PJM is proposing a MISO scheduling product similar to the PJM-NYISO Coordinated Transaction Scheduling solution that gained conditional FERC approval in February.
At last month’s Joint and Common Market meeting, PJM presented an overview of the PJM-NYISO CTS, along with a proposed work plan for developing a similar product with MISO. Joint MISO-PJM stakeholder meetings are scheduled for April 28 at MISO and June 10 at PJM.
The meetings will be devoted to “setting up what the proposal will look like,” said PJM’s Rebecca Carroll, who provided the Market Implementation Committee with an update last week.
“We are trying to keep it as similar [to the NYISO product] as we can,” she said. “We would like the products to be complementary.”
PJM and MISO had discussed optimization in 2011 and 2012 but tabled the matter to pursue higher priorities. “The JCM has been up for one and a half years now. We thought it was time to take up this issue again,” Carroll said.
MISO Has Second Thoughts on Interface Pricing
The two regions are no closer to a solution, however, on eliminating the double counting of congestion in interface prices.
PJM wants MISO to agree on a common definition of the PJM-MISO interface to eliminate double counting that can inflate congestion calculations in market-to-market transactions. Transactions overestimate congestion when they settle with both RTOs because both are pricing its full effect on the constraint.
In February, PJM said it had concluded that its definition puts the interface too far west of the congestion. It proposed a revised definition comprised of 10 generator pnodes closer to the RTOs’ seam. MISO’s Market Monitor suggested an alternative that would eliminate the double payment by basing the settlement entirely on the monitoring RTO’s shadow price. (See PJM, MISO Seek Common Ground on Congestion Values.)
According to MISO’s presentation at the March 21 JCM meeting, MISO stakeholders found none of the proposals was “obviously superior” to the current definition and concluded it may be impossible to develop a methodology that provides more accurate signals in all situations.
MISO said it will continue to evaluate alternatives in the search for one that works better in most cases.
For now, however, Carroll said PJM and MISO will retain their current definitions.
Carroll said it appears the proposed changes stalled due to concern within MISO about the impact on Financial Transmission Rights.
Stakeholders endorsed rule changes last week to clarify that generation owners providing Tier 2 synchronized reserves will be measured in the aggregate when PJM evaluates their performance under a new penalty structure. The Federal Energy Regulatory Commission approved the new penalties effective Jan. 1 (ER14-297).
Manual 11: Energy and Ancillary Services Market Operations already included a business rule that allows resource providers to aggregate in order to use an over-responding resource to offset the deficiency of an under-responding resource, Suzanne Coyne of PJM told the Market Implementation Committee.
The MIC voted to add new language to the Tariff, Operating Agreement and Manual 28: Operating Agreement Accounting to reflect this rule.
WASHINGTON — EPA Secretary Gina McCarthy told no secrets last week as she continued her charm offensive in advance of the agency’s long-awaited greenhouse gas rules for existing power generators.
EPA Secretary Gina McCarthy
The proposed regulations are due to be released June 1, and McCarthy, the star attraction at a Bipartisan Policy Center forum April 7, knew she wasn’t allowed to spill the beans.
“I know I can’t be tellin’ what the rule says, so kick me if you think I’m starting to get on the verge,” she joked to BPC President Jason Grumet.
Instead, she continued her promises to provide states “flexibility” and to honor reliability concerns. She also made clear that the rulemaking to be released in about 50 days will not be the final word.
McCarthy, deputy Janet McCabe and other agency officials have won widespread praise for their outreach to state regulators, including a shout-out at the forum from Colette Honorable, president of the National Association of Regulatory Utility Commissioners (NARUC).
But McCarthy, an earnest, plain-spoken former state environmental regulator with a strong Boston accent, acknowledged that the warm and fuzzy feelings may evaporate once the details are released.
“I think we’re presenting a little bit of a rosy picture. I think everyone realizes that I’m a stark realist. I know the challenge we’re having,” she said near the end of her session, before being hustled out a side door away from reporters. “The only thing I really hope when this proposal goes out is that people will look at it and say ‘EPA listened.’”
Mission accomplished, said Honorable, who shared the stage with McCarthy at the Grand Hyatt hotel.
“Gina has certainly been no stranger to NARUC,” she said, playfully noting the contrast between McCarthy’s accent and her own Arkansas drawl. “She’s fearless. … It really has been a pleasure to engage with her.”
Informed by Further Discussion
The proposed GHG rules — now undergoing an interagency review — will leave “lots more room for improvement,” McCarthy said. As a result, she promised, the final rule will be “informed by further discussion” in the comment process.
“I think many times we get criticized because there’s so much change between the proposal and final. That’s when I dance in the streets. Because I think that is exactly as it’s supposed to be, because you’ve put concrete ideas on [the table] — instead of lofty discussions — and you start digging in to what really matters to people, which is all the details.
“It needs to be incredibly smartly crafted … to make sure it provides the flexibility that states need while continuing to provide the impetus for the carbon reductions we need,” she added. “States that are out in front can continue to be there and get rewarded for that and recognized for that, while states that haven’t yet gone down this road can craft a way to do that in a time frame that will be meaningful for them.”
RTO Involvement
NARUC President Collette Honorable
RTOs such as PJM “are going to have to be a strong voice” in the final rule, McCarthy said, “because the president has made clear … nothing we can do can threaten reliability.” (See related story, RTOs Weigh Role in GHG Compliance)
Honorable agreed that “certainly the regions will have a role to play.
“The nuance here is … who’s on first,” she added. “The states … are the sole entities with jurisdiction over things such as resource adequacy. We can’t allow utility regulators to check that duty.”
Not an Aspirational Goal
McCarthy made clear that while states will be given flexibility, the rule will be “federally enforceable. It is going to be a requirement.
“We are going to be looking at the state plans to determine whether or not they are conforming with the guidance and getting us significant carbon pollution reductions … We’re going to make them cost effective,” McCarthy continued. “We’re going to make them make sense. We’re going to recognize that different regions … are in different places [regarding compliance]. But we’re not going to rely on an aspirational goal.”
Don’t Reinvent the Wheel
That’s fine by the states, said Honorable. “We’re not saying let everything count. But we’re saying let’s not reinvent the wheel,” she said. “We aren’t saying ‘let’s throw it all against the wall and see what sticks.’”
McCarthy and Honorable led off the day-long conference, which also featured panels with economic and environmental regulators from New Jersey, Ohio, Delaware, Michigan and other states, and representatives from Dominion Resources and PJM. Several PJM staffers were among the hundreds watching from the ballroom or via webcast.
The panelists discussed the roles of energy storage, energy efficiency, combined heat and power, nuclear energy and carbon capture under the new rules.
Coal, Wind Roles
Commissioner Greg White, Michigan Public Service Commission
Jon Brekke, vice president of Great River Energy, said that worldwide coal capacity additions over the next five years will equal the current U.S. coal fleet, potentially negating any emissions cuts the U.S. makes.
“If you simply turn away from coal we won’t contribute to global solutions. We won’t contribute to technological development,” he said, urging continued research on carbon capture technology. “This is the country that can lead the world in innovation.”
Commissioner Greg White, of the Michigan Public Service Commission, put in a pitch for research to improve energy storage, which would address the intermittency of wind and solar. “It should be a national imperative,” he said.
PTC Help or Hindrance?
Speakers differed over the impact continuation of the production tax credit (PTC) for wind would have on meeting emission goals.
Commissioner Asim Haque, Public Utilities Commission of Ohio
Tom Vinson, the American Wind Energy Association’s vice president for federal regulatory affairs, predicted the PTC, which expired Dec. 31, will be renewed. Although wind’s costs have dropped substantially in the last decade, Vinson said the industry isn’t ready to compete without subsidies just yet.
But White noted that the PTC allows wind generators to make money even in overnight hours, contributing to negative prices that nuclear operators say threatens the viability of their carbon-free baseload generation.
Cost Concerns
The impact of the regulations on customer bills was on the minds of many of the panelists.
Ohio Public Utility Commissioner Asim Haque said he was concerned that his state, which is considering freezing its energy efficiency program, get credit for its past reductions. If the state legislature approves the freeze, he said, EPA shouldn’t take over the state program but simply require other savings. “I still think people will pursue energy efficiency,” he said.
Commissioner Jeanne Fox, New Jersey Board of Public Utilities
Pamela Faggert, Dominion Resources’ chief environmental officer, said the utility, which once had 17 coal-fired plants, expects to have only five by 2016. The company’s most recent Integrated Resource Plan includes “eight or nine” scenarios based on different levels of emission reductions that may be required by the EPA — with a big spread in potential costs. “We do expect the price of power will go up in the U.S.,” she said.
“It’s going to be a real test of agility for all of us,” said Robert Balazar, principal consultant for the Tennessee Valley Authority. “Where I come from we already have a large number of people who can’t afford their [electric] bills.”
Michigan’s White was one of several speakers who acknowledged the hard work is yet to come. The EPA is “saying all the right things, but I’m waiting for the details,” he said.
Elizabeth (Libby) Jacobs, chair of the Iowa Utilities Board, agreed. “Check with me … in July to see if we’re all still singing ‘Kumbaya,’” she said.
Powhatan Energy Fund, the firm that is waging an unusual public battle against the Federal Energy Regulatory Commission’s investigation of it for manipulative trading in PJM, is now also campaigning against the man chosen by the White House to be FERC’s new chairman. The nominee, Norman Bay, is a former federal prosecutor who has been FERC’s enforcement chief since mid-2009. (See PJM Trader Calls FERC on Manipulation Probe.)
The twin brothers who own Powhatan have a website devoted to combating FERC’s position on the transactions in question. Now that Bay has been tagged to lead the commission, “we’re out there actively trying to talk to senators and staffers about our story and spreading the word about the website and trying to get his nomination defeated,” an attorney for Powhatan said. The White House announced its nomination of Bay in January, but the Senate Energy and Natural Resources Committee has not scheduled a hearing on it yet.
CFTC to Give Public Power Assurance on Swaps Deals
The Commodity Futures Trading Commission will write a formal rule to fix a problem public power utilities have complained about since 2012. Soon after issuing a “no action” letter with assurances to public power in March, the CFTC said it would provide permanent assurance with a rule that effectively allows counterparties — natural gas companies, other utilities, power producers — to do “swaps” deals with public power without having to register as swaps dealers, as long as their aggregate swaps deals do not exceed $8 billion a year. The rule will put publicly owned utilities on the same basis as other energy companies. Current regulation sets a limit of $25 million a year, blocking traditional counterparties from doing these deals with public power.
US Power Plant Capacity Additions 2013 (Source: EIA)
A little more than 13,500 MW of capacity was added to U.S. utility-scale supply in 2013, less than half the amount added in 2012, the Energy Information Administration reported. Natural gas plants accounted for slightly more than 50% of the 2013 additions, with solar contributing nearly 22%, coal making up 11% and wind at almost 8%. California led the additions, followed at a good distance by Texas, Florida and North Carolina.
Among new gas plants, additions came nearly equally from combustion turbine peakers and combined-cycle plants. Nearly 60% of the gas capacity added was in California. Two coal plants accounted for all the added coal capacity: one in Texas and the 571-MW Edwardsport integrated gasification combined-cycle plant in Indiana.
The Department of Energy will open the door to new applications for renewable energy project loan guarantees during the second quarter of his year, Secretary Ernest Moniz said. Peter Davidson, head of the loan program, has suggested the revived loan guarantee program will focus on initiatives to help integrate renewables into the grid.
Under the low-emissions technology program, DOE recently finalized a guarantee for Georgia Power’s Vogtle nuclear project in Georgia and it is taking applications for coal- and petroleum-related carbon capture projects.
The Senate Finance Committee approved a tax-extenders package that includes a two-year extension of the wind energy production tax credit, which expired at the end of 2013. The 2.3-cent/kWh credit, as before, would apply to utility-scale production for the first 10 years of operation.
Two Californians and 14 other Democrats have introduced a bill to create what they are calling Clean Energy Victory Bonds, an effort to put the World War II financing mechanism to work for renewable power and clean energy technology.
In the measure sponsored by Reps. Zoe Lofgren and Doris Matsui, Treasury bonds in denominations as low as $25 would “leverage $50 billion investment to provide up to $150 billion in public and private financing to fund the production of innovative energy technologies.”
PJM and the Independent Market Monitor have reached an agreement on a rule change to reduce the number of Frequently Mitigated Units eligible for “adders,” but the proposal appears to face heavy opposition from generation owners.
Only units whose net revenues are not covering their avoidable cost rate (ACR) would be eligible for adders under the proposal presented to the Market Implementation Committee on first read last week.
The proposal represented a compromise by Market Monitor Joe Bowring, who had previously called for eliminating the adders altogether.
Had the proposal been in effect in 2013, it would have reduced the number of units receiving adders from 112 to only 28 — 23 of which are scheduled to retire. “Implementing the screen would result in a notable smaller number of FMUs” receiving the compensation, said PJM’s Tom Zadlo.
In polling among members of the generation-heavy MIC subgroup that has considered alternatives, however, 72% of voters said they opposed the proposal. A nearly identical percentage said they would favor either of two alternatives.
One of the proposals that received support in the poll would set the adders based on a plant’s run hours. The second would limit the compensation based on the gross Cost of New Entry for the unit’s Locational Deliverability Area.
FMUs were allowed adders in 2006 to ensure that they cover their avoidable, or going-forward, costs. The adders are graduated: Generators that are cost capped for 60% of their running hours receive an adder of either 10% of their cost-based offer or $20/MWh; those capped for 80% or more of their hours can receive $40/MWh. Similar rules apply to “associated units,” which share physical and economic characteristics to FMUs. The idea is to keep units in service that otherwise would not be economically available.
Bowring said the adders had become unnecessary for most units since the introduction of the capacity market in 2007 and changes to scarcity pricing rules in 2012. (See PJM Reconsiders Adders on Cost-Capped Generators.)
Despite the lack of support for the PJM-IMM proposal in the poll, PJM officials said they intend to bring their plan to an MIC vote next month.
“Although it was spun as a compromise proposal it’s only a compromise between PJM and the IMM, not other participants,” said Dave Pratzon, who represents generators. “I don’t think … that this is the best way to move forward.”
“This is a load-gen[eration] issue,” responded Dave Mabry, of the PJM Industrial Customer Coalition. “Nothing is going to get sector-weighted support.”
PJM has dropped a plan that would have allowed dispatchers to cut interchange ramp limits in order to reduce price volatility and uplift, the RTO told the Market Implementation Committee last week.
The proposal was received coolly by stakeholders when PJM officials floated it at the MIC’s March meeting. (See Ramp Limits Cause Stir at MIC.)
After internal discussions among PJM staff, the proposal “has been taken off the table,” PJM’s Lisa Morelli told the MIC last week.
Dispatchers will continue to have the ability to limit ramp to protect reliability and may use it more frequently in the future, Morelli said. But PJM will develop manual language to clarify the circumstances under which such action may be taken, she said.
At a Federal Energy Regulatory Commission technical conference April 1, PJM Executive Vice President for Operations Mike Kormos said PJM might consider requiring interchange transactions be scheduled two or three hours in advance so that operators can avoid having too much supply. Current interchange rules allow scheduling with only 15 minutes’ notice.
Kormos said unexpected imports contributed to PJM’s nearly $600 million in uplift costs in January. (See PJM May Offer Firm-Fuel Premium.)
Stakeholders will attempt to develop more accurate measurement and verification of residential demand response under a problem statement approved by the Market Implementation Committee last week.
PJM currently measures load reductions for much of its residential DR based on data that was compiled more than a decade ago in Maryland and New Jersey.
PJM’s Shira Horowitz said the data is no longer representative because of the growth of PJM’s footprint, changes in DR programs and increases in the energy efficiency of air conditioners and other appliances.
The old data were collected based on legacy “direct load control” (DLC) programs. Residential demand response now includes use of smart meters and programmable thermostats.
Some stakeholders questioned why PJM wants the review to include firm service level (FSL) and guaranteed load drop (GLD) programs in addition to DLC.
“I’m not seeing any concerns with the other two verifications,” said one stakeholder. “I’m struggling with why we want to expand this past DLC programs.”
Pete Langbein, of PJM, said the RTO wants to take a holistic approach to the issue.
“Residential [DR] is unique. We’re not dealing with a few thousand customers, we’re looking at millions,” he said. “From PJM’s standpoint, we don’t think we should limit this to DLC.”
Residential demand response supplies about 1,000 MW of capacity in PJM.
Among the many questions about the pending EPA carbon rules on existing generation are how state implementation rules will mesh with regional compliance approaches and what role RTOs such as PJM will play.
Paul Sotkiewicz, chief economist, PJM
PJM stands ready to help, Paul Sotkiewicz, PJM’s chief economist, told a Bipartisan Policy Center forum last week.
The economies of scale that RTOs have brought to unit dispatch, planning and other grid functions can also help reduce the costs of complying with the greenhouse gas rules, Sotkiewicz said.
“We can reflect the cost of environmental retrofits. It makes sense to piggyback on the existing infrastructure,” he said.
While it will be up to state officials to decide what the RTO role is and whether they want to participate, states that go it alone, he said, “are leaving money on the table.”
Two visions for how RTOs might take part were sketched out earlier this year. In January, PJM and other RTOs asked the EPA to allow states to meet the greenhouse gas rules through regional caps and to include a “safety valve” to maintain reliability.
ISO/RTO Council
The ISO/RTO Council (IRC) said that it usually doesn’t take policy positions on EPA regulations, but that it wanted to ensure EPA officials “recognize the relationship between proposed environmental rules, electric system reliability and economically efficient dispatch.”
The council’s seven-page proposal asks the EPA to allow states to adopt State Implementation Plans (SIPs) based on “a regional measurement mechanism for determining compliance.” The group also said the EPA’s regulations should include a process to mitigate reliability impacts of the regulations.
MISO Role Envisioned
In February, The Brattle Group and Great River Energy, a cooperative in MISO, proposed that RTOs build the carbon emission limits into their markets instead of making individual generators or states meet them.
Jeanne Fox, commissioner, New Jersey Board of Public Utilities
For the states that joined MISO or other regional operators, “It doesn’t seem like much of a stretch to add carbon management to that plate,” said Jon Brekke, vice president of Great River.
The proposal would have RTOs and ISOs translate EPA emission reduction limits into targets for their regional power markets. The reductions would be met by applying an RTO- or ISO-administered carbon price to generation and refunding the revenues to load serving entities based on consumption levels.
“This not a social cost of carbon … this is an economic signal,” said Brekke, who added that it would avoid stigma as a “tax” because the funds would go to LSEs rather than government.
Asked after the forum whether MISO was willing to take on the market-clearing role envisioned in the plan, Brekke responded: “We know that MISO is willing to facilitate a discussion that’s state-led.”
The idea of a regional solution is “getting traction,” he added. “Whether it’s our approach or another is secondary.”
RGGI Redux?
A top Delaware official, meanwhile, pitched the nine-state Regional Greenhouse Gas Initiative (RGGI) as a “plug-and-play” solution that other jurisdictions could adopt.
Collin O’Mara, secretary, Delaware Department of Natural Resources and Environmental Control
Carbon emissions in RGGI states have dropped by nearly 52% since 2005, thanks to energy efficiency and fuel switching — as well as the lackluster economy.
Current emission levels are 45% below RGGI’s 2013 cap, said Collin O’Mara, secretary of the Delaware Department of Natural Resources and Environmental Control. Participating in addition to Delaware are Connecticut, Maine, Maryland, Massachusetts, New Hampshire, New York, Rhode Island and Vermont.
Money collected through RGGI is reinvested in energy efficiency and renewable energy giving every expenditure a multiplier effect twice or triple the investment he said. (New Jersey Gov. Chris Christie, however, used some of the revenues to balance his budget before pulling the state out of the program in 2011.)
Rather than calling it cap and trade, however, O’Mara suggested a less politically combustible name: “budget and invest.”
New Jersey’s Democratic-controlled legislature has tried on several occasions to pass legislation reversing Christie’s decision, but it has been defeated by vetoes. “I don’t see [rejoining RGGI] happening in the near future,” said New Jersey Board of Public Utilities Commissioner Jeanne Fox.
Seams
The PJM-MISO seam has vexed both regions for years, but when it comes to GHG compliance it could be a boon, Sotkiewicz said.
State implementation plans for the four states split between PJM and MISO — Michigan, Illinois, Indiana and Kentucky — could manage emission allowances across RTO borders, he said.
“Rather than seams being a problem it actually creates fungibility between different regional compliance programs,” Sotkiewicz said. “Rather than being a barrier, per se, it almost becomes an opportunity.”
PJM is planning a system-wide drill Sept. 23 to simulate simultaneous physical attacks on critical substations, cyber attacks and the loss of supervisory control and data acquisition (SCADA).
The drill will assess PJM’s and transmission operators’ readiness to respond to nation-state sponsored attacks.
It will incorporate lessons learned from the North American Electric Reliability Corp.’s GridEx II, an exercise that drew participation from 200 organizations, including PJM, in November. Some participants complained that the GridEx “injects” were introduced too rapidly and that communications between participants didn’t use real-world methods. (See Grid Exercise `Like a Disaster Movie.’)
“GridEx was a good exercise, but sometimes they used communication paths that were not traditional,” said LeRoy Bunyon, PJM manager of business continuity planning. He said the PJM drill will feature communication “not between planner and planner, but operator to real operator.”
According to a presentation to the Operating Committee last week, the drill will test the communication channels between PJM and transmission owners and their ability to respond to attacks by implementing emergency procedures.
Bunyon said PJM will participate using its Dispatcher Training Simulator and asked transmission owners to consider simulator use, as well, instead of using the drill as a tabletop exercise. He asked transmission owners to designate planners to help develop drill materials and conduct training.
Fuel procurement and environmental limitations are the top obstacles to increasing the flexibility of PJM’s generating fleet, according to survey results released last week.
About 83% of generator operators responding to the survey said they are operating to the limits of their plants’ flexibility. Of the remaining 17%, most cited fuel and emissions limits, with insufficient compensation “a distant third,” PJM said.
The survey was developed in response to what Adam Keech, manager of wholesale market operations, said was a decline in generation flexibility over the last decade.
PJM’s Eric Hsia told the Market Implementation Committee last week 20% of those who said their units were being offered as flexibly as possible reported their flexibility has decreased over time. Among the reasons cited were compensation rules that discourage investment in aging plants, lack of fuel, emission limits and “additional risk of tripping.”
PJM’s next step will be one-on-one meetings with companies to get more details. Hsia said some of the fuel issues are already being addressed by the Gas-Electric Senior Task Force.
