Southwest Power Pool Independent Coordinator of Transmission RELIABILITY PLAN for Entergy in the Southeastern Electric Reliability Council September

Southwest Power Pool Independent Coordinator of Transmission RELIABILITY PLAN for Entergy in the Southeastern Electric Reliability Council September 23, 2009

TABLE OF CONTENTS INTRODUCTION A. RESPONSIBILITIES AUTHORIZATION B. RESPONSIBILITIES DELEGATION OF TASKS C. COMMON TASKS FOR NEXT-DAY AND CURRENT-DAY OPERATIONS D. NEXT-DAY OPERATIONS E. CURRENT-DAY OPERATIONS F. EMERGENCY OPERATIONS G. SYSTEM RESTORATION H. COORDINATION AGREEMENTS AND DATA SHARING I. FACILITY J. STAFFING APPENDIX A APPENDIX B

Introduction The North American Electric Reliability Council (NERC) requires every Region, Subregion, or interregional coordinating group to establish at least one Reliability Coordinator (RC) to provide the reliability assessment and emergency operations coordination for the control areas within the region and across the regional boundaries. Entergy is a member of the Southeastern Electric Reliability Council (SERC) Region of NERC. The Southwest Power Pool, as the Independent Coordinator of Transmission (ICT) for Entergy, will provide the required RC functions for ICT RC Reliability Area (ICT RC RA) that consists of the Balancing Authorities and Transmission Operators listed in Appendix A. NERC Regions/Subregions This document is the Southwest Power Pool Independent Coordinator of Transmission Reliability Plan for the ICT RC RA. The existing Entergy Reliability Plan (October 31, 2005) is posted on the NERC website (www.nerc.com/~filez/reliaplans.html). Upon approval of the 4 NERC Operating Committee and commencement of ICT RC operations, this plan will supersede the existing plan. The Southwest Power Pool, in accordance with a contract with Entergy, will be the ICT Reliability Coordinator (ICT RC). The ICT RC is responsible for bulk transmission reliability and power supply reliability within the ICT RC RA. Bulk transmission reliability functions include assessment of real-time, current day and next-day operating conditions, loading relief procedures, re-dispatch of generation, coordination of transmission and generation outages and ordering curtailment of transactions and/or load. ICT RC procedures and policies are consistent with those of NERC. A. Responsibilities Authorization 1. The ICT RC is responsible for the reliable operation of the Bulk Electric System (BES) in accordance with the NERC Reliability Standards. The ICT RC RA is composed of the Balancing Authorities and Transmission Operators listed in Appendix A. 1.1. The ICT RC has a wide area view and the operating tools, processes and procedures to prevent or mitigate emergency operation situations in both the nextday and real-time operating environments. 1.2. The ICT RC has clear decision-making authority to act and direct actions to be taken by Balancing Authorities and Transmission Operators within the ICT RC RA in order to preserve the integrity and reliability of the BES (which is defined as all facilities 100 kv and above). ICT RC responsibilities and authority are clearly defined in the executed contract between the ICT RC and Entergy and any applicable Reliability Coordination agreements. 1.3. The ICT RC has not delegated any tasks.

2. The ICT RC will act in the interests of reliability for the overall Reliability Area and its Interconnection before the interests of any other entity. 3. All Balancing Authorities and Transmission Operators within the ICT RC RA shall comply with the ICT RC s directives (including load shedding) unless such actions would violate safety, equipment, regulatory or statutory requirements. Under those circumstances, Balancing Authorities and Transmission Operators within the ICT RC RA must immediately inform the ICT RC of the inability to perform the directive so that the ICT RC may implement alternate remedial actions. B. Responsibilities Delegation of Tasks 1. The ICT RC has not delegated any tasks. C. Common Tasks for Next-Day and Current-Day Operations The ICT RC coordinates operations with regard to System Operating Limits (SOLs) and Interconnection Reliability Operating Limits (IROLs) during the real-time and next-day operating horizons for the ICT RC RA including thermal, voltage and stability related analyses. The ICT RC will communicate and coordinate the results of its reliability assessments within the ICT RC RA to ensure that any potential or actual SOL violations are properly identified and reported. Any potential SOL or IROL violations identified by a Transmission Operator within the ICT RC RA during their reliability assessments (if any) are immediately reported to the ICT RC. The ICT RC will inform adjacent RCs of any potential IROLs or SOLs noted on the adjacent RC system by the ICT or noted by a Transmission Operator in the ICT RC RA during their analysis and reported to the ICT RC. The ICT RC models a sufficient wide-area view to ensure properly coordinated operations with neighboring RCs. 1. The ICT RC identifies possible IROLs using the daily planning model based on the criteria defined in the Calculation of Interconnection Reliability Operating Limits process document. This is done on a daily basis or as warranted by changes in system topology. The Entergy Transmission Operator (ETO) will also use the same criteria to identify possible IROLs and will immediately notify the ICT RC of any possible IROL conditions that are identified, including any potential IROL violations caused by outages of multiple facilities that are normally non-critical. 2. The ICT RC is responsible for identifying any possible SOLs or IROLs within the ICT RC RA using the daily planning model. The ETO also performs this analysis and communicates the results of their analysis through daily RC meetings with the ICT RC. The ICT RC screens the information presented at the RC meeting to ensure that the ICT

RC is aware of any potential SOL or IROL violations. In instances where there are differences in operating limits derived by the ICT RC, the ETO and adjacent RC s, the ICT RC will operate to the most conservative limit or to the limit agreed upon by both/all parties until the reasons for these differences can be identified. 3. The ICT RC ensures that the entities within the ICT RC RA operate to prevent the likelihood that a disturbance, action or non-action in the ICT RC RA will result in a SOL or an IROL violation in another area of the Interconnection. Entities within the ICT RC RA are required to operate in accordance with both the NERC Reliability Standards and the SERC Supplements to these standards. The ETO, in its operational planning process, coordinates maintenance outages with its neighbors to minimize potential impacts on those systems reliability and provides the results to the ICT RC for final approval and coordination with adjacent RCs. Each business day (Monday through Friday), the ICT RC and the ETO perform N-1 (single) contingency analyses for up to a 14 day rolling calendar period. The ETO also operates a Real-time Analysis desk 24 hours per day, 7 days per week. The state estimator automatically runs an N-1 contingency analysis every ninety (90) seconds and displays the results for both the ICT RC and the Entergy Real- Time Analysis position operator to review. This enables both the ICT RC and the ETO Real-Time Analysis operator to monitor changing system conditions through N-1 contingency analysis. In instances where there are differences in operating limits derived by the ETO and its neighbors, the ICT RC will ensure that the ICT RC RA is operated to the most conservative limit or the limit agreed upon by both/all parties until the reasons for these differences can be identified. 4. In compliance with NERC s Emergency Preparedness and Operations Standards, the ICT RC ensures that entities within the ICT RC RA are always operating under known and studied conditions. The ICT RC reassesses and repositions the system (if necessary) within 30 minutes following contingency events, regardless of the number of contingency events that occur or the status of the monitoring, operating and analysis tools. Each business day (Monday through Friday), the ICT RC and the ETO perform N-1 contingency analysis for up to a 14 day rolling calendar period. The analyses look at peak conditions for the days being studied including scheduled generation outages, scheduled transmission outages, and anticipated generation dispatch to support the forecasted load plus net interchange. The ICT RC and the ETO share the results of their analyses. If a potential SOL or IROL violation is observed, the ICT RC will coordinate with the impacted and impacting parties to develop an appropriate mitigation plan with input from the ETO, if a mitigation plan does not already exist. The ICT RC and the ETO monitor all facilities considered critical in real-time. Real-time flows on all critical facilities are monitored and alarmed at the SOL level in the ETO Energy Management System (EMS) system. The ETO Real-Time Contingency Analysis (RTCA) application runs automatically every 90 seconds. The ICT RC and ETO monitor all branches, 100kV and higher within the ICT RC RA via the RTCA application. The ICT RC and the ETO monitor post-contingent loading on selected transmission facilities

within neighboring systems that are known to be significantly impacted by contingencies within the ICT RC RA. The ICT RC communicates all identified SOLs and IROLs within the ICT RC RA to all entities that may be impacted by these limits. 5. The ICT RC issues directives in a clear, concise, definitive manner within the ICT RC RA in compliance with the NERC Reliability Standards. Proper communication protocols are included in training provided to the ICT RC operators. D. Next-Day Operations 1. The ICT RC has the primary responsibility for current day and next day operational planning. Each business day (Monday through Friday), the ICT RC and the ETO perform next-day reliability analyses to identify potential SOL and IROL violations. The ICT RC s day-ahead reliability assessment consists of off-line PSS/E (Power System Simulation for Engineering power flow analysis system) N-1 contingency analysis studies of the expected peak system conditions. The ETO performs an N-2 contingency analysis for known load pockets, which looks simultaneously at the loss of the largest generator and the loss of the strongest transmission source/line and makes the results available to the ICT RC. ETO facilities rated 100kV and above are included in these contingency analyses. The ICT RC and the ETO also perform an N-1 contingency analysis for up to a 14 day rolling calendar period. Planned transmission outages within the ICT RC RA are accounted for in this analysis. Entergy s Transmission Automated Outage Request System (TAORS) documents all approval/disapprovals of line outages and provides the information required for updates to the System Data Exchange (SDX). Planned outages external to the ICT RC RA are obtained from the SDX and included in all N-1 and/or N-2 analyses. Peak conditions are modeled using forecasted generation dispatch to support the forecasted load plus expected scheduled net interchange. These models and analysis results are made available to the ICT RC for review. If the ICT RC has concerns about the analysis or needs some additional analysis performed, the ICT RC may perform the additional analysis or request that the ETO perform the analysis and provide the results to the ICT RC on a high priority basis. 1.1 The ICT RC will contact the affected RC if, in the next-day reliability analysis, parallel flows from the ICT RC RA are observed as causing a potential IROL violation within the neighboring RC s Reliability Area. If it is agreed that an IROL violation could occur, the ICT RC will coordinate with the neighboring RC to develop an appropriate mitigation plan if one does not currently exist. The mitigation plan will identify appropriate actions to be taken in order to prevent the IROL violation from happening, including commitment of appropriate generation capacity, reconfiguration of the transmission system, or re-dispatch of generation. The mitigation plan will also address real-time actions to be taken in the event of the IROL violation. These actions may include transmission system reconfigurations, generation re-dispatch, curtailment of schedules and load shedding.

2. The ETO receives information such as transmission and generation facility maintenance schedules, load forecasts, generation resource plans, and operating reserve projections required for performing reliability analyses from: Entergy s TAORS, Planned Generator Outages Information source (E-POWR), Entergy s System Planning and Operations (SPO) Projected 7 Day Load and Capability Report, and the Monthly Energy Plan (MEP). Other sources such as SDX are used to obtain outage information from neighboring control areas. The ETO uses E-tag data as its basis for incorporating Interchange Transactions into the reliability analyses. The resulting models are made available to the ICT RC for use in their analysis. 3. The ICT RC and ETO share the results of their reliability analyses. When conditions warrant, or upon request, the ICT RC shares the analyses results with other entities within the ICT RC RA (to the extent permitted by the applicable Standards of Conduct) or neighboring RCs either directly by phone or via conference calls. The ICT RC shall issue the appropriate alerts via the RCIS, if the results of the reliability analyses indicate potential reliability problems and efforts outlined in (4.) below do not resolve the potential condition. 4. The ICT RC initiates conference calls or other appropriate communications as necessary when conditions revealed by the reliability analyses warrant. Conditions that warrant communications with other RCs include potential IROL violations determined as described in (1.1) above and capacity deficiencies that could result in the shedding of firm load. E. Current-Day Operations 1. The ICT RC monitors all facilities within the ICT RC RA and adjacent RC areas as necessary to ensure that, at any time, regardless of prior planned or unplanned events, the ICT RC is able to determine any potential SOL and IROL violations within the ICT RC RA. The ICT RC and the ETO monitor real-time flow and status information for all facilities rated 100 kv and above. All branches rated 100kV and higher within the ICT RC RA are defined as contingencies in the RTCA. The ICT RC and the ETO monitor the post-contingent loading on its branches rated 100 kv and higher through a contingency analysis report from RTCA that is generated to notify the ICT RC if post contingent flow on a particular branch is projected to be above the operating limit of the branch. 1.1. The ICT RC will make reasonable efforts to provide notice to a neighboring RC if a potential reliability problem is identified that impacts that RC s Area. If both parties agree that a reliability problem exists, the ICT RC will coordinate any actions required to mitigate the situation with its neighboring RCs. This coordination may include evaluation of the impact of maintenance and forced outages on the situation, the implementation of existing emergency procedures or operating guides, reconfiguration of the transmission system, curtailment of point-to-point transactions, re-dispatch of generation and load shedding.

2. Real-time flows on all facilities rated 100 kv and higher are monitored and alarmed for SOL violations in the EMS system. Post-contingent loading on flowgates is calculated using realtime flows and Line Outage Distribution Factors (LODFs) that are updated to reflect current system topology at least once per day or more often as system topology changes. Postcontingent loading on flowgates is also calculated using the State Estimator. The ICT RC has knowledge of current and planned critical facility status. The planned outage schedule is communicated to the ICT RC by means of the TAORS application. 3. The ICT RC and the ETO monitor the necessary subregion parameters to ensure continuous awareness of conditions within the ICT RC RA. 3.1. The ICT RC and the ETO monitor the status of the BES elements using an EMS system, which includes a State Estimator, Alarming, RTCA, and Power Flow applications. 3.2. The ICT RC and the ETO monitor the real-time status of all BES elements in the ICT RC RA. Entergy s EMS model has approximately 3,400 buses modeled. Entergy receives approximately 59,000 real-time EMS data points from the ICT RC RA and surrounding areas. These points are updated every 2-30 seconds. The real-time data points received include real and reactive flows on lines, transformers, generating units, loads, and shunts; status points of breakers, switches, and disconnects; frequency values from selected points across the ICT RC RA ; and voltage measurements on buses. 3.3. The ICT RC and the ETO monitor selected post-contingency element conditions in realtime using custom EMS displays which utilize (LODFs) that are calculated once a day or more often as system topology changes. The ICT RC and the ETO also monitor all Postcontingency conditions in real-time using the RTCA tool. 3.4. The ICT RC and the ETO monitor real and reactive reserves as well as real and reactive output of generators within the ICT RC RA. The ICT RC and the ETO receive MW and MVAR values from generators located within the Balancing Authorities in the ICT RC RA by direct telemetry or ICCP. 3.5. The ICT RC and the ETO monitor capacity and energy adequacy conditions. The ICT RC communicates with the Balancing Authorities in the ICT RC RA as necessary. 3.6. The ICT RC monitors current Area Control Error (ACE) in real-time for all Balancing Authorities in the ICT RC RA. This information is displayed and monitored continuously. 3.7. The ICT RC and the ETO monitor local procedures and TLR procedures that are in effect outside the ICT RC RA using both the IDC and the RCIS. 3.8. The ICT RC and the ETO monitor planned generation dispatch. The ICT RC receives and reviews resource plans for the Balancing Authorities in the ICT RC RA.

3.9. The ICT RC and the ETO monitor the impact of all planned transmission and generation outages within the ICT RC RA to ensure that no unforeseen adverse impacts occur when the outages are taken. 3.10. The ICT RC and the ETO monitor and manage contingency events using an EMS alarming application and State Estimator/Power Analysis tools and displays. 4. The ICT RC and the ETO monitor BES parameters that may have a significant impact on the ICT RC RA and neighboring RC Areas as follows: 4.1. The ICT Tariff Administrator approves all transmission service requests using the OASIS and maintains awareness of all Interchange Transactions (E-Tags) that wheelthrough, source, or sink in the ICT RC RA. The ETO is the approval authority for all transactions (E-Tags) that wheel-through, source, or sink in the Entergy Balancing Authority Area. When a transaction that wheels-through, sources, or sinks outside the Entergy Balancing Authority impacts a flowgate within the ICT RC RA, the ICT RC is made aware of this transaction via the IDC. The ICT RC can and will make that information available to all RCs in the Interconnection as necessary. 4.2. The ICT RC and the ETO evaluate and assess additional Interchange Transactions that could violate SOLs and/or IROLs. The ICT RC and the ETO utilize tag information in the IDC and real-time data in EMS to make an assessment of the impact of additional transactions on flowgate loading. The ICT RC is authorized to utilize all resources including load shedding to address a potential or actual IROL violation. This authorization is given to each ICT RC operator in their job description. 4.3. The ICT RC Operator monitors Balancing Authority parameters to ensure that the required amount of Operating Reserves is provided and available, as required to meet NERC Control Performance Standard and Disturbance Control Standards, using the EMS system. If necessary, the ICT RC will direct the Balancing Authorities in the ICT RC RA to arrange for assistance from neighboring Balancing Authorities. 4.4. The ICT RC will identify the cause of potential or actual SOL or IROL violations. The ICT RC shall initiate control actions or emergency procedures to relieve the potential or actual IROL violation without delay and in no longer than 30 minutes. The ICT RC will choose the most effective means of relieving the violation within 30 minutes including directing schedule curtailment, generation redispatch, facility switching and load shedding, if an IROL violation should occur. As stated in Section 4.2 above, the ICT RC has the authority to direct utilization of all resources, including load shedding, to address a potential or actual IROL violation. 4.5. The ICT RC will communicate start and end times for time error corrections to all Balancing Authorities within ICT RC RA via phone calls or other appropriate communication methods. The ICT RC will ensure that all Balancing Authorities and Transmission Operators within the ICT RC RA are aware of Geo-Magnetic Disturbance

(GMD) forecast information and will assist in the development of any required response plans via phone calls or other appropriate communication methods. 4.6. The ICT RC will participate in NERC and regional Hotline discussions, assist in the assessment of reliability of the Regions and the overall interconnected system, and coordinate actions in anticipated or actual emergency situations. The ICT RC will disseminate this information within the ICT RC RA using phone or other appropriate communication methods. 4.7. The ICT RC monitors system frequency and the ACE and Operating Reserves of each Balancing Authority in the ICT RC RA. The ICT RC will direct any necessary rebalancing required for a Balancing Authority to return to CPS and DCS compliance. At the direction of the ICT RC, its Balancing Authorities shall utilize all resources, including firm load shedding, to relieve an emergency condition. 4.8. The ICT RC coordinates with other RCs and neighboring Balancing Authorities as needed, for the development and implementation of action plans to mitigate potential or actual SOL, IROL, CPS, or DCS violations. The ICT RC coordinates pending generation and transmission maintenance outages with other RCs as necessary, in both the real-time and next-day reliability analysis timeframes. Both the ICT RC and the ETO participate in weekly conference calls to coordinate outages with CLECO, Lafayette, SPP, AECI, and SPA. 4.9. The ICT RC will assist the Balancing Authorities in the ICT RC RA in arranging for assistance from neighboring RCs or Balancing Authorities by issuing Energy Emergency Alerts as appropriate. 4.10. The ICT RC identifies sources of large Area Control Errors that may be contributing to frequency, time error, or inadvertent interchange and will implement corrective actions with the appropriate Balancing Authority. The ICT RC receives the real-time ACE from each Balancing Authority in the ICT RC RA via the EMS. Where excessive ACE is noted, the Balancing Authority is called to determine the cause of the deviation and the course of action that the Balancing Authority has planned and/or implemented to address the situation. If the situation is causing overloads on system facilities, direction is issued to dispatch/redispatch generation to relieve the situation. 4.11. The ICT RC maintains awareness of Special Protection Systems (SPS) that are armed and that could potentially affect transmission flows resulting in a SOL or IROL violation. The ETO will keep the ICT RC informed of any expected degradation or potential failure of an SPS to operate. 4.12. The ICT RC will issue an alert to all Balancing Authorities and Transmission Operators in the ICT RC RA, and all RCs within the Interconnection via the RCIS when it foresees an IROL violation or an event such as a significant loss of real and/or reactive generation capacity within the ICT RC RA. The ICT RC will disseminate this information to its Balancing Authorities by phone.

5. The ICT RC confirms reliability assessment results and determines the effects within the ICT RC RA. The ICT RC and the ETO will derive and discuss options to mitigate potential or actual SOL or IROL violations and identify and implement only those actions as necessary. The ICT RC will act in the best interest of the Interconnection at all times. F. Emergency Operations 1. The ICT RC will direct its Balancing Authorities and Transmission Operators to return facility loadings on the transmission system to within applicable IROLs as soon as possible, but no longer than 30 minutes. The ICT RC will direct the necessary actions such as system reconfiguration, generation redispatch or load shedding until relief requested through the congestion management process has been achieved. 2. The ICT RC will implement processes and procedures when IROL violations are imminent. The procedures include generation redispatch, reconfiguring transmission, managing Interchange Transactions or reducing system demand to mitigate the IROL violation until transactions can be reduced utilizing the appropriate loading relief procedure to return the system to a reliable state. The ICT RC will coordinate its alert and emergency procedures with other RCs as necessary via the NERC RCIS and/or telephone. 3. In the event that the loading of transmission facilities progresses to or is projected to progress to an SOL violation and Interchange Transactions exist that have significant loading impact on the transmission facilities, the ICT RC will use Transmission Loading Relief (TLR) procedures to reduce the loading. If no significantly impacting Interchange Transactions exist, the ICT RC and the ETO will identify the appropriate actions to be taken to reduce the loading, including generation redispatch and system reconfiguration. In the event that the loading of transmission facilities progresses to or is projected to progress to an IROL violation, the ICT RC will ensure that immediate actions are taken to alleviate the potential violation. 3.1. The ICT RC may implement a local transmission loading relief procedure or the NERC TLR procedures for resolving a potential or actual SOL or IROL violation on the transmission system within the ICT RC RA. The ICT RC maintains communication with the Transmission Operator(s) within the ICT RC RA who are responsible for implementing the guides for local area relief to ensure regional reliability is not jeopardized by the implementation of these procedures. 3.2. Local relief procedures and guides are used by the ICT RC and the ETO in response to appropriate contingency events. When these guides are anticipated to impact neighboring facilities outside of the ICT RC RA, the ICT RC will ensure appropriate communications and coordination occurs with the RC of the impacted entities.

3.3. The ETO will implement a local transmission loading relief procedure simultaneously with the NERC TLR procedures implemented by the ICT RC when the ICT RC deems it necessary. It is typically assumed that NERC TLR procedures are ineffective in dealing with local area problems. In the event of local area problems, the ICT RC will direct the ETO to implement operating directives as necessary. The ETO may request the ICT RC to implement a TLR and the ICT RC may implement the TLR, if it deems a TLR to be the appropriate course of action. 3.4. The ICT RC will comply with the provisions of the NERC TLR procedure. If the ICT RC receives notification via the IDC that another RC has issued a TLR that calls for curtailment and/or halts of transactions within the ICT RC RA, the ICT RC will use the IDC to acknowledge the curtailments/holds. The ICT RC will ensure that the transaction curtailments/holds are properly implemented. After impact evaluations, if the ICT RC determines that curtailment of a transaction as identified by the IDC would actually increase flows on the flowgate for which relief has been requested, it will not acknowledge curtailment of such transaction. The ICT RC may also determine, through impact evaluation, any transaction that has a significant impact on the flowgate, but has not been identified for curtailment by the IDC. If this should occur, the ICT RC will direct curtailment of those transactions as necessary. 3.5. The ICT RC will follow established procedures and processes to achieve the required relief including emergency procedures as required during the implementation of relief procedures. When the ICT RC observes flowgate loading that approaches the applicable SOL, it will communicate with the flowgate owner to verify actual real-time flows and coordinate necessary actions to be taken. The ICT RC will make a coordinated decision based on current and/or anticipated conditions to pursue relief by using either the NERC TLR procedures or an available local operating procedure. The ETO may, in an emergency, unilaterally take actions to preserve reliability and must immediately inform the ICT RC of the actions taken and the reasons for taking the action. 4. The ICT RC constantly monitors the interconnection frequency. If a significant interconnection frequency deviation is noted, the ICT RC will then check the ACE of each of the balancing authorities within the ICT RC RA to see if any Balancing Authorities are contributing to the frequency deviation. If a Balancing Authority is contributing to the frequency deviation, the ICT RC will notify them and instruct them to take all necessary actions to restore their ACE to zero. 5. The ICT RC will take or direct action as needed, including load shedding, to mitigate an energy emergency within the ICT RC RA in compliance with NERC Standard EOP- 002-0. The ICT RC will also provide assistance to other RCs experiencing an energy emergency as necessary. 6. When experiencing a potential or actual Energy Emergency within the ICT RC RA, the ICT RC will implement processes and procedures, including the NERC Standard EOP- 002-0, to 14 mitigate the emergency condition. The ICT RC will take the necessary

actions, including a request for emergency assistance and directing load shedding, if required. G. System Restoration 1. Each entity within the ICT RC RA has a restoration plan and the ICT RC has a written copy of each plan in its possession. Each restoration plan is reviewed annually. The ICT RC will monitor the restoration progress and coordinate any needed assistance during the system restoration with adjacent RC s. 2. The ICT RC will ensure that the restoration plans of each entity within the ICT RC RA are coordinated in order to ensure that reliability is maintained during system restoration events. 3. The ICT RC will disseminate information regarding restoration to entities not immediately involved and neighboring RCs via direct phone call or by posting pertinent information on the RCIS. The ICT RC may also use the NERC Hotline for periodic updates to neighboring RCs. H. Coordination Agreements and Data Sharing 1. The ICT RC and its adjacent RCs (MISO, Southern and TVA) will begin negotiating written coordination agreements as soon as the enabling order is issued by the FERC. 2. The ICT RC and other RCs share data (via ISN and RCIS) as requested to support reliability coordination. I. Facility The ICT RC performs the ICT RC function at the SPP Coordination Center (SPPCC) located in Little Rock, Arkansas. The SPPCC has the necessary facilities for the ICT RC to perform its responsibilities. The SPPCC building has back-up power supplies. The back-up facility for the ICT RC will be the Entergy System Operations Center (SOC) in Pine Bluff, Arkansas. The Entergy SOC will provide disaster recovery functionality and will have a full backup of systems, communications, data, and tools required for the ICT RC to perform its responsibilities for the ICT RC RA in the event of an emergency. 1. The ICT RC has adequate and reliable voice and data link communications to the appropriate entities within the ICT RC RA, which are staffed and available to act in addressing a real time emergency condition. Cell phones are used as the secondary voice communication capability. Cell phones will be used for communications during the ICT RC transition to the Entergy SOC. SPP and Entergy Information Technology on-call staff provides support of the voice and data communications. Call-out service is available 24

hours/day for hardware and application software. The ICT RC controls its Reliability Coordinator analysis tools, including approvals for planned maintenance. 2. The ICT RC has multi-directional data and voice capabilities with its Balancing Authorities and Transmission Operators and neighboring Reliability Coordinators. 3. The ICT RC has the ability to monitor key external components that may cause an SOL or IROL violation in the ICT RC RA. The ICT RC has established data links with all Balancing Authorities and Transmission Operators within the ICT RC RA along with each of the neighboring RCs for the purpose of exchanging system data. These capabilities are provided to the ICT RC by the ETO EMS and the associated NERC Net connection. 4. The ICT RC utilizes a State Estimator (provided by the ETO EMS) to identify contingency elements that have the potential to cause an SOL or IROL violation. In addition to the State Estimator, the ICT RC monitors the status of key generators, transmission lines, busses, transformers, breakers and other equipment within the ICT RC RA and neighboring Balancing Authorities. 5. Study and Analysis Tools 5.1. The ICT RC has access to a fully functional State Estimator (provided by remote terminals connected to the ETO EMS) that is capable of calculating pre and Postcontingency thermal and voltage analysis. The ETO has a voltage stability analysis tool that will work with the State Estimator. 5.2. The ICT RC currently has a wide area view built into the State Estimator that monitors approximately 1600 external busses. The ICT RC is continually making improvements to their wide area view as needed to ensure reliability. 5.3. The ICT RC continuously monitors the ICT RC RA for potential SOL and IROL violations using the state estimator, custom EMS displays and the EMS alarm application. The ICT RC backup capability is provided by the ETO SOC in Pine Bluff, Arkansas 5.4. The ICT RC utilizes PSS/E to study projected system conditions in the next day environment. In the current day environment, the ICT RC utilizes the State Estimator and/or PSS/E to study all planned maintenance. J. Staffing 1. The ICT RC is staffed 24 hours per day, 7 days per week with appropriately trained, NERC Certified RC operators. The ICT RC requires its operators to complete a minimum of ten days per year of training and drills in addition to other training to maintain

qualified operating personnel. The ICT RC employs full-time trainers that are responsible for all operator training and certification. 2. The ICT RC ensures that its RC operators have a comprehensive understanding of the ICT RC RA and neighboring RCs. ICT RC operators communicate with the neighboring RCs by telephone or RCIS as needed. Each ICT RC operator has an extensive understanding of the Balancing Authorities and Transmission Operators, within the ICT RC RA; including staff, operating practices and procedures, restoration priorities and objectives, outage plans, equipment capabilities and restrictions. The ICT RC operators pay close attention to post contingent loading on facilities within the ICT RC RA using the state estimator and other real-time monitoring tools. In order to be prepared, the ICT RC ensures that the proper operating procedures are in place when necessary. Below is a list of procedures that are available to help the operators prepared for unexpected events. Blackstart Restoration Plans Emergency Evacuation Plans Operating During a Loss of Voice Communications Procedure for Operating Without an EMS System 3. The ICT RC is responsible for the Reliability Coordinator function and has signed and will adhere to the NERC Reliability Coordinator Standards of Conduct. The NERC Reliability Coordinator Standards of Conduct was signed by the SPP on August 23, 2000. 4. The ICT RC is independent of any merchant function and does not share information or data with any wholesale merchant function or retail merchant function that is not made available simultaneously to all wholesale merchant functions (Internal and External). Notifications to the marketplace are done through an internet posting on the Entergy OASIS website. Appendix A ICT RC Balancing Authorities: Entergy Electric System (EES) ICT RC Transmission Operators: Entergy Electric System (EES) Appendix B

Entergy Transmission Loading Relief Procedures The various procedures referred by this document are subject to change from time to time and new procedures are implemented as operational conditions dictate. Such changes and additions do not necessarily require modification of this document as such changes are incorporated into this document by reference. These procedures, along with others that are used by the ICT RC and the Balancing Authorities and Transmission Operators, are available upon request.