Topic:"Emergency Response" in M03324

Directory 2, Emergency Operations Approved, October 21, 2008 The purpose of this Directory is to present the basic factors to be considered in formulating plans and procedures to be followed in an emergency or during conditions which could...

AI summary The Directory outlines objectives for emergency operations to prevent service interruptions, minimize system disturbances, contain their effects, and ensure public safety. It emphasizes coordination within NPCC and adjacent areas.

5.5.3 Post Contingency Operation Immediately after the occurrence of a contingency , the status of the bulk power system must be assessed and transfer levels must be adjusted, if necessary, to prepare for the next contingency . If the read...

AI summary Post-contingency operations require immediate assessment of the bulk power system, adjustment of transfer levels, and potential use of emergency measures like voltage reduction or load shedding within 30 minutes. Pre-contingency disconnection of firm load may be necessary if other measures fail to maintain emergency limits.

4.6 Proposed Resource Capacity Mix - 4.6.1 Discuss any reliability impacts resulting from the proposed resources fuel supply and transportation or environmental considerations. - 4.6.2 Describe available mechanisms to mitigate any potentia...

AI summary The document outlines requirements for assessing reliability impacts of resource capacity mix, including fuel supply, environmental considerations, and compliance with regulations. It mandates an Annual Interim Review detailing load forecasts, generation resources, emergency procedures, and reliability assessments based on engineering studies and joint analyses.

6.2 Emergency Preparedness Conference Call Whenever adverse system operating or weather conditions are expected, any RC Area may request the NPCC Staff to arrange an Emergency Preparedness Conference Call (NPCC Document C-01) to discuss op...

AI summary The document outlines a procedure for arranging Emergency Preparedness Conference Calls when adverse operating or weather conditions are anticipated. An RC Area may request NPCC Staff to coordinate discussions with operations management from NPCC RC Areas and neighboring systems to address operational details.

1.0 Introduction - 1.1 TitleEmergency Operations - 1.2 Directory Number 2 - 1.3 Objective The purpose of this Directory is to present the basic factors to be considered in formulating plans and procedures to be followed in an emergency or...

AI summary This document outlines the objectives of the NPCC Emergency Operations Directory, focusing on minimizing service interruptions, system disturbances, and public hazards during emergencies. It emphasizes coordination among reliability coordinators, balancing authorities, and transmission operators, with an effective date of October 21, 2008.

Appendix B Guideline and Procedure for Emergency Operation

AI summary Appendix B outlines guidelines and procedures for emergency operations, focusing on system reliability and response protocols. It references regulatory frameworks and operational standards relevant to Nova Scotia's energy sector.

1.0 Introduction This Appendix provides the guidelines and procedures for anticipating and operating under emergency conditions. These guidelines and procedures are intended to provide specific instructions to the System Operator during su...

AI summary This Appendix outlines guidelines for emergency operations, targeting the System Operator in NPCC Balancing Authority, Transmission Operator, and Reliability Coordinator areas. The goal is to minimize emergency impacts and ensure containment through specific procedures.

NPCC Directory D2 Emergency Operations - 3.2.5 If two or more Transmission Operators are experiencing voltage problems simultaneously, they will assist each other as above to the extent feasible. If the problem is so severe as to require t...

AI summary The NPCC Directory D2 outlines procedures for Transmission Operators to address simultaneous voltage issues, emphasizing mutual assistance and reactive power flow management. If external conditions cause voltage anomalies, operators must identify the source, communicate, and take corrective actions, including load shedding if necessary, to stabilize the system.

4.0 Actions to Contain an Emergency If preventative measures as outlined under Sections 2.0 and/or 3.0 have not been adequate, the Balancing Authority or the Transmission Operator experiencing the abnormal conditions may need to declare an...

AI summary The section outlines emergency actions by Balancing Authorities and Transmission Operators to address transmission emergencies and maintain system reliability, referencing preventative measures from earlier sections. It details scenarios where one area's operations impact another's reliability and specifies actions for frequency/ACE control issues.

1.0 Introduction This Appendix provides the guidelines and procedures to the Reliability Coordinator, Transmission Operator and Balancing Authority to manage system restoration events that affect the NPCC member Areas and adjoining operati...

AI summary The document outlines procedures for managing system restoration in NPCC regions, emphasizing the need for Reliability Coordinators and Transmission Operators to maintain restoration plans. It highlights the importance of preparing for blackouts by building basic power systems from key facilities and adhering to NERC and NPCC standards.

3 All member Areas in NPCC are registered as the Reliability Coordinator and Transmission Operator. Hence, only the member Areas names are shown in this column to indicate they represent both the RC and the TOP. Table 2-1 NPCC Reliability...

AI summary The document outlines the restoration plans for different NPCC member areas, including New England, New York, and Ontario, detailing procedures for restoring AC station service and power supply in the event of system shutdowns or blackouts.

5.0 Assessment of Conditions Prior to Interconnecting When assistance is required from an external Reliability Coordinator or Transmission Operator area, communications between the requesting and assisting Reliability Coordinator and Trans...

AI summary The section outlines the need to assess system conditions (load, generation, reserves, etc.) and types of assistance (frequency control, tie line regulation) before interconnecting to ensure reliability and prevent separation during emergencies. It emphasizes mutual agreements between system operators for reliable assistance.

5.6 Provision of External Restoration Service External restoration service may be provided to an adjacent blacked-out Reliability Coordinator or Transmission Operator area. When the assisting area has strong tie lines remaining with the Ea...

AI summary External restoration services must limit load restoration based on tie line capacity to adjacent areas and 5% of synchronized generator capacity in electrical islands to avoid frequency/voltage transients. Special caution is required for cold load pickup and energizing transmission lines due to potential surges.

Exercises may include: - 1. Simulated emergency response activities; - 2. Table top simulations; - 3. Exercise participants participating from their normal work headquarters; - 4. Minimal to zero coaching by exercise coordinators; and - 5....

AI summary The document outlines procedures for conducting system restoration exercises, emphasizing simulated emergencies, tabletop simulations, and minimal coaching. Post-exercise assessments and lessons learned are critical, with coordination led by the NPCC Inter-Control Area Restoration Coordination Working Group (CO-11) to ensure inter-area collaboration during restoration events.

Objective This restoration summary is a brief overview of how the Maritimes Area restores the power system following a complete blackout of the Maritimes Area . It does not attempt to cover details of the individual system restoration plan...

AI summary This document outlines the restoration process for the Maritimes Area's power system following a complete blackout, emphasizing it as a high-level overview rather than a detailed analysis of individual plans or all potential blackout scenarios.

B. ISO New England - 1. Determine the extent of the blackout throughout New England and adjacent power systems and inform all Local Control Centers of existing generation and transmission capabilities. - 2. Implement the ISO restoration pr...

AI summary ISO New England is tasked with assessing blackout severity, coordinating restoration efforts with Local Control Centers, and providing temporary dispatch assistance if needed during system outages. The procedures emphasize communication, restoration protocols, and contingency support for regional power systems.

Administration to Sustain Emergency Response Capabilities The IESO has implemented all identified opportunities for improvement identified in the various blackout investigations following the power system collapse of August, 2003. In consi...

AI summary The IESO has enhanced emergency preparedness following the 2003 blackout, requiring Ontario market participants to submit Emergency Preparedness Plans and restoration plans. The OPSRP aligns with NERC and NPCC standards, emphasizing training, testing, and large-scale exercises for system restoration.

2.0 Objective To allow restoration of the system, safely, in the shortest possible time.

AI summary The objective is to restore the system safely and in the shortest possible time, focusing on system reliability and rapid emergency response to minimize disruptions.

3.0 Methodology The design of the restoration plan contains the following elements: - 1. Basic plan; - 2. Regular follow-up; - 3. Personnel and material required; and - 4. Testing of critical components associated with key facilities .

AI summary The restoration plan design includes four elements: basic plan development, regular follow-up procedures, personnel and material requirements, and testing of critical components at key facilities to ensure reliability and preparedness.

3.1 Basic Plan The primary priority of the basic restoration plan is the restoration of AC station service to the nuclear plant. If a blackout occurs, the configuration of the system has to be examined to identify possible restoration path...

AI summary The Basic Plan prioritizes restoring AC service to the nuclear plant during blackouts by partitioning the system into Basic Minimum Power Systems (BMPS), which are restored independently. The system operator selects a main BMPS for synchronization, allowing gradual restoration. Special cases involve synchronization with neighboring utilities under existing agreements.

Emergency Procedures The plan must be broken down into a set of emergency procedures for each key facility . These procedures state in a short and precise way the operations that are to be performed to isolate the station (preliminary oper...

AI summary Emergency procedures must be established for key facilities to isolate stations and restore power following blackouts. Procedures are mandatory, require step-by-step application, and modifications need system operator approval. They are part of a coordinated plan dependent on prior and subsequent operations.

2. Reset Function This function allows the operation, through the remote control center, of any critical circuit breaker in order to speed up the restoration process.

AI summary The Reset Function enables remote operation of critical circuit breakers via a control center to expedite power restoration during outages, enhancing system reliability and emergency response capabilities.

5.2 Individual Facility After the blackout has occurred, determine: - 1. Tripped equipment; - 2. Energized or in service equipment; - 3. Breakers which have remained closed; - 4. Unavailable equipment; - 5. Proceed with emergency procedure...

AI summary Post-blackout procedures include assessing tripped and energized equipment, identifying closed breakers, addressing unavailable equipment, initiating emergency protocols, and notifying the remote control system operator. These steps focus on rapid fault diagnosis and coordination with operational authorities.

Emergency Preparedness The MISO reliability coordinators and real-time operational staff handle system emergencies according to NERC guidelines and internal MISO procedures. Information for dissemination to public entities comes from the M...

AI summary MISO's reliability coordinators and operational staff manage emergencies using NERC guidelines and internal procedures. Public information is relayed through MISO's real-time management to the public relations department for dissemination.

External Power Systems-PJM Restoration Overview In the PJM RTO, during the initial stages of a restoration, each Load Serving Entity is responsible for restoring its own customer load with internal generation or through coordinated efforts...

AI summary The PJM RTO outlines procedures for restoring power during emergencies, emphasizing coordination between Load Serving Entities and Transmission Owners. Priority is given to neighboring entities' power requests over restoring internal loads. Pre-arranged communication plans and the PJM dispatcher's role in establishing emergency communications are highlighted.

Implement Restoration Procedure The purpose of this step is to direct the restart of Generation Owners internal generation and load on-line generation in planned steps while maintaining system load , scheduled frequency, voltage control an...

AI summary The procedure outlines steps to restart generation and load in planned increments while maintaining system load, frequency, voltage control, and reserves. It applies when a Transmission Owner/Generation Owner is isolated and must restart without external assistance.

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.

A-10, IEEE C37.100-1981 Significant adverse impact — With due regard for the maximum operating capability of the affected systems, one or more of the following conditions arising from faults or disturbances , shall be deemed as having sign...

AI summary The document defines 'significant adverse impact' in power systems, including instability, dynamic response issues, equipment tripping, and violations of emergency voltage/transmission limits. Key conditions involve uncontrollable instability, undamped oscillations, improper protection system operations, and breaches of emergency operational thresholds.

Full (100%) Compliance The Area load-shedding program fully complies with the requirements of the NPCC Inc. Emergency Operation Criteria (Document A-3), Section 4.6.

AI summary The Area load-shedding program is confirmed to fully comply with the NPCC Inc.'s Emergency Operation Criteria (Document A-3), Section 4.6, ensuring alignment with established emergency operational standards.

B. Overview of Reliability Standards NERC Reliability Standards define the requirements for reliably planning and operating the North American bulk power system. These standards are developed by industry stakeholders using a balanced, open...

AI summary NERC Reliability Standards outline requirements for the North American bulk power system's planning and operation, developed through an inclusive process by industry stakeholders. The standards cover real-time balancing, equipment limits, contingency management, vegetation control, critical infrastructure protection, and emergency planning, ensuring system reliability and safety.

C. Detailed Description of Proposed Reliability Standards The Reliability Standards presented in Exhibits C and E are grouped by topical area, as summarized below. Resource and Demand Balancing (BAL) ⎯ balancing resources and demand to mai...

AI summary The document outlines proposed reliability standards grouped into 13 topical areas, including resource balancing, cybersecurity, emergency operations, and transmission planning. It references NERC's glossary and Exhibit B, which details each standard's purpose, approval percentages, and changes. The standards aim to ensure grid reliability through coordinated operations, infrastructure protection, and compliance with NERC and FERC guidelines.

Applicability: - Balancing Authorities - Transmission Operators On January 7, 2005, EOP-001-0 was approved by the registered ballot body by a 95.5% affirmative vote. On February 8, 2005, EOP-001-0 was approved by the NERC Board of Trustees...

AI summary The text outlines the approval process of EOP-001-0 by the registered ballot body, NERC Board of Trustees, and FERC. It also introduces Standard EOP-002-2.1, which mandates preparedness for capacity and energy emergencies by Reliability Coordinators and Balancing Authorities.

Applicability: - Balancing Authorities - Reliability Coordinators - Load-Serving Entities On October 29, 2008, EOP-002-2.1 was approved by the NERC Board of Trustees. On May 13, 2009, EOP-002-2.1 was approved by the Federal Energy Regulato...

AI summary The text outlines the approval history of EOP-002-2.1 by NERC and FERC, its derivation from errata changes, and the 2005 approval of EOP-002-0. It also introduces Standard EOP-003-1, mandating load-shedding capabilities for Balancing Authorities and Transmission Operators during capacity shortages.

- than annually, their probable contingencies to determine their prospective most severe single contingencies. - R4. A Balancing Authority or Reserve Sharing Group shall meet the Disturbance Recovery Criterion within the Disturbance Recove...

AI summary The text outlines requirements for Balancing Authorities and Reserve Sharing Groups to meet the Disturbance Recovery Criterion, including returning ACE to zero within 15 minutes post-disturbance and compliance methods under the Disturbance Control Standard (DCS).

A. Introduction 1. Title: Communication and Coordination 2. Number: COM-002-2 3. Purpose: To ensure Balancing Authorities, Transmission Operators, and Generator Operators have adequate communications and that these communications capabilit...

AI summary The purpose of COM-002-2 is to ensure effective communication among Balancing Authorities, Transmission Operators, and Generator Operators during real-time emergencies, emphasizing staffing and availability of communication capabilities.

C. Measures - M1. Each Transmission Operator, Balancing Authority and Generator Operator shall have communication facilities (voice and data links) with appropriate Reliability Coordinators, Balancing Authorities, and Transmission Operator...

AI summary The measures mandate communication facilities for Transmission Operators, Balancing Authorities, and Generator Operators to address real-time emergencies. They must provide evidence such as logs or recordings to confirm notifications to Reliability Coordinators and other entities about potential reliability threats or load shedding.

1.2. Compliance Monitoring Period and Reset Timeframes The Regional Reliability Organization shall review and evaluate emergency plans every three years to ensure that the plans consider the applicable elements of Attachment 1- EOP-001-0....

AI summary The Regional Reliability Organization must review emergency plans every three years, considering Attachment 1-EOP-001-0. Self-certification by the Transmission Operator and Balancing Authority may be requested in non-review years. The reset timeframe is one calendar year.

2. Levels of Non-Compliance 2.1. Level 1: One of the applicable elements of Attachment 1-EOP-001-0 has not been addressed in the emergency plans. Adopted by NERC Board of Trustees: February 8, 2005 2 of 4

AI summary Level 1 non-compliance involves unaddressed elements of Attachment 1-EOP-001-0 in emergency plans. The NERC Board of Trustees adopted this standard on February 8, 2005, highlighting its regulatory significance.

Standard EOP-001-0 — Emergency Operations Planning - 2.2. Level 2: Two of the applicable elements of Attachment 1-EOP-001-0 have not been addressed in the emergency plans. - 2.3. Level 3: Three of the applicable elements of Attachment 1-EO...

AI summary The text outlines levels of non-compliance (Level 2 to Level 4) for the Emergency Operations Planning Standard EOP-001-0, specifying the number of unaddressed elements in emergency plans. Higher levels indicate more severe deficiencies, including the absence of a plan.

Attachment 1-EOP-001-0

AI summary Attachment 1-EOP-001-0 outlines requirements for Emergency Operations Planning under EOP-001-0, focusing on NSUARB and NSPI compliance with reliability standards, including coordination with RROs and adherence to CIP and FAC protocols for system resilience.

Elements for Consideration in Development of Emergency Plans - 1. Fuel supply and inventory An adequate fuel supply and inventory plan that recognizes reasonable delays or problems in the delivery or production of fuel. - 2. Fuel switching...

AI summary The document outlines 15 elements for developing emergency plans, focusing on fuel management, load reduction, public appeals, and coordination with government and entities. It references NERC's EOP-002-2.1 standard for capacity and energy emergencies.

C. Measures - M1. Each Reliability Coordinator and Balancing Authority shall have and provide upon request evidence that could include but is not limited to, job descriptions, signed agreements, authority letter signed by an appropriate of...

AI summary The measures outline evidence requirements for Reliability Coordinators, Balancing Authorities, and Transmission Service Providers to demonstrate compliance with emergency plans, operator logs, and NERC/EEA standards during capacity and energy emergencies.

Attachment 1-EOP-002-2.1 Energy Emergency Alerts

AI summary This attachment outlines the Energy Emergency Alerts framework under EOP-002-2.1, part of Nova Scotia's regulatory process for ensuring grid reliability during emergencies. It references standards for emergency operations planning and cyber security protocols relevant to critical infrastructure protection.

Introduction This Attachment provides the procedures by which a Load Serving Entity can obtain capacity and energy when it has exhausted all other options and can no longer provide its customers' expected energy requirements. NERC defines...

AI summary This document outlines procedures for Load Serving Entities (LSEs) to obtain capacity and energy during energy emergencies, as defined by NERC. The Energy Emergency Alert Procedure is triggered by a Reliability Coordinator, with alert levels detailed in Section B. Transmission Providers' obligations under FERC-approved tariffs remain unchanged.

A. General Requirements - 1. Initiation by Reliability Coordinator. An Energy Emergency Alert may be initiated only by a Reliability Coordinator at 1) the Reliability Coordinator's own request, or 2) upon the request of a Balancing Authori...

AI summary The document outlines procedures for initiating and notifying Energy Emergency Alerts by Reliability Coordinators, specifying conditions such as Load Serving Entity resource shortages or scheduling issues due to Available Transfer Capability (ATC) limitations. Notifications must be sent to Balancing Authorities, Transmission Providers, and other Reliability Coordinators via the Reliability Coordinator Information System (RCIS).

Circumstances: - Balancing Authority, Reserve Sharing Group, or Load Serving Entity is no longer able to provide its customers' expected energy requirements, and is designated an Energy Deficient Entity. - Energy Deficient Entity foresees...

AI summary The text outlines procedures for Energy Deficient Entities (EDEs) unable to meet customer energy demands, including demand reduction measures and notification requirements. During Alert 2, EDEs must communicate needs to Balancing Authorities and post alerts on NERC's website, with Reliability Coordinators assisting in declarations.

C. Energy Emergency Alert 3 Report A Deficient Balancing Authority or Load Serving Entity declaring an Energy Emergency Alert 3 must complete the following report. Upon completion of this report, it is to be sent to the Reliability Coordin...

AI summary The document outlines procedural requirements for entities declaring an Energy Emergency Alert 3, mandating submission of a report to the Reliability Coordinator within two business days to ensure compliance with reliability standards during critical system events.

Requesting Balancing Authority: Entity experiencing energy deficiency (if different from Balancing Authority): Date/Time Implemented: Date/Time Released: Declared Deficiency Amount (MW): Total energy supplied by other Balancing Authority d...

AI summary The document outlines the steps taken to avoid calling for an 'Energy Deficiency Alert 3' by activating all available generation, making purchases, recalling sales, curtailing load, utilizing load reduction programs, and using operating reserves. It also references the 'Standard EOP-002-2.1 — Capacity and Energy Emergencies' and mentions the 'Load Shedding Plans' adopted by the Board of Trustees.

2. Number: EOP-003-1 3. Purpose: A Balancing Authority and Transmission Operator operating with insufficient generation or transmission capacity must have the capability and authority to shed load rather than risk an uncontrolled failure o...

AI summary This document outlines the purpose of EOP-003-1, which is to ensure that Balancing Authorities and Transmission Operators have the capability and authority to shed load when facing insufficient generation or transmission capacity, thereby preventing uncontrolled failures in the Interconnection.

Introduction The U.S. Department of Energy (DOE), under its relevant authorities, has established mandatory reporting requirements for electric emergency incidents and disturbances in the United States. DOE collects this information from t...

AI summary The U.S. Department of Energy (DOE) mandates reporting of electric emergency incidents via Form OE-417 to support national security and Federal Response Plan (FRP) obligations. The Energy Information Administration (EIA) utilizes this data for monthly reporting and legislative recommendations. All Reliability Coordinators, Balancing Authorities, and similar entities must submit reports to the DOE Operations Center, with EIA requesting notification of joint or separate filings.

Adopted by Board of Trustees: November 1, 2006 Page 11 of 13 Table 1-EOP-004-0 Summary of NERC and DOE Reporting Requirements for Major Electric System Emergencies Incident No. Incident Threshold Report Required Time 1 Uncontrolled loss of...

AI summary This document outlines the NERC and DOE reporting requirements for major electric system emergencies, detailing specific incidents, thresholds, required reports, and timeframes for submission. It includes nine types of incidents with varying thresholds and reporting schedules.

Version History Version Date Action Change Tracking Attachment 1 – EOP-005

AI summary The document includes a version history table and an attachment labeled 'EOP-005', which refers to an Emergency Operations Planning Standard. The content is currently sparse and lacks detailed information.

Elements for Consideration in Development of Restoration Plans The Restoration Plan must consider the following requirements, as applicable: - 1. Plan and procedures outlining the relationships and responsibilities of the personnel necessa...

AI summary The document outlines key elements for developing system restoration plans, emphasizing black-start capabilities, coordination with reliability coordinators, testing procedures, personnel training, and communication protocols to ensure reliable system restoration and interconnection priority.

- 1. The following Interconnection-wide Regional Difference shall be applicable in the Western Interconnection: - 1.1. As governed by the requirements of R2.5 and R2.6, starting with all Facilities in service, shall require the evaluation...

AI summary The text outlines the Interconnection-wide Regional Difference applicable in the Western Interconnection, detailing specific multiple Facility Contingencies that must be evaluated when establishing System Operating Limits (SOLs). It includes various fault scenarios and conditions under which certain contingencies may be excluded or considered.

sectionalizing breaker to clear a permanent Phase to Ground Fault. - 1.2. SOLs shall be established such that for multiple Facility Contingencies in E1.1.1 through E1.1.5 operation within the SOL shall provide system performance consistent...

AI summary The text outlines requirements for System Operating Limits (SOLs) to ensure system performance during multiple facility contingencies, including maintaining thermal, frequency, and voltage limits, preventing cascading failures, and ensuring stability. It also mentions adjustments based on system performance and design.

Applicability This standard only applies to the Eastern Interconnection. - 1. Transmission Loading Relief (TLR) Procedure - 1.1. Initiation only by Reliability Coordinator. A Reliability Coordinator shall be the only entity authorized to i...

AI summary The standard applies to the Eastern Interconnection, detailing the Transmission Loading Relief (TLR) Procedure initiated by Reliability Coordinators to mitigate System Operating Limit (SOL) and Interconnection Reliability Operating Limit (IROL) violations. TLR is not effective as a sole tool for existing IROL violations, with alternatives like redispatch and load shedding recommended.

2.9. TLR Level 6 — Emergency Procedures - 2.9.1 The Reliability Coordinator shall use following circumstances to establish the need for entering TLR Level 6 : - One or more Transmission Facilities are above their SOL or IROL. - One or more...

AI summary TLR Level 6 emergency procedures are triggered when transmission facilities exceed or risk exceeding their System Operating Limits (SOL) or Interconnection Reliability Operating Limits (IROL). The Reliability Coordinator must direct Balancing Authorities and Transmission Operators to redispatch generation, reconfigure transmission, or reduce load to stabilize the Bulk Electric System (BES) until conditions are resolved.

B. Requirements - R1. The Reliability Coordinator shall have Operating Procedures, Processes, or Plans in place for activities that require notification, exchange of information or coordination of actions with one or more other Reliability...

AI summary The requirements outline procedures for Reliability Coordinators to ensure interconnection reliability through communication protocols, outage management, voltage control, and coordinated action plans. Procedures must be agreed upon, distributed, and periodically reviewed, with specific focus on addressing energy shortages, unplanned outages, and adverse reliability impacts.

4. Levels of Non-Compliance for a Generator Operator: Effective Date: January 1, 2007 - 4.1. Level 1: Not applicable. - 4.2. Level 2: Not applicable. - 4.3. Level 3: Not applicable. - 4.4. Level 4: There shall be a separate Level 4 non-com...

AI summary The document outlines four levels of non-compliance for generator operators, with Level 4 detailing specific violations including failure to follow reliability directives, refusing emergency assistance, and improperly removing Bulk Electric System (BES) facilities from service. Effective January 1, 2007, these levels define consequences for non-adherence to reliability and operational standards.

Glossary of Terms Used in NERC Reliability Standards Updated April 20, 2010

AI summary This document provides a glossary of terms from NERC Reliability Standards, defining key concepts, acronyms, and standards critical to electric system reliability. It includes terms related to cybersecurity, emergency operations, transmission planning, and facility ratings, with updates as of April 20, 2010.

Exhibit D

AI summary Exhibit D provides a list of acronyms and their expansions relevant to regulatory standards, compliance, and operational protocols in the Nova Scotia utility sector, including cybersecurity, emergency operations, and transmission planning.

Table 1 Compliance Schedule for Standards CIP-002-1 through CIP-009-1 Balancing Authorities and Transmission Operators Required to Self-certify to UA Standard 1200, and Reliability Coordinators End of 2nd Qtr 2007 End of 2nd Qtr 2008 End o...

AI summary The text presents a compliance schedule for various standards (CIP-002-1 through CIP-009-1) related to cybersecurity, incident reporting, and recovery planning for Balancing Authorities, Transmission Operators, and Load-Serving Entities. It outlines compliance milestones including Baseline Work, Supplemental Compliance, Compliance, and Annual Compliance.

Disaster Recovery and Restoration Activities A special case of restoration as part of a disaster recovery situation (such as storm restoration) shall follow the emergency provisions of the Responsible Entity's policy required by CIP-003 R1...

AI summary The text outlines that during disaster recovery, restoration activities must follow emergency provisions without delay from CIP compliance. Post-restoration, the Responsible Entity must implement CIP compliance and demonstrate it via audits or self-reports.

Matrix of Violation Risk Factors for Approval Standard Number Requirement Text of Requirement Violation EOP-001-0 R3. Each Transmission Operator and Balancing Authority shall: Medium EOP-001-0 R4. Each Transmission Operator and Balancing A...

AI summary The document presents a matrix outlining requirements and associated violation risk factors for emergency planning under EOP-001-0. It specifies that Transmission Operators and Balancing Authorities must develop, maintain, and coordinate emergency plans with relevant entities, including Reliability Coordinators and neighboring operators.

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 R2. The Transmission Operator shall have an emergency load reduction plan for all...

AI summary The document outlines a matrix for evaluating the severity of violations related to the emergency load reduction plan requirements under EOP-001-0. It defines different levels of violation severity based on the Transmission Operator's compliance with the requirement to have a plan that can be implemented within 30 minutes.

B. Requirements - R1. Each Reliability Coordinator, Balancing Authority, Transmission Operator, Generator Operator, and Load Serving Entity shall have procedures for the recognition of and for making their operating personnel aware of sabo...

AI summary The requirements outline procedures for entities to recognize, communicate, and respond to sabotage events, including establishing contacts with law enforcement agencies.

1. Title: Emergency Operations Planning 2. Number: EOP-001-2 3. Purpose: Each Transmission Operator and Balancing Authority needs to develop, maintain, and implement a set of plans to mitigate operating emergencies. These plans need to be...

AI summary This document outlines the need for Transmission Operators and Balancing Authorities to develop and implement emergency operations plans, ensuring coordination with other entities and the Reliability Coordinator to mitigate operating emergencies.

2. Violation Severity Levels: Requirement Lower Moderate High Severe R4 The Transmission Operator and Balancing Authority's emergency plan has complied with 90% or more of the number of sub-components. The Transmission Operator and Balanci...

AI summary This section outlines the violation severity levels based on compliance with the sub-components of the Transmission Operator and Balancing Authority's emergency plan, categorizing them into lower, moderate, high, and severe levels based on the percentage of compliance.

Elements for Consideration in Development of Emergency Plans - 1. Fuel supply and inventory An adequate fuel supply and inventory plan that recognizes reasonable delays or problems in the delivery or production of fuel. - 2. Fuel switching...

AI summary The document outlines 15 elements for developing emergency plans, focusing on fuel supply management, load reduction strategies, public engagement, and coordination with government and industry stakeholders to ensure system reliability during energy crises.

A. Introduction 1. Title : Capacity and Energy Emergencies 2. Number : EOP-002-3 3. Purpose : To ensure Reliability Coordinators and Balancing Authorities are prepared for capacity and energy emergencies.

AI summary This document, titled 'Capacity and Energy Emergencies' (EOP-002-3), outlines measures to ensure Reliability Coordinators and Balancing Authorities are prepared for capacity and energy emergencies, emphasizing the importance of emergency preparedness in maintaining grid reliability.

Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0 August 8, 2005 Removed "Proposed" from Effective Date Errata 1 September 19, 2006 Changes R7. to refer to "Requirement 6" instead of "Requirement 7" E...

AI summary The document provides a version history of a regulatory proceeding, detailing changes and approvals over time. It also includes an attachment related to Energy Emergency Alerts.

Introduction This Attachment provides the procedures by which a Load Serving Entity can obtain capacity and energy when it has exhausted all other options and can no longer provide its customers' expected energy requirements. NERC defines...

AI summary This document outlines procedures for Load Serving Entities to obtain energy during capacity shortages, termed 'Energy Emergencies' by NERC. The Reliability Coordinator initiates alert levels to assist deficient entities, while emphasizing that Transmission Providers must adhere to FERC-approved obligations.

B. Energy Emergency Alert Levels

AI summary The section outlines energy emergency alert levels, critical for managing grid reliability and response during crises. It references regulatory frameworks and standards like NERC, FERC, and NSUARB, emphasizing preparedness and operational protocols for energy emergencies.

Circumstances: - Balancing Authority, Reserve Sharing Group, or Load Serving Entity foresees or is experiencing conditions where all available resources are committed to meet firm load, firm transactions, and reserve commitments, and is co...

AI summary The text outlines two scenarios: (1) a Balancing Authority, Reserve Sharing Group, or Load Serving Entity facing reserve shortfalls due to committed resources and curtailed non-firm energy sales, and (2) the activation of load management procedures under Alert 2. These circumstances highlight system reliability and emergency response challenges.

1. All generation capable of being on line in the time frame of the energy deficiency was on line (including quick start and peaking units) without regard to cost. 2. All firm and nonfirm purchases were made regardless of cost. 3. All nonf...

AI summary The text outlines measures taken during an energy deficiency, including activating all available generation, making purchases regardless of cost, recalling nonfirm sales, curtailing interruptible load, utilizing load reduction programs, and employing operating reserves. It references the Standard EOP-002-3 — Capacity and Energy Emergencies.

Comments: Standard EOP-002-3 — Capacity and Energy Emergencies Reported By: Organization: Title: A. Introduction

AI summary The document begins with a section titled 'A. Introduction' under the 'Comments' heading, which is related to the EOP-002-3 standard concerning Capacity and Energy Emergencies. However, the content within the introduction is currently empty or not provided.

which Blackstart Resources have been utilized in restoring the shut down area of the BES to service, each Transmission Operator involved shall have evidence such as voice recordings, e-mail, dated computer printouts, or operator logs, that...

AI summary The measures outline documentation and evidence requirements for Transmission Operators regarding Blackstart Resource utilization, restoration plans, resynchronization after disturbances, testing, and training materials, as per specific regulatory requirements.

an i h in t t ap p ro ve p p ro ve p s w 4 5 len da da f r ip t. ca r s o ec e y O R T he Re l ia b i l i Co d in fa i le d ty to or a r i fy he Tr iss io Op to t t to n o an sm n er a r f i l o d isa l w i h ts t o ap p ro va r p p ro va...

AI summary The text discusses the approval process for various components of the Bulk Electric System (BES), including reliability coordinator (RC) and transmission operator (TO) functions, as well as the roles of balancing authorities (BA) and generator operators (GO). It references the need for approval of reliability standards and emergency preparedness procedures.

- R3. As portions of the transmission system approach or exceed SOLs or IROLs, the Reliability Coordinator shall work with its Transmission Operators and Balancing Authorities to evaluate and assess any additional Interchange Schedules tha...

AI summary The text outlines requirements for Reliability Coordinators to manage transmission system limits, ensure operating reserves, address geomagnetic disturbances, and coordinate emergency responses. Key actions include monitoring IROL/SOL violations, load shedding, and disseminating GMD forecasts.

- event logs, operator action notes or equivalent evidence that will be used to determine if it initiated control actions or emergency procedures to relieve that IROL violation within 30 minutes. (Requirement 3 Part 2 and Requirement 5) -...

AI summary The Reliability Coordinator must maintain and provide evidence for handling IROL violations, managing insufficient operating reserves, responding to GMD forecasts, and disseminating information within its area. This includes documentation such as operator logs, voice recordings, and electronic communications to ensure compliance with reliability requirements.

- R1.7. Current local or Transmission Loading Relief procedures in effect. - R1.8. Planned generation dispatches. - R1.9. Planned transmission or generation outages. - R1.10. Contingency events. - R2. Each Reliability Coordinator shall mon...

AI summary The requirements outline Reliability Coordinators' responsibilities to monitor system parameters, coordinate with Transmission Operators and Balancing Authorities, ensure compliance with Control Performance Standards (CPS) and Disturbance Control Standards (DCS), and manage contingency events, including Geo-Magnetic Disturbance (GMD) forecasts and emergency response actions.

C. Measures - M1. The Reliability Coordinator shall have and provide upon request evidence that could include, but is not limited to, Energy Management System description documents, computer printouts, a prepared report specifically detail...

AI summary The Reliability Coordinator must provide evidence for compliance with requirements including EMS/SCADA system performance, handling insufficient reserves, GMD response planning, and information dissemination. Measures emphasize documentation of operations, communication logs, and adherence to reliability standards.

Disaster Recovery and Restoration Activities A special case of restoration as part of a disaster recovery situation (such as storm restoration) shall follow the emergency provisions of the Responsible Entity's policy required by CIP-003 R1...

AI summary During disaster recovery, restoration must follow emergency provisions of the Responsible Entity's CIP-003 R1.1 policy to prioritize power system restoration and customer load service. Cybersecurity measures support reliability, but full CIP compliance implementation is deferred post-restoration, requiring audits or self-reports to demonstrate compliance.

E O P- 0 0 1- 0 R 1. Ba lan in Au ho it ies ha l l ha ing t t c g r s ve op era it h a d j lan in Ba ts t ag re em en w ac en c g Au ho it ies ha ha l l, in im t t t s at r a m um , in is ion fo nt co a p ro v s r e me rg en cy ist inc lu...

AI summary The document outlines a matrix of violation risk factors related to balancing authority operations and emergency assistance. It discusses the balancing authority's role in managing energy resources and responding to emergencies, including the provision of emergency assistance and the responsibilities associated with those actions.