fiell4,b r E.VERGY HLBP - REAL n.we OPER4 T1O.VS DfI ISI0.v OWAGE AND CLEARANCE COORDINATlOtV PROCEDUW rvove%.weer I. I999

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1 fiell4,b r E.VERGY HLBP - REAL n.we OPER4 T1O.VS DfI ISI0.v OWAGE AND CLEARANCE COORDINATlOtV PROCEDUW rvove%.weer I. I999 The Customer is responsible for providing all equipment, in accordance with the Company s specifications, whenever changes in the Company s transmission system, including monitoring and protection devices, require changes in the Customer s interconnected facilities to maintain compatibility. The Customer will notify the Company of any proposed changes to their facilities. This notification will include providing necessary details so that the Company can provide comments based upon a general, functional, and compliance review. The Customer will not procure any equipment or materials or begin any work until all Company comments are incorporated or resolved. The Customer must obtain written consent from the Company to operate generation equipment in parallel with and concurrent with transmission service supplied by the Company. Special protective relaying may be required to prevent back-energizing the Company s system. All typical and special generator relaying will be in service whenever such generation is on-line. The Customer will operate generating units in such a manner so as not to unduly affect Company s voltage waveform. The Customer is responsible for providing suitable apparatus to hold voltage fluctuations to reasonable limits should Customer equipment cause voltage fluctuations that interfere with the Company s transmission service. The Customer will switch substation equipment, reduce MW output, change reactive output, or perform other measures to help alleviate an emergency. The Company may interrupt transmission service to and deliveries from the Customer in the event of an emergency. Authorized representatives of the Company are to have access to the Customer s premises for the purpose of inspecting Company s wiring and apparatus, repairing, erecting, removing, or replacing its facilities, reading its meters, and for all other purposes related to the interconnection including switching Company equipment. The Customer will provide necessary equipment outages to allow the Company to perform periodic maintenance on its facilities or to repair or replace its facilities. 5 50

2 2. Communications with Company Real Time Operations Division The Company's Real Time Operations Division (RTO) is responsible for operating the Company's transmission system and coordinating the operation of interconnected high voltage facilities and generation facilities. RTO provides routine and emergency switching instructions, issues clearances, schedules generation, provides generation instructions, implements power transfers, and dispatches Company crews for electrical outages and problems. The Customer will schedule planned outages and obtain switching instructions related to the incoming substation that is directly interconnected with the Company's transmission system. Switching in remote facilities interconnected to the incoming substation does not need to be scheduled. Long Range Transmission Outage Scheduling: RTO System Coordinator The Customer will schedule planned outages with the RTO System Coordinator from one month to eighteen months before the desired outage date. The RTO System Coordinator can be contacted from 7:OO A.M. to 3:30 P.M. on Company business days. Short Range Transmission Outage Scheduling: RTO System Scheduler , Fax The Customer will schedule planned outages with the RTO System Scheduler from one day to one month before the desired outage date. All requests must be received by at least 1 :00 P.M. of the last Company business day before the desired outage date. Requests are considered in the order they are received. The RTO System Scheduler can be contacted from 7:OO A.M. to 3:30 P.M. on Company business days. Switching Orders, Clearances: RTO Svstem Controller The Customer will call the RTO System Controller immediately before any switching to obtain switching instructions and to request or release clearances. The Customer will notify the RTO System Controller of emergencies, unplanned outages, and equipment problems and alarms. The RTO System Controller can be contacted twenty-four hours a day, seven days a week. UnDlanned Outages, Emergencies: RTO HOTLINE The Customer may use the RTO HOTLINE for advising the RTO System Controller of unplanned outages, forced transmission equipment outages, or emergencies involving their substation or Company transmission lines. The RTO HOTLINE can be used at any time. Generation Outage Scheduling: RTO Control Area Coordinator The Customer, if applicable, will schedule planned unit outages with the RTO Control Area Coordinator from one month to eighteen months before a planned outage. The RTO Control Area Coordinator can be contacted from 7:OO A.M. to 3:30 P.M. on Company business days. Independent Power Producers, although not required, are encouraged to schedule their outages also. Generation ODeration: RTO Control Area ODerator , Fax The Customer, if a Cogenerator selling NEP or FEP energy to Company, will fax weekly or twentyfour hour generation schedules from one day to one month before the effective date to the RTO Control Area Operator. All schedules must be received by at least 1:00 P.M. of the day before the effective date. The Customer will call the RTO Control Area Operator for advising the Company of 6 51

3 RELUNT EMRGY HL&P - RL~L TIME OPER~~OXS DIVISION ObTAGE AND CLEARANCE COORDINAnON PROCEDLIm XOVEMBER forced unit outages and generation equipment problems. The RTO Control Area Operator can be contacted twenty-four hours a day, seven days a week. Industrial & Large Commercial Accounts Division The Company s Industrial & Large Commercial Accounts Division (ILCA) is responsible for coordinating the Customer s service needs within the Company. ILCA Power Consultants will endeavor to inform the Customer of planned switching that may affect the Customer s facility. The Customer will notify the ILCA Power Consultant when equipment additions are planned or when high voltage equipment or associated equipment requires modification or replacement. The Customer can contact an ILCA Power Consultant to request current Company specifications and applicable bills of material for substation equipment additions and replacement. ILCA s Power Consultants can be contacted for any questions concerning the operation of the Customer s substation. An on-duty ILCA Power Consultant can be contacted at from 8:00 A.M. to 5:OO P.M. on Company business days or at twenty-four hours a day, seven days a week. Substation and Equipment Identification The Company assigns a Substation ID of six characters or less to identify the Customer s substation facility. The Substation ID is also referred to as the six character mnemonic name in which some characters may be blank. The Company will mount signs with the Substation ID on a substation control house door and 0n.a substation entrance gate at the Customer s facility. The Customer s high voltage circuit breakers and switches, transformers, and certain low side equipment will be identified with Company assigned numbers. The Company will develop a substation basic one-line diagram that includes these assigned numbers. The Company or the Customer will mark these numbers on the substation equipment. The Company may stencil identification numbers on substation equipment and mount signs, labels, drawings, telephone numbers, and instructions on the Customer s facilities. The Customer will use the Company assigned Substation ID and equipment identification numbers in discussions with the RTO System Controller and the RTO System Scheduler. Telephone Lines and Data Communication The Customer will maintain a telephone in the substation control house connected to an outside telephone line independent from the Customer s telephone system. The Customer will maintain an automatic ring down telephone from the Customer s generation control centers to the RTO Control Area Operator and will maintain data acquisition equipment to provide real-time data to RTO if the Customer operates applicable electric generating facilities. The Company will maintain a communication circuit for real time data if applicable SCADA (Supervisory Control and Data Acquisition) equipment is installed at the Customer s facility. 7 52

4 Alarm Response The Company will respond to alms for communication relaying equipment installed for the protection of Company transmission circuits. The Customer will report alarms to the RTO System Controller and respond to alarms pertaining to their equipment. A LOSS of DC alarm should be immediately reported and investigated. 8 53

5 3. Schedulinv Transmission Equipment Outapes Long Range Outage Scheduling R&LL.I.%T E.+ ERG Y HL&P - ndwe OPERA TOIVS DIVISION OLITAGE AND CLEAR.hK COORDINA~ON PROCEDURES JVOVEMBER I The Customer will schedule planned transmission equipment outages with the RTO System Coordinator from one month to eighteen months before the desired outage date. This applies to the incoming substation that is directly interconnected with the Company s transmission system. Outages do not need to be scheduled for remote facilities interconnected to the incoming substation. An eighteen-month substation maintenance and construction outage schedule should be provided. The RTO System Coordinator can be contacted at from 7:OO A.M. to 3:30 P.M. on Company business days. Short Range Outage Scheduling The Customer will schedule planned transmission equipment outages with the RTO System Scheduler from one day to one month before the desired outage date. This applies to the incoming substation that is directly interconnected with the Company s transmission system, Switching in remote facilities does not need to be scheduled. All requests must be received by at least 1:00 P.M. of the last Company business day before the desired outage date. Requests are considered in the order they are received. The Customer may request the Company provide switching or grounding services at the Customer s substation by contacting the RTO System Scheduler. This request must be received at least two Company business days before the desired date. The RTO System Scheduler can be contacted at from 7:OO A.M. to 3:30 P.M. on Company business days. An Outage Scheduling Check List form is included in this document. The RTO System Scheduler will coordinate a review and notify the Customer whether or not the outage can be scheduled for the desired day. Certain transmission line outages require the approval of the ERCOT IS0 (Electric Reliability Counsel of Texas Independent System Operator). The Customer will notify the RTO System Scheduler as soon as possible if an outage is canceled prior to the outage date. The Customer will immediately notify the RTO System Controller if an outage is canceled on the day of the outage. The Company will endeavor to notify the Customer as soon as possible when the Company deems it necessary to cancel an outage. 9 54

6 E.VERCY HL&P - R.E..(L nme O?ER4nONS DIV/S/Or~ ~LIAiCT OUTAGE AND CLE4RANCE COORDINATION PROCEDURES NOVEMBER I RELIANT ENERGY HL&P OUTAGE SCHEDULING CHECK LIST The following basic procedures are for scheduling transmission equipment outages. This applies to the incoming substation that is directly interconnected With the Company s transmission system. RTO SYSTEM SCHEDULER: o Call the RTO System Scheduler a Record the RTO System Scheduler s name: o Provide the following information o Your name, company affiliation, and telephone number o Substation ID: a Equipment to be de-energized: Date of desired outage: c1 Time of desired outage: o Expected duration of desired outage: a Specify whether a clearance will be requested on the day of the outage o Specify whether any isolated, high voltage devices will be operated during the outage o Specify if maintenance of instrument transformers connected to Company meters is planned o Specify if Company grounding of Company lines or equipment is required o Specify the number of grounds: Specify the preferred locations of grounds: a Provide the name, phone number, and pager number of the person to contact BY: DATE: 10 55

7 4. Switchinv, Clearances, Grounding Switching The Company will provide all necessary switching at remote, line end facilities for outages of Company transmission lines. The Company will provide switching instructions for the high voltage devices in the incoming substation that is directly interconnected with the Company s transmission system. Switching instructions are not provided for remote facilities interconnected to the incoming substation. A Switching Order form and a Transmission Switching Check List form are included in this document. The Customer will follow switching instructions, provided by the RTO System Controller, prior to initiating any switching to remove equipment from service or return equipment to service in the Customer s facilities. The Customer will implement specific procedures for the switching of its facilities. These procedures will include a visual check that all phases have filly opened or closed. A device bearing a Hold Tag will not be operated under any circumstances. The Customer will notify the RTO Control Area Operator immediately before a unit is synchronized.and connected to the Company s transmission system. Clearances A clearance is required for applicable work on high voltage apparatus connected to Company transmission lines when switching at remote facilities is necessary. Clearances are also issued when the Customer and Company will be working on apparatus within the same isolated area at the Customer s facilities. Each party will be issued an individual clearance. The Customer will request a clearance from the RTO System Controller when required. Personnel authorized by the Company will either trip and hold or check for trip and hold on necessary devices before a clearance will be issued. A clearance cannot be released by anyone other than the person to whom it was issued to unless uncontrollable circumstances make that impossible. In this situation, the person s supervisor may, after informing each member of the crew that such action is being taken, contact the RTO System Controller to release the clearance. For field personnel shift changes, the person to whom the clearance was issued must release the clearance. The person assuming the leadership of the work will be issued a new clearance. Grounding The Customer is responsible for assuring that protective grounds are installed on all deenergized electrical apparatus before applicable work is performed on it. When more than one party (e.g., the Customer and Company) will be working on apparatus within the same isolated area at the Customer s facilities, each party will install their own individual grounds before applicable work is performed

8 mi.w EMRGY H L ~ - P RE~L nm OPER~ no~s OUTAGE AND CLL(RANCE C~ORDlNAnON PROCEDUW DIYISIO~V NOVEMBER Work may be performed on the control circuits and mechanisms of a device without grounding the apparatus - if such work can be performed without risk of contact with primary voltages. Grounds may be temporarily removed if required by testing procedures. Before a grounding device is attached to any conductor, that conductor will first be tested to confirm that it is de-energized. Grounds will be placed where a switching device cannot remove their protection. The clamps and conductors of grounding devices will be designed for the available fault current. Grounding devices will be inspected for broken strands and loose connections. The surface of the ground clamps will be clean of corrosion and oxides. Grounding devices for transmission voltage conductors will be installed and removed with the use of applicable live line tools. Grounding devices will always be securely connected at the ground end before connection is made to the conductor. Grounds will always be removed by first detaching the connection at the conductor and, then, detaching the connection at the ground end. When grounding to a steel structure, the ground will not be applied to a flat sur!ace unless an appropriate flat surface clamp is used. Switching 345kV Buses Ferroresonance protection is installed whenever a wound potential transformer (PT) is connected to a 345kV bus. If applicable, the Customer will implement specific procedures for switching 345kV buses that have fenoresonance protection installed. Procedures will include the following. o Place the sync handle in position for the last breaker along the bus that will be opened a Monitor the bus potential lights on all three phases before and after the last breaker is opened R If one or more of the lights do not dim immediately and get brighter o Immediately close the last breaker opened to reenergize the bus o Investigate the ferroresonance protection If all three lights dim immediately.. R Reset the targets on the ferroresonance protection relays n If relay targets do not indicate proper action o Investigate the ferroresonance protection Terminology for Switching Orders The following is terminology typically used for Switching Orders. Time - Military time, or 24 hour clock, based on prevailing Central Time. Check Ring for Close - Veri@ by visual inspection that all devices in the ring are in the closed position. Block Transformers - Place automatic control of the load tap changer to the manual position. Unblock Transformers - Place automatic control of the load tap changer to the automatic position

9 RELIANT E?iERGY HL&' 0 LIIAG E AND CLEA - RUL TIME OPERA RONS DNISION COORLUNA TION PROCEDum NOVLUBER I. I999 Remove 1 Roll Loads - Remove all loads connected to a power transformer. Thls may be done by tripping applicable low side breakers or by rolling load to an adjacent transformer and tripping applicable low side breakers. 3 - Initiate and complete an opening operation on a device. Close - Initiate and complete a closing operation on a device. Hold Tag - A tag placed on a device to indicate it shall not be operated. The tag will indicate the party who placed the tag. Trip and Hold - Trip device, physically or mechanically (e.g., affix padlock) disable device from closing, and place a Hold Tag on the device. Check for Trip and Hold - Verify by visual inspection that a device is in the trip position and place a Hold Tag on the device. Secure APainst Operation (SAO) - Physically, mechanically, andor electrically disable a device (e.g., a motor 'operated disconnect switch) to prevent it from operating. Secondarv Potential Fuse (SPF1 - Remove and tag fuses on the secondary side of potential devices to prevent the possibility of back energizing isolated equipment

10 ~~~ SWITCHING ORDER # RELIANT ENERGY HLL~P - R E~L n1w OPER~TIO.VS DwsIo,v OCrrAGE AND CLMMNCE COORDINATION PROCEDUW 2VOVE,4fBER I RELIANT ENERGY HL&P SWITCHING ORDER CLEARANCE # SUBSTATION ISSUED RELEASED EQUIPMENT DISP. DISP. OUT RESTORE TIME TIME DISP DISP. DATE DATE TIME TIME ISSUED TO DATE DATE NUMBER OF MEN AND GROUNDS EXEC. BY EXEC. BY ON TIME TIME INSTRUCTIONS SWITCHING PROCEDURES DISCUSSED WITH ALL MEMBERS OF CREW: Y N CREW INITIALS 14 59

11 ~ W E Y E R G HL&P Y - REAL U.UE OPER47lO.vS DIMSlON OUTAGE AND CLEARANCE COORDINATIOIV PROCEDURES.VOVE.CtBER I, 1999 RELIANT ENERGY HL&P TRANSMISSION SWITCHING CHECK LIST The following basic procedures are for the dav of the switching; after the outage has been scheduled with and authorized by the RTO Svstem Scheduler ( ). This applies to the incoming substation that is directly interconnected with the Company s transmission system. RTO SYSTEM CONTROLLER: Q Q Call the RTO System Controller and request a Switching Order a Provide name, company affiliation, and telephone number a Provide Substation ID a Describe reason for request P Fill out Switching Order a Record the Switching Order number o Record start time provided by the RTO System Controller Q Record the RTO System Controller s name P Record the instructions to take equipment OUT a Repeat the instructions Execute the Switching Order placing Hold Tags where appropriate Call the RTO System Controller when the instructions have been completed a Report the actual completion time a Record the completion time provided by the RTO System Controller on Switching Order o Request a Clearance if necessary a Provide the number of personnel in the crew Q Provide the number of and location of grounds Verify apparatus is de-energized with a hot line indicator Install protective grounds when required Perform work Remove protective grounds if installed Call the RTO S.ystem Controller to request to RESTORE equipment Q ReporE whether more than one Hold Tag is on any device a Provide Clearance number if applicable P Provide the number of personnel in the crew clear of the apparatus a Provide the number of grounds removed a Provide the Switching Order number Q Fill out Switching Order P Record start time provided by the RTO System Controller a Record the RTO System Controller s name a Discuss performing Switching Order instructions in reverse order Alert all personnel to move to a safe distance from apparatus being energized Execute the Switching Order removing Hold Tags where appropriate Call the RTO System Controller when restoration has been completed Q Report the actual completion time a Record the completion time provided by the RTO System Controller on Switching Order 60

12 5. Undanned Outapes Unplanned Outages The Customer will contact the RTO System Controller as soon as possible whenever any unplarined tripping of _any transmission service voltage breaker occurs. Company crews will be dispatched when high voltage breakers remain open in the incoming substation. Company crews wiil reset relay targets except in emergency situations. A Forced Outage Check List form is included in this document. Company crews are not dispatched when high voltage breakers remain open in a remote, non-company substation connected to a Customer s substation but not directly interconnected with the Company s system. In such a case, the Customer will discuss and evaluate the event with the RTO System Controller. The Customer will notify the RTO System Controller prior to any switching. Unplanned Outages of 345kV Buses Ferroresonance protection is installed whenever a wound potential transformer (PT) is connected to a 345kV bus. If applicable, the Customer will implement specific procedures for unplanned tripping of 345kV buses that have fenoresonance protection installed. Procedures will include the following. a Visually inspect the bus potential lights on all three phases o If one or more of the lights are bright and not dim Open all the breaker disconnect switches along the affected bus o Remove the PTs from service on the phases with the bright lights o If one or more of the lights are dark and not dim o Open all the breaker disconnect switches along the affected bus o Remove the PTs from service on the phases with the dark lights a If remote monitoring of bus voltages indicated a ferroresonance condition occurred o Open all the breaker disconnect switches along the affected bus o Remove the PTs from service on the phases that indicated ferroresonance a If all three lights are dim o Reset the targets on the ferroresonance protection relays o If relay targets do not indicate proper action o Investigate the ferroresonance protection Emergency Switching In emergency situations, switching may be performed prior to a Company crew arriving at a Customer s incoming substation. A qualified person, authorized by the Customer, may operate breakers and switches based upon switching instructions provided by the RTO System Controller. Prior to switching, all relay trip targets will be reset after the Customer has recorded them and reported them to the RTO System Controller. All personnel will move to a safe distance from apparatus being energized prior to switching. An Emergency Switching Check List form is included in this document

13 WNT EXERGY H L ~ - P REAL n,ue OPERATIONS DIVISION OUTAGE AND C.!.L(RANCE COORDINATION PROCEDUW.VOVE.UBER 1. I999 RELIANT ENERGY HL&P UNPLANNED OUTAGE CHECK LIST The following basic procedures are for whenever any unplanned tripping of any transmission service voltage breaker occurs. RTO SYSTEM CONTROLLER HOTLINE: RTO SYSTEM CONTROLLER: o Call the RTO System Controller Hot Line a Provide the following - information to the RTO System Controller Your name, company affiliation, and telephone number Substation ID Nature of the problem Time of outage Status of all breakers and switches (Le., open, closed, tagged) Cause of the event if known Faultlocation and faulted equipment if known Fires and their proximity to energized equipment Plant and substation entry constraints (e.g., chemical releases) 0 Record the RTO System Controller's name 0 Investigate and provide the following information to the RTO System Controller a Cause of the event if found during investigation a Fault location and faulted equipment if found during investigation o Number of trip operations for each breaker (Le., change in breaker veeder reading) o Relay trip targets - Do not reset targets Discuss outage with Company crews Company crews record and reset relay trip targets Company crews record breaker veeder readings Resolve outage and complete any necessary corrective action Call the RTO System Controller to request to RESTORE equipment o Record the instructions to RESTORE equipment Repeat the instructions a Execute the instructions a Call the RTO System Controller when instructions have been completed BY: DATE: 17 62

14 The following basic procedures are for emergency situations. Contact the RTO System Controller at one of the following telephone numbers. RTO SYSTEM CONTROLLER HOTLINE: RTO SYSTEM CONTROLLER: o Call the RTO System Controller Hot Line a Provide the following information to the RTO System Controller 0 Your name, company affiliation, and telephone number 0 Substation ID 0 Nature of the problem 0 Time of outage 0 Status of all breakers and switches (Le., open, closed, tagged) 0 Cause of the event if known 0 Fault location and faulted equipment if known 0 Fires and their proximity to energized equipment 0 Plant and substation entry constraints (e.g., chemical releases) 0 Relay trip targets o Record the RTO System Controller's name Record the instructions to RESTORE equipment o Reset relay trip targets o Execute the instructions o Call the RTO System Controller when instructions have been completed BY: DATE: 18 63

15 This section applies only if the Customer operates electric generating facilities and participates in the wholesale transmission market. The Customer will follow the ERCOT Operating Guides ( or other regulatory requirements that apply to their facilities. Scheduling Power Transfers, Ancillary Services, and Outages The Customer will schedule all power transfers and ancillary services with the ERCOT IS0 Scheduler (Electric Reliability Council of Texas Independent System Operator). The ERCOT IS0 will send approved schedules to the RTO Control Area Operator for implementation. The Customer will provide proposed revisions to active power transfer and ancillary services schedules to the ERCOT ISO. The ERCOT IS0 will send approved changes to the RTO Control Area Operator for implementation. Generation Schedule Imbalance (GSI) will occur if active schedules do not match actual generation. Unit Verification Tests The Customer will perform the ERCOT IC1 Real Power Capability Verification test during each ERCOT season that energy is provided for more than 168 hours. The ERCOT Winter season months are December, January, and February. The ERCOT Spring season months are March, April, and May. The ERCOT Summer season months are June, July, and August. The ERCOT Fall season months are September, October, and November. The Customer will perform the ERCOT IC2 Unit Reactive Limits Verification test at least once per year on each unit. The Customer will provide the test results to the RTO Control Area Coordinator ( ) who will submit them to the ERCOT ISO. The RTO Control Area Coordinator will provide additional testing information upon request. Unit Operation The Customer will have generation control personnel on duty at all times generating units are on-line. The Customer will maintain an operations log including real and reactive power production, operating status changes, scheduled and forced outages, unusual events, and unusual conditions found during inspections. The Customer s operations log will be provided to the ERCOT IS0 and the Company upon request. The Customer will notify the RTO Control Area Operator immediately before a unit is synchronized and connected to the Company s transmission system. The Customer will notify. as soon as practical, the RTO Control Area Operator of any potential unit problems, internal load changes, and any unusual operating events. The Customer will report forced unit outages providing the amount of generation lost and the expected duration of the outage. The RTO Control Area Operator can be contacted through the Customer s automatic ring down telephone or at , twenty-four hours a day, seven days a week

16 RELLkVT LVERGY HL&P - RL4L TI.rrE OPER~~O,VS DIVISION OUTAGE AND CLhiRANCE COORD1,VA non PREED(/W.VOVEMBER 1, 1999 The Customer will operate units to support the transmission system voltage by regulating reactive power output up to levels demonstrated in the ERCOT 1C2 test. The Customer will maintain the Company specified voltage level unless otherwise directed by the RTO Control &ea Operator. If the Company specifies a maximum voltage in addition to the recommended level, the Customer will maintain the maximum voltage only during light system load conditions. If the Company does not specify a voltage level, the Customer will provide reactive support based on instructions provided by the RTO Control Area Operator. The Customer s voltage regulators and speed governors Will be h service whenever generating units are on-line. The Customer will immediately notify the RTO Control Area Operator whenever a voltage regulator or speed governor is taken out of service or placed back in service. The Customer will maintain settings as close as practical to five percent speed regulation. The Customer will maintain generating units on-line during system under-frequency conditions except that units may be tripped manually at 58.3 Hertz, by instantaneous relaying at 58.3 Hertz, or by 0.5 second time delay relaying at 58.4 Hertz

17 This section applies only if the Customer operates electric generating facilities and provides firm or non-firm energy to the Company. The Customer will follow the ERCOT Operating Guides ( or other regulatory requirements that apply to their facilities. Scheduling The Customer, if a Cogenerator selling NEP or FEP energy to Company, will fax weekly or twenty-four hour generation schedules to the RTO Control Area Operator from one day to one month before the effective date. All schedules must be received by at least 1:00 P.M. of the day before the effective date. The RTO Control Area Operator (Fax , ) can be contacted twenty-four hours a day, seven days a week. For long range generation scheduling, the Customer will schedule planned outages with the RTO Control Area Coordinator from one month to eighteen months before a planned outage. An eighteen-month outage schedule should be provided. The RTO Control Area Coordinator can be contacted at from 7:OO A.M. to 3:30 P.M. on HL&P business days. Unit Operation The Customer will have generation control personnel on duty at all times generating units are on-line. The Customer will maintain an operations log including real and reactive power production, operating status changes, scheduled and forced outages, unusual events, and unusual conditions found during inspections. The Customer s operations log will be provided to the Company upon request. The Customer will notify the RTO Control Area Operator immediately before a unit is synchronized and connected to the Company s transmission system. The Customer will notify. as soon as practical, the RTO Control Area Operator of any potential unit problems, internal load changes, and any unusual operating events. The Customer will report forced unit outages providing the amount of generation lost and the expected duration of the outage. The RTO Control Area Operator can be contacted through the Customer s automatic ring down telephone or at , twenty-four hours a day, seven days a week. The Customer will maintain the Company specified voltage level unless otherwise directed by the RTO Control Area Operator. If the Company specifies a maximum voltage in addition to the recommended level, the Customer will maintain the maximum voltage only during light system load conditions. If the Company does not specify a voltage level, the Customer will provide reactive support based on instructions provided by the RTO Control Area Operator. The Customer s voltage regulators and speed governors will be in service uhenelw generating units are on-line. The Customer will immediately notify the RTO Control Area Operator whenever a voltage regulator or speed governor is taken out of service or placed back in senice. The Customer will maintain settings as close as practical to five percent speed regulation

18 RELI.4V E.VERGY HLdP - R UL rr.w OPERI ~ 10~s ~1~1x10,~ OflAGE AND CLE.4RANCE COORDINA~~N ~ROCEDC;RES ivove.uber The Customer will maintain generating units on-line during system under-frequency conditions except that units may be tripped manually at 58.3 Hertz, by instantaneous relaying at 58.3 Hertz, or by 0.5 second time delay relaying at 58.4 Hertz

19 8. Protective Relay Settinm The Company will issue all settings for relays installed for the protection and automatic reclosing of Company transmission lines and for relays installed to prevent back-energizing Company s system from generation installed on the low side of customer power transformers. On a case-by-case basis, the Company may issue settings for other Customer relays. The relay settings issued by the Company for the Customer s facility will be provided to the Customer upon request. The Customer will provide the Company with applicable relay settings issued by the Customer that trip or close any Customer transmission service voltage breakers. The Customer will notify the ILCA Power Consultant of any proposed settings changes for such relays for the Company s review

20 The Customer will notify the ILCA Power Consultant when equipment additions are planned or when high voltage equipment or associated equipment requires modification or replacement. The Customer will provide equipment and installation per applicable Company specifications and bill of materials. The Customer will provide necessary details (e.g., drawings, specifications, and manufacturer type and catalog number) fop. the Company s review. All Company comments will be incorporated or resolved before any equipment or materials are procured or any work is begun. The Customer modifies, repairs, or replaces all customer owned equipment except for metering current transformers, Supervisory Control and Data Acquisition (SCADA) equipment, and transmission line protective relaying equipment. On a case-by-case basis, the Customer and the Company will develop the responsibilities for the modification, repair, and replacement of this equipment. The Company will endeavor to notify the Customer of problems in their facilities that the Company becomes aware of. The Customer will provide any needed equipment modifications, repairs, or replacement within an appropriate time frame. The Customer will replace equipment that the Company demonstrates is no longer maintainable. Industry experience may dictate that certain equipment requires modification, repair, or replacement due to manufacturing defects or unacceptable failure rates and consequences. The Customer will modify, repair, or replace equipment based on manufacturer issued product service advisories and Company issued advisories within an appropriate time frame

21 10. Equipment Maintenance Company Maintenance The Company will perform periodic testing of certain Customer,equipment if the equipment is installed for the protection of Company transmission lines. This includes power line carrier tuning and testing of wave traps, tuners, and carrier sets and calibration and testing of relays and fiber optic communication equipment. The Company will perform periodic calibration and testing of SCADA (Supervisory Control and Data Acquisition) transducers that provide real time data to the Company. The Company may designate additional Customer equipment for maintenance by the Company. The Company will label equipment maintained by the Company. The Company will endeavor to coordinate Company maintenance with the Customer's maintenance outages. Company transmission line outages are required for the Company to perform testing of applicable wave traps. Outages of approximately ten hours for certain Customer facilities are required for the Company's periodic maintenance of any Company high voltage metering instrument transformers. For substations with a single power transformer and certain tap substations, a total separation from the Company's system is required. Transformer outages are required for metering instrument transformers installed on the high side of transformers. Customer Maintenance The Customer will perform periodic inspections and preventive maintenance on all structures and equipment owned by the Customer except for equipment designated by the Company for maintenance by the Company. The Customer will not perform preventive maintenance on the equipment maintained by the Company. The Customer will maintain equipment logs and test reports, which will be provided to the Company upon request. Depending upon ownership, equipment maintained by the Customer may include the following: line surge arresters, potential and current transformers not owned by the Company. coupling capacitors, coupling capacitor potential devices, switches (including auxiliary contacts and motors if installed), breakers (bushings, mechanism. tanks), transformers (bushings, surge arresters. main tank, load tap changer, alarms), relays not tested by the Company, and DC Battery system equipment. The Customer will notify the RTO System Scheduler, preferably one week but at least two Company business days in advance, before performing maintenance on potential or current transformers connected to Company revenue meters. Monthlv InsDections The Customer will perform monthly inspections to include the following as applicable. Visual inspection of outdoor equipment including inside control cabinets Verify oil levels Verify transformer nitrogen blanket pressure Verify transformer fan operation Verify breaker compressor or hydraulic pump operation Drain condensate from breaker mechanism air tanks Verify operation of control house heating and air conditioning 25 70

22 Ouarterly, Semi-annual Testing and InsDection Company recommends Total Combustible Gas (TCG) testing once every three months on transformers equipped with a nitrogen blanket. Infrared thermography of high voltage equipment is recommended once every six months. DC Batterv System The Customer will perform periodic DC battery system equipment inspections and maintenance to include the following as applicable. o Every Month o Visually inspect batteries (corroded connections, leaks, cracked cases) Visually inspect chargers o Verify and correct water levels o Record and verify float voltage o Record and verify ground reference voltage o Every Six Months Clean battery surfaces Check charger ventilation Record and verify cell voltages Perform cell impedance testing Measure connection resistance Record and verify specific gravity reading on a single pilot cell Verify float and equalize voltage settings Verify proper operation of chargers and alarms Verify proper operation of high voltage shutdown circuits Functional Testing The Customer andor Company will perform functional trip testing following substation additions or modifications. Each high voltage breaker will be tripped and closed from the breaker control switch at least once every year. This breaker tripping, as well as functional trip testing. may be coordinated with the switching required for maintenance outages. The Customer will no ti^ the RTO System Scheduler, preferably one week but at least two Company business days in advance. before performing functional testing and allow the Company to witness the testing. High voltage circuit breakers equipped with dual trip coils that use a common actuating shaft (e.g., Allis Chalmers, Westinghouse) require special functional testing. The Customer will perform a test on each breaker by applying trip voltage simultaneously to both trip coils. If the breaker does not immediately trip, the voltage must be quickly removed to avoid damaging the coils. After verifying the wiring, the Customer will appropriately label the control wiring. The Customer's maintenance procedures will include tagging and properly reconnecting trip coil wiring. The Customer will perform this test whenever a trip coil is replaced or breaker control wiring is modified

23 Industry experience may dictate that certain equipment requires special inspection and testing due to manufacturing defects or unacceptable failure rates and consequences. The Customer will perform special inspection and testing based on manufacturer issued product service advisories and Company issued advisories. Breaker Maintenance Precautions As certain protective relaying schemes utilize breaker auxiliary contacts, the Customer will implement specific procedures for breaker maintenance. The following protection schemes require special procedures, which include opening and tagging or jumpering and tagging control circuitry. o Breaker failure schemes for high voltage generator breakers utilize a breaker auxiliary 'a' contact to determine whether the breaker has opened. Fenoresonance protection schemes for 345kV buses utilize breaker auxiliary 'b' contacts to initiate the protection when all breakers along the bus open

24 11. Plant Desiyn Considerations /ELI.i.CTE'.\.ERGk HLdiP - R LiL TI.\lEOP&RiTIOVS Dll'lSIOV 007.-iG& AdVD CLE.IR4.VCE COORDI.V.4 TIOgV PROCEDL'MS.VOI'E.IfR&R I, f 999 Emergency Systems Continuous electric service from utility power systems cannot be guaranteed even for facilities that are connected to a large number of transmission lines. The probability that a total power outage or separation from the utility system may occur depends upon many factors. It is important to consider this when plant emergency systems are designed. Automatic Reclosing The Company utilizes automatic reclosing of high voltage circuit breakers following unplanned tripping of Company transmission lines. The Company endeavors to intentionally delay the initial reclose attempt by at least one second. The Customer is responsible for the separation of necessary motors or equipment within one second of the tripping. System Voltage Sags Electric service from a utility power system cannot be guaranteed against fluctuations. A common fluctuation is a voltage sag that occurs during the time of a fault. The large majority of faults on a utility transmission system are single line-to-ground faults. With automatic reclosing of circuit breakers, several voltage sags can occur within about a one-minute period. Most voltage sags from faults on transmission systems have a very short duration of less than ten cycles with high-speed fault clearing. Equipment, such as motor contactors, adjustable speed drives, programmable logic controllers, and high intensity discharge lamps, can be sensitive to these short duration voltage sags. It is important to consider voltage sag "ride-through" for equipment applied to critical processes where nuisance tripping can cause a whole process to shut down. Plant power systems and equipment control systems can be designed or modified to ride-through the most common voltage sags on utility power systems. The Company will provide additional information upon request. Electrical Protection Coordination Studies Customers typically perform plant electrical protection coordination studies from time to time. The Customer may contact an ILCA Power Consultant to request the available Company system fault current and system impedance at the Customer's facility. Substation Design The Customer can contact an ILCA Power Consultant to request current Company specifications and applicable bills of material for new substations and substation equipment additions and replacement. I HANDBOOK1 0-99GEN.doc I 28 73

25 RELIANT ENERGY HL&P TELEPHONE NUMBERS Real Time ODerations Division (RTO) RTO HOTLINE RTO System Controller (24 hours a day) (24 hours a day) RTO System Coordinator RTO System Scheduler (FAX) RTO Control Area Coordinator RTO Control Area Controller (24 hours a day) (FAX) Industrial & Large Commercial Accounts Division (ILCA) ILCA Power Consultant ILCA Power Consultant (24 hours a day) Other Telephone Numbers 74

26 Exhibit G Generator Interconnection Specification 75

27 SPECIFICATION FOR COGENERATOR CONNECTED TO THE HL&P TRANWISSION SYSTEW HOUSTON LIGHTING &POWER COMPANY SYSTEM ENGINEERING DEPARTMENT P.O. BOX 1700 HOUSTON, TEXAS REFERENCE DRAWINGS: R EF ER EN C E SPEC1 FI CAT1 0 N S: HL&P Specification , Latest Revision HL&P Specification , Dated 2/15/86 HL&P Specification , Dated 4/15/85 I HOUSTON LIGHTING a POWER CO. HOUSTON. TEXAS l 1 3fiqhh Completely Rewritten PR (A0 $g sntm 1 OF 17 snms NO DATE KEYS RMSED BY CW ACP I 007 I 231 I 78, 76

28 ITEM NO C O N T E N T S - TITLE SCOPE INTERCONNECTION CRITERIA GENERATING UNIT GENE RAT I 0 N STE P -UP TRANS FORME R PROTECTIVE RELAYING SCADA AND TELEMETRY SYSTEM LETTER OF CERTIFICATION TURBINE GENERATOR DATA GENERATOR CONSTANTS FOR TRANSIENT STABILITY STUDIES GENERATION STEP-UP TRANSFORMER DATA DATA SPEED GOVERNOR EXCITER DATA PAGE NO REVISION NO. I l l I SPECIFICATION SHEET 2 OF 17 SHERS I

29 ~ 1.0 SCOPE 1.1 This specification covers technical requirements for a cogenerator interconnecting to the Houston Lighting and Power Company (HLLP) transmission sys tem. 1.2 Each cogenerator will have its own design parameters that may necessitate some deviation from these requirements. However, a1 1 exceptions must be approved by HLbP. 1.3 Because this specification is limited to technical requirements for cogenerator interconnection, the cogenerator may be required to enter separate contractual arrangements (including, without limitation, an Interconnection Study Agreement, Interconnection Construction Agreement, Agreement, and Agreement for Purchase of Energy and/or ~!~~~~~~~ with HL&P prior to interconnection. These agreements may detai 1 procedures, guide1 ines, and requirements for cogenerator interconnection besides the technical specifications provided by this document INTERCONNECTION CRITERIA I 2.1 Cogenerator shall provide certain information to HL&P so that HL&P can 1 determine if an Interconnection Study is necessary. This information includes, without limitation, the proposed location of the cogenerator facility, the gross and net generation capability of the new facility, and an approximate date that interconnection is desired. I 2.2 If an Interconnection Study is required, it shall be conducted in accordance with an Interconnection Study Agreement between HL&P and the cogenerator. HL&P shall determine the transmission voltage and number of transmission lines required for the cogenerator substation. HL&P shall also estimate the cost and lead time for interconnection. Subsequent interconnection studies may be required if there are changes in projected cogenerator or HL&P transmission system parameters. 2.3 HL&P will plan transmission system improvements or additions to interconnect the cogenerator to the HL&P grid HL&P will design the interconnection to be consistent with HLLP and El ectri c Re1 i abi 1 i ty Counci 1 of Texas (ERCOT) re1 i abi 1 i ty gui del ines For all cogenerators with a combined generation output in excess of 100 MW, HL&P will design the transmission interconnection so that all cogenerator output will be delivered into the system for any two transmission line or substation component outages For all cogenerators with an output of less than 100 Hw, the minimum acceptable design will be a two transmission line, three breaker ring bus. SPECIFICATION REVISION NO. I 1. l - l l l - l 78

30 2.3.4 HL&P will further design the transmission system for improvements that may be required to avoid overloading any single transmission line above 100% of the line's normal continuous current rating in the event of any other single component outage. In addition, all substation voltages will be no less than 0.95 per unit nor greater than 1.05 per unit for any single contingency HL&P is required, as a member of ERCOT, to provide a reliable transmission grid that will not cause cascading outages following the events listed below. a. Loss of all generating capacity at any generating station. b. Loss of any two generating units. c. Outage of any single or double circuit transmission line, generating unit, transformer, or bus d. Outage of any circuit or generating unit during scheduled maintenance on any other transmission line or generating unit. e. Simultaneous outage of overhead transmission 1 ines para1 le1 to each other for a substantial distance having a spacing between circuits of less than the height of the structures, f. Any fault cleared by normal operation of back-up relays, g. Loss of any large load or concentrated load area. HL&P will include in its analysis various load levels as well effect of firm contractual interchange transactions. as the 2.4 If HL&P's interconnection plan requires the cogenerator to connect to the 138kV system, the interconnecting substation will comply with HL&P Specification enti tied "Customer Owned 138kV Substation Design." The cogenerator shall be required to sign an Operating Agreement prior to interconnecting on the HL&P transmission system. The Operating Agreement will specify procedures for switching, maintenance, and what to do in the event of an abnormal occurrence as well as procedures for bringing generators on or off line Ownership, maintenance, operation, and control of equipment shall be detailed after design is finalized and shall be consistent with the Operating Agreement, HLLP Specification , and HLLP Specification Cogenerator shall incorporate into his design provisions for having a control room manned by a qualified operator 24 hours a day and for providing hourly readings of megawatt hour production at the generator terminals so that the cogenerator can comply with the terms of the Operating Agreement. REVlSlOW NO. 1 I I SPECIFICATION SHEET 4 of 17 SHEETS I

31 2.5 If HW's interconnection plan requires the cogenerator to connect to the 345kV system, the interconnecting substation shall comply with HL&P Specification entitled "345kV Qual ified/customer Faci 1 ity" The cogenerator shall be required to sign an Operating Agreement prior to interconnecting on the HL&P transmission system. The Operating Agreement will specify procedures for switching, maintenance, and what to do in the event of an abnormal occurrence as well as procedures for bringing generators on or off line Ownership, maintenance, operation, and control of equipment shall be detailed after design is finalized and shall be consistent with the Operating Agreement, HLbP Specification , and HLLP Specification Cogenerator shall incorporate into his design provisions for having a control room manned by a qualified operator 24 hours a day and for providing hourly readings of megawatt hour production at the generator terminals so that the cogenerator can comply with the terms of the Operating Agreement, 3.0 GENERATING UNIT 3.1 The cogenerator shall submit specific information regarding the electrical characteristics of each generating machine during the initial planning stages of the project The required forms are contained in sheets 8 through 17 of this specification. This information is necessary in order to establish an interconnection plan that will be consistent with HL&P loading and stability criteria HLbP will furnish typical generator data for planning purposes, i f requested. 3.2 The generator excitation system response ratio shall not be less than 0.5 (f i ve-tenths). 3.3 The generator shall have a short circuit ratio of not less than 0.5 (five-tenths). 3.4 In order to regulate a high side voltage consistent with HL&P voltage profile needs, the generator and step up transformer shall maintain an HL&P specified high side bus voltage up to a power factor of 0.89 lagging or the generating unit's leading power factor capability, as appropriate HLAP will periodically specify a voltage level that the cogenerator shall monitor and maintain subject to the above criteria. If the specified voltage cannot be met, the cogenerator may be required to contribute to the purchase of other reactive sources. specified and installed by HL&P or limit their generation output. REVlSlOH NO I I 1 -~ ~ SPECIFICATION,SHEET OF l7 SHEETS

32 3.5 The maximum allowable deviation factor of the open circuit terminal voltage wave shall not exceed 0.1 (one-tenth). 3.6 The balanced Telephone Influence Factor (TIF) shall not exceed 30 (thirty). The residual TIF shall not exceed 30 (thirty), 3.7 The generator shall be capable of withstanding, without damage, the 1 effects of a continuous current unbalance corresponding to a negative phase sequence current of lo%, providing rated kva is not exceeded, and the maximum current does not exceed 105% of rated current in any phase. 4.0 GENERATION STEP-UP TRANSFORMER 4.1 The low side voltage rating of the generation step-up transformer shall be rated generator voltage. 4.2 The high side voltage rating of the generation step-up transformer shall be either 138kV or 345kV as appropriate, with three taps above 138kV or 345kV at 2 1/22 increments and one tap 2 1/2% below 138kV or 345kV. Each tap shall be able to handle the full MVA rating of the transformer. 4.3 The impedance shall be 7-8% (7% preferred) on the generator base. 4.4 The generation step-up transformer shall be rated to deliver to the transmission system (as a minimum) the rated MVA output of the generator less any auxiliary load. 4.5 The high side connection of the generation step-up transformer shall be wye grounded. 5.0 PROTECTIVE RELAYING 5.1 Protective relaying for the substation shall be in accordance with HL&P Specification for 138kV substations and HL&P Specification for 345kV substations. 5.2 The cogenerator machine characteristics and plant design shall incorporate the under-frequency guidelines and criteria of the Electric Reliability Council of Texas (ERCOT) system. These guidelines state that all generators shall remain on line until all three load shedding blocks have been executed. The blocks are automatically tripped by under-frequency relays at 59.3 Hz, 58.9 Hz, and 58.5 Hz. Therefore, the cogenerator shall not separate from the HLLP system during under-frequency. conditions until the frequency has declined to a level below 58.5 Hz. Options acceptable to HLbP include: manual trip at 58.3 Hz, relay trip at 58.4 Hz with a.5 second time delay, or 58.3 Hz with no time delay. 5.3 The loss-of-excitation relaying shall have sufficient time delay to prevent false tripping for stable transient impedance swings. REVISION NO. I l l I I I 1 1 SPECIFICATION

33 j.0 SCAOA AND TELEMETRY SYSTEM 6.1 Supervisory Control and Data Acquisition (SCADA) system and an analog tone telemetry system shall be in accordance with HL&P Specification for 138kV or 345kV substations. 7.0 LETTER OF CERTIFICATION 7.1 A letter of certification stating compliance with this specification shall be submitted to HLLP before the substation is energized. SPECIFICATION REVISION NO, 1 1 swn 7 OF 17 SHEETS

34 STATION AND UNIT # TURBINE - GENERATOR DATA MANUFACTURER P.O. # YEAR INSTALLED - - TURBINE NO. TYPE: STEAM REHEAT NON REHEAT COMBUSTION TURBINE - RATED TURBINE KW GAS OIL RATED PSIG RATED GENERATOR KV RATED GENERATOR MVA COAL NUCLEAR SPEED RATED POWER FACTOR NET MW CAPABILITY F SHORT CIRCUIT RATIO FULL-LOAD FIELD RATED P.F. FIELD RESISTANCE (OHMS) TEMP COEFFICIENT Rated Output & Power Factor Less Auxiliaries) UNIT WR' (Lbs-Ft') (Combined Turbi ne- Generator) H CONSTANT (Combined Turbine- Genera tor) VOLTAGE REGULATOR TYPE EXCITER TYPE KW RATING SPECIFICATION REVISION NO. 1 SHEET 9 OF 17 SHEETS A,

35 TURBINE - GENERATOR DATA VOLTAGE RESPONSE RATIO % SPEED REGULATION SATURATION CURVE NO. VEE CURVE NO. CAPABILITY CURVE NO. EXPECTED TURBINE KW OUTPUT VS. AMBIENT AIR TEMPERATURE CURVE NO. (Supply 1 COPY) (Supply 1 COPY) (SUPP1Y 1 COPY) (Supply 1 COPY) 84

36 GENERATOR CONSTANTS FOR TRANSIENT STABILITY STUDIES STATION AND UNIT REACTANCES:, percent, based on rated MVA, KV SYNCHRONOUS (Xd) SYNCHRONOUS (Xq) TRANSIENT (X'di), (at rated current) (unsat) TRANSIENT (X'dv), (at rated voltage) (sat) TRANSIENT (Xlqi) TRANSIENT (X'qv) SUB-TRANSIENT (X"di ) SUB-TRANSI ENT (X"dv ) SUB-TRANSIENT (Xl'qi) SUB-TRANSIENT (X"qV) NEGATIVE-PHASE-SEQUENCE (X2), (at rated voltage) ZERO-PHASE-SEQUENCE (Xo), (at rated voltage) LEAKAGE REACTANCE (X ), (at rated voltage) POTIER REACTANCE (Xp) ARMATURE RESISTANCE, OHMS PER PHASE TIME CONSTANTS : Seconds Open Circuit (T'do) Open Circuit (T'qo) Open Circuit (T"do) Open Circuit (T'lqo) I SPECIFYCATION REVISION NO. I ISHEW, lo YF l7 ;HEETS I I I I 85

37 GENERATOR CONSTANTS FOR TRANSIENT STABILITY STUDIES STATION AND UNIT SATURATION FACTORS : S1.0 (@ Rated Terminal Volts) S1.2 (@ 120% of Rated Terminal Vo SPEClFtCATlON REVISION NO. I SHEET 11 OF 17 SHEETS I

38 GENERATION STEP-UP TRANSFORMER DATA STATION AND UNIT # YEAR INSTALLED MANUFACTURER P.O.# RATED KVA H WINDING X WINDING Y WINDING TYPE PHASE 55 C Rise 65 C Rise H WINDING VOLTAGES AND BIL (INCLUDE ALL TAPS) X Y WINDING VOLTAGES AND BIL WINDING VOLTAGES AND BIL % EXCITING CURRENT AT 100% RATED VOLTAGE CYCLES IMPEDANCE % ON MVA BASE WINDING RESISTANCE H X Y CURRENT TRANSFORMERS H Winding X Winding Y Winding Neu tra I REVISION NO. 1 1 I 1 I SPECIFICATION SHEET 12 OF 17 SHEETS I 231) 78 87

39 GENERATION STEP-UP TRANSFORMER DATA PRESENT TAP SETTING: H Winding X Winding Y Winding SPEC1 FICAtlON REVISON NO. 1 I SHE^ 13 OF 17 SHEETS I 007 I

40 DATA SPEED GOVERNOR Provide the data constants required for your speed governor and steam turbine systems based on the above generalized block diagram. If your machine cannot be represented by the above block diagram. include a block diagram and the necessary data constants. SPEED GOVERNOR CONSTANTS K T1 T2 STEAM TURBINE CONSTANTS T4 T5 T6 T3 T, I "0 uc K1 KZ - REVISION NO. 111 I SPECIFICATION SMER 14 OF 17 SHEETS I 007 I

41 ~ - Note: If your governor has the fast K5 valving feature, necessary data. provide the Kg K7 SPECIFICATION REVISON NO. 1 90

42 EXCITER DATA IEEE EXCITER TYPE* DATA CONSTANTS KI KP '0.75MAX TF 1 REVISION NO. 1 SPECIFICATION SHEET, l6 CiF /.HEl36I 1 I I 91

43 IEEE EXCITER TYPE* DATA CONSTANTS "EMAX 'EMAX *Fill in column of applicable data constants to your machi ne. for the IEEE Exciter type correspondin! I SPECIFICATION REVISION NO. 1 1 I 1 I I

44 Exhibit H Telemetry Specification 93

45 G i.,.*. ' '. 4 SPECIFICATION FOR RMOTE TELRiETRY OF A WSTOHER QWNED FACILITY HOUSTON UGfillNG & POWER COMPANY SYSTEM ENGINEERING DEPARTMENT P.O. BOX1700 HOUSTON,TD(ASf1251 REFERENCE DRAWINGS: REFERENCE SPEC1FiCAnONS: ANSI/IEEE C ANSIIIEEE C (R1987) ANSI/NFPA REA Speci f i cati on PE-39 HLhP Specification , Rev. 11/23/88 HLhP Specfficatfon , Rev. 3/1/83 HLhP Specfficatjon , latest Revision 94

46 ITEX NO SCOPE GENERAL TITLE ScmA SYSTEX DESIGN, LAYOUT, AND PEYSIW CRITERIA COXKUNICATION LINE CALIBRATION AND HAINTE = CDRRENT TRANSFQ~ AND POTENTIAL TRANSFORHERS DRAWING APPROW LIST OF ABBRFVSATIONS USED IN FIGURE 1 FIGURC 1 FIGURC 2 PAGE NO

47 1 SCOPE 1.1 Thie epecification defines the requirements for the engineering, installation, calibration, and maintenance of remote telemetry at Customer owned facilities connected to the Houston Lighting and Power canpany {&&P) transmission system. 2 GENERAL Remote telemetry in custotner-owned facilities is requked or (1) all new transmission substations, (2) existing transmianion substations which are undertaking significant rearrangement or expand.on of thek existing electrical facilities, or (3) existfmg transmission substations which XL&P considers critical to system reliability. All equipent and work covered by this specification shall be designed, constructed, and tested Fn accordance with the latest revisions or editions in effect at the time of fabrication; of the applicable codes, standards, specifications, regulations, testa, and procedures of all federal, state and local laws, and including (but not limited to) the following: 1) American National Standards Institute (ANSI) 2) National Electrical Manufacturers Association ("A) 3) Occupational Safety and Health Administration (OSEA) 4) Federal Communications Commission (FCC) In the event of conflicting requirements, the order of precedence shall be the applicable.federal, state, and local laws and regulations, this specification, and other referenced 5&;P specif lcatiolls. HL&p provides the Supervisory Control And Data Acquisition (SCADA) equipment itaelf while the Customer must provide interface equipment consisting of items such as transducere, etatua and alarm contacts, cabling, terminal blocks, conduit, and communication e'quipment. All equipment shall be furnished and installed by the Customer unless otherwise noted in this specification or agreed to by sepaxate agreements. Equipment specified may be substituted with written approval from the HL&P Electrical System Engineering Division. All SCADA equipent shall be readily accessjble to HL&P persormel. 3 SCADA SYSTEM, 3.1 The SCADA system is composed of three subsystems: (I) analog, (2) status, and (3) control. 3.2 Analog subsystem: The analog subsystem consists of various Customer-supplied transducers which report electrical data to the SCADA set. HL&P will determine the transducer electrical requirements. The Customer shall provide an electrical one-line diagram of the existing or proposed Customer-owned substation Single phase watt monitoring and single phase var. monitoring are required for each wwer flow into or out of the substation busses. These include (1) 5 &P transmission line power flows and (2) loads or auxiliaries connected to REYISION NO. I I %En 3 OF 10 SHEETS 96

48 the substation busses. See Table 1 for acceptable transducer models SLngle phase bus voltage InOdtOring is repuked for each substation transmission bus equipped with a Potential Transformer (PT). see Table 1 for an acceptable voltage tramducer models Electrical Systems Engheerbg will determine the voltage monitoring requirements for single tap (=uetuaer~& substations Xeter test switches are requlred for each transducer's current and voltage connection. Single phase test switches are specified in Table 1. TABLE _ ~ _ 1 ~ ACCEPTABLE RNALM? TRANSDUCER AND TEST SWITCE MODELS I1 I I 1 I rl Hodel No. Quantity Description Comment L JEHTEC XLWVSCSAQ One per power Watt/Var Transducer XLVSCSA4 mer fluw Transducers JENTEC VTllOA4 One per Voltage substation bus Transducer,superior 748-F One each per Shgle Phase (two-pole 1 Transducer Test switch Alternate to il r 3.3 Status Subsystem: The status subsystem of the S O A aystem shall consist af the following Status of transmission voltage breakers OE other devices directly affecting the EL&P electrical system as determined by KL&P ahall be required. Status shall be derived feom either an isolated auxiliasy 'a" contact'or monitoring primary trip coil at EIL&P's option. Refer to Fi.g.1 for Breaker Status Connections Indication of low voltage and battery charger. failure is required for the 130 VDC battery systea(s). For new installations, a chaxger that hae low voltage, high voltage, loss of AC input, and loss of charger output indications shall be provided. A single alarm shall be generated by connecting in parallel the normally open contacts for these indications. For exfatlag installations a charging system monitor ( F Squared Industries, Hdel CSM2-130, HVA) shall be provided SCADA Close Inhibit (SCI) indication is required of breakers whenever a lockout relay can inhibit breaker closure. A dry, normally open, contact from that relay shall be supplied for SCI indication. Indication contacts from all lockout relays shall be wired in parallel for a single indication to the SCADA Cabinet. 97

49 3.4 Control subsystem: The control subsystem of the SCADA sy8t+?nl shall consist of the following: All 69Kv, 138KV, or 34SKV circuit breakers that direely affect the HL&P transmission system a8 determined by HL&P requke r-te control by EIL&P. Should BL&P require the control of any additional breakers, these items will be indicated by HLkp on an electrical one-line diagram ~ual remote control (control of a breaker by both the Customerr's and BL&P'S control Center) f0 not mtted Cbcuit breaker control shall be through the control subsystem of the SCADA system. Figure 1 illustrates how SCADA control will interface with a typical breaker control scheme.. 4 DESIGN, LAYOUT, AM) PHYSICAL QSTERIA 4.1 SCADA Set Designation: The type of SCADA set installed by of breakers controlled. will depend on the number A free-standing cabinet will require an area of dimensions 36" wide by 36" deep and 90' tall. Each cabhet shall have front and rear access. Clearance of 40" in front of both doors shall be reserved for maintenance access. Substations with more than ten breaker control points will require two cabinets. Connections by the Customer: EiLW shall provide an Intertie cabinet to house the SCADA set(s). The Custaner shall install all interconnections between the SCADA set and the substation control house in this cabinet in accordance with drawings supplied by W The Customer shall provide a 120 VAC fifteen (15) amp dedicated AC parer circuit, protected by a fifteen (15) amp circuit breaker, mounted on a sepaxate sliding-link terminated on the Intertie Cabinet The Customer shall provide a 130 VDC fifteen (15) amp dedicated DC parer circuit, protected by a fifteen amp circuit breaker, mounted on a sliding-link terminal block All cable shields shall be grounded at a location other than the SCADA Intertie Cabinet. Cable shields shall be grounded at one end only. Cabling: The Customer shall size and install all conduit or cable troughs in accordance with ANSIINFPA 70 (National Electrical Code) Polyethylene Polyvhylchlotide (PEWC) inaulated shielded 2/C f16 cable with stranded copper conductors shall be used for terminations for all transducer outputs Breaker controls shall use ei.ght conductor (f12) PEWC insulated cable with stranded copper conductors for these terminations. The color code shall conform to Figure 1. L

50 m Tu0 conductor (#lo or latger) PEPVC insulated cable with stranded copper conductors shall be used for terminations of the AC and DC power circuit Status and alarms shall be terminated with two conductor (f16) PEPVC insulated Cable with stranded copper conductors The Customer shall install the necessary conduit or cable trough between the Intertie Cabinet and the relay panels. 4.4 Every breaker with 130 W C control circuits shall have breaker coil eurge suppression. A one hundred (100) ohm, eleven (11) watt resistor (Ohmite style A) and a zener diode (Xotorolatype ln305l.a) shall be used for this suppression. The series comb3nation of the zener diode and the resistor shall be parallel to each breaker trip and breaker close coil. States company slider-link terminal blocks shall be installed in the breakers for terminating the resistors and zener diodes. BL&P will verify breaker coil surge suppression. 5 COKKUNICATION LINE 5.1 BL&P will order and pay for the communication line(8) from the telephone company. The customer ehall supply the name and telephone number of a representative for purposes of coordination of installation of these 1he( 8). The communication lbe(s) will be in HL&P's name The Customer shall provide two dedicated 12-pair cables for ccnnsunications circuits between the SCADA Intertie Cabinet and an appropriate telephone company demarcation point. The cables shall have the following specifications: a. Grease filled b. Shielded, twisted pair cable c AWC solid copper d. REA Specification PE-39 e. gas tube lightning protection The Customer ahall provide a conduit between the communication circuit and the SCADA RT[I Cabinet. The conduit shall be sized for two shielded 122 audio cablee (3/4" or 1"). Pull lines shall be left in the conduit RL&P, at its option, may use S W A Radio (952/928 HHz FM) for the SCADA cornmunication circuit. The requirements of the radio, antenna, and associated equipent will be determined by KLCP. The Customer shall provide a location for this equipnent. The Customer shall provide a full buainess (1FB) phone line inside the relay control house. This phone shall have a cord extendable to the Intertie cabinet. This phone is an outside phone line independent from Customer phone system. The Customer shall provide uninterruptible per for SCADA telephone coaununication ckcuit(6). This pwer source shall be capable of eight hours of operation in the event of an electrical outage. RMYOH NO. I