DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 A. Introduction 1. Title: Automatic Underfrequency Load Shedding Requirements Deleted: Deleted: 10 Deleted: 20 9 2. Number: PRC 006 RFC 01. Purpose: To establish ReliabilityFirst requirements for automatic underfrequency Load shedding (UFLS) to support NERC Reliability Standard PRC-006. 4. Applicability: 4.1 Distribution Providers 4.2 Transmission Owners 4. Generator Owners 4.4 Planning Coordinators 5. (Proposed) Effective Date: Upon ReliabilityFirst Board Approval, the standard will be mandatory and enforceable (without monetary penalties for noncompliance) to applicable ReliabilityFirst members based on the PRC-006-RFC- 01 Implementation Plan and the enforcement mechanism will be as a Term Of Membership under the ReliabilityFirst By-Laws. B. Requirements R1 Upon regulatory approval, the standard will be mandatory and enforceable (with monetary penalties for non-compliance) to all applicable NERC registered entities within the ReliabilityFirst footprint based on the PRC-006-RFC-01 Implementation Plan Each Distribution Provider that has more than 50 feeders shall implement an automatic UFLS program for their facilities or each Distribution Provider (regardless of number of feeders) shall participate with one or more Distribution Providers to collectively implement by mutual agreement a single automatic UFLS program. Providers automatic UFLS program shall include the following: [Violation Risk Factor: High][Time Horizon: Long-term Planning] 1.1 Have the capability of shedding at least 25 percent of the Load. This shall be satisfied by implementing the load shedding capability based on the forecasted annual peak hour. 1.2 Shed Load in a minimum of three steps. 1. Size each step equally where the variance between steps shall be no more than two percent of forecasted annual peak hour Load (additional Load shedding required per Requirement R9 or Requirement R11 is excluded from this requirement). 1.4 The first frequency set point shall not be lower than 59. Hz and not be higher than 59.5 Hz. Deleted: (all generators with an individual nameplate rating or plants, including Wind Generating Stations, with an aggregate nameplate rating of 20 MVA or greater, connected at 69kV or above) Deleted: The first day of the first calendar quarter, one year after applicable regulatory approval Formatted: Font: Not Bold Deleted: ; or in those jurisdictions where no regulatory approval is required, the first day of the first calendar quarter one year after Board of Trustees adoption. Deleted: Formatted: Font: Not Bold Formatted: Indent: Left: 6 pt, Hanging: 6 pt, No bullets or numbering Deleted: Deleted: Upon Board Approval Deleted: Deleted: Deleted: include the following requirements Deleted: Deleted: at peak based on the forecasted annual peak hour. Deleted: sub-requirement Deleted: may Deleted: planning and Deleted: Check for definition Formatted: Highlight Deleted: ( Deleted:. Deleted: ) Deleted: Deleted: 4 Deleted: be Approved: XXXX XX, 201X Page 1 of 19 Effective Date: XX/XX/XX
Deleted: Standard PRC-006- RFC-... [1] DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 Deleted: be ot be... [2] Deleted: or Requirement R11R4... [] R2 R 1.5 The last frequency set point shall not be lower than 58.5 Hz and not be higher than 58.7 Hz (additional Load shedding required per Requirement R9 or Requirement R11 is excluded from this requirement). 1.6 The difference between frequency set points shall be at least 0.2 Hz but no greater than 0.5 Hz (additional Load shedding required per Requirement R9 or Requirement R11 is excluded from this requirement). 1.7 Intentional relay time delay shall be no greater than 20 cycles. For installations where motor loads or distributed generation may be isolated, additional supervision (e.g. undercurrent) shall be used to avoid false operation during Fault isolation. 1.8 Undervoltage inhibit (where applicable) shall be set as low as practical, but shall not be greater than 75 percent of nominal primary voltage. Each Distribution Provider, that has less than or equal to 50 feeders and has not aggregated their Load with other Distribution Providers to implement a collective UFLS program, shall implement a modified UFLS program as defined below. Providers modified automatic UFLS program shall include the following: [Violation Risk Factor: High][Time Horizon: Long-term Planning] 2.1 Have the capability of shedding at least 25 percent of the Load. This shall be satisfied by implementing the load shedding capability based on the forecasted annual peak hour. 2.2 Intentional relay time delay shall be no greater than 20 cycles. For installations where motor loads or distributed generation may be isolated, additional supervision (e.g. undercurrent) shall be used to avoid false operation during Fault isolation. 2. Undervoltage inhibit (where applicable) shall be set as low as practical, but shall not be greater than 75 percent of nominal primary voltage. 2.4 Either of the following frequency set points: Single frequency set point at 59.0 Hz Two frequency set points, with approximately equal amounts of load, at 59.0 Hz and 58.7 Hz (the variance between steps shall be no more than five percent of forecasted annual peak hour Load) Each Transmission Owner shall provide automatic switching of its existing capacitor banks and reactors to control over-voltage as a result of an UFLS event in accordance with the assessment performed by the Planning Coordinator in Requirement R16. [Violation Risk Factor: Medium][Time Horizon: Long-term Planning] Deleted: or Requirement R114... [4] Deleted:... [5] Deleted: [Violation Risk Factor: High][Time... [8] Formatted... [6] Deleted: Each Transmission Owner owning... [7] Deleted: Formatted... [9] Formatted... [11] Formatted... [10] Formatted... [12] Formatted... [1] Formatted... [14] Formatted... [15] Formatted... [16] Deleted: does not comply with sub-requirements... [22] Formatted... [2] Deleted: Formatted... [21] Deleted: Deleted: 1 Deleted:.1 Deleted:. Deleted: 1 Deleted: Single frequency set point at 59.0... Hz [24] Deleted: Deleted: 1 Formatted... [17] Formatted... [18] Deleted: 5 Deleted: 1.5 Deleted: Deleted: If a Deleted: Each Distribution Provider, that has... less [19] Deleted: R4 Each Planning Coordinator shall have a documented methodology to determine areas of credible islanding. The methodology shall include the following: [Violation Risk Factor: Medium][Time Horizon: Long-term Planning] Approved: XXXX XX, 201X Page 2 of 19 Effective Date: XX/XX/XX Deleted: their Load with other Distribution... [20] Deleted:.2 Deleted: 5 Deleted:. Deleted: 2 Deleted: Two frequency set points, with equal... [25] Formatted... [26] Formatted... [27] 1.6 The difference between frequency... [28] Deleted: 2 Deleted: and implement a Deleted: ed Comment [A1]: if you are not defining "area" -... [29]
Deleted: Standard PRC-006- RFC-... [2] DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 Deleted: ]: Formatted... [] Formatted... [4] R5 R6 R7 R8 R9 4.1 Consideration of historical islanding scenarios 4.2 Consideration of areas with a limited number of connecting lines 4. Consideration of System Operating Limit interfaces which define importing areas 4.4 A process to involve stakeholders in the analysis and results Each Planning Coordinator shall make its credible island determination methodology available for inspection and technical review by those entities directly and materially affected by the reliability of ReliabilityFirst Bulk Electric System (BES), within 15 calendar days of the receipt of a request. [Violation Risk Factor: Lower][Time Horizon: Long-term Planning] Each Planning Coordinator shall provide a written response to that commenting entity that is materially affected by the reliability of ReliabilityFirst BES, within 45 calendar days of receipt of those comments. The response shall indicate whether a change will be made to the credible island determination methodology and, if no change will be made, the reason why. [Violation Risk Factor: Lower][Time Horizon: Long-term Planning] Each Planning Coordinator shall use the credible island determination methodology at least every five years to determine areas of credible islanding, which have a forecasted annual peak hour Load of greater than 1,000 MW, that are within or partially within their area of responsibility. [Violation Risk Factor: Medium][Time Horizon: Long-term Planning] Each Planning Coordinator shall supply the results of applying the island methodology within 0 calendar days of completion of the process to the Distribution Providers, Transmission Owners and Generator Owners in the identified areas of credible islanding. [Violation Risk Factor: Lower][Time Horizon: Long-term Planning] Each Planning Coordinator shall establish a mitigation plan that specifically addresses generation/load imbalances in the area of credible islanding (as determined in Requirement R7). The mitigation plan shall consist of one or both of the following: [Violation Risk Factor: Medium][Time Horizon: Long-term Planning] 9.1. Installation of additional UFLS capability of Distribution Providers in the island area so as to cover potential generation/load imbalances in excess of the 25 percent specified in R1.1 or R2.1where the amount of additional UFLS capability Load to be shed in the island area and the corresponding Load shedding step sizes, relay trip and time delay settings of the additional UFLS capability shall be determined by engineering assessments. Each Planning Coordinator shall exempt Distribution Providers from installing total UFLS capability greater than 50 percent of their forecasted annual peak hour Load in the island area. Approved: XXXX XX, 201X Page of 19 Effective Date: XX/XX/XX Formatted... [5] Deleted: H Formatted... [6] Deleted: A Deleted: Formatted... [7] Formatted... [8] Deleted: S Formatted... [9] Formatted... [40] Formatted... [41] Deleted: 2.1 Deleted: business Formatted... [42] Deleted: 2.2 If entities directly and materially... [4] Formatted... [44] Formatted... [45] 2. Deleted: ach Planning Coordinator shall... use [46] Deleted: Formatted... [47] Formatted... [48] Deleted: 7 Deleted: 2.4 Deleted: Deleted: s of the determination (... [49] Deleted: Deleted: ) eliabilityfirst footprint of Deleted: (or sub areas) Deleted: 8 Deleted: Deleted: Distribution Provider, Transmission... [50] Deleted: (or sub areas) Deleted: of credible islanding (as determined... in [51] Formatted... [52] Deleted: participate in the engineering assessment... [5] Formatted... [54] Deleted: 2. The mitigation plan must be... [55] Formatted... [56] Deleted: h of the following: [Violation Risk... [57].1 Distribution Providers shall... utilize [58] Deleted: Deleted: Deleted: 8 Deleted: 1.1... [59] Deleted: Install nstallation of additional UFLS... [60] Deleted: ( Deleted: he island area and the corresponding... [61] Deleted: )
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 Deleted: Standard PRC-006- RFC-... [62] R10 R11 R12 R1 9.2 Apply other methods of balancing Load and resources. Each Distribution Provider, Transmission Owner and Generator Owner in an identified area of credible islanding (as determined in Requirement R7) shall participate in the establishment of the mitigation plan (as required in Requirement R9). [Violation Risk Factor: Lower][Time Horizon: Long-term Planning] Each Distribution Provider, Transmission Owner and Generator Owner shall implement the mitigation plan as determined in Requirement R9 within three years of the completion of the mitigation plan. [Violation Risk Factor: Medium][Time Horizon: Long-term Planning] Each Generator Owner that owns a unit(s) with automatic underfrequency protection installed, shall set such protection in accordance with the minimum tripping time delays in Table 1, or if automatic underfrequency protection is not installed, the Generator Owner s underfrequency tripping procedures shall conform to Table 1: [Violation Risk Factor: Medium][Time Horizon: Long-term Planning] Table 1 Frequency (Hz) Minimum Time Delay (Sec) 59.5 Automatic Frequency Dependent Tripping Not Permitted <59.5 to > 59.2 2,700.0 59.2 to > 58.5 120.0 58.5 to > 58.2 15.0 58.2 Owner s Discretion 12.1 It is the sole responsibility of each Generator Owner to ensure that the time vs. frequency requirement listed in Table 1 is met. In those cases where a generator must be tripped for its own underfrequency protection outside the specifications in the above Table 1, each Generator Owner may become compliant by arranging for Load shedding, to be installed by mutual agreement with Distribution Providers, in addition to that required in Requirement R1. 12.2.1 This additional Load shedding shall be equal to or greater than the generator MW dispatch, instituted at the same frequency and time as the generator would be expected to trip. 12.2.2 If the generator is located within a credible island, arrangement for additional Load shedding shall be within the credible island. Each Planning Coordinator shall establish and maintain an UFLS database. [Violation Risk Factor: Lower][Time Horizon: Long-term Planning] 1.1 The database shall be updated every five calendar years or as required by changes in system conditions. Deleted: 8.1.1 Formatted: Don't keep lines together.1.1.1 Deleted: Identified areas (or sub areas) of credible islanding with a forecasted annual... [6].1.1.2 Deleted: 8.1.2 Distribution Providers are not... [64].1.1. Upon determination of... a new [65] Deleted: Deleted:.1.2 Deleted: 8 Deleted:... [66].1.2.1 Deleted: 8.2.1 Identified areas (or sub areas)... of [67] Formatted... [68] Formatted: Indent: Left: 0 pt, First line: 0 pt.1.2.2 Deleted: 8.2.2 Upon determination of a new... [69].2 Each Generator Owner in... [70] Formatted: Indent: Hanging: 6 pt Deleted: 9 Each Distribution Provider,... [71] Formatted: Not Highlight Deleted: of identification of a new credible... island [72] Deleted: 4 Deleted: High Deleted: 4 4 Deleted: 1 4 Deleted: 1 Deleted: 5 Deleted: 1 Each Planning Coordinator shall... [7] 5 1 The database shall be updated... [74] 1.2 The database shall include the areas of credible islanding determined in Requirement R7. 5 2 The database shall include the... [75] Approved: XXXX XX, 201X Page 4 of 19 Effective Date: XX/XX/XX
Deleted: Standard PRC-006- RFC-... [76] DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11. R14 R15 R16 Each Distribution Provider and Transmission Owner required to comply with the relevant sections of Requirement R1, Requirement 2 or Requirement R11,shall provide their Planning Coordinator the following data in a pre-arranged format to populate the UFLS database within 45 calendar days of the Planning Coordinators request: [Violation Risk Factor: Lower][Time Horizon: Long-term Planning] 14.1 Frequency trip points. 14.2 Percent of forecasted peak hour Load dropped at each trip point. 14. Relay operating time delay, intentional and unintentional. 14.4 Circuit breaker operating time. 14.5 UFLS relay undervoltage inhibit voltage level. 14.6 Information describing non-fault clearing tie-tripping schemes, islanding schemes, automatic load-restoration schemes, additional Load shedding schemes or any other schemes that are part of or impact the UFLS programs in sufficient detail to allow modeling for dynamics simulations 14.7 Any underfrequency trip set points, all overvoltage trip set points and time delays of capacitor banks connected to the BES. Each Generator Owner required to comply with the relevant sections of Requirement R11 or Requirement R12 shall provide their Planning Coordinator the following data in the pre-arranged format to populate the UFLS database within 45 calendar days of the Planning Coordinators request: [Violation Risk Factor: Lower][Time Horizon: Long-term Planning] 15.1 Underfrequency trip set points and time delays of each generating unit. 15.2 Information describing any other schemes that are part of or impact the UFLS program. Each Planning Coordinator shall perform and document an assessment of the effectiveness of the design and implementation of the UFLS programs within its footprint. This assessment shall include effects of neighboring Planning Coordinator areas and may be performed jointly with other Planning Coordinators. This assessment shall be conducted periodically at least every five years or as required by changes in system conditions and shall include, but not be limited to the following: [Violation Risk Factor: Medium][Time Horizon: Longterm Planning] 16.1 A review of the current frequency set points and timing. 16.2 A review of automatic switching of existing capacitor banks and reactors to control over-voltage as a result of an UFLS event Approved: XXXX XX, 201X Page 5 of 19 Effective Date: XX/XX/XX Deleted: 2 Deleted: 6 Each Distribution Provider, nd... [77] Deleted:, Requirement R11 or R4... [78] Deleted: populate Deleted: needed Deleted: s FLS database ( ithin 45 calendar... [79] Deleted:, in the pre-arranged format Deleted:, as follows Deleted: : 6.1 Each Distribution Provider... and [80] Formatted... [81] Deleted:... [82] Deleted: 6 Deleted:.1 Formatted... [8] Deleted: 6 Deleted: 1.2 Deleted: T ip pp... [84] Formatted... [85] Deleted: 6 Deleted: 1. Formatted... [86] Deleted: 6 Deleted: 1.4 Formatted... [87] Deleted: 6 Deleted: 1.5 Formatted... [88] Deleted: 6 Deleted: 1.6 Formatted... [89] Deleted: 6 Deleted: 1. Formatted... [90] Deleted: 6 Deleted: Deleted:.2 Deleted: supply the following information... as [91] Deleted: 5R6.2 1 Underfrequency trip... set [92] Formatted... [9] 6.2 Deleted: 4 Deleted: 7 Each Planning Coordinator shall... [94] Deleted: Lower [Time Horizon: Long-term... [95] Formatted... [96] Deleted: 4 7 Deleted:. Formatted... [97]
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 Deleted: Standard PRC-006- RFC-... [100] R17 R18 16. Dynamic simulation of possible Disturbances that cause the Planning Coordinators systems or portions of the Planning Coordinators systems to experience imbalances between Load and generation sufficient to cause activation of one or more steps of UFLS. Each Distribution Provider, Transmission Owner and Generator Owner for which UFLS or other protection system changes are recommended by the Planning Coordinators assessment, (as determined in Requirement R16) shall complete the changes within three years of the completion date of the Planning Coordinators assessment (as determined in Requirement R16). [Violation Risk Factor: Medium][Time Horizon: Long-term Planning] Each Planning Coordinator shall coordinate UFLS programs with neighboring Planning Coordinators and entities responsible for UFLS assessment. Coordination of UFLS programs shall be accomplished by the following; [Violation Risk Factor: Lower][Time Horizon: Long-term Planning] 18.1 Each Planning Coordinator shall provide the data in the database required in Requirement R14 and Requirement R15 to neighboring Planning Coordinators within ReliabilityFirst. 18.2 Each Planning Coordinator shall provide the data in the database required in Requirement R14 and Requirement R15 and assessment results required in Requirement R16 to neighboring entities responsible for UFLS assessment external to ReliabilityFirst. 18. Each Planning Coordinator shall request UFLS data and assessment results from neighboring entities responsible for UFLS assessment external to ReliabilityFirst. C. Measures The following documentation will be used to determine compliance with the above requirements. M1 M2 Each Distribution Provider that has more than 50 feeders shall have dated evidence such as lists summarizing feeder load armed with UFLS relays, lists with UFLS relay settings, or other dated documentation showing they implemented an automatic UFLS program for their facilities or shall have shall have dated evidence such as a dated mutual agreement along with lists summarizing feeder load armed with UFLS relays, lists with UFLS relay settings, or other dated documentation showing they participated with one or more Distribution Providers to collectively implement a single automatic UFLS program per Requirement R1. Each Distribution Provider that has less than or equal to 50 feeders and has not aggregated their Load with other Distribution Providers shall have dated evidence such as lists summarizing feeder load armed with UFLS relays, lists with UFLS relay settings, or other dated documentation showing they implemented a modified automatic UFLS program for their facilities per Requirement R2. Deleted: 4 7 2... [101] Deleted:. Dynamic simulation of possible... [102] Formatted: Highlight Formatted: Indent: Left: 0 pt, First line: 0 pt Formatted: Not Highlight Deleted: 14 7 Deleted:.4 Deleted: Formatted... [10] Deleted: If Formatted: Not Highlight Deleted: FLS or other protection system... [104] Formatted... [105] Deleted:, Formatted: Not Highlight Deleted: the responsible entity has Formatted... [106] Deleted: from he approval... [107] Formatted: Not Highlight Deleted: report Formatted... [108] Deleted: to complete the changes Deleted: Deleted: 5 Deleted: 8 Deleted:. oordination of UFLS programs... [109] shall 8 1 Each Planning Coordinator... [110] shall 8 2 Each Planning Coordinator... [111] shall 8 Formatted... [112] Deleted: Measures must include examples... [11] the Formatted: Deleted: and Transmission Owner Formatted... [114] Deleted: Formatted... [115] Deleted: they comply with all applicable... [116] Formatted... [117] Approved: XXXX XX, 201X Page 6 of 19 Effective Date: XX/XX/XX
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 M Each Transmission Owner shall have dated evidence such as relay settings, tripping logic or other dated documentation that it implemented automatic switching of its existing capacitor banks and reactors in order to control overvoltage as a result of underfrequency load shedding event per Requirement R. Deleted: Deleted: 10 Deleted: 20 9 Formatted: Formatted: M4 M5 M6 M7 M8 M9 M10 M11 M12 Each Planning Coordinator shall have evidence of a documented methodology to determine areas of credible islanding per Requirement R4. Each Planning Coordinator shall have dated evidence such as letters, memorandums, meeting minutes, e-mails or other dated documentation that it made its credible island determination methodology available for inspection and technical review by those entities directly and materially affected by the reliability of ReliabilityFirst Bulk Electric System (BES), within 15 business days of the receipt of a request Requirement R5. Each Planning Coordinator shall have dated evidence such as letters, memorandums, e-mails or other dated documentation that it provided a written response to the commenting entity, within 45 calendar days of receipt of those comments per Requirement R6. Each Planning Coordinator shall have dated evidence such as reports, memorandums, e-mails, or other documentation that it used the credible island determination methodology at least every five years to determine areas of credible islanding within their area of responsibility per Requirement R7. Each Planning Coordinator shall have dated evidence such as letters, memorandums, e-mails or other dated documentation that it supplied the results of applying the island methodology within 0 days of completion of the process to the Distribution Providers, Transmission Owners and Generator Owners in the identified areas of credible islanding per Requirement R8. Each Planning Coordinator shall have dated evidence such as reports or other documentation of a mitigation plan that specifically addresses generation/load imbalances in the area of credible islanding per Requirement R9. Each Distribution Provider, Transmission Owner and Generator Owner in an identified area of credible islanding shall have evidence such as letters, memorandums, meeting minutes, e-mails, reports or other dated documentation that it participated in the establishment of the mitigation plan per Requirement R10. Each Distribution Provider, Transmission Owner and Generator Owner shall have dated evidence such as lists summarizing feeder load armed with UFLS relays, lists with UFLS relay settings, or other dated documentation that it implemented the mitigation plan within three years of the completion of the mitigation plan per Requirement R9. Each Generator Owner owns a unit(s) with automatic underfrequency protection installed, shall have evidence such as lists or other documentation that the frequency protection settings conforms to Table 1 or if automatic underfrequency protection is not installed, the Generator Owner shall have dated evidence such Deleted: 2 Formatted: Deleted: documentation detailing processes to assess areas of credible islanding giving consideration to the items listed in R2. Each Planning Coordinator shall have evidence that an assessment to determine if credible islands exist was performed within the past 5 years. Each Planning Coordinator shall have documentation that the results of the assessment were supplied to the applicable Distribution Providers, Transmission Owners and Generator Owners. Deleted: Formatted: Formatted: Formatted: Formatted: Formatted: Formatted: Formatted: Formatted: Formatted: Deleted: Each Distribution Provider, Transmission Owner and Generator Owner in the ReliabilityFirst footprint in identified areas (or sub areas) of credible islanding (as determined in R2) shall have documentation of participation in the engineering assessment and documentation of installed applicable UFLS capability as required in R. Formatted: Indent: Left: 0 pt, First line: 0 pt Deleted: 4 Formatted: Formatted: Formatted: Deleted: it complies with the frequency protection settings of generators Formatted: Approved: XXXX XX, 201X Page 7 of 19 Effective Date: XX/XX/XX
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 Deleted: Standard PRC-006- RFC-... [118] M1 M14 M15 as underfrequency tripping or other documentation that its underfrequency tripping procedures conforms to Table 1 per Requirement R12. Each Planning Coordinator shall have dated evidence such as a UFLS database, data requests, data input forms, or other dated documentation to show that it established and maintained an UFLS database per Requirement R1. Each Distribution Provider and Transmission Owner required to comply with the relevant sections of Requirement R1, Requirement 2 or Requirement R11 shall have dated evidence such as responses to data requests, lists, letters or other dated documentation that it provided data in the pre-arranged format to its Planning Coordinator to populate the UFSL database within 45 days of the Planning Coordinators request, per Requirement R14. Each Generator Owner, required to comply with the relevant sections of Requirement R11 or Requirement R12, shall have dated evidence such as responses to data requests, lists, letters or other dated documentation that it provided data in the pre-arranged format to its Planning Coordinator to populate the UFLS database within 45 days of the Planning Coordinators request, per Requirement R15. Formatted: Deleted: has made arrangements for additional Load shedding, if appropriate, as required in R4. Formatted: Indent: Left: 6 pt, Hanging: 6 pt Deleted: 5 Formatted... [119] Deleted: as required in R5. Deleted: 6 Each respective istribution... [120] Formatted... [121] Deleted: and Generator Owner Formatted... [122] Deleted: that the information as required in R6 was supplied to the Planning Coordinator to populate the UFLS Database. Formatted... [12] M16 M17 M18 Each Planning Coordinator shall have dated evidence such as reports or other documentation of an assessment of the effectiveness of the design and implementation of the UFLS programs within its footprint which includes effects of neighboring Planning Coordinator areas and is conducted periodically at least every five years or as required by changes in system conditions per Requirement R16. Each respective Distribution Provider, Transmission Owner and Generator Owner shall have dated evidence such as lists summarizing feeder load armed with UFLS relays, lists with UFLS relay settings, lists with other protection system settings or other dated documentation that it made the UFLS or other protection system changes, which were recommended by the Planning Coordinators assessment, within three years of the completion date of the Planning Coordinators assessment, per Requirement R17. Each Planning Coordinator shall have dated evidence such as letters, memorandums, meeting minutes, e-mails or other dated documentation that it coordinated its UFLS programs with neighboring Planning Coordinators and entities responsible for UFLS assessment per Requirement R18. D. Compliance 1 Compliance Monitoring Process 1.1 Compliance Enforcement ity Compliance Monitor: ReliabilityFirst Corporation 1.2 Data Retention Applicable entities shall retain information for five years. Deleted: 7 Formatted: Deleted: evidence that the assessment of the design effectiveness and implementation of UFLS as required by R7 has been completed and documented. Formatted... [124] Deleted: 8 Formatted... [125] Deleted: that the data in the database and relevant study results have been exchanged with neighboring Planning Coordinators as required by R8. Formatted: Indent: First line: 6 pt, No bullets or numbering Deleted: Compliance Monitoring Responsibility Formatted: Indent: Left: 90 pt, First line: 18 pt Formatted: Font: Not Italic Deleted: Deleted: 1.2 Compliance Monitoring Period and Reset On request (within 45 calendar days) Deleted: Formatted: Font: Bold Deleted: F Approved: XXXX XX, 201X Page 8 of 19 Effective Date: XX/XX/XX
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 If an Applicable entity is found non-compliant, they shall keep information related to the non-compliance until found compliant. The Compliance Monitor shall retain any audit data for five years. Deleted: Deleted: 10 Deleted: 20 9 Formatted: Indent: Left: 108 pt Deleted: 1. Compliance Monitoring and Assessment Processes Compliance Audits Self-Certifications Spot Checking Compliance Violation Investigations Self-Reporting Complaints 1.4 Additional Compliance Information None 2 Violation Severity Levels Req. Number R1 Provider total UFLS is less than 25% but greater than or equal to 2% of the Load as Requirement 1, Part 1.1 VIOLATION SEVERITY LEVEL LOWER MODERATE HIGH SEVERE Provider total UFLS is Provider total UFLS is Provider total UFLS is less than 2% but less than 21% but less than 18% of the greater than or equal to greater than or equal to Load, as required in 21% of the Load as 18% of the Load, as Requirement 1, Part 1.1 required in Requirement required in Requirement 1, Part 1.1 1, Part 1.1 Provider intentional relay time delays are greater than 20 cycles, but less than or equal to 22 cycles, as required in Requirement 1, Part 1.7 Provider UFLS program steps are not equal to within 2% of the forecasted annual peak hour Load as required in Requirement R1, Part 1. Provider intentional relay time delays are greater than 22 cycles, but less than or equal to 24 cycles, as required in Requirement 1, Part 1.7 Provider difference between frequency set points is less than 0.2 Hz or greater than 0.5 Hz, as required in Requirement 1, Part 1.6 Provider undervoltage inhibit (where applicable) is set greater than 75 % of nominal primary voltage, as required in Requirement 1, Part 1.8 Provider UFLS program contains less than Deleted: three steps, as required in Requirement 1, Part 1.2 Provider first frequency R1.5; set point of the UFLS program is less than 59. Hz per Requirement 1, part 1.4, Provider last set point is Formatted: Indent: Left: 6 pt, No bullets or numbering Deleted: 4 Formatted: Indent: Left: 90 pt, First line: 18 pt Formatted: Indent: Left: 72 pt, First line: 6 pt Formatted: Indent: Left: 108 pt Formatted: Indent: Left: 90 pt, First line: 18 pt Formatted: Indent: Left: 72 pt, First line: 6 pt Formatted: Indent: Left: 6 pt, No bullets or numbering Deleted: Additional Compliance Information None Formatted: No bullets or numbering Formatted: Font: Bold Formatted: Font: Not Bold Deleted: as required in R1.1; Deleted: required in R1.1; Formatted: Font: Not Bold Formatted: Font: Not Bold 1.1; Deleted: as required in R1.1; Formatted: Font: Not Bold Formatted: Font: Not Bold Formatted: Font: Not Bold Deleted: as required in R1.2, except as allowed by Formatted: Font: Not Bold 1.7 Deleted: as required in R1.6; Deleted: as required in R1., except as allowed by R1.5; Formatted: Font: Not Bold Formatted: Font: Not Bold Deleted: as required in R1.7 Approved: XXXX XX, 201X Page 9 of 19 Effective Date: XX/XX/XX
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 Provider intentional relay time delays are greater than 24 cycles, but less than or equal to 0 cycles, as required in Requirement 1, Part 1.7 Deleted: Deleted: 10 Deleted: 20 less than 58.5 Hz or greater than 58.7 Deleted: Hz, as 09 required in Requirement 1, Part 1.5 Provider intentional relay time delays are greater than 0 cycles, by R1.5; as required in Requirement 1, Part 1.7 Provider failed to implement an automatic UFLS program for their facilities Deleted: as required in R1.8; Transmission Owners capacitor banks connected to the BES are not tripped as specified in R1.9; Formatted: Font: Not Bold Formatted: Font: Not Bold Deleted: Provider first frequency set point of the UFLS program is less than 59. Hz, or the last set point is less than 58.5 Hz or greater than 58.7 Hz, as required in R1.4, except as allowed Formatted: Font: Not Bold Deleted: as required in R1.7 Deleted: as required in R1.7 R2 Provider total UFLS is less than 25% but greater than or equal to 2% of the Load as required in Requirement 2, Part 2.1 Provider total UFLS is less than 2% but greater than or equal to 21% of the Load as required in Requirement 2, Part 2.1 Provider total UFLS is less than 21% but greater than or equal to 18% of the Load, as required in Requirement 2, Part 2.1 Provider failed to participate with one or more Distribution Providers to collectively implement by mutual agreement a single automatic UFLS program Provider total UFLS is less than 18% of the Load, as required in Requirement 2, Part 2.1 Provider intentional relay time delays are greater than 20 cycles, but less than or equal to 22 cycles, as required in Requirement 2, Part 2.2 Provider intentional relay time delays are greater than 22 cycles, but less than or equal to 24 cycles, as required in Requirement 2, Part 2.2 Provider intentional relay time delays are greater than 24 cycles, but less than or equal to 0 cycles, as required in Requirement 2, Part 2.2 Provider intentional relay time delays are greater than 0 cycles, as required in Requirement 2, Part 2.2 Approved: XXXX XX, 201X Page 10 of 19 Effective Date: XX/XX/XX
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 Provider undervoltage inhibit (where applicable) is set greater than 75 % of nominal primary voltage, as required in Requirement 2, Part 2. Deleted: Deleted: 10 Deleted: 20 Provider failed to include either a Deleted: single 09 frequency set point at 59.0 Hz or two frequency set points, with equal amounts of load, at 59.0 Hz and 58.7 Hz, as required by Requirement 2, Part 2.4 R R4 The Transmission Owner failed to provide for 5% or less of the automatic switching of its existing capacitor banks and reactors to control over-voltage as a result of an UFLS event in accordance with the review performed by the Planning Coordinator in Requirement R16 Coordinator has a documented methodology to determine areas of credible islanding but failed to include one (1) of the Parts as specified in Requirement R4, Parts 4.1, 4.2, 4. or 4.4 The Transmission Owner failed to provide for more than 5% but less than or equal to 10% of the automatic switching of its existing capacitor banks and reactors to control overvoltage as a result of an UFLS event in accordance with the review performed by the Planning Coordinator in Requirement R16 Coordinator has a documented methodology to determine areas of credible islanding but failed to include two (2) of the Parts as specified in Requirement R4, Parts 4.1, 4.2, 4. or 4.4 The Transmission Owner failed to provide for more than 10% but less than or equal to 15% of the automatic switching of its existing capacitor banks and reactors to control overvoltage as a result of an UFLS event in accordance with the review performed by the Planning Coordinator in Requirement R16 Coordinator has a documented methodology to determine areas of credible islanding but failed to include more than three () of the Parts as specified in Requirement R4, Parts 4.1, 4.2, 4. or 4.4 Provider failed to implement an automatic UFLS program for their facilities The Transmission Owner failed to provide more than 15% of the automatic switching of its existing capacitor banks and reactors to control over-voltage as a result of an UFLS event in accordance with the review performed by the Planning Coordinator in Requirement R16 Coordinator has a documented methodology to determine areas of credible islanding but failed to include all four (4) of the Parts as specified in Requirement R4, Parts 4.1, 4.2, 4. and 4.4 Deleted: 2 Deleted: Coordinator did not make its credible islanding determination methodology available within 15 business days of the receipt of a request, as required in R2.1; Coordinator did not respond to comments on its credible islanding determination methodology within 45 calendar days of receipt of a written comment, as required in R2.2 Deleted: Coordinator performed the assessment required in R2 but did not report the results to the Distribution Provider and Transmission Owner and Generator Owner in the ReliabilityFirst footprint affected by the credible islanding, as required in R2.4; Coordinator did not perform the assessment within five years of the previous determination, as required in R2. Coordinator failed to have a documented methodology to Deleted: Coordinator failed to address one or more of the bullet point per R2 to identify areas (or sub areas) of credible islanding in the methodology Approved: XXXX XX, 201X Page 11 of 19 Effective Date: XX/XX/XX
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 R5 Coordinator made its credible island determination methodology available for inspection and technical review by those entities directly and materially affected by the reliability of ReliabilityFirst Bulk Electric System (BES), but was more than 15 calendar days but less than or equal to 20 business days of the receipt of a request Coordinator made its credible island determination methodology available for inspection and technical review by those entities directly and materially affected by the reliability of ReliabilityFirst Bulk Electric System (BES), but was more than 20 calendar days but less than or equal to 25 business days of the receipt of a request Coordinator made its credible island determination methodology available for inspection and technical review by those entities directly and materially affected by the reliability of ReliabilityFirst Bulk Electric System (BES), but was more than 25 calendar days but less than or equal to 0 business days of the receipt of a request Deleted: Deleted: 10 Deleted: 20 determine areas of credible islanding Coordinator made its credible island determination methodology available for inspection and technical review by those entities directly and materially affected by the reliability of ReliabilityFirst Bulk Electric System (BES), more than 0 calendar days of the receipt of a request 9 Deleted: Coordinator did not perform the determination of credible islands as required in R2 R6 Coordinator provided a written response to that commenting entity that is materially affected by the reliability of ReliabilityFirst BES, but was more than 45 calendar days but less than or equal to 50 calendar days of the receipt of the comments. Coordinator provided a written response to that commenting entity that is materially affected by the reliability of ReliabilityFirst BES, but was more than 50 calendar days but less than or equal to 55 calendar days of the receipt of the comments. Coordinator provided a written response to that commenting entity that is materially affected by the reliability of ReliabilityFirst BES, but was more than 55 calendar days but less than or equal to 60 calendar days of the receipt of the comments. Coordinator failed to make its credible island determination methodology available for inspection and technical review by those entities directly and materially affected by the reliability of ReliabilityFirst Bulk Electric System (BES) Coordinator provided a written response to that commenting entity that is materially affected by the reliability of ReliabilityFirst BES, but was more than 60 calendar days of the receipt of the comments. Coordinator provided a written response to that Coordinator failed to provide a written response to that commenting entity that Approved: XXXX XX, 201X Page 12 of 19 Effective Date: XX/XX/XX
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 R7 R8 Coordinator supplied the results of applying the island methodology but was more than 0 calendar days but less than or equal to 5 of completion of the process to the Distribution Providers, Transmission Owners and Generator Owners in the ReliabilityFirst footprint of identified areas of credible islanding Coordinator supplied the results of applying the island methodology but was more than 5 calendar days but less than or equal to 40 of completion of the process to the Distribution Providers, Transmission Owners and Generator Owners in the ReliabilityFirst footprint of identified areas of credible islanding commenting entity that is materially affected by the reliability of ReliabilityFirst BES, within 45 calendar days of receipt of those comments but the response failed to indicate whether a change was made to the credible island determination methodology and, if no change will be made, the reason why Coordinator supplied the results of applying the island methodology but was more than 40 calendar days but less than or equal to 45 of completion of the process to the Distribution Providers, Transmission Owners and Generator Owners in the ReliabilityFirst footprint of identified areas of credible islanding Deleted: Deleted: 10 Deleted: 20 is materially affected by the reliability of 9 ReliabilityFirst BES Coordinator failed to use the credible island determination methodology at least every five years to determine areas of credible islanding within their area of responsibility. Coordinator supplied the results of applying the island methodology but was more than 45 of completion of the process to the Distribution Providers, Transmission Owners and Generator Owners in the ReliabilityFirst footprint of identified areas of credible islanding Coordinator failed to supply the results of applying the island methodology to the Distribution Providers, Transmission Owners and Generator Owners in the ReliabilityFirst Deleted: Provider, Transmission Owner or Generator Owner did not participate in the engineering assessment and mitigation that specifically address generation/load imbalances in the area of credible islanding as required in R Deleted: Providers did not install UFLS capability or apply other methods of balancing Load and resources as required in R.1.1 or R.1.2. Approved: XXXX XX, 201X Page 1 of 19 Effective Date: XX/XX/XX
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 R9 R10 R11 R12 Coordinator established a mitigation plan that specifically addressed generation/load imbalances in the area of credible islanding but the mitigation plan failed to consist one or both of Requirement R9, Part 9.1 or 9.2 Deleted: Deleted: 10 Deleted: 20 footprint of identified areas of credible islanding Coordinator failed to establish a mitigation plan that specifically addresses generation/load imbalances in the area of credible islanding. 9 Provider, Transmission Owner and Generator Owner in an identified area of credible islanding failed to participate in the establishment of the mitigation plan. Provider, Transmission Owner and Generator Owner failed to implement the mitigation plan within three years of the completion of the mitigation plan. The Generator Deleted: Owner 4 that owns a unit(s) with automatic underfrequency protection installed, failed to set such protection in accordance with the minimum tripping time delays in Requirement 12, Table 1 without using the mitigation technique suggested in Requirement R12, Part 12.1 Deleted: The Generator Owner that owns a unit with automatic underfrequency protection installed, greater than 0% but less than or equal to 5% of a Generator Owner s total MWs is tripped by underfrequency protection sooner than the minimum time delays required in the Table 1 in R4 without using the mitigation technique suggested in R4.1; The Generator Owner that owns a unit with automatic underfrequency protection not installed, the Generator Owner has an underfrequency tripping procedure(s) but it does not conform to Table 1 Approved: XXXX XX, 201X Page 14 of 19 Effective Date: XX/XX/XX
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 R1 R14 Each Distribution Provider and Transmission Owner required to comply with the relevant sections of Requirement R1, Requirement R2 or Requirement R11 provided their Planning Coordinator the data in the pre-arranged format to populate the UFLS database but was more than 45 calendar days but less than or equal to 50 calendar days of the Planning Coordinators Each Distribution Provider and Transmission Owner required to comply with the relevant sections of Requirement R1, Requirement R2 or Requirement R11 provided their Planning Coordinator the data in the pre-arranged format to populate the UFLS database but was more than 50 calendar days but less than or equal to 55 calendar days of the Planning Coordinators Coordinator established an UFLS database but failed to update the database every five calendar years or as required by changes in system conditions per Requirement R1, Part 1.1 Coordinator established an UFLS database but failed to include the areas of credible islanding determined in Requirement R7 per Requirement R1, Part 1.2 Each Distribution Provider and Transmission Owner required to comply with the relevant sections of Requirement R1, Requirement R2 or Requirement R11 provided their Planning Coordinator the data in the pre-arranged format to populate the UFLS database but was more than 55 calendar days but less than or equal to 60 calendar days of the Planning Coordinators Deleted: Deleted: 10 Deleted: 20 The Generator Owner that owns a unit(s) Deleted: with 09 automatic underfrequency protection installed, failed to have underfrequency tripping procedures which conform to Requirement R12, Table 1 Coordinator failed to established an UFLS database as required by R1 Each Distribution Provider and Transmission Owner Deleted: 6 required to comply with the relevant sections of Requirement R1, Requirement R2 or Requirement R11 provided their Planning Coordinator the data in the pre-arranged format to populate the UFLS database but was more than 60 calendar days of the Planning Coordinators request Deleted: The Generator Owner that owns a unit with automatic underfrequency protection installed, greater than 5% of a Generator Owner s total MWs is tripped by underfrequency protection sooner than the minimum time delays required in the Table 1in R4 without using the mitigation technique suggested in R4.1; The Generator Owner that owns a unit with automatic underfrequency protection not installed, the Generator Owner does not have an underfrequency tripping procedure(s). Deleted: 5 Deleted: Coordinator has not established and maintained UFLS database as required by R5 Coordinator has established and maintained the UFLS database as required by R5 but has not been updated within the last five years or as required by changes in system conditions as required by R5.1 Deleted: Coordinator established and maintained the UFLS database required by R5 but areas of credible islanding were not included as required by R5.2 Approved: XXXX XX, 201X Page 15 of 19 Effective Date: XX/XX/XX
DRAFT 6 V4 Standard PRC-006- RFC-01 01/11/11 request request request Each Distribution Provider and Transmission Owner required to comply with the relevant sections of Requirement R1, Requirement R2 or Requirement R11 provided their Planning Coordinator the data in the pre-arranged format to populate the UFLS database within 45 calendar days of the Planning Coordinators request but failed to include one (1) of the Parts as specified in Requirement R14, Parts 14.4, 14.5, 14.6, or 14.7 Deleted: Deleted: 10 Deleted: 20 9 Each Distribution Provider and Transmission Owner required to comply with the relevant sections of Requirement R1, Requirement R2 or Requirement R11 provided their Planning Coordinator the data in the pre-arranged format to populate the UFLS database within 45 calendar days of the Planning Coordinators incomplete request but failed to include more than one (1) of the Parts as specified in Requirement R14, Parts 14.1, 14.2 or 14. Each Distribution incomplete Provider and Transmission Owner required to comply with the relevant sections of Requirement R1, Requirement R2 or Requirement R11 provided their Planning Coordinator the data in the pre-arranged format to populate the UFLS database within 45 calendar days of the Planning Coordinators request but failed to include two (2) or more of the Parts as specified in Requirement R14, Parts 14.4, 14.5, 14.6, or 14.7 Each Distribution Deleted: Providers or Transmission Owners supplied the information but between 1% and 2% of the information submitted for any of the individual applicable sub-requirements listed in R6.1 is incomplete Providers, Transmission Owners and Generator Owners failed to supply the information within 45 days but not longer than 90 days from the Planning Coordinators request Deleted: Providers or Transmission Owners supplied the information but greater than or equal to 2% but less than % of the information submitted for any of the individual applicable sub requirements listed in R6.1 is The Generator Owner supplied the information within 45 days from the Planning Coordinators request but failed to submit underfrequency trip set points and time delays for one (1) generator as required by R6.2 Deleted: Providers or Transmission Owners supplied the information and greater than or equal to % but less than 6% of the information submitted for any of the individual applicable sub requirements listed in R6.1 is The Generator Owner supplied the information within 45 days from the Planning Coordinators request but failed to submit underfrequency trip set points and time delays for more than one (1) generator as required by R6.2 Approved: XXXX XX, 201X Page 16 of 19 Effective Date: XX/XX/XX