Project Consideration of Commission Directives in Order No. 693
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1 Project Consideration of Commission Directives in Order Order P Further, consistent with the NOPR, the Commission directs the ERO to modify IRO to require a minimum set of tools that must be made available to the reliability coordinator. We believe this requirement will ensure that a reliability coordinator has the tools it needs to perform its functions. [t]he Commission clarifies that the Commission s intent is to have the ERO develop a requirement that identifies capabilities, not actual tools or products. The Commission agrees that the latter approach is not appropriate as a particular product could become obsolete and technology improves over time. Proposed IRO addresses issues identified by the NERC Operating Committee's Real-time Tools Best Practices Task Force (RTBPTF) related to the availability and quality of the Reliability Coordinator's (RC) monitoring and analysis capabilities. The monitoring and analysis capabilities required by proposed IRO and other IRO standards discussed below ensure RCs have the capabilities to maintain Real-time situational awareness. Monitoring Capabilities Requirement R1 addresses the quality of the Real-time data needed by the RC to perform its monitoring and Real-time Assessments. Each RC is required to implement a documented procedure for addressing Real-time data quality issues. The procedure must include criteria for evaluating Real-time data quality, provisions for indicating data quality to the System Operator, and actions to resolve Real-time data quality issues when data quality affects Real-time Assessments. Requirement R3 addresses capabilities for operator awareness of failures in Real-time monitoring alarm processes by requiring RCs to use an alarm process monitor. Requirements for the RC to perform Real-time monitoring are specified in IRO-002-2, IRO-002-4, and IRO Proposed IRO R1. Each Reliability Coordinator shall implement an Operating Process or Operating Procedure to address the quality of the Real-time data necessary to perform its Real-time 1
2 monitoring and Real-time Assessments. The Operating Process or Operating Procedure shall include: 1.1. Criteria for evaluating the quality of Real-time data; 1.2. Provisions to indicate the quality of Real-time data to the System Operator; and 1.3. Actions to resolve Real-time data quality issues with the entity(ies) responsible for providing the data when data quality affects Real-time Assessments. R3. Each Reliability Coordinator shall have an alarm process monitor that provides notification(s) to its System Operators when a failure of its Real-time monitoring alarm processor has occurred. IRO R5. Each Reliability Coordinator shall monitor Bulk Electric System elements (generators, transmission lines, buses, transformers, breakers, etc.) that could result in SOL or IROL violations within its Reliability Coordinator Area. Each Reliability Coordinator shall monitor both real and reactive power system flows, and operating reserves, and the status of Bulk Electric System elements that are or could be critical to SOLs and IROLs and system restoration requirements within its Reliability Coordinator Area. IRO R1. Each Reliability Coordinator shall monitor all Bulk Electric System facilities, which may include sub-transmission information, within its Reliability Coordinator Area and adjacent Reliability Coordinator Areas, as necessary to ensure that, at any time, regardless of prior planned or 2
3 unplanned events, the Reliability Coordinator is able to determine any potential System Operating Limit and Interconnection Reliability Operating Limit violations within its Reliability Coordinator Area. IRO R3. Each Reliability Coordinator shall monitor Facilities, the status of Special Protection Systems, and non-bes facilities identified as necessary by the Reliability Coordinator, within its Reliability Coordinator Area and neighboring Reliability Coordinator Areas to identify any System Operating Limit exceedances and to determine any Interconnection Reliability Operating Limit exceedances within its Reliability Coordinator Area. 3 Analysis Capabilities Requirement R2 addresses the quality of the analysis used by the RC to perform its Real-time Assessments. Each RC is required to implement a documented procedure to address the quality of the analysis used in its Real-time Assessments. The procedure must include criteria for evaluating the quality of analysis used in Real-time Assessments, provisions for indicating the quality of analysis, and actions to resolve analysis quality issues affecting its Real-time Assessments.. Requirements for the RC to perform Real-time Assessments are specified in IRO and IRO Proposed IRO R2. Each Reliability Coordinator shall implement an Operating Process or Operating Procedure to address the quality of analysis used in its Real-time Assessments. The Operating Process or Operating Procedure shall include:
4 2.1. Criteria for evaluating the quality of analysis used in its Real-time Assessments; 2.2 Provisions to indicate the quality of analysis used in its Real-time Assessments; and 2.3. Actions to resolve analysis quality issues affecting its Real-time Assessments. IRO R2. Each Reliability Coordinator shall perform a Real-Time Assessment at least once every 30 minutes to determine if its Wide Area is exceeding any IROLs or is expected to exceed any IROLs. Definition of Real-time Assessment An evaluation of system conditions using Real-time data to assess existing (pre-contingency) and potential (post- Contingency) operating conditions. The assessment shall reflect applicable inputs including, but not limited to: load, generation output levels, known Protection System and Special Protection System status or degradation, Transmission outages, generator outages, Interchange, Facility Ratings, and identified phase angle and equipment limitations. (Real-time Assessment may be provided through internal systems or through third-party services.) IRO R4. Each Reliability Coordinator shall ensure that a Real-time Assessment is performed at least once every 30 minutes. 4
5 P 1660 We adopt our proposal to require the ERO to develop a modification [to TOP standards] related to the provision of a minimum set of analytical tools. In response to LPPC and others, we note that our intent was not to identify specific sets of tools, but rather the minimum capabilities that are necessary to enable operators to deal with real-time situations and to ensure reliable operation of the Bulk-Power System. Proposed TOP addresses issues identified by the NERC Operating Committee's Real-time Tools Best Practices Task Force (RTBPTF) related to the availability and quality of the monitoring and analysis capabilities used by Transmission Operators (TOPs) and Balancing Authorities (BAs). The monitoring and analysis capabilities required by TOP and other TOP standards discussed below ensure TOPs and BAs have the capabilities to maintain Real-time situational awareness. Monitoring Capabilities Requirements R1 and R2 address the quality of the Real-time data needed by TOPs and BAs to perform their Real-time monitoring and Real-time analysis. Each TOP and BA is required to implement a documented procedure for addressing Realtime data quality issues. The procedure must include criteria for evaluating Real-time data quality, provisions for indicating data quality to the System Operator, and actions to resolve Real-time data quality issues when data quality affects analysis. Requirement R4 addresses capabilities for operator awareness of failures in Real-time monitoring alarm processes by requiring TOPs and BAs to use an alarm process monitor. Requirements for TOPs to perform Real-time monitoring are specified in TOP and TOP Requirements for BAs to perform Real-time monitoring are specified in TOP-006-2, TOP-001-3k and BAL standards. Proposed TOP R1. Each Transmission Operator shall implement an Operating Process or Operating Procedure to address the quality of the Real-time data necessary to perform its Real-time 5
6 monitoring and Real-time Assessments. The Operating Process or Operating Procedure shall include: 1.1. Criteria for evaluating the quality of Real-time data; 1.2. Provisions to indicate the quality of Real-time data to the System Operator; and 1.3. Actions to resolve Real-time data quality issues with the entity(ies) responsible for providing the data when data quality affects Real-time Assessments. R2. Each Balancing Authority shall implement an Operating Process or Operating Procedure to address the quality of the Real-time data necessary to perform its analysis functions and Real-time monitoring. The Operating Process or Operating Procedure shall include: 2.1 Criteria for evaluating the quality of Real-time data; 2.2 Provisions to indicate the quality of Real-time data to the System Operator; and 2.3 Actions to coordinate resolution of Real-time data quality discrepancies with the entity(ies) responsible for providing the data. 6 R4. Each Transmission Operator and Balancing Authority shall have an alarm process monitor that provides notification(s) to its System Operators when a failure of its Real-time monitoring alarm processor has occurred. TOP R1. Each Transmission Operator and Balancing Authority shall know the status of all generation and transmission resources available for use.
7 Each Generator Operator shall inform its Host Balancing Authority and the Transmission Operator of all generation resources available for use Each Transmission Operator and Balancing Authority shall inform the Reliability Coordinator and other affected Balancing Authorities and Transmission Operators of all generation and transmission resources available for use. TOP R10. Each Transmission Operator shall perform the following as necessary for determining System Operating Limit (SOL) exceedances within its Transmission Operator Area: Within its Transmission Operator Area, monitor Facilities and the status of Special Protection Systems, and Outside its Transmission Operator Area, obtain and utilize status, voltages, and flow data for Facilities and the status of Special Protection Systems. R11. Each Balancing Authority shall monitor its Balancing Authority Area, including the status of Special Protection Systems that impact generation or Load, in order to maintain generation-load-interchange balance within its Balancing Authority Area and support Interconnection frequency. 7 Analysis Capabilities Requirement R3 addresses the quality of the analysis used by the TOP to perform its Real-time Assessments. Each TOP is required to implement a documented procedure to address the quality of the analysis used in its Real-time Assessments. The procedure must include criteria for evaluating the quality of
8 8 analysis used in Real-time Assessments, provisions for indicating the quality of analysis, and actions to resolve analysis quality issues affecting its Real-time Assessments. Requirements for the TOP to perform Real-time Assessments are specified in TOP Proposed TOP R3. Each Transmission Operator shall implement an Operating Process or Operating Procedure to address the quality of analysis used in its Real-time Assessments. The Operating Process or Operating Procedure shall include: 3.1. Criteria for evaluating the quality of any analysis used in its Real-time Assessments; 3.2. Provisions to indicate the quality of analysis used in its Real-time Assessments; and 3.3. Actions to resolve analysis quality issues affecting its Real-time Assessments. Definition of Real-time Assessment An evaluation of system conditions using Real-time data to assess existing (pre-contingency) and potential (post- Contingency) operating conditions. The assessment shall reflect applicable inputs including, but not limited to: load, generation output levels, known Protection System and Special Protection System status or degradation, Transmission outages, generator outages, Interchange, Facility Ratings, and identified phase angle and equipment limitations. (Real-time Assessment may be provided through internal systems or through third-party services.) TOP R13. Each Transmission Operator shall ensure that a Real-time Assessment is performed at least once every 30 minutes.
9 P [w]e direct the ERO, through its Reliability Standards development process, to modify Reliability Standard VAR to include requirements to perform voltage stability analysis periodically, using online techniques where commerciallyavailable, and offline simulation tools where online tools are not available, to assist real-time operations. The directive was considered in developing the scope of Project NERC believes TOP, IRO, and VAR standards address the directive as discussed below. Accordingly, additional requirements were not developed in Project RCs and TOPs are required to periodically perform Real-time Assessments consisting of an evaluation of system conditions "to assess existing (pre-contingency) and potential (post- Contingency) operating conditions." Entities must use whatever analysis is necessary to obtain an evaluation of system conditions, which may include real-time voltage stability analysis. Real-time Assessments assist operators in maintaining operations within established SOLs and IROLs, to include voltage stability criteria. Requirements for performing Real-time Assessments are contained in IRO-008-1, IRO-008-2, and TOP Reliability Standards as discussed above. VAR was revised in Project The resulting standard, VAR-001-4, did not include an explicit requirement for periodic performance of voltage stability analysis because "such analysis would be performed pursuant to the SOL methodology developed under FAC standards." 1 VAR requirement R1 specifies the TOP must establish a system voltage schedule as part of its plan to operate within SOLs and IROLs. VAR R1. Each Transmission Operator shall specify a system voltage schedule (which is either a range or a target value with an associated tolerance band) as part of its plan to operate 1 Reliability Standard VAR , Guidelines and Technical Basis section, page 13. Available at: 9
10 within System Operating Limits and Interconnection Reliability Operating Limits Each Transmission Operator shall provide a copy of the voltage schedules (which is either a range or a target value with an associated tolerance band) to its Reliability Coordinator and adjacent Transmission Operators within 30 calendar days of a request. 10
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