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August 15, 2024

Company Briefs

Kinder Morgan formally withdrew its application for the Northeast Energy Direct natural gas pipeline in a filing with FERC (CP16-21).

Tennessee Gas Pipeline, a Kinder Morgan subsidiary, in April suspended development of the $3.3 billion project that would have brought 1.3 million dekatherms per day into the New York-New England power markets from Pennsylvania. (See Kinder Morgan Board Suspends Work on Northeast Energy Direct Pipeline.) It cited a lack of customers and low natural gas prices.

“Tennessee provides notice of its withdrawal of the application in this proceeding,” the company wrote to FERC, with no further explanation.

More: New Hampshire Union Leader

Talen Energy Signals Retreat from Colstrip

Talen Energy gave notice that it will pull out of its operator role at the Colstrip coal-fired power plant in Montana by May 2018. The Pennsylvania-based merchant generating company co-owns the plant near Billings, part of the fleet it inherited from its predecessor, PPL.

Talen notified the other owners of the plant that its role as operator of the giant complex is “not economically viable” and that they should start seeking a new operator. “This decision is part of Talen Energy’s overall strategy to conclude our business operations in the state,” said Todd Martin, the company spokesman. Talen is obligated to give two years’ notice.

The other owners are Avista, Puget Sound Energy, Portland General Electric, PacifiCorp and NorthWestern Energy.  Unlike the plant’s other shareholders, Talen is an unregulated entity and unable to recover costs related to the plant.

More: Billings Gazette; The Associated Press

TVA’s Watts Bar 2 Nuke Goes Critical

The Tennessee Valley Authority’s Watts Bar Unit 2 went critical last week, the first new nuclear reactor to achieve a self-sustaining nuclear reaction in 20 years. When it comes online and is synchronized to the grid, it will bring 1,411 MW of generation to the region.

The plant’s $4.7 billion cost is far less than another new reactor in the wings, Southern Co.’s Plant Vogtle in Georgia, which has an estimated $14 billion price tag. Construction of Watts Bar began nearly 30 years ago.

More: Times Free Press

Ameren Illinois Touts Savings Secured Through Auction

Ameren Illinois is touting the lower prices it secured in April during MISO’s annual capacity auction. The company said its 2016 $72/MW-day capacity prices — compared with $150/MW-day in last year’s auction — will translate into a $1.75/month savings for the average utility customer.

“This year’s capacity planning auction resulted in a much more equitable distribution of charges for customers in the MISO footprint,” said Richard J. Mark, president of Ameren Illinois.

However, watchdog group Citizens Utility Board said more can be done to lower costs, including purchasing electricity at off-peak times. “Nobody thinks their electric bills are low, so we’ve got a lot more to do to fix the Illinois electricity market,” said CUB spokesman Jim Chilsen.

More: Herald & Review

Invenergy to Build 25-MW Solar Plant on Long Island

Invenergy announced that it will build a 25-MW solar facility on the grounds of Long Island’s former Tallgrass Golf Course in Brookhaven.

The Long Island Power Authority will buy the output, the company said. The plant, to be called the Shoreham Solar Commons project, still needs the approvals of the New York attorney general’s office and the state comptroller, according to a company spokeswoman. Construction is expected to begin in October.

More: Bloomberg

Lincoln Electric Accelerates Local Transmission Project

Lincoln Electric System, the public utility serving Nebraska’s capital city, is accelerating the timeline for a $17.7 million transmission line and substation that will help meet increasing electric demands. The SPP member plans to complete its Southeast Reliability Project in in 2018, two years earlier than planned.

LES held three open houses for the project last year and is now expediting the project to stay ahead of continuing development in the area, LES representatives said during the monthly meeting of the utility’s board.

The project includes construction of three substations and a 7.5-mile-long 115-kV overhead transmission line, as well as the relocation of a 345-kV line that will follow the same route.

More: Lincoln Journal Star

Chinese American Subsidiary Acquires Texas Wind Farm

China’s Xinjiang Goldwind Science & Technology says its American subsidiary, Goldwind Americas, has signed an agreement with Renewable Energy Systems Americas to acquire the 160-MW Rattlesnake Wind Project in West Texas.

Goldwind says the Rattlesnake project will be its largest U.S. wind project once it is operational.

Located approximately 125 miles northwest of Austin, the project will use 64 Goldwind 2.5-MW permanent magnet direct-drive wind turbines. According to Goldwind, the development represents the first phase of an expected 300-MW wind project, which will be constructed under a balance-of-plant agreement by RES.

More: North American Windpower

ND Allam Cycle Project Sponsors Seek More Funding

North Dakota researchers and regional energy companies are asking the state’s Lignite Research Council for $3.5 million to continue research on what the industry considers a promising carbon-capture technology.

Energy & Environmental Research Center, Basin Electric Power Cooperative, 8 Rivers and ALLETE say the funds are needed for further lab testing and pre-planning for a synthetic gas-fired pilot plant using the Allam Cycle system for lignite coal. The Allam Cycle, invented by 8 Rivers, uses pressurized carbon dioxide rather than steam to generate power more efficiently, cheaply and cleanly.

A $140 million, 50-MW natural gas-fired Allam Cycle pilot power plant in Texas will start up in 2017. If the technology is proven to work with natural gas, the lignite coal industry is hopeful the system and processes can be adapted to handle gasified lignite.

More: The Bismarck Tribune

New York Hydro Owner Says It Has Buyer

The owner of the 33-MW Glen Park hydro facility near Watertown, N.Y., says it has a prospective buyer for the plant.

Calgary-based Veresen did not identify the prospective buyer, but it expects to close the $61 million transaction by the end of September, pending FERC approval.

Veresen, previously known as Fort Chicago Energy Partners, acquired the facility in 2010 for $80.1 million.

More: HydroWorld.com

Caithness II Plant Proponents Urge PSEG, LIPA to Deal

Proponents of Caithness II, a proposed 750-MW natural gas-fired power plant, are calling for PSEG Long Island and the Long Island Power Authority to enter into power purchase agreements with the plant. Caithness Energy already operates a 350-MW plant in Yaphank on Long Island and sells the output to PSEG and LIPA.

PSEG hasn’t committed to Caithness II and questions the need for it. But local elected officials and others say the area is served by outdated, inefficient plants that should be replaced.

“Caithness II will help offset Long Island’s reliance on aging power plants that are inefficient and costly,” said Brookhaven Councilman Kevin LaValle. “Brookhaven and the entire region stands to prosper greatly from a modernized electric power supply, and this project brings us closer to the goal of providing Long Island ratepayers with more affordable and reliable energy.”

More: Long Island Business News (subscription required)

Fluor Says Brunswick County Generating Station Complete

Fluor, the primary contractor for Dominion Resources’ Brunswick County Power Station in Virginia, said that it has completed constructing the 1,358-MW natural gas-fired plant. Final testing will be needed before it goes into operation.

Fluor is now scheduled to begin construction of another Dominion project, the 1,600-MW gas-fired Greensville County generating station, which will be located 7 miles from Brunswick Station.

More: Fluor

Duke Signs Deal to Use Captured Swine Manure Gas

Duke Energy has signed a deal with pork producers in North Carolina to use captured methane to run two power stations.

Methane from the Smithfield Foods farms in the Kenansville area will be captured by Optima KV, converted to pipeline-quality fuel and transported  to the H.F. Lee and Sutton power plants. Optima has a 15-year contract with Duke.

Duke in March joined in a similar project with Carbon Cycle Energy to capture manure gas to fuel four of its plants in the state.

More: Charlotte Business Journal

Union, Talen Offer Conflicting Reports on Job Losses

Talen Energy plans to eliminate 125 union jobs at three Pennsylvania power plants, according to the International Brotherhood of Electrical Workers 1600.

A Talen spokesman, however, disputed the report and would confirm only job cuts at the Susquehanna nuclear plant. The other two plants slated for job losses, according to the union, are the Brunner Island and Montour coal-fired facilities.

The company and the union cited the depressed cost of electricity as a driver in the restructuring.

More: The Morning Call; The Daily Item

PSE&G Says Upgrades Will Help Meet Summer Demand

Public Service Electric and Gas this year has deployed $2.7 billion in infrastructure improvements that it said will help it meet summer demand.

“Equipment has been replaced, facilities upgraded and additional redundancies added systemwide in order to maintain reliability,” said John Latka, vice president of electric and gas operations.

The summer peak is expected to hit 10,090 MW, compared with last year’s peak of 9,579 MW, set July 20.

More: Transmission & Distribution World

Utah Supreme Court Upholds PacifiCorp Fine

The Utah Supreme Court last week voted to uphold a $130.7 million jury award against PacifiCorp and its lawyers for violating trade secrets when the company constructed a power plant similar to a nearby facility being built by Dallas-based USA Power.

In bringing the suit in 2005, USA Power argued that PacifiCorp — parent of Utah’s Rocky Mountain Power — had copied the plans for the air-cooled, gas-fired Spring Canyon plant, which was designed to limit impact on the local environment. PacifiCorp had previously entered negotiations to buy the plant, but it later backed out and constructed a similar unit a mile away.

After a five-week trial in 2012, a jury awarded USA Power $18.2 million in damages for stealing trade secrets and $112.5 million in damages because PacifiCorp unjustly profited from the theft.

More: KSL.com

Massachusetts Clean Power Bill Hit from All Sides

By William Opalka

A long-awaited bill introduced in the Massachusetts House of Representatives last week that would ease the path for Canadian hydropower and offshore wind into the state and New England electricity markets was criticized by both clean energy advocates and power generators.

Massachusetts Clean Power Bill
Daniel-Johnson Dam and Manic Generating Station Source: Hydro-Quebec

The bill calls for power distribution companies and the state Department of Energy Resources to procure 1,200 MW of offshore wind and 9,450 GWh of hydropower annually by June 30, 2017. The contracts would last between 15 and 20 years.

Gov. Charlie Baker called the proposal “a very strong bill that’s built around the idea of expanding our portfolio, diversifying our energy sources and incorporating big slugs of hydro and wind into our portfolio here in Massachusetts and across New England.” (See Baker: Hydropower Contracts Best Way to Lower Costs.)

The bill isn’t as comprehensive as many stakeholders had hoped for, lacking provisions for solar, nuclear power, energy efficiency or other technologies. An extension of the solar net metering cap earlier this year was the only significant issue addressed this session. (See Massachusetts Raises Net Metering Cap, Cuts Payments.)

The New England Power Generators Association said the bill interferes with market mechanisms that had delivered lower-cost power.

“The proposal would carve up one-third of the Massachusetts electricity marketplace into decades-long contracts that have the potential to dramatically increase electricity costs for consumers,” NEPGA president Dan Dolan said in a statement.

Some environmental advocates see the bill as weighted too heavily toward hydropower. “The Massachusetts House deserves full credit for recognizing the urgent need to address our state’s energy future. However, this bill is not strong enough,” said Caitlin Peale Sloan, a staff attorney for the Conservation Law Foundation. “We need to take bold action to counter climate change and that means choosing the cleanest energy that we can. Wind is one of the cleanest energy sources — cleaner than imported hydropower.”

A coalition of offshore wind developers said the bill begins a new era for the state.

“Offshore Wind Massachusetts looks forward to continuing to work with the House and Senate to fashion a final bill that will enable Massachusetts to make use of one of its greatest resources — abundant and reliable wind that will power a new industry and benefit our citizens for the rest of this century and beyond,” said Matthew A. Morrissey, its managing director.

The bill would exclude the Cape Wind project in Nantucket Sound by limiting eligible offshore wind projects to those in a “competitively solicited federal lease area” south of Massachusetts and Rhode Island. The project, once expected to be the country’s first offshore wind farm, has struggled to obtain financing.

MISO Advisory Committee Briefs

MISO’s Advisory Committee last week settled on five priorities for 2016 after adding an obligation to “improve coordination across market and non-market seams” under the seams optimization priority.

In approving the priorities, the committee also called for:

  • Improving operational coordination when dealing with federal regulations such as the Clean Power Plan;
  • A focus on price formation under the grid technology advancement priority; and
  • Refinement of the competitive transmission development process under the infrastructure development enablement priority.
MISO Advisory Committee Briefs
AC Vice Chair Tia Elliot (L) and AC Chair Audrey Penner discuss retirement of the Stakeholder Governance Working Group © RTO Insider

The changes were made in response to recommendations from MISO sectors. (See “AC to Finalize Priority-Setting for May Vote,” MISO Advisory Committee Briefs.)

Advisory Committee Chair Audrey Penner noted that the priorities would be revisited during the committee’s October strategic session. “I want to remind folks that … we will review this again,” she said. “It’s meant to be a reiterative, back-and-forth document.”

With priorities set for this year, work on 2017 begins immediately. Penner said the committee should focus on deciding if this year’s priorities have a shelf life that can continue into 2017 or if they should be reworked.

Committee Retires Stakeholder Governance Working Group

The committee retired the Stakeholder Governance Working Group after the group concluded modifications on the governance guide.

Vice Chair Tia Elliott said the Steering Committee will absorb the group’s responsibilities, and task teams could be formed to deal with more specific issues involving the governance guide. Outstanding governance issues could also be addressed at the annual stakeholder workshop.

Elliot said an “expertise safety net” already exists in the Steering Committee with MISO liaison Eric Stephens, who is able to assist with the governance guide and data requests from the recently retired Data Transparency Working Group.

Final Advisory Committee Priorities (MISO) - MISO Advisory Committee BriefsGary Mathis, representing the Transmission-Dependent Utilities sector, said more work is needed on stakeholder redesign implementation and that task teams are not the ideal venue.

“The Stakeholder Governance Working Group doesn’t meet very often, it’s efficient, has a chair and vice chair and, unlike a task team, follows the governance guide,” Mathis said.

He said the decision to retire the working group should rest with its parent entity, the Steering Committee.

Dynegy’s Mark Volpe said he has viewed the working group as a “transitional body” since February, when it first dodged retirement through an Advisory Committee motion. (See “Stakeholder Governance Working Group Sidesteps Retirement,” MISO Advisory Committee Briefs.) Elliott said the committee retained the right to retire the group.

— Amanda Durish Cook

ERCOT Stakeholders Reject Ancillary Service Revisions

By Tom Kleckner

AUSTIN, Texas — ERCOT members last week voted down the ISO’s attempt to salvage a revision request that would have replaced several ancillary services with four new products.

Frazier © RTO Insider
Frazier © RTO Insider

The nodal protocol revision request (NPRR), rejected earlier in the month by the Protocol Revision Subcommittee, was shot down again when the Technical Advisory Committee upheld the subcommittee vote by a 23-3 margin Thursday.

NPRR 667 would have improved regulation service and replaced non-spinning reserve and responsive reserve service with a combination of four new services: fast-frequency response, primary frequency response, contingency reserve and supplemental reserve.

However, staff was unable to convince stakeholders the revisions were ready for prime time. Speaking for the subcommittee, Luminant’s Amanda Frazier said ERCOT did not demonstrate a current or future reliability need for the services and did not adequately address their costs and funding.

“What I heard from PRS members is [ERCOT has] exceptional performance from a reliability perspective,” said Frazier, the subcommittee’s chair. “It has consistently improved over time, so even though we’ve seen growth of intermittent resources over the last decade — exponential growth — we also see performance that is improving.”

Frazier said stakeholders also had concerns over market liquidity for the new services and would prefer to see ERCOT focused on identifying reliability needs and alternatives to NPRR 667. “ERCOT has expressed a preference for a vote on 667 before examining alternatives,” Frazier said. (See “NOGGR Tabled, Other Revision Requests Approved,” ERCOT Technical Advisory Committee Briefs.)

Woodfin © RTO Insider; ERCOT Ancillary Service
Woodfin © RTO Insider

“ERCOT doesn’t do this very often,” said Dan Woodfin, the ISO’s director of system planning, of the appeal by staff. “I can’t recall [something like] this in my 13 to 14 years here.”

Woodfin based his case to the TAC on ERCOT’s changing resource mix since the ancillary service framework was built. Whereas ERCOT was 75% reliant on coal- and gas-steam energy in the late 1990s, half the current resource mix comes from gas turbines, combined cycles and renewables.

He said the current bundled framework will keep more expensive generation online, extend negative price periods and curtail less expensive resources, resulting in increased ancillary service prices and higher overall costs — especially with an increase in high-wind, low-load periods.

Ancillary service “was designed around the characteristics of those steam boilers,” he said. “We have a whole lot of new resources … that has changed both the needs and the ability of different resources to provide those services. We’re expecting the resource mix to continue to change. We’re seeing some pretty tremendous changes on wind in the system … solar is growing exponentially.

“[ERCOT’s current] ancillary service requirements … provide a barrier to entry to new types of resources that don’t have inherent characteristics of the old steam boilers.”

Woodfin pointed to The Brattle Group’s recent report on the ERCOT market, which he said found the ancillary service proposal to be a good, cost-effective market design. (See Brattle Study Sees ERCOT Continuing to Rely on Nat Gas, Renewables.)

Proposed Future Ancillary Services (ERCOT)“We don’t want to maintain barriers of entry for any technology,” said Frazier in questioning the benefit of ERCOT’s proposed changes. “It seems expensive to invest millions of dollars for new technology that would only bring in 200 MW.”

Frazier said several market participants (MPs) believed ERCOT’s estimated impact analysis of $12 million to $15 million was too low. She also acknowledged “the good work done in the last several years to think through the future resource mix.”

“We think there are also many MPs that believe there are incremental changes that can be made to the ancillary service suite that can deliver the value Dan mentioned,” Frazier said.

ERCOT was unfazed by losing its appeal of NPRR 667, which was first filed in November 2014 after a year of stakeholder discussions. Spokesperson Robbie Searcy said the ISO will continue its work with stakeholders to plan for future ancillary service needs.

“ERCOT continues to believe the concepts set forth in” the NPRR, she said. “As grid characteristics evolve, it is important that we are planning ahead to ensure we have appropriate market tools in place to maintain system frequency and overall reliability.”

NYISO Monitor: Modify Capacity Export Planning

By William Opalka

RENSSELAER, N.Y. — NYISO’s Market Monitoring Unit is recommending changes to the capacity market and planning processes in import-constrained zones as a result of a New York generating plant’s successful offers into the last two ISO-NE Forward Capacity Auctions.

NYISO Market Monitor: Modify Capacity Export PlanningPallas LeeVanSchaick of Potomac Economics outlined the recommendations in a presentation on the monitor’s 2015 State of the Market Report to the NYISO Management Committee meeting on Wednesday.

The changes would better account for capacity that is exported to neighboring control areas from import-constrained capacity zones, he said. “This is new this year and we see it as high priority.”

The Roseton 1 generator, a 1,242-MW dual-fuel generator in Newburgh, N.Y., sold 511 MW of capacity in ISO-NE’s FCA 9 for the 2018/19 commitment period and 532 MW in FCA 10 for 2019/2020. The plant will have simultaneous capacity obligations in New York and New England. Roseton 1 is in Zone G in the Lower Hudson Valley, which has been designated as import-constrained.

Potomac said rules were needed to prevent inefficient capacity prices and anticompetitive outcomes.

“If such rules are not devised soon, clearing prices will be set above competitive levels in the Lower Hudson Valley. Therefore, we recommend rules to account for these transactions that would ensure efficient pricing in NYISO’s capacity zones,” according to the report.

The monitor said planning for this now would reduce uncertainty regarding future prices and reliability.

“This would avoid the scenario where prices would be inflated in June 2018 by $40/kW-year” in zones G-J, (Lower Hudson Valley and New York City), LeeVanSchaick said.

Potomac said underlying principles of the adjustments should be that the capacity clearing price is equal to the value of the additional megawatts in the area and that the capacity payment is equal to the reliability value to NYISO.

It proposed:

  • Accounting for the reliability benefits provided by a Southeast New York resource that exports to another control area when clearing zones G-J;
  • Compensating exporters based on local/rest-of-state price differentials; and
  • Adjusting planning assumptions to recognize these benefits.

ISO Seeking Feedback on Potomac

Separately, NYISO will collect comments on Potomac’s performance until July 15 in its annual solicitation of market participant input.

Federal Briefs

The House of Representatives voted 241-178 to pass an amended version of the Senate’s Energy Policy Modernization Act of 2016, tacking on drought relief aid for California, among other provisions. The passage means the House can now enter a conference with the Senate to reconcile the two versions.

repfreduptonsourcegov
Upton

“This has been a multiyear, multi-Congress effort, and a lot of work has gone into making sure that the bill we put forward to support the future of American energy is truly comprehensive,” Rep. Fred Upton (R-Mich.) said.

The House’s version would make it more difficult for the federal government to use endangered fish species protections to increase the flow of water from California’s dams into the sea. Republicans say this practice wastes precious fresh water for humans in the drought-plagued state, while Democrats say the provision would damage fisheries.

More: The Hill

Obama Proposes Emissions Rules for Contractors

The Obama administration has put forward new rules that would mandate federal contractors disclose their greenhouse gas emissions.

The White House’s Federal Acquisition Regulation Council filed the proposals in the Federal Register requiring contractors to say if they disclose emissions numbers, if they have reduction goals and what effect climate change will have on business operations.

“We’ll be able to better assess supplier greenhouse gas management practices, manage direct and indirect greenhouse gas emission, address climate risk in the federal government’s supply chain and engage with contractors to reduce supply chain emissions,” White House officials said.

More: The Hill

Trump Vows to Undo Environmental Regulations

trumpsourcewiki
Trump

Donald Trump, the presumptive Republican presidential nominee, vowed to end President Obama’s Climate Action Plan, of which the Clean Power Plan is the centerpiece, within his first 100 days in office if he’s elected.

“Any regulation that’s outdated, unnecessary, bad for workers or contrary to the national interest will be scrapped and scrapped completely,” he said. “Any future regulation will go through a simple test: Is this regulation good for the American worker? If it doesn’t pass this test, this rule will not be under any circumstances be approved.”

Trump also said he would kill EPA’s Waters of the United States rule, “cancel” the Paris Agreement and ask TransCanada to apply again for the Keystone XL Pipeline.

More: Morning Consult

DOE: Keep Funding International Fusion Effort

ITERsourceITERAn Energy Department official said the U.S. should continue funding an international attempt to develop fusion technology, despite the project’s overruns and delays.

Franklin Orr, undersecretary for science and energy, says the U.S. government should increase its support for ITER, a magnetic fusion device being built in France and initiated by President Ronald Reagan in 1985. The department says the U.S. contribution needs to be $230 million in 2018, or $105 million more than it has budgeted.

If successful, ITER would be the first device to maintain fusion for long periods of time and develop more energy than it consumes. Thirty-five nations are now contributing to the project, whose price has escalated dramatically over decades of development.

More: Science

NRC Sets Sliding Fee Scale For Small Modular Reactors

nrcsourcegovThe Nuclear Regulatory Commission finalized rules that set a sliding fee scale for small modular reactors, aimed at encouraging development of the technology.

The annual fee for light water SMRs will be set according to how much heat they generate, according to the commission. The rules set a minimum fee, a variable fee and a maximum fee.

The commission said applying the same fee to smaller reactors that is applied to large reactors would be unfair, as smaller reactor designs pose a “lower regulatory oversight burden.”

More: Bloomberg

NRC Approves La Crosse License Transfer

lacrossenuclearsourcewikiThe Nuclear Regulatory Commission has approved the transfer of the license of the shuttered La Crosse Nuclear Plant in Genoa, Wis., to La Crosse Solutions, a subsidiary of radioactive waste disposal specialist Energy Solutions.

Dairyland Power Cooperative retired the plant in 1987 and filed with the commission last year to transfer the decommissioning and fuel storage license to La Crosse Solutions, which will lease the above-ground structures and assume decommissioning responsibility.

Energy Solutions has a similar arrangement with Exelon’s retired Zion nuclear plant in Illinois.

More: Nuclear Street

Environmental Groups Call for End to FERC Pipeline Review

penneastsourcepenneastNew Jersey opponents to the $1.2 billion PennEast natural gas pipeline project urged FERC to halt its review, contending the developers have failed to provide required information on the project.

The organizers of the 118-mile project, which would deliver 1 Bcf/d from the Marcellus Shale region in northeastern Pennsylvania primarily to New Jersey utilities, say they have provided all necessary information. “As PennEast moves through the FERC process, PennEast will continue to provide application information to FERC,” a company spokeswoman said.

The project has aroused organized opposition, especially in New Jersey, where opponents say 70% of the property owners along the proposed path refused to allow PennEast to survey their land, and municipalities have passed resolutions opposing it.

More: NJ.com

FERC Fines Coaltrain $37.5M For Sham UTC Trades

FERC last week fined Coaltrain Energy and its owners $37.5 million for fraudulent up-to-congestion trades in PJM.
It also demanded the company disgorge $4.1 million in unjust profits. (See Traders Deny FERC Charges; Seek Independent Review.)

Coaltrain attorney Ken Irvin, of Sidley Austin, said the order “reflects the flawed process FERC uses and reiterates the need for our judicial system to impose the rigors due process provides. With ample transparency and cooperation on our part, we have shown compliance with the market rules and regulations. Our confidence remains that we have proven our case before FERC and will prove it in court too.”

More: IN16-4

Order 719: FERC Balanced MMU Independence Against RTO Autonomy

After allegations of management interference led PJM to replace its internal market monitoring unit with an independent monitor in 2008, FERC had an opportunity to prohibit other RTOs from using the internal structure. Because it chose not to do so, the temptation for RTO officials to muzzle their MMUs still exists.

First in a Series

By Rich Heidorn Jr.

The independence concerns raised by former SPP market monitors John Hyatt and Catherine Mooney resulted in part from FERC’s compromises in Order 719, its 2008 rule spelling out market monitoring units’ duties and their relationships with their RTOs (RM07-19, AD07-7). (See related story, SPP Squelching MMU Independence, Former Monitors Say.)

FERC HQ (Copyright RTOInsider) - Order 719 - FERC Balanced MMU IndependenceFERC said the rules, which updated a 2005 policy statement, were needed to “improve the performance and transparency of organized RTO and ISO markets.” They prohibited RTO management from supervising their MMUs, and required, in most instances, that MMUs report directly to their RTOs’ board of directors.

But the commission rejected protections urged by some stakeholders — allowing RTOs to choose their structures and declining to provide job security protections for MMU employees.

RTO Choice on Structure

The commission allowed each RTO to decide through its stakeholder process whether it will have an external or internal MMU, or a hybrid structure using both. FERC also declined to remove MMUs from any oversight by the RTOs.

The commission ruled that the RTO boards would supervise market monitoring functions and that RTO management representatives on the board “be excluded from this oversight function.” However, it permitted MMUs to report to management “for administrative purposes, such as pension management, payroll and the like.”

“Removing the MMU from reporting to management will give it the separation needed to foster independence,” the commission said, promising to revisit the decision “if occasion demands.” However, it declined to conduct periodic reviews, as requested by the Federal Trade Commission.

Both internal and external monitors can face conflicts of interest, the commission noted. As the market operator, the RTO is one of the players a monitor is expected to critique. So are market participants, who are essentially the RTO’s constituents, with the ability to leave or switch RTOs.

Inherent Tension

Order 719 acknowledged this, citing the “inherent tension between [market] mitigation and the RTO or ISO goal of promoting new markets.”

An external monitor that is too critical could find itself unemployed when it comes time to renew its contract. In 2013, some PJM board members considered seeking a new monitor before state regulators pressured them to renew the RTO’s contract with Monitoring Analytics.

An internal MMU, on the other hand, can face peer pressure and management interference.

The commission also rejected a proposal by the American Public Power Association, Exelon and the Pennsylvania Public Utility Commission that it use the settlement that created PJM’s independent monitoring structure as a “best practice.”

“The provisions of that agreement were specific to one RTO and represented a negotiated balancing of interests,” the commission said. “It would be inappropriate to impose the specifics of that settlement on all other RTOs and ISOs.”

Core Duties

The Transmission Access Policy Study Group, an association of transmission-dependent electric utilities in 35 states, recommended that the “core” MMU duties — reviewing market performance, identifying ineffective market rules and making confidential referrals to the commission — be assigned exclusively to the external monitor in hybrid structures.

FERC disagreed.

“This solution might impose upon the RTO or ISO an MMU structure that it does not want,” the commission said, insisting its requirement that the monitors performing the core functions report to the board was sufficient. “This solution allows the RTO or ISO to structure its MMU function in the way it deems most suitable, while also ensuring that the market monitor that performs the core MMU functions enjoys the independence from management that reporting to the board accomplishes.”

It also rejected the Public Utility Commission of Ohio’s proposal that monitors report to a federal-state board independent of both the management and boards of RTOs. “Not only does an arrangement of this type raise jurisdictional concerns, it is difficult to see how such a potentially cumbersome structure could oversee MMUs in a timely and responsive manner. … Should the reforms we adopt in this final rule fail to achieve the needed independence we envision for MMUs, we will not hesitate to rectify the situation.”

Employee Protections

Some commenters proposed that major changes in MMU status, such as termination of employment, be subject to FERC review, a requirement included in the contracts that PJM, MISO, ISO-NE and SPP (which then had a hybrid structure) signed with outside monitors. The commission, however, said it did not want to impose “a ‘one size fits all’ requirement on the remaining RTOs or ISOs absent their consent.”

“Should the situation arise in which an RTO or ISO terminates its MMU in such a way as to violate its tariff requirements concerning MMU independence, the commission will address such a violation on a case-by-case basis,” it said.

Order 719 in Summary

Below is a summary of Order 719’s requirements. Except in direct quotations, this article will use “RTOs” or “grid operators” to refer to RTOs and ISOs.

Functions

The commission limited MMU functions to three: evaluating the effectiveness of market rules, tariff provisions and market design elements (and proposing changes where needed); reporting on market performance; and referring suspected wrongdoing to the commission.

It also broadened the monitors’ reporting duties — requiring them to refer to the commission any misconduct by the grid operators as well as by market participants — and expanded their referral obligations to include market design flaws in addition to tariff and rule violations.

RTO Review of MMU Reports

FERC said RTOs may require their MMUs to submit reports in draft form for RTO review and comment but could not alter the reports “or dictate the MMU’s conclusions.”

“RTOs or ISOs need not require submission of draft reports, but if they do, input from knowledgeable employees may serve to strengthen the end product or catch errors of fact or reasoning,” the commission said. “In any event, the MMU is free to disregard any suggestions with which it disagrees.”

APPA opposed giving RTOs advance review of MMU reports, saying FERC should impose the same prohibition against such review as was included in the PJM-MMU settlement. The settlement resulted from Monitor Joe Bowring’s complaint at a FERC technical conference in 2007 that PJM ordered him — then a PJM employee — to modify the State of the Market Report and delayed the release of another MMU report because management disagreed with his conclusions.

Market Mitigation Role

The market mitigation role of external MMUs was limited to retrospective mitigation and the calculation of inputs required for the RTOs to conduct prospective mitigation. The separation was made because of concerns that an MMU would have a conflict of interest in proposing prospective market mitigation and then opining on how the resulting market rules worked. It also separated the duties of internal and external MMUs for RTOs with hybrid structures.

In its Notice of Proposed Rulemaking, FERC proposed that MMUs be removed from tariff administration, including market mitigation, “to free MMUs from a role that might make them subordinate to the RTO or ISO.” The proposal “engendered heated disagreement” by commenters, the commission said.

SPP, the Electric Power Supply Association, some industrial customers and several utilities supported the commission’s proposal. But more commenters opposed it, including Potomac Economics, other industrial customers and utilities, the Organization of MISO States, the National Association of Regulatory Commissioners and regulators from California, Maine, New York and Ohio.

The opponents said RTO officials who have designed and implemented the markets — and whose compensation may be based on market growth — may have a greater conflict of interest than the MMU. As FERC described the argument, RTOs would be disincented from imposing enforcement measures “on what in effect are their customers, or in refraining from mitigating a member that threatens to leave the RTO or ISO.”

FERC said it took seriously comments that “the MMU serves as a useful buffer between the RTO or ISO and the market participants, performing what is often viewed as a hostile act.”

Ultimately, the commission chose a compromise that it said “strikes the appropriate balance between allowing modified participation by the MMUs in mitigation, while protecting against the conflict of interest and subordination inherent in their unfettered participation.”

The commission said RTOs may allow their MMUs to conduct retrospective mitigation because it is only prospective mitigation — that which can affect market outcomes on a forward-going basis, such as altering the prices of offers —  that creates a potential conflict of interest for an MMU.

The commission also said the MMU may provide inputs required by the RTO to conduct prospective mitigation, including determining reference levels, identifying system constraints and calculating costs.

Information Sharing

The order required MMUs to report on market performance at least quarterly to commission staff, state commissions and RTO management and boards. MMUs must conduct regular conference calls for FERC, state commissions and RTO staff, as well as market participants.

It cut the lag time for the release of offer and bid data to three months from six but allowed RTOs to propose a shorter period — or, if the RTO demonstrates a collusion concern, it may propose a longer lag. The identity of market participants remained masked, although RTOs were permitted to propose a time period for eventual unmasking.

Requests for Information

State commissions were permitted to make “tailored” requests for information from the MMUs, limited to information regarding general market trends and the performance of the wholesale market. “If this limitation were not imposed, the MMU could rapidly become an unpaid consultant for the states, and would be unable to perform its core functions,” the commission said.

PJM Markets and Reliability Committee Briefs

Barry Trayers of CitiGroup Energy won endorsement from the Markets and Reliability Committee for his proposal to add an acceptable reason for early capacity replacement to Manual 18: PJM Capacity Market.

After Trayers agreed to remove the words “wind” and “solar,” the motion passed with three objections and six abstentions.

The change adds the following as an acceptable reason for early replacement: “If the replacement resource’s capacity is not affected by its outage rate, such as cleared incremental auction buy bids, the replacement transaction can be completed at any time.”

“The reason is the deal’s already done,” Trayers said. “There’s a sale and a purchase, and you’d like to merge those in your portfolio and know where you stand.”

End of Life Senior Task Force has New Name, Charter

Members approved a charter for the Transmission Replacement Process Senior Task Force, previously referred to as the End of Life Senior Task Force.

The group will be tasked with developing ways to provide more transparency and consistency in the communication and review of end-of-life projects in the Regional Transmission Expansion Plan. (See PJM TOs Oppose Proposal to Develop End-of-Life Criteria.)

New Issue for Energy Market Uplift Senior Task Force

virtual transactions - PJM Markets and Reliability Committee BriefsThe committee approved revisions to the Energy Market Uplift Senior Task Force charter to incorporate a problem statement and issue charge regarding the review of virtual transaction rules.

The group will study biddable nodes and the application of uplift and determine whether recommendations from PJM’s
October 2015 white paper on virtual transactions should be implemented. (See PJM Suggests Changes to Virtual Transactions.)

PJM is awaiting a related FERC order on whether up-to-congestion trades will be charged uplift and made subject to the RTO’s financial transmission rights forfeiture rule (EL14-37). (See FERC Issues Request for Comments in UTC Uplift Docket; Ruling by October?)

Stricter Standards OK’d for Project Queue Submittal

Members approved the Earlier Queue Submittal Task Force’s recommended Tariff revisions, which would require earlier submittal of documentation in order for projects to secure a place in the interconnection queue.

The revisions will be presented for endorsement to the Members Committee at its June 30 meeting. (See “New Project Submittal Process to Require Earlier Filing of Documents,” PJM Planning Committee and TEAC Briefs.)

Tweaks to DER Problem Statement OK’d

Members approved clarifications to the previously approved distributed energy resources problem statement. (See “Faster Path to Market for Distributed Resources to be Studied,” PJM Markets and Reliability Briefs.)

The changes recast the entry of distributed resources into the PJM market as having “unique challenges” instead of being “cost-prohibitive and time-consuming.”

Members Hear First Reads on PLS, Tx Equipment Upgrades

  • Members heard the first read of a proposal to update the parameter limited schedule exception process to permit more flexibility.
  • Paul McGlynn, senior director of planning, presented a first read of a proposal to except transmission substation equipment upgrades from the competitive window. (See “Typical TO Upgrades Would be Excluded from Competitive Window Under Proposal,” PJM Planning Committee and TEAC Briefs.)

Real-Time Values Added to Manual 11

The committee approved changes to Manual 11: Energy and Ancillary Services Market Operations that incorporate real-time values.

The changes allow a market seller to communicate a unit’s actual operating parameters to PJM before and after the day-ahead market closes when the unit cannot operate for certain reasons.

The language stipulates that real-time values may be used to modify the turn-down ratio, minimum run time, minimum down time, maximum run time, start-up time and notification time, and they can be made whole due to an actual constraint.

Committee Unanimously Endorses Manual Changes

The following manual changes were approved Thursday:

Suzanne Herel

MISO, PJM Working to Comply with NIPSCO Order

By Amanda Durish Cook

MISO last week presented a plan to address FERC’s order in an ongoing dispute over its seam with PJM, even as the RTOs and other parties sought rehearing on the ruling.

NIPSCO territory map w tx lines (NIPSCO) - MISO PJMThe RTOs have until June 20 to submit a compliance filing in response to an April 21 order in which the commission partially denied and granted a 2013 complaint by Northern Indiana Public Service Co. regarding the two RTOs’ interregional planning (EL 13-88). (See FERC Orders Changes to MISO-PJM Interregional Planning.)

At a Joint and Common Market meeting last week, MISO said the RTOs will work together to create “step-by-step deadlines” for a coordinated system plan in their joint operating agreement (JOA) by the filing deadline. By mid-August, the RTOs will align their respective annual transmission project packages — MISO’s Transmission Expansion Plan and PJM’s Regional Transmission Expansion Plan.

As ordered by FERC, MISO will also:

  • Lower its interregional project voltage threshold to 100 kV;
  • Eliminate the $5 million cost threshold for interregional projects;
  • Remove its interregional cost-benefit analysis; and
  • Work with PJM to incorporate interconnection coordination procedures from their respective business practice manuals into the JOA.

“With the order, FERC required a lot of MISO,” Planning Advisory Committee Chair Bob McKee said during last week’s Steering Committee meeting.

PJM’s Chuck Liebold said the RTOs continue to work together on a targeted market efficiency project study that would identify quick, low-cost upgrades to alleviate congestion, while simultaneously adding JOA language that incorporates the study process.

The RTOs and SPP are also seeking alternatives to the April 1, 2004, “freeze date” for determining firm rights on flowgates based on flows before they instituted their current markets. The RTOs plan to develop a solution and file Tariff revisions by the fourth quarter, with implementation expected by next June.

MISO is also seeking stakeholder input on how to implement a new joint model that uses the same assumptions and criteria in the regional processes for both RTOs.

“The rest of the order didn’t order stakeholder involvement, but we certainly want some input,” said Eric Thoms, MISO’s manager of planning coordination.

Rehearing Requests

Last week, NIPSCO, MISO, PJM and others filed requests for rehearing of FERC’s order.

NIPSCO asked the commission to reverse its decision disallowing use of market-to-market payments as an alternative justification for interregional projects. It also wants FERC to impose a timeline on market efficiency project analyses.

“NIPSCO appreciates the commission’s attention to seams issues to date, but respectfully requests that the commission ‘hold the RTOs’ feet to the fire’ regarding the significant compliance efforts that remain,” the company wrote in its request.

The Organization of MISO States argued that the new 100-kV threshold for interregional economic transmission projects is unjust and unreasonable. The group contends there is no “substantial” evidence that projects above 100 kV but below 345 kV can provide benefits broad enough to justify a 20% load ratio cost allocation across MISO’s footprint.

“Any such change would require an appropriate process that includes substantial stakeholder input and engineering studies to support any changes,” OMS said.

MISO Transmission Owners asked FERC to revisit its decision to lower the voltage threshold and eliminate the $5 million cost threshold for interregional economic transmission projects. The TOs say that in ordering the changes, the commission “inappropriately relies on the results of MISO and PJM’s quick hit analysis, which utilizes different planning criteria and inputs than MISO and PJM utilize for identifying and evaluating interregional market efficiency projects.”

MISO asked FERC to reconsider a decision to eliminate the interregional benefits-to-costs analysis — also known as the joint metric — claiming the commission provided no explanation for the move. The RTO also contends that the joint metric “is not a hurdle and is needed to harmonize regional benefits calculations and prevent gaming.”

PJM asked the commission to clarify whether it meant for the RTOs to eliminate the current 1.25-to-1 benefit-to-cost ratio on interregional projects. Determining a cost split using separate regional metrics “will result in significantly different benefit values for the same project,” the RTO said.

Oversight of Smart Meter Data Debated at ERCOT

By Rory Sweeney

AUSTIN, Texas — ERCOT’s Technical Advisory Committee last week continued the debate over who should be responsible for Texas’ largely unused smart meter monitoring  website.

The website, which allows authorized parties to access individual consumers’ electricity-usage data, has been operated from its inception by Smart Meter Texas (SMT), an entity created by a coalition of transmission and distribution utilities. For the past two years, the state Public Utility Commission has been considering whether to transfer oversight of the website to ERCOT. The coalition, along with several other industry and advocacy groups, has supported the move. The ISO, with support from the state Office of Public Utility Counsel, has resisted the responsibility, citing technical and financial hurdles.

At the TAC meeting last week, the main concern was the potential impact on ERCOT’s budget and administrative fees.

TAC Chairman Randa Stephenson, of the Lower Colorado River Authority, asked for a synopsis from an ERCOT workshop earlier in the week that had focused on the potential transition. Mark Ruane, ERCOT’s director of settlements, retail and credit, explained that the PUC has been looking at data-flow projections if the ISO were to take over the website. Attendees at an April PUC meeting agreed to a “high-level” concept, he said, in which ERCOT would provide settlement data to the web portal rather than take control of the portal itself.

Cost Information Sought

The goal of last week’s workshop was to decide the scope of the project. Attendees left saying they needed more information on the likely costs versus the potential benefits. The PUC plans to take up this issue again at its June 9 meeting.

CenterPoint Energy’s Kathy Scott, chair of the Retail Marketing Subcommittee, said that the subcommittee has asked competitive retailers to detail what functionality they’d want to see from both ERCOT and SMT if the ISO takes over operation of the web portal. CenterPoint is one of the utilities that runs SMT. She said committee members and the competitive retailers will meet after the June PUC meeting to determine how to move forward.

Stephenson asked that updates to the process be included in future RMS reports.

Eric Goff, of Citigroup Energy, noted that SMT is funded through rate surcharges and asked whether there are legal mechanisms to direct some of that funding to ERCOT for taking on the responsibility.

Scott said it’s likely within the PUC’s purview to decide on the allocation.

Website Usage Low

Perhaps a larger question is what should be done with the website. Scott highlighted statistics showing that the site has about 68,000 registered users. That equals a little less than 1% of the more than 7 million customers who have smart meters installed and could be using the site.

Additionally, according to a 2014 report by the South-central Partnership for Energy Efficiency as a Resource (SPEER), it’s just 8,000 more users than the site had two years ago.

Connecting to the website is supposed to enhance the usefulness of energy-saving “home area network” (HAN) devices, but the statistics showed that consumers who purchase them aren’t continuing to use them. While the 2014 SPEER report noted 12,000 HAN devices being used throughout ERCOT’s territory, Scott reported last week that only about 9,700 were still in use as of March.

Concerns have also been raised about SMT’s privacy and data protection. At May’s RMS meeting, representatives of consumers and several investor-owned utilities abstained from voting on two measures that would allow using SMT to submit information from small generation sources, such as rooftop solar arrays. The IOUs questioned whether providing generation data violated customers’ privacy.

Quicker Processing

The TAC also voted to endorse retail market guide revision request (RMGRR) 136, which is meant to help the market process documents quicker by clarifying the procedures for removing holds on switching customers’ retail providers. Holds can occur when a customer has an outstanding balance or the provider believes the meter has been tampered with.

The TAC also endorsed RMGRR 137, which would create a timeline for correcting inaccurate customer billing information.

Additionally, the final review has been performed for system change request 786, which sets “retail testing environment” business requirements. ERCOT has assigned it project number 192-01.

Finally, Scott noted that a draft nodal protocol revision request (NPRR) is being developed that may replace RMGRR 132 or require it to be rewritten. With the help of Oncor’s Taylor Woodruff, Tom Burke of Amarillo-based Golden Spread Electric Cooperative will guide the new NPRR through the stakeholder process.