Topic:"Generator Interconnection" in M03324

Directory 10, Verification of Generator Gross and Net Reactive Power Capability Approved, December 22, 2008 This Directory presents the minimum criteria for verifying the Gross Reactive Power Capability and Net Reactive Power Capability of...

AI summary This directory establishes minimum criteria for verifying the gross and net reactive power capability of generators, ensuring compliance with NERC Standard MOD-025-1. It aims to maintain accuracy in steady-state models assessing the reliability of the NPCC bulk power system, with NSPI and NPCC as key entities involved.

Revision History Version Date Action Change Tracking (New, Errata or Revisions) Table of Content Title Page 1 Revision History 2 Table of Content 3 1.0 Introduction 4 2.0 Terms Defined in This Directory 5 3.0 NERC ERO Reliability Standard...

AI summary The document outlines the NPCC Directory D3 Maintenance Criteria for Bulk Power System Protection, detailing reliability standards, regional requirements, and testing procedures for power system components and protection systems.

- (1) Non-Self Monitored protection assemblies include electromechanical relays and solid state relays . - (2) Microprocessor-based protection assemblies where the principal fault-sensing and logic components include self monitoring or sel...

AI summary The document outlines testing requirements for protection assemblies and systems, including non-self monitored relays, microprocessor-based relays with self-monitoring, and DC circuit testing for protection groups. It emphasizes verifying the operation of protection equipment and ensuring system reliability.

- 2.16.2.2 When a directional over current or distance relay is applied to remove the generator for slowly cleared faults on the external system, such protection is a backup and need not be duplicated. - 2.16.2.3 The apparatus should be pr...

AI summary The text outlines technical guidelines for generator protection systems, emphasizing relay configurations for fault detection, power swing discrimination, and coordination with underfrequency load shedding. It distinguishes between backup protection and specialized systems like Special Protection Systems (SPS) for maintaining power stability, while noting non-electrical considerations in generator protection.

Table 1 - Standard Test Procedures for key facilities and associated critical components required for system restoration Table 1 - Standard Test Procedures for key facilities and associated critical components required for system restorati...

AI summary Table 1 outlines standard test procedures for key facilities and critical components required for system restoration, focusing on blackstart generating units. The test involves an annual startup test of the generating unit's blackstart capability without dependencies on the power system, with criteria for successful operation.

6.0 Establishing Interconnection via Inter-Area Tie Lines When two systems are to be interconnected, options may be available as to where the interconnection may take place. When these options exist, it is up to the Reliability Coordinator...

AI summary The document outlines that when interconnecting systems, the Reliability Coordinator or Transmission Operator determines the optimal location and voltage level for interconnection via inter-area tie lines, emphasizing their role in ensuring reliable system integration.

6.1 Synchronous Tie Line When synchronizing Reliability Coordinator or Transmission Operator areas, the following guidelines should be followed: Synchronize at locations where: - 1. Synchronism-check relays and / or manual synchroscopes ar...

AI summary This section outlines technical guidelines for synchronizing Reliability Coordinator and Transmission Operator areas, emphasizing voltage and frequency matching, availability of control resources, and communication protocols. It specifies voltage differences (≤3%), frequency alignment (≤20° phase angle difference), and the use of synchronism-check relays for safe synchronization.

7.0 Considerations to Remain Stable Following Interconnection Once interconnected, the increase in tie line flow(s) into an island , in response to a generation contingency within the island , is proportional to the relative amounts of gen...

AI summary The document explains how tie line flows between interconnected systems respond to generation contingencies, using load as a proxy for synchronized generation capacity. It emphasizes the importance of secure flow management on tie lines, referencing prior sections on operational considerations.

Member Interconnection The purpose of this step is to provide guidelines for the Transmission Owners to interconnect and control frequency, tie line , voltage schedules, share reserves and coordinate emergency procedures. This step is perf...

AI summary The purpose of the Member Interconnection step is to establish guidelines for Transmission Owners to interconnect, manage frequency and voltage, share reserves, and coordinate emergency procedures post-restart. This occurs after Transmission Owners have restarted and seek to interconnect or have coordinated restart plans while interconnected.

this Directory include: - 3.1 MOD-024-1 -Verification of Generator Gross and Net Real Power Capability - 3.2 TOP-002-2 Normal Operations Planning - 3.3 FAC-008-1 Facility Ratings Methodology - 3.4 FAC-009-1 Establish and Communicate Facili...

AI summary The document outlines requirements for verifying generator real power capabilities, including documentation of declared and verified gross/net real power capability, discrepancies, and exemptions. The Transmission Operator must maintain records and establish a verification program, aligning with NPCC regional reliability standards.

ata, or performance tracking for the same previous seasonal verification period for this generator or generation facility. For new generators only, the Generator Owner shall submit commissioning data. - 1. Adverse impact on transmission sy...

AI summary The text outlines requirements for Generator Owners to submit commissioning data for new generators, exemptions for verification testing, and obligations to document and report verified power capabilities. Transmission Operators must notify exemptions and manage discrepancies in declared versus verified capabilities, with resolution plans required.

NPCC Specific Definitions: - Net Real Power Capability (of a generator or generating facility) The Gross Real Power Capability, less the auxiliary real power loads necessary to operate the generator at maximum real power output. - Verified...

AI summary The document defines two NPCC-specific terms: Net Real Power Capability (generator output minus auxiliary loads) and Verified Capability (capacity confirmed by Transmission Operator methods). These definitions establish criteria for assessing generator performance and reliability within the NPCC framework.

ive Power Capability of a generator or generation facility is insignificant for NPCC Bulk Power System reliability analysis, then periodic verification will be required for only one numerical value. - 5.3.1.3 If a Transmission Operator det...

AI summary The text outlines procedures for verifying generator reactive power capabilities for NPCC Bulk Power System reliability. Transmission Operators must specify verification periods and real power levels, while Generator Owners must notify equipment issues. Verification criteria include on-peak/off-peak testing and handling intermittent units.

5.4.2 Intermittent Power Resources For intermittent power resources (wind, tidal or geo-thermal generators) the manufacturers' or commissioning data can be used until sufficient performance tracking data is available to verify generator or...

AI summary The text outlines procedures for verifying reactive power capabilities of intermittent power resources (wind, tidal, geothermal) using manufacturer data until performance data is available. It also addresses verification for multiple generators and requirements to identify limitations affecting declared reactive power capabilities.

Appendix A Definition of Terms1 - Declared Capability (of a generator or generating facility) The values submitted by the Generator Owner to the respective Transmission Operator. - Generation Facility generating units, which are modeled as...

AI summary Appendix A defines technical terms related to generator capabilities, including declared capability, gross and net reactive/real power, and load. Definitions focus on generator performance metrics and system conditions during specific seasonal periods.

Basic Flow Chart for Verification of Generator Gross and Net Reactive Power Capability

AI summary The document outlines a flow chart for verifying generator gross and net reactive power capability, critical for ensuring grid reliability. It involves NSUARB and NSPI, highlighting regulatory and operational processes in Nova Scotia's power system.

APPENDIX B-2 – Generator Reactive Capability Form 1 Data Propaga ion Da RATOR REACT IVE CA PABILI TY DAT A FORM 1. Data Preparat Generator Fa nit No. Fac ility ID Generator r Owner Primai ry Contact Big Genera tor Statio n 1 1 2234 Big Po...

AI summary This document is a Generator Reactive Capability Form used to report auxiliary reactive power requirements and seasonal reactive capability data for a generator facility. It includes details such as generator owner, contact information, and verification methods for both lagging and leading capability.

5.4 Generator Under frequency Protection Requirements Generators shall not be tripped for under-frequency conditions in the area above the curve in Figure 1, except as provided for in Sections 5.4.1 and 5.4.2. 5.4.1 It is recognized that,...

AI summary Generators must not be tripped for under-frequency conditions above a specified curve, except under Sections 5.4.1 and 5.4.2. Special cases require load shedding equivalent to the generation tripped, with Balancing Authority notification. Generator Owners cannot modify under-frequency trip settings for exempt generators to avoid higher frequency tripping.

2.2 Uncleared Locally Within this document the phrase uncleared locally is used to denote failure of the protection including Special Protection Systems for the bus under test to initiate tripping of all associated interrupting devices reg...

AI summary The document defines 'uncleared locally' as the failure of protection systems, including Special Protection Systems (SPS), to trip interrupting devices at the bus under test. It outlines scenarios where protection at other buses may be assumed operational if they use independent DC sources, and discusses exceptions when backup protection at other buses can clear faults.

Standard VAR-002-1.1a — Generator Operation for Maintaining Network Voltage Schedules: To ensure generators provide reactive and voltage control necessary to ensure voltage levels, reactive flows, and reactive resources are maintained with...

AI summary This standard requires generators to provide reactive and voltage control to maintain voltage levels, reactive flows, and resources within applicable Facility Ratings, ensuring equipment protection and reliable Interconnection operation.

2. Number: FAC-002-0 3. Purpose: To avoid adverse impacts on reliability, Generator Owners and Transmission Owners and electricity end-users must meet facility connection and performance requirements.

AI summary This document outlines the purpose of FAC-002-0, emphasizing the need for Generator Owners, Transmission Owners, and electricity end-users to meet facility connection and performance requirements to prevent adverse impacts on reliability.

- 1. The following Interconnection-wide Regional Difference shall be applicable in the Western Interconnection: - 1.1. As governed by the requirements of R3.3, starting with all Facilities in service, shall require the evaluation of the fo...

AI summary The text outlines specific interconnection-wide regional difference requirements for the Western Interconnection, detailing various facility contingencies that must be evaluated when establishing system operating limits (SOLs), including fault conditions, circuit failures, and protection system responses.

C. Measures - M1. The Nuclear Plant Generator Operator shall, upon request of the Compliance Enforcement Authority, provide a copy of the transmittal and receipt of transmittal of the proposed NPIRs to the responsible Transmission Entities...

AI summary The measures outline compliance requirements for the Nuclear Plant Generator Operator and Transmission Entities, including documentation, coordination, and evidence of adherence to Nuclear Plant Interface Requirements (NPIRs) during operations and planning. The Compliance Enforcement Authority is tasked with verifying compliance through inspections and evidence reviews.

B. Requirements - R1. The Generator Operator shall operate each generator connected to the interconnected transmission system in the automatic voltage control mode (automatic voltage regulator in service and controlling voltage) unless the...

AI summary The document outlines operational requirements for Generator Operators and Owners, including voltage control modes, reactive power management, notification procedures for status changes, and data submission obligations. Requirements emphasize compliance with Transmission Operator directives, timely communication, and adherence to facility ratings and safety standards, effective May 13, 2009.

Timing Requirements for all Interconnections except WECC Inte uest for rchange omitted change Timeline with M bility-Related Respons Α В C D If Arranged Interchange (RFI) 2 is Submitted IA Assigned Time Classification IA Makes Initial Dist...

AI summary The document outlines timing requirements for interconnections (excluding WECC), specifying deadlines for submitting, distributing, and confirming arranged interchange requests based on submission times relative to ramp start. It details response times for entities like IA, BA, and TSP, ensuring reliability assessments and timely implementation.

Timing Requirements for all Interconnections except WECC Request for Interchange Submitted hange Timeline with M pility-Related Respons A В С D If Arranged Interchange (RFI) 2 is Submitted IA Assigned Time Classification IA Makes Initial D...

AI summary The document outlines strict timelines for handling interchange requests based on submission times relative to the ramp start. Time classifications (On-time, Late, ATF) dictate deadlines for actions like initial distribution, reliability assessments, and confirmed interchange implementation, with response windows ranging from 10 minutes to 2 hours depending on submission timing.

Matrix of Violation Risk Factors for Approval Standard Number Requirement Text of Requirement Violation EOP-008-0 R1.8. Interim provisions must be included if it is expected to take more than one hour to implement the contingency plan for...

AI summary This matrix outlines the risk factors for violations of reliability standards, focusing on interim provisions for contingency plans and testing requirements for blackstart generating units. Standards EOP-008-0 and EOP-009-0 are highlighted with medium and lower risk levels based on compliance requirements.

Matrix of Violation Severity Levels for Approval Standard Number Requirement Number Text of Requirement Lower VSL Moderate VSL High VSL Severe VSL EOP-001-0 R7.3. The Transmission Operator and Balancing Authority shall coordinate transmiss...

AI summary The document presents a matrix outlining violation severity levels for approval, focusing on the coordination between the Transmission Operator and Balancing Authority to manage transmission and generator maintenance schedules, particularly in the context of conserving fuel in short supply.

R14. N/A N/A N/A The Generator Operator does not have documented starting and bus energizing procedures for each Blackstart Resource.

AI summary The Generator Operator lacks documented starting and bus energizing procedures for each Blackstart Resource, which may impact system reliability and emergency response capabilities.

1. Title: Interchange Authority Distributes Arranged Interchange 2. Number: INT-005-3 3. Purpose: To ensure that the implementation of Interchange between Source and Sink Balancing Authorities is distributed by an Interchange Authority suc...

AI summary This document outlines the purpose of an Interchange Authority in distributing interchange information between Source and Sink Balancing Authorities to support reliability assessments.

Timing Requirements for all Interconnections except WECC Inte uest for rchange omitted Interchange Timeline with Minimum Reliability-Related Response Times Α В С D If Arranged Interchange (RFI) 2 is Submitted IA Assigned Time Classificatio...

AI summary The document outlines strict timing requirements for interconnection processes outside WECC, specifying response deadlines for interchange requests (RFI) and reliability assessments. Time classifications (On-time, Late, ATF) dictate varying response windows, with reliability assessments needing completion within 2 hours (or 10 minutes for late requests) and confirmed interchanges implemented 3 minutes post-assessment.

Timing Requirements for all Interconnections except WECC Request for Interchange Submitted Interchange Timeline with Minimum Reliability-Related Response Times Α В С D If Arranged Interchange (RFI) 3 is Submitted IA Assigned Time Classific...

AI summary The document outlines timing requirements for interconnections excluding WECC, specifying response deadlines for Interchange Administrators (IA), Balancing Authorities (BA), and Transmission Service Providers (TSP) based on when a Request for Interchange (RFI) is submitted relative to a ramp start. Deadlines vary from immediate actions (≤1 minute) to extended periods (up to 2 hours) depending on submission timing.

Timing Requirements for all Interconnections except WECC Request for Interchange Submitted Interchange Timeline with Minimum Reliability-Related Response Times Α В С D If Arranged Interchange (RFI) 2 is Submitted IA Assigned Time Classific...

AI summary The document outlines timing requirements for interconnections, specifying response deadlines for Interchange Administrators (IA), Balancing Authorities (BA), and Transmission Service Providers (TSP) based on the submission time of Request for Interchange (RFI) and Arranged Interchange Time Frame (ATF). Time classifications (On-time, Late, ATF) dictate varying response windows to ensure reliability.

mentation to the Generator Owner specifying the required tap changes, a timeframe for making the changes, and technical justification for these changes. - R12. The Transmission Operator shall direct corrective action, including load reduct...

AI summary The Transmission Operator must direct corrective actions, including load reduction, to prevent voltage collapse when reactive resources are insufficient (R12). Additionally, the Transmission Operator must specify required tap changes to the Generator Owner with a timeframe and technical justification (R11).

B. Requirements - R1. The Generator Operator shall operate each generator connected to the interconnected transmission system in the automatic voltage control mode (automatic voltage regulator in service and controlling voltage) unless the...

AI summary This section outlines technical operational requirements for Generator Operators, including voltage control modes, reactive power management, and communication protocols with Transmission Operators. It emphasizes compliance with schedules, timely notifications of capability changes, and data provision for transformers and impedance.

C. Measures - M1. The Generator Operator shall have evidence to show that it notified its associated Transmission Operator any time it failed to operate a generator in the automatic voltage control mode as specified in Requirement 1. - M2....

AI summary The document outlines seven measures (M1-M7) requiring Generator Operators and Owners to provide evidence of compliance with transmission operator directives, voltage control, transformer specifications, and timely notifications. These measures aim to ensure grid reliability and proper coordination between generation and transmission entities.

Request: VAR-002 — Generator Operation for Maintaining Network Voltage Schedules, addresses the generator's provision of voltage and VAR control. Confusion exists in the industry and regions as to which requirements in this standard apply...

AI summary The document discusses confusion regarding the application of VAR-002 standards to generators without automatic voltage regulators (AVRs). Generator owners seek clarification on whether they must comply with these requirements, as they lack the necessary equipment. The response clarifies that all requirements apply regardless of AVR presence, but no requirement mandates AVR installation.

I N T- 0 0 7- 1 R 1. 3. 2. f i le. M att eg aw p ro he ha T In ter c ng e Au ho ity fa i le d t t r o i fy im e t ve r on e, as in d ica d in 1 t ha R te t Ar d In ha ter ran g e c ng e ba lan d a d wa s ce n l i d p ior to va r it ion ing...

AI summary The text discusses a matrix of violation risk factors for information, referencing a filing related to a hearing and interconnection authority. It appears to be part of a regulatory proceeding involving interconnection processes and validation of information.

& lt;sup>4 The voltage schedule is a target voltage to be maintained within a tolerance band during a specified period. Standard Number Requirement Number Text of Requirement Lower VSL Moderate VSL High VSL Severe VSL VAR-002- 1.1b R2. Unl...

AI summary The text outlines a voltage schedule requirement for Generator Operators, specifying that they must maintain generator voltage or reactive power output within a tolerance band as directed by the Transmission Operator, with varying consequences based on the degree of non-compliance.