Page 1673 – RTO Insider

September 10, 2013

State Briefs

ComEd Not to Blame for Smart Meter Fires

Commonwealth Edison’s smart meters are not to blame for overheating and fires that occurred in a pilot program. State regulators said the problem was loose connections and corrosion in customer-owned casings. Three smart meters caught fire during a 2010 pilot program, in which ComEd installed 130,000 smart meters.

Meanwhile, ComEd began installing smart meters for 60,000 customers in Chicago’s western suburbs last week. The company expects to complete the installations by the end of the year and hopes to switch all of its 4 million customers to the devices by 2021.

More: Chicago Tribune

KENTUCKY

Coal Layoffs Boost E. KY Unemployment Rates

Harlan County recorded the state’s highest unemployment rate in July at 17.2% while neighboring Bell County saw its rate hit 14.5%. “The majority of the layoffs have been coal mining jobs or jobs related to the mining field,” said one official. “In Bell and Harlan counties, coal impacts almost every business and almost every family in some way.”

Eastern Kentucky lost more than 4,000 coal jobs in 2012 as production in the region fell to its lowest levels since 1965, according to the Kentucky Department of Energy Development and Independence.

More: Middlesboro Daily News; Mountain Association for Community Economic Development

MARYLAND

Ex-PSEG Exec’s PSC Appointment Criticized

Some in Montgomery County are criticizing Gov. Martin O’Malley’s appointment of a former PSEG executive to the Public Service Commission, saying the agency needs a stronger consumer perspective. Anne E. Hoskins of Baltimore, was a senior vice president of public affairs and sustainability for PSEG.

More: The Gazette

PSC Extends Deadline on Wind Project

The Public Service Commission agreed Wednesday to give a wind power developer until the end of 2014 to begin work on a 25-turbine wind farm on Dan’s Mountain in Allegany County.

Laurel Renewable Partners, developer of the project, said it was unable to meet the PSC’s original September 2013 deadline due to financial difficulties and restrictive local zoning regulations. The company says Exelon Corp. has agreed to fund the project.

More: Cumberland Times-News

NEW JERSEY

JCP&L to Partner with IBEW to Speed Storm Repairs

Jersey Central Power & Light is partnering with a local electrical workers’ union to quicken system restoration following storms. Members of IBEW Local 102 will supplement utility personnel in providing damage assessments for downed wires and other hazards, freeing up JCP&L crews to do major restoration work. Union members may also be used to repair damaged connections at homes, hook up generators and help at water distribution stations.

The company said it expects the JCP&L-IBEW Emergency Response Team program — the first of its type in New Jersey — to be adopted by other utilities.

More: NJ.com

NORTH CAROLINA

Dominion, Solar Developer Dispute `Avoided Cost’ Calcs.

Dominion North Carolina Power asked the state Utilities Commission to reject a request by the developer of a 20 MW solar project for a higher price for its power. Dominion said it is willing to sign a 15-year contract with SunEnergy1 to buy all the power produced by the $50 million solar project in Scotland Neck but not at the price the developer is seeking. The dispute centers on how Dominion computed its “avoided cost” for the power.

More: Charlotte Business Journal

OHIO

Electricity Probe Ignores Consumers, Critics Say

State regulators’ investigation of the electricity market in Ohio has focused too much on ways to help energy companies and has largely ignored consumer issues, according to a coalition of consumer groups. Those groups said consumers have little access to information about how to choose suppliers and too little protection against misleading solicitations. State regulators say that consumer issues are being addressed in a separate case.

More: The Columbus Dispatch

Enviros Don’t `Like’ FirstEnergy

More than 60,000 Facebook users reportedly signed a pledge not to switch to FirstEnergy Solutions for electricity service. A coalition of environmental groups organized the online campaign in response the company’s push to change Ohio’s energy efficiency law.

FirstEnergy is trying to attract central Ohio customers who now get their electricity service from incumbent American Electric Power. In April, a FirstEnergy executive told an Ohio Senate committee the state needs to change its energy efficiency policy, claiming it is harming electricity customers and the state’s economy.

More: The Columbus Dispatch; Columbus Business First

Anti-Fracking Group Seeks Drilling Ban in Youngstown

Members of a group seeking to ban fracking in Youngstown collected enough signatures for the charter amendment to be on the Nov. 5 ballot, but a pro-business group that helped defeat a similar anti-fracking measure in May is challenging the legality of the proposal.

Meanwhile, new research concluded that a fracking waste disposal well linked to 11 earthquakes that rocked the Youngstown area was likely also responsible for at least 98 additional temblors that were too weak for people to notice. The results were published in the Journal of Geophysical Research: Solid Earth.

More: The Vindicator; The Columbus Dispatch

PENNSYLVANIA

Shale Taxes at Issue in PA Governors Race

U.S. Rep. Allyson Schwartz joined two other Democratic gubernatorial hopefuls in calling for a 5% severance tax on Marcellus Shale natural gas production. Schwartz said she would invest the tax revenues — estimated at $612 million this year — in education and transportation infrastructure.

The tax would be in addition to an impact fee enacted last year. The Democrats are vying to face off against Republican Gov. Tom Corbett, who opposes additional taxes on the industry.

More: The Patriot-News

PJM Meets State over Plant Closures; Neighbors Sue

State officials met with the PJM Interconnection in an effort to prevent FirstEnergy Corp. from its planned Oct. 9 closure of the Hatfield’s Ferry and Mitchell power stations. PJM asked the company in early August to postpone the shutdown, saying it needed more time to complete transmission upgrades to maintain reliability in the plants’ absence.

Several state legislators and representatives of the governor’s office met with PJM at the Public Utility Commission’s office in Harrisburg to brainstorm on ideas to get FirstEnergy to reconsider its plans.

Meanwhile, neighbors of Hatfield’s Ferry filed a class action suit over particulate emissions from the coal-fired generator. The suit, filed in U.S. District Court in Pittsburgh, seeks to represent more than 1,000 residents living within a 1.5-mile radius of the plant.

More: Herald-Standard; Observer-Reporter

Prior coverage in RTO Insider: FE Issues Coal Plant Layoff Notices as PJM Seeks Delay

West Penn Power Energizes 138 kV Line

West Penn Power energized a new 138-kilovolt (kV) transmission line connecting a substation near Kirby, Pa., with a substation in Monongalia County, W. Va. Both substations were expanded and reconfigured to accommodate the new line. While the majority of $20 million project is located in the West Penn Power service area, the West Virginia portion of the line is expected to benefit customers of Mon Power, another FirstEnergy subsidiary.

West Penn Power plans to spend about $110 million on reliability projects in 2013.

More: FirstEnergy

PA Studying Radioactivity in Marcellus Wastes

The state Department of Environmental Protection is conducting a study of radioactive shale gas waste to determine any risks involved in its transportation or disposal. Nearly 1,000 trucks hauling 16,000 tons of Marcellus Shale waste were stopped at Pennsylvania landfill gates after tripping radioactivity alarms last year. After testing, more than 600 tons were shipped to out-of-state landfills designed to dispose of radioactive materials.

More: Associated Press

VIRGINIA

Celanese Spending $150M to Switch from Coal to Gas

Celanese Corp. has begun work on a $150 million project to replace its coal-fired boilers with ones fueled by natural gas. The project, prompted by federal air quality regulations, will include a 16-mile pipeline to connect the company’s plant near Narrows, Va., to a natural gas supply in West Virginia.

State and local governments agreed to contribute $7 million in grants and tax breaks to keep the plant — Giles County’s largest employer with more than 1,000 workers — from moving. The plant, which opened in 1939, produces acetate tow, a material with various industrial uses.

More: Roanoke Times

WEST VIRGINIA

Fuel Cost Cut for AP, Wheeling

The West Virginia Public Service Commission has approved a rate decrease for Appalachian Power Co. and Wheeling Power Co. customers. The PSC Friday issued an order reducing the Expanded Net Energy Cost (ENEC) rates for customers by more than $50 million due to lower coal costs.

More: MetroNews

Coal Plant Developer Seeks Chapter 13 Protection

Limestone Conveyor at Longview Power Plant (Source Mascaro Construction Co.)

Longview Power LLC, developer of a $2 billion coal-fired power plant in north-central West Virginia, filed for Chapter 11 bankruptcy protection but said neither workers nor customers will be affected in the short term. Longview said that it will continue operations while negotiating with lenders.

More: Associated Press

Dominion Clarksburg Office Moving to Bridgeport

Dominion will move its office in Clarksburg to a more modern 100,000 square foot facility in Bridgeport. About 300 Dominion employees will be affected by the move, which is targeted for late 2015.

More: Exponent-Telegram

September 10, 2013

Company Briefs

Seneca Pump hydro plant in Warren, PA (Source: FirstEnergy)

FirstEnergy Corp. asked the Federal Energy Regulatory Commission for approval to sell 11 hydroelectric power stations in Pennsylvania, Virginia and West Virginia to Harbor Hydro Holdings, LLC, a subsidiary of LS Power Equity Partners II, LP.

The hydro projects, totaling 527 MW, represent less than 3% of FirstEnergy’s total generation. They are:

Seneca Pumped Storage (451 MW) in Warren, Pa.;
Allegheny Lock & Dam 5 (6 MW) in Schenley, Pa., and Allegheny Lock & Dam 6 (7 MW) in Ford City, Pa.;
Lake Lynn (52 MW) in Lake Lynn, Pa.;
Millville (3 MW) in Millville, W. Va.;
Dam 4 (2 MW) in Shepherdstown, W. Va., and Dam 5 (1.2 MW) in Falling Waters, W.Va.;
Warren (750 kW) in Front Royal, Va.;
Luray (1.6 MW) in Luray, Va.; and
Shenandoah and Newport (860 kW and 1.4 MW, respectively) in Shenandoah, Va.

The company announced in February plans to sell up to 1,180 MW of hydroelectric generation acquired in the company’s merger with Allegheny Energy. But a FirstEnergy spokeswoman told RTO Insider the company is not “actively seeking” buyers for its remaining hydro assets: Allegheny Generating Co.’s 1,200 MW of the 3,000 MW Bath County Pumped-Storage Hydro facility in Warm Springs, Va., and Jersey Central Power & Light’s 200 MW of the 400 MW Yards Creek Pumped-Storage Hydro facility in Blairstown, N.J.

More: FirstEnergy

NRG to Market Fuel Cells

1.2 MW Fuel Cell at Food Processing Plant (Source: FuelCell Energy, Inc.) — 1.2 MW Fuel Cell at Food Processing Plant(Source: FuelCell Energy, Inc.)

FuelCell Energy, Inc. announced a co-marketing agreement with NRG Energy for the company’s distributed generation power plants.

NRG will market the power plants to its customer base, offering a financing option in which NRG will purchase and own the power plant and sell power and heat to the end-user. The agreement also allows NRG to purchase power plants for its own portfolio. FuelCell Energy will operate and maintain the power plants owned or sold by NRG.

FuelCell Energy saw its stock jump 15 percent on the announcement Sept. 5. The company’s power plants are installed at more than 50 locations in the U.S., South Korea, Germany and the United Kingdom.

More: FuelCell Energy, Inc.

NRG Launches Retail Business in Philly

NRG Energy announced its entry into the retail electric business with a new company that will compete for residential customers in the Philadelphia region. NRG Residential Solutions will offer a choice of plans “emphasizing choice, control, rewards or innovation.” The company said it plans to expand throughout Pennsylvania, New Jersey, Maryland and the District of Columbia.

More: NRG Energy

Pepco Promotes Donna M. Cooper Region President

Pepco promoted Donna M. Cooper to president of its Pepco Region.

Cooper replaces Thomas H. Graham, who was promoted Aug. 1 to vice president, people strategy and human resources for Pepco’s parent company, PHI.

More: Pepco

FirstEnergy Names VP at Perry Plant

FirstEnergy Nuclear Operating Company, a subsidiary of FirstEnergy Corp., named Ernest J. Harkness site vice president at the Perry Nuclear Power Plant in Perry, Ohio. Harkness was previously site vice president at Exelon Corp.’s Oyster Creek Generating Station in Forked River, New Jersey. He replaces Vito Kaminskas, who is retiring.

More: FirstEnergy

Duke Names Controller, Investor Relations VP

Duke Energy named Brian Savoy vice president, controller and chief accounting officer. He replaces Steve K. Young, who became executive vice president and chief financial officer on Aug. 6. Savoy, 38, has served as director of financial forecasting since 2012 and is a former vice president and controller of the company’s commercial power segment.

The company also named Bill Currens vice president, investor relations. Currens replaces Bob Drennan, 65, who will retire Dec. 31.

More: Duke Energy

September 10, 2013

Nine PJM Nukes Lag in Mid-Year Grades

The Nuclear Regulatory Commission Friday cited nine PJM plants for additional scrutiny in its mid-year gradings of the nation’s nuclear fleet.

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 all operating units within one of four levels, with the agency’s scrutiny increasing as plant performance declines. (See sidebar: NRC Plant Rating Methodology.)

Eight PJM reactors were named among 17 nationwide in the second highest category and will undergo additional inspections because of items of low safety significance: FirstEnergy’s Beaver Valley 1 and 2 (Pa.) and Davis Besse (Ohio); PPL’s Susquehanna 2 (Pa.), and Exelon’s Three Mile Island 1 (Pa.), Dresden 2 and 3 (Ill.) and LaSalle 2 (Ill.).

In addition, FirstEnergy’s Perry 1 plant in Ohio was among eight reactors cited for a “degraded level of performance,” the third performance level.

The agency said the Perry plant and the Beaver Valley units resolved their issues after the close of the mid-year review and are now in the highest performing level, which are subject to only “baseline” inspections. The agency gave top grades to 75 reactors in the mid-year assessment for the period ending June 30.

One reactor, Browns Ferry 1 in Alabama, is in the fourth category because of a “high significance” safety finding.

In addition, the NRC has shut down the Fort Calhoun plant in Nebraska due to significant performance issues. It is in a special NRC oversight program and did not receive a mid-cycle assessment.

PJM Nuclear Plants Lagging in Mid-Year Grades (Source: NRC) — (Source: NRC)

Two other plants, Crystal River 3 and Kewaunee, entered decommissioning during the first half of the year and are no longer considered operating reactors.

September 10, 2013

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