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November 5, 2024

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Transmission System Briefs

In an effort to improve data collection, PJM will soon begin testing a new method for making interconnection applications.

Reason for Change: PJM engineers have to request additional information on half of the applications made using the current method.

Impact: The new method will use a question-and-answer process to guide applicants. PJM will be seeking a half-dozen volunteers to test the system in June and July before it is deployed. Those interested in volunteering should contact PJM through RTEP@PJM.com.

New Network Protocol for Small Generators

Small generators using public-domain Internet for access to PJM’s SCADA system will be switching to a new system intended to improve security and reliability.

The change affects load response and renewable generation assets under 100 MW not ‘sponsored’ by a generation company, aggregator or marketer.

The current system employs asymmetric “Shared Secret” encryption and uses the public-domain Internet. The new system, which uses “Public Key” encryption based on open standards, is favored by auditors and is considered close to industry best practice, PJM said.

The transition will take three to four years.

PJM contact: Ryan Nice

Dominion Adding Four New 500 kV Line Designations

Dominion’s interconnection of the Brunswick Power Station, a 1,551 MW combined cycle plant, will result in the creation of four new 500 kV line designations.

Dominion is building two new 500kV substations at Rawlings and Brunswick which will require the split of the two existing 500 kV lines: 511 Clover – Carson and 570 Wake – Carson.  The two will be split into four lines: 511 Carson – Rawlings; 585 Carson – Brunswick; 591 Brunswick – Rawlings, a new 14-mile line; and 509 Brunswick – Brunswick Power Station, a new one-mile line. The work is targeted for completion in 2016.

FirstEnergy Shutting Reading Control Center

FirstEnergy will shut down its Reading, Pa., transmission control center and move operations to its Wadsworth, Ohio, center on April 29th. The phone numbers will remain the same.

The Wadsworth facility will itself be replaced by a $45 million control center planned for FirstEnergy’s West Akron campus.  The new facility is expected to be complete by the end of 2013.  It will oversee transmission operations for all of FirstEnergy’s  utilities excluding Mon Power, Potomac Edison and West Penn Power, which will continue to be run from the company’s Fairmont, W. Va., center. The Wadsworth location will be used as a back-up and training facility.

Revised Transmission Matrix Approved

The Operating Committee last week approved revisions to the Transmission Owner/Transmission Operator matrix, an index between NERC reliability standards and PJM manuals.

Reason for change: The matrix is used as a tool during TO/TOP audits. The changes incorporate standards becoming effective this year.

Impact: The changes go next to the Transmission Owner Agreement Administrative Committee for approval.

PJM contact: Mark Kuras

Transient Security Assessment Coming to Real-Time Ops

PJM has begun testing Transient Security Assessments in real-time operations in preparation for a scheduled for June 1 deployment.

Reason for Change: The tool will monitor the transient stability of the PJM system and compute stability limits through real-time data input and network models. The system will collect data every 15 to 20 minutes, allowing PJM operators to implement controls to prevent generators from becoming unstable. PJM has been using the tool in near-term outage studies since the end of 2012.

Impact: Operators will switch from using stability limits found in Manual 3 to those coming from the TSA. PJM’s Dave Souder said the new tool should be more accurate because it is based on real-time conditions as opposed to the light load, conservative case, in Manual 3. The market impact should be “very minor,” said PJM’s Liem Hoang.

The deployment will require completion of benchmarking with ComEd and AEP, updates to Manual 3 and 3A and additional training for PJM operators. Immediately after deployment, operators will monitor only known stability concerns identified in M-03.

PJM contacts: Jianzhong Tong (tongji@pjm.com), Liem Hoang (hoangl@pjm.com)

Removal of Edison Mission Energy SPS in ComEd Zone

A Special Protection System activated to allow an Edison Mission Energy merchant interconnection in the ComEd zone (V3-052 and W2-038) will be removed on August 15. The SPS was used regularly and was still providing congestion relief after the completion of the required upgrades. Economic upgrades for the area have not passed PJM’s cost-benefit screens.

Baltimore Gas & Electric Activating SPS

Baltimore Gas & Electric will activate a Special Protection System for its Concord Street and Mount Washington 115kV lines on June 1 to allow for baseline system upgrades. The Concord Street SPS, designed to alleviate thermal overloads, will be removed with the completion of baseline upgrade b1086, expected in June 2014.  The Mt. Washington SPS, intended to correct voltage drop violations, will be removed on the completion of baseline upgrades b1267 and b1267.1 in about June 2018.

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EPA Delays GHG Limits for New Generators

The Environmental Protection Agency has delayed indefinitely its proposed greenhouse gas limits on new power plants.

EPA last year proposed a rule that would bar new generators from emitting more than 1,000 pounds of carbon dioxide per megawatt hour of electricity production.

An EPA spokeswoman told The Washington Post Friday that the agency could not complete review of the more than 2 million comments in time for an April 13 deadline for finalizing the rule. The spokeswoman said no new timetable had been set.

The Post reported that EPA is considering changes to improve the regulation’s chances of surviving a legal challenge. Read more in the Post.

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MIC to Probe ‘Sham Scheduling’

The Market Implementation Committee approved a request by Market Monitor Joseph Bowring to investigate whether traders could be manipulating PJM’s interface pricing points by breaking schedules into multiple “back-to-back” transactions.

In the 2012 State of the Market report, the monitor described the practice as “sham scheduling,” in which he said traders were hiding the actual source of generation.

PJM prices transactions with external balancing authorities based on the source and sink identified on the NERC eTag. Breaking the transaction into portions with separate eTags can lead to loop flows and incorrect pricing.

A trade from NYISO into PJM, for example, should be priced at the PJM/NYIS Interface. But if a trader breaks the transaction into one trade from NYIS to Ontario and a second on the ONT-MISO-PJM market path, PJM would price the transaction at the ONT Interface price, which is often higher. The monitor recommended that PJM work with NYISO, MISO and Ontario to prevent the practice.

“It’s not a huge problem but we’re worried about the potential of the problem,” Bowring told the committee.

One member representing a Midwestern utility affiliate, was skeptical. “I don’t see how logically you could break up transactions to game the system,” he said. (NOTE: PJM Insider is withholding the speaker’s name and company affiliation in accordance with the PJM Code of Conduct. The rules require the media to obtain a speaker’s permission before quoting him by name at all meetings except those of the Members and Markets and Reliability committees.)

In response to questions from PJM vice president of market operations Stu Bresler, Bowring said that he had contacted traders making back-to-back trades but that it had not changed their behavior.

“Did they say it’s not parking and hubbing?” Bresler asked.

Bowring said he could not discuss specifics of his conversations but added, “We have not been satisfied there was a satisfactory explanation.”

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DR Providers Cry Foul on Information Requirements

Three demand response providers asked the Federal Energy Regulatory Commission April 2 to block new PJM rules requiring them to provide officer certifications and additional information on their customers.

Comverge, Inc., Viridity Energy and Energy Curtailment Specialists said the rules create unnecessary barriers to demand response participation in PJM’s capacity markets, in violation of the Energy Policy Act of 2005. The companies also said the rules, which PJM made effective immediately after their approval by the Markets and Reliability Committee March 28, should have been submitted to FERC for review.  (See previous story.)

The rules require Curtailment Service Providers seeking to participate in capacity auctions to file “Sell Offer Plans,” including information about the provider’s customers. CSPs also must have a company officer sign a certification attesting to the company’s intent to physically deliver MWs.

The group, filing as the Demand Response Coalition, asked FERC to rule by April 19, the deadline for DR providers to file Sell Offer Plans for consideration in the 2016-17 Base Residual Auction (see EL13-57).

The coalition said the Sell Offer Plan requirement is “unduly burdensome and fails to take into account the dynamic nature of these customers and their respective demand resources.”

The officer certification requirement, the group said, “ignores the right of all capacity providers to plan to meet their capacity obligations with multiple capacity products through market mechanisms specifically enabled by the PJM tariff.”

The Ohio Public Utilities Commission filed an intervention in the case on Thursday, saying the new rules were necessary to ensure PJM’s reliability. “The issue is simple, whether a DR provider should be afforded the potential for unwarranted profits for undeliverable or overcounted DR resources to the detriment of PJM’s obligation to ensure reliability,” the commission wrote.

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PJM Reconsiders Adders on Cost-Capped Generators

PJM will evaluate whether it’s time to end extra compensation for generators that frequently run on cost-based offers under market power mitigation rules.

The Market Implementation Committee approved an issue charge by Market Monitor Joseph Bowring to review the “adders” for frequently mitigated units (FMU). Bowring said the adders are no longer needed because of the introduction of the capacity market in 2007 and changes to scarcity pricing rules in 2012.

FMUs were allowed adders in 2006 to ensure that they cover their avoidable costs. The adders are graduated: Generators that are cost capped for 60% of their running hours receive an adder of either 10% of their cost-based offer or $20 per MWh; those capped for 80% or more of their hours can receive $40 per MWh. Similar rules apply to “associated units,” which share physical and economic characteristics to FMUs.

Bowring acknowledged that less than 1% of megawatts sold last year were offer capped. But Bowring said that because the affected units are concentrated in load pockets “it can have more significant impacts locally.” Of the 133 units eligible for FMU or AU status in at least one month during 2012, 25 (19%) were FMUs or AUs for all months.

The monitor won support for the issue charge after agreeing to modify it so that it won’t be pursued until the fourth quarter; some members wanted time to evaluate the impact of scarcity pricing during this summer. Bowring also agreed to remove from the issue charge his conclusion that the reasons for the creation of the adders no longer exists.

Dave Pratzon, who represents generators, said he believed the issue would prove more complicated and time consuming than Bowring suggested. “I think this issue has a lot more hair on it,” Pratzon said.

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CIP Audit Has No Findings

ReliabilityFirst Corp. completed its Critical Infrastructure Protection (CIP) audit of PJM last week with no findings. The audit covered 29 standards, Mark Kuras, PJM Senior Lead Engineer for NERC and Regional Coordination, told the Planning Committee.

Kuras said auditors had seven recommendations, most related to a lack of clarity in PJM’s manuals regarding control room operators’ responsibility for reliability functions.

They also indicated that the transmission line naming conventions used by transmission owners could result in violations in a future audit, Kuras said. NERC names lines based on voltage levels and the substations at either end; transmission owners identify lines by numbers.

“It’s an easy fix for PJM but there will be a lot of pushback from TOs,” Kuras said.

Kuras also said PJM and NERC are still in settlement discussions over violations resulting from the 2010 CIP spot check and Order 693 audit.

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New Modeling OK’d for Combined Cycle Plants

PJM will change the way it models combined cycle generators in its least cost dispatch.

The Operating Committee voted overwhelmingly last week to switch to a “composite” model. This will allow combined cycle owners to bid their units in multiple configurations, including duct firing, that reflect the flexibility of the units (i.e., 1×0, 1×1, 2×1, 3×1). Each configuration will have its own parameters (i.e., start time, minimum run time and startup cost).

Under PJM’s current modeling, combined cycle operators must bid as either a combustion turbine or steam unit.

Dave Pratzon, who represents generators, said the change was necessary because combined cycle units have become more prevalent and are more often setting prices. “To my clients the status quo is not a reasonable alternative,” he said.

John Citrolo, of PSEG, also supported the change, saying the current model doesn’t properly compensate generators for combustion turbines starts and stops. “It models the units’ parameters more accurately, gives PJM [dispatchers] more flexibility and compensates owners more fairly,” he said.

The committee chose the composite model over an alternate “additive (pseudo)” option. The additive option would allow combustion turbines to be modeled as separate market units, with the steam turbine modeled as part of the combustion turbines. Pratzon said the additive model was “just a Band-Aid” and was inferior to the composite model.

The proposed change, which will be considered next by the Markets and Reliability Committee, will require software development by PJM’s vendor, Alstom, and changes by generators. The changes are not expected to be implemented before summer 2014.

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Manual Changes to Implement Electronic Notification System

The Market Implementation Committee approved changes to Manuals 1 and 18 Wednesday to implement an automated process that will allow Curtailment Service Providers to provide operational data to — and receive dispatch instructions from — PJM.

The new Load Response System (eLRS) process replaces the current manual methods, which rely on email and spreadsheets.

Reason for Change: PJM needs operational data to estimate the real time energy reductions likely in response to a PJM dispatch of emergency demand response resources.

Impact: The automated data should allow PJM more accurate dispatch of Emergency DR resources and help determine those resources eligible to set the real time LMP.

CSPs will be required to contact their emergency DR resources to determine their load reduction capability (e.g., outages at the facility; reductions based on high expected prices, peak shaving or contract provisions). The updates are to be done monthly in October through May, daily in June through September and hourly when under a Max Emergency Generation Alert or Action.

The real time dispatch instructions will be used in emergency and synchronized reserve events. CSPs will have a communication link through eLRS that will poll PJM once a minute for event notifications and instructions and provide PJM acknowledgement that the instructions have been received. For companies without an information technology staff, PJM will provide a software client.

The real time dispatch system will be available in the PJM “sandbox” May 16 for testing, prior to the production deployment May 22.

Resources:

PJM contact: Jack O’Neill

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PJM May Bar Some Financial Players from Trading – UPDATE

By Rich Heidorn Jr.
PJM Insider

PJM’s announcement last week that it may deny trading privileges to as many as 55 small market participants provoked both praise and criticism from financial traders.

PJM said that it would bar members from most trading if they are unable to qualify for the Dodd-Frank exemption approved by the Commodity Futures Trading Commission last month.

“This is good for the market,” said Pat Sunseri, of financial trader Twin Cities Energy, LLC. Sunseri said PJM’s move will eliminate severely undercapitalized companies whose strategy is “hit it big or leave the market holding the bag.”

Attorney Carol Smoots, who represents the Financial Marketers Coalition, called PJM’s response an overreaction, although she said her coalition members won’t be affected.  “This approach will close the market out to smaller companies,” she said. “The market isn’t protected by making sure a company is of sufficient size; big companies can cause huge defaults. The market is protected by reasonable collateral policies.”

 “Appropriate Persons”

The CFTC agreed March 28 to largely exempt from its regulations Financial Transmission Rights, day ahead and real time energy transactions, forward capacity transactions and reserve regulation transactions, sales that are already regulated by the Federal Energy Regulatory Commission. However, the CFTC said the exemption did not apply to financial market participants that cannot qualify as “appropriate persons” under the Commodity Exchange Act (CEA).

“We can’t be convinced that if we transact with a party not meeting the exemption that we’re not transacting a swap” under Dodd-Frank rules, PJM General Counsel Vince Duane told a special meeting of the Markets and Reliability Committee Thursday.  Being deemed a swap dealer could subject PJM to CFTC reporting requirements, he said.

PJM Chief Financial Officer Suzanne Daugherty said that about 55 financial traders that have not provided PJM with financial statements may fall outside the exemption.

CFTC’s definition of appropriate persons includes banks and broker-dealers regulated by the Securities Exchange Act, futures traders regulated under the CEA and other companies with a net worth exceeding $1 million or total assets exceeding $5 million.

The commission order also exempted those participating “in the generation, transmission, or distribution of electric energy” but declined to extend the exemption to all those participating in RTO and ISO markets.

The only parties not exempt in RTOs, the commission said, are “market participants that can demonstrate neither the financial wherewithal nor the requisite business activities and congruent expertise to qualify as appropriate persons under” the Commodity Exchange Act.

Daugherty said PJM will give financial traders not otherwise exempt the opportunity to provide financial statements establishing their qualification for the exemption under the $1 million/$5 million threshold.

Duane said those not meeting the CFTC exemption would still be able to take transmission service under the PJM tariff. “It primarily will affect those trading in FTRs and the energy market,” he said.

Reaction Varied

Twin Cities’ Sunseri said PJM’s move will help eliminate irresponsible financial traders.

“I don’t want people with $50,000 cash slinging huge megawatts [trading positions] that that could blow up any day of the week,” Sunseri said. “Without a company having adequate funding to bear losses, it delegitimizes our sector and promotes a negative stereotype from other market members.”

Smoots, however, said PJM’s action is unnecessary and anticompetitive. She took issue with Duane’s conclusion that allowing trading by companies not covered by the exemption might subject PJM to regulation as a swaps dealer. “There’s nothing in the order to suggest that,” she said.

The Dodd-Frank Wall Street reform act encouraged the CFTC’s jurisdictional handoff by inserting a section in the Commodity Exchange Act underscoring FERC’s authority over RTO transactions. But it is unclear whether CFTC’s action will end its turf skirmishes with FERC because the agency retained its right to police RTO trades under its anti-fraud and anti-manipulation authority.

Next Steps

The CFTC included several conditions in its exemption, including a requirement that PJM maintain the confidentiality of any subpoenas the commission issues for information about PJM members. PJM will amend its Operating Agreement to comply.

PJM will need to modify its Operating Agreement and tariff to bar the non-exempt participants from trading. Other regional transmission organizations and independent system operators have said they will take similar action, Duane said. CFTC issued a “no action” letter giving PJM and other regions until Sept. 30 to comply with its conditions.

PJM will brief members on its response at an MRC conference call April 18and at the Members Committee Information Webinar April 22. It will seek approval of the proposed OATT and OA changes from the MRC April 25 and the Members Committee on May 16. Assuming a filing with FERC in late May, the changes would take effect by Sept. 30.

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MC/MRC Final Approval: ARR Modeling Revised

The Markets and Reliability and Members Committees approved modeling changes for the annual Auction Revenue Rights (ARR) allocation to reflect the return of transmission facilities to service after outages.

The current tariff states that if any ARR requests made during stage 1A of the allocation process are not feasible because of transmission outages, PJM will allow the allocation by increasing the capability limits of the binding constraints. The increased limits are then used in subsequent ARR and Financial Transmission Rights allocations and auctions for the planning year.

During the ARR allocation for the 2013/2014 planning year, PJM found infeasibilities on some paths due to planned transmission outages in the annual process that were not scheduled to be out of service every month of the planning year. Continuing the increased ratings in subsequent auctions would overstate transmission capability, exacerbating FTR underfunding.

The changes to section 7.4.2(i) of the Operating Agreement will exclude increased capability limits in monthly auctions for months in which the transmission facility is not out of service.

The MRC agreed to waive the normal 60-day review period so that the changes can be implemented in time for the May monthly balance of planning period FTR auction.

PJM contact: Tim Horger