This month's Inside Lines informs PJM's stakeholders of various committee actions, upcoming training and other activities. PJM would like to highlight the following:

System Ready for 2006 Summer Power Demands
PJM Interconnection expects the system to be ready this summer with sufficient generating capacity to meet consumers’ forecasted peak usage. (more)

Moving Closer to Defining a Non-Synchronized Reserve Market
PJM’s Markets Implementation Committee may be closer to having a definition for the Non-Synchronized Reserve Market when it reviews recommendations by the Reserve Markets Working Group (RMWG) recently submitted. (more)

Installed Reserve Margin Virtually Unchanged
The PJM proposed 2007/08 Installed Reserve Margin (IRM) value is virtually unchanged from last year’s at 15.0 percent, according to the recently completed 2006 Installed Reserve Margin (IRM) Study. Last year’s margin was 14.7 percent. (more)

2006 PJM Annual Members Meeting Next Week
We’ll See You There
PJM members are days away from the 2006 PJM Annual Meeting of Members to be held May 2- 4 at the Hyatt Regency Chesapeake Bay, Cambridge, Md. The program will be similar to last year's event starting with the Markets and Reliability Committee meeting on Tuesday, May 2 and ending on Thursday, May 4 with the Members Committee Meeting and buffet luncheon.

The agenda for the meeting is at http://annualmeeting.pjm.com.

Online registration is now closed, but walk-up registration will be accepted. Registrants will need to make their own hotel accommodations by calling the Hyatt directly at 800.233.1234 or 410–901-1234. Please mention PJM when making room reservations.

PJM, Parties File Proposed Settlement on Stated-Rate Plan
PJM Interconnection and a number of its members have filed a settlement agreement this month with the Federal Energy Regulatory Commission establishing a system of stated rates to recover PJM’s administrative costs. PJM has requested a June 1, 2006, effective date for the new rate structure, which will enhance cost accountability. (more)

New Features on the PJM.com Calendars
Based on your feedback, PJM has implemented several new features to its calendars on PJM.com. These features include:

• Exports & Imports - Export calendar events to Excel and Microsoft Outlook; Import iCal format data; Export to MS Outlook & Palm OS PDAs using the export icon:
• Searches - Search by calendar or event using the search icon:
• RSS Export - Display event data on external Web sites via RSS or read it in Outlook Newsreader, Bloglines or other RSS newsreaders. This feature is available by clicking the RSS icon:
• Calendar List View - Display calendar events in list format by clicking the list view icon:

Visit the calendars below to check out the new features:
Meeting Advisor
Training Advisor

Let us know how you like the new changes by e-mailing us.

Feedback can be provided to Dave Anders at andersd@pjm.com or Bryon Koskela at koskela@pjm.com.

www.pjm.com

We are unable to respond to account inquiries sent in reply to this e-mail. To contact us by phone, please call our member hotline at 610.666.8980 or toll free 866.400.8980.

What's Inside:

Committees Report
Highlights
Regulatory Reports

04.24.2006 PJM 101: The Basics
04.25.2006 – 04.28.2006 2006 PJM System Operator Seminar
05.02.2006 – 05.05.2006 2006 PJM System Operator Seminar
05.08.2006 PJM 101: The Basics
05.09.2006 – 05.12.2006 2006 PJM System Operator Seminar
05.16.2006 – 05.19.2006 2006 PJM System Operator Seminar
05.22.2006 – 05.26.2006 Load Serving Entity 201
06.13.2006 Generation 101
06.14.2006 Generation 201
06.15.2006 Generation 301
06.16.2006 Operations 101
06.20.2006 – 06.21.2006 Market Settlements 301
06.27.2006 PJM 101: The Basics
06.28.2006 Scenario-Based Training

Committee Meetings:

• ISO-NE/PJM/NYISO Inter-Regional Planning Stakeholder Advisory Committee – 04.27.2006 - Topics: Status of Studies Planned for NCSP06, Review of Preliminary Conclusions and Results.
• Planning Committee (PC) – 04.26.2006 - Topics: Automated Sectionalizing scheme, Installed Reserve Margin (IRM) Study Results, Annual Plan Ideas Update, Markets and Reliability Committee Update, Regional Update, MMWG Case Development, Voltage Schedule Working Group, RPPWG Update, Stakeholder Review and Discussion of RTEP.
• Market Implementation Committee (MIC) – 04.25.2006 - Topics: Long-Term Transmission Right Allocation Process, Uncompensated Parallel Flow (Loop Flow), 3-Pivotal Supplier Test and Scarcity Pricing Implementation, DSR in Ancillary Services Market, Operating Reserve Proposal, FTR Proposal, Update on Expansion of Bid/Offer Data Postings, FTR Reconfiguration Proposal, Non-Synchronized Reserve Market, Day-Light Savings Whitepaper, eMKT User Interface, Demand Side Response Working Group Update, Black Start Service Working Group Update.
• Dispatcher Training Task Force Conference Call (DTTF) – 04.24.2006 - Topics: Report from SOS Liaison, eDART, PJM Operations Training 2006, 2006 PJM Operator Seminar, LMS - Implementation - Review Status of LMS for Company Operators, Upcoming Operator Training courses, PJM Emergency Procedures Drill 5/16 (5/23 BU), Recent Revisions to PJM Operational Manuals, PJM System Operator Certification, Blackout Period 5/1-5/31, PJM Certification page will be updated in May, NERC.
• MISO-PJM Joint and Common Stakeholders Working Group – 04.21.2006 - Topics: Transmission Service and OASIS, Price Transparency.
• Nuclear Generation Owners/Operators User Group (NGOUG) – 04.20.2006 - Topics: 2005 Reactive Testing Results, EMS Modeling/Plant Notifications.
• Regional Planning Process Working Group (RPPWG) – 04.20.2006 - Topics: Review Drafts of Market Efficiency Business Rules, Review Draft of Regional Planning Rules.
• Systems Information Subcommittee (SIS) – 04.19.2006 - Topics: Member Company Roundtable, PJM Operations Update, Inter-RTO Activities, eSuite Update, PJMnet Project Update, Electric Utility Security Issues, PJM Advanced Control Center Project Update, Communication and System Issues, Metrics.
• Small Generation Interconnection Working Group (SGIWG) – 04.19.2006 - Topics: Review the Addendum Materials Detailing the Internet Enabled Scada Approach, to the Attachment H, Interconnection Technical Standard 10MW and Below, Continue the Development of the 10MW to 20MW Interconnection Technical Standard.
• Reserve Markets Working Group (RMWG) – 04.19.2006 - Topic: Operating Reserve Business Rules.
• Reserve Requirement Assumptions Working Group (RRAWG) – 04.18.2006 - Topics: Review Draft of 2006 Reserve Requirement Study, Review Draft of the FPR and ALM Factor for the 2007/08 Planning Period.
• Operating Committee (OC) – 04.18.2006 - Topics: Review of Operations, System Operations Subcommittee (SOS)PJM Manual Changes, Black Start Services Working Group, Committee Background on Automatic Sectionalizing, Reactive support initiative, Scarcity Pricing, Markets and Reliability Committee, NERC / Reliability First / MAAC Update, System Information Services (SIS), Eastern Standard Time Discussion, OC Action Items.
• Reserve Markets Working Group (RMWG) – 04.17.2006 - Topic: Operating Reserve Business Rules.
• Transmission Owners Agreement-Administrative Committee (TOA-AC) – 04.17.2006 - Topics: Vote on SECA Revenue Distribution Resolution, Vote on Section 205 Filing to Amend Schedule 12 to Facilitate PJM RTEP Allocations to Merchant Transmission Entities, 500/230 kV Transformer Specifications, TRSWG Business Model Update, Procurement Process Update, Posting of Critical Documents Outcome, EMS Model Update, Legal Issues Team Update, TOAC Interpretation of Process for 30 Day Consultation With Members Committee for Section 205 filings, Reliability Cross-Border Cost Allocation with MISO update, Economic Cross-Border Cost Allocation with MISO Update, Stated Rate Settlement Document Update, Finance Committee Update.
• System Operations Subcommittee – 04.13.2006 - Topics: Review of Operations, Update on Steam Unit Modeling Issues, Regulation Changes, Unit Status via ICCP, Scarcity Pricing, Demand Response in Ancillary Markets, Daylight Savings Time (DST) Status and Whitepaper Discussion, eDART update, System Operator Certification, Dispatcher Training Task Force Update, Spring Restoration Drill, Summer Emergency Procedures Drill, 2006 Reactive Test Plan, Quarterly Reactive Analysis, Generator Semi-Annual Reactive Curve Review, Automatic Sectionalizing Discussion, Operational Performance Metrics, Manual Changes.
• Markets and Reliability Committee (MRC) – 04.12.2006 - Topics: Legal Report, Special Protection Schemes, 3-Pivotal Supplier Test & Scarcity Pricing Implementation, Non-Synchronized Reserve Market, DSR in Ancillary Services Market, Long-Term Transmission Rights Allocation Proposal, Operating Agreement Limitations Provision, Regional Planning Process Working Group Update, Markets Implementation Committee Report, Operating Committee Report, Planning Committee Report.
• Governance Working Group (GWG) – 04.11.2006 - Topics: Governance Model Development Presentation, Group Discussion of Articulating Perceptions of “Fair and Equitable” and How It Pertains to the Stakeholder Process, Working Group Protocols and Conduct of Meetings, Protocols for Sector Operations, Sector Definition and Qualification for Membership in Sectors, Governance Among Members and Voting Protocols, Evaluation of Alternative Governance Protocols.
• Long-Term FTR Working Group (LTFTRWG) – 04.10.2006 - Topics: Draft Business Rules for Long-Term Transmission Rights Allocation Proposal, Review Draft Operating Agreement Changes.
• Cross Border Economic Planning – 04.07.2006 - Topics: Joint MISO/PJM Meeting on Cross Border Allocation.
• Reserve Markets Working Group (RMWG) – 04.06.2006 - Topics: Operating Reserves.
• Regional Planning Process Working Group (RPPWG) – 04.05.2006 - Topic: Market Efficiency.
• Demand Side Response Working Group (DSRWG) – 04.03.2006 - Topics: Completed and Proposed Load Response Business Rule Revisions, Forward Energy Reserve Lite Concept, eLoadResponse Application Update, Matrix of Market Opportunities for Demand Resources.
  

Return to Top

System Ready for 2006 Summer Power Demands
PJM Interconnection expects the system to be ready this summer with sufficient generating capacity to meet consumers’ forecasted peak usage.

PJM’s forecasted 2006 summer peak usage is 131,439 megawatts of electricity for the states and areas within its region. PJM expects to have 165,303 megawatts of generating capacity on line. The generation capacity available beyond the forecasted peak provides a reserve margin of 25.8 percent—well above the 15 percent reserve margin PJM requires for reliability. Reserve margin provides a “cushion” of generating capacity to meet unexpected high usage levels or equipment problems.

PJM’s ability to meet the demand of the forecasted summer peak may also be enhanced by the estimated effects of 4,044 megawatts of interruptible demand and load management programs. Customers in these programs typically receive either a special rate or payments for stopping or reducing their use of electricity when requested by PJM in order to reduce demand on the grid.

The forecast assumes normal summer weather conditions. It is a standard “50-50” forecast, meaning there is a 50 percent chance that actual peak summer usage will be higher than the forecast and a 50 percent chance that it will be lower.

Return to Top

Moving Closer to Defining a Non-Synchronized Reserve Market
PJM’s Markets Implementation Committee may be closer to having a definition for the Non-Synchronized Reserve Market when it reviews recommendations by the Reserve Markets Working Group (RMWG) recently submitted.
In its recommendations, the RMWG defines the Non-Synchronized Reserve resources as those that provide contingency reserve, reserve capability that:

• can be fully converted into energy within 10 minutes from the request of the PJM dispatcher,
• is provided by equipment which may not necessarily be electrically synchronized to the system,
• includes both demand and generation resources.

The RMWG recommendations also address the non-synchronized reserve requirement, the market’s clearing methodology and settlement mechanisms.

The RMWG was created by the Markets Implementation Committee in the first quarter of 2005. The working group was created to evaluate the Operating Reserve structure and to develop a product definition for a Non-Synchronized Reserve Market.

According to the working group charter, the RMWG has a dual mission: to make recommendations ensuring that there is an appropriate compensation method for sufficient operating reserves for market efficiency and operating reliability needs; and to recommend potential rules for a market and/or compensation mechanism for non-synchronized reserve.

Return to Top

Installed Reserve Margin Unchanged
The PJM proposed 2007/08 Installed Reserve Margin (IRM) value is unchanged from last year’s at 15 percent, according to the recently completed 2006 IRM Study.

The IRM sets the level of installed reserves required to satisfy PJM’s generation adequacy criterion of a one-day-in-ten-year loss of load expectation (LOLE). The IRM is one of the inputs used to determine Load Serving Entity (LSE) capacity obligations.

The Study results and recommendations from PJM management and from the Members Committee will be forwarded to the Board. The Board will review, for approval, an IRM for the 2007/2008 planning period by June 30, 2006.

The PJM Reliability Assurance Agreements and the PJM West Reliability Assurance Agreement require that the IRM be approved by the Board by June 30 each year for the planning year that begins the following June 1.

PJM staff performs a study each spring to calculate the IRM. The study uses a probabilistic model that recognizes, among other factors, historical load variability, load forecast error, scheduled maintenance requirements for generating units, forced outage rates of generating units and the capacity benefit of interconnection ties with other regions. Study results are reviewed through the PJM committee structure, and the PJM Members Committee forwards its recommendation on the IRM to the Board. The Board is ultimately responsible for approving the PJM IRM.

PJM’s objectives are to establish an IRM that preserves reliability while not imposing an undue cost on load to pay for unnecessary generation reserves. PJM has taken a conservative approach in the past in recommending an IRM to the Board due to some of the uncertainties associated with the current unforced capacity structure.

The implementation of the Reliability Pricing Model (RPM) will remove some of those uncertainties. When RPM is in place, PJM will review the IRM study assumptions and consider appropriate changes to address the reduction in uncertainty.

Return to Top

PJM, Parties File Proposed Settlement on Stated-Rate Plan
PJM Interconnection and a number of its members have filed a settlement agreement this month with the Federal Energy Regulatory Commission establishing a system of stated rates to recover PJM’s administrative costs. PJM has requested a June 1, 2006, effective date for the new rate structure, which will enhance cost accountability.

The settlement agreement follows a July 2005 filing by PJM that proposed to replace its current system of formula rates, in which the rates members pay vary from month to month, with stated rates that are fixed for a period of years. Settlement discussions began in December 2005.

The agreement also establishes a method for collecting the capital and operating costs of a new second control center for PJM. In addition, the agreement enhances information sharing between PJM and the member-elected PJM Finance Committee.

"The stated-rate agreement will provide an unprecedented level of transparency and accountability in our operations," said Audrey Zibelman, PJM’s executive vice president and chief operating officer. "Members will have a clear picture of PJM’s administrative costs and a high level of rate certainty and stability."

Pointing out that PJM will be the first regional transmission organization (RTO) to move to a stated-rate design, Zibelman added:

"With the current focus on the costs of RTOs, stated rates will give additional impetus to PJM’s cost-control and performance-improvement initiatives. Through these efforts the company achieved $28 million in annual ongoing cost savings in 2005."

The settlement agreement implements a four-step structure of declining rates over the next six years to recover administrative costs – the costs that PJM members pay for the operation of the electric transmission system and wholesale electricity markets. The declining rates deliver to PJM members the benefits of cost efficiencies. Beginning June 1, 2006, the composite rate would be 33 cents per megawatt-hour (MWh); beginning Jan. 1, 2007, 32 cents per MWh; beginning Jan. 1, 2008, 31 cents per MWh; and beginning Jan. 1, 2011, 30 cents per MWh.

In 2010, PJM management and the Finance Committee will discuss whether the rate level in the fourth step needs to be adjusted to collect PJM’s costs and continue to fund a financial reserve.

In recovering the costs of the new second control center, the proposed agreement establishes formula rates to recover the costs of assets as they are placed in operation. This formula-rate recovery is to end seven years after the date that the new energy management system is declared in-service. The agreement also sets capital and operating cost ceilings for the project and requires that actual costs above the ceilings be recovered through the stated rates.

Return to Top

FERC Orders

April

• 04.27.2006 Docket Nos. ER05-6, EL04-135, EL02-111, EL03-212 (PDF)
  In the attached Order the Presiding ALJ in the SECA proceeding (Docket Nos. ER05-6, et. al.) denies the Motion of Green Mountain which requested an amendment to the List of Issues adopted by the ALJ on March 16, 2006. PJM and the PJM Transmission Owners filed a Joint Answer to the Green Mountain Motion on April 24, 2006. The ALJ agreed with PJM and the PJM TOs and found that the issue is already before the Commission in a request for rehearing of the Commission's October 31 2005 Order. The ALJ further stated that the justness and reasonableness of the SECA charges is the main issue in the this proceeding (thus there is no need to add the justness and reasonableness of the Green Mountain SECA charges as a separate issue).
• 04.21.2006 Docket No. EL05-103-000 (PDF)
  On April 21, 2006, the Commission issued an order dismissing, without prejudice, the complaint filed by Northern Indiana Public Service Company (Northern Indiana) in Docket No. EL05-103-000. The Commission also directed that the Midwest ISO and PJM include in their June 1, 2006 filings recommendations for costs apportionment addressing transmission problems on Northern Indiana's system as described in the complaint.
• 04.20.2006 Docket Nos. ER05-148-000, ER05-1410-000, 001 (PDF)
  On April 20, 2006, the Commission issued an Initial Order conditionally accepting PJM's Reliability Pricing Model in Docket Nos. ER05-148-000 and ER05-1410-000. PJM will make a compliance filing on open issues by May 19, 2006 and the Commission will set a Staff Technical Conference, at a future date to be scheduled.
• 04.19.2006 Docket No. ER06-499-000, 001 (PDF)
  On April 19, 2006, in Docket No. ER06-499, FERC issued a letter order accepting PJM's January 18, 2006 filing of tariff revisions to comply with Order 661 and Order 661-A with the requested October 14, 2005 effective date. Additionally, some tariff revisions regarding reactive power design criteria for all generating facilities interconnecting to PJM's transmission system, including wind generation facilities, are subject to the outcome of Docket ER06-199-000 which is still pending before the Commission.
• 04.17.2006 Docket No. ER06-649-000 (PDF)
  On April 17, 2006, the Commission issued an order accepting the unexecuted interconnection service agreement (ISA) and an unexecuted construction service agreement (CSA) among PJM, East Coast Power, LLC and Public Service Electric and Gas Company. The Commission accepted the requested effective date of January 17, 2006.
• 04.17.2006 Docket Nos. ER05-626-000, 001, ER05-1354-000 (PDF)
  On April 17, 2006, the Commission issued an order accepting PJM's filing in compliance with Order No. 2003-B and Order No. 2003-C as designated and made effective January 19, 2005, as requested.
• 04.12.2006 Docket No. ER06-319-001 (PDF)
  On April 12, 2006 the Commission issued an order in Docket No. ER06-319-001 granting rehearing for further consideration in this proceeding of the order issued on February 9, 2006 concerning the allocation of reactive revenue requirements from the Bath County facility.
  

March

• 03.28.2006 Docket Nos. ER05-6-035, EL04-135-037, EL02-111-055, EL03-212-051 (PDF)
  On March 28, 2006, the FERC accepted revised SECA tariff sheets, effective January 1, 2006, subject to refunds and surcharges depending on the outcome of ongoing SECA proceedings.
• 03.22.2006 Docket Nos. EL03-236-007, EL03-236-008, EL04-121-003 (PDF)
  On March 22, 2006, the FERC dismissed several requests for rehearing as moot in light of the settlement reached by the parties and approved by the FERC regarding offer capping in PJM. It also denied a request for rehearing regarding the removal of the post-1996 exemption from offer capping for certain units.

Return to Top

April

• 04.27.2006 Docket No. ER06-826-000 (PDF)
  On April 27, 2006, PJM filed a Motion for an Extension of Time of the Comment Due Date in Docket No. ER06-826-000 regarding the PJM Market Monitoring Plan. The requested extension would postpone the deadline from April 24, 2006, the date prescribed in the Commission's notice, to June 8, 2006.
• 04.27.2006 Docket No. ER06-765 (PDF)
  On April 26, 2006, PJM filed an answer in Docket No. ER06-765 to a protest filed by H-P Energy. The proceeding concerns an unexecuted ISA filed by PJM for H-P's merchant network upgrade to the PJM transmission system. In its answer, PJM showed that H-P had provided no reason for disapproval of the ISA, and that other relief requested by H-P is outside the scope of the proceeding.
• 04.25.2006 Docket No. ER06-406-000 (PDF)
  Attached is a notification of PJM to the Commission in Docket No. ER06-406 that it will implement the economic and ancillary demand response initiatives on May 1, 2006, and the emergency demand response initiatives on June 1, 2006.
• 04.25.2006 20060424-ER05-3-001, EL04-135-003, EL02-111-020, EL03-212-017 (PDF)
  On April 24, 2006, PJM and PJM Transmission Owners filed the attached Joint Answer to in the SECA Proceeding, Docket No. ER05-6, et. al., to Green Mountain's Motion to Modify Joint Stipulation of Issues.
• 04.24.2006 Docket Nos. EL06-54-000, EL06-50-000 (PDF)
  Attached is a copy of the Answer of PJM Interconnection, L.L.C. to Motion to Defer Consideration filed in Docket Nos. EL06-54 and EL06-50 on April 24, 2006 with FERC.
• 04.21.2006 Docket No. ER06-xxx (PDF)
  On April 21, 2006, the PJM Transmission Owners submitted to the Commission a filing modifying Schedule 12 of the PJM Open Access Transmission Tariff. These modifications clarify Schedule 12 with respect to: (i) the allocation of transmission expansion costs to merchant transmission owners; and (ii) the calculation of transmission enhancement charges for point-to-point transmission customers.
• 04.20.2006 Docket Nos. ER05-6-023, EL04-135-025, EL02-111-043, EL03-212-039 (PDF)
  On April 20, 2006, PJM and the PJM Transmission Owners jointly submitted proposed revisions to the Joint Operating Agreement between the Midwest ISO and PJM in compliance with the FERC’s directives in an order issued November 21, 2005 (Docket Nos. ER05-6-023, EL04-135-025, EL02-111-043, EL03-212-039) to provide supplemental information regarding the joint RTO planning model for cross-border cost allocations arising from reliability projects.
• 04.20.2006 Docket No. ER06-836-000 (PDF)
  On April 20, 2006, PJM filed a request in Docket No. ER06-863 to withdraw the unexecuted amended AEP NITSA that PJM had filed in the proceeding on April 12, 2006.
• 04.18.2006 Docket No. ER05-1181-000 (PDF)
  On April 18, 2006, in Docket No. ER05-1181, PJM, on behalf of the settling parties, filed contemporaneously with settlement documents a Motion To Permit Revised Rates To Become Effective Pending Commission Action On Settlement Agreement to permit settlement stated rates to go into effect on June 1, 2006.
• 04.18.2006 Docket No. ER05-1181-000 (PDF)
  On April 18, 2006, PJM, on behalf of the settling parties, filed settlement documents in Docket No ER05-1181 resolving all issues in the docket and establishing a rate structure for the recovery of PJM's administrative costs and a revised protocol to govern future communications between PJM and the member-elected Finance Committee.
• 04.17.2006 Docket Nos. ER06-456-000, 001, 002 (PDF)
  On April 17, 2006, PJM filed in Docket No. ER06-456, an answer to protests regarding PJM's filing to report the allocation of cost responsibility for certain transmission upgrades as part of PJM's RTEP.
• 04.13.2006 Docket Nos. ER06-611-000, ER06-691-000 (PDF)
  On April 13, 2006, in Docket Nos. ER06-611-000 and ER06-691-000, PJM filed a request for a one week extension of time, until April 24, 2006, to submit additional information requested by the Commission in its March 31, 2006 deficiency letter.
• 04.13.2006 Docket No. ER06-657-000 (PDF)
  PJM has filed a response letter in regard to the above mentioned docket ER06-657-000 requesting the Commission grant of a shortened comment period and that the Commission act expeditiously in this matter.
• 04.13.2006 Docket No. ER06-487-001 (PDF)
  On April 13, 2006, PJM and the PJM Transmission Owners jointly submit a compliance filing pursuant to the Commission’s Order Accepting Proposed Tariff Revisions For Filing, Subject to Revision issued March 17, 2006 in the Consolidated TOA proceeding.
• 04.12.2006 Docket No. EL06-62-000 (PDF)
  On April 12, 2006, PJM filed in Docket No. EL06-62 its answer to a complaint filed by H-P Energy Resources. In its Answer, PJM showed that FERC should dismiss the complaint as premature, because H-P objects only to a non-binding, preliminary ARR estimate that could change in the future. PJM also showed that H-P's objections to the results of PJM's preliminary estimate were unsupported.
• 04.12.2006 Docket No. ER06-xxx-000 (PDF)
  On April 12, 2006, PJM filed at FERC in Docket No. ER06-____-000 an unexecuted amended Network Service Agreement with AEP, with changes to reflect AEP's external network resources in the OVEC control area. PJM requested an effective date of March 13, 2006.
• 04.10.2006 Docket No. ER05-1181-000 (PDF)
  On April 10, 2006, PJM notified the Commission that it is extending the proposed effective date of its stated rates filing in Docket No. ER05-1181 from May 1, 2006 to June 1, 2006.
• 04.03.2006 Docket Nos. RM06-8-000, AD05-7-000 (PDF)
  On April 3, 2006, PJM filed Reply Comments in the Commission's Long-Term Firm Transmission Rights Notice of Proposed Rulemaking in Docket Nos. RM06-8-000 and AD05-7-000.
• 04.03.2006 Docket No. ER06-833-000 (PDF)
  On April 3, 2006, PJM filed revisions to Schedule 2 of the PJM Tariff to reflect the direct allocation of First Energy Companies' reactive power revenue requirements to the current owners of the generating plants associated with the revenue requirements.
• 04.03.2006 Docket No. ER06-xxx-000 (PDF)
  On April 3, 2006, PJM filed revisions to Attachment M of the Tariff. The revisions amended Attachment M by (i) conforming the PJM Market Monitoring Unit's (MMU) procedures with the Commission's policy regarding corrective actions to enforce compliance with PJM's market rules, (ii) delineating the MMU's rule in the development of specific recommendations for improvement of PJM's market design, (iii) clarifying certain language consistent with PJM practices and (iv) streamlining and updating certain provisions.
  

March

• 03.29.2006 Docket No. EL06-54 (PDF)
  On March 29, 2006, PJM filed a Motion to Intervene in Docket No. EL06-54, in which Allegheny Energy Inc., Monongahela Power Company, The Potomac Edison Company and West Penn Power Company (collectively "Allegheny Energy Companies") filed a petition requesting a declaratory order approving the proposed incentive rate treatments for a new 500 kV transmission project that Allegheny Energy Companies propose to construct within PJM's Allegheny Power transmission zone.
• 03.29.2006 Docket No. ER06-456-000 (PDF)
  On March 29, 2006, PJM filed a second amendment to its January 5, 2006, filing of proposed cost allocations for RTEP upgrades in Docket No. ER06-456. The purpose of this amendment is to correct two minor errors in the initial amendment of March 1, 2006, i.e., correcting the transmission owner under which one upgrade is listed in Schedule 12-Appendix of the PJM Tariff and deleting another upgrade, which PJM determined to be unnecessary.

Return to Top