Will an Old Utility Learn New Tricks?

Dominion Virginia Power last week won the rights to develop Virginia’s “Wind Energy Area,” nearly 113,000 acres of Atlantic Ocean with the potential to support 2,000 MW of offshore wind generation. But Virginia’s largest utility is making no promises that it will exploit the resource.

“Offshore wind has the potential to provide the largest, scalable renewable resource for Virginia,” the company said in a statement after the auction, “if it can be achieved at reasonable cost to customers.”

That’s a big “if.” The company’s proposed Integrated Resource Plan, filed Aug. 30 with the Virginia State Corporation Commission, commits it to developing only a 12 MW offshore demonstration project. The base 15-year plan, which commits virtually all of its new generation to natural gas, ranked offshore wind as the most expensive of the non-dispatchable resources the company considered, far more expensive than solar or onshore wind.

Dominion estimated a plan incorporating up to 1,600 MW of offshore wind would cost about 14% more than its base plan. This includes an assumption by Dominion that a carbon tax will be enacted by 2023, increasing the cost of generating power with coal and natural gas.

Average Costs of Natural Gas vs. Wind (Source: Energy Information Administration) — (Source: Energy Information Administration)

The Energy Information Administration estimates the levelized cost of offshore wind at $221/MWh (2011 dollars), more than twice the $87/MWh cost of onshore wind. By comparison, EIA estimates the cost of power from new natural gas-powered combined cycle plants favored by Dominion at $66/MWh.

No Renewable Incentives

The high costs will be a particular challenge in Virginia. The state does not have a mandatory Renewable Portfolio Standard, and unlike Maryland and New Jersey, is not offering any subsidies to encourage offshore wind developers. It also does not allow retail choice, which could create a niche for a green alternative. (See previous coverage: PJM States Seek ‘First Mover’ Status.)

Dominion outdueled competitor Apex Virginia Offshore Wind, LLC in six rounds of bidding conducted by the Interior Department’s Bureau of Ocean Energy Management (BOEM). Six other companies that were prequalified for the auction chose not to bid. One of them, Iberdrola Renewables, told RTO Insider it decided to focus on bringing its pipeline of “more competitively priced” onshore wind projects to market.

Dominion’s $1.6 million bid won it the rights to 112,799 acres on the Outer Continental Shelf, 23.5 nautical miles off Virginia Beach. Assuming it passes an antitrust review by the Justice Department, the company will have five years to submit a Construction and Operations Plan for BOEM’s approval. Including review by state rate regulators, Dominion said it will be a decade before the first turbine could be installed.

Wind Backers Disappointed

Dominion’s victory was a disappointment to environmentalists. Beth Kemler, Virginia State Director at the Chesapeake Climate Action Network, said the company’s IRP “doesn’t leave us with high hopes for Dominion’s speedy development of this clean energy resource.”

“While Dominion came out on top …that unfortunately doesn’t guarantee that the company will actually erect a single turbine. The company could rent the wind energy area for years without moving forward with any development, preventing a more eager company from doing so,” she said.

Dominion spokesman Dan Genest noted that Dominion cannot add new generation without approval of Virginia regulators, who must judge it “prudent.”

“Anything we present as a generation project has to meet the price test,” he said. “To say we’re going to build wind at any cost — the state corporation commission is not going to allow us to do it.”

Genest said the purpose of the company’s demonstration project is to “find ways to make [offshore wind] affordable.”

Demonstration Project

The project, two six-megawatt turbines, will test the use of “twisted jacket” foundations that offer the strength of traditional structures but use substantially less steel. It was one of seven projects awarded $4 million each in federal matching funds to explore ways to lower costs of offshore wind.

Chesapeake Action’s Kemler said another bidder that is not a cost-of-service utility might be willing to develop the site as a merchant project. Other offshore projects under development in Rhode Island, Massachusetts, New Jersey and Maryland hope to finance them through state subsidies, purchase power agreements and the sale of credits tied to mandatory Renewable Portfolio Standards.

Although Virginia has no mandatory RPS, Dominion says it will meet a voluntary goal to obtain 15% of its power from renewables by 2025. Excluding pump storage, renewables represent 3% of Virginia Power’s capacity.

“The legislative climate in the Northeast is a lot friendlier to renewables,” than Virginia, Kemler acknowledged. “But there are certainly plenty of states in PJM that have mandatory RPSs” that might be buyers of offshore wind.

Integrated Resource Plan

Virginia law requires utilites’ Integrated Resource Plans to “promote reasonable prices, reliable service, energy independence, and environmental responsibility.”

Dominion’s recommended expansion plan predicts annual increases in peak demand of 1.6% through 2028. It’s base “least-cost” plan proposes that the company add up to 7,060 MW of new gas-fired generation and 59 MW of solar and biomass, with 544 MW of demand-side management. Also included are PJM market purchases representing 127 MW of capacity and 12% of energy.

In addition, the company developed a higher-cost, lower-emission “fuel diversity” plan that could be needed to respond to potential federal rules restricting greenhouse gases.

It would eliminate one 1,375-MW combined cycle plant, and add 1,453 MW of nuclear power — a third unit at the company’s North Anna facility. Renewables are limited to 220 MW of solar, 247 MW of onshore wind and the 12 MW offshore wind demonstration project. PJM market purchases would increase to 173 MW of capacity.

The company notes that its onshore wind assets are limited to three mountaintop locations in western Virginia. By contrast, the National Renewable Energy Laboratory estimates Virginia has a “technical potential” of 89 GW of offshore wind capacity.

NREL’s estimates don’t consider economic or market constraints that will reduce actual renewable generation. The 2,000 MW “Wind Energy Area” was mapped out by BOEM to avoid conflicts with other ocean uses such as commercial fishing and shipping traffic.

September 10, 2013

Federal Briefs

If Democrats backing a carbon tax agree to use the revenue to reduce personal and corporate income taxes, congressional Republicans could sign on, says Harvard economist N. Gregory Mankiw, who served as chairman of the Council of Economic Advisers under President George W. Bush. Most economists agree a carbon tax is a less expensive way to reduce carbon dioxide emissions than current federal policies, such as the corporate average fuel economy (CAFÉ) standards for automobiles.

More: The New York Times

NRC Seeks Comment on Yucca Mt. Spending

The Nuclear Regulatory Commission is seeking public comments on how to spend the remaining $11 million in its budget for licensing a nuclear waste repository at Yucca Mountain. The project has been in limbo since 2011 due to opposition from Congress and the Obama administration. On Aug. 13, however, the U.S. Court of Appeals for the District of Columbia ordered the NRC to continue the work required to issue a decision on licensing the facility.

More: NRC

Enviro Groups Seek to Resurrect CSAPR

Environmental groups urged the Supreme Court to revive the Environmental Protection Agency’s Cross-State Air Pollution Rule (CSAPR), saying that a lower court’s nullification would prevent regulators from ever tackling unhealthy power plant emissions that cross state lines. The lower court ruling “would force EPA to follow unworkable judicial algorithms that Congress never enacted,” the Environmental Defense Fund, the American Lung Association and others said in a brief filed Wednesday.

The Supreme Court agreed in June to review the appellate decision vacating the 2011 regulation. The rule would force cuts in smog- and soot-forming power plant emissions in more than two dozen states in the eastern half of the country.

More: The Hill

Solar Panels Reinstalled at White House

Re-installing Solar Panels on The White House Roof (Source: The White House) — (Source: The White House)

Three years after the Obama administration announced plans to return solar power to the White House, workers have completed the installation. President Jimmy Carter had solar panels installed on the White House roof in the late 1970s for heating water. They were removed during a roofing job in 1986 under President Ronald Reagan.

More: Greentech Media

September 10, 2013

Electric Power Emissions: 29,000 Deaths/Year in PJM

Air pollution from electric generation is responsible for more than 29,000 premature deaths annually in PJM states, more than any other air pollution source, according to a new study by researchers at the Massachusetts Institute of Technology.

Map of Average Annual Ground Particulate Concentration from Electric Generation (Source: MIT) — (Source: MIT)

The study found that fine particulates (PM_2.5) and ozone pollution from electric generation caused 52,000 deaths in the continental U.S. annually, second only to the 53,000 deaths attributed to tailpipe emissions from autos. Within PJM states, auto pollution was second, responsible for more than 23,000 premature deaths.

All told, including other emission sources, such as industrial smokestacks, commercial and residential heating and cooking and marine and rail transportation, air pollution is responsible for 200,000 deaths annually, the study found.

Coal-burning Kentucky, West Virginia and Ohio had the highest electric generation mortality rates in PJM, with Kentucky’s 40.2 deaths per 100,000 population nearly double the rate for New Jersey (22.2). New Jersey has a higher overall death rate, however due to higher impacts from autos, shipping and commercial and residential emissions.

Among cities, the Baltimore metropolitan area ranked worst, with an annual mortality rate of 130 per 100,000 due to high emissions from power generation, autos and industry.

Persons who die from an air pollution-related cause typically have about a decade cut from their lifespan, according to Steven Barrett, an assistant professor of aeronautics and astronautics who was one of the authors of the study.

The researchers found that the impact of auto emissions was highest in densely populated areas while power plants emissions, which are deposited at a higher altitude, were more dispersed.

Premature Deaths by State from Electric Generation Emissions (Source: MIT) — (Source: MIT)

The highest electric generation-related death rates were in the east-central U.S. and Midwest, which researchers suggested was due to the burning of coal with higher sulfur content than burned in the west.

The Environmental Protection Agency estimates that 74 million people in the U.S. are exposed to levels of PM

_2.5 higher than permitted by the Clean Air Act and that more than 131 million live in regions not compliant with ozone limits. The EPA computed the costs for the implementation of the 1990 Clean Air Act to be about $65 billion from 1990 to 2020, potentially avoiding 230,000 premature deaths in 2020.

The MIT researchers based their study on data from EPA’s National Emissions Inventory. The results were published in the journal Atmospheric Environment.

September 10, 2013

NRC Plant Rating Methodology

NRC 2013 Mid-Year Assessments (Source: NRC) — (Source: NRC)

The NRC grades each reactor based on data submitted quarterly by plant operators (“performance indicators”) and inspections by resident inspectors and regional staff. Its mid-year assessment places each operating unit within one of four levels of regulatory response, with the agency’s scrutiny increasing as plant performance declines:

The top-rated plants, judged to be meeting all of the agency’s objectives, are subject to the “baseline” inspection program.
Plants with no more than two white findings — indicating problems causing minimal reductions in safety margin — fall into the second category, subjecting them to additional inspections and oversight by NRC regional officials.
Reactors with “degraded” performance, for example those receiving a yellow finding indicating a moderate reduction in safety margin are subject to higher scrutiny, including involvement of senior regional officials.
NRC headquarters officials take part in scrutiny of plants with multiple yellow findings or a red finding, indicating a significant reduction in safety margin.
Not Operating: Plants with unacceptable reductions in safety margins are not permitted to operate and may have their licenses revoked.

September 3, 2013

MRC Considers Changes to Wind Capacity Calculations

The Markets and Reliability Committee Thursday reviewed two alternatives to protect wind generators from being assigned artificially depressed capacity values due to curtailments ordered by PJM. The committee will be asked to approve one of the alternatives at its next meeting.

Under current policy, when wind generators are curtailed by PJM for any portion of a peak summer hour (2-6 p.m.), the entire hour is excluded from the generator’s capacity calculation.

Under Alternative 2, state estimator data would be used to interpolate output for each five-minute period with curtailments. Under Alternative 3, forecast data from PJM operations — which is currently used for lost opportunity cost calculations — would be used for curtailment periods.

Impact of Alternative 2 & 3 on Curtailed Units (Source: PJM Interconnection, LLC) — (Source: PJM Interconnection, LLC)

Both options would use metered data for all hours without curtailments. Units with no curtailments over peak summer hours would not be affected by either option.

The Planning Committee last month approved Alternative 2 by a 101-23 margin, making it the primary option MRC will consider Sept. 26. The MRC also can select Alternative 3, which was approved more narrowly, 68-40. (See Planning Committee OKs Relief for Wind Generators.)

PJM’s Tom Falin said Alternative 2 may be more accurate for short curtailments while Alternative 3 is more accurate for long curtailments. “The most important curtailments are the long ones,” Falin said. “They’re going to impact the average more than a five-minute interruption.”

An analysis released by PJM showed that Alternative 2 would have increased ratings for 21 wind generators with 12 reduced and two unchanged. Alternative 3 increased ratings for 24 generators and reduced them for 11. (See chart)

Any new procedure approved by would be applied to summer 2013 data when capacity credit calculations are finalized in December 2013.

September 3, 2013

MRC First Readings

The following issues generated little or no discussion among members when they were brought before the Markets and Reliability Committee for first readings Thursday. The issues will be brought to a vote at the next MRC meeting Sept. 26.

Below are brief descriptions of the issues along with their agenda numbers and links to prior coverage in RTO Insider.

6. COORDINATED TRANSACTION SCHEDULING

MRC will be asked to approve a new product for scheduling trades between PJM and the New York ISO.

Under the current system, power often flows from PJM into New York even when PJM’s prices are higher. The new product, Coordinated Transaction Scheduling (CTS), is intended to reduce uneconomic power flows between the two regions. Traders would be able to submit “price differential” bids that would clear when the price differences between New York and PJM exceed a threshold set by the bidder.

PJM officials had planned to ask the Market Implementation Committee to endorse the proposal Aug. 7 but postponed a vote to provide answers to members’ questions.

Addressing one of the questions that came up before the MIC, PJM’s Rebecca Carroll told MRC Thursday that PJM does not expect the new product to have any impact on balancing congestion, which results because of a change in transmission system capability between the day-ahead and real-time markets. (Negative balancing congestion occurs when the real-time transmission system cannot accommodate all the transactions scheduled day ahead; positive balancing congestion occurs when the real-time transmission capability increases above what was available day ahead.)

Carroll said the scheduling of external interchange transactions won’t affect transmission capability.

(See PJM, NYISO Tout New Option to Improve Power Scheduling.)

7. SYNCHRONIZED RESERVE (SR) PERFORMANCE

PJM and the Market Monitor will seek a vote on a joint proposal to boost penalties for resources that fall short of their synchronized reserve commitments. The measure, intended to address concerns that the current penalty structure is insufficient to ensure compliance, stalled at the Operating Committee in August as utilities called for more details. (See Bid to Boost Synch Reserve Penalties Stalls at OC.)

9. EFFICIENCY OF DEMAND RESPONSE REGISTRATION PROCESS

MRC will be asked to choose among three proposals for streamlining the demand response registration process. Current rules require Curtailment Service Providers to submit customer names to both the Electric Distribution Company and Load Serving Entity. The LSE’s role in the process has been largely eliminated as a result of FERC Order 745. (See PJM Proposes Streamlined DR Registration.)

10. ENERGY MARKET UP-LIFT SENIOR TASK FORCE (EMUSTF) CHARTER

MRC will be asked to vote next month on a charter for the Energy Market Uplift Senior Task Force. The task force was created by MRC May 30 to conduct a broad review of its method of providing operating reserve payments. PJM said changes are needed to reduce growing uplift costs. (See MRC Approvals 5/30/13; PJM Proposes Operating Reserve Changes to Cut Uplift.)

12. PJM MANUALS

A. Manual 12: Energy and Ancillary Market Operations and Manual 27: OATT Accounting.

Reason for changes: The changes conform to new policies developed by the System Restoration Strategy Task Force on black start generation, critical load and restoration plans.

PJM will lose some existing black start capacity as a result of pending coal plant retirements. The changes are intended to increase the pool of potential resources. Tariff changes reflecting the new policies were filed with FERC July 9 (ER13-1911).

Impact: Affected are manuals 12 and 27:

Section 7 of Manual 27 allows the cost of cross-zonal black start units to be allocated to multiple zones based on transmission owners’ critical load share.
Section 4.6 of Manual 12 governs the number of critical units in a zone and the ratio of black start generation to critical load in a zone. It also eliminates a restriction on the number of black start units at a station, allows units to provide service outside their zone and changes the time in which a unit must close to a dead bus.

PJM contact: Tom Hauske

B. Manual 01: Control Center and Data Exchange Requirements.

Reason for changes: The changes are necessary to comply with NERC Standard BAL-005-0.2b — Automatic Generation Control.

Impact: Creates a new tie line cut-in process requiring telemetry be in place prior to energization. Includes major changes to Section 5.3.5 (Tie Line Telemetry Specification) to provide more detailed requirements for Tie Line Telemetry and Attachment B to remove redundant text and streamline table. EOP-005-2 and EOP-008-1 requirements are updated.

PJM contact: Chris Smart

September 3, 2013

Company Briefs

FirstEnergy Corp.’s nuclear operating company will meet with the Nuclear Regulatory Commission Sept. 5 after security forces at the company’s Beaver Valley nuclear plant apparently failed part of a routine “force-on-force” exercise in April.

More: The Plain Dealer

PPL to Sell Power Plants to NorthWestern Energy?

An environmental group asked Montana regulators for documents that may indicate whether PPL Montana is in talks to sell several power plants to NorthWestern Energy. PPL Montana, which owns 11 hydroelectric plants and several coal-fired plants, and NorthWestern, Montana’s largest electric utility, have refused to comment on rumors of a possible sale.

More: The Missoulian

NRG May Follow DR Buy With More Renewables

NRG Energy Inc., the largest independent U.S. electricity generator, may further expand its clean-energy portfolio after its purchase of Energy Curtailment Specialists Inc., an analyst said. NRG announced the purchase of Energy Curtailment in a statement without giving a price. Energy Curtailment manages more than 2 GW of demand response for at least 5,000 customers.

“We see the transaction as among a series of other potential moves for NRG,” an UBS Securities LLC analyst said. “Other potential ‘alternative energy’ investments to complement NRG’s retail offerings could include distributed solar generation.”

More: Bloomberg

Duke CEO Talks Merger Fallout, Coal Ash Dispute

Duke Energy chief executive Lynn Good, who began work July 1, discussed her priorities, the coal ash pollution that has prompted state lawsuits and the future of electric service in an interview with The Charlotte Observer.

More: The Charlotte Observer

EnerNOC on Big Data, Business Models

In an interview, Brad Davids, vice president of utility solutions with EnerNOC Inc., talked about the company’s evolving business model, big data and renewable energy.

More: Utility Dive

Previous coverage in RTO Insider: PJM, FERC Rules Buffet EnerNOC

September 3, 2013

Federal Briefs

DOE Chief: ‘Incumbents’ Should Embrace Change

“The future is not always 10 years away,” Energy Secretary Ernest Moniz warned in his first major policy address. Speaking at Columbia University’s Center on Global Energy, Moniz discussed President Obama’s climate action plan and said industry change will be driven by extreme weather, distributed generation, electric vehicles and pollution concerns.

More: Utility Dive, Greentech Media, National Journal

Video of speech: Department of Energy

DOE Issues Regs On Commercial Fridges

After a wait of nearly two years, the Energy Department proposed energy efficiency rules for new commercial refrigeration equipment and walk-in coolers and freezers. The rules represent one of the Obama administration’s first steps to address climate change through executive authority since the president announced his climate action plan in June.

More: The Washington Post

FERC

Wellinghoff: Solar Power to Overtake Wind

U.S. solar power capacity will exceed wind power generation in about a decade, outgoing FERC Chairman Jon Wellinghoff told Greentech Media. Wellinghoff predicted rooftop solar prices will drop from more than $4 per watt to $1 or $2. “It is going to be the dominant player,” Wellinghoff said. “Everybody’s roof is out there.”

Some analysts predict the U.S. will double its capacity of distributed solar within three years.

More: Greentech Media

JPMorgan Records Sought by Senate Investigators

The U.S. Senate Permanent Subcommittee on Investigations asked the Federal Energy Regulatory Commission to turn over “key documents” from FERC’s probe of JPMorgan Chase & Co.

Democrat Carl Levin, who leads the panel, and John McCain, its ranking Republican, asked FERC to include a 70-page document outlining investigators’ findings, which was cited in articles by The New York Times. The regulator kept that document private when announcing a $410 million accord with JPMorgan last month.

More: Bloomberg

Opinion: Ron Binz a Good Choice for FERC

Most people find it tough to get excited about regulators. But President Obama’s nomination of Ron Binz to head the Federal Energy Regulatory Commission is reason to sit up and take notice.

More: Forbes

OIL AND GAS

Report: Frackers Cheating Landowners, Govt.

Energy companies are manipulating costs and other data to deny private and government landholders billions in oil and natural gas royalties, ProPublica alleges. Thousands of landowners are receiving far less money than they were promised by energy companies, with some receiving virtually nothing.

Federal law requires that royalty payments to landowners be no less than 12.5% of the oil and gas sales from their leases.

More: ProPublica

September 3, 2013

DOE Study: Carbon Capture No Salvation for Coal

Coal boosters who hope carbon capture technology will ensure the fuel’s future will find little support in a new report conducted for planners in the Eastern Interconnection.

EPA’s proposed New Source Performance Standards for greenhouse gases will likely make it impossible to permit new coal-fired generation that doesn’t include Carbon Capture and Storage (CCS) technology.

But the report notes that the Department of Energy’s flagship CCS project, FutureGen in Illinois, “has experienced multiple delays and changes of scope and design [and] its prospects remain uncertain.”

Even if CCS becomes economical, the report concludes, the higher capital costs of coal generators means CCS “may be first deployed on natural gas plants before coal-fired plants, if natural gas prices remain low.”

“… Any state-level incentives to support coal mining and encourage the use of coal face an uphill battle in contending with these challenges.”

PJM Coal-Fired Capacity & Avg. Age (Source: EPA) — (Source: EPA)

The report also predicts the retirement of more than 50 GW of current plants between 2013 and 2016, in addition to the approximately 12 GW retired during 2010 through 2012. Of the 269 GW of coal capacity in the Eastern Interconnection, about one-third is located in five states that fall all or partly within PJM: Ohio, Indiana, Pennsylvania, Illinois and West Virginia. The average age of coal units in these states will be nearly 50 years by 2015.

The study, “Current State and Future Direction of Coal-fired Power in the Eastern Interconnection,” was conducted by ICF International for the Eastern Interconnection States’ Planning Council and the National Association of Regulatory Utility Commissioners (NARUC) with funding from DOE.

More: Full Report; Summary

September 3, 2013

MRC Actions

The Markets and Reliability Committee approved agenda items 2, 4 and 5 unanimously Thursday. Details are below:

2. PJM MANUALS

A. Manual 28: Operating Agreement Accounting

Reason for change: Revises the manual to reflect Tariff changes regarding lost opportunity cost compensation, as approved by FERC in docket ER13-1200.

The changes regard the amount of lost opportunity costs that a generator receives when PJM ordered it to reduce its output to maintain system reliability.

PJM made the changes to ensure that generators were not rewarded for operating units above the Maximum Facility Output specified in their interconnection agreements.

PJM told FERC the change was needed to prevent generators from causing constraints by operating above their Maximum Facility Output and then being rewarded with lost opportunity cost payments when PJM orders them to reduce output.

The new rules limit lost opportunity cost compensation to the lesser of the Maximum Facility Output or Economic Maximum (the highest incremental megawatt output level the unit can achieve while following economic dispatch).

Impacts:

Changes sections 5.2.6 and 5.2.8 (Operating Reserve & Reactive Services Lost Opportunity Cost Credits) to limit lost opportunity cost compensation.
Section 7.2 (Shortage Pricing) amended to incorporate calculation details for non-synchronized reserve market lost opportunity costs.
Modifies section 5.3 (Operating Reserve) to correct errors and provide clarifications on exempting deviations during shortage conditions; adds revisions for associating interfaces to the East or West BOR regions.
Modifies sections: 5.2.3 to incorporate details of Lost Opportunity Cost Credit for Synchronous Condensing; 5.2.6 (Wind Lost Opportunity Cost) to align language with Tariff; 17.3 (Allocation of Annual and Monthly FTR Auction Revenues) to correct section reference.

PJM contact: Stan Williams

B. Manual 14B: PJM Region Transmission Planning Process

Reason for changes: Updates to reflect changes from FERC Order 1000, switch to two-year planning cycle and revised benefit/cost test for Market Efficiency projects.

Impact:

Separates Reliability and Market Efficiency into subsections
Adds a new section (2.1.2) to explain two-year planning cycle on Market Efficiency projects.
Changes to reflect Order 1000.
Changes energy market benefit calculation component of benefit/cost ratio for Market Efficiency projects eligible for regional cost allocation. The change in total energy production cost and change in load energy payments (previously weighted .70/.30) will be equally weighted.

PJM contact: Tim Horger

4. PARAMETER LIMITED SCHEDULES (PLS) REVISIONS

PJM will add new processes for generators seeking exemptions from operating parameters under changes endorsed by the MRC.

The parameters are defaults for different types and sizes of generators, covering minimum run and down times, maximum daily and weekly starts and turn down ratios (Eco Max/Eco Min). They were initiated in 2008 to ensure lower make whole payments for generators whose entire offers were not covered by Locational Marginal Pricing revenues.

Reason for change: The change will reduce administrative burdens on members.

Impact: The proposed change would create three types of exemptions:

Temporary Exception: A one-time exception of 30 days or less;
Period Exception: An exception lasting for at least 31 days but no more than one year during the 12 months between June 1 and May 31; and
Persistent Exception: An exception lasting for at least one year.

The changes will require revisions to Attachment K of the OATT, Schedule 1 of the Operating Agreement and section 2.3.4 of Manual 11: Energy & Ancillary Services Market Operations.

Assuming FERC approval, the changes will be effective Oct. 1.

PJM contact: Jacqui Hugee

5. STAKEHOLDER PROCESS ON TRIENNIAL CONE REVIEW

Members will consider changes to the Cost of New Entry (CONE) triennial review process under a problem statement and issue charge approved by the MRC. CONE values are used in PJM’s Reliability Price Model (RPM) to obtain capacity resources.

Reason for problem statement: PJM and members agreed to explore changes in the review process in a settlement approved by the Federal Energy Regulatory Commission in January (Docket No. ER12-513).

Impact: The inquiry will assess the use of the Handy-Whitman Index of public utility construction costs for adjusting CONE and consider other potential changes.

PJM is required to file Tariff changes with FERC in time for the 2014 triennial review or a status report if stakeholders are unable to reach consensus on changes.

PJM contact: Paul Sotkiewicz