Manual 13 - Emergency Operation pdfPDF
Revision 40
Effective Date: 08.13.2010
• Updated diagram in Exhibit 1 (Emergency Levels)
• Updated language in Load management (Section 5) to match language in Section 2
• Updated table in Attachment E
• Updated table in Attachment F
• Completed 2010 Annual Review of the EOP manual
o Section 2 Capacity Emergencies, page 27, Step 7A (Real-Time): Voltage Reduction
o Section 2.4.2: Minimum Generation Alert, page 32 updated text box:
o Updated 6.1 Reporting System Disturbances to the Department of Energy, page 79
o Updated 6.4 Fuel Limitation Reporting, page 81
o All UDS entries changed to SCED.
o All Scheduling Coordinator entries changed to Master Coordinator.
o All PJM CA entries changed to PJM RTO.
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Manual 33 - Administrative Services for the PJM Interconnection Operating Agreement pdfPDF
Revision 9
Effective Date: 07.22.2010
Added Section 3.6 Market Data Postings as required for FERC Order 719 Compliance and approved by the MRC on March 17, 2010.
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Manual 9 - PJM eSchedules User Guide pdfPDF
6
Effective Date: 06.23.2010
Revisions pursuant to the counterparty clarification initiative approved at April 21, 2010 MRC meeting.
General clean up and conversion from a Manual to a User Guide approved at June 23, 2010 MRC meeting.
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Manual 11 - Energy and Ancillary Services Market Operations pdfPDF
Revision 45
Effective Date: 06.23.2010
Revisions approved by stakeholders at MRC on June 23, 2010 to incorporate changes due to PJM markets manuals review.
Revisions made to to clarify that PJM will be the counterparty to all transactions, unless market participants expressly and mutually contract between themselves (or self schedule to themselves). Revisions have been approved at the Markets and Reliability Committee on April 21, 2010 and by FERC (Order ER10-1003 issued on May 5, 2010)
(Reference: FERC Order ER10-1003)
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Manual 28 - Operating Agreement Account pdfPDF
Revision 45
Effective Date: 06.23.2010
• Revisions resulting from 2010 PJM review approved at June 16, 2010 MRC meeting.
• Revisions in Section 10, PJM Load Response Programs Accounting, for economic load response and Real-time index based contracts approved at June 16, 2010 MRC meeting.
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Manual 40 - Certification and Training Requirements pdfPDF
Revision 10
Effective Date: 06.23.2010
• Annual review of Manual.
• Added additional detail to section 1.4 Compliance Monitoring of Certification
• Added additional clarity to Section 2.6 – Training Requirements for Demand Response Resources Supplying Regulation or Synchronized Reserve
• Added new Section 2.7 - Training Requirements for Storage Resources Supplying Regulation or Synchronized Reserve
• Miscellaneous clarifying changes to Section 4.
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Manual 03 - Transmission Operations pdfPDF
Revision 37
Effective Date: 06.18.2010
• Annual Review
• Section 3.5 – Clarified verbiage with regard to the section pertaining to Voltage Coordination.
• Section 5 – Formatting, corrections and additions where appropriate within Index Tables.
• Section 5 – Clear designation via ‘[SPS]’ denotation of Special Protection Schemes within PJM.
• Section 5 – Revised naming of First Energy East Tie Lines (aka, PJM/AP Tie Lines via First Energy) operating procedure to FE East/AP Tie Lines throughout Operating Procedures.
• Section 5 – Removed separate Voltage Setpoints based upon LTC’s being in Auto or Manual mode for Dresden Nuclear Voltage Limits. Added distinct Voltage Drop %’s and Limits for Susquehanna when only one start-up transformer is in service or when both are in service. Added 138kV Voltage limits for Beaver Valley #1 & #2. All within the Voltage Control at Nuclear Stations section of Operating Procedures for PJM RTO.
• Section 5 – Retired the Deptford 230kV Breaker Relay within the Operating Procedures for AE Transmission Zone due to system upgrades.
• Section 5 – Additional Regional Procedures revision within the Operating Procedures for the AEP Transmission Zone. Indicate that opening the 138kV ‘B’ CB at Hinton is an accepted practice for alleviating loading on Kanawha River – Bradley 138kV lines. Indicate that opening the Layman 138kV CB at Corner is an accepted practice for alleviating loading on the Muskingum River – Wolf Creek – Corner 138kV line.
• Section 5 – Updated Kammer Operating Procedures to reflect current revision (rev. 5) of AEP’s Kammer Operating Procedures within the Operating Procedures for the AEP Transmission Zone.
• Section 5 – Revised Rockport Operating Guide, including the removal of references to the Rapid Unit Runback procedure, to correlate with AEP’s Revision 5 of the Rockport Operating Guidelines within the Operating Procedures for the AEP Transmission Zone.
• Section 5 -- Nottingham - Cooper 230 kV Line Limitations. Due to relay changes, revised “does not” to “will” in regard to contingency changes at Conowingo upon opening Bus Tie CB within the Operating Procedures for the BC Transmission Zone.
• Section 5 – Clarified applicable circuit breakers in the Single Breaker Derate section for the BC Transmission Zone.
• Section 5 – Equipment associated with cancelled ComEd SPOG 2-19 were removed from the Normally Opened Circuit Breaker Table within the Operating Procedures for the ComEd Transmission Zone.
• Section 5 – Added Islanding Prevention Scheme for TSS 941 Grand Ridge Generation within the Operating Procedures for the ComEd Transmission Zone.
• Section 5 – Added procedure for Davis Creek 345kV Bus Tie 2-3 Auto-Closing [SPS] within the Operating Procedures for ComEd Transmission Zone.
• Section 5 – Added procedure for the Dresden Unit 2 Trip Scheme [SPS] within the Operating Procedures for ComEd Transmission Zone.
• Section 5 – Added language regarding to MISO notification to the Quad City/Cordova Stability Procedure within the Operating Procedures for ComEd Transmission Zone.
• Section 5 – Added Marsh Run and Remington CT Stability Restrictions to Operating Procedures for DVP Transmission Zone and associated index tables.
• Section 5 – Changed name from ‘Bath County Contingency Restrictions’ to ‘Bath County Stability Restrictions’. Changed type from Contingency to Stability. Added reference to Fluvanna where Cunningham generation was noted. All in the Bath County Stability Restrictions section within the Operating Procedures for the DVP Transmission Zone.
• Section 5 – Clarified line/cb labeling and tripping sequence of the Virginia Beach SPS within the Operating Procedures for DVP Transmission Zone.
• Section 5 – Clarified line/cb labeling and tripping sequence of the Harmony Village SPS within the Operating Procedures for DVP Transmission Zone.
• Section 5 – Clarified line labeling and tripping sequence of the Carolina Substation 22 Line SPS within the Operating Procedures for DVP Transmission Zone.
• Section 5 – Clarified line labeling and tripping sequence of the Carolina Substation 54 Line SPS within the Operating Procedures for DVP Transmission Zone.
• Section 5 – Added Mt Storm Single Breaker Derates within the Operating Procedures for the DVP Transmission Zone.
• Section 5 – Added Crescent TR1 345/138kV Autotransformer Relief Procedure within the Operating Procedures for the DLCO Transmission Zone.
• Section 5 – Added DLCO Single Breaker Derates to Operating Procedures for DLCO Transmission Zone.
• Section 5 – Removed ratings table for Erie West #1 345/115kV Xfrmr in the Seneca Pump Operations section within the Operating Procedures for FE Transmission Zone.
• Section 5 – Corrected line voltage for the Erie South – Warren 230kV line within the Seneca Stability Procedures of the Operating Procedures for FE Transmission Zone. Previously designated as a 345kV line.
• Section 5 – Added Muddy Run Restrictions within the Operating Procedures for the PECO Transmission Zone.
• Section 5 – Revised naming of ‘Nottingham – Graceton 230kV Line Limitations’ to ‘Nottingham – Cooper 230kV Line Limitations’ due to addition of Cooper Substation within the Operating Procedures for the PECO Transmission Zone. For any reference to the ‘220-08’ 230kV line, replaced any reference to “Graceton” with “Cooper” due to substation addition along that path within the PECO Transmission Zone.
• Section 5 – Steel City – Hosensack 500kV Line Reclosing Limitation. Clarified description of reclosing limitation and associated procedure within the Operating Procedures for the PPL Transmission Zone.
• Section 5 – Added Montour Stability Restrictions within the Operating Procedures for the PPL Transmission Zone.
• Section 5 – Removed 500kV CB Derate for the ‘5020’ 500kV line CB Derate Table due to breaker replacement within the Operating Procedures for PSE&G Transmission Zone. Removed the 500kV CB Derate for the New Freedom ‘7-8’ 500kV CB due to breaker replacement within same procedure.
• Section 5 – Removed section pertaining to Deans Single Breaker Derates on the Breaker Derate Table within the Operating Procedures for PSE&G Transmission Zone.
• Section 5 – Revised the Closing Normally Open Breakers section within the Operating Procedures for PSE&G Transmission Zone. Removed reference to Athenia 138kV bus due to breaker replacements the Athenia 138kV bus is now solid. Revised the Linden section due to breaker replacements on the Linden 138kV bus.
• Section 5 – Revised Single Breaker Derate Table within the Operating Procedures for APS Transmission Zone. Added ratings for North Longview substation. Corrected ratings for the Cabot ‘CL6’ 500kV CB. Revised Ft Martin section to reflect system upgrages.
• Section 5 – Revised name of Pleasants and Willow Island Operating Restrictions within the Operating Procedures for the APS Transmission Zone to Pleasants and Oak Grove Operating Restrictions as it pertains to schemes to trip Pleasants and Oak Grove units. Clarified output restrictions, arming conditions, contingency control and Oak Grove circuit breakers
• Section 5 – Added Black Oak 500/138kV Transformer SPS within the Operating Procedures for the APS Transmission Zone.
• Section 5 – Added ‘Note1’ and ‘Note2’ box to the MISO Safe Operating Mode Procedure within the Operating Procedures for the MISO.
• Attachment D – Removed Yorkana #1 & #4 230/115kV transformers l/o Jackson-Yorkana 230kV line and Yorkana #3 230/115kV transformer from Congestion Management Program due to substation upgrades at Yorkana in the ME Transmission Zone.
• Attachment E – Added Automatic Sectionalizing Schemes at Burches Hill, Bowie & Benning for the PEPCO Transmission Zone and are effective as of August 1, 2010.
• Attachment E – Added Automatic Sectionalizing Schemes at Bristers, Suffolk, Surry, Morrisville & Valley for the DVP Transmission Zone and are effective as of June 1, 2010.
• Attachment E – Corrected numbering within the APS Transmission Zone.
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Manual 14D - Generator Operational Requirements pdfPDF
Revision 18
Effective Date: 06.01.2010
• Revised Attachment D, E, and F to remove redundancy and reorder.
• Modified Attachment E to change requirement to submit completed PJM Leading and/or Lagging Test Form R to PJM within 30 calendar days after completion of the testing (changed from 10 days).
• Added bullet 7 under Section Data Requirements in Attachment D, “Company can either test or apply the best engineering judgment to construct D-curve at min load points.”
• Added a line in Bullet 5 under Section Testing Requirements for both Units Larger than 70 MW and Black Start Units in Attachment E, “This requirement may require a departure from scheduled voltage during the test, provided no adverse effect on the validity of test results can be demonstrated.”
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Manual 15 - Cost Development Guidelines pdfPDF
Revision 14
Effective Date: 06.01.2010
Section 5: Updated Chronology of Maintenance Adder Escalation Index Numbers for the year 2010.
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Manual 18 - PJM Capacity Market pdfPDF
Revision 10
Effective Date: 06.01.2010
• Revisions made to rules for Non Unit-specific Capacity Transactions to clarify that PJM will be the counterparty to all transactions, unless market participants expressly and mutually contract between themselves (or self schedule to themselves). Revisions have been approved at the Markets and Reliability Committee on April 21, 2010 and by FERC (Order ER10-1003 issued on May 5, 2010) .
(Reference: FERC Order ER10-1003
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Manual 03A - Energy Management System Model Updates and Quality Assurance pdfPDF
Revision 5
Effective Date: 05.03.2010
Revision 05 (05/03/2010)
Appendix A ‘TERM Processing’ was re-written and re-named ‘Processing Ratings in TERM’. An explanation of new TERM Bulk Upload capability scheduled for implementation 2Q10 was also included.
Appendix C ‘Bulk Electric System (BES) Implementation’ revised as follows:
• Removed indents from section headers to improve readability
• Added special modeling discussion to the Electrical Models section
• Inserted ‘an’ before ad hoc in last sentence
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Manual 15 - Cost Development Guidelines pdfPDF
Revision 13
Effective Date: 05.07.2010
Section 5: Updated Maintenance Period for the choice of 20 years or 10 years and added Unit Configuration Addition Adder language
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Manual 14B - PJM Region Transmission Planning Process pdfPDF
Revision 15
Effective Date: 04.21.2010
Revision 15 (04/21/2010)
• Added new Attachment G describing PJM stability, short circuit and special RTEP practices and procedures. This Attachment includes the special requirements for coordination of planning for nuclear interfaces.
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Manual 33 - Administrative Services for the PJM Interconnection Operating Agreement pdfPDF
Revision 08
Effective Date: 04.13.2010
Corrected Title Page – typographical error: changed Council to Counsel
Approval: updated Vince Duane’s title to Vice President & General Counsel and added Sean McNamara as Manager of Member Relations
Section 2: Qualifications for PJM Membership – grammatical changes and updated links to new website
Section 2: Qualifications of PJM Membership – Effective Date, Termination & Withdrawal Process: corrected Article 6 to Article 5 and identified Reliability Assurance Agreement
Section 2: Qualifications of PJM Membership – updated settlement obligation period ending time frame
Section 2: Qualifications of PJM Membership – Application Cost: added membership costs and fee structure and clarifying language
Section 2: Qualifications of PJM Membership – Credit Policy and Credit Requirements: removed entire section and replaced it with a summary and added the link to the Credit Policy and Credit Requirements on the PJM website.
Section 5: Dispute Resolution – Arbitration Costs: clarifying language regarding PJM member
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Manual 21 - Rules and Procedures for Determination of Generating Capability pdfPDF
Revision 09
Effective Date: 05.01.2010
Added requirement to document cases where unit winter ratings are less than summer ratings.
Clarified language regarding correction of observed test data to rated site ambient conditions.
Changes to Appendix B to specify that, in the calculation of an intermittent resource’s capacity value, any hours during which PJM directed the resource to reduce its output are excluded.
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Manual 29 - Billing pdfPDF
Revision 21 (04.13.2010)
Effective Date: 04.13.2010
General clean up including fixing outdated Web links and exhibit references.
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Manual 39 - Nuclear Plant Interface Coordination pdfPDF
Revision 01
Effective Date: 04.01.2010
- Section 2.1: Outage Coordination – modified language to clarify outage coordination process.
- Section 2.3: Notification for Loss of Calculation Capability – added 30 minute timeframe to notify Nuclear Station of loss of EMS.
- Section 2.4.1: Communications – modified language to clarify real-time communication process.
- Section 2.6: System Restoration – highlighted urgency if the nuclear plant has lost both offsite and onsite AC power.
- Attachment B: Added individual Plant Specific NPIR for all nuclear plants with PJM RTO footprint. Plant Specific NPIR are not posted due to the confidential nature of subject matter.
- Attachment C: Plant Specific NPIR Revision History – updated to include approval date for plant specific Nuclear Plant Interface Requirements.
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Manual 35 - Definitions and Acronyms pdfPDF
Revision 17
Effective Date: 04.01.2010
Added Nuclear Energy related definitions
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Manual 27 - Open Access Transmission Tariff Accounting pdfPDF
Revision 74
Effective Date: 03.17.2010
• Replaced the Expansion Cost Recovery rates with a link to the PJM Guide to Billing on the pjm.com website and added the new RPM billing line items called Load Management Test Failure Charge/Credit.
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Manual 28 - Operating Agreement Accounting pdfPDF
Revision 44
Effective Date: 02.01.2010
• Revised Meter Reconciliation Accounting section to reflect the changes to the Meter Correction Allocation as approved by FERC (Docket No. ER10-320).
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Manual 18B - Energy Efficiency Measurement and Verification pdfPDF
Revision 01
Effective Date: 03.01.2010
Revisions approved by stakeholders at MRC on November 11, 2009
• One CSP Rule - Conforming Revisions for FERC Order ER10-366 accepted on January 22, 2010 and effective January 31, 2010, to include changes to
• Revisions to allow Energy Efficiency Resources to participate in 2011/2012 Deliver Years
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Manual 18 - PJM Capacity Market pdfPDF
Revision 9
Effective Date: 03.01.2010
• Clarifying Revisions
• Conforming Revisions for FERC Order ER10-15, accepted on 11/13/09 and effective 12/01/09, to include changes to Credit Rate Change
• Conforming Revisions for FERC Order ER09-1679 accepted on October 29, 2009 and effective November 1, 2009 to include changes for:
o New Entry Pricing Adjustment
o Removal of Existing EE and DR offer caps
o Allocation of LM Test Failure Charges
o Planned DR Deadline - change to 15 business days
o Excess Commitment Credit for LSEs if cannot sell excess in IA
o Reduction in FRR Obligation when Load Forecast is reduced
• Conforming Revisions for FERC Order ER05-1410 accepted on October 30, 2009 and effective 11/1/09 to include changes to Incremental Auctions design
• Conforming Revisions for FERC Order ER09-412 accepted on November 5, 2009 and effective November 13, 2009, to include changes to the trigger for a Conditional IA only for delay of Backbone Transmission Upgrade
• Conforming Revisions for ER09-1679 to include changes to Revisions for the automated adjustment to Net CONE
• Conforming Revisions for FERC Order ER10-366 accepted on January 22, 2010 and effective January 31, 2010, to include changes to
o evaluate the method for creation of additional CONE regions
o Revisions to allow Energy Efficiency Resources to participate in Earlier Deliver Years
o RPM Incremental Auction Times
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Manual 39 - Nuclear Plant Interface Coordination pdfPDF
Revision 01
Effective Date: 10.01.2009
New manual to address NUC-001 standard
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Manual 01 - Control Center Requirements pdfPDF
Revision 17
Effective Date: 01.01.2010
• Corrected section 2.7 from PJM EMS to transmission owner EMS and clarified timing requirement – within 2 hours
• Updated Section 3.2.3 changing 500 kV to 345 kV
• Updated language in section 4.2.3 to include a PJM definition of Directives
• Updated section 5.3.3 – generators (less than 500 kV) can be metered from high side or low side of GSU.
• Updated tables in Attachment A
• Added Attachment C – notification for system outages affecting telecommunications to include EMS and State Estimator outages.
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Manual 10 - Pre-Scheduling Operations pdfPDF
Revision 25
Effective Date: 01.01.2010
Section 6: Winter Net Capability Test Exemption. Deleted section based on RFC Standard MOD-024-RFC-01, which permits verification of winter gross Real Power capability by adjusting the summer verification, eliminating the need for exemption program. Revisions approved by stakeholders at MRC on November 30, 2009 (tariff change filed and awaiting FERC approval by February 1, 2010).
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Manual 11 - Scheduling Operations pdfPDF
Revision 44
Effective Date: 01.01.2010
Revisions approved by stakeholders at MRC on November 11, 2009 to incorporate the following revision:
One CSP rule (Section 10)
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Manual 13 - Emergency Operations pdfPDF
Revision 39
Effective Date: 01.01.2010
• Updated language in Load Management steps in section 2 and section 5, and Attachment G
• Updated table in Attachment F
• Updated IROL table in Attachment N
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Manual 14B - PJM Region Transmission Planning Process pdfPDF
Revision 14
Effective Date: 02.01.2010
• Attachment C: Added language to specify how energy efficiency is incorporated into deliverability tests. Added additional language to specify the load level modeled in the load deliverability test for the area being tested. (1/22/10 MRC Approval)
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Manual 14D - Generator Operational Requirements pdfPDF
Revision 17
Effective Date: 01.01.2010
• Updated section 7.1.2 – language for voltage schedule exemption (VAR-001/002)
• Added language to section 7.1.5 – Black Start units operators shall not permit their fuel inventory for Critical Black start CTs to fall below 10 hours – if it falls below this level, unit operators shall notify PJM and place the unit in Max Emergency.
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Manual 15 - Cost Development Guidelines pdfPDF
Revision 11
Effective Date: 12.02.2009
Section 4: Updated Fuel Cost Policy Guidelines
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Manual 15 - Cost Development Guidelines pdfPDF
Revision 12
Effective Date: 02.23.2010
Section 9: Updated Regulation Cost Guidelines approved 8/25/2009
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Manual 18 - PJM Capacity Market pdfPDF
Revision 08
Effective Date: 01.01.2010
Revisions approved by stakeholders at MRC on November 11, 2009 to incorporate the following revisions:
One CSP Rule (Section 4)
Permanent Load Departure (Section 8)
Tracking Existing DR (Section 4)
Revisions approved by stakeholders at MRC on November 30, 2009 (awaiting FERC approval by February 1, 2010) to incorporate revisions to the Winter Capacity Test Exemption (Sections 4 & 8, pp 24, 27, 104-105)
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Manual 21 - Rules and Procedures for Determination of Generating Capability pdfPDF
Revision 08
Effective Date: 01.01.2010
Revisions approved by stakeholders at November 30, 2009 MRC meeting and awaiting FERC approval by February 1, 2010:
Removed all references to the Winter Net Capability Test Exemption Program.
Revision to Appendix A allowing submission of ambient weather-adjusted data from the summer verification test in place of an actual winter verification test.
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Manual 28 - Operating Agreement Accounting pdfPDF
Revision 43
Effective Date: 01.20.2010
Revised Transmission Losses Accounting section to reflect the changes to the distribution of Transmission Loss Charges as retroactively approved by FERC (EL08-14)
Added clarifying item in the Operating Reserve Accounting section related to the Day-ahead pumped storage optimization program
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Manual 03 - Transmission Operations pdfPDF
Revision 36
Effective Date: 01.01.2010
Section 2.1: Thermal Operating Guidelines: Provided clarity regarding operator timeline to control thermal overloads.
Section 3.2 Voltage Operating Criteria and Guidelines: Provided clarity on controlling simulate post-contingency high voltage limit violations.
Section 3.7: Bulk Electric System Capacitor/SVC Operations: Updated table of AP 500kV relay automatic trip settings.
Section 4.2: Scheduling Transmission Outage Requirements: Provided clarity on TO/GO reporting requirements for protective relay outages/failures.
Section 5: Index of Operating Procedures for PJM RTO Operations: Updated Voltage Control at Nuclear Station limits for Peach Bottom Station.
Section 5: Index of Operating Procedures for AE Transmission Zone: Added Logan Runback Special Protection Scheme.
Section5: Index of Operating Procedures for First Energy Transmission Zone: Updated Keystone-Conemaugh 5003 Line / Re-Close Procedure.
Section 5: Index of Operating Procedures for PECO Transmission Zone: Modified Peach Bottom Xfmr, Peach Bottom #35, and Peach Bottom #45 SPS.
Section5: Index of Operating Procedures for BGE Transmission Zone: Deleted switching procedure to control Conastone Xfmr due to increased ratings resulting from transformer replacement. Updated Breaker Derate Table.
Section 5: Index of Operating Procedures for PPL Transmission Zone: Updated Sunbury 500/230kV Xmfr rating with 1 CB out-of-service.
Section 5: Index of Operating Procedures for ComEd Transmission Zone: Updated Powerton Stability Limit (ComEd SPOG 1-3-B, 1-3-B-1) and Quad City/Cordova Stability Limit Procedure (ComEd SPOG 1-3-C, 1-3-C-1, 1-3-G).
Section 5: Index of Operating Procedures for PSE&G Transmission Zone: Inserted Breaker Derate Table. Updated Closing Normally Open Breakers (Bus Sections) to remove Roseland, Marion and Metuchen as a result of CB replacements.
Attachment E: Automatic Sectionalizing Schemes: Added FE-E (PN) and Dayton Auto sectionalizing Schemes effective 2/1/10 and 3/1/10.
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Manual 35 - Definitions and Acronyms pdfPDF
Revision 16
Effective Date: 01.22.2010
Added the definition for Hub
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Manual 36 - System Restoration pdfPDF
Revision 12
Effective Date: 01.01.2010
• Section 6.1.4 - added - Black Start unit operators should not permit their fuel inventory for Critical Black start CTs to fall below 10 hours - if it falls below this level, unit operators shall notify PJM and place the unit in Max Emergency.
• Clarified language in Sections 3.1.5 and 7.2.1 that PJM must both approve and coordinate synchronization
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Manual 37 - Reliability Coordination pdfPDF
Revision 06
Effective Date: 01.01.2010
• Updated SOL definition to include all facilities 230kV and above, removing reference to MP-1.
• Added reference to NAESB Business Practice WEQ-008 and other editorial changes in Section 4
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Manual 38 - Operations Planning pdfPDF
Revision 04
Effective Date: 01.01.2010
• Attachment B: Added details to incorporate Wind Power Forecast.
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Manual 40 - Certification and Training Requirements pdfPDF
Revision 09
Effective Date: 01.01.2010
1) Added NERC Certification requirement for Transmission Owner Local Control Center operators.
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