Page 1651 – RTO Insider

March 11, 2014

Education Sessions Set on Smart Inverters

The Electric Power Research Institute will lead an educational session on smart inverters March 31 as the Planning Committee begins work on developing standards for the devices.

The Markets and Reliability Committee approved a problem statement/issue charge on Feb. 27 directing the Planning Committee to set rules for the devices, which allow solar PV and other renewables to provide reactive power. (See Enhanced Inverters Clear MRC.)

The Planning Committee will meet twice monthly on the issue. PJM will provide a second educational session April 18.

March 11, 2014

PJM Adds Controversial Demand Response Rules

PJM said it will change Manual 11’s rules regarding compensation for demand response despite a lack of stakeholder support.

In an unusual move, the Markets and Reliability Committee last month balked at endorsing the manual changes, which outline when Economic Demand Response qualifies for payment.

In an email to the Demand Response Subcommittee Friday, PJM’s Dave Anders cited a provision of the Operating Agreement that gives PJM the authority to make manual changes without a two-thirds member endorsement. “While PJM rarely exercises this right and responsibility, PJM has determined that this is the proper course of action in this case,” Anders wrote.

The changes were backed by only 57% of the MRC in a sector-weighted vote Feb. 27, with no End Use Customers and less than half of Other Suppliers voting in support. (See Manual Change on DR Compensation Rejected; 3 Others OK’d.)

Most Generation Owners and Transmission Owners voted in support of the changes, which specify that demand reductions are eligible for compensation only when they “are not implemented as part of normal operations.”

Load reductions “that would have occurred without PJM dispatch, or that would have occurred absent PJM energy market compensation” would be ineligible for compensation, according to the new rule.

PJM officials contend the manual changes only explained the RTO’s existing interpretation of FERC Order 745, and would not change operating practices.

But John Webster, of Icetec Energy Services, said the new language would give PJM too much latitude in determining the motives of DR participants and when they should be compensated. He said any revisions should be made through Tariff changes and subject to full stakeholder review.

March 11, 2014

Federal Briefs

“It’s kind of a national crisis,” an Oak Ridge National Laboratory scientist said about the systems vulnerable to shock from climate change. In a report for the Department of Energy to inform the third annual National Climate Assessment, the Oak Ridge author identifies vulnerabilities and challenges to energy systems, including electricity. For example, according to the report, one meter of sea level rise could prompt 4.6 million people in seven Florida counties to relocate, which would stress power infrastructure because those people account for more than 11% of power demand in the area. Before the people moved, however, the seven counties could be susceptible to hurricane-induced sweeping blackouts lasting weeks.

The report may help Public Service Electric & Gas’ case for the $3.9 billion Energy Strong program it wants authorized to shore up utility infrastructure against storms like Superstorm Sandy.

More: Scientific American; Island Press; NJSpotlight

House Blocks GHG Rule; Senate Outlook Iffy

The House of Representatives voted 229-183 to block the Obama administration’s plan for power plant greenhouse gas controls. The White House has said it would veto the measure if it passed the Senate as well, which is considered unlikely. The bill, the Electricity Security and Affordability Act, would reverse the Environmental Protection Agency’s proposal for limits on GHG emissions from new power plants, proposed in January, and would bar the EPA from issuing GHG rules for existing power plants until at least six U.S. plants have achieved the carbon capture technology standards for at least a year. The measure also requires EPA to study the domestic and global impact of the proposed rules.

Meanwhile, at the IHS CERAWeek conference in Houston, EPA Administrator Gina McCarthy assured attendees that “conventional fuels like coal and natural gas are going to play a critical role in a diverse energy mix for years to come.” At the same event, American Electric Power chief Nick Akins said he was encouraged by EPA’s outreach on the issue but was skeptical about the outcome.

More: The Intelligencer; The Dallas Morning News

House OKs Efficiency Bill; Senate Version Pending

A bipartisan energy efficiency bill passed the House of Representatives 375-36 in action widely hailed as proof that efficiency is a value honored by both parties in the ongoing political wars. The measure’s provisions are largely voluntary or involve studies, but it could provide a platform for negotiation with the Senate if that body passes its own, much broader, energy efficiency bill. The Shaheen-Portman bill could see a Senate vote soon. The House bill calls for a study of the feasibility of improving efficiency in commercial buildings, with encouragement for owners and tenants to implement high-efficiency measures and a requirement for development of a voluntary Tenant Star program to recognize commercial-building tenants that achieve high levels of efficiency. The program would be similar to the existing Energy Star efficiency labeling program for appliances.

More: Bloomberg

Governors Coalition Plans Grid-Development Measures

With support voiced from the Federal Energy Regulatory Commission, the Governors Wind Energy Coalition said it would pursue activities this year to promote construction of transmission lines that support renewable energy development. Among things the group will promote: establishing one-stop shops for transmission siting; supporting state and regional cooperation through collaboration among policymakers, utility commissions and system operators; and removing legislative barriers to siting, “such as those that don’t allow state utility commissions to consider economic, reliability, environmental and functional benefits beyond state boundaries in considering transmission siting.”

More: AWEA

March 11, 2014

Artificial Island Price Tag Rising?

Artificial Island Proposals - Southern Delaware Crossings (Source: PJM Interconnection, LLC) — Artificial Island Proposals – Southern Delaware Crossings (Source: PJM Interconnection, LLC)

The solution to the Artificial Island transmission stability problem may be more costly than originally estimated, PJM officials said last week.

PJM planners, who received 26 proposed solutions with costs as high as $1.5 billion, have been concentrating their review on several proposals with estimated costs of $110 million to $270 million.

Vice President for Planning Steve Herling told the Transmission Expansion Advisory Committee Thursday that addressing technical concerns stakeholders have raised about the proposals “could drive costs up.”

PJM’s Paul McGlynn said costs could be increased, for example, due to “the complexity that comes from working in a substation outside a nuke plant.” Artificial Island is home to the Salem and Hope Creek nuclear plants.

Officials gave TEAC members a briefing on the preliminary findings of the constructability review by the RTO’s engineering consultant.

Right of Way Concerns

The review found that the availability of land that Transource Energy proposed using in New Jersey “is in question.”

Proposals by LS Power and Virginia Electric and Power Co., in contrast, would require no additional land for expansion of the existing Salem substation. LS Power has acquired an option on a site for its proposed new switching station in Delaware.

The consultant also raised concerns about proposals that would cross or parallel Delaware Route 9, which is designated as a “Scenic and Historic” highway. Sharon Segner, of LS Power, said her company has obtained a legal opinion that Delaware law does not prohibit transmission lines near scenic highways.

Some proposals also could impact a wildlife refuge in New Jersey.

Artificial Island is PJM’s first competitive transmission project under FERC Order 1000.

McGlynn said planners are doing their best to conduct an “apples to apples” comparison of the proposals. “It’s proving to be more of a challenge than I originally thought,” he said, adding that planners still hope to recommend a solution to the PJM board by summer.

March 4, 2014

PSEG Employees Hurt in Gas Explosion

By David Jwanier

At least seven people were injured, including five PSE&G workers, Tuesday afternoon when a gas explosion ripped through a Ewing Township, N.J. condo complex. The blast destroyed at least one home and others were damaged by what witnesses described as a fireball.

Two hours after the explosion, firefighters from West Trenton Fire Co. and surrounding communities in Mercer County and beyond were still dousing the flames.

PSE&G said crews were working on repairs to a gas line that was reported damaged by a contractor when “there was an ignition.” The cause was under investigation.

According to news reports, the accident occurred about 1 p.m. in the South Fork development when witnesses said they heard what sounded “like a thunderbolt hitting” the area. One witness described diving to avoid a fireball.

Details were still unclear late Tuesday afternoon.

Ewing Police Lieutenant Ron Lunetta said five PSE&G workers were injured in the explosion, in addition to two employees of utility contractor Henkels and McCoy. PSE&G said two of its employees were hospitalized.

One of the injured was undergoing emergency surgery for lower body fractures at Capital Health Regional Medical Center in Trenton, according to Chief of Surgery Louis D’Amelio. None of the injuries were considered life threatening.

It did not appear that any residents were injured.

Dozens of homes were evacuated and affected residents were taken to the fire company and a local golf course in the immediate aftermath.

News reports said homeowners whose homes weren’t directly affected by the blaze would have to wait until late evening to return to their homes.

March 4, 2014

Stakeholders Reject Pay Hike for Black Start Units

By David Jwanier

Black start generators anticipating increased compensation came away empty handed Thursday as stakeholders rejected two proposals that would have boosted payments to existing units by at least 40%.

The Markets and Reliability Committee split along supply-load fault lines in rejecting the proposals.

Proposals Described

The Minimum Incentive proposal, which would have increased total payments to existing black start units by an estimated $3.4 million, won only 60% support in a sector-weighted MRC vote, short of the two-thirds needed to clear. While every Transmission Owners sector member and most members of the Generation Owners sector voted in favor, the proposal failed to win a single vote from End Use Consumers and got about half of Other Suppliers and Electric Distributors votes.

An alternative proposal, the Proxy for Base Formula Replacement, which would have more than doubled costs for existing black start units, also fell short with only 45% support and no support from the EUC and ED sectors.

The proposals had garnered 65% and 63% support, respectively, in unweighted votes in the System Restoration Strategy Senior Task Force.

Existing black start units are paid a base formula rate plus an incentive. The Minimum Incentive proposal would have increased the incentive factor from 10% of the base to the greatest of 10% or $25,000. This would raise the annual payment for a 20 MW black start unit from approximately $51,000 to nearly $72,000.

The same 20 MW unit would have received $312,000 under the proxy proposal. (See Black Start Units to See More Green?)

Bowring: No Need for Increase

Market Monitor Joe Bowring and stakeholders representing load questioned the need for the increase, noting that PJM said it had received a good response to its recent solicitation for new resources.

After the Minimum Incentive proposal failed, NRG Energy’s Neal Fitch made a statement endorsing the Proxy proposal, which he said was similar to compensation methods in New England.

Dave Weaver, representing Exelon, said generators in the PECO zone “are receiving revenues that are nowhere near the proxy.”

“What’s the benefit?” asked the Delaware Public Service Commission’s John Farber.

“I would say the benefit is you don’t lose these resources,” responded Weaver.

Bowring opposed both options, eschewing the “idea of some minimum payment that isn’t based on costs.”

“We support paying black start units full costs,” he said. “This is not what this is about. This is about an artificial cost based on what other units are getting. There is no basis for the assertion that these units will go away” without an increase.

PJM’s Chantal Hendrzak said although some operating generators have stopped offering black start service recently, “we’re finding sufficient black start to meet these critical load needs” as a result of the solicitation.

After the second proposal failed, Gloria Godson, representing Pepco Holdings, called for a renewed effort to create a “back-stop” solution for zones that fail to attract sufficient black start resources. “Generators are not in the business of just breaking even,” she said.

The issue will be returned to the task force for further consideration.

March 4, 2014

Pepco Earnings Up, FE Down

By Ted Caddell

Pepco Holding Inc.’s quarterly earnings shot up to 23 cents a share on $58 million for the final quarter of 2013, compared to 15 cents a share on $34 million for the same quarter a year ago.

Year-end results were $1.14 per share on $280, compared to 98 cents a share on $225 million a year ago.

The company attributed the increase to higher electric distribution revenues — primarily from higher rates from infrastructure investments — and lower operating expenses.

“Over the past three years, decreases in the duration and number of power outages have been dramatic, reflecting the significant investments we have made in the electric system,” CEO Joseph Rigby said during a conference call Friday. “The increase in adjusted earnings in 2013 reflects the impact of these investments.”

As with many utilities announcing year-end financial results, Pepco’s regulated delivery service posted an annual increase in revenue (4 %) while its non-regulated business posted a decrease (3.4 %) for the year.

Rigby said that the company’s improvements in system reliability helped drive its improved results. Having announced his retirement in January, he’ll have little time to enjoy the upswing, however. (See Pepco CEO to Retire.)

FirstEnergy Posts Lower Q4, Year-End Results

FirstEnergy reported a decrease in both quarterly and year-end earnings for 2013, a tough announcement in a year that already saw the company cut its dividend.

The company reported fourth-quarter earnings of 75 cents per share, compared to 80 cents for the same quarter a year ago, and $3.04 for the year, compared to $3.34 the year before.

Its 2014 guidance numbers show that it’s not out of the woods, either, with first-quarter earnings estimates of 35 cents to 45 cents per share, and year-end earnings at $2.45 to $2.85 per share.

The company said increased regulated delivery revenue helped make up for lower power prices coming from its aging generation fleet.

In January, it announced it was reducing its quarterly dividend to 36 cents a share from 55 cents, the first dividend cut in the company’s 17-year history, and said it will concentrate on its regulated delivery businesses going forward. (See Reboot for FirstEnergy.)

FirstEnergy CEO Anthony J. Alexander said the company’s actions “were intended to strengthen our financial position and reposition the company to focus on more predictable and stable growth initiatives in our regulated businesses.”

The company plans to invest $4.2 billion on its transmission business over the next four years.

March 4, 2014

RPS Targets’ Cost: $13.7B in Tx Upgrades

Renewable Portfolio Standards in PJM States (Source: DESIRE)

PJM could get 30% of its energy from wind and solar power without reliability problems, but it will require as much as $13.7 billion in transmission upgrades and 1,500 MW in additional regulation reserves, according to a long-awaited study.

The results of the study, which PJM commissioned in 2011, were presented to stakeholders yesterday by a study team headed by GE Energy.

Stakeholders had asked PJM to assess the impact on grid operations of state renewable portfolio standards. PJM states have targets calling for at least 10% of their electricity from renewables by the middle of the next decade, with most states setting targets between 20% and 25%. In total, the state targets anticipate the addition of 33 GW of wind and 9.2 GW of solar by 2029 (see chart).

Ten Scenarios

The study considered 10 scenarios, ranging from a business-as-usual case based on 2011 levels of wind and solar generation to a high-end case in which nearly one-third of the region’s power was generated by those renewables.

The study looked at the impact on regulating and operating reserves, transmission upgrades, PJM markets and operations, power plant emissions and the impact of cycling duty on variable operation and maintenance (VOM) costs.

Findings

Wind and Solar Requirements in PJM (MW) By 2029 - 33 GW of Wind 9.2 GW of Solar (Source: PJM Interconnection, LLC) — (Source: PJM Interconnection, LLC)

It found that PJM could adapt to the 30% renewable scenario without significant reliability problems by adding transmission and regulation reserves. “PJM has long held that ISOs and RTOs are better able to integrate variable energy resources because of their organized markets and regional infrastructure planning processes,” PJM said in its summary of the study. “… The study found that PJM’s large geographic footprint also provides significant benefit for integrating wind and solar generation because it greatly reduces the magnitude of variability-related challenges.”

All 10 of the scenarios predicted lower average Locational Marginal Prices and reduced revenues for conventional generators.

Although renewable generation increased the amount of cycling on existing generators, the increased VOM costs were small relative to the reduction in spending on fuel.

Recommendations

The study recommends that PJM:

Develop a method for determining reserve requirements based on forecasted levels of wind and solar production.
Consider intra-day unit commitments that would allow use of more efficient combined cycle units rather than combustion turbines to balance renewables’ variability. The study’s authors said that four-hour wind and solar forecasts have half the error rate of day-ahead projections.
Identify the reasons for ramping constraints on individual generators (i.e., technical, contractual, or otherwise) and seek methods for improving the flexibility of those that have traditionally operated as baseload units.

The study suggested PJM consider further study on how conventional generators can remain economically viable despite reduced energy market revenues.

It also recommended the RTO investigate how wind and solar plants could contribute to frequency response. Current wind and solar generators have the ability to respond to frequency response and down-regulation.

PJM’s Ken Schuyler, who introduced the study team yesterday, said PJM management has not taken a position on the study’s recommendations and plans to consult with members to “see which ones stakeholders think we should pursue.”

March 4, 2014

Company Briefs

American Municipal Power issued a request for proposal for carbon offset projects its six-state territory. Offsets may be from existing or new projects, including forest management, coal mine methane, landfill methane, wastewater treatment and anaerobic digestion. AMP has developed forestry offset projects and continues to pursue them, but says “carbon offset diversification is desired as well.”

More: AMP

Former Southern Exec Joins AEP Board

American Electric Power elected J. Barnie Beasley Jr. to its board of directors. Beasley, former chairman, president and CEO of Southern Nuclear Operating, is an adviser to the board of the Tennessee Valley Authority. His “nuclear operations expertise and insights into our industry will be valuable contributions to our board,” said AEP Chairman and chief executive Nick Akins.

More: AEP

— Compiled by Kathy Larsen

March 4, 2014

TOs Will Disclose Calculation Methodologies

Transmission owners will publicly post the calculations they use to allocate energy, capacity and transmission costs under a plan outlined to the Markets and Reliability Committee.

The Transmission Owners Agreement-Administrative Committee’s plan is intended to promote greater transparency, addressing a problem statement approved by the MRC last year. (See MRC Backs Industrials’ Call for Transparency in Transmission Owner Calculations.)

The proposal would add a page to the PJM website containing the methodologies transmission owners use to calculate total hourly energy obligations (THEO), peak load contributions (PLC) and network service peak loads (NSPL). The calculations are used to allocate cost responsibility among load-serving entities.

The issue arose because some TOs have not filed tariffs disclosing the methodology they use. Some members complained that the lack of transparency made it difficult to ensure they were being properly charged.