zilongwang/ReadingBank huggingface dataset:
Completed Actions Date SAR Filed. November 28, 2012 Review Team files Preliminary Recommendation. June 20, 2013 WSC approves ballot to retire WR1, WR2, WR4 and WR5. June 26, 2013 Notice of Joint Session to discuss retirement. August 2, 2013 Ballot Pool opens asking for retirement of WR1, WR2, WR4 and WR5. August 5, 2013 WSC approves Drafting Team. August 8, 2013 Ballot Pool closed asking for retirement of WR1, WR2, WR4 and WR5. September 3, 2013 Joint Session to discuss retirement. September 5, 2013 Ballot opens asking for retirement of WR1, WR2, WR4 and WR5. September 16, 2013 Drafting Team – First Meeting – Orientation. September 26, 2013 Ballot closed asking for retirement of WR1, WR2, WR4 and WR5. Retirement approved. October 8, 2013 Posting 1 - Open 45-day October 15, 2014 Posting 1 – Closed December 1, 2014 Posting 1 – Response to Comments Posted February 4, 2015 15. Posting 2 – Open 30-day February 4, 2015 16. Posting 2 – Closed March 6, 2015
17. Posting 2 – Response to Comments Posted March 17, 2015 18. Posting 3 – Open 30-day July 24, 2015 19. Posting 3 - Closed August 24, 2015 20. Posting 3 – Response to Comments Posted October 16, 2015 Anticipated Actions Date Version 4 Posted – Open 30-Day Comment Period October 27, 2015 Version 4 Posted – Closed November 30, 2015 DT meets for final Comments / Forward to WSC December 3, 2015 WSC Meets Open Ballot Pool Joint Session – Notice Close Ballot Pool Joint Session Open Ballot Ballot Closed WSC Meets Notice to WECC Board of Directors Board Implementation Plan Approvals Required
Requirements and Measures Rationale Blocks will be relocated to the Guidance section when the project is complete. Rationale for Requirement WR1: This is a planning criterion. WR 1 addresses NERC TPL R5 and R6. WR1 is designed to state the base planning criteria the system must meet – unless an individual entity or group of entities has different criteria. WECC Requirements WR2 and WR3 allow for entities to have different criteria. Neither WR2 nor WR3 changes the WR1 default; rather, WR2 and WR3 allow for deviation from the WR1 default. WR2 allows for a more stringent approach without changing the WR1 default. A more stringent approach may be used in accordance with WR2 so long as all the affected parties agree. Similarly, WR3 allows deviation from the default with the additional protection that when used, other Transmission Planners and Planning Coordinators are allowed to use the same criteria on that part of the system for the same category of planning events (e.g., P1 and P2). In the context of Requirement WR1, the word “nominal” carries its common definition and could be, for example, either the base voltage or the operating voltage as established in the entity’s Planning Assessment. This means that nominal may have a varying definition or use from one entity to the next. If an entity does not specify what is nominal, the default use of the term nominal defaults to the kilo-volt class that is specified in the WECC Base Case, with the exception of the 500 kilo-vote class, in which case the default nominal would be specified as 525 kilo-volt. Requirement WR1.1.2 refers to the post automatic equipment adjustment effect prior to manual adjustment. WR1. Each Transmission Planner and Planning Coordinator shall use the following default base planning criteria, unless otherwise specified in accordance with Requirements WR2 and WR3: Steady-state voltages at all applicable Bulk-Electric System (BES) buses shall stay within each of the following limits: 1.1.1 95 percent to 105 percent of nominal for P0 event (system normal event powerflow); contingency
E.B.7 The Generator Owner did not provide all of the data required in E.B.7, on any one occasion. The Generator Owner did not provide all of the data required in E.B.7, on any two occasions. The Generator Owner did not provide all of the data required in E.B.7, on any three occasions. The Generator Owner did not provide all of the data required in E.B.7, on any four or more occasions. The following table replaces the MOD-026 Attachment 1, Excitation Control System or Plant Volt/Var Model Verification Periodicity table in its entirety, and is only applicable to the Western Interconnection. Row Number MOD-026 Attachment 1 This Table is Applicable Only to the Western Interconnection. Excitation Control System or Plant Volt/Var Function Model Verification Periodicity Verification Condition Required Action Establishing the initial verification date for an applicable unit. (Requirement R2) Transmit the verified model, documentation and data to the Transmission Planner on or before the Effective Date. Row 4 applies when calculating generation fleet compliance during the five-year implementation period. See Section E.A.5 of this variance for Effective Dates. 2 Subsequent verification for an applicable unit. (Requirement R2) Transmit the verified model, documentation and data to the Transmission Planner on or before the five-year anniversary of the last transmittal, per Note 1 at the end of this table. 3 Initial verification for a new applicable unit or for an existing applicable unit with new excitation control system or plant volt/var control function equipment installed. (Requirement R2) Transmit the verified model, documentation and data to the Transmission Planner within 365 calendar days after the commissioning date.
MOD-026 Attachment 1 Applicable to the Western Interconnection Control or Model Periodicity Verification Condition Required Action 2 Subsequent verification for an applicable unit. (Requirement R2) Transmit the verified model, documentation and data to the Transmission Planner on or before the anniversary of the last transmittalper Note the of .
MOD-026 Attachment 1 Excitation Control System or Plant Volt/Var Function Model Verification Periodicity Row Number Verification Condition Required Action 1 Establishing the initial verification date for an applicable unit. (Requirement R2) Transmit the verified model, documentation and data to the Transmission Planner on or before the Effective Date. Row 4 applies when calculating generation fleet compliance during the implementation period. See Section A5 for Effective Dates. 2 Subsequent verification for an applicable unit. (Requirement R2) Transmit the verified model, documentation and data to the Transmission Planner on or before the 10-year anniversary of the last transmittal (per Note 1). 3 Initial verification for a new applicable unit or for an existing applicable unit with new excitation control system or plant volt/var control function equipment installed. (Requirement R2) Transmit the verified model, documentation and data to the Transmission Planner within 365 calendar days after the commissioning date. year
Version Date Action Change Tracking 0 April 23, 2004 WECC Effective Date: 1 July 1, 2011 FERC Effective Date: VAR-501-WECC-1 2 May 28, 2014 WECC Ballot Body Approved Paragraph 81 clean-up 3 Implementation Plan VAR-501-WECC-, Power System Stabilizers () Standards Authorization Request VAR-501-WECC-, Power System Stabilizers () Applicable Entities Generator Operator Generator Owner Conforming Changes to Other Standards
The Industry Segments are: 1 — Transmission Owners 2 — RTOs, ISOs 3 — Load-serving Entities 4 — Transmission-dependent Utilities 5 — Electric Generators 6 — Electricity Brokers, Aggregators, and Marketers 7 — Large Electricity End Users 8 — Small Electricity End Users 9 — Federal, State, Provincial Regulatory or other Government Entities 10 — Regional Reliability Organizations, Regional Entities Group/Individual Commenter Organization Registered Ballot Body Segment 1 2 3 4 5 6 7 8 9 10 Group Cain Braveheart Bonneville Power Administration X X X X Individual Dean W Spratt Avista X Individual Amy Casuscelli Xcel Energy X X X X Individual Catrina Martin Utility System Efficiencies, Inc. X Individual Arizona Public Service Company Arizona Public Service Company X X X X
Introduction The Western Electricity Coordinating Council (WECC) is a Regional Entity authorized through a delegation agreement between the North American Electricity Reliability Corporation (NERC) and WECC pursuant to Section 215 of the Federal Power Act. NERC delegates designated powers, rights, and responsibilities to WECC regarding the administration within the Western Interconnection of electric Reliability Standards adopted or approved by NERC and the Federal Energy Regulatory Commission (FERC). These Reliability Standards Development Procedures (Procedures) define the process to be used by WECC for the development, modification, retirement, and interpretation of Regional Reliability Standards (RRS) and WECC Regional Criteria (CRT). These Procedures establish the structure for open and transparent due process in the development of WECC RRSs and CRTs. These Procedures include, but are not limited to, public notice of intent to develop RRSs and CRTs, a public comment period on the proposed documents, due consideration of comments provided, and a balanced Ballot Body. The Procedures shall be interpreted and applied in a manner that is consistent with the WECC Bylaws. Should any conflict arise between the Procedures and the WECC Bylaws, the WECC Bylaws will prevail. Definitions Ballot Body That body of qualified persons that register with WECC for participation in Ballot Pools. Ballot Pool That pool of Ballot Body entities that have registered to vote on a specific document. Drafting Team (DT) A team of pertinent subject matter experts (SME) appointed by the WECC Standards Committee (WSC) to develop the document(s) called for in a Standard Authorization Request (SAR), consider and respond to industry comments, participate in forums to help build consensus on draft documents, and to perform other tasks as assigned by the WSC. NERC Compliance Registry Registry of the Bulk-Electric System owners, operators, and users that are subject to approved reliability standards. Non-Substantive Changes Revisions that do not change the scope, applicability, or intent of any requirement, including but not limited to, correcting the numbering of a requirement, correcting references, changes to document
Interchange Authority Software Provider July 29, 2010 The Help Desk of the Software Vendor who is supporting the Interchange Authority Software System (WECC Interchange Tool). Contact information will be provided on the homepage of the WECC Interchange Tool. INT-020-WECC-CRT-1.2
back-stop scheduling process that protects the reliability of the grid during Interchange-software failure that prevents the distribution of e-Tag information for assessment of confirmed interchange transactions, distribution of confirmed interchanged transactions, or both." To: purpose of this document is to establish a coordinated back-stop scheduling process that protects the reliability of the grid during Interchange-software failure that prevents the distribution of e-Tag information." WR3, WR7, WM7: From: "Each Balancing Authority shall maintain a duplicate copy of its aggregate Net Scheduled Interchange (NSI) as previously confirmed by the interchange software." To: "Each Balancing Authority shall maintain a duplicate copy of its aggregate Net Scheduled Interchange (NSI) as previously confirmed in the interchange software." Balancing Authorities confirm NSI within the interchange software. WM5 WM5 asks for an attestation if no failures of the interchange software were suspected. Entities are not audited on regional criteria, so keeping an attestation on file seems burdensome. BPA believes it is sufficient to keep evidence that the Balancing Authority/Purchasing-Selling Entity reported a suspected failure of the interchange software to the interchange software provider. The DT concurs with BPA and has redrafted the Purpose statement as follows: Purpose Statement The proposed change to the Purpose statement would strike the phrase, “….for assessment of confirmed interchange transactions, distribution of confirmed interchanged transactions, or both.” “By” versus “In”
Completed Actions Date WECC-0118 Standard Authorization Request (SAR) received 1/12/2016 WECC Standards Committee (WSC) approved the SAR 1/28/2016 Drafting Team (DT) solicited 1/28/2016 WSC approved the DT 3/8/2016 First DT meeting 4/5/2016 Posting 1 Open 4/7/2016 Posting 1 Closed 5/23/2016 DT Meets to Respond to Comments 5/31/2016 Posting 2 Open 6/6/2016 WSC Expands Scope 6/14/2016 Posting 2 Closed 7/6/2016 DT meets to answer Comments 7/14/2016 DT meets to answer Comments 7/21/2016 Posting 3 Open 7/25/2016 Posting 3 Closed 8/25/2016 DT meets to answer Comments 8/30/2016 Anticipated Actions Date WSC Meets (TBA) DT requests ballot TBA September 2016
Contingencies and system conditions for which the RAS was designed, “Data required to describe Design Objectives – contingencies and system conditions for which the scheme was designed.” R1.2. Operation actions taken by the RAS in response to Disturbance conditions, and WECC CRT Attachment A, WECC Remedial Action Scheme Information Sheet, Row 7, Operation “Data required describing Operation – The actions taken by the scheme in response to Disturbance conditions.” RASRS Procedure. Replicated in Attachment A, WECC RAS Database Information. R1.3. Modeling — Information on detection logic or relay settings that control operation of the RAS. WECC CRT Attachment A, WECC Remedial Action Scheme Information Sheet, Row 8, Modeling “Data required for adequate Modeling – Information on detection logic or relay settings that control operation of the scheme. RASRS Procedure. Replicated in Attachment A, WECC RAS Database Information. Attachment C addressing PRC-014
PRC-12/14, WRs 2, 4, and 8 through 12 are not proposed for retirement. Although not proposed for retirement, PRC-12/14 WR4 could be retired without affecting WECC’s role assigned in the underlying FITB standard because the required procedure is also addressed in the RASRS Procedure. R1.2. Requirements to provide data that describes design, operation, and modeling of a RAS. WR2. Each Reporting Party shall complete and forward the data described in the WECC Remedial Action Scheme Information Sheet (Attachment A) to the Reliability Assurer (WECC) no later than 90 days after the Effective Date of this document. (PRC 12/14) PRC-12/14, WR2 is not proposed for retirement; however, it could be because the content is contained in the Design document coupled with the RASRS Guideline. PRC 12/14, Attachment A requires submittal of information regarding: 1) operating procedures, design objectives, operating, and modeling. PRC-12/14, WR2 is itself partially redundant to Protection System and Remedial Action Scheme Misoperation; however, PRC-004 only applies to Major WECC transfer Paths in the Bulk-Electric System. RAS Design RAS Procedure, Sections A through H., pages See also, WECC Remedial Action Scheme Database at pages, 9 and 20. See also Periodic Assessments addressing Corrective Action Plans, page 9. R1.3. Requirements to demonstrate that This Requirement is met in PRC-003-WECC-CRT-1, ARM RAS Misoperation Procedure WR1. Even if the WECC WR1 is retired, the NERC Requirement R1.3 is still met in the RAS Design and Remedial Action Scheme Design Guide, June 2006. Procedure to Submit a RAS for Assessment
Plan. Plan, E. Coordinated Plan Details, at 6. WR2. The Reliability Assurer (WECC) shall verify the Coordinated Plan contains the comprehensive data and information necessary to comply with NERC Reliability Standard PRC-006-2, Automatic Underfrequency Load Shedding. Purpose/Responsibilities The UFLSRG shall: Annually review the Plan’s consistency with the requirements of PRC-006. The WECC PCC and OC, or a designated subcommittee, will annually review the Coordinated Plan submittals to confirm that all the required information is in the format necessary to comply with applicable Reliability Standards. Section G, page 13. WR3. The Reliability Assurer (WECC) shall instruct the Review Group to conduct simulations of the Coordinated Plan (Attachment A) by November 1 of every other year, to ensure the Coordinated Plan meets all the requirements of NERC Reliability Standard Purpose/Responsibilities The UFLSRG shall: b. Conduct annual simulations of the Plan to assess consistency with the performance requirements of PRC-006. The WECC PCC and OC will assess and document the effectiveness of the design and implementation of this Coordinated Plan… Section I., Review and Update, page 13. WR13. The Reliability Assurer (WECC) shall designate the Review Group to coordinate and perform all post-event analyses associated with the Coordinated Plan. D.B.11. Each [PC]…shall participate in and document a coordinated event assessment with all affected [PCs]… D.B.12. Each [PC]…shall participate in and document a coordinated UFLS design assessment…with the other [PCs] in [WECC] The WECC PCC and OC will maintain a UFLS database…for use in event analyses and assessments of the UFLS program… Section I. Review and Update, page 13. WR14. The Reliability Assurer (WECC) shall instruct the Review Group, or its successor, to review Attachment B, the Coordinated Plan – Data Submittals Requirements, at least once a year, and make changes as deemed necessary by the Review Group. Purpose/Responsibilities c. Review the submitted UFLS data for consistency and accuracy of modeling. The WECC PCC and OC may recommend to the WECC Board of Directors changes to this Coordinated Plan as necessary to reflect system changes in the Western Interconnection. Section I., Review and Update, page 13.
Attachment A WECC Requirement Is Met BY WR1. The [RA] shall designate the [Review Group]…to review the Coordinated Plan… WR2. The [RA] shall verify the Coordinated Plan contains [specified data]… WR3. The [RA] shall instruct the Review group… WR4. The [RA] shall verify that the Review Group conducts a review… WR13. The [RA] shall designate the Review Group to coordinate… WR14. The [RA] shall instruct the Review group…to review…. The roles and assignments of WECC, the Standing Committees, the Joint Guidance Committee, and the WECC Board of Directors are all designated by the WECC Bylaws, WECC Policies, and the charters of the associated groups. These roles and assignments need not be specifically re-stated in the WECC CRT. The Joint Guidance Committee’s Charter specifies that it will coordinate WECC projects and facilitate communication between Standing Committees.
Criterion Development Timeline This section is maintained by the drafting team during the development of the criterion and will be removed when it becomes effective. Nomenclature Change The nomenclature of this document is proposed for change from PRC-(012 through Remedial Action Scheme Review and Assessment Plan to PRC-012-WECC-CRT-1, Remedial Action Schemes. The change aligns the WECC Criterion with a single NERC Standard bearing similar content. NERC Standard, PRC-012-2, Remedial Action Schemes, was approved by a NERC Ballot Pool on April 29, 2016. Original NERC Standards: PRC-012-0, Special Protection System Review Procedure; PRC-013-0, Special Protection System Database, and; PRC-014-0, Special Protection System Assessment. Description of Current Draft The WECC-0119B Removal of Reliability Assurer Drafting Team (DT) is recommending retirement of Requirements (WR) 1, 3, 5, 6, and 7 from the existing Version 2 document because the WRs are redundant to peripheral NERC and WECC documents. The applicable entity of each of these requirements is the Reliability Assurer/WECC (RA). Requirements WR 2, 4, 8 through 12 are not proposed for retirement; however, under the expanded scope of the Standard Authorization Request (SAR) provided by the WECC Standards Committee in June 2016, the balance of the document will be updated to current drafting conventions. In Posting 1, a white paper was presented providing evidence of redundancy and illustrating how the reliability content would be continued in the event the specified Requirements were retired. Two comments were received in Posting 1. Both agreed the specified Requirements could be retired without creating a reliability gap.
Education, Audiovisual and Culture Executive Agency Erasmus+ : Higher Education - International Capacity Building Erasmus+ Project Officers for Capacity Building in Higher Education Projects* 2015 – 2016 * In accordance with the article I.6.2 of the grant agreement and the Instructions for operational and financial reporting, the progress and final reports as well as any request for payment or/and related communications sent by email, in addition to the mandatory paper version, MUST always be sent to . Project Number Title Project Officer E-mail* 2015 561478-EPP-1-2015-1-AT-EPPKA2-CBHE-JP Building Inclusive Urban Communities MOREAU Patricia 2015 561485-EPP-1-2015-1-AT-EPPKA2-CBHE-JP Curriculum Development joint European Political Science MA ENCISO Belen 2015 561492-EPP-1-2015-1-FI-EPPKA2-CBHE-JP Supporting Entrepreneurial Development in the Field of IT in Vietnamese HEIs MOREAU Patricia 2015 561495-EPP-1-2015-1-AT-EPPKA2-CBHE-JP Implementing a Central Asian Centre for Teaching, Learning and Entrepreneurship SPANGEMACHER Anne Anne.SPANGEMACHER@ec.europa.eu 2015 561510-EPP-1-2015-1-AT-EPPKA2-CBHE-JP Strategic support on strengthening the quality assurance structures at the private higher education institutions in Albania ENCISO Belen
2016 574219-EPP-1-2016-1-UK-EPPKA2-CBHE-JP THE UNIVERSITY COURT OF THE UNIVERSITY OF ABERDEEN BRUNO Giordana 2016 574220-EPP-1-2016-1-ES-EPPKA2-CBHE-JP UNIVERSIDAD PABLO DE OLAVIDE VALLE CASANOVA Eva 2016 574243-EPP-1-2016-1-PT-EPPKA2-CBHE-JP UNIVERSIDADE DE LISBOA HEINAMAKI Piia 2016 574253-EPP-1-2016-1-DE-EPPKA2-CBHE-JP HOCHSCHULE FUR TECHNIK WIRTSCHAFT UND KULTUR LEIPZIG HEINAMAKI Piia 2016 UNIVERSITE FRANCAISE EN ARMENIE FONDATION SAENZ DE MIERA Almudena 2016 574282-EPP-1-2016-1-FI-EPPKA2-CBHE-JP TURUN YLIOPISTO MOREAU Patricia 2016 574283-EPP-1-2016-1-LT-EPPKA2-CBHE-JP ALYTAUS KOLEGIJA/UNIVERSITY OF APPLIED SCIENCES DANTIN France
an Applicable Governmental Authority, in their respective roles of monitoring and/or enforcing compliance with mandatory and enforceable Reliability Standards in their respective jurisdictions. Evidence Retention: The following evidence retention period(s) identify the period of time an entity is required to retain specific evidence to demonstrate compliance. For instances where the evidence retention period specified below is shorter than the time since the last audit, the Compliance Enforcement Authority may ask an entity to provide other evidence to show that it was compliant for the full-time period since the last audit. The applicable entity shall keep data or evidence to show compliance as identified below unless directed by its Compliance Enforcement Authority to retain specific evidence for a longer period of time as part of an investigation. The Transmission Owners listed in section 4.1 shall keep data or evidence of Requirements 1-3 for three calendar years, or since the last audit, whichever is longer. Compliance Monitoring and Enforcement Program: As defined in the NERC Rules of Procedure, “Compliance Monitoring and Enforcement Program” refers to the identification of the processes that will be used to evaluate data or information for the purpose of assessing performance or outcomes with the associated Reliability Standard. Violation Severity Levels R # Violation Severity Levels Lower VSL Moderate VSL High VSL Severe VSL R1. The Transmission Owner’s TMIP did not include one of the items listed in Attachment A, as required in Requirement R1. The Transmission Owner’s TMIP did not include two of the items listed in Attachment A, as required in Requirement R1. The Transmission Owner’s TMIP did not include three of the items listed in Attachment A, as required in Requirement R1. The Transmission Owner’s TMIP did not include four or more of the items listed in Attachment A, as required in Requirement R1. R2. The Transmission Owner did not annually update its TMIP (within the 365 days following the last review), as required by R2. The Transmission Owner did not update its TMIP within the last one year and 1 day (within the 366 days following the last The Transmission Owner did not update its TMIP within the last two years and 1 day (within the 731 days following the last The Transmission Owner did not update its TMIP within the last three years and 1 day (within the 1095 days following the last
WSC approves forwarding document to the WECC Board of Directors November 15, 2017 WECC Board of Directors Approved December 6, 2017 NERC Posting for 45 days Closes December 18, 2017 Anticipated Actions Proposed Date NERC Board of Trustees approval Pending FERC approval Pending
Transmission Owners are not performing maintenance and inspection for one maintenance category identified in Attachment 1 FAC-501-WECC-1 as required in R3. High: There shall be a High Level of non-compliance if any of the following condition exists: The TMIP does not include associated Facilities for three of the Paths identified in the most current Table titled “Major WECC Transfer Paths in the Bulk Electric System” as required by R.1 and Transmission Owners are not performing maintenance and inspection for the missing Facilities. The TMIP does not include three maintenance categories identified in Attachment 1 FAC-501-WECC-1 as required by R.2 but Transmission Owners are performing maintenance and inspection for the missing maintenance categories. Transmission Owners are not performing maintenance and inspection for two maintenance categories identified in Attachment 1 FAC-501-WECC-1 as required in R3. Severe: There shall be a Severe Level of non-compliance if any of the following condition exists: The TMIP does not include associated Facilities for more than three of the Paths identified in the most current Table titled “Major WECC Transfer Paths in the Bulk Electric System” as required by R.1 and Transmission Owners are not performing maintenance and inspection for the missing Facilities. The TMIP does not exist or does not include more than three maintenance categories identified in Attachment 1 FAC-501-WECC-1 as required by R.2 but Transmission Owners are performing maintenance and inspection for the missing maintenance categories. Transmission Owners are not performing maintenance and inspection for more than two maintenance categories identified in Attachment 1 FAC-501-WECC-1 as required in R3. Version History – Shows Approval History and Summary of Changes in the Action Field Version Date Action Change Tracking 1 April 16, 2008 Permanent Replacement Standard for PRC-STD-005-1 1 October 29, 2008 NERC BOT conditional approval 1 April 21, 2011 FERC Approved in Order 751 2 TBD TBD TBD
review their TMIP annually as required by R.1.1. and inspection for the missing Facilities. R2. The TMIP does not include one maintenance category identified in Attachment A of this document as required by R.2; but, Transmission Owners are performing maintenance and inspection for the missing maintenance categories. The TMIP does not include two maintenance categories identified in Attachment A of this document as required by R.2 but Transmission Owners are performing maintenance and inspection for the missing maintenance categories. The TMIP does not include three maintenance categories identified in Attachment A of this document as required by R.2 but Transmission Owners are performing maintenance and inspection for the missing maintenance categories. The TMIP does not exist or does not include more than three maintenance categories identified in Attachment A of this document s required by R.2 but Transmission Owners are performing maintenance and inspection for the missing maintenance categories. R3. Transmission Owners do not have maintenance and inspection records as required by R.3 but have evidence that they are implementing and following their TMIP. Transmission Owners are not performing maintenance and inspection for one maintenance category identified in Attachment A of this document as required in R3. Transmission Owners are not performing maintenance and inspection for two maintenance categories identified in Attachment A of this document as required in R3. Transmission Owners are not performing maintenance and inspection for more than two maintenance categories identified in Attachment A of this document as required in R3. D. Regional Variances
review), as required by R2. review), as required by R2. R3. The Transmission Owner failed to adhere to: one transmission line maintenance item or one station maintenance item, as contained in its TMIP, as required in R3. The Transmission Owner failed to adhere to: 1) two transmission line maintenance items; or, 2) two station maintenance items; or 3) any combination of two items taken from the above list, for items contained in its TMIP, as required in R3. The Transmission Owner failed to adhere to: 1) three transmission line maintenance items; or, 2) three station maintenance items; or 3) any combination of three items taken from the above list, for items contained in its TMIP, as required in R3. The Transmission Owner failed to adhere to: 1) four or more transmission line maintenance items; or, 2) four or more station maintenance items; or, 3) any combination of four or more items taken from the above list, for items contained in its TMIP, as required in R3. D. Regional Variances None. E. Associated Documents None Version History – Shows Approval History and Summary of Changes in the Action Field Version Date Action Change Tracking 1 April 16, 2008 Permanent Replacement Standard for 1 October 29, 2008 NERC BOT conditional approval 1 April 21, 2011 FERC Approved in Order 751 2 TBD TBD
Ballot Pool Title Company Sector Vote Comments Created By WECC-0121A Arizona Public Service Company Transmission Owners Yes 0 Michelle Amarantos WECC-0121A Balancing Authority of Northern California Transmission Owners Yes 0 Joe Tarantino WECC-0121A Balancing Authority of Northern California Electricity Brokers, Aggregators, and Marketers Yes 0 Joe Tarantino WECC-0121A Bonneville Power Administration Electricity Brokers, Aggregators, and Marketers Yes 0 Andrew Meyers WECC-0121A Bonneville Power Administration Transmission Owners Yes 0 Kammy WECC-0121A Bonneville Power Administration Load-Serving Entities (LSEs) Yes 0 Rebecca Berdahl WECC-0121A British Columbia Hydro & Power Authority Electric Generators Yes 0 Adrian Andreoiu WECC-0121A British Columbia Hydro & Power Authority Load-Serving Entities (LSEs) Yes 0 Adrian Andreoiu WECC-0121A British Columbia Hydro & Power Authority Transmission Owners Yes 0 Adrian Andreoiu
WECC-0121A Public Service Company of Colorado (Xcel Energy) Electric Generators Yes 0 Gerry Huitt WECC-0121A Public Service Company of Colorado (Xcel Energy) Electricity Brokers, Aggregators, and Marketers 0 0 Carrie Simpson WECC-0121A Public Service Company of New Mexico Electric Generators Yes 0 Laurie Williams WECC-0121A Public Service Company of New Mexico Transmission Owners Yes 0 Laurie Williams WECC-0121A Public Service Company of New Mexico Load-Serving Entities (LSEs) Yes 0 Laurie Williams WECC-0121A Public Service Company of New Mexico Electricity Brokers, Aggregators, and Marketers Yes 0 Laurie Williams WECC-0121A Sacramento Municipal Utility District Electric Generators Yes 0 Joe Tarantino WECC-0121A Sacramento Municipal Utility District Transmission Dependent Utilities (TDUs) Yes 0 Joe Tarantino WECC-0121A Sacramento Municipal Utility District Transmission Owners Yes 0 Joe Tarantino WECC-0121A Sacramento Municipal Utility District Load-Serving Entities (LSEs) Yes 0 Joe Tarantino
WECC-0121A Sacramento Municipal Utility District Electricity Brokers, Aggregators, and Marketers Yes 0 Joe Tarantino WECC-0121A Salt River Project Electricity Brokers, Aggregators, and Marketers Yes 0 Bobby Olsen WECC-0121A Salt River Project Load-Serving Entities (LSEs) Yes 0 Robert Kondziolka WECC-0121A Salt River Project Electric Generators Yes 0 Kevin Nielsen WECC-0121A Seattle City Light Transmission Dependent Utilities (TDUs) Yes 0 Hao Li WECC-0121A Tri-State Generation & Transmission - Reliability Load-Serving Entities (LSEs) 0 0 Janelle Gill WECC-0121A Tri-State Generation & Transmission - Reliability Transmission Owners 0 0 Tracy Sliman WECC-0121A Tucson Electric Power Transmission Owners Yes 0 John Tolo WECC-0121A Tucson Electric Power Load-Serving Entities (LSEs) Yes 0 John Tolo WECC-0121A Tucson Electric Power Electric Generators Yes 0 John Tolo WECC-0121A US Bureau of Reclamation Transmission Owners 0 0 Wendy Center WECC-0121A US Bureau of Reclamation Electric Generators 0 0 Wendy Center
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adjustments within 120 days. recalculations and adjustments within 150 days. recalculations and adjustments within 180 days. R3 Real-Time Operations Medium The Balancing Authority operated during a calendar quarter without ATEC in service for more than an accumulated 24 hours, but less than or equal to 72 hours. The Balancing Authority operated during a calendar quarter without ATEC in service for more than an accumulated 72 hours, but less than or equal to 120 hours. The Balancing Authority operated during a calendar quarter without ATEC in service for more than an accumulated 120 hours, but less than or equal to 168 hours The Balancing Authority operated during a calendar quarter without ATEC in service for more than an accumulated 168 hours. R4 Operations Medium The Balancing Authority did not compute PIIhourly, PIIaccum, and IATEC within 50 minutes, but made the required calculations in less than or equal to two hours. The Balancing Authority did not compute PIIhourly, PIIaccum, and IATEC within two hours, but made the required calculations in less than or equal to four hours. The Balancing Authority did not compute PIIhourly, PIIaccum, and IATEC within four hours, but made the required calculations in less than or equal to six hours. The Balancing Authority did not compute PIIhourly, PIIaccum, and IATEC within six hours. R5 Real-Time Operations Medium N/A N/A N/A The Balancing Authority is not able to change its AGC operating mode
Table of Compliance Elements R # Time Horizon VRF Violation Severity Levels Lower VSL Moderate VSL High VSL Severe VSL R1 Operations Assessment Medium Following the conclusion of each month each Balancing Authority’s absolute value of PIIaccum for either the On-Peak period or Off-Peak period exceeded 150%, but was less than or equal to 160% of the previous calendar year’s Demand or peak generation for generation-only Balancing Authorities. Following the conclusion of each month each Balancing Authority’s absolute value of PIIaccum for either the On-Peak period or Off-Peak period exceeded 160%, but was less than or equal to 170% of the previous calendar year’s Peak Demand or peak generation for generation-only Balancing Authorities. Following the conclusion of each month each Balancing Authority’s absolute value of PIIaccum for either the On-Peak period or Off-Peak period exceeded 170%, but was less than or equal to 180% of the previous calendar year’s Peak Demand or peak generation for generation-only Balancing Authorities. Following the conclusion of each month each Balancing Authority’s absolute value of PIIaccum for either the On-Peak period or Off-Peak period exceeded 180% of the previous calendar year’s Peak Demand or peak generation for generation-only Balancing Authorities. R2 Operations Assessment Medium The Balancing Authority did not recalculate PIIhourly and adjust the PIIaccum within 90 days of the discovery of the error; but made the required recalculations and adjustments within 120 days. The Balancing Authority did not recalculate PIIhourly and adjust the PIIaccum within 120 days of the discovery of the error; but made the required recalculations and adjustments within 150 days. The Balancing Authority did not recalculate PIIhourly and adjust the PIIaccum within 150 days of the discovery of the error; but made the required recalculations and adjustments within 180 days. The Balancing Authority did not recalculate PIIhourly and adjust PIIaccum within 180 days of the discovery of the error.
R # Time Horizon VRF Violation Severity Levels Lower VSL Moderate VSL High VSL Severe VSL telemetry); Tie Line Bias; or Tie Line Bias plus Time Error control (used in ATEC mode). R6 Operations Assessment Medium N/A N/A N/A When making adjustments to hourly Inadvertent Interchange or TE, the Balancing Authority did not recalculate the PIIhourly and the PIIaccum for the and Off-Peak periods. R7 Operations Assessment Medium N/A N/A N/A When making any month-end meter reading adjustments to Inadvertent Interchange, the Balancing Authority did not make the same adjustment to the PIIaccum.
Compliance 1. Compliance Monitoring Process 1.1 Compliance Monitoring Responsibility Compliance Enforcement Authority 1.2 Compliance Monitoring Period Compliance Enforcement Authority may use one or more of the following methods to assess compliance: - Misoperation Reports - Reports submitted quarterly - Spot check audits conducted anytime with 30 days notice given to prepare - Periodic audit as scheduled by the Compliance Enforcement Authority - Investigations - Other methods as provided for in the Compliance Monitoring Enforcement Program 1.2.1 The Performance-reset Period is one calendar month. 1.3 Data Retention Reliability Coordinators, Transmission Owners, and Generation Owners shall keep evidence for Measures M1 and M2 for five calendar years plus year to date. 1.4. Additional Compliance Information None. 2. Violation Severity Levels R1 Lower Moderate High Severe System Operating personnel of the Transmission Owner or Generator Owner did not review the Protection System Operation or RAS operation within 24 hours but did review the Protection System Operation or RAS operation within six business days. System Operating personnel of the Transmission Owner or Generator Owner did not review the Protection System operation or RAS operation within six business days. System Protection personnel of the Transmission Owner and Generator Owner did not analyze the Protection System operation or RAS operation within 20 business days but did analyze the Protection System operation or RAS operation within 25 business days. System Protection personnel of the Transmission Owner or Generator Owner did not analyze the Protection System operation or RAS operation within 25 business days. R2.1 and R2.2.1 Lower Moderate High Severe
Attachment N - Final Ballot Pool Results Guidance Document Attachment O - Optional File Name: Not Used Minority Issues Attachment P File Name: WECC-0127 VAR-002-WECC-2 Request to Retire Attachment P - Minority Issues WECC Standards Committee Roster Attachment Q File Name: WECC-0127 VAR-002-WECC-2 Request to Retire Attachment Q - WECC Standards Committee Roster Responses to Comments – WECC Attachment R File Name: WECC-0127 VAR-002-WECC-2 Request to Retire Attachment R1 – Responses to Comments WECC Attachment R2 – Responses to Comments NERC FERC Issues Table Attachment S – Optional File Name: Not Used. Additional Supporting Documentation Attachment T File Name: Not Used. Petition Filing (FERC) Attachment U – Optional File Name: *Applicable governmental authorities in the United States, Canada, and Mexico To be provided by NERC. The above documents have been provided to NERC in MS Word format. Not used A Guidance Document is not provided with this filing. VAR-002-WECC-2 is proposed for retirement.
Table of Compliance Elements R Time Horizon VRF Violation Severity Levels Lower VSL Moderate VSL High VSL Severe VSL R1 Operational Assessment Medium There shall be a Lower Level of non-compliance if AVR is in service less than 98% but at least 90% or more of all hours during which the synchronous generating unit or synchronous condenser is on line for each calendar quarter. There shall be a Moderate Level of non- compliance if AVR is in service less than 90% but at least 80% or more of all hours during which the synchronou s generating unit or synchronou s condenser is on line for each calendar quarter. There shall be a High Level of non- compliance if AVR is in service less than 80% but at least 70% or more of all hours during which the synchronous generating unit or synchronous condenser is on line for each calendar quarter. There shall be a Severe Level of non- complian ce if AVR is in service less than 70% of all hours during which the synchron ous generatin g unit or synchron ous condense r is on line for each calendar quarter.
Analysis Table: Requirement R1 Applicable Entities and Facilities Covered Elsewhere WECC Standard NERC Standards Narrative VAR-002-WECC-2 Applicability 4.1 Generator Operators 4.2 Transmission Operators that operate synchronous condensers 4.3 This VAR-002-WECC-2 Standard only applies to synchronous generators and synchronous condensers that are connected to the Bulk Electric System. VAR-001-4.2 Applicability 4.1 Transmission Operators 4.2 Generator Operators within the Western Interconnection (for the WECC Variance) VAR-002-4.1 Applicability 4.1 Generator Operator 4.2 Generator Owner The Applicable Entities of the WECC Standard are addressed in VAR-001-4.2 and Whereas VAR-002-WECC-2 specifically identifies generators and synchronous condensers as the applicable facilities, these specific assets need not be called out. Rather, by setting the voltage schedule as a results-oriented goal, the Transmission Operator can allow for an array of assets to deploy without confining the resources to a specific list. Analysis Table: Requirement R1 AVR in Service and Controlling – Covered Elsewhere VAR-002-WECC-2 VAR-002-4 VAR-001-4.1 Narrative Generator Operator and Transmission Operator Generator Operator Transmission Operator
condenser, and the AVR is unavailable for service. R1.10. If AVR exhibits instability due to operation of a Load Tap Changer (LTC) transformer in the area, the Transmission Operator may authorize the Generator Operator to operate the excitation system in modes other than automatic voltage control until the system configuration changes. [R1.10] Other than start up, shutdown, or testing. Section 3: Existing Standard Proposed for Retirement VAR-002-WECC-2 A. Introduction 1. Title: Automatic Voltage Regulators (AVR) 2. Number: VAR-002-WECC-2 3. Purpose: To ensure that Automatic Voltage Regulators on synchronous generators and condensers shall be kept in service and controlling voltage.
R Time Horizon VRF Violation Severity Levels Moderate VSL High VSL Severe VSL R1 Operational Assessment Medium There shall be a Lower Level of non-compliance if AVR is in service less than 98% but at least 90% or more of all hours during which the synchronous generating unit or synchronous condenser is on line for each calendar quarter. There shall be a Moderate Level of if AVR is in service less than 90% but at least 80% or more of all hours during which the generating unit or condenser is on line for each calendar quarter. There shall be a High Level of if AVR is in service less than 80% but at least 70% or more of all hours during which the synchronous generating unit or synchronous condenser is on line for each calendar quarter. There shall be a Severe Level of if AVR is in service less than 70% of all hours during which the unit or is on line for each calendar quarter. Version History Version Date Action Change Tracking 1 April 16, 2008 Permanent Replacement Standard for VAR-STD-002a-1 April 21, 2011 FERC Order issued approving VAR- 002-WECC-1 (FERC approval effective June 27, 2011; Effective Date July 1, 2011)
R Time Horizon VRF Violation Severity Levels Moderate VSL High VSL Severe VSL R1 Operational Assessment Medium There shall be a Lower Level of non-compliance if AVR is in service less than 98% but at least 90% or more of all hours during which the synchronous generating unit or synchronous condenser is on line for each calendar quarter. There shall be a Moderate Level of if AVR is in service less than 90% but at least 80% or more of all hours during which the generating unit or condenser is on line for each calendar quarter. There shall be a High Level of if AVR is in service less than 80% but at least 70% or more of all hours during which the synchronous generating unit or synchronous condenser is on line for each calendar quarter. There shall be a Severe Level of if AVR is in service less than 70% of all hours during which the unit or is on line for each calendar quarter. Version History Version Date Action Change Tracking 1 April 16, 2008 Permanent Replacement Standard for VAR-STD-002a-1
target value with an associated tolerance band). R6 Operations Planning Lower The Transmission Operator does not provide either the technical justification or timeframe for changing generator step-up tap settings. N/A N/A The Transmission Operator does not provide the technical justification and the timeframe for changing generator step-up tap settings.
E # Lower VSL Moderate VSL High VSL Severe VSL E.A.13 For the specified period, the Transmission Operator did not issue one of the voltage schedules listed in E.A.13 to at least one generation resource but less than or equal to 5% of the generation resources that are on-line and part of the BES in the Transmission Operator Area. For the specified period, the Transmission Operator did not issue one of the voltage schedules listed in E.A.13 to more than 5% but less than or equal to 10% of the generation resources that are on-line and part of the BES in the Transmission Operator Area. For the specified period, the Transmission Operator did not issue one of the voltage schedules listed in E.A.13 to more than 10% but less than or equal to 15% of the generation resources that are on-line and part of the BES in the Transmission Operator Area. For the specified period, the Transmission Operator did not issue one of the voltage schedules listed in E.A.13 to more than 15% of the generation resources that are and part of the BES in the Transmission Operator Area. E.A.14 The Transmission Operator did not provide a voltage schedule reference point for at least one but less than or equal to 5% of the generation resources in the Transmission Operator area. The Transmission Operator did not provide a voltage schedule reference point for more than 5% but less than or equal to 10% of the generation resources in the Transmission Operator Area. The Transmission Operator did not a voltage schedule reference point for more than 10% but less than or equal to 15% of the generation resources in the Transmission Operator Area. The Transmission Operator did not provide a voltage schedule reference point for more than 15% of the generation resources in the Transmission Operator Area. E. Interpretations None. F. Associated Documents None. Guidelines and Technical Basis For technical basis for each requirement, please review the rationale provided for each requirement.