N-7Notice of Filing of NERC's 2010 Business Plan and Budget and the 2010 Business Plans and Budgets of Regional Entities and the Proposed Assessments to Fund Budgets 6/29/2010
6 passages
supports the statutory activities of development of reliability standards and achieving compliance with reliability standards, and includes NERC's metrics, benchmarking and event analysis activities. (5) The Situation Awareness and Infrast...
AI summary The text outlines NERC's 2010 Business Plan and Budget, emphasizing compliance with reliability standards, infrastructure security, and funding distribution. It highlights the Situation Awareness and Infrastructure Security Program's role in reliability enforcement and critical infrastructure protection (CIP), alongside the need for additional staffing and resources to improve operational efficiency and reliability initiatives.
for each Regional Entity. MRO, NPCC and WECC are the only Regional Entities whose footprints encompass Canadian provinces (and in the case of WECC, Mexico). As noted earlier, the year 2008 is the most performed by NERC or a Regional Entity...
AI summary The text outlines funding allocations by Regional Entities (MRO, NPCC, WECC) and adjustments for the IESO and Québec. It discusses compliance and enforcement resource allocations, exceptions in NPCC and WECC allocations, and ongoing negotiations for a memorandum of understanding between WECC, NERC, and AESO regarding duplicate costs.
em events and other off-normal events occurring on the bulk power system; identifying the root causes of events that may be precursors of 60 Section 215(g) of the FPA and 18 C.F.R. §39.11. potentially more serious events impacting the reli...
AI summary The Reliability Assessment and Performance Analysis Program focuses on analyzing abnormal events, root causes, and improving bulk power system reliability through performance metrics, benchmarks, and initiatives like the System Protection Initiative. It maintains GADS and develops TADS, with NERC generating revenue from GADS software sales.
5. Situation Awareness and Infrastructure Security NERC's Situation Awareness and Infrastructure Security Program coordinates all of NERC's efforts to improve physical and cyber security for the North American bulk power system as it relat...
AI summary NERC's Situation Awareness and Infrastructure Security Program enhances physical and cyber security for the North American bulk power system through standards, compliance, risk assessments, and real-time monitoring. It oversees the ES-ISAC, established in 1999, and the ESSG created in 2008 to guide infrastructure security efforts.
5. SERC SERC's total statutory budget for 2010 is $10,701,683, an increase of $606,137 over its 2009 Budget. SERC plans total staffing for statutory and administrative programs of 45.5 FTEs, an increase of 2.5 FTEs over its 2009 Budget. SE...
AI summary SERC's 2010 budget increased by $606,137, with major allocations to infrastructure security and administrative services. Staffing rose to 45.5 FTEs, and the Working Capital Reserve target is $1,009,555. SERC will handle TFE processing with existing resources and may request supplemental funding if needed. No non-statutory activities are planned.
e resource requirements for processing TFE become clearer during 2010, it is possible that WECC may need to submit a supplemental budget and funding request for additional resources for this activity. WECC is budgeting increases in direct...
AI summary WECC outlines 2010 budget adjustments, including increased FTEs for reliability programs, reduced consultant costs, and funding for new Reliability Coordination Centers. It seeks a $1M increase to meet its Working Capital Reserve target, while addressing resource needs from TFE processing.
N-9Northeast Power Coordinating Council, Inc. Criteria Filing 6/30/2010
32 passages
- 1.1 Title Design and Operation of the Bulk Power System - 1.2 Directory Number 1 - 1.3 Objective The objective of these criteria is to provide a "design-based approach" to ensure the bulk power system is designed and operated to a level...
AI summary This document outlines the design and operation criteria for the bulk power system to ensure reliability, focusing on the ability to withstand design contingencies and prevent cascading outages. It emphasizes the need for balanced resource and transmission planning to meet customer demand.
5.0 NPCC Full Member, More Stringent Criteria NPCC provides a forum for coordinating the design and operations of its five Reliability Coordinator Areas. NPCC shall conduct regional and interregional studies, and assess and monitor Plannin...
AI summary The NPCC coordinates regional and interregional studies to ensure compliance with stringent criteria for the bulk power system. Reliability Coordinators, Transmission Planners, and Planning Coordinators are responsible for operating and designing their portions of the system according to these standards through committees and task forces.
5.1.3 Data Exchange Requirements for Modeling and System Analysis It is the responsibility of NPCC and NPCC Members to protect the proprietary nature of the following information and to ensure it is used only for purposes of efficient and...
AI summary The document outlines data exchange requirements for system analysis and modeling, emphasizing NPCC's responsibility to protect proprietary information while ensuring data sharing supports reliable system operations. Reliability Coordinators and Registered Entities must provide verified data for analysis, with annual reviews and periodic verification mandated for equipment data.
5.4 Transmission Design Criteria The portion of the bulk power system in each Planning Coordinator Area and in each Transmission Planning Area shall be designed with sufficient transmission capability to serve forecasted demand under the c...
AI summary The transmission system in Planning Coordinator and Transmission Planning Areas must be designed to handle forecasted demand, including scenarios with lost critical infrastructure. Ten-minute reserves and control mechanisms are used to adjust power flows during outages. Power transfers between areas must be considered in transmission design.
5.4.3 Fault Current Assessment Each Transmission Planner and Planning Coordinator shall establish procedures and implement a system design that ensures equipment capabilities are adequate for fault current levels with all transmission and...
AI summary The section mandates that Transmission Planners and Planning Coordinators establish procedures and system designs to ensure equipment can handle fault current levels under all operating conditions, with coordination across adjacent Planning Coordinator Areas.
5.7 Extreme System Conditions Assessment The bulk power system can be subjected to wide range of other than normal system conditions that have low probability of occurrence. One of the objectives of extreme system conditions assessment is...
AI summary The document outlines procedures for assessing extreme system conditions on the bulk power system, including peak load scenarios and fuel shortages. It emphasizes planning studies to evaluate system robustness and dynamic performance, with responsibilities assigned to Transmission Planners and Planning Coordinators. Mitigation measures are discussed, along with a multi-step approval process for revising planning directories through NPCC and RCC.
3.0 The Study Year to be considered It is suggested that a study year of 4 to 6 years from the reporting date is a realistic one, both from the viewpoint of minimum lead times required for construction, and the ability to alter plans or fa...
AI summary The suggested study year for planning considerations is 4–6 years from the reporting date, allowing for construction lead times and plan adjustments. Longer-term reviews may be conducted beyond 6 years to address marginal conditions requiring extended solutions.
6.0 Format of Presentation - Interim Review Introduction of Interim Review Reference the most recent Comprehensive Review and any subsequent Intermediate or Interim Reviews as appropriate. Changes in Facilities (Existing and Planned) and F...
AI summary The document outlines the format for interim reviews, including updates on load forecasts, generation resources, transmission facilities, and special protection systems. It emphasizes assessing the impact on the reliability of the interconnected bulk power system.
8.0 Task Force Follow-Up Procedures - 8.1 Once a Planning Coordinator has presented its Review report to the TFSS, TFSS will review the Planning Coordinator's report and any supporting documentation and: - a. Consider whether to accept the...
AI summary The Task Force on Coordination of Planning (TFSS) reviews Planning Coordinators' reports for compliance with guidelines, addresses discrepancies, and ensures alignment with NPCC standards. It also identifies reliability concerns and recommends studies when necessary, reporting findings to relevant bodies.
1.0 Introduction NPCC has established a Reliability Assessment Program to bring together work done by the NPCC and Planning Coordinators relevant to the assessment of bulk power system reliability . As part of the Reliability Assessment Pr...
AI summary The NPCC's Reliability Assessment Program ensures resource adequacy assessments by Planning Coordinators, emphasizing supply-side and demand-side contributions to bulk power system reliability. Resource adequacy depends on interconnection assistance between Planning Coordinator Areas, with NPCC referencing but not duplicating member reviews.
4.3 Introduction - 4.3.1 Reference the previous NPCC Area Review. - 4.3.2 Compare the proposed resources and load forecast covered in this NPCC review with that covered in the previous review
AI summary The introduction references the previous NPCC Area Review and outlines a comparison between the proposed resources and load forecasts in this review and those from the prior review, focusing on changes in resource planning and demand projections.
4.5 Resource Adequacy Assessment - 4.5.1 Evaluate proposed resources versus the requirement to reliably meet projected electricity demand assuming the Planning Coordinator's most likely load forecast. - 4.5.2 Evaluate proposed resources ve...
AI summary The section outlines a four-part assessment of resource adequacy, focusing on evaluating proposed resources against load forecasts, discussing reliability impacts from uncertainties, and reviewing market rule changes. It emphasizes reliability planning under different load scenarios and mechanisms to mitigate risks.
1.0 Introduction The Northeast Power Coordinating Council (NPCC) was formed to promote the reliability and efficiency of electric service of the interconnected bulk power system of the members of the NPCC by extending the coordination of t...
AI summary The Northeast Power Coordinating Council (NPCC) ensures reliability and efficiency of the interconnected bulk power system through standardized design and operation criteria. Specific contingencies, such as simultaneous faults on multi-circuit towers, are addressed with risk-based exclusion procedures requiring Reliability Coordinating Committee (RCC) approval. Directory #1 outlines these standards and exclusion processes.
2.0 Load/Capacity Forecasts 2.1 Twice yearly, by May 15th and November 15th respectively, the Operations Planning Working Group (CO 12) will perform a summer and winter assessment for the next season. The methodology and format of the seas...
AI summary The document outlines procedures for seasonal load/capacity assessments by the Operations Planning Working Group (CO 12), using NPCC Document C-45 methodology. Results are reviewed by NPCC's TFCO and RCC. Weekly capacity margin reviews by RC Areas are required, with mitigation measures for deficiencies or light load conditions.
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.
1.6.2.2 Existing Facilities It is the responsibility of individual companies to assess the protection systems at existing facilities and to make modifications which are required to meet the intent of these criteria as follows. 1.6.2.2.1 Pl...
AI summary Companies must assess and modify protection systems at existing facilities to meet criteria. Upgrades to bulk power system (BPS) facilities requiring assessments if they don't meet criteria, with reporting via specified forms for TFSP review.
3.3.8 Physical Separation/Environment Criteria - 3.3.8.1 In addition to the physical separation as referenced in sections 3.3.1.2 and 3.3.9.5, if a Special Protection System is designed to have multiple protection groups at a single locati...
AI summary The section outlines physical separation requirements for Special Protection Systems (SPS), mandating non-adjacent mounting assemblies for redundant protection groups and fire barriers in common raceways to ensure reliability and safety.
and commissioning requirements must ensure that all critical component loads are supplied from batteries and battery charger as part of the engineering and design. If, and when, modifications are
AI summary The text emphasizes that engineering and design requirements must ensure critical component loads are supplied by batteries and battery chargers. Modifications to this requirement are contingent on specific conditions, highlighting the importance of reliable power supply for essential systems.
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, including battery capacity tests and backup generator tests, with specified frequencies and success criteria.
5.7 Radially Energize and Restore a Portion of an Adjacent Area's System Situations can occur where it is desirable for an operating area to supply generating stations, substations and customer load in an adjacent operating area. In doing...
AI summary Section 5.7 addresses scenarios where an operating area may need to supply generating stations, substations, and customer load in an adjacent area. It emphasizes caution in determining system separation points and highlights the need to assess considerations before providing assistance, though the text is cut off mid-sentence.
Background The Maritimes Area consists of three Canadian provinces: New Brunswick (NB), Nova Scotia (NS) and Prince Edward Island (PEI), as well as a radially connected portion of the state of Maine {Northern Maine Independent System Admin...
AI summary The Maritimes Area includes New Brunswick, Nova Scotia, Prince Edward Island, and Northern Maine, interconnected via multiple transmission lines. The New Brunswick System Operator (NBSO) serves as the Reliability Coordinator, managing synchronization across the region. Grid connections exist between provinces and Maine, with no direct NS-PEI link. The 2004 peak load for the Maritimes was 6,000 MW.
3.2.1 Daily Follow-up of the System Configuration Once the restoration plan is set up, it must be constantly updated to keep track of equipment outages. Some equipment is designated as necessary for the restoration process (i.e., they are...
AI summary The restoration plan requires continuous updates to track equipment outages, identify critical components, and analyze alternate paths when necessary. Maintenance schedules are assessed annually to prevent disruptions during restoration. Key facilities and simultaneous outage scenarios are evaluated to ensure reliability.
3.2.2 System Expansion Plan The impacts of additions and modifications must be assessed and their impact on the restoration procedure thoroughly evaluated.
AI summary The text emphasizes the necessity of evaluating the impacts of system additions and modifications on restoration procedures, ensuring reliability and compliance with regulatory standards. It underscores the importance of thorough assessment to maintain system integrity during expansion planning.
3.3.2 Material
AI summary The section '3.3.2 Material' introduces a regulatory proceeding context involving Nova Scotia's energy sector, referencing key organizations, acronyms, and topics relevant to electricity reliability, grid operations, and regulatory oversight.
Key facilities and Critical Components Lists: These lists are continuously kept up to date.
AI summary The document outlines the maintenance of Key Facilities and Critical Components Lists, emphasizing their continuous updates to ensure relevance in regulatory proceedings related to power system reliability and infrastructure planning.
5.4.3 Hydro Generators - 5.4.3.1 Hydro capability shall be determined on a generation facility or an individual generator basis. - 5.4.3.2 The Gross Real Power Capability and Net Real Power Capability shall be determined on the basis of th...
AI summary The section outlines criteria for determining hydro generator capabilities, emphasizing gross and net real power based on water availability and head. Verification methods include testing, historical data, and performance tracking during seasonal periods.
and form designated by the Compliance Committee. ________________________________________________________________________ Prepared by: Task Force on Coordination of Operation / Task Force on Coordination of Planning Review and Approval: Re...
AI summary The document outlines the process for revising and approving a directory prepared by the Task Force on Coordination of Operation and Planning. It requires a 45-day review period, RCC approval, and adherence to NPCC bylaws. Revisions must align with NERC standards and NPCC documents, with updates occurring every three years or as needed.
4.0 Procedures 4.1 Scheduling - 4.1.1 Each Area shall ensure that sufficient resources are available such that its requirements for operating reserve are met at all times. - 4.1.2 An Area shall meet its requirement for operating reserve us...
AI summary Section 4.0 outlines procedures for scheduling, requiring areas to maintain sufficient operating reserve through internal resources or external capacity, considering uncertainties like load forecast errors to ensure reliability.
1.0 Introduction The purpose of the Northeast Power Coordinating Council Inc. is to promote the reliable and efficient operation of the interconnected bulk power systems in Northeastern North America through the establishment of criteria,...
AI summary The Northeast Power Coordinating Council Inc. (NPCC Inc.) aims to ensure reliable and efficient operation of bulk power systems through reliability criteria, planning coordination, and compliance enforcement. Its Reliability Compliance and Enforcement Program assigns compliance assessment responsibilities between NPCC Inc. and regional 'Areas,' emphasizing that the latter handles market participant reporting. The program applies to all full members and aligns with NPCC Inc. bylaws.
Area Transmission Review Standard: The interconnected trans mission sy stems sh all be planned, designed, and constructed to reliably meet projected c ustomer electricity demand and energy requirements in ac cordance with NPC C Inc. Basic...
AI summary The document outlines standards for interconnected transmission systems, requiring planning and design to meet customer demand per NPCC Inc. guidelines (Documents A-2 and B-4). Studies must align with NPCC's criteria for transmission reviews and system operation.
4.0 Application and List Maintenance Each Area shall be responsible for the application of the Classification of Bulk Power System Elements as described in this document and shall submit proposed changes and supporting documentation to the...
AI summary Each Area is responsible for applying the classification of Bulk Power System elements, submitting changes to the Task Force on System Studies (TFSS). The TFSS maintains the NPCC Bulk Power System List and submits additions/removals to the Reliability Coordinating Committee (RCC) for approval.
5.0 Dynamic Disturbance Recording (DDR) Capability - 5.1 Where the DDR capability is deemed necessary by the Reliability Coordinator, the Reliability Coordinator shall provide guidance in setting triggers and shall monitor the performance...
AI summary The document outlines requirements for Dynamic Disturbance Recorder (DDR) deployment, including placement based on load, generation, and transmission factors, monitoring parameters (voltage, current, frequency), sampling rates (≥960 samples/sec), and triggers (e.g., frequency changes). DDRs must be distributed across major load centers, generation clusters, and transmission interfaces, with continuous recording mandated for devices installed post-2009.
N-10Reliability Standards of the North American Electric Reliability Corporation 7/5/2010
20 passages
Applicability: - Transmission Owner - Generator Owner On November 28, 2005, FAC-009-1 was approved by the registered ballot body by a 93% affirmative vote. On February 7, 2006, FAC-009-1 was approved by the NERC Board of Trustees. On March...
AI summary The document outlines the approval history of FAC-009-1 by the registered ballot body, NERC Board of Trustees, and FERC, followed by the introduction of FAC-010-2.1, which establishes methodology for determining System Operating Limits (SOLs) in BES planning to ensure reliability.
Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 1. Title: Coordination of Plans For New Generation, Transmission, and End-User Facilities
AI summary This document outlines the coordination of plans for new generation, transmission, and end-user facilities. It includes a version history table and a title indicating the focus on coordination among different infrastructure components.
- vegetation management work. Local conditions may include, but are not limited to: operating voltage, appropriate vegetation management techniques, fire risk, reasonably anticipated tree and conductor movement, species types and growth ra...
AI summary The document outlines requirements for vegetation management, clearance distances between vegetation and conductors, and personnel qualifications. It references IEEE 516-2003 standards for minimum air insulation distances and specifies adjustments based on altitude and transient overvoltage factors.
2.3. Level 3: - 2.3.1. The Transmission Owner reported one Category 1 or multiple Category 2 transmission vegetation-related outages in a calendar year, or; - 2.3.2. The Transmission Owner did not maintain a set of clearances (Clearance 2)...
AI summary Level 3 criteria include transmission vegetation-related outages, failure to maintain required clearances, and incomplete Transmission Vegetation Management Plans (TVMP). These conditions relate to infrastructure planning and system reliability requirements.
C. Measures - M1. The Transmission Owner and Generator Owner shall each have a documented Facility Ratings Methodology that includes all of the items identified in FAC-008 Requirement 1.1 through FAC-008 Requirement 1.3.5. - M2. The Transm...
AI summary The document outlines requirements for Transmission and Generator Owners to document and make available their Facility Ratings Methodology, ensuring compliance with FAC-008 standards. It specifies access rights for Reliability Coordinators, Transmission Operators, and Planning Authorities, and mandates responses to technical reviews within 45 days.
system configuration, generation dispatch and Load level. - R3.6. Criteria for determining when violating a SOL qualifies as an Interconnection Reliability Operating Limit (IROL) and criteria for developing any associated IROL Tv. - R4. Th...
AI summary The text outlines procedural requirements for determining when a System Operating Limit (SOL) violation becomes an Interconnection Reliability Operating Limit (IROL), and mandates the Planning Authority's responsibilities in issuing SOL Methodology, including stakeholder notifications and response timelines for technical comments.
3. Violation Severity Levels: Requirement Lower Moderate High Severe R3 The Planning Authority has a methodology for determining SOLs that includes a description for all but one of the following: R3.1 through R3.6. The Planning Authority h...
AI summary This section outlines the severity levels of violations related to the methodology used by the Planning Authority for determining System Operating Limits (SOLs), with different levels based on the number of required descriptions (R3.1 through R3.6) that are missing.
a. 1 The Contingencies identified in FAC-011 R2.2.1 through R2.2.3 are the minimum contingencies that must be studied but are not necessarily the only Contingencies that should be studied.
AI summary The text states that the contingencies outlined in FAC-011 R2.2.1 through R2.2.3 are the minimum required for study, though additional contingencies may also need consideration. This emphasizes a baseline requirement for contingency analysis in regulatory proceedings.
4. Applicability: - 4.1. Transmission Owners specified in the data requirements and reporting procedures of MOD-013-0_R1 - 4.2. Transmission Planners specified in the data requirements and reporting procedures of MOD-013-0_R1 - 4.3. Genera...
AI summary Section 4 outlines applicability requirements for Transmission Owners, Planners, Generator Owners, and Resource Planners under MOD-013-0_R1. Section 5 sets the effective date as April 1, 2005.
A. Introduction - 1. Title: System Performance Under Normal (No Contingency) Conditions (Category A) - 2. Number: TPL-001-0.1 - 3. Purpose: System simulations and associated assessments are needed periodically to ensure that reliable syste...
AI summary This standard (TPL-001-0.1) establishes requirements for periodic system simulations and assessments to ensure reliable system development, modification, and upgrades to meet current and future performance needs. It applies to Planning Authority and Transmission Planner, with an effective date of May 13, 2009.
Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 0 February 8, 2005 BOT Approval Revised 0 June 3, 2005 Fixed reference in M1 to read TPL-001-0 R2.1 and TPL-001-0 R2.2 Errata 0 July 24, 2007 Corrected...
AI summary This document tracks the version history of a regulatory filing, including effective dates, approvals, and revisions related to transmission planning standards. It outlines changes made over time, including corrections to references and updates to the effective date.
only as needed to address identified marginal conditions that may have longer lead-time solutions. - R1.3.5. Have all projected firm transfers modeled. - R1.3.6. Be performed and evaluated for selected demand levels over the range of forec...
AI summary The text outlines requirements for addressing marginal conditions with long-term solutions, including modeling all projected firm transfers (R1.3.5) and evaluating demand levels across forecast system demands (R1.3.6).
C. Measures - M1. The Planning Authority and Transmission Planner shall have a valid assessment and corrective plans as specified in Reliability Standard TPL-002-0_R1 and TPL-002-0_R2. - M2. The Planning Authority and Transmission Planner...
AI summary The Planning Authority and Transmission Planner must maintain valid assessment and corrective plans per Reliability Standards TPL-002-0_R1 and TPL-002-0_R2, and document results of reliability assessments as required by TPL-002-0_R3.
Current Critical Infrastructure Protection Implementation Plan for Version 2
AI summary Nova Scotia's Version 2 Critical Infrastructure Protection Implementation Plan outlines measures to secure energy systems against cyber threats, aligning with NERC CIP standards. It emphasizes compliance with CIP-004-2, CIP-005-2, and other cybersecurity protocols, while addressing physical security and incident response planning.
R5.2. Be allocated as follows: - For ATC Paths, based on the expected import paths or source regions provided by Load-Serving Entities or Resource Planners - For Flowgates, based on the expected import paths or source regions provided by L...
AI summary The allocation of ATC Paths and Flowgates depends on inputs from Load-Serving Entities and Resource Planners. The Transmission Planner must establish a Capacity Benefit Margin (CBM) value every 13 months for long-term planning, incorporating studies and reserve margin requirements from various entities.
r>a Ge Tr iss ion to an sm o r ne ra r Ow in he ir Tr iss ion t ne r an sm de l. m o T he Tr iss ion to an sm o p er a r d i d inc lu de in he t t no Tr iss ion de l de i le d ta an sm m o de l ing da d log ta to m o a n p o y fo i Re l...
AI summary The text discusses the transmission of data and models, emphasizing the inclusion of transmission data in models and the reliability of information. It highlights the importance of accurate and reliable data transmission and modeling for effective decision-making.
tandard C57.115, Table 3, specifies that transformers are to be designed to withstand a winding hot spot temperature of 180 degrees C, and cautions that bubble formation may occur above 140 degrees C. - with the calculated circuit capabili...
AI summary The text outlines transformer design standards (C57.115) and mandates for identifying critical transmission facilities to ensure Bulk Electric System reliability. Planning Coordinators must assess facilities (100–200 kV lines and transformers) for reliability impact, consult adjoining entities, and maintain updated lists of critical infrastructure to prevent cascade tripping.
C. Measures - M1. The Transmission Owner, Generator Owner, and Distribution Provider shall each have evidence to show that each of its transmission relays are set according to one of the criteria in R1.1 through R1.13. (R1) - M2. The Trans...
AI summary The document outlines three measures requiring Transmission Owners, Generator Owners, and Distribution Providers to demonstrate compliance with relay settings (R1.1-R1.13), obtain approvals for specific relay configurations (R1.6-R1.13), and ensure Planning Coordinators maintain documented processes for facility ratings. Reliability Coordinators, Transmission Operators, and Generator Operators are also involved in validation.
Matrix of Violation Risk Factors for Approval Standard Number Requirement Text of Requirement Violation COM-001-1.1 R1.3. With other Reliability Coordinators, Transmission Operators, and Balancing Authorities as necessary to maintain relia...
AI summary The document presents a matrix outlining violation risk factors for approval, focusing on compliance with specific standards. It highlights requirements related to reliability coordination, redundancy of facilities, and management of telecommunications infrastructure, with risk levels categorized as HIGH or MEDIUM.
Matrix of Violation Severity Levels for Approval Standard Number Requirement Number Text of Requirement Lower VSL Moderate VSL High VSL Severe VSL Standard Number Requirement Number Text of Requirement Lower VSL Moderate VSL High VSL Sever...
AI summary The document presents a matrix outlining violation severity levels for approval, focusing on the inclusion of subrequirements related to facilities and their impacts on interconnected transmission systems. The matrix categorizes severity levels from lower to severe, though the specific criteria for each level are not fully detailed in the provided text.
07810Quarterly Application for Approval of Reliability Standards of the North American Electric Reliability Corporation - September 2, 2011 9/6/2011
7 passages
B. Requirements - R1. Physical Security Plan The Responsible Entity shall document, implement, and maintain a physical security plan, approved by the senior manager or delegate(s) that shall address, at a minimum, the following: - R1.1. Al...
AI summary The Responsible Entity must establish a physical security plan approved by senior management, ensuring Cyber Assets are within secured perimeters, identifying access points, and implementing monitoring processes for physical access control.
C. Measures - M1. Each Transmission Operator shall have a dated, documented System restoration plan developed in accordance with Requirement R1 that has been approved by its Reliability Coordinator as shown with the documented approval fro...
AI summary The measures require Transmission Operators to document, update, and verify system restoration plans with Reliability Coordinators, ensuring compliance with requirements related to approval, annual reviews, and post-disturbance verification. Each measure specifies documentation standards and submission processes.
ator Operators as needed to develop and implement action plans to mitigate potential or actual SOL, CPS, or DCS violations including the coordination of pending generation and transmission maintenance
AI summary The text outlines measures requiring operators to develop action plans to mitigate potential or actual violations of System Operating Limits (SOL), Control Performance Standards (CPS), and Disturbance Control Standards (DCS), emphasizing coordination of generation and transmission maintenance.
calculations is obtained from the sink field or the Point of Delivery (POD) field of the transmission reservation - R1.5.3. The source/sink or POR/POD identification and mapping to the model.
AI summary The text outlines a technical requirement (R1.5.3) related to identifying and mapping source/sink or Point of Receipt (POR)/Point of Delivery (POD) fields in transmission reservations to a model, with calculations derived from these fields.
- R1.1.6. Uses Transmission Facility additions and retirements. - R1.1.7. Uses Generation Facility additions and retirements. - R1.1.8. Uses Special Protection System (SPS) models where currently existing or projected for implementation wi...
AI summary The text outlines modeling and transmission operational requirements, including facility additions/retirements, Special Protection System (SPS) modeling, series compensation, and Total Transfer Capability (TTC) determination processes. It specifies criteria for normal and contingency conditions, emphasizing reliability limits and stability standards.
Ge Ow in he ir to t or ne ra r ne r Tr iss ion de l. an sm m o O T he Tr iss ion to an sm p er a r d i d da he de l p t u te t no p m o er R 3. 2 fo ha 3 t r m or e n len da da bu t n t m ca r s o or e y ha 4 len da da t n ca r y s O T h...
AI summary The document discusses violation severity levels related to transmission service providers and available flowgate capability, including terms such as Available Transfer Capability (ATC), Transmission Reliability Margin (TRM), and Capacity Benefit Margin (CBM). It outlines various factors and metrics used in transmission planning and reliability assessments.
Matrix of Violation Risk Factors for Information S d d Nu b ta n a r m e r Re ire t q m e n u Nu b m e r Te f Re ire t o t q m e n x u V io la io R is k t n Fa to c r MOD-001-1a R4.1. Each Planning Coordinator associated with the Transmiss...
AI summary The document presents a matrix outlining violation risk factors for information, with a focus on MOD-001-1a and R4.1, which relates to each Planning Coordinator associated with the Transmission Service Provider's area. The status of this item is listed as 'Pending'.