed concerns that the RTO already has one of the lowest planning reserve margins, at 13.6%. The task force has said that margin could be lowered to about 10%.
“A small decrease in the reserve margin may be appropriate, but a substantial decrease in what we have would be revolutionary, not evolutionary,” said Oklahoma Gas & Electric’s Philip Crussup, alluding to one of the tenets in SPP’s value proposition during the Oct. 27 Board of Directors and Members Committee meeting. “This should be approached very cautiously.”
“No one on the task force wants a capacity margin we’ll have to raise,” said Hestermann, of Sunflower Electric Power. “We hope we can come up with a requirement that will last every five years, instead of looking at it every 17 years.”
It has been that long since SPP last reviewed its planning reserve margin. But times change, as SPP’s Vice President of Engineering Lanny Nickell noted in introducing the LOLE study.
“The task force became necessary partly because of the $5.6 billion in transmission investment we’ve made since 2004,” he said. “We’ve recognized the criteria could withstand some improvement. Do we need to bring more people into the obligation to carry capacity? Can we reduce the capacity margin requirement, given the transmission increase and diversity of load?”
Among its inputs, the study used summer-peak models from the 2016 and 2017 near-term transmission planning assessments and five years of hourly load data for each of the RTO’s 16 balancing authorities. The results indicated the SPP region can maintain an LOLE of 0.1 day/year with reserve margins as low as 8.7% (see chart).
“We wanted you to see how we used the assumptions and get to a common understanding of what we did,” Nickell told the Generation and Operating Reliability working groups.
SPP staff said the LOLE study could be improved by including uncertainties such as wind variability, forced outage rates for interregional transactions and demand response.
The task force also approved for circulation to other groups its planning reserve assurance policy, an effort to address concerns that current mechanisms to ensure sufficient reserve margins are inadequate. The policy proposes penalties be timely and “economically incent” load-responsible entities (LREs) to correct planning reserve deficiencies.
The task force has already completed a white paper defining LREs to account for the fact SPP’s load-serving members do not cover all the load in the RTO’s planning coordinator footprint.
Its draft deliverability study is looking at an option to allow an LRE to meet its reserve requirements without having to obtain firm transmission service.
The task force has suggested a workshop before the January meeting of the Markets and Operations Policy Committee to share its work in more detail. It also has urged that its work be taken up by a permanent working group, as is the practice in MISO and ERCOT.
LITTLE ROCK, Ark. — The SPP Board of Directors and its Members Committee applauded the recent settlement with MISO before getting down to the sticky business of deciding how — and to whom — to distribute the settlement’s funds during its quarterly meeting Oct. 27.
Under terms of the settlement agreement filed last month over MISO’s use of SPP’s transmission grid, MISO will pay SPP and its members $9.6 million to settle all claims for compensation since 2014. NRG Energy, which had a firm-service agreement with MISO, will split an additional $3.7 million between SPP and other parties to the settlement. (See SPP, MISO Reach Deal to End Transmission Dispute.)
As the settlement’s funds are not being collected under SPP’s Tariff, the RTO will have to file revised language with FERC designating how those funds will be distributed, which could happen as soon as March 2016. SPP has said it favors revenue allocating the funds to transmission owners with benefits flowing through to SPP’s load.
Kelley
David Kelley, SPP’s director of interregional relations, said a majority of TOs involved in the settlement negotiations favor a 100% flow-based approach. He said other TOs favor a 100% load-ratio share or a 50-50 split between the flow-based approach and annual transmission revenue requirements.
Kelley said any new Tariff language will likely require revenue be credited to the benefit of all customers taking SPP transmission service “in the same manner in which point-to-point revenue is credited.”
The board voted to adopt the 100% flow-based approach, but not before Chairman Jim Eckelberger proposed creating a task force that would “come to a quick conclusion” on the appropriate Tariff language.
“That way, I think we are engaged in the stakeholder process,” Eckelberger said. “I want to ensure everyone gets a say and everyone gets a vote. I would like to settle it here and not [at FERC].”
Eckelberger’s proposal met with immediate pushback, both from those who intervened at FERC and stand to collect the settlement funds, and those who didn’t.
“Any TO could have intervened,” Westar Energy’s Kelly Harrison said. “Some who didn’t want to spend money on litigation … now that there’s money on the table, they want to have a say?”
“We thought SPP was carrying the ball,” said Golden Spread Electric Cooperative’s Mike Wise. “We didn’t realize we would be excluded from discovery once it came to getting the ball across the goal line.”
Dennis Reed, director of FERC compliance for Westar Energy and chairman of the Regional Tariff Working Group, said work on the Tariff language “has to be on a very fast track.”
“We would really need the Tariff language by mid-December, so the [distribution] policy would have to be set by mid-November,” Reed said. “Anyone who wants to participate should know this will be on a very fast track.”
“My concern is we will have spent a lot of time and a lot of resources to get back to the same place,” said Stuart Solomon, president and COO of American Electric Power’s Public Service Company of Oklahoma. “Someone wants a study, someone wants analysis, and it goes on and on … we consume a lot of resources. If this is the step we take, we would really need tight parameters on the work.”
Members debated whether to write new business practices to handle this issue in the future.
“This only applies to the settlement with MISO,” Kelley said.
A vote to create the task force failed, leaving the heavy lifting to the Tariff working group. It will take up the Tariff language during its regular monthly meetings in November and December before bringing it to the Markets and Operations Policy Committee and Board of Directors in January for approval.
LITTLE ROCK, Ark. — Arkansas’ political loss has been SPP’s gain.
When six-term Congressman Mike Ross left Washington for full-time residence in Arkansas in 2013, he quickly found a home at SPP setting up a federal-level governmental affairs organization — only to become the only viable Democratic candidate for governor, an ill-fated run that was swamped by the Republican wave last year.
Ross
Ross rejoined SPP last December as a senior vice president of government affairs and public relations, with quick results. He helped set up SPP’s first governmental affairs conference in D.C. in late September, with the RTO hosting 54 member-company representatives from nine states. They were joined by two FERC commissioners and the Environmental Protection Agency’s legal counsel, who listened to six congressman and senators discuss the Clean Power Plan’s political ramifications.
“It’s critical we work with members on educating policymakers,” Ross told RTO Insider. “I was very pleased with the participation. It was an opportunity for us to hear from our members and educate policymakers on the role of SPP and its importance to grid reliability in 14 states.”
SPP Chairman Jim Eckelberger, who was in attendance, called the event “a spectacular success.”
“Between Paul [Suskie, SPP’s general counsel and executive vice president of regulatory policy,] and Mike, we pulled in everyone we needed to hear from, with respect to where we need to go with the Clean Power Plan,” he told the Regional State Committee on Oct. 26.
“Based on the feedback we’ve received, that was our first annual conference,” said SPP CEO Nick Brown, stressing the word “annual.”
“Mike knows senators and congressmen. They responded to his request [to participate],” Brown said. “This is new for our organization. We’re out working with the folks in each of your states we never worked with before. These are new relationships we need to form and have formed.”
Brown told the RSC that Ross will be “collaborating” with and creating networking opportunities for member legislative representatives. What SPP won’t be doing is lobbying or staking out political positions.
“We’re communicating regularly with government affairs folks at our member companies, from the investor-owned utilities to the co-ops to public agencies, from Louisiana to Canada,” Ross said, “and we’ll continue to do that.”
LITTLE ROCK, Ark. — Lanny Nickell, SPP’s vice president of engineering, told the Regional State Committee on Oct. 26 that the Clean Power Plan Review Task Force has begun meeting and participating in stakeholder events with state regulatory and air-quality groups, environmental groups and legislative representatives.
Nickell said the task force, which is reviewing the final version of the Environmental Protection Agency’s Clean Power Plan, continuously stresses its talking points. They include calls for a regional-compliance approach over a state-by-state approach — “bigger the trading market, the better,” Nickell said — state plans developed in parallel with litigation; and telling audiences that SPP is “best positioned” to conduct reliability reviews of state plans.
“From a reliability perspective, we believe states that develop [implementation plans] give us the leverage to look at … reliability,” Nickell said, responding to concern about the level of SPP’s interaction with the states. “If our assessment yields reliability concerns we would share that by early 2016.”
The task force faces a Jan. 21 deadline to file comments with EPA.
RSC OKs Wind Study
The RSC unanimously approved the scope of a study considering changes to a rule barring base plan transmission funding for wind generation projects that push wind’s share of capacity above 20% of summer peak load.
The study resulted from Western Farmers Electric Cooperative’s April request for base plan transmission funding for a wind generation project that would have boosted wind to 25% of its peak load.
Although the Markets and Operations Policy Committee rejected the co-op’s request, several members called for review of the rules on base plan funding — set years ago when SPP was comprised of smaller balancing authorities and there was concern over being able to balance large swings in wind generation. (See Wind Waiver Rejected; SPP Members will Revisit Assumptions.)
The study scope was proposed by the Cost Allocation Working Group, which will return with a recommendation on whether to change, eliminate or keep the current process. The group hopes to complete its work by the end of next year.
New Allocation Process for Long-Term Congestion Rights
The RSC also approved a Tariff revision request establishing a new incremental long-term congestion rights (ILTCR) allocation process.
The revision request addresses a 2014 FERC order finding fault with SPP’s interpretation of LTCRs. The commission rejected multiple rehearing requests in July. (See FERC Rejects Rehearing on SPP Congestion Rights.)
The new process will result in awards to market participants with ILTCRs when a transmission upgrade goes into service, instead of waiting until the annual LTCR allocation. Rights awarded in the initial allocation cannot be renewed; participants with candidate ILTCRs will be eligible to nominate in the same round of the next annual LTCR allocation as load-serving entity LTCRs.
New Chair, Members for RSC
Lyons
The RSC meeting was Dana Murphy’s last as the committee’s chairperson. Murphy, an Oklahoma Corporation Commissioner in her fourth year on the committee, handed over her responsibilities to Patrick Lyons, chairman of the New Mexico Public Regulation Commission.
Murphy, always quick to thank those around her and hand out compliments, expressed gratitude to the members and SPP. “It’s stretched and grown me,” she said.
The committee also welcomed three new members as a result of the Integrated System’s incorporation into SPP: Brian Kalk (North Dakota Public Service Commission), Kristie Fiegen (South Dakota Public Utilities Commission) and Libby Jacobs (Iowa Utilities Board). With the additions, the RSC now numbers 10 members.
NYISO gave NRG Energy a green light to shut down two coal plants in western New York, saying reliability will be maintained through transmission. NYISO and National Grid were asked in the summer to perform a reliability study after NRG said it intended to close the 380-MW Huntley Generating Station and the 435-MW Dunkirk Station. (See NRG Plant Closures Could Impact Reliability in NY.)
“Based upon the expectation of the timely completion of the National Grid upgrades and that no other changes occur to the current and planned status of the New York electric system, reliability will be maintained through at least the year 2020 if Dunkirk is mothballed Jan. 1, 2016, and Huntley is retired March 1, 2016,” NYISO wrote in an Oct. 30 letter to the New York Public Service Commission (15-E-0505).
NRG said the plants were unable to compete with lower-priced natural gas generators. A legal challenge to a state subsidy negotiated for Dunkirk in its proposed repowering to natural gas created enough uncertainty to put that project on hold, NRG added.
NYISO said National Grid updated its local transmission plan to install capacitor banks at the Huntley 230-kV station by June 1, 2016. National Grid’s plan also includes possible system configuration changes and relay adjustments.
In its own letter to the PSC, National Grid said that it will complete in December three transmission system upgrades it proposed last year in the event that the Dunkirk repowering was delayed. “These projects contribute to the overall plan to operate the system reliably in the short and long term,” it wrote.
CARMEL, Ind. — MISO told stakeholders last week it is confident the RTO’s shortage pricing rules are compliant with FERC’s Sept. 17 Notice of Proposed Rulemaking (RM15-24).
The rule would trigger shortage pricing “for any dispatch interval when a shortage of energy or operating reserves occurs.”
MISO employs an operating reserve demand curve in its five-minute dispatch. Dhiman Chatterjee, senior manager of market design and delivery, told the Market Subcommittee he expects FERC’s final rule will align closely with what MISO already has in place.
“If they come back with some different opinions, it would affect us,” Chatterjee said, adding that MISO would make adjustments during the four-month compliance filing period before the final rule. Chatterjee said MISO “would potentially need more time” if FERC imposed something unexpected in their rule.
MISO will have to make changes, however, to comply with the NOPR’s requirement that organized markets settle real-time energy transactions financially at the same five-minute time interval that they use in issuing dispatch instructions. (See NOPR Requires RTOs Switch to 5-Minute Settlements.)
MISO told the committee the shift will require hardware, software and business process changes that could take until the fourth quarter of 2017 to complete.
FERC is accepting comments on the NOPR until Nov. 30. MISO is planning to submit its remarks around Nov. 18. Comments to help shape MISO’s response are due by Nov. 11.
$80 Million in SPP Invoices Voided in Settlement
Managing Assistant General Counsel Erin Murphy said SPP will cancel about $80 million in invoices sent to MISO as a result of the RTOs’ Oct. 13 settlement of their dispute over energy flows between MISO’s North and South regions.
“All of those invoices will be pulled back and considered to be null once the settlement is in place,” Murphy explained.
In an order Oct. 20, Chief Administrative Law Judge Curtis L. Wagner Jr. approved the compensation and transfer limit provisions of the settlement, to begin on Feb. 1 (ER14-1174, et al.).
“Fundamentally, the notion of sharing capacity has stayed in the agreement,” Murphy told stakeholders.
Compensation for system usage will be based on capacity factor: available system capacity divided by the maximum available system capacity (the difference between the contract path and the operational limit).
Stakeholders asked for more clarity on what equations MISO uses to determine the capacity factor. Murphy suggested a special meeting to walk through computations used in the settlement’s manuals.
Initial comments on the settlement were due Nov. 2, with MISO’s reply comments due Nov. 12.
FERC: Commission Can Operate with 3 Members
Chris Miller, of FERC’s Office of Energy Market Regulation, told the committee that the commission could drop to three members if former Commissioner Philip Moeller is not replaced and lone Republican Commissioner Tony Clark is not reappointed when his five-year term expires at the end of June.
“We can operate down to three [commissioners] without too much difficulty, so that’s not a big issue there,” he said.
Miller also discussed the potential for a federal government shutdown. “We’re funded into December as it is right now,” he said.
On Nov. 2, President Obama signed into law a budget agreement and debt limit increase, reducing the chances of a shutdown. But Obama noted that Congress still has to enact appropriations bills before the continuing resolution funding fiscal 2016 government operations expires Dec. 11.
Xcel Energy has launched North Dakota’s first Federal Aviation Administration-sanctioned utility flight of an unmanned aircraft. The drone, which measures about 4.5 feet in length, resembles a small helicopter and is being used to inspect a 7-mile section of a transmission line as part of an FAA pilot project.
The aircraft Xcel is using is a Pulse Aerospace Vapor 35, a 35-pound drone with about a 5-mile, one-hour range while transmitting images and data to a ground station. The 230-kV line runs from Xcel’s Prairie substation in Grand Forks to the Canadian border, where it connects with Manitoba Hydro Electric Energy.
The drone technology can also be used in security flights to assess infrastructure damage and construction work.
Coal-Fired Power Plants Begin Installing Emissions Controls
Two Farmington-area power plants in northeastern New Mexico have begun installing pollution controls to comply with federal regulations intended to reduce atmospheric haze. The multimillion-dollar retrofitting projects at San Juan Generating Station and Four Corners Power Plant are to be completed by 2018.
The upgrades are intended to comply with the Environmental Protection Agency’s 1999 regional haze rule, which calls for the “best available retrofit technology” to be added to industrial facilities that emit air pollutants that cause or contribute to regional haze. EPA finalized additional portions of the rule this summer.
The pollution controls will also help the state comply with EPA’s Clean Power Plan, which aims to reduce carbon pollution from power plants to address climate change.
PPL Electric Utilities is proposing a transmission line linking the grids of northern Pennsylvania and southeastern New York to strengthen reliability in the region.
Called Project Compass, the line is expected to cost $500 million to $600 million. The first leg would be a 95-mile 345-kV line running from Lackawanna County, Pa., to Rockland County, N.Y.
The link is expected to save New York customers $200 million annually. PPL, which operates in Pennsylvania, is recommending that New York state customers pay the line’s cost.
Southern Co. has increased the estimated cost of its troubled Kemper County coal gasification power plant in Mississippi by another $159 million, the latest price boost for a project whose cost has risen from $2.8 billion initially to $6.4 billion.
Mississippi Power, a Southern subsidiary, said it will absorb about $110 million of the most recent overruns but is likely to ask the state Public Service Commission to pass on to customers the remaining $49 million. The PSC has already allowed Mississippi Power an emergency 18% rate increase after the utility said it was running out of money.
A utility spokesman said much of the most recent cost overruns are associated with the need to fix problems and go into startup mode. The plant may not go into operations until the end of next June.
Panda Power Funds said it has arranged financing for its latest Pennsylvania natural-gas fired power plant, a 1,124-MW station on the site of the retired Sunbury coal-fired station. Panda said the new Hummel Station will use gas from the nearby Marcellus Shale fields.
Panda is employing a three-on-one combustion turbine combined-cycle plant that uses Siemens turbines and generators. Bechtel will be the construction manager. The plant, which is due to be completed in 30 months, is expected to cost about $710 million.
Hummel Station is Panda’s third new natural-gas plant in Pennsylvania and its seventh in the nation.
Vermont Yankee Sirens Sounding Together for Last Time
The 37 emergency sirens tied in to the Vermont Yankee nuclear generating station emergency notification network are going to be tested all at once for the last time this weekend, a station spokesman said.
The plant is being decommissioned, and it has a request before the Nuclear Regulatory Commission to terminate its emergency planning activities in April. The sirens will still be tested individually until then.
The sirens are located in Vermont, Massachusetts and New Hampshire towns located within 10 miles of the plant.
Duke Conducting Groundwater Studies Enviros Call Flawed
Duke Energy is assessing groundwater to learn whether ash ponds at its power plants are contaminating private wells. Residents living near two Duke power plants have been advised to avoid drinking well water. Tests conducted by the company have found increased levels of vanadium and hexavalent chromium, which are suspected carcinogens.
There are no federal safety levels for those substances, however, and the state Department of Environmental Quality says the contaminants can occur in areas unrelated to coal ash impoundments, so they may not be connected to the ash dumps. “The fact that some well owners many miles from coal ash impoundments and municipal water customers are consuming water with levels at the same level, or higher, leads investigators to believe that vanadium and hexavalent chromium also occur naturally,” the state health agency wrote well owners Oct. 15.
In a letter to state authorities, the Southern Environmental Law Center said that Duke’s studies are flawed. “The assessments we’ve reviewed contain bad science and do not determine the full extent of Duke Energy’s coal ash pollution of our groundwater and drinking water sources,” it said.
Public Service Electric and Gas is nearing completion on a 13-MW solar array it is building on a closed 50-acre Superfund landfill in Burlington County, N.J.
PSE&G will own and operate the solar farm, which is scheduled to go into service near the end of this year. The facility will be the largest photovoltaic array that PSE&G has built so far under its Solar 4 All program, in which the utility is developing 125 MW of grid-connected solar power.
Cove Point Protesters Disrupt Monday Night Football
Source: We Are Cove Point
Four people were arrested at Bank of America Stadium in Charlotte, N.C., during a Monday Night Football game last week, after activists protesting Dominion Resources’ Cove Point LNG facility rappelled from an overhang in front of the press box.
The protesters, belonging to the organization We Are Cove Point, held a sign that said “BoA: Dump Dominion.” They said they were protesting Bank of America’s financing of the liquefied natural gas export facility in Lusby, Md.
The incident occurred during the third quarter of the game between the Carolina Panthers and Indianapolis Colts. Police and stadium security cleared the section of the stadium below the press box, but firefighters had to forcibly remove the protesters when they refused police orders to come down.
Dynegy announced plans Nov. 4 to close its Wood River Power Station in mid-2016. The 465-MW facility in Alton, Ill., contains two coal-fueled units, one that began operating in 1954 and the other in 1964.
Dynegy said it’s being forced to retire the 60-plus-year-old Wood River because the utility cannot turn a profit under the “poorly designed wholesale capacity market in Central and Southern Illinois that does not allow competitive generators to recover costs.”
Dynegy expects to file a formal retirement notice with MISO by Dec. 1. The RTO will determine whether the plant is needed for grid reliability. Dynegy CEO Robert C. Flexon said that if capacity auction conditions in Illinois don’t change, other generating plants in the MISO-controlled portions of the state could face similar financial obstacles.
Entergy Names Hinnenkamp COO; Will Oversee Capital Investments
Entergy announced Oct. 30 it has appointed Paul Hinnenkamp as its senior vice president and COO, effective Nov. 1. Hinnenkamp replaces the outgoing Mark Savoff and will report directly to the New Orleans-based corporation’s chairman and CEO, Leo Denault.
Hinnenkamp is responsible for executive oversight of fossil generation, transmission, system planning and capital projects-management. Denault said his assignment will be important “at a time when we are deploying significant capital resources to replace aging generation and modernize our grid for enhanced reliability.”
Earlier this year, Entergy reported the need to add approximately $3.7 billion in new generation resources consisting of six new power plants by 2020 and 635 miles of new and upgraded transmission by 2022.
Exelon is accusing the federal government of having knowledge of and approving a radiological waste dump in the 70s that is now causing concern because of an underground fire at an adjacent landfill.
In 1973, 43,000 tons of what was billed as “clean fill dirt” was dumped at West Lake Landfill on the western edge of St. Louis County; however, almost a quarter of the dirt was in fact radioactive waste from a nearby storage site owned by Colorado-based Cotter Corp.
Today, Exelon Chicago retains Cotter’s liability for the West Lake contamination, while the Department of Energy holds the liability for the Atomic Energy Commission, which records show ultimately approved the dump despite false claims by Cotter about the location.
In 1974, AEC approved the termination of Cotter’s license for the radioactive material, a move critics say should have never happened. By 1975, AEC was dissolved, with responsibilities eventually passed to the Nuclear Regulatory Commission. The former commission had long been accused of being too cozy with the nuclear industry.
Public concern about the incident has recently increased because of an underground fire burning at the adjacent Bridgeton Landfill, prompting concern that the fire will spread to West Lake and release radiation. The Environmental Protection Agency has said that the fire is not moving toward West Lake, and a plan for cleanup will be introduced in late 2016. In the meantime, Exelon has inferred that the federal government might have allowed more toxic waste into the landfill since Cotter’s dispatch over 40 years ago. A spokesperson for Exelon said more on-site testing at the landfill is needed.
A federal appeals court indicated it will not decide on challenges to the Environmental Protection Agency’s Clean Power Plan until the end of December, too late to make a statement directed at the global climate change talks scheduled for early December in Paris.
Opponents to the carbon emissions rule wanted the D.C. Circuit Court of Appeals to stay the regulations until after the United Nations summit. But the court’s most recent filing schedule allows opponents and EPA to file documents until Dec. 23. So far, 26 states and businesses and interest groups have joined in the action to stop the rule.
Global Climate Change Goals Good Start, but not Enough
A United Nations analysis of promises made by 146 countries to cut greenhouse gas emissions indicates that the proposed cuts will have a positive impact but won’t reverse climate change.
The data analysis will be examined at the U.N.’s climate change conference in Paris beginning Nov. 30. The analysis concluded that while the cuts would reduce global warming trends by almost 3 degrees Celsius over 100 years, the reduction is not enough to meet a 2-degree limit on temperature increases, a scientific consensus “limit of safety.”
NV Energy, CAISO Wait for FERC Approval to Enter EIM
NV Energy of Nevada and CAISO have delayed the utility’s entry into the ISO’s Energy Imbalance Market pending final authorization from FERC.
NV Energy would be the second utility to enter the EIM. PacifiCorp joined in 2014. Puget Sound Energy of Washington and Arizona Public Service also plan to join the market next October.
APPA’s Sue Kelly Named One of DC’s ‘Most Powerful Women’
Kelly
The Washingtonian has recognized Sue Kelly, the president and CEO of the American Public Power Association, as one of D.C.’s 100 “Most Powerful Women” in its November 2015 print issue.
Kelly took the helm of the trade organization in the spring of 2014, and the magazine said she has improved the association’s relationship with the media, lawmakers and other energy trade groups.
“This is a proud moment not just for Sue and APPA but for all of public power,” said Doug Hunter, APPA board chair and CEO of the Utah Associated Municipal Power Systems. “We appreciate how effectively Sue has raised our profile in the nation’s capital.”
FERC says that renewable energy accounted for about 60% of the new generation capacity added in the U.S. in the first three quarters of 2015.
FERC’s Energy Infrastructure Update shows wind, hydro, solar, biomass and geothermal accounted for 4,380 MW of the total 7,276 MW of installed capacity added during the first nine months of 2015. That breaks down to 2,966 MW of wind, 1,137 MW of solar, 205 MW of biomass, 45 MW of geothermal and 27 MW of hydro.
By comparison, over the same period, about 2,884 MW of natural gas generation came online, along with 12 MW of coal and oil-fired generation.
Pipeline Opponents Ask FERC for Single Review of Projects
About 30 opposition groups in Virginia and West Virginia are asking FERC to combine the commission’s reviews of four natural gas pipeline projects. They want a single environmental impact statement that studies the cumulative impact of the projects.
“Our region is facing an unprecedented level of natural gas infrastructure development,” said the groups, which include the Sierra Club, the Augusta County Alliance and the Friends of the George Washington Forest Against Fracking.
The projects they’ve asked FERC to conjoin are the Atlantic Coast Pipeline, Mountain Valley Pipeline, Appalachian Connector Pipeline and the WB Express Project. The pipelines are designed to deliver natural gas found in the Marcellus and Utica shale regions to coastal population centers.
The Nuclear Regulatory Commission has issued a new list of cybersecurity reporting requirements for nuclear power plants.
The rules will require greater reporting of cyberattacks to improve understanding of the digital threats facing nuclear reactors. The information will aid in NRC’s “analysis of the reliability and effectiveness” of cybersecurity programs for nuclear power reactors, according to a Federal Register notice.
The move comes in the wake of real or rumored hacks of computer systems at nuclear plants around the globe. A recent report out of the U.K. charged that the nuclear industry is ignoring the risks of such attacks.
NRC Rejects Call to Look into Vermont Yankee Funds
The Nuclear Regulatory Commission says Entergy’s Vermont Yankee’s decommissioning fund is healthy and doesn’t need to be audited, rejecting a request from Vermont state officials for a closer examination.
The state asked NRC to limit Entergy’s use of the funds set aside for the plant’s retirement for anything other than radiological decommissioning.
NRC Spokesman Neil Sheehan said the Vermont Yankee decommissioning account has 60 years’ worth of funds in it and the company may complete the decommissioning in less time than that. “In terms of that time frame, the company should have sufficient funding to not only carry out radiological decommissioning but also to perform other activities and use the money for other uses,” Sheehan said.
NRC: Earthquake Risk Study Further Along than Thought
A detailed examination of risks to U.S. nuclear generating facilities won’t take as long as first anticipated, according to the Nuclear Regulatory Commission.
All of the country’s operating nuclear plants were ordered to reassess seismic risks after the 2011 Fukushima disaster in Japan. NRC at first said 33 sites needed further review, but it reduced that number to 20 after closer examination. The agency said all of the reviews will be completed by the end of 2019, a year earlier than initially projected.
Report: EV Use not Growing Fast Enough to Meet State Goals
A report by three environmental groups says usage of electric vehicles is growing, but not fast enough to meet goals set in a 2013 memorandum of understanding signed by officials in eight states in the Northeast and Midwest.
“Charging Up,” the report by the Conservation Law Foundation, the Sierra Club and Acadia Center, offers recommendations for increasing the number of electric vehicles on the road. They include auto dealership and consumer incentive programs, policies to encourage widespread availability of consumer-friendly charging stations, public education initiatives to raise awareness about the benefits of electric vehicles, and the use of electric vehicles in municipal and statewide fleets.
New York leads the way, with 12,000 EVs at mid-year, but its goal for 2025 is about 852,000. It would need to add almost 53,000 in the next two years. Meanwhile, Rhode Island is furthest behind, both in total and in reaching its goal: the state has registered only 421 EVs out of 43,596 needed.
ISO-NE has issued its 2015 Regional System Plan, the annual report that provides the foundation for long-term power-system planning in New England.
The comprehensive report details power system needs for the next 10 years, through 2024, and how these needs can be addressed. A preliminary draft was discussed at a presentation in September. (See ISO-NE Sees Flat Load Growth, More Solar and Wind.)
“The Regional System Plan charts the progress of the regional high-voltage power system, identifies the challenges to continued reliability, and forecasts future developments,” ISO-NE CEO Gordon van Welie said. “New England’s energy landscape is undergoing a dramatic transformation as oil, coal, and nuclear power plants retire, more generators are fueled by natural gas, and wind and solar resources are added to the power system.”
A U.S. District Court judge ruled Nov. 3 the Environmental Protection Agency has until Aug. 31 to approve a regional haze plan for the state, which the Sierra Club said should have been done years ago.
The Sierra Club brought the lawsuit against EPA in 2014, charging that the agency should have promulgated a federal implementation plan for the state in 2014 but didn’t, according to the order filed by Judge J. Leon Holmes.
PUC won’t Force Xcel to Share Facilities with Boulder
The City of Boulder cannot acquire Xcel Energy facilities that exclusively serve customers outside city limits, and the Public Utilities Commission will not force the utility to share facilities with the city, the commission ruled Nov. 4.
The commission partially dismissed an application from Boulder to acquire facilities, including substations and distribution infrastructure, outside city limits for the creation of a city-run energy utility.
However, the commission said it would allow Boulder and Xcel to engage in discovery and allow the city to supplement its original application after it learns more about Xcel’s system.
Bloom Energy Loses Lock on Renewable Energy Program
Fuel cell manufacturers other than Bloom Energy will be able to compete in the state’s renewable energy program under a settlement of a federal lawsuit brought by FuelCell Energy.
The Connecticut company had claimed that a 2011 amendment to the state code designed to entice Bloom Energy to set up a factory in Newark discriminated against out-of-state companies.
Bloom’s deal with the state allowed Delmarva Power and Light to count power from fuel cells manufactured in the state toward its renewable energy purchase requirements. Rival out-of-state manufacturers argued the law illegally excluded them.
‘Intellectual Capital’ Could Fuel NOLA’s Future in Energy Sector
Hecht
The energy industry is still an economic force in the state, though the number of company headquarters in New Orleans has declined amid Houston’s rise as a global energy hub.
New industrial projects sparked by low oil and gas prices promise to add thousands of blue-collar jobs in the region, from welders to pipefitters to maintenance workers. But New Orleans is also trying to reclaim its title as a white-collar energy town.
Michael Hecht, CEO of Greater New Orleans Inc., said New Orleans has emerged as a hospitable place to move or start a technology firm. It is only a matter of time before local tech growth intersects with the city’s historical strength in energy, he said.
The Community College of Baltimore County’s three main campuses have begun using a system of 16,500 solar panels that cover 1,400 parking spaces.
The installation is expected to generate 6.5 million kWh of electricity per year.
The carports were built by Constellation Energy. The college signed a 20-year agreement to buy power from the system, which is expected to save it $4 million in electricity costs.
Nexamp Peak, the largest community solar installation in the Northeast, has been powered up.
After more than three years of preparation and three months of construction, the facility is poised to generate 2.3 MW, 50% of which will be used by Jiminy Peak Mountain Resort. The balance of the generated power will be sold to 115 local subscribers at a 15% discount from the residential retail rate.
The solar farm, which contains 7,500 solar panels over 12 acres, is within the service areas of both National Grid and Eversource Energy, with interconnection agreements established with both companies. Final connection to both utilities is expected in the next four weeks.
Recent developments have revived the hopes of Cape Wind developer Jim Gordon that the controversial wind farm project in Nantucket Sound can survive several serious blows earlier this year, as it missed a crucial financing deadline and lost major contracts from utilities Eversource Energy and National Grid.
State lawmakers have expressed support for legislation that would direct utilities to enter into more long-term contracts for clean energy, including imposing a potential requirement favoring offshore wind sources. And the Pilgrim nuclear power plant’s recent announcement that it would close by 2019 is adding pressure on policymakers to find new sources of power that don’t produce greenhouse gases.
“It’s just more urgent to really start accelerating the penetration of renewable energy projects in this region,” said Gordon, who was a major player in building the first generation of natural gas plants in New England. “We think we’ve got a terrific project in a great location.”
Joplin Seeking Permission to Intervene in Empire Rate Case
Joplin city leaders will ask the Public Service Commission to allow the city to intervene on behalf of residents in a pending request by Empire District Electric to raise electric rates next year by more than 7%. Empire has asked the PSC to allow a $33.4 million increase in rates next year, in part to cover costs the company said it will incur to comply with new pollution regulations.
The city intervened in Empire’s 2014 rate case, when the company sought a $26.5 million increase. After hearing the case, the PSC reduced Empire’s increase to $17.13 million.
Empire said in the filing of the rate request that it is needed to pay for compliance with new pollution standards as well as compliance with the 2008 law known as Proposition C, which requires utilities to incorporate wind and solar power into their electricity production.
New Tool Proposed to Compare Residential Energy Prices
Singer
The state Senate has approved legislation that would require electricity and gas suppliers to provide current pricing to the Board of Public Utilities, which would make them accessible to consumers in a single database.
The measure, which must still be passed by the General Assembly, is designed to make it easier for residents to pick the most economical energy supplier.
Few residents have changed suppliers since the market was deregulated, but doing so could cut some bills by as much as 20%, according to Sen. Bob Singer.
A state District Court has found that the negligence of two electric utilities resulted in the 2011 Las Conchas Fire, at the time the largest blaze in the state’s history. The verdict came following four weeks of testimony.
The fire, which consumed 156,000 acres, broke out when a gust of wind caused an aspen tree to fall onto a Jemez Mountains Electric Cooperative power line located on U.S. Forest Service land. Tri-State Generation and Transmission Association provided wholesale electricity distributed by the cooperative.
The jury found that both JMEC and Tri-State were negligent, and that their negligence caused damages to the plaintiffs. They further found that JMEC was 75% responsible, Tri-State was 20% responsible and the Forest Service was 5% responsible.
The Public Regulation Commission has approved spending nearly $215,000 on lawyers to represent four commission members who an alternative-energy advocacy group seeks to have removed from deliberations over the aging San Juan Generating Station.
The case, pending before the state Supreme Court, will bring together two of the state’s highest-profile political lawyers at the defense table on Nov. 9 when the high court hears arguments in the case filed by the advocacy group, New Energy Economy.
New Energy claims the four elected regulators have shown bias toward Public Service Company of New Mexico and can’t be trusted to make a fair decision on the company’s plans for the coal-fired power plant.
The Public Regulation Commission has denied El Paso Electric’s move to create a separate rate class for solar residential customers in the utility’s proposed rate increase case.
The commission’s vote was 3-2 against the utility. “We reviewed our rules, state statute and federal law and upheld that El Paso Electric cannot do that,” said Commissioner Sandy Jones, whose PRC district includes Las Cruces. “We cited a number of federal rules … We felt like the facts were against them.”
Homeowners and solar installers had criticized the proposal, saying a separate rate category would penalize solar customers who operate systems they claim benefit El Paso Electric. Eddie Gutierrez, El Paso Electric vice president of external and public affairs, said the PRC’s decision won’t change rate increases sought by the utility.
The Public Regulation Commission has agreed to pay $20,000 to the Santa Fe New Mexican to settle all pending litigation over the PRC’s effort in August to block the newspaper from publishing documents it had obtained regarding the regulatory case on the San Juan power plant.
The five commissioners unanimously approved the settlement, which includes official acknowledgement of constitutional protections. It also commits the PRC to never again attempt to impose a prior restraint on publication of information by the paper.
Responding to a reporter’s public records request, the agency in August accidentally included several documents marked “confidential” among emails to and from the commission pertaining to Public Service Company of New Mexico’s plans to replace two coal-fired units at the 43-year-old San Juan plant with a combination of coal, nuclear power and a small portion of solar power.
An Obama official said that helping the state develop offshore wind projects is a top priority right now.
Speaking at the fall conference of the Alliance for Clean Energy New York, Abigail Ross Hopper, director of the federal Bureau of Ocean Energy Management, said that getting offshore wind projects up and running off New York City and Long Island is going to happen in the next couple of years.
Hopper said that she would like to see offshore wind projects launched by the time Obama leaves office. Officials with ACENY believe that large offshore wind projects that feed into the state’s wholesale electricity market will be the key to helping it achieve its goal of getting 50% of its electricity from renewable sources by 2030.
NYISO named Kevin Lanahan as vice president for external affairs to lead its regulatory affairs, government relations, stakeholder/member services, media relations and corporate communications activities.
“Kevin Lanahan is an experienced energy industry professional with a diverse background and outstanding knowledge of New York’s electric system,” said NYISO President and CEO Brad Jones. “He is superbly equipped to guide the NYISO’s role as an authoritative source of information on key energy issues.”
Lanahan previously served as Consolidated Edison’s director of government relations. He was vice president of state government affairs at JPMorgan Chase from 2009 to 2011.
FitzPatrick Nuclear Plant Talks Resume with Entergy
Entergy and New York state officials have resumed negotiations aimed at averting a shutdown of the James A. FitzPatrick nuclear power plant, according to U.S. Rep. John Katko.
The talks came two days after Entergy said it would close the plant in late 2016 or 2017. Katko said he spoke Wednesday with an Entergy executive and Gov. Andrew Cuomo’s office and confirmed the two sides are back at the negotiating table after a brief pause.
Katko said he did not know the substance of the conversations between Entergy and the governor’s office, and he did not want to interfere in the private discussions. Neither Entergy nor the governor’s office would confirm the continuing negotiations.
Utilies Back State, but Want CPP Implementation Plan
Niezwaag
Though they support the state’s challenge of the federal Clean Power Plan, utility companies in the state said they also backed the state’s efforts to begin drafting a plan to reduce carbon dioxide emissions by 45% to comply with the hotly contested new rule.
“The state has been very proactive,” said Dale Niezwaag, senior legislative representative for Basin Electric Power Cooperative, adding that the co-op has had regular meetings with state officials.
The companies support Attorney General Wayne Stenehjem joining a lawsuit to fight the Environmental Protection Agency’s Clean Power Plan, as well as developing a state implementation plan in tandem, should the legal challenge fail.
Despite having a project denied earlier this year, NextEra Energy Resources is continuing its work to put a wind farm in the state.
Company spokesperson Steve Stengel said an 87-turbine project planned for areas of southwest Stark County closely mimics the one that had been planned between Taylor and Gladstone earlier this year. That project was struck down by county commissioners after it created deep rifts within the community.
The company has regrouped since its first project in Stark County failed and is proposing an alternative two-part project it’s referring to as Brady Wind Energy Center 1. Another likely project, called Brady Wind Energy 2, would be located in Hettinger County.
PUC Gives NorthWestern First Rate Increase in 34 Years
The Public Utilities Commission gave final approval recently to NorthWestern Energy’s first base-rate increase in 34 years, allowing the company to raise its electric rates by 15.5%.
NorthWestern requested a 20.2% rate increase in December. All parties involved came to an agreement on a lower rate last week. NorthWestern will collect $20.9 million in additional revenues annually, according to the PUC.
Dallas uses the most renewable energy of any city in the country thanks to the purchase of wind energy credits, according to the Environmental Protection Agency.
City leaders approved a contract in June with energy provider TXU Energy requiring half of the energy for city operations come from renewable resources. In 2014, Dallas paid Invenergy Renewable $1.3 million to buy credits for another 50% of operations, so the city has credit for 100% renewable energy, staff said.
Dallas city facilities use about 715,000 MWh/year, enough to power 51,000 homes, according to the U.S. Energy Information Administration. The city ranked seventh among all U.S. energy users in EPA’s voluntary Green Power Partnership, behind Intel, Microsoft, Kohl’s, Apple, Google and Mars Inc.
El Paso Electric’s proposal to create a new rate class for residential rooftop solar customers has ignited a battle between the company and residential solar system providers, environmental groups and consumers.
The new rate class would result in the average solar residential bill in the El Paso area increasing by almost 24% versus the 12% average increase proposed for regular residential customers.
At least five solar companies and solar industry-related groups — all indicating opposition to the solar proposal — have been allowed by the state’s administrative hearing office to intervene in EPE’s rate case pending before the Public Utility Commission.
Northern Virginia has bested the New Jersey-New York region as the country’s largest data center market, according to real estate firm Jones Lang Salle.
The area accounts for nearly 20% of the market share this year, it said.
The region is home to 7.3 million square feet of data center space, and another 1 million is either planned or under construction.
State Judge Peter Anderson has struck down a rule approved by state regulators that would have imposed fees on a utility’s customers who installed solar generation or other renewable power sources.
The Public Service Commission approved a We Energies-supported proposal to impose the fees on those who installed solar, hydro and biogas systems. Solar customers would have had to pay $3.79/kWh of installed capacity; the fee rose to $8.60/kWh for biogas or hydro. The judge said the PSC’s decision was not supported by the evidence.
The Milwaukee Journal Sentinel said the PSC’s decision “generated more outcry and public involvement than any other rate case involving the Milwaukee utility in recent years.” It was challenged in Dane County Circuit Court by a solar trade group.
Lawmakers Reject Bill Challenging Clean Power Plan
Lawmakers have voted down a bill that would have required legislative approval or a final court decision before the state could implement new federal environmental regulations.
The proposed law was meant to be another avenue for the state to challenge, delay or at least soften the impacts of the Environmental Protection Agency’s Clean Power Plan. The Joint Minerals, Business and Economic Development Interim Committee voted 9-5 to reject the proposal Oct. 23.
The state has one of the steepest challenges in the country. The plan sets a goal of cutting the state’s total emissions by up to 44% compared to its 2012 baseline.
CARMEL, Ind. — MISO will not raise its energy offer cap for the coming winter but will ask FERC to approve another waiver allowing recovery of costs above $1,000/MWh through uplift.
MISO officials told the Market Subcommittee on Oct. 27 that they were responding to stakeholder feedback that generally preferred to repeat the approach that ruled the RTO’s market last winter (ER15-691). Like last winter, all offers are still subject to mitigation by the Independent Market Monitor.
MISO is expected to file the waiver request with FERC by Nov. 2, asking for a January implementation date. As late as last month, MISO had been considering raising the limit to $1,500. (See MISO Considering Raising Energy Offer Cap.)
Markets System Analyst Chuck Hansen said that MISO will seek a long-term solution for winter 2016/17 that complies with FERC guidance. FERC on Sept. 17 announced its intention to take action on offer caps and other price formation issues, though it offered no timeline. (See NOPR Requires RTOs Switch to 5-Minute Settlements.)
“Any permanent solution is going to have to follow what FERC might do,” Hansen said. “We don’t know what that direction is yet, but we’re going to have to respond to it.”
The offer cap is designed to limit potential market power, but natural gas price spikes, such as those in January 2014, can push generators’ costs higher.
Jeff Bladen, MISO’s executive director of market design, said no generators sought to use the waiver last winter.
Hansen said that MISO’s database could accommodate a higher offer cap with only minor “tweaks.” But MISO said caps above $1,500 could require changes to market rules governing the value of lost load (VOLL) and operating reserve demand curves.
During gas price spikes and high loads that tighten operating reserves, system marginal prices could near or exceed MISO’s $3,500/MWh VOLL, and congestion and loss components of LMPs could be reduced or lost.
“Our studies have shown that the energy offer cap has to be in sync with other market parameters,” Hansen said. “Before the following winter, we want to raise the offer cap, but we want to be careful of fixing one thing and creating issues under a different scenario. The point is we don’t want to solve one problem, then cause a bigger problem in other market conditions.”
Another consideration is that MISO generation could be lured to other regions with higher caps. PJM members agreed in September to seek FERC approval to increase its offer cap to $2,000/MWh beginning this winter. (See PJM Members OK $2,000/MWh Energy Market Offer Cap.)
MISO said generator responses also would be affected by different operating reserve scarcity curves.
MISO’s call for feedback on the issue generated 10 stakeholder responses: six votes to maintain a $1,000 cap, two votes to raise the cap to $1,500 and two votes supporting either case. Eight stakeholders voted to use uplift to recover verifiable costs above the cap; two stakeholders disagreed with using uplift to recover costs exceeding $1,000.
