File Name: \\oktulsafp002\tplan\Grpdate\NERC\AEP West Intrcnt_guidelines ver_ 10-8-2007.pdf CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to The AEP West Transmission System October 8, 2007 Note: This document has been prepared by, and is the property of, American Electric Power Company, Inc. This document may be changed by AEP. Users should consult the OASIS site at http://www.aep.com/about/codeofconduct/OASIS/default.asp to determine the latest effective version. TRANSMISSION PLANNING GUIDELINE TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Responsible Engineer: Rev. 3 Steve M Scott Page 1 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Document Control Preparation ACTION NAME(S) TITLE Prepared by: Steve M. Scott Engineer Reviewed by: Teresa A. Gallup Reviewed by: J. Paul Hassink Approved by: Edward G. Schnell Manager SWTP Manager TTP Director TP Review Cycle Quarterly Semi-annual Annual X As Needed X Release 0 DATE RELEASED 12/12/2006 1 5/4/2007 2 6/12/2007 3 8/23/2007 VERSION FILE NAME CHANGE NOTICE AEP West Intrcnt_guidelines ver_ 12-12-2006 AEP West Intrcnt_guidelines ver_ 5-4-2007 AEP West Intrcnt_guidelines ver_ 6-12-2007 AEP West Intrcnt_guidelines ver_ 8-23-2007 REMARKS Update technical data Standardize with AEP East Guidelines. Standardize with AEP East Guidelines. Standardize with AEP East Guidelines. Distribution List NAME(S) DEPARTMENT TITLE Teresa Gallup Southwest Transmission Planning Manager J. Paul Hassink Texas Transmission Planning Manager Transmission and Interconnection Services West FERC Order 890 Manager Robert Pennybaker OASIS TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 2 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 1.0 2.0 3.0 4.0 5.0 6.0 7.0 8.0 Introduction Interconnection Practices and General Requirements for New Transmission Generation Facilities 2.1 Generation Sources 2.2 Practices for Parallel Generation 2.3 Practices for Separate and Parallel System 2.4 Induction Generators 2.5 Inverter Systems 2.6 Specific Interconnection Requirements 2.7 General Operating and Design Requirements 2.8 Restriction on Using Autotransformer Tertiary to Supply Load Interconnection Practices and General Requirements for New Transmission Establishing New Interconnections with Other Control Areas 3.1 Design Information 3.2 General Operating and Design Requirements Interconnection Practices and General Requirements for New Transmission Electrical End-Users Facilities 4.1 Design Information 4.2 General Operating and Design Requirements 4.3 Load Connection Definition and Requirements 4.4 Tap Connection Definition and Requirements 4.5 Looped Connection Definition and Requirements Construction Practices Substation Equipment, Insulation, Structural and Conductor Requirements 6.1 Substation Design Requirements Transmission Line Design, Loading, Clearance, Insulation and Structural Design Requirements 7.1 Transmission Line Design Requirements Metering and SCADA Requirements 8.1 Transmission Interconnect Metering Requirements 8.2 Transmission Interconnect SCADA Requirements 8.3 Communication Requirements 8.4 RTU Requirements 8.5 Generation Metering Requirements 8.6 Generation SCADA Requirements Appendices A: AEP Power Quality Requirements B: Typical Transmission Tap Supply & Line Looped Supply Configurations C: Electrical Clearances and Equipment Ratings D: Generation Abnormal Frequency Operating Allowance E: Information Supplied By Generator Owner F: 800 kV Major Equipment Specifications G: AEP Metering Requirements for Transmission Interconnection Facilities H: AEP SCADA RTU Requirements at Transmission Interconnection Facilities I: AEP Protection Requirements for Connecting to the AEP Transmission Grid J: Transmission Switching Guidelines for In-line Stations TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 3 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 1.0 INTRODUCTION American Electric Power Service Corporation (AEPSC), acting on behalf of the four electric operating companies (OPCO) in AEP’s Western Region (AEPW) has developed these guidelines, which state the minimum interconnection requirements for Transmission Generation (TG), Transmission Interconnections (TI) and Transmission Electrical End-Users (TEEU) Requester's facilities to the OPCO owned transmission system or transmission owned by others connected and operated in a control area. This document may be used as a guide when planning an installation but may not cover all details in specific cases. TG, TI and TEEU Requesters should note that the Electric Reliability Council of Texas (ERCOT) and Southwest Power Pool (SPP) have certain requirements and procedures that must be met. These AEPW guidelines augment the written interconnection requirements of ERCOT and SPP in those areas where the ERCOT and SPP written interconnection requirements are silent. If there is a conflict between these guidelines and the interconnection requirements of ERCOT or SPP, whichever is applicable to an OPCO, the ERCOT or SPP interconnection requirements will prevail. A TG Requester whose generating facility will be connected to the AEP Texas Central Company (TCC) or AEP Texas North Company (TNC) system must request an interconnection from the ERCOT in accordance with ERCOT procedures. A TG Requester whose generating facility will be connected to the Public Service Company of Oklahoma (PSO) or Southwestern Electric Power Company (SWEPCO) system must request an interconnection from the SPP in accordance with SPP procedures. A TI and TEEU Requester should request an interconnection from the AEPSC Manager of Transmission and Interconnection Services. TG, TI and TEEU Requesters should also follow the interconnection notification rules established by ERCOT and SPP, as applicable. In all cases, an Impact Study and a Facility Study will be conducted in accordance with the provisions of the generally available transmission service tariff. A TG, TI or TEEU Requester should not purchase interconnecting equipment until the Facility Study has been completed and an interconnection agreement has been executed between the TG, TI or TEEU Requester and the OPCO. 2.0 INTERCONNECTION PRACTICES FOR TRANSMISSION GENERATION FACILITIES 2.1 GENERATION SOURCES The TG Requester may elect to use a variety of energy sources. The end conversion for connection to the OPCO’s system must be 60-Hertz alternating current. 2.2 PRACTICES FOR PARALLEL GENERATION It is the practice of the OPCOs to permit any QF or any Exempt Wholesale Generator (EWG) to operate its generating equipment in parallel with the OPCO electric system whenever this can be done without adverse effects on the general public, OPCO equipment or other customers. Certain protective devices (relays, circuit breakers, etc.), specified by AEPW, must be installed at the location where a TG Requester will operate generation in parallel with the OPCO system. The purpose of these devices is to promptly disconnect the TG Requester’s equipment from the OPCO system whenever faults or abnormal operations occur. Other modifications to the existing electrical system configuration or protective relays may be required in order to accommodate parallel operation. Neither the OPCO nor AEPW assumes any responsibility for the protection of the TG Requester’s generator(s), nor of any other portion of the TG Requester’s electrical equipment for any or all operating conditions. The TG Requester is fully responsible for protecting his equipment in such a manner that faults or other disturbances on the OPCO system or other interconnected systems do not cause damage to the TG Requester’s equipment. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 4 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. In addition to installation of specified protective devices for disconnection from the power system, a TG Requester requesting parallel operation of their generation must install and maintain equipment to monitor and verify the proper interconnected operation (both transient and steady state) for expected power system disturbances. The TG Requester shall set generator-operating parameters to enhance power system security as specified by AEPW (see Section 2.7). 2.3 PRACTICES FOR SEPARATE AND PARALLEL SYSTEM The TG Requester may elect to run his generator in parallel with the OPCO or as a separate system with the capability of non-parallel load transfer between two independent systems. The requirements for these two methods of operation are outlined below. 2.3.1 SEPARATE SYSTEM (QF Only) - A separate system is defined as one in which there is no possibility of connecting the TG Requester’s generating equipment in parallel with the OPCO’s system. For this design to be practical, the TG Requester must be capable of transferring load between the two systems in an open transition or non-parallel mode. This can be accomplished by either an electrically or mechanically interlocked switching arrangement, which precludes operation of both switches in the closed position. If the TG Requester has a separate system, AEPW will require verification that the transfer scheme meets the non-parallel requirement. This will be accomplished by review of drawings by AEPW, by notification in writing to AEPW and if AEPW so elects, by field inspection of the transfer scheme. AEPW will not be responsible for reviewing, approving or evaluating the customer’s generation equipment and assumes no responsibility for its design or operation. Most Uninterruptible Power Supply (UPS) systems do not specifically meet the separate system criteria. However, if a UPS system is not capable of back feed (transfer of electric power from the emergency source to the normal source), it will be classified as a separate system. If it can back feed, it must meet the requirements of parallel generation. 2.3.2 PARALLEL SYSTEM - A parallel system is defined as one in which the TG Requester generation can be connected to a bus common with the utility’s system. A transfer of power between the two systems is a direct and often desired result. A consequence of such parallel operation is that the parallel generator becomes an electrical part of the utility system, which must be considered in the electrical protection of the utility’s facilities. Utility lines are subject to a variety of natural and man-made hazards. Among these are lightning, wind, animals, automobiles, malicious mischief, etc. Residential and commercial electric systems are subject to these hazards but not to nearly the same degree because of the limited extent and protected environment of such systems. Electrical problems, which can result from these hazards, include short circuits, grounded conductors, and broken conductors. These fault conditions require that the damaged equipment be de-energized as soon as possible because of the hazards they pose to the public and the operation of the system. A parallel generator connected to a utility line represents another source of power to energize the line. The parallel generator must have adequate protective devices installed to sense trouble in the utility system and to disconnect from the utility system. Parallel generation can also cause another condition, “accidental isolation”, in which a portion of the utility’s load becomes isolated from the utility source but is still connected to the TG Requester’s parallel generation. In this condition, the voltage may collapse or the isolated system may continue to operate independent of the utility (possibly with abnormal voltage or frequency). The probability of an isolated system, continuing to operate under these conditions, increases when the parallel generator size is greater than the amount of potentially isolated load. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 5 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. The protective devices and other requirements required by AEPW in the following sections are intended to provide protection against the hazards noted above by disconnecting the parallel generator when trouble occurs. If the generator is small compared with the magnitude of any load with which it could be isolated and the OPCO’s protective relays operate and isolate the generation with a large amount of load, the voltage will collapse and should automatically shutdown the generator. This approach is particularly appropriate for the induction generator or inverter systems since these systems do not contribute sustained overcurrents, which could also be used to detect faults directly. In most cases, it is impossible to predict with certainty that the generators will be isolated; as a result, AEPW requires the use of voltage and frequency measuring relays to detect isolation and trip the TG Requester unit. For synchronous generator installations, the probability of staying connected in isolated operation is higher since the available generation may be sufficient to carry the entire load of the facility and/or OPCO load. For these installations, specific devices are required for the detection of short circuits and grounds on the utility system as well as voltage and frequency relays to detect isolated operation. 2.4 INDUCTION GENERATORS Reactive power supply for induction generators may pose difficult design problems, depending on the generator size. Some installations may require capacitors to be installed to limit the adverse effects of reactive power flow on the OPCO’s system. The installation of capacitors for reactive power supply at or near an induction generator greatly increases the risk that the induction machine may become self-excited if accidentally isolated from the OPCO’s system. A self-excited induction generator can produce abnormally high voltages, which can cause damage to the equipment of other Customers. Over-voltage relays can limit the duration of such over-voltages but cannot control their magnitude because of the rapid voltage rise, which occurs with self-excitation. Because of these problems, the reactive power supply for induction generators must be studied on an individual basis. Where self excitation problems appear likely, special service arrangements will be required in order to avoid the induction generator becoming isolated with small amounts of the OPCO load. For installations considering an induction generator(s), AEPW should be consulted during the planning and design process. 2.5 INVERTER SYSTEMS Reactive power supply requirements for inverter systems are similar to those for induction generators and the general guidelines discussed in Section 2.4 apply. Likewise, inverter systems are also capable of isolated operation. Self-commuted inverters have this capability by design. Line commuted inverters could operate isolated if connected to rotating machines which provide the necessary commutation. Because of the possibility of self-excited operation, inverter systems are treated as induction machines in these guidelines. At present no standards exist for the harmonic output of power inverters. If a TG Requester using such a device for parallel generation is found to be interfering with other OPCO customers or utilities, or if standards are adopted in the future, TG Requester may be required to install filtering or other equipment to bring the harmonic output of his inverter to an acceptable level. For installations considering an inverter system(s), AEPW should be consulted during the planning and design process. 2.6 SPECIFIC GENERATOR STEP UP (GSU) TRANSFORMER REQUIREMENTS AEPW has established Generator Step Up (GSU) transformer requirements for TG Requester owned parallel generation, with specific protection, metering and operating requirements based upon typical AEPW installations. The final decision as to the requirements for each installation will be made depending on the TG Requester’s electrical location of the generator, the existing electrical facilities, the rating of TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 6 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. existing electrical equipment and generators connected to that circuit or system, available short circuit contributions, etc. For parallel transmission generation, Wye - Delta connected Generator Step Up (GSU) transformers, the GSU will be connected Wye to the bulk transmission system on lines rated 69 kV and above and connected Delta to the TG Requester’s side. This ground source will provide a means for the TG Requester to separate its equipment from the OPCO system for ground faults that have not been cleared in a reasonable amount of time. The low side Delta connection will limit the ground fault currents the TG Requester will experience for faults on their system. 2.7 GENERAL OPERATING AND DESIGN REQUIREMENTS 2.7.1 The OPCO’s nominal transmission voltages are 69 kV, 115 kV, 138 kV, 161 kV, 230 kV and 345 kV. Contact AEPW for information on the specific circuit(s) serving or available to serve the TG Requester’s facility. 2.7.2 The TG Requester shall change his facility or equipment as may be required by AEPW to meet future changes in the transmission system. The TG Requester shall be given reasonable notice by AEPW prior to the date that the required changes in the TG Requester’s facilities must be made. 2.7.3 The TG Requester is solely responsible for properly synchronizing its generation with the OPCO and shall provide to AEPW for review, the most current specifications for interconnection equipment, including control drawings and one-line diagrams. AEPW’s review of TG Requester’s specifications shall not be construed as confirming or endorsing the design or as any warranty of safety, durability or reliability of the facility or equipment. Please refer to Appendix I “Automatic Reclosing”. 2.7.4 The TG Requester shall not energize a de-energized circuit owned by the OPCO, unless under direction of AEPW System Operations. 2.7.5 The TG Requester’s generating equipment shall not cause objectionable interference with the electric service provided to other Customers by the OPCO nor jeopardize the security of the power system. In order to minimize the interference of the TG Requester’s parallel generation with AEPW System Operations, the TG Requester’s generation shall meet the following criteria: a) Voltage - The TG Requester’s generating equipment shall not cause excessive voltage excursions. The TG Requester shall operate its generating equipment in such manner that the voltage levels on the system are in the same range as if the generating equipment was not connected to the OPCO system. The TG Requester shall provide an automatic method of disconnecting his generating equipment from the OPCO’s facilities to protect against excessive voltage excursions. b) Flicker - The TG Requester shall not cause excessive voltage flicker on the electric facilities of the OPCO. Flicker is to be measured at the TG Requester’s service point and shall not exceed 1.5% or the Borderline of Visibility Curve (see Section 9, Voltage Flicker Chart, ANSI/IEEE Std 141-1993) whichever is less. c) Frequency - The operating frequency of the TG Requester’s generating equipment shall not deviate from the OPCO’s system frequency. The TG Requester’s under frequency relays shall be set the same as the OPCO’s under frequency relays, so that TG Requester’s generator shall not separate from the OPCO’s system during under frequency conditions until all of OPCO’s under frequency load shedding equipment has operated. Please refer to Appendix I “Frequency Protection”. d) Harmonics, Telephone Interference and Carrier Interference - The TG Requester’s generating equipment shall not introduce: excessive distortion of the OPCO’s TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 7 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. waveforms; voltage and current; telephone interference; or carrier interference at the TG Requester service point. IEEE Standard 519, approved 1992, shall be used as a guide. e) Fault and Line Clearing - The TG Requester shall remove its generating equipment from connection with the OPCO’s system on occurrence of an outage or fault on the OPCO’s electric facilities serving the TG Requester’s facilities radially. The TG Requester is responsible for the stability of its units and providing adequate facilities so that critical fault clearing times are met. f) Power Factor – The power factor of the generator(s) will be at least 0.85 lag and 0.95 lead. For synchronous generators, the generator voltage-VAR schedule, voltage regulator, and transformer ratio settings will be jointly determined by AEPW and TG Requester to ensure proper coordination of voltages and regulator action. TG Requester’s must generate their Var requirements. AEPW may, in order to maintain security of the power system, request TG Requester to accept or supply reactive power. In cases where starting or load changes on induction generators will have an adverse impact on the OPCO system voltage, AEPW is to be consulted on techniques required to bring voltage changes to acceptable levels. g) SCADA – The TG Requester shall provide individual SCADA data values to AEPW System Operations for all generation. For more detail on these requirements, see Metering and SCADA Requirements in Section 8. h) Excitation System and Automatic Voltage Regulation – TG Requester’s or any interconnected generator(s) excitation system response ratio shall not be less than 0.5 (five-tenths). TG Requester’s or any interconnected generator(s) excitation system(s) shall conform, as near as achievable, to the field voltage vs. time criteria specified in American National Standards Institute Standard C50.13-1989 in order to permit adequate field forcing during transient conditions. Depending on ERCOT Operating Guide or SPP criteria requirements or the results of AEPW small signal stability studies (subject to Independent System Operator review), it may be necessary for TG Requester to install power system stabilizers (PSS) on TG Requester’s exciter system. If so, AEPW will require TG Requester to install such PSS on it’s exciter system and AEPW will do so in a manner that is not discriminatory to TG Requester. Each generator’s exciter and exciter controls shall have a ride-through capability for significant system voltage disturbances (i.e., utilize UPS or DC design). TG Requester’s or any interconnected generator(s) shall maintain the Automatic Voltage Regulator (AVR) of each generating unit in service and operable at all times. If the AVR is removed from service for maintenance or repair, AEPW System Operations shall be notified. i) Governor System – TG Requester’s or any interconnected generator(s) governor(s) shall be able to respond to interconnection frequency deviations and help return interconnection frequency to normal following an upset on the SPP or ERCOT system to assist in maintaining interconnection stability. 2.7.6 AEPW shall require dedicated communication channel(s) and/or dial-up facilities be installed, at the TG Requester’s expense, as part of the relay protection, remote monitoring/control, remote metering and/or direct voice contact between AEPW and TG Requester is required for switching. For more detail on these requirements, see Communication Requirements in Section 8.3. 2.7.7 It is the sole responsibility of the TG Requester to protect his equipment from excessive negative sequence currents. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 8 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 2.7.8 The TG Requester shall be required to install, operate and maintain in good order and repair, and without cost to AEPW, all facilities required by AEPW for the safe operation of the TG Requester’s generation facilities in parallel with the OPCO’s electrical system. The TG Requester’s generation and electrical facilities shall be installed, operated, and maintained by the TG Requester at all times in conformity with generally accepted utility practice and shall comply with the National Electrical Code, the National Electrical Safety Code, any applicable local codes, and any applicable AEPW service standards included in the Interconnection Agreement. Any electrical facilities operated, as a part of the transmission grid shall have the ownership and maintenance responsibility outlined in the interconnection agreement. 2.7.9 The TG Requester shall furnish at a minimum, a manual disconnect switch with visual contacts and allowance for padlocking, to separate the TG Requester’s generator from the OPCO. The location of this switch will be determined by AEPW, and be readily accessible to AEPW at all times. The disconnect switch will be under the exclusive control of AEPW and will be considered as part of AEPW’s switching arrangement. AEPW reserves the right to open this disconnecting device, isolating the TG Requester generation, for any of the following reasons: a) The TG Requester’s generating equipment upon AEPW’s determination causes objectionable interference with other Customer’s service or with the secure operation of the OPCO’s electrical system. b) The TG Requester’s generator output as determined by AEPW exceeds the operating boundaries outlined in Section 2.7.5. c) The TG Requester’s control and protective equipment causes or contributes to a hazardous condition. AEPW reserves the right to verify on demand all protective equipment including relays, circuit breakers, etc. at the inter-tie location. Verification may include the tripping of the tiebreaker by the protective relays. d) In AEPW’s opinion, continued parallel operation is hazardous to TG Requester, the OPCO System or to the general public. e) To provide AEPW or OPCO personnel the clearances for dead line or live line maintenance. The OPCO or AEPW will attempt to notify the TG Requester before disconnection, but notification may not be possible in emergency situations that require immediate action. 2.7.10 Automatic reclosing is normally applied to transmission and distribution circuits. When the OPCO’s source breakers trip and isolate the TG Requester’s facilities, TG Requester shall insure that his generator is disconnected from the OPCO circuit prior to automatic reclosure by the OPCO. Automatic reclosing out-of-phase with the TG Requester’s generator may cause damage to TG Requester’s equipment. The TG Requester is solely responsible for the protection of his equipment from automatic reclosing by the OPCO. 2.7.11 TG Requester is solely responsible for providing adequate protection for TG Requester’s facilities operating in parallel with the OPCO’s system in such manner that faults or other disturbances on the OPCO system do not cause damage to TG Requester’s equipment. 2.7.12 The TG Requester may not commence parallel operation of generator(s) until consent has been given by AEPW. AEPW reserves the right to inspect TG Requester’s facility and witness testing of any equipment or devices associated with the interconnection. Operating Procedures will be jointly developed and be agreed to in the Interconnection Agreement. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 9 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 2.7.13 The TG Requester shall install protective devices (relays, circuit breakers, etc.), metering equipment, and synchronizing equipment by as required by AEPW. The protective devices and the installing party (the OPCO or TG Requester) may differ between installations. 2.7.14 For parallel operation the TG Requester shall submit single-line drawings of this equipment to AEPW for review of the protective, metering and remote monitoring/control functions. Any changes required by AEPW shall be made prior to final issue of drawings and AEPW shall be provided with final copies of the revised drawings. AEPW will review only those portions of the drawings, which apply to protection, metering and monitoring which affect the OPCO’s system. To aid the TG Requester, AEPW may make suggestions on other areas, but will not assume responsibility for the correctness pertaining to TG Requester’s system. 2.7.15 The TG Requester shall maintain an operating log at each generating facility that at a minimum will indicate changes in operating status (available or unavailable), maintenance outages, trip indications or other unusual conditions found upon inspection. For generators, which are “block-loaded” to a specific MW level, changes in this setting shall also be logged; AEPW may waive this requirement at its discretion. The TG Requester, as required by NERC or ERCOT/SPP, will maintain reliability information. Regarding MW production, the TG Requester will be required to back down their generation at certain times to maintain reliability. For example, when system loading is at minimum levels and the TG Requester has not scheduled the sale/transport of their production outside the AEPW control area, or when transmission maintenance is required, the TG Requester should be prepared to reduce generation to maintain operation within system limitations. 2.7.16 Fault (Transient) recorders are designed to record events that are very short in nature, such as faults on transmission lines or transients produced during switching or arcing of electrical equipment. Fault (Transient) event records may be only one or two seconds long, but their sample rate may be as high as 75 to 100 samples per cycle. Dynamic recorders are designed for long-term events, such as under frequency or voltage conditions. Dynamic recorders events may be 5 to 10 minutes long, but their sample rate may be only 1 to 12 samples per cycle. These events usually show only the trending of the analog values or power flow out of a generator. The OPCO shall purchase, install and maintain fault (transient) and long term dynamic recording equipment to monitor and verify generator’s proper transient and steady-state response to power system disturbances. This equipment may be located at either the OPCO’s or TG Requestor substation, depending on each site’s particular needs and requirements. The fault (transient) / dynamic recorder at the TG Requester’s generator location will be at a mutually agreed location. The TG Requester shall provide the necessary connections to the recording equipment and the OPCOs will terminate the signals in the recorder. The OPCO shall own and maintain the recorder(s). The necessary communication equipment (See Section 8) shall be installed by the TG Requester and access shall be provided to allow the OPCO the ability to monitor the recorder(s) and verify the TG Requester’s generator response to power system disturbances. All fault (transient) / dynamic recorders shall be equipped with time synchronizing equipment. The monitoring requirement of AEPSC does not reduce the TG Requester’s obligation to meet all NERC – Disturbance Monitoring requirements contained in the NERC Reliability Standards. 2.8 Restriction on Using Autotransformer Tertiary to Supply Load The tertiary winding of an AEP autotransformer cannot be used as a source for non-generator or generator load. The restriction on the tertiary winding as an off-site power source is due to the facts that: 1) significant fault exposure can be introduced to the transformer when load is served from the transformer tertiary, and 2) there are several documented cases of transformer life being shortened due to this type of configuration. In addition to TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 10 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. shortening transformer life, these configurations are inordinately difficult and expensive to remove from service for maintenance. Such load serving configurations are therefore considered reliability risks and are not allowed. 3.0 INTERCONNECTION PRACTICES AND GENERAL REQUIREMENTS FOR NEW INTERCONNECTIONS WITH OTHER CONTROL AREAS 3.1 DESIGN INFORMATION 3.1.1 The OPCO’s nominal transmission voltages are 69 kV, 115 kV, 138 kV, 161 kV, 230kV and 345 kV. Contact AEPW Transmission Planning Department for information on the specific circuit(s) serving or available to serve the TI Requester facility 3.1.2 All OPCO’s 200Kv and above transmission lines are primarily protected by two different highspeed pilot relaying system, such as Directional Comparison Blocking, Permissive Overreaching Transfer Trip (POTT), Permissive Under-reaching Transfer Trip (PUTT), Current Differential, and Directional Comparison Un-blocking schemes. Most OPCO’s 100Kv – 200Kv transmission lines are protected by a single high-speed Pilot relaying system, with a Step Distance phase, and directional ground overcurrent relaying scheme for backup. Most OPCO’s below 100kV lines are protected by a primary and backup phase Step Distance scheme with a directional ground over-current relay. AEPSC will determine the appropriate protection for each TI Request. Current differential relays may require fiber optic, microwave, etc., for their pilot channels.. 3.1.3 The TI Requester shall be required to furnish the AEPW System Protection Department with the specific relay setting information on the TI Requester facilities. This will allow AEPW the opportunity to review the TI Requester settings to ensure proper coordination with the OPCO’s equipment. 3.1.4 Because most short circuits faults on overhead lines are of a temporary nature, it is the OPCO’s practice to reclose the circuit breakers on such lines (high-speed) after they have automatically tripped. This high-speed reclosing typically involves an intentional time delay of 15 - 30 cycles and some additional time required for the operating speed of the relays and circuit breaker(s). Reclosing for 69kV lines and those lines that have a high-side transformer recovery scheme have a second reclose. This second reclose has an intentional time delay of 20 seconds. This practice improves continuity of service to all OPCO Customers. 3.1.5 All OPCO’s interconnections with other control areas require synchronizing equipment at the OPCO’s location. 3.1.6 The TI Requester may be responsible for the installation of equipment to island during under frequency or under voltage conditions. This may include such as transfer trip equipment, at the OPCO (local end), TI Requester (remote end), or both locations 3.1.7 The TI Requester shall change his facility or equipment as may be required by NERC, ERCOT/SPP or AEPW for AEPW to meet future changes in the transmission system. The TI Requester shall be given reasonable notice by AEPW prior to the date that required changes in the TI Requester’s facilities must be made. 3.1.8 The OPCO reserves the right to inspect, calibrate, test and maintain TI Requester protective equipment located on OPCO property associated with the protection of the OPCO’s system. 3.2 GENERAL OPERATING AND DESIGN REQUIREMENTS 3.2.1 The TI Requester is solely responsible for properly connecting its equipment to AEPW and shall provide to AEPW for review the most current specifications for interconnection equipment, including drawings and one-line diagrams. AEPW’s review of TI Requester specifications shall not be construed as TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 11 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. confirming or endorsing the design or as any warranty of safety, durability or reliability of the facility or equipment. 3.2.2 The TI Requester shall not energize a de-energized circuit owned by the OPCO, unless under direction of AEPW System Operations or except by automatic relay operation approved by AEPW. 3.2.3 The TI Requester interconnected system shall not cause objectionable interference with the electric service provided to other Customers by the OPCO. The TI Requester equipment shall meet the following criteria: a) Voltage - The TI Requester shall operate its system in such manner that the voltage levels on the system are maintained at reliable levels as per ERCOT Operating Guides or SPP criteria. b) Flicker - The TI Requester shall not cause excessive voltage flicker on the electric facilities of the OPCO. Flicker is to be measured at the TI Requester’s service point and shall not exceed 0.6% (see Appendix A, AEP Power Quality Requirements, ANSI/IEEE Std 1453-2004). c) Harmonics, Telephone Interference and Carrier Interference - The TI Requester interconnect system shall not introduce: excessive distortion of the OPCO’s waveforms; voltage and current; telephone interference; or carrier interference at the TI Requester service point. IEEE Standard 519, approved 1992, shall be used as a guide. d) Fault and Line Clearing - The TI Requester is responsible for the stability of its system and providing adequate facilities so that critical fault clearing times are met. e) SCADA - The TI Requester shall provide individual SCADA data values to AEPW System Operations for all interconnects. For more detail on these requirements, see Metering and SCADA Requirements in Section 8. 3.2.4 AEPW shall require dedicated communication channel(s) and/or dial-up facilities be installed, at the TI Requester’s expense, as part of the relay protection, remote monitoring/control and, remote metering. Direct voice contact between AEPW and TI Requester is required for switching. For more detail on these requirements, see Communication Requirements in Section 8.3. 3.2.5 The TI Requester shall be required to install, operate and maintain in good order and repair, and without cost to AEPW, all facilities required by AEPW for the safe operation of the TI Requester’s facilities connected to the OPCO’s electrical system. The TI Requester’s electrical facility shall be installed, operated, and maintained by the TI Requester at all times in conformity with generally accepted utility practice and shall comply with the National Electrical Code, the National Electrical Safety Code, any applicable local codes, NERC Reliability Standards, and any applicable AEPW or other service standards included in the Interconnection Agreement. Any electrical facilities operated, as a part of the transmission grid shall have the ownership and maintenance responsibility outlined in the interconnection agreement. 3.2.6 The TI Requester is solely responsible for providing adequate protection for its interconnecting facilities operating connected to the OPCO’s system in such manner that faults or other disturbances on the OPCO system do no cause damage to TI Requester’s system. Please refer to Appendix I for details. 3.2.7 The TI Requester may not connect to OPCO’s system until consent has been given by AEPW. AEPW reserves the right to inspect the TI Requester facility and witness testing of any equipment or devices associated with the interconnection. Operating Procedures will be developed and become a part of the Interconnection Agreement. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 12 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 3.2.8 The TI Requester shall install protective devices (relays, circuit breakers, etc.), metering equipment, and synchronizing equipment as required by AEPW. The protective devices may differ in equipment between installations. 3.2.9 The TI Requester shall submit single-line drawings of their interconnection equipment to AEPW for review of the protective, metering and remote monitoring/control functions. Any changes required by AEPW shall be made prior to final issue and AEPW shall be provided with final copies of the revised drawings. AEPW will review only those portions of the drawings, which apply to protection, metering and remote monitoring/control, which affect the OPCO’s system. To aid the TI Requester, AEPW may make suggestions on other areas, but will not assume responsibility for the correctness pertaining to TI Requester’s system. 4.0 INTERCONNECTION PRACTICES AND GENERAL REQUIREMENTS FOR NEW TRANSMISSION ELECTRICAL END-USERS FACILITIES 4.1 DESIGN INFORMATION 4.1.1 The OPCO nominal transmission voltages are 69 kV, 115 kV, 138 kV, 161 kV, 230 kV and 345kV. Contact AEPW Transmission Planning department for information on the specific circuit(s) serving or available to serve the TEEU Requester Facility. 4.1.2 TEEU Requester’s two winding transformer connected to OPCO’s transmission system will be connected high side Delta and low side Wye. Distribution system with very high fault currents may require grounding resistor or inductor in the transformer neutral with AEPW approval. 4.1.3 Transformers associated with the bulk (69kV and up) transmission system should be provided with high-speed protection to minimize damage to the transformer, the associated substation equipment and the effects upon the system. A protective zone should be provided for each protected transformer. The various zones should overlap so that no area will be unprotected. a) Power transformer fuses are the most economical means of protecting a transformer. But AEPW recommends that fuses not be used on transformers larger than 10MVA due to their inability to adequately protect the transformer for all fault conditions. Please refer to Appendix I “Customer Tapped Station and Fused Transformer Application”. 4.1.5 The TEEU Requester shall be required to furnish the AEPW System Protection Department with the specific fuse and relay setting information at the TEEU Requester facilities. This will allow AEPW the opportunity to review the TEEU Requester settings to ensure proper coordination with the OPCO’s equipment. 4.1.6 A TEEU Requester’s facility that is located on a transmission line tap, where the OPCO’s transmission line relays cannot adequately protect, the TEEU Requester shall be required to provide breakers, wave traps, CCVTs, CT, relays and carrier blocking signals at the transmission tap location. The TEEU Requester will trip and carrier block for faults on the TEEU Requester tap. 4.1.7 All OPCO TEEU Requester Interconnect facilities utilize revenue meters and associated equipment at the TEEU Requester’s location. Revenue meters shall be specified by AEPW. 4.1.8 The TEEU Requester’s may be required to purchase and install equipment to shed load during under frequency or under voltage conditions as per ERCOT Operating Guides or SPP criteria at the TEEU Requester’s facilities. Please refer to Appendix I “Automatic Underfrequency Load Shedding”. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 13 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 4.1.9 The TEEU Requester shall change their facility or equipment as may be required for AEPW to meet future changes in the transmission system including a voltage change. The TEEU Requester shall be given reasonable notice by AEPW prior to the date that the required changes in the TEEU Requester facilities need to be made. 4.1.10 AEPW shall require dedicated communication channel(s) and/or dial-up facilities be installed, at the TEEU Requester’s expense, as part of the relay protection, remote monitoring/control, remote metering and/or direct voice contact between AEPW and TEEU Requester is required for switching. For more detail on these requirements, see Communication Requirements in Section 8.3. 4.1.11 4.2 See other substation and transmission requirements in sections 6 and 7. GENERAL OPERATING AND DESIGN REQUIREMENTS 4.2.1 The TEEU Requester is solely responsible for proper coordination of its equipment with the OPCO’s and shall provide to AEPW for review, the most current specifications for interconnection equipment, including drawings and one-line diagrams. AEPW’s review of TEEU Requester specifications shall not be construed as confirming or endorsing the design or as any warranty of safety, durability or reliability of the facility or equipment. 4.2.2 The TEEU Requester shall not energize a de-energized circuit owned by the OPCO, unless under direction of AEPW System Operations. 4.2.3 The TEEU Requester’s interconnect equipment shall not cause objectionable interference with the electric service provided to other customers by the OPCO. The TEEU Requester’s equipment shall meet the following criteria: a) Power Factor - The TEEU Requester shall operate its equipment in such manner that the power factor will be as specified in the transmission service agreement. b) Flicker - The TEEU Requester shall not cause excessive voltage flicker on the electric facilities of the OPCO. Voltage flicker will be dictated by the sensitivity of the load or loads being served. Flicker is to measured at the TEEU Requester’s service point and shall not exceed 1.5% or the Borderline of Visibility Curve (see Section 9, Voltage Flicker Chart, ANSI/IEEE Std 141-1993), whichever is less. c) Under frequency - The TEEU Requester shall install under frequency relays and shed load as outlined in the SPP or ERCOT Load Shedding Guides. d) Harmonics, Telephone Interference and Carrier Interference - TEEU Requester’s interconnect equipment shall not introduce: excessive distortion of the OPCO’s wave forms; voltage and current; telephone interference; or carrier interference at the TEEU Requester’s service point. IEEE Standard 519, approved 1992, will be used as a guide. e) SCADA - The TEEU Requester shall provide individual SCADA data values to AEPW System Operations for all interconnects. For more detail on these requirements, see Metering and SCADA Requirements in Section 8. 4.2.4 The TEEU Requester will be required to install, operate and maintain in good order and repair, and without cost to AEPW, all facilities required by AEPW for the safe operation of the TEEU Requester facility’s connected to the OPCO’s electrical system. The TEEU Requester electrical facility shall be installed, operated, and maintained by the TEEU Requester at all times in conformity with generally accepted utility practice and shall comply with the National Electrical Code, the National Electrical Safety Code, any applicable local codes, NERC Reliability Standards, and any applicable AEPW service standards included in the Interconnection Agreement. Any electrical facilities operated, as a part of the TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 14 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. transmission grid shall have the ownership and maintenance responsibility outlined in the interconnection or operating agreement. 4.2.5 TEEU Requester is solely responsible for providing adequate protection for its interconnecting facilities connected to the OPCO’s system in such manner that faults or other disturbances on the OPCO system do no cause damage to TEEU Requester’s equipment. Please refer to Appendix I for details. 4.2.6 The TEEU Requester may not connect to OPCO’s system until consent has been given by AEPW. AEPW reserves the right to inspect the TEEU Requester’s facility and witness testing of any equipment or devices associated with the interconnection. Operating Procedures will be developed and become a part of the Interconnection Agreement. 4.2.7 TEEU Requester shall install protective devices (relays, circuit breakers, etc.) for the protection of the OPCO’s system and metering equipment as required by AEPW. The protective devices and the installing party (the OPCO or TEEU Requester) may differ between installations. 4.2.8 The TEEU Requester shall submit single-line drawings of their equipment to AEPW for review of the protective, metering and remote monitoring/control functions. Any changes required by AEPW shall be made prior to final issue and AEPW shall be provided with final copies of the revised drawings. 4.2.9 AEPW will review only those portions of the drawings, which apply to protection, metering and remote monitoring/control, which affect the OPCO’s system. To aid the TEEU Requester, AEPW may make suggestions on other areas, but will not assume responsibility for the correctness of protection pertaining to TEEU Requester system. 4.3 Load Connection Definition and Requirements 4.3.1 Tap Connection Definition and Requirements Any connection to the AEP West Transmission System that results in only the transmission customer load passing through the connecting facilities under all conditions is considered a tap connection. If the Requester’s facilities are located near an existing AEP station, the connection from the AEP West Transmission System may be provided by constructing a radial line from the AEP station to the Requester's facility. If the Requester's facilities are located near an existing AEP transmission line, the connection from the AEP Transmission System may be provided by tapping the nearby AEP line (if adequate transmission capacity exists) and constructing a radial line to the Requester's facility. This arrangement will provide a radial connection to the Requester but will also result incidentally in creating in-line facilities at the tap point. For facilities below 200 kV, Figures 1 and 2 in Appendix J illustrate typical radial line supply configurations and some of the basic connection requirements. Other possibilities exist depending on the particular situation. As indicated, line switches are typically the minimum requirements at the tap location point. The tap line air break switch can disconnect the Load Connection without de-energizing the supply line and the in-line air break switches allow for sectionalizing the line without supply interruption to the Load Connection. Motor operated mechanisms (with or without supervisory control) may be required (refer to TP-000004 – Transmission Switching Guidelines for the In-Line Stations), or optionally can be added, to in-line air break switches to minimize the time required for restoration following a failure of the AEP supply line. The in-line switches or circuit breakers must match the thermal capability of the line conductor. The in-line switches must also be designed to provide appropriate "Line Dropping" or "Loop Interrupting" capabilities. Capabilities of the radial line and other associated facilities would depend on the magnitude of the connected load. In addition, the ground wire must meet the selection criteria as outlined in AEP Report #792, entitled "Selection of Transmission Ground Wires". Connection to the AEP Extra High Voltage (EHV) transmission system (200 kV and above) will be reviewed on a case-by-case basis. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 15 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 4.3.2 Looped Connection Definition and Requirements Any connection to the AEP West Transmission System that provides two line extensions to supply the Transmission Interconnection and Load Connection is considered a looped connection. In general, the two line extensions are installed to facilitate the Requester obtaining looped service, not to enable AEP to provide adequate electrical service to any location other than the Load Connection. Since some looped connections have the potential to significantly affect the reliability and loadability of the AEP Transmission System, specific design and operational requirements are imposed which may not be required for a tapped connection. Figure 3 in Appendix J illustrates typical looped supply configurations for connections below 200 kV and some of the basic connection requirements. Other possibilities exist depending on the particular situation. For looped supply configurations, either a delta or ungrounded-wye high side transformer-winding configuration is preferred for connecting substation transformers. 5.0 CONSTRUCTION PRACTICES The following practices are minimum construction standards and as such do not represent a warranty from AEPW or the OPCOs of the adequacy of the Requester design. These minimum practices refer to initial and all future construction by Requesters on OPCO facilities located on OPCO property or property owned by Requesters and also, construction by Requesters on Requester facilities on OPCO property. These practices would also cover construction by Requester on Requester facilities located on Requesters property, where the facilities are to be transferred to OPCO ownership and/or control. Construction practices to be followed by the TG, TI and TEEU Requesters include, but are not limited to the following: 5.1 Work Schedule and Material - A proposed project timetable, including construction milestones shall be prepared. The schedule should list types, quantity and delivery schedule of major materials and equipment, required dead line clearances, temporary construction, etc. These milestones should include service date for the transmission connection and a date for temporary service to test facilities prior to commercial in service. 5.2 Supervision - Knowledgeable and experienced construction management personnel shall be used to insure quality workmanship, use of specified materials, and coordination of work between TG, TI and TEEU Requester’s contractor and AEPW. 5.3 Contractors - Qualification of contractors shall be based on familiarity and experience in working around energized and similar installations and on known reputation for quality workmanship. 5.4 Insurance - TG, TI and TEEU Requester’s Contractors working on OPCO property or facilities, shall have insurance equal to or better than the OPCO contractor requirements and the policy shall name the OPCO and AEPW as an insured. 5.5 Safety - TG, TI and TEEU Requesters personnel, their guests and agents are to be fully aware of the existence and location of the OPCO transmission, substation and distribution facilities. TG, TI and TEEU Requesters Requester’s personnel shall be knowledgeable of the risks of conducting activities in the vicinity of such facilities and be knowledgeable of the procedures and precautions necessary to minimize such risks. This includes but is not limited to those set for in the OSHA regulations, National Electric Safety Code (NESC, ANSI C2-1990), National Electrical Code (NEC and Sections 754.001 et. seq. of the Texas Health and Safety Code). 5.6 For facilities on the TG, TI and TEEU Requester’s side of the point of service, the TG, TI and TEEU Requesters is responsible for all design and construction. AEPW may advise of known similar construction and may provide, if requested, a listing of engineering, construction, and construction management contractors familiar to AEPW. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 16 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 6.0 SUBSTATION EQUIPMENT, INSULATION AND STRUCTURAL DESIGN REQUIREMENTS Upon determination of the point of service, the design and construction of new substation facilities on the OPCO electric system necessary to connect the TG, TI and TEEU Requester shall be done utilizing current OPCO construction, insulation, and structural practices for new facilities. For proposed facilities on the OPCO-side of the Interconnections, AEPW will review project plans with the TG, TI and TEEU Requester before work commences. 6.1 SUBSTATION DESIGN REQUIREMENTS The following is general information on various aspects concerning the design of substation. More detailed information concerning AEPW guidelines may be obtained by contacting the AEPW Manager of Substation Design. 6.1.1 Lightning Arrester - The lightning arrester ratings recommended by AEPW are shown in the table below. Arresters for 230 kV and greater applications need to be evaluated on case by case basis due to the special duty placed on the arresters due to switching surge capabilities. AEPW Manager of Transmission Planning can provide more information on this topic. Characteristics of the units to be installed will be provided to AEPW prior to construction. AEP Standard Arrester Ratings System kV Duty-Cycle Voltage (kV) 69 60 115 90 138 108 161 120 230 ** 345 ** 765 ** Arrester selection shall conform to IEEE STD C62.22. Maximum Continuous Operating Voltage (MCOV) (kV) 48 70 84 98 ** ** ** 6.1.2 Oil Containment - The type of containment system that is to be used in a AEPW substation shall be determined on a case by case basis by AEPW. TG, TI and TEEU Requesters shall be responsible for the design, installation and maintenance of the containment system required for its facilities. 6.1.3 Substation Static Wires - The TG, TI and TEEU Requesters shall provide locations and attachments for required AEPW static wires that will be terminated on TG, TI and TEEU Requester’s Facilities. Loading requirements will be determined on a case-by-case basis by AEPW. 6.1.4 Substation Ground Grid - Personnel safety is the primary objective of an adequate grounding system. The ground grid must be designed to limit surface potential gradients to safe values in accordance with ANSI/IEEE 80. A substation grounding system shall be designed to fulfill the following requirements: a) Proper grounding of equipment, structures, and installation of an adequate earth ground grid for safety to personnel. b) Grounding of system neutrals to stabilize circuit potentials with respect to earth ground, and to provide circuit relaying for clearing ground faults. c) Proper equipment grounding for lightning, surge protection, and low voltage faults. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 17 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Contact the AEPW Project Manager to obtain ground fault values and clearing times for AEPW facilities. The TG, TI and TEEU Requesters shall provide AEPW design drawings and material lists for its proposed substation ground grid. Ground grid connections between AEPW facilities and TG, TI and TEEU Requester’s facilities shall be designed and installed in a manner that is acceptable to AEPW. 6.1.5 Substation Fence - The National Electric Safety Code (ANSI 2-1993) references IEEE std. 11191988 as a guide by AEPW for station fence clearances. AEPW recommends the use of 7 foot fabric with three strands of barbed wire on a single bayonet which extends out of the substation at a 45° angle above the fabric. The vertical height of bayonets should be one foot. AEPW also recommends that snake fences be used in new substation construction within certain AEPW areas. 6.1.6 Bus Heights and Phase Spacing - AEPW recommends new substation construction be designed to the bus heights and phase spacing presented in the table below. An exception is an addition to an existing substation where existing steel and bus heights may have to be matched. Matching existing steel is not mandatory, however. System Voltage BIL (kV) 345 kV 1300 345 kV 1050 161 kV 650 138 kV 550 138 kV 650 69 kV 350 Recommended Bus Heights and Phase Spacing Phase to Phase High Bus Low Bus 15’-0” 15’-0” 12’-0” 10’-0” 10’-0” 7’-0” 36’-2” 35’-0” 22’-0” 22’-0” 22’-0” 18’-0” 23’-2” 22’-0” 15’-0” 15’-0” 15’-0” 14’-0” 6.1.7 Control Buildings – AEPW recommends that TG, TI and TEEU Requester’s facilities are designed to meet the following minimum loading requirements: Control buildings located within approximately 140 miles of the Gulf of Mexico shall be designed for a minimum basic wind speed equal to 135 mph. Facilities located in all other areas of the OPCO’s service territories shall be designed for a minimum basic wind speed equal to 90 mph. Control buildings shall be designed to support all anticipated dead load including the weight of the building and the equipment that it supports, including all tray and cable. Buildings shall be designed using a live load equal to 20 pounds per square foot. The ground snow load used in determination of the design snow load shall be as defined by the authority having jurisdiction, but shall not be less than 30 pounds per square foot. Loads shall be combined as defined in the latest edition of the “International Building Code” or as directed by the authority having jurisdiction. In addition to these requirements, the TG, TI and TEEU Requester must ensure that all structural, electrical, and mechanical design work meets the minimum requirements of the authority having jurisdiction. 6.1.8 Substation Lighting is needed to provide sufficient illumination where needed in the substation. With such lighting, personnel will be able to observe and effectively control the operation and maintenance of various substation equipment and processes. Other applications of lighting will be for security in the substation. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 18 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 6.1.9 AC station service system is extremely important to the reliable operation of substation equipment when AEPW facilities are located in TG, TI and TEEU Requester’s substation, AEPW must approve the design and construction of the AC station service system. Receptacles are needed in the substation yard adjacent to AEPW equipment for various AC needs. AEPW will indicate the type of receptacle needed for each location. 6.1.11 DC station service system for a substation is needed to supply critical station loads. These station loads include: circuit switchers, breakers, motor operated switches, switchgear, RTUs, and relays. The DC system voltage is typically obtained from a station battery and the associated charging system. The standard AEPW battery voltages are 48VDC and 125 VDC. (It should be noted that some substations have 24 VDC, 32 VDC or 250 VDC.) Each substation must have a properly sized battery and charger to carry the DC station loads during an AC power failure. AEPW will work with the TG, TI and TEEU Requesters to determine proper sizing and requirements for the DC system. The DC station service system shall be no smaller than that determined by AEPW as the minimum size required in joint facilities. 6.1.12 Fusing of Potential Transformers is AEPW’s general rule that fuses should be used in both the primary and secondary circuits of potential transformers. Secondary fuses should be applied with potential transformers to protect the transformer against high impedance faults on the secondary circuit of the transformer. It is general practice to omit the fuses on the connections to grounded terminals of potential transformers. This practice is essential in the case of single primary bushing type potential transformers. In addition for certain applications involving regulators or protective relays, where the continuity of excitation to these devices is more important than the possibility of damage to the transformer, it is customary to omit the fuse. 6.1.13 SCADA / RTU - A transmission-specific remote terminal unit (RTU) is required for all transmission interconnections. In addition, a generation-specific RTU may also be required at TG Requester’s facilities for AEP’s generation-specific supervisory control and data acquisition (SCADA); for more detail see Section 8.6. For additional information see Appendix H (AEP SCADA RTU Requirements at Transmission Interconnection Facilities – Verification of latest revision required). 6.1.14 Control Cable - AEPW recommends that all control cables be shielded with both ends grounded. It is also recommended. Historically, AEPW substation control cable has been 20 mils of polyethylene insulation covered with 10 mils of color-coded polyvinyl chloride (PVC) with an outer PVC jacket and #10 copper stranded conductors. The color coding is to be in accordance with the below table Method 1, Table K-1 Number of Conductors 1 2 3 4 5 6 7 8 9 Base Color Black White Red Green Orange Blue White Red Green TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System First Tracer or Stripe Black Black Black TP-0002 Rev. 3 Page 19 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 10 Orange Black 11 Blue Black 12 Black White Cable to be used for SCADA indication and control by AEPW is to be shielded 20/10 utilizing #18 conductors and the K1 color. Each cable shall consist of twisted black and white numbered pairs (labeled Pr #1, 2, etc.). Cable tabulations will be prepared for any location where OPCO facilities and TG, TI and TEEU Requester’s facilities are located in the same yard or interconnections will be made between the two adjacent facilities. Each of the OPCO’s has standards for labeling control cables for safety reasons and prevention of misoperations. The Requester who must follow NEC color codes shall end wrap each interconnect control cable with the appropriate OPCO’s standard color code tape. The following tables shows what presently exist in each OPCO; however, when a standard does not exist the typical template will be used. DISTRIBUTION BREAKER - RELAY INSIDE CONTROL HOUSE No. of Wire No. of Cables Conductors Guage Purpose 1 4/c #10 DC Supply 1 4/c #10 AC Supply 1 12/c #10 Control/Relaying 1 12/c #10 Spare 1 4/c #10 CTs 2 4/c #10 Spare for CTs 1 12/c #10 Telemetering (SWEPCO Only) 1 (Note 1) 4/c #10 Bus Differential (CT) 1 (Note 2) 4/c #10 Transformer Differential (CT) Note 1: Use this cable/conduit in case of a bus differential scheme Note 2: Use this cable/conduit in case of a transformer differential scheme Conduit No. 1 1 1 1 1 1 1 2 3 DISTRIBUTION BREAKER - RELAY IN YARD (LAST ON COMMUNICATION LOOP) No. of Wire Conduit Conductors Guage No. No. of Cables Purpose 1 4/c #10 DC Supply 1 1 4/c #10 AC Supply 1 1 12/c #10 Control 1 1 12/c #10 Spare 1 1 4pr #16 RTU Communication 1 2 4/c #10 Spare for CTs 1 1 12/c #10 Telemetering (SWEPCO Only) 1 1 4pr #16 RTU Communication 2 1 4/c #10 PT 3 1 (Note 1) 4/c #10 Bus Differential 4 1 (Note 2) 4/c #10 Transformer Differential 5 Note 1: Use this cable/conduit in case of a bus differential scheme Note 2: Use this cable/conduit in case of a transformer differential scheme TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System Conduit Size 4" 4" 4" 4" 4" 4" 4" 1.25" 1.25" Conduit Size 4" 4" 4" 4" 4" 4" 4" 1.25" 1.25" 1.25" 1.25" TP-0002 Rev. 3 Page 20 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. DISTRIBUTION BREAKER - RELAY IN YARD No. of No. of Cables Conductors Wire Guage Purpose 1 4/c #10 DC Supply 1 4/c #10 AC Supply 1 12/c #10 Control 1 12/c #10 Spare 2 4/c #10 Spare for CTs 1 12/c #10 Telemetering (SWEPCO Only) 1 4pr #16 RTU Communication 1 4pr #16 RTU Communication 1 4/c #10 PT 1 (Note 1) 4/c #10 Bus Differential 1 (Note 2) 4/c #10 Transformer Differential Note 1: Use this cable/conduit in case of a bus differential scheme Note 2: Use this cable/conduit in case of a transformer differential scheme COUPLING CAPACITOR POTENTIAL DEVICE No. of No. of Cables Conductors Wire Guage 1 7/c #10 1 7/c #10 1 4/c #10 1 Coaxial BUS POTENTIAL CABINET No. of No. of Cables Conductors Purpose PT PT Spare AC (heater) Carrier only Conduit No. 1 1 1 1 1 1 2 3 4 5 6 Conduit Size 4" 4" 4" 4" 4" 4" 1.25" 1.25" 1.25" 1.25" 1.25" Conduit No. 1 1 1 2 Conduit Size 2" 2" 2" 1.25" Wire Guage Purpose Conduit No. Conduit Size 1 7/c #10 PT 1 2" 1 7/c #10 PT Spare 1 2" Purpose Conduit No. Conduit Size TRANSMISSION BREAKER - NON EHV No. of No. of Cables Conductors Wire Guage 1 4/c #10 DC Supply 1 4" 1 4/c #10 AC Supply 1 4" 1 12/c #10 Control & Relaying 1 4" 1 12/c #10 Spare 1 4" 1 8pr #16 Alarms 1 4" 1 4pr #16 RTU Communication 1 4" 2 or 4 (Note 1) 4/c #10 CTs 1 4" 1 4/c #10 Spare for CTs 1 4" 1 (Note 2) 4/c #10 Bus Differential (CT) Primary 2 1.25" 1 (Note 2) 4/c #10 Bus Differential (CT) Backup 3 1.25" TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 21 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Note 1: (4) if low impedance scheme is used. (2) if high impedance or summation scheme is used for differential Note 2: In case of a summation or high impedance bus differential scheme POWER TRANFORMERS No. of Conductors No. of Cables 4 (Note 1) 4/c 1 4/c 1 4/c 1 4/c 1 4/c 1 8pr 1 8pr 1 4/c Wire Guage #10 #10 #10 #10 #10 #16 #16 #6 Purpose CTs CTs Spare Neutral CT LTC Potential Sudden Pressure Relay Alarms Spare for Alarms AC for fans and pump Conduit No. 1 1 1 1 1 1 1 2 Conduit Size 4" 4" 4" 4" 4" 4" 4" 1.25" Note 1: In case a bus or transformer differential scheme is used that requires summation. Use 1.25" conduit for each CT that is going to differential cabinet in yard FREE STANDING CT CABINET No. of Cables 1 1 1 No. of Conductors 4/c 4/c 4/c Wire Guage #10 #10 #10 Purpose CT CT Spare AC (heater) Conduit No. 1 1 1 Conduit Size 2" 2" 2" No. of Conductors 4/c 4/c Wire Guage #10 #6 Purpose TCC PSO, TNC, SWECPO Conduit No. 1 1 Conduit Size 1.25" 1.25" Purpose AC Spare Conduit No. 1 1 Conduit Size 2" 2" FILTER TRUCK RECEPTACLE No. of Cables 1 1 STATION SERVICE No. of No. of Cables Conductors Wire Guage 3 (Note 1 1 #2 - 2/0 1 (Note 1) 1 #2 - 2/0 Note 1: Use 1.25" conduit for #2 and 2" conduit for 2/0 TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 22 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. CIRCUIT SWITCHER Wire Guage #10 #10 #10 #10 #16 Purpose AC DC Control Control Spare Alarms Conduit No. 1 1 1 1 1 Conduit Size 3" or 4" 3" or 4" 3" or 4" 3" or 4" 3" or 4" MOTOR OPERATED AIR BREAK SWITCH No. of No. of Cables Conductors Wire Guage 1 4/c #10 1 4/c #10 1 12/c #10 1 12/c #10 Purpose AC DC Control Control Spare Conduit No. 1 1 1 1 Conduit Size 3" or 4" 3" or 4" 3" or 4" 3" or 4" No. of Cables 1 1 1 1 1 No. of Conductors 4/c 4/c 12/c 12/c 8pr TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 23 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 6.1.15 Capacitors - Transmission capacitor banks in AEPW system are usually connected single wye. Size will vary from 5 to 50 MVARs. A resistive potential device connected in the neutral of the bank to sense any imbalances caused by pack failures along with a Vee-switch ahead a capacitor switcher to provide for a means visible of disconnecting it from the circuit. 6.1.16 Substation Power Transformer - The following table list the typical transformer BIL and Percent Impedance Voltages drop at Self-Cooled (OA) Ratings of the power transformers used by AEPW. High Voltage BIL (Without LTC) (With LTC) Low Voltage 480 V Low Voltage Low Voltage 2400 V 2400 V and Above and Above 60-110 5.75 * 5.5 * 150 6.75 6.5 7.0 200 7.25 7.0 7.5 250 7.75 7.5 8.0 350 8.0 8.5 450 8.5 9.0 550 9.0 9.5 650 9.5 10.0 750 10.0 10.5 * For a transformer greater than 5000 KVA self-cooled, these values should be the same as those shown for 150 kV HV BIL. (kV) 6.1.17 AEPW Standard Breaker Ratings Used on the AEPW System - The following ratings are intended to cover any application on the AEPW system. The “Item #” refers to the number used to identify each breaker within the AEPW Circuit Breaker Specification. Item # Voltage Class (kV) 1A 1B 1C 2A 2B 3A 4A 5A 5B 5C 5D 5E 5F 5G 5H 6A 6B 7A 7B 7C 7D 15.5 15.5 15.5 25.8 25.8 38 72.5 145 145 145 145 145 145 145 145 169 169 362 362 362 362 Continuous Current (A) 1200 2000 2000 1200 2000 1200 3150 2000 3000 2000 3000 4000 2000 3000 4000 3000 3000 2000 3000 2000 3000 Interruptible Current (kA) 20 20 25 20 20 20 40 40 40 63 63 63 80 80 80 40 63 40 40 63 63 TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System BIL (kV) 110 110 110 150 150 200 350 650 650 650 650 650 650 650 650 750 750 1300 1300 1300 1300 TP-0002 Rev. 3 Page 24 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 6.1.18 Switches - AEPW switch specifications are as follows: a) Switches will be designed to withstand a 150 mph wind loading and ANSI ice loading. Switches shall have limited flex, keeping it in a static position such that high resistance connections will not be created. b) Temperature rise for switches will be ANSI standard. c) All make-break contact surfaces will be silver-to-silver and replaceable. d) Roller, ball, or needle bearings with zert grease fittings are the only acceptable types. 6.1.19 CT’s, PT’s, CCVT’s, & Wavetraps: Wavetrap Specifications a) Provide with resonant type tuning pack b) Units to be factory tuned c) 4-hole NEMA line terminals on both ends d) Bird barriers both ends e) Corona rings required at voltages 230 kV and above f) Standard ampere ratings range from 800 to 2000 amps. g) Specify - single, double, or wide band frequency range. l) Standard frequencies for wide band traps ranges are 50 - 150 kHz, 70 - 200 kHz, and 100 - 300 kHz. Consult with the AEPW Project Manager for frequency requirements and ampere rating. Coupling Capacitors with Voltage Transformers Specifications a) Base to contain a case ground terminal case ground terminal b) Base and metal parts to be painted with weather resistant ANSI-70 gray paint c) Base and metal parts to be stainless steel or aluminum for corrosive environment d) Coupling capacitor porcelain housing to be ANSI-70 gray e) Top cover to be furnished with a 4-hole NEMA line terminal unless used as a support for the line trap, where as a 5” bolt circle pattern NEMA is required. f) Voltage transformer rated at 150 VA output at marked relaying ratios per ANSI C93.2 g) Base to contain a potential grounding switch and a 1.5” conduit nipple for potential lead exit. h) Two secondary windings are required. Each winding shall have at least two output voltages achieved by means of a tap (115/67.7v). i) If carrier accessories are required, the base is to contain: Drain coils, choke coil, carrier grounding switch and gap, and a carrier lead-in bushing. j) Tuners are required with carrier and should be designed to pass carrier frequencies specified by AEPW System Protection Department. If a separate enclosure is used to mount the tuner it shall be equipped with a 120 VAC heater. Voltage Transformers Specifications - Voltage transformers shall conform to NEMA and ANSI standards in all respects. Low voltage PT’s are to be dry-type single bushing transformers with a ±0.3% metering accuracy for burdens W, X, Y, and Z. High voltage PT’s are to be oil-filled transformers, with a ±0.3% metering accuracy for burdens W, X, Y, and ZZ for line to ground connections, and will include the following: a) Base and metal parts to be painted with weather resistant ANSI-70 gray paint b) Base and metal parts to be stainless steel or aluminum for corrosive environment c) Top cover to be furnished with a 4-hole NEMA terminal. d) Base shall be equipped to accommodate a minimum of two (2) conduit entrances. e) Two secondary windings are required. Each winding shall have at least two output voltages achieved by means of a tap. (Check substation for special requirements.) Current Transformers Specifications - The current transformers shall conform to NEMA and ANSI standards in all respects. Low voltage CT’s can be window or terminal type with a metering accuracy class TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 25 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. of ±0.3% at specified burden ratings. Relay class may be used if revenue meters are not needed. High Voltage CT’s shall be outdoor type; freestanding, oil or SF6 filled and shall include the following: a) Base and metal parts to be painted with weather resistant ANSI-70 gray paint b) Base and metal parts to be stainless steel or aluminum for corrosive environment c) Base shall be equipped to accommodate a minimum of two (2) conduit entrances. d) Manufacturer shall provide a ground point for grounding the case. e) Bushing shall be one-piece porcelain, and ANSI-70 gray. f) Bushings shall meet ANSI standards for the type and class required. g) If oil filled, oil to be certified non-PCB. h) If oil filled, CT’s shall have a visual indication of oil level. i) If gas filled, CT’s shall have approved gas density mounting devices for visual indication of the gas density, which can be read from ground. 6.1.20 INSULATION - Equipment utilized in substations shall comply with the following BIL standard: Basic Lightning Impulse Insulation Level(BIL) (kV rms) at System kV listed below 12.47 13.8 25 34.5 Description 2Wdg Xfmr Internal BIL 110 110 150 150 2Wdg Xfmr Bushing BIL 110 110 150 150 Bus/Switch Support BIL 110 110 150 150 Circuit Breaker Bushing BIL 110 110 150 150 Auto Xfmr Internal BIL 110 110 150 150 Auto Xfmr Bushing BIL 110 110 150 150 Description 69 Basic Lightning Impulse Insulation Level(BIL) (kV rms) at System kV listed below 115 138 161 230 345 2Wdg Xfmr Internal BIL 350 550 550 650 750 1050 2Wdg Xfmr Bushing BIL 350 650 650 750 900 1300 Bus/Switch Support BIL 350 550 550 650 900 1300 Circuit Breaker Bushing BIL 350 650 650 750 900 1300 Auto Xfmr Internal BIL 350 550 550 650 750 1050 Auto Xfmr Bushing BIL 350 650 650 750 900 1300 In areas, classified as “Corrosive Environments”, insulator and bushings will be supplied with high creep skirts. The BIL rating of the insulator need not be increased, but the total creepage must meet the following requirements: Minimum External Creepage Distance (inch) Equipment Voltage BIL AEP Creepage Required ANSI C37.01.06 Rating (kV) (kV) (Reference Only) 15.5 110 17 9 25.8 150 26.5 15 38 200 - 22 TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 26 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 72.5 350 72 42 121 550 - 70 145 650 133 84 169 750 - 93 242 900 - 140 362 1300 318 209 6.1.21 Foundations - Foundations shall be proportioned to resist the maximum calculated structure and equipment loads using site-specific soil parameters. 6.1.22 Structure Loading – Structures shall be designed to resist all applied loads including but not limited to conductor tension, wind, ice, and short circuit forces. In addition to strength requirements, structures shall be proportioned such that the load-induced deflections do not hinder the functionality of the structure and the equipment it supports. For a proposed facility on the OPCO-side of the point of service, specifically any dead-end structure and foundation in an existing OPCO substation, AEPW will design and construct such facility. AEPW/OPCO will provide a point of attachment on the dead-end structure to connect the proposed facility to existing OPCO substation. The following are requirements are used by AEPW in the design of the substation facilities. All design parameters follow the rules set forth by the “National Electric Safety Code” (NESC); ASCE 7, “Minimum Design Loads for Buildings and Other Structures”; and other accepted industry practices. 6.1.22.1 Equipment Structures - AEPW recommends that TG, TI, and TEEU Requester’s facilities located within approximately 140 miles of the Gulf of Mexico be designed for a minimum basic wind speed equal to 135 mph. AEPW recommends that TG, TI, and TEEU Requester’s facilities located in all other areas of the OPCO’s service territory be designed for a minimum basic wind speed equal to 90 mph. 6.1.22.2 Dead-End Structures – Dead-end structures must be designed to the conductor, wind, and ice loading conditions and strength requirements described in Part 25 of the NESC. A minimum of three loadings conditions shall be satisfied: NESC Heavy Loading, Grade B Construction Extreme Wind, using the basic wind speed of 90 mph or 135 mph as appropriate for the geographical area in which the facility will be located Combined Wind and Ice, as defined in Part 25 of the NESC 6.1.23 Steel in Coastal and Industrial Corrosive Environments – AEPW recommends that the average coating thickness of hot dip galvanizing for structures installed in coastal corrosion or industrial corrosion environments shall be 5.0 mils. Coastal regions in Texas are defined as the area bounded by the Gulf of Mexico and US Highway 77. All other structures shall be hot dip galvanized in accordance with ASTM A 123. 7.0 TRANSMISSION LINE DESIGN, LOADING, CLEARANCE, INSULATION AND STRUCTURAL DESIGN REQUIREMENTS 7.1 TRANSMISSION LINE DESIGN REQUIREMENT - Upon determination of the point of service, the design and construction of new transmission line facilities on the OPCO electric system necessary to TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 27 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. connect to TG, TI and TEEU Requester’s facilities shall be done in accordance with the following criteria. 8.0 7.1.1 New Transmission Lines Serving only the TG, TI and TEEU Requester and that will not be owned by the OPCO - New Transmission Lines that are “taps” of existing transmission circuits built solely to serve the TG, TI and TEEU Requester or otherwise do not involve carrying OPCO services to other customers or delivery points and will not be owned by the OPCO may be built to any criteria determined by the facility owner and operator so long as it meets the minimum requirements of: • ANSI-C2, National Electric Safety Code (NESC), latest edition, and • NFPA 70, National Electrical Code (NEC), latest edition, and • Governmental agencies as needed to obtain permits to construct the line (Ex. U.S Army Corps of Engineers, FAA, etc.). • Any additional applicable state and local code or criteria. 7.1.2 New Transmission Lines serving the TG, TI and TEEU Requester and integrated in the OPCO Network - New Transmission Lines that, in addition to serving the TG, TI and TEEU Requester involve carrying OPCO services to other customers or delivery points or will be owned by the OPCO shall, in addition to the criteria indicated above, be designed in accordance with AEP System Standard TLES-10, “Clearances, Mechanical Loadings and Load Factors Applicable to Structures, Foundations Hardware, Insulators, Conductors Ground wire and Line Design” (latest revision). METERING AND SCADA REQUIREMENTS 8.1 TRANSMISSION INTERCONNECT METERING REQUIREMENTS For all transmission interconnections, a transfer of power between AEPW and the TG, TI or TEEU Requester system shall be metered at the point of interconnection. The power transfer between the OPCO and the TG, TI and TEEU Requester will be metered with bi-directional metering for bi-directional interconnections. Power flow from AEPW to the TG, TI and TEEU Requester will be designated as “Out” kWh. “Out” kWh is considered positive and “In” kWh is considered negative. The same conventions will be observed on the reactive power. Each of the four quantities will be recorded separately. Recording of TG, TI and TEEU Requester energy usage for the billing period will be determined by AEPW. If requested by the TG, TI and TEEU Requester, and if available from the AEPW metering equipment, the following information can be provided to the TG, TI and TEEU Requester at the point of interconnection. If not available from the OPCO’s metering equipment, the following information can be provided to the TG, TI and TEEU Requester at the TG, TI and TEEU Requester’s expense: 1) “Out” kWh 2) “In” kWh 3) “Out” kVARh 4) “In” kVARh 5) +/- kW 6) +/- kVAR If requested by the TG, TI and TEEU Requester, MW and MVAR transducers shall be 3-element transducers with an accuracy of ±0.2% or better. For a TG, TI and TEEU Requester having more than one point of interconnection (e.g., two lines), independent bidirectional metering is required on each interconnecting circuit. All current transformers shall conform to a minimum of ±0.3% metering accuracy class or better. Voltage transformers shall conform to a minimum of ±0.3% metering accuracy class or better. The current transformers and TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 28 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. voltage transformers used to meter bi-directional power flow shall meet the latest ANSI C57.13 requirements for instrument transformers. All affected parties shall be involved in engineering changes of interconnect metering equipment from project inception. All parties must be notified so a mutually agreeable time can be set for the changes. All parties involved must be satisfied to the making of any changes. Metering and Operation personnel of all affected parties shall be notified at least 48 hours in advance, or at a mutually acceptable advance notice, prior to any calibrations or maintenance. In emergency conditions, the owner of the metering installation may make necessary repairs with notification to affected parties within 24 hours. Copies of the repair and calibration records shall be forwarded to all involved parties. For additional information see Appendix G (AEP Metering Requirements for Transmission Interconnection Facilities – verification of latest revision required). 8.2 TRANSMISSION INTERCONNECT SCADA REQUIREMENTS The following information shall be supplied by the TG, TI and TEEU Requester for each point of interconnection and connected to the AEPW’s recording equipment and the transmission-specific remote terminal unit (RTU) used for the point of interconnection. Except where specified as hardwired, RTU inputs shall be supplied from an IED (Intelligent Electronic Device), from an AEPW–approved interface device, or hardwired. RTU inputs from an IED or an AEPW–approved interface device shall be Ethernet or RS-485 using DNP 3.0 protocol. 1) Status Points a) Transmission line breaker status (required for each TG, TI and TEEU Requester line) b) IED failure (required for each IED sourcing a required point) c) IED communications failure (required for each IED sourcing a required point) d) Battery charger trouble (required for the battery powering the RTU) e) Battery charger AC power failure (required for the battery powering the RTU) f) Smoke alarm (required for the structure housing the RTU) g) Fire or high temperature alarm (required for the structure housing the RTU) 2) Analog Points a) MW from each TG, TI and TEEU Requester line b) MVAR from each TG, TI and TEEU Requester line c) Voltage per phase from each TG, TI and TEEU Requester line d) Current per phase from each TG, TI and TEEU Requester line 3) Hourly Accumulation Points a) MWh IN from each TG, TI and TEEU Requester line b) MWh OUT from each TG, TI and TEEU Requester line c) MVARh IN from each TG, TI and TEEU Requester line d) MVARh OUT from each TG, TI and TEEU Requester line All Supervisory Control and Data Acquisition (SCADA) equipment shall be satisfactory to AEPW. For additional information see Appendix H (AEP SCADA RTU Requirements at Transmission Interconnection Facilities – verification of latest revision required). TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 29 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 8.3. COMMUNICATION REQUIREMENTS 8.3.1 CIRCUIT REQUIREMENTS TG, TI and TEEU Requesters shall be responsible for procuring and paying for communication circuits for use by AEPW. The TG, TI and TEEU Requester shall be responsible for confirming with AEPW the project-specific circuit requirements and requesting specific AEPW addresses and AEPW contact names in preparation for issuing communication circuit orders with the TG, TI or TEEU Requester's telecommunication service provider of choice. These communication circuits shall be leased telephone company circuits or other media satisfactory to AEPW. For each telephone company circuit leased by the TG, TI and TEEU Requester, the TG, TI and TEEU Requester shall provide AEPW and the telecommunication service provider with advanced authorization for communication circuit maintenance, allowing AEPW and any of its affiliates and subsidiaries to monitor the circuit, report trouble and take corrective action with the telecommunication service provider, at the TG, TI or TEEU Requester's expense, to maintain circuit reliability. The communication circuits described here shall be operational and commissioned by AEPW prior to AEPW providing a continuous power source to the interconnection facility. Typical facility circuit requirements include the following: 1) RTU Communications Circuit - This is a leased circuit from the demark associated with the RTU at the TG, TI or TEEU Requester's facility to an AEPW Dispatch office; this circuit is to be ordered and paid for by the TG, TI or TEEU Requester. One circuit is required for each RTU. This circuit will be utilized by AEPW to communicate with the RTU and, if applicable, the fault recorder. The required circuit is a 56 Kbps Frame circuit with DDS interface at the RTU end and DDS interface at the AEPW Dispatch office end. 2) Voice Dispatch Circuit - This is a leased circuit from the TG Requester's facility plant operators to an AEPW Dispatch office. If the TG Requester's facility plant operators are not located on the plant site, then the circuit must be terminated at the actual location of the plant operators. This circuit is required of the TG Requester where the total plant generation capacity is equal to or greater than 50 MVA. This circuit is to be ordered and paid for by the TG Requester. The required circuit is a Bell 428, also known as an OSPA 428. This circuit is a two-point off-premise station voice-grade two-wire analog facility with loop start signaling at the AEPW Dispatch office end. For circuit design and ordering purposes, the circuit origination is to be at the AEPW Dispatch office; the circuit termination is to be at the actual location of the TG Requester's facility plant operators. 3) Dial-Up Circuit - This is a standard business telephone line (with a 10-digit telephone number) with long distance provisioning to be ordered and paid for by the TG, TI or TEEU Requester. The requirement for one or more Dial-Up Circuits will be determined by AEPW on a projectspecific basis. This circuit may be required for interconnect meter reading, system protection equipment interrogation and access to the fault recorder. If the interconnect metering, system protection equipment and fault recorder are located at multiple sites, then multiple Dial-Up Circuits may be required. If these devices are located at the same site, one Dial-Up Circuit may suffice for dial-up access. (In this case, the TG, TI or TEEU Requester is to receive approval from AEPW prior to installing a telephone switch to share one Dial-Up Circuit among multiple devices.) 8.3.2 DEMARK REQUIREMENTS For all telephone company circuits leased into a substation, demarcation equipment (demark) satisfactory to AEPW shall be installed and maintained. The demark will provide the interface between the telephone company’s service cable and the substation. The demark design shall accommodate 24x7 accessibility by AEPW personnel without escort from telephone company personnel, the TG, TI or TEEU Requester, facility operator or land owners. The demark design shall accommodate 24x7 accessibility by telephone company personnel without escort from AEPW personnel, the TG, TI or TEEU Requester, facility TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 30 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. operator or land owners. The demark shall be located on the substation ground grid and accessible from outside the substation fence or through a secured personnel gate. The TG, TI and TEEU Requester shall be responsible for providing surge protection satisfactory to AEPW on the communications cable between the demark and the substation control building. The demark described here shall be operational and commissioned by AEPW prior to AEPW providing a continuous power source to the interconnection facility. 8.3.3 HIGH VOLTAGE ISOLATION REQUIREMENTS If required by the OPCO or the telephone company, high voltage isolation (HVI) equipment for all telephone company circuits leased into a substation shall be installed and maintained. The HVI equipment shall be designed to adequately protect against ground potential rise and shall be satisfactory to AEPW and the telephone company. The HVI equipment design shall accommodate 24x7 accessibility by AEPW personnel without escort from telephone company personnel, the TG, TI or TEEU Requester, facility operator or landowners. The HVI equipment design shall accommodate 24x7 accessibility by telephone company personnel without escort from AEPW personnel, the TG, TI or TEEU Requester, facility operator or landowners. The HVI equipment shall be located on the central office (telephone company) side of the demark (see Section 8.3.2). The HVI equipment shall be located on the substation ground grid and accessible from outside the substation fence or through a secured personnel gate. The HVI equipment described here shall be operational and commissioned by AEPW prior to AEPW providing a continuous power source to the interconnection facility. 8.4 RTU REQUIREMENTS A transmission-specific remote terminal unit (RTU) is required for all transmission interconnections. In addition, a generation-specific RTU may be required at TG Requester’s facilities for AEPW’s generation-specific Supervisory Control and Data Acquisition (SCADA); for more information see Section 8.6. The RTU protocol from the RTUs to the AEPW Dispatch office shall be satisfactory to AEPW. The TG, TI and TEEU Requester shall marshal all their RS-485 and hardwired RTU inputs at a marshalling cabinet (interface terminal block or interface cabinet) satisfactory to AEPW. The TG, TI and TEEU Requester shall engineer, procure, construct and own the marshalling cabinet, wire to the marshalling cabinet from the various generation or substation equipment, provide AEPW with documentation identifying the location of generation or substation SCADA points wired to the marshalling cabinet, and provide AEPW with terminals at the marshalling cabinet from which to wire to the RTU. The TG, TI and TEEU Requester shall provide a dedicated station DC breaker for each RTU. For additional information see Appendix H (AEP SCADA RTU Requirements at Transmission Interconnection Facilities – verification of latest revision required). Prior to AEPW providing a continuous power source to the interconnection facility, the transmission-specific RTU and the generation-specific RTU described here shall be operational with AEPW-required RTU functions commissioned by AEPW. 8.5 GENERATION METERING REQUIREMENTS For generation metering, the “In” / “Out” power flow is referenced from AEPW or the grid’s perspective. Normal MW generation will be designated as “In” MW. “In” MW is considered negative. Backfeed power from the OPCO to the TG Requester is “Out” MW and is considered positive. The same conventions will be observed on the reactive power. Meters are required for generation gross and station use auxiliaries. Unless used for transmission interconnect metering (see Section 8.1), all voltage and current transformers used for generation metering shall conform to relay accuracy class or better. MW and MVAR transducers shall be 3-element transducers with an accuracy of ±0.2% or better. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 31 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. For additional information see Appendix G (AEP Metering Requirements for Transmission Interconnection Facilities – verification of latest revision required). For those locations where it may be possible to switch the generation between power pools, there will be unique requirements for metering; such requirements will be determined by AEPW on a project-specific basis. 8.6 GENERATION SCADA REQUIREMENTS For TG Requesters where the total plant generation capacity is equal to or greater than 50 MVA, a generationspecific RTU is required at TG Requester’s facilities for AEPW’s generation-specific SCADA, and the following SCADA information shall be required. A specific RTU data interface list will be developed by AEPW as a part of each generation project based upon the project's electrical configuration. For such purpose the TG Requester shall be responsible for providing AEPW with metering and relaying one-line diagrams of the generation and substation facilities. The generation-specific RTU located at the TG Requester's facility will supply the following SCADA information to AEPW: 1) Control Points – RTU inputs shall be hardwired. a) Trip (required for one or more generation or transmission line breakers to allow AEPW to trip all generation units during system emergencies) 2) Status Points – Except where specified as hardwired, RTU inputs shall be supplied from an IED (Intelligent Electronic Device), from an AEPW–approved interface device, or hardwired. RTU inputs from an IED or an AEPW–approved interface device shall be Ethernet or RS-485 using DNP 3.0 protocol. a) Generator breaker status (hardwired for each breaker where Trip control is required) b) Circuit switcher / line switch status (“a” and “b” contacts) c) Transformer high-side breaker status (hardwired for each breaker where Trip control is required) d) Transformer high-side motor operated switch status (“a” and “b” contacts) e) Transmission line lockout relay operated f) Transmission line lockout relay failure g) Auxiliary breaker status h) Capacitor bank breaker/switch status i) Supervisory cutoff (hardwired for each breaker where Trip control is required) j) Breaker failure lockout status (hardwired for each breaker where Trip control is required) k) Breaker critical alarm (required for each breaker where Trip control is required, combine critical alarms for each breaker) l) Transformer critical alarm (combine critical alarms for each transformer) m) Transformer primary lockout relay operated n) Transformer primary lockout relay failure o) Transformer backup lockout relay operated p) Transformer backup lockout relay failure q) IED failure (required for each IED sourcing a required point) r) IED communications failure (required for each IED sourcing a required point) s) Battery charger trouble (required for the battery powering the RTU) t) Battery charger AC power failure (required for the battery powering the RTU) u) Smoke alarm (required for the structure housing the RTU) v) Fire or high temperature alarm (required for the structure housing the RTU) w) Generator automatic voltage regulator (AVR) status x) Fault recorder trouble alarm TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 32 of 98 CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 3) Analog Points – Except where specified as hardwired, RTU inputs shall be supplied from an IED, from an AEPW–approved interface device, or hardwired. RTU inputs from an IED or an AEPW–approved interface device shall be Ethernet or RS-485 using DNP 3.0 protocol. a) Generator gross MW (required for each generation unit) b) Generator gross MVAR (bi-directional values required for each generation unit) c) Generator station use MW auxiliary (required for each auxiliary transformer) d) Generator station use MVAR auxiliary (bi-directional values required for each auxiliary transformer) e) Station frequency HZ (for those stations where a common bus does not exist between multiple generation units, individual unit frequency points will be required) f) Voltage per phase where the facility connects to transmission system g) Voltage per phase for each winding of each transformer h) Current per phase for each winding of each transformer i) MW for each winding of each transformer j) MVAR for each winding of each transformer For additional information see Appendix H (AEP SCADA RTU Requirements at Transmission Interconnection Facilities – verification of latest revision required). For those locations where it may be possible to switch the generation between power pools, there will be unique requirements for SCADA; such requirements will be determined by AEPW on a project-specific basis. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 33 of 98 Appendix A CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. APPENDIX A A: AEP Power Quality Requirements TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 34 of 98 Appendix A CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. AEP Power Quality Requirements This document summarizes the AEP policy on power quality requirements, which include voltage flicker, harmonic distortion and other factors, for customers connected to the AEP Transmission System. The term Company is defined as American Electric Power (AEP). The term Customer is defined as the party connected to the AEP System. POINT OF COMPLIANCE The point where the Customer connects to the Company system will be the point where compliance with AEP power quality requirements is evaluated. VOLTAGE FLICKER CRITERIA The random voltage fluctuations (flicker) occurring at the Compliance Point directly attributable to the Customer shall remain within the limits specified in IEEE Standard 1453-2004, “IEEE Recommended Practice for Measurement and Limits of Voltage Fluctuations and Associated Light Flicker on AC Power Systems.” These limits are 0.8 and 0.6 for the PST (short term) and PLT (long term) flicker measures, respectively. PST is the standard reading of a flicker meter, obtained for each 10-minute interval; PLT is derived mathematically (cube root-mean-cube) from twelve consecutive PST readings (see Table 1). The Customer agrees that under no circumstances will it permit the voltage flicker to exceed the Company criteria, whether or not complaints are received or service/operational problems are experienced on the Company sub-transmission or transmission system. Should complaints be received by the Company or other operating problems arise, or should the Customer flicker exceed the Company criteria, the Customer agrees to take immediate action to reduce its flicker to a level at which flicker complaints and service/operational problems are eliminated. Corrective measures could include, but are not limited to, modifying production methods/ materials or installing, at the Customer's expense, voltage flicker mitigation equipment such as a static var compensator. The Company will work collaboratively with the Customer to assess problems, identify solutions and implement mutually agreed to corrective measures. If the Customer fails to take corrective action after notice by the Company, the Company shall have such rights as currently provided for under the ISO/RTO OATT, which may include discontinuing service, until such time as the problem is corrected. HARMONIC DISTORTION CRITERIA The Company also requires that the Customer's operation be in compliance with the Company's Harmonic Distortion Guidelines (see Exhibit 2). These requirements are based on IEEE Standard 519, "IEEE Recommended Practices and Requirements for Harmonic Control in Electric Power Systems". The Customer agrees that the operation of motors, appliances, devices or apparatus served by its facility that result in harmonic distortions in excess of the Company's Requirements will be the Customer's responsibility to remedy immediately, at the Customer's expense, in order to comply with the Company's Harmonic Distortion Requirements. The Company will work collaboratively with the Customer to assess problems, identify solutions, and implement mutually agreed to corrective measures. If the Customer fails to take corrective action after notice by the Company, the Company shall have such rights as currently provided for under the ISO/RTO OATT, which may include discontinuing service, until such time as the problem is corrected. While IEEE Standard 519-1992 recommends that even-numbered harmonic currents be limited to only 25% of the stated values, the requirements established herein are uniform at the full-limit values for both odd and even harmonics. AEP reserves the right to limit the even harmonic currents, as recommended by IEEE Standard 519-1992, if operational problems and/or customer complaints are experienced in the future. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 35 of 98 Appendix A CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. COMMUNICATION INTERFERENCE The total communication interference (I*T product) shall not exceed the level of weighted Amperes, at the Compliance Point, prescribed by IEEE Standard 519-1992 (see Exhibit 2). OTHER REQUIREMENTS A. Electrical Interactions If Power Quality Compliance Monitoring recordings or analytical studies conducted by AEP indicate likely adverse electrical interactions (e.g., resonance) between the connected facility and the AEP System, joint efforts will be undertaken by the Parties to determine the nature and extent of the electrical interaction and to resolve, at no expense to AEP, any likely adverse impacts on the performance of AEP facilities. B. Compliance Assessment To achieve compliance, at least 95% of all recordings within each harmonic measure and 99% within each flicker measure must fall below the applicable limit, i.e., the customer will be in material non-compliance with the AEP Power Quality Requirements if more than 5% of the harmonic voltage and harmonic current recordings and 1% of the flicker recordings exceed the specified limits. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 36 of 98 Appendix A CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. EXHIBIT 1 AEP VOLTAGE FLICKER REQUIREMENTS [Based on IEEE Standard 1453-2004, “IEEE Recommended Practice for Measurement And Limits of Voltage Fluctuations and Associated Light Flicker on AC Power Systems”] Voltage Flicker Measure Maximum Value PST (Short Term) 0.8 PLT (Long Term) 0.6 TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 37 of 98 Appendix A CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. EXHIBIT 2 AEP HARMONIC DISTORTION REQUIREMENTS [Extracted from IEEE/ANSI Standard 519-1992, “IEEE Recommended Practices and Requirements for Harmonic Control in Electric Power Systems.”] 1. HARMONIC VOLTAGE DISTORTION (THDV) LIMITS [Applicable to Transmission Systems] Individual Harmonic Voltage Distortion (%) 3.0 1.5 1.0 Bus Voltage at PCC ≤ 69 kV > 69 kV and ≤ 161 kV > 161 kV Total Voltage Distortion THDv (%) 5.0 2.5 1.5 2. HARMONIC CURRENT DEMAND DISTORTION (TDD) LIMITS [Applicable to Individual Customers at the Point of Common Coupling (PCC)] Maximum Harmonic Current Distortion in Percent of Base Quantity Harmonic Order (Odd Harmonics) V ≤ 69 kV ISC/IL < 11 11 ≤ h < 17 17 ≤ h < 23 23 ≤ h < 35 35 ≤ h TDD <20* 20<50 50<100 100<1000 >1000 4.0 7.0 10.0 12.0 15.0 2.0 3.5 4.5 5.5 7.0 1.5 2.5 4.0 5.0 6.0 0.6 1.0 1.5 2.0 2.5 0.3 0.5 0.7 1.0 1.4 5.0 8.0 12.0 15.0 20.0 0.3 0.5 0.75 1.0 1.25 0.15 0.25 0.35 0.5 0.7 2.5 4.0 6.0 7.5 10.0 0.3 0.45 0.15 0.22 2.5 3.75 69 kV < V ≤ 161 kV <20* 20<50 50<100 100<1000 >1000 2.0 3.5 5.0 6.0 7.5 1.0 1.75 2.25 2.75 3.5 0.75 1.25 2.0 2.5 3.0 161 kV < V <50 ≥50 2.0 3.0 1.0 1.5 0.75 1.15 Even harmonics are limited to 25% of the odd harmonic limits above. * All power generation equipment is limited to these values of current distortion, regardless of actual ISC/IL. where ISC = Maximum short-circuit current at PCC. IL = Load current (fundamental frequency component) at time of maximum metered amount at PCC. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 38 of 98 Appendix A CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Definitions • Harmonic Voltage Distortion is to be normalized to the nominal system voltage and calculated using Equation 1 TOTAL VOLTAGE HARMONIC DISTORTION (THDV) in percent: ∞ THDV = ∑ n=2 V n2 × 100 % Vs (Eq. 1) Where: Vn = Magnitude of Individual Harmonics (RMS) Vs = Nominal System Voltage (RMS) n = Harmonic Order • Harmonic Current Distortion is to be normalized to the customer‘s load current at the time of the maximum metered demand which occurred over the preceding twelve months for existing customers and the customer’s anticipated peak demand for new customers. For existing customers who are increasing their load, the projected demand should be used. The harmonic current demand distortion (TDD) should be calculated using Equation 2. TOTAL CURRENT DEMAND DISTORTION (TDD) in percent: ∞ TDD = ∑ n=2 I I n2 × 100% (Eq. 2) L Where: In = Magnitude of Individual Harmonic (RMS) IL = Load current at the time of the maximum metered demand n = Harmonic Order • PCC – Point of Common Coupling is the location where the customer accepts delivery of electrical energy from the utility. Field Measurements To gauge the acceptability of field measured harmonic distortion, a statistical evaluation of the data is to be performed. Measurements should be taken at five minute intervals or less over a minimum of 24 hours. For the measured data to be considered acceptable, two criteria must be met: 1) 95% of the measured data must fall below the limits stated; and 2) no measure data shall exceed the limits specified by than 50% of the absolute upper limit value. 3. COMMUNICATION INTERFERENCE LIMITS (I*T) Rather than provide specific limits on I*T values, due to the limitations involved, IEEE/ANSI standard 519 outlines the ranges of I*T values for three potential states of telephone interference inflicted by the harmonic components of current and voltage, which are shown in the table below. The actual interference to voice communication systems in proximity to the power system is dependent upon a number of factors not under the control of the utility or customer. These factors will vary from location to location and from time to time as the state-of-the-art of inductive coordination progresses. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 39 of 98 Appendix A CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. IEEE STANDARD 519 – BALANCED I*T GUIDELINES Category Description I*T I Levels most unlikely to cause interference < 10,0000 II Levels that might cause interference 10,000 to 25,000 III Levels that probably will cause interference > 50,000 The limit applicable to AEP is the upper bound limit of the I*T levels that might cause interference on telephone systems. Thus, the customer induced harmonics shall not result in an I*T product to exceed 25,000 weighted amperes per phase, applicable to both the transmission and distribution systems. Residual I*T should also be minimized. Residual I*T is IG*T, where IG is the earth return current and is defined as the difference between the phasor sum of phase currents and neutral current. The I*T calculation is to be performed using Equation 3. The weighting of harmonic currents should conform to the 1960 TIF data shown in the table below. I*T PRODUCT in amperes: K I*T = I*TIF = ∑ (I n =1 n ∗ Wn ) 2 weighted amperes (Eq. 3) Where: I = Current of individual harmonics, RMS T = Telephone Influence Factor (TIF) Wn = Single frequency TIF weighting at frequency n (refer to tables below) K ≤ 42, Maximum harmonic order Frequency Wn Frequency Wn Frequency Wn Frequency Wn 60 0.5 1020 5100 1860 7820 3000 9670 180 30 1080 5400 1980 8330 3180 8740 300 225 1140 5630 2100 8830 3300 8090 360 400 1260 6050 2160 9080 3540 6730 420 650 1380 6370 2220 9330 3660 6130 540 1320 1440 6650 2340 9840 3900 4400 660 2260 1500 6680 2460 10340 4020 3700 720 2760 1620 6970 2580 10600 4260 2750 780 3360 1740 7320 2820 10210 4380 2190 900 4350 1800 7570 2940 9820 5000 840 1000 5000 TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 40 of 98 Appendix B CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. APPENDIX B B: Typical Transmission Tap Supply & Line Looped Supply Configurations Typical Transmission Tap Supply Configurations Figure 1 Radial Line Supply Alternatives - For Facilities below 200 kV Non-Generators - Connected to an Existing Station Figure 2 Radial Line Supply Alternatives - For Facilities below 200 kV Non-Generators - Connected to an Existing Line Typical Transmission Line Looped Supply Configurations Figure 3 Loop Supply Alternatives - For Facilities below 200 kV Non-Generators - Looped Service Typical Generation Connection Configurations Figure 4 Generator Connection Alternatives TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 41 of 98 Appendix B CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 42 of 98 Appendix B CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 43 of 98 Appendix B CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 44 of 98 Appendix B CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Figure 4 Generator Connection Alternatives G eneration C onnections To A E P Transm ission S ystem 1. C onnection To E xisting S tation B us(es) M S tation B us ( F or a double connection, another sim ilar connection can be m ade with any other station bus) G 2. S ingle C onnection To E xisting Line M M G G 3. D ouble C onnection To E xisting Line(s) M M LE G END M M Looping A Single Circuit Line G enerating U nit(s) G Loop ing A Double Circuit Line G C ircuit B reaker G M G G TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System M etering Air Bre ak Switch TP-0002 Rev. 3 Page 45 of 98 Appendix C CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. APPENDIX C C: Electrical Clearances and Equipment Ratings TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 46 of 98 Appendix C CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 47 of 98 Appendix D CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. APPENDIX D D: Generation Abnormal Frequency Operating Allowance TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 48 of 98 Appendix D CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 49 of 98 Appendix E CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. APPENDIX E E: Information Supplied By Generation Owner TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 50 of 98 Appendix E CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Information Supplied By Generator Owner (TG) Name, address, telephone number, and E-mail address of Generator Owner (TG): Title: Name: Company: Address: Phone: __________________ Email: Name of TG Project Manager’s “Single Point of Contact” - individual with authority (equal to Generator Owner) to make day to day decisions regarding the processing of the Interconnection Request with ISO/RTO: Title: Name: Company: Phone: Address: Email: Name, address, telephone number, and E-mail address of individual(s) representing the TG related to technical questions about the design and operation of the proposed Facility: Name: Title: Company: Phone: Address: Email: TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 51 of 98 Appendix E CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Provide the Following data at time of “Kickoff Meeting”: Site Plan (on tax map, USGS Topo map, etc) for Interconnection Customer’s Facilities (Electronic file if available):________________________________________________ Interconnection Customer’s proposed location (if known) for Point of Interconnection (POI) to AEPW system:_________________________________________________ Type (Synchronous, Induction, Inverter, etc), and rating of proposed generator(s): ______________________________________________________ Project Schedule: Backfeed Requirement & Date. _______________________ Generation Testing (1st energy into grid) Dates. , 2____________; 3____________; 4 ____________ Expected Commercial Dates. , 2____________; 3____________; 4 ____________ Confirm/acknowledge Queue MWs (at 920F ambient) & choice of Capacity or Energy-Only rights: MW: Capacity or Energy-Only: Fuel (gas, wind, nuclear, diesel), and technology (steam turbine-generator, combustion turbine-generator, combined / simple cycle etc) for generation:___________________________________________ Estimated maximum and minimum Facility load at Point of Interconnection with generation in service: Maximum __________________ Minimum: __________________ Estimated maximum and minimum Facility load at Point of interconnection without generation in service: Maximum __________________ Minimum: __________________ Estimated maximum net energy to AEPW System: If customer’s facilities are already connected to the AEPW System, provide a one line diagram of existing connection arrangement with existing meter locations identified. Identify meter type (e.g. KWH Revenue, etc.) TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 52 of 98 Appendix E CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. The Generator Owner shall provide copies of the following drawings: One line diagram of Facility electrical arrangement. All potential elementary drawings associated with the protection and control schemes for the generator and interconnection equipment. All current elementary drawings associated with the protection and control schemes for the generator and interconnection equipment. A control elementary of the generator breaker and the interconnection breaker. A three line diagram of generation system. 1. Documentation of all protective device settings shall be provided. The setting documentation shall also include relay type, model/catalog number and setting range. If automatic transfer schemes or unique or special protective schemes are used, a description of their operation should be included. The Company must review and approve the settings of all protective devices and automatic control equipment which: (1) serve to protect the Connective Power Delivery System from hazardous currents and voltages originating from the Facility or (2) must coordinate with protective devices or control equipment located on the Connective Power Delivery System. 2. The following modeling data must be supplied to the Company and/or ISO/RTO to allow necessary interconnection studies to be performed. It is recognized that some of this data may initially be preliminary in nature. Interconnection studies will be based on data submitted. Any changes, or modifications, to this data after the interconnection study has been completed may render the analysis invalid and require re-opening of the interconnection study. It is the Generator Owners responsibility to make the Company and / or ISO/RTO aware of any changes to this data, and to provide final certified test reports and modeling data as soon as it is available. Notes: The One Line Diagram & Three Line Diagram shall include the following information: 3. Equipment names and/or numerical designations for all circuit breakers, contactors, air switches, transformers, generators, etc. associated with the generation as required by the Company to facilitate switching. 4. Power Transformers – name or designation, nominal kVA, nominal primary, secondary, tertiary voltages, vector diagram showing winding connections, tap setting and transformer impedance. A copy of the transformer nameplate and test report can be substituted. 5. Station Service Transformers – Designate phase(s) connected to and estimated kVA load. 6. Instrument Transformers – Voltage and current, phase connections. 7. Surge Arresters/Gas Tubes/Metal Oxide Varistors/Avalanche Diode/Spill Gaps/Surge Capacitors, etc. – Type and Ratings. 8. Capacitor Banks – kVAR rating. 9. Disconnect Switches – Indicate status normally open with a (N.O.) and whether manual or motor operated. Include switch voltage, continuous and interrupting ratings. 10. Circuit Breakers and/or Contactors – Interrupting rating, continuous rating, operating times. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 53 of 98 Appendix E CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 11. Generators(s) – Include nameplate , test report, type, connection, kVA, voltage, current, rpm, PF, impedances, time constants, etc. 12. Point of Interconnection to Connective Power Delivery System and phase identification. 13. Fuses – Manufacturer, type, size, speed, and location. Elementary Diagrams shall include the following information: 1. Terminal designation of all devices – relay coils and contacts, switches, transducers, etc. 2. Relay functional designation – per latest ANSI Standard. The same functional designation shall be used on all drawings showing the relay. 3. Complete relay type (such as CV-2, SEL321-1, REL-301, IJS51A, etc.) 4. Switch contact shall be referenced to the switch development if development is shown on a separate drawing. 5. Switch developments and escutcheons shall be shown on the drawing where the majority of contacts are used. Where contacts of a switch are used on a separate drawing, that drawing should be referenced adjacent to the contacts in the switch development. Any contacts not used should be referenced as spare. 6. All switch contacts are to be shown open with each labeled to indicate the positions in which the contact will be closed. Explanatory notes defining switch coordination and adjustment where mis-adjustment could result in equipment failure or safety hazard. 7. Auxiliary relay contacts shall be referenced to the coil location drawing if coil is shown on a separate drawing. All contacts of auxiliary relays should be shown and the appropriate drawing referenced adjacent to the respective contacts. 8. Device auxiliary switches (circuit breakers, contactor) should be referenced to the drawing where they are used. 9. Any interlocks electromechanical, key, etc., associated with the generation or interconnection substation. 10. Ranges of all timers and setting if dictated by control logic. 11. All target ratings; on dual ratings note the appropriate target tap setting. 12. Complete internal for electromechanical protective relays. Microprocessor type relays may be shown as a “black box”, but manufacturer’s instruction book number shall be referenced and terminal connections shown. 13. Isolation points (states links, PK-2 and FT-1 blocks), etc., including terminal identification. 14. All circuit elements and components, with device designation, rating and setting where applicable. Coil voltage is shown only if different from nominal control voltage. 15. Size, type, rating and designation of all fuses. 16. Phase sequence designation as ABC or CBA. 17. Potential transformers – nameplate ratio, polarity marks, rating, primary and secondary connections (see Guidelines for minimum ratings.) 18. Current transformers (including aux. CT's) – polarity marks, rating, tap ratio and connection. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 54 of 98 Appendix E CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Generator & Generator Step-up Transformer Data Impedance data required immediately. Remaining data must be provided prior to start of Impact Study analysis. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 55 of 98 Appendix E CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Unit Capability Data Gross MW Output GSU MW Losses Unit Auxiliary Load MW Station Service Load MW Net MW Capacity Net MW Capacity = (Gross MW Output - GSU MW Losses – Unit Auxiliary Load MW – Station Service Load MW) ISO/RTO Queue Letter/Position/Unit ID: ______________________________________________________ Primary Fuel Type: _______________________________________________________________________ Maximum Summer (92º F ambient air temp.) Net MW Output: _____________________________________ Maximum Summer (92º F ambient air temp.) Gross MW Output: ___________________________________ Minimum Summer (92º F ambient air temp.) Gross MW Output ____________________________________ Maximum Winter (30º F ambient air temp.) Gross MW Output: ____________________________________ Minimum Winter (30º F ambient air temp.) Gross MW Output: _____________________________________ Gross Reactive Power Capability at Maximum Gross MW Output (Leading and Lagging): _______________ *** Please submit Reactive Capability Curve when available Individual Unit Auxiliary Load at Maximum Summer MW Output (MW/MVAR):______________________ Individual Unit Auxiliary Load at Minimum Summer MW Output (MW/MVAR): ______________________ Individual Unit Auxiliary Load at Maximum Winter MW Output (MW/MVAR): _______________________ Individual Unit Auxiliary Load at Minimum Winter MW Output (MW/MVAR): _______________________ Station Service Load (MW/MVAR): __________________________________________________________ Please provide any comments on the expected capability of the unit: TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 56 of 98 Appendix E CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Unit Generator Dynamics Data ISO/RTO Queue Letter/Position/Unit ID: ____________________________________________________ MVA Base (upon which all reactance, resistance and inertia are calculated): _________________________ Nominal Power Factor:___________________________________________________________________ Terminal Voltage (kV): __________________________________________________________________ Unsaturated Reactance (on MVA Base) Direct Axis Synchronous Reactance, Xd(i _____________________________________________________ Direct Axis Transient Reactance, X’d(i): _____________________________________________________ Direct Axis Sub-transient Reactance, X”d(i): _________________________________________________ Quadrature Axis Synchronous Reactance, Xq(i): _______________________________________________ Quadrature Axis Transient Reactance, X’q(i): _________________________________________________ Quadrature Axis Sub-transient Reactance, X”q(i): _____________________________________________ Stator Leakage Reactance, Xl: _____________________________________________________________ Negative Sequence Reactance, X2(i): _______________________________________________________ Zero Sequence Reactance, X0: _____________________________________________________________ Saturated Sub-transient Reactance, X”d(v) (on MVA Base):______________________________________ Armature Resistance, Ra (on MVA Base):__________________________________________ at _____° C Time Constants (seconds) Direct Axis Transient Open Circuit, T’do:_____________________________________________________ Direct Axis Sub-transient Open Circuit, T”do: _________________________________________________ Quadrature Axis Transient Open Circuit, T’qo:_________________________________________________ Quadrature Axis Sub-transient Open Circuit, T”qo: _____________________________________________ Inertia, H (kW-sec/kVA, on KVA Base):_____________________________________________________ Speed Damping, D:______________________________________________________________________ Saturation Values at Per-Unit Voltage [S(1.0), S(1.2)]: __________________________________________ Please submit generator certified test report information when available IEEE dynamic model parameters: Governor Model: _______________________________________________________________________ Exciter Model: _________________________________________________________________________ Power System Stabilizer Model: ___________________________________________________________ TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 57 of 98 Appendix E CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Generator Step-up Unit (GSU) Transformer Data ISO/RTO Queue Letter/Position/Unit ID ________________________________________________________ GSU MVA Rating: ____________________________________________________________________ MVA GSU Positive Sequence Impedance (R+jX, on transformer MVA Base):_________________________ Per Unit GSU Zero Sequence Impedance (Ro+jXo, on transformer MVA Base): _________________________ Per Unit GSU MVA Base: ______________________________________________________________________ MVA GSU Low-side Voltage (kV): ______________________________________________________________KV GSU High-side Voltage (kV): ______________________________________________________________KV GSU Windings (Delta/Wye):__________________________________________________________________ GSU High-side No Load Tap Changer (NLTC) Taps: ___________________________________________KV GSU Low-side No Load Tap Changer (NLTC) Taps:____________________________________________KV Please submit transformer certified test report information when available In addition, please indicate whether the transformer is shared with other units. TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 58 of 98 Appendix F CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. APPENDIX F F: 800 kV Major Equipment Specifications TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 59 of 98 Appendix F CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 800 kV Equipment Dielectric Withstand Rating SWW (kV Peak) Equipment Type 60 Hz 1 minute Dry Withstand (kV rms) Closed/Open BIL 1.2X50 Usec. (kV peak) Closed/Open CWW 1.2X50 Usec. chopped @ 2Usec. kV Peak Closed/Open CWW 1.2X50 Usec. chopped @ 3Usec. kV peak Closed/Open Closed/Open Wet Closed/Open Dry 800 kV Circuit Breaker 960 dry 2050/2250 2640 2360 1425/1550 1700/1870 800 kV Current Transformer 960 dry 2050 2640 2360 1550 1700 800 kV Disconnect Switches 850 kV (10sec. Wet) 2050 - - 1400 (Closed) 1750 (Open) 800 kV CCVT - 2425 - 2850 1675 - 765 kV Transformer 883 kV (5 sec) 795 kV (1 hr) 2050 - 2260 1450 1700 TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 60 of 98 Appendix F CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. TECHNICAL REQUIREMENTS OF 800 KV EQUIPMENT Equipment Type Max. kV Rating 800 KV SF6 Dead Tank Circuit Breaker 800 kV Equipment Type Cont. Nominal kV Rating Current SA Rating 765 kV 3000 A SA MCOV Interrupting Current Max. Interruting Time Minimum Oper. Temp. Maximum Oper. Temp. Limit switching Surge level CT Ratio & Accuracy CT TRF 50/63 kA 2 Cycles -350 C >400 C <1.9 PU 3000/5 C800 @ 2000/5 OR 2000/5 C800 @1200/5 >2 FOW Protective Level @ 20 kA 800 kV Metal Oxide 588 kV RMS 476 kV RMS <1620 kV Crest Surge Arrester Max. Switching Surge Protective Level @ 2KA <1200 kV Crest Maximum Maximum Discharge kV Discharge kV For 8X20 Usec For 8X20 Usec 3 kA 10 kA <1240 kV Cres Maximum Discharge kV For 8X20 Usec 20 kA Maximum Discharge kV For 8X20 Usec 40 kA <1340 kV Crest < 1420 kV Crest <1570 kV Crest TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 61 of 98 Leakage Distance Inches > 620 inches Appendix G CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. APPENDIX G G: AEP Metering Requirements for Transmission Interconnection Facilities TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 62 of 98 Appendix G CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. AEP METERING REQUIREMENTS FOR TRANSMISSION INTERCONNECTION FACILITIES TABLE OF CONTENTS TABLE OF CONTENTS -..................................................................................................................................................... 63 PURPOSE - ............................................................................................................................................................................ 63 SCOPE - ................................................................................................................................................................................. 63 REFERENCES - .................................................................................................................................................................... 64 REVSION HISTORY ............................................................................................................................................................ 64 METERING PACKAGE ....................................................................................................................................................... 64 General ..............................................................................................................................................................................67 Standard Requirements:.....................................................................................................................................................65 Metering Equipment Maintenance & Testing: ..................................................................................................................65 Current Transformer Specifications: .............................................................................................................................66 Voltage Transformers Specifications: ...............................................................................................................................66 Remote Meter Access and Communications .....................................................................................................................66 Requestor Access to AEP Metering Circuits .....................................................................................................................67 Metering For Mining Facilities With An Isolated Neutral Resister Under MSHA Regulations .......................................67 GENERATOR METERING .................................................................................................................................................. 67 Specific Meter Requirements: ...........................................................................................................................................67 Specific Instrument Transformer Requirements................................................................................................................67 RTU Requirements ............................................................................................................................................................68 METERING RADIAL LOADS ............................................................................................................................................. 68 Specific Meter Requirements ............................................................................................................................................68 BIDIRECTIONAL INTERCONNECTION METERING ..................................................................................................... 69 Specific Meter Requirements ............................................................................................................................................69 RTU Requirements ............................................................................................................................................................69 PURPOSE This document is intended to guide AEP Engineers who are involved in the process of connecting non-AEP customer facilities to the AEP Transmission grid. This provides Planning Engineers, Project Managers, Asset Management personnel, Design Teams and Field Services personnel with the minimum requirements for associated revenue metering systems. These requirements are vital in ensuring accurate metering of energy at the customer delivery point, and provide for reliable cost-effective service of the metering systems. This document is intended to complement the System Planning connection criteria. This document addresses the specifics of metering requirements while the Planning Connection Guide addresses the metering requirements in more general terms. SCOPE This document addresses not only the general energy metering requirements, but also addresses specific applications and related issues. However, this does not address the requirements at a schematic level of detail. Design and testing requirements are addressed for not only metering but also a few schedule coordination and other logistical considerations between the Interconnection requestor and AEP. This document is only applicable for retail and wholesale customer connections to the AEP Transmission System Note: This document has been prepared by, and is the property of, American Electric Power Company, Inc. This document may be changed by AEP. Users should consult the OASIS site at http://www.aep.com/about/codeofconduct/OASIS/default.asp to determine the latest effective version STATION STANDARDS TITLE: AEP METERING REQUIREMENTS FOR TRANSMISSION INTERCONNECTION FACILITIES Responsible Engineer: J.C Park Copyright 2007 American Electric Power Company, Inc Rev. 3 SS-490011 Page 63 of 98 Appendix G CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. REFERENCES There was no legacy AEP or CSW standard that this supercedes. However, the following Transmission Planning Documents were used as starting points for development, and this standard is compatible and complements these Planning Guides: CSW Guidelines for Generation, Transmission and Transmission Electricity End-Users Interconnection Facilities. March 2000. (updated to American Electric Power West Guidelines, May 2002). AEP Requirements For Connection of Non-Generation Facilities To The AEP Transmission System. March, 2000 AEP Requirements for Connection of Generation facilities to the AEP Transmission System. May 1999. AEP “In-Line” Facility Policy and Guideline for Generation and Non-Generation Transmission Customers. May 2002. o o o o Other References Include: SS-451001 AEP Protection Requirements for Connection to AEP Transmission Grid. SS-500000 AEP SCADA RTU Requirements at Transmission Interconnection Facilities. o o Standard References Include: ANSI C12.1: Code for Electricity Metering ANSI C12.7: Requirements for Watt-Hour Meter Socket ANSI C12.9: Test Switches for Transformer-Rated Meters ANSI C12.11: Instrument Transformers for Revenue Metering, 10kV thru 350kV BIL ANSI C12.10: Electromechanical Watthour Meters ANSI C12.16: Solid State Electricity Meters ANSI C12.20: Electricity Meters 0.2 and 0.5 Accuracy Class ANSI C37.90.1: Surge Withstand Capability (SWC) Test ANSI/IEEE C57.13: Standard Requirements for Instrument Transformers o o o o o o o o o REVSION HISTORY Rev. Description of Change(s) By Date Approved 0 Original Issue Dan Recker 1-24-03 DJR 1 Scope section and General section, 3rd bullet (page 3), and added exemption for AEP-owned Distribution. Clarified “Freeze Signal” section, pg 4. Added a section for special requirements for mine facilities (pg 5). Dan Recker 4-19-03 DJR 2 Customer Meter Access - Option for shared meter data on meters equipped with hardware security lock Dan Recker 12-29-03 DJR 3 General Changes D. Bernert 03-09-07 JS 4 METERING PACKAGE General o All metering quantities shall be measured at or, at AEP’s option, compensated to the Point of Interconnection. There are a number of technical considerations that influence the viability of compensated metering, and AEP STATION STANDARDS TITLE: AEP METERING REQUIREMENTS FOR TRANSMISSION INTERCONNECTION FACILITIES SS-490011 Page 64 of 98 Appendix G CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Transmission Protection & Measurements Asset Engineering group shall be consulted before offering this option to the customer. o All reasonable costs associated with the initial installation of the metering package or any recurring operation & maintenance charges including changes to and/or upgrades to the metering equipment, shall be borne by the requestor, unless this requirement is superceded by regulatory or contractual requirements o This standard applies to all new non-AEP facilities. Existing facilities and like kind replacements of existing facilities are exempt from these standards and are covered by the existing agreements. However, any modification, addition or upgrade to facilities and equipment that are necessary to physically and electrically interconnect to the AEP Transmission system shall require that associated revenue metering systems be reviewed and brought into compliance with the most recent version of AEP Transmission metering standards. o At least (N-1) metering elements will be used to measure all real and reactive power crossing the metering point, where N is the number of wires in service including the ground wire. Standard Requirements: The revenue quality metering package (consisting of instrument transformers, meters, sockets, and test switches) shall be installed, calibrated, and tested (at Requestor’s expense) in accordance with the latest approved version of (but not limited to) the Standard Documents listed below: ANSI C12.1: “Code for Electricity Metering” ANSI C12.7: “Requirements for Watt-Hour Meter Socket” ANSI C12.9: “Test Switches for Transformer-Rated Meters” ANSI C12.11: “Instrument Transformers for Revenue Metering, 10kV thru 350kV BIL” ANSI C12.10: “Electromechanical Watthour Meters” ANSI C12.16: “Solid State Electricity Meters” ANSI C12.20: “Electricity Meters 0.2 and 0.5 Accuracy Class” ANSI C37.90.1: “Surge Withstand Capability (SWC) Test” ANSI/IEEE C57.13: “Standard Requirements for Instrument Transformers” To the extent that the above requirement conflict with the manuals, standards or guidelines of the applicable Reliability Council regarding interchange metering and transactions, the manuals, standards and guidelines of such Reliability Council shall control. AEP shall provide functional specifications and design for the revenue metering at the Requestor’s facility. The criteria for these functional specifications shall be based on existing AEP measurements practices and standards. AEP reserves the right to specify the type and manufacturer for all associated revenue metering equipment including the instrument transformers. Metering Equipment Maintenance & Testing: o Unless otherwise specified, the Revenue Meters shall be inspected and tested in accordance with latest applicable ANSI Standards upon installation, and at least once every year thereafter. If the requestor requires additional testing other than the normal test cycle, and the meter is found to be within the established tolerances, this additional testing shall be performed at the requester’s expense. o The accuracy of the Revenue Metering package shall be maintained at three tenths of one percent (0.3%) accuracy or better, and the meter test shall require the use of a meter standard with accuracy traceable to the National Institute of Standards and Technology (NIST). o If Revenue Metering equipment fails to function, the energy registration shall be determined from the best available data. This shall include backup metering, check metering, or historical metering data. STATION STANDARDS TITLE: AEP METERING REQUIREMENTS FOR TRANSMISSION INTERCONNECTION FACILITIES SS-490011 Page 65 of 98 Appendix G CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. o Instrument Transformers shall be inspected and maintained based on existing AEP Station practices and standards. o The Party that owns the metering equipment shall maintain records that demonstrate compliance with all meter tests and maintenance conducted in accordance with Good Utility Practice for the life of the Interconnection Point. The other Party shall have reasonable access to the records. Current Transformer Specifications: o Current transformers shall meet or exceed an accuracy class of 0.3% (as defined in IEEE C57.13). o Current transformers shall comply with the minimum BIL rating as specified in standards IEEE C57.13 and ANSI C12.11. In addition, dielectric withstand levels shall meet AEP’s current standard. o The mechanical and thermal short time current ratings of the current transformer shall exceed or withstand the available fault current. o The connected CT secondary burden of the current transformer shall not exceed the CT nameplate burden rating. o Optical CT’s shall not be used on AEP Transmission revenue metering applications, where the equipment is owned or serviced by AEP. If installed by the requestor, Optical CT’s shall be tested at a minimum test frequency of five years. o Interconnections with two or more interconnecting circuits shall be metered independently with independent CT’s. Under no circumstances shall CT secondary circuits be connected in parallel. Voltage Transformers Specifications: o Voltage transformers shall meet or exceed an accuracy class of 0.3% (as defined in IEEE C57.13). o A 115VAC nominal secondary winding of the Voltage Transformer shall be exclusively used for the Revenue Meters. o The VT connected secondary burden of the voltage transformer shall not exceed the VT nameplate burden rating. o Optical VT’s shall not be used on AEP Transmission revenue metering applications, where the equipment is owned or serviced by AEP. Coupling Capacitor Voltage Transformers may be used only in installations where a ferroresonance problem is indicated. If installed by the requestor, Optical VT’s and CCVT’s shall be tested at minimum test frequency of five years. o Voltage Transformers shall comply with the minimum BIL rating as specified in standards IEEE C57.13 and ANSI C12.11. In addition, the dielectric withstand levels shall meet AEP’s most recent standard. Remote Meter Access and Communications: o Communications – Upon request by AEP, the requestor shall provide the appropriate communication for electronic remote interrogation of meters and metering devices as specified by the appropriate AEP parties, in a manner that is compatible with AEP data systems. o Remote Terminal Unit (RTU) – Prior to the interconnection of the requestor’s facilities to the AEP Transmission system, an RTU or equivalent device acceptable to AEP, the requestor, and appropriate parties shall be installed. At the requestor’s expense, the RTU shall provide continuous energy and real time quantity measurements to the appropriate parties designated by AEP. The communication STATION STANDARDS TITLE: AEP METERING REQUIREMENTS FOR TRANSMISSION INTERCONNECTION FACILITIES SS-490011 Page 66 of 98 Appendix G CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. o requirements shall be specified by AEP. See SS-500000 AEP SCADA Requirements at Transmission Interconnection Facilities for more specific requirements. Freeze Signals – Revenue meters shall provide energy pulse accumulators (bi-directional, if required) or energy counters to the RTU (or equivalent device). The energy counters or pulse accumulator data shall be frozen based on upon the AEP RTU configuration. The accumulator freeze signal shall be synchronized to Universal Coordinated Time within +/- 2 seconds. Requestor Access to AEP Metering Circuits: o Requester access to AEP metering circuits is permitted under the terms and conditions of the most recent version of the AEP Measurements Bulletin #31. Metering For Mining Facilities With An Isolated Neutral Resister Under MSHA Regulations: This document is not intended to address the detailed special requirements of this rare application. Please refer to AEP Measurements Bulletin 33 for the special AEP requirements of this application. AEP Meter Services maintains this special bulletin. GENERATOR METERING Specific Meter Requirements: Revenue Meters shall meet all requirements outlined under “METERING PACKAGE” with the following specific requirements: o Primary and Backup energy meters shall be installed on each Transmission Interconnection circuit with the Generating facility. o The Revenue energy metering package shall be maintained at 0.3% accuracy or better over the entire CT secondary current range, including full generator output and, if applicable, the nominal back-feed auxiliary power. o If, at any test of metering equipment, an inaccuracy shall be disclosed exceeding the ANSI specification of two percent (2%), the account between the Parties for service theretofore delivered shall be adjusted to correct for the inaccuracy disclosed over the shorter of the following two periods: (1) for the 30-day period immediately preceding the day of the test, or (2) for the period that such inaccuracy may be determined to have existed. o Revenue energy meters shall be programmable and capable of measuring, recording, and displaying bidirectional, four-quadrant, kWh and kVARh energy quantities. The meter(s) shall be capable of storing these quantities as 4 independent 15-minute interval channels for a minimum of 45 days. o Power/energy flow from AEP to the Requestor will be designated as “Out” or “Delivered” kWh. “Out” kWh is considered positive and “In” or “Received” kWh is considered negative. The same conventions will be observed for reactive energy/power. o At a minimum, revenue energy meters shall be capable of displaying the following instantaneous quantities: Bi-directional kW, Bi-directional kVAR, Primary Voltage (each phase), and Primary Current (each phase). o Revenue energy meters shall have at least one RS-485/232 selectable port and (1) Ethernet port addressable by AEP’s RTU and capable of providing bi-directional kWh and kVARh energy counters and all of the above instantaneous values in either DNP 3.0 or Modbus standard protocols. The energy meter package shall also have an option available to provide hard-wired KYZ energy pulse contacts for each of the bi-directional kWh and kVARh energy quantities measured, and analog transducers for the kW and STATION STANDARDS TITLE: AEP METERING REQUIREMENTS FOR TRANSMISSION INTERCONNECTION FACILITIES SS-490011 Page 67 of 98 Appendix G CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. kVAR instantaneous quantities measured. All of the kWh, kVARh, kW, and kVAR multipliers shall be scaled to sufficiently to resolve full generator output and minimum back-feed of auxiliary power. o Revenue energy meters shall be equipped with an internal modem for remote interrogation. Specific Instrument Transformer Requirements Current transformers shall meet all requirements outlined under “METERING PACKAGE” with the following specific requirements: o Unless otherwise specified, the current transformers shall be located at the defined point of delivery on the high side of the Generator Step Up Transformer (GSU) or Reserve Auxiliary Transformer. o If applicable, current transformer ratio and accuracy range shall be specified to account for the extended range of current for measuring maximum generation and nominal auxiliary back-feed, while maintaining 0.3% accuracy or better across the entire range. The secondary burden rating of the CT shall be specified to meet all the standard burdens of B0.1 through B1.8. Wide Range/Extended Accuracy current transformers shall be used to meet these requirements. The continuous Thermal Rating factor (RF) of the CT’s shall be a minimum of 2.0 o Where practical, individual freestanding combination units shall be specified for generation interconnection metering. These units shall meet the same electrical, accuracy, and mechanical specifications as required for the individual revenue class CT’s and VT’s. RTU Requirements The Remote Terminal Unit (RTU) shall meet all requirements outlined under “METERING PACKAGE” with the following requirements: See SS-500000 AEP SCADA Requirements at Transmission Interconnection Facilities for more specific requirements. o The AEP Remote Terminal Unit (RTU) (provided at requestor’s expense) shall have at least five communication ports, (4) RS-232 ports, and (1) Ethernet port, capable of communicating simultaneous Modbus, DNP 3.0, or other protocols as specified by AEP. See SS-500000 AEP SCADA Requirements at Transmission Interconnection Facilities for more specific requirements. o Requestor shall provide real time status of station switching equipment (i.e., circuit breakers, motor operated air break switches, etc.) and real time analog measurements of individual generator kW and kVAR output to the AEP RTU as serial data . The communication protocol of this data shall be specified by AEP. See SS-500000 AEP SCADA Requirements at Transmission Interconnection Facilities for more specific requirements. METERING RADIAL LOADS Specific Meter Requirements Revenue Meters shall meet all requirements outlined under “METERING PACKAGE” with the following specific requirements: o Revenue Meters shall be programmable and capable of measuring, recording, and displaying kWh, and bi-directional KVarh energy quantities. The meter(s) shall be capable of storing these quantities as 15minute interval data for a minimum of 45 days. o For multiple load centers where the aggregate of all measured energy quantities of the connected facility is required, totalization shall be performed by AEP Load Research and the independent energy meter STATION STANDARDS TITLE: AEP METERING REQUIREMENTS FOR TRANSMISSION INTERCONNECTION FACILITIES SS-490011 Page 68 of 98 Appendix G CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. recorders will be synchronized with a satellite GPS clock, which shall be provided by the requestor. o The Revenue Meter(s) shall also have the option to provide form C (K-Y-Z) dry contact outputs representing the measured energy quantities. o Revenue meters shall have the capability for programmable transformer and line loss compensation. All displayed, recorded, and output energy quantities will represent the compensated quantities. o Revenue Meters shall be equipped with internal modem for remote interrogation. In addition, the revenue meter shall be equipped with an RS-232 or optical port for local interrogation. o The Revenue Meters will be tested periodically as defined in the service agreement and the test results will be available to all involved parties. BIDIRECTIONAL INTERCONNECTION METERING Specific Meter Requirements Revenue Meters shall meet all requirements outlined under “METERING PACKAGE” with the following additional requirements: o Primary and Backup energy meters shall be installed on each Transmission Interconnecting circuit with Interconnection facilities. o Revenue Meters shall be programmable and capable of independently measuring, recording, and displaying bi-directional kWh, and KVARh energy quantities. The meter(s) shall be capable of storing these quantities as 15-minute interval data for a minimum of 45 days. o Power/energy flow from AEP to the Requestor will be designated as “Out” or “Delivered” kWh. “Out” kWh is considered positive and “In” or “Received” kWh is considered negative. The same conventions will be observed for reactive energy/power. o If the Metering location is different than the contractual point of Interconnection, losses shall be compensation to the contractual point of Interconnection. o For a Requester with two or more Interconnections (e.g., two lines) with AEP, metering shall be installed at each independent Interconnection point. o Suitable telemetry equipment shall be installed at the metering point to provide real-time (Bi-directional kW, kVar) data to AEP and to other participating parties designated by AEP. o All real time quantities will originate from common metering equipment. Real time quantities will be 0.2 % or better accuracy. If, at any test of metering equipment, an inaccuracy of shall be disclosed exceeding the ANSI specification of two percent (2%), the account between the Parties for service theretofore delivered shall be adjusted to correct for the inaccuracy disclosed over the shorter of the following two periods: (1) for the 30-day period immediately preceding the day of the test, or (2) for the period that such inaccuracy may be determined to have existed. If the agreed upon Interconnection agreement between AEP and the requestor differs then the above criteria, the Interconnection Agreement will take precedence. RTU Requirements The Remote Terminal Unit (RTU) shall meet all requirements outlined under “Metering Package” with the following requirements: See SS-500000 AEP SCADA Requirements at Transmission Interconnection Facilities for more specific requirements. o STATION STANDARDS TITLE: AEP METERING REQUIREMENTS FOR TRANSMISSION INTERCONNECTION FACILITIES SS-490011 Page 69 of 98 Appendix G CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. o The AEP Remote Terminal Unit (RTU) (provided at requestor’s expense) shall have at least five communication ports, (4) RS-232 ports, and (1) Ethernet port, capable of communicating simultaneous Modbus, DNP 3.0, or other protocols as specified by AEP. See SS-500000 AEP SCADA Requirements at Transmission Interconnection Facilities for more specific requirements. o Requestor shall provide real time status of station switching equipment (i.e., circuit breakers, motor operated air break switches, etc.) and real time analog measurements of individual generator kW and kVAR output to the AEP RTU as serial data . The communication protocol of this data shall be specified by AEP. See SS-500000 AEP SCADA Requirements at Transmission Interconnection Facilities for more specific requirements. STATION STANDARDS TITLE: AEP METERING REQUIREMENTS FOR TRANSMISSION INTERCONNECTION FACILITIES SS-490011 Page 70 of 98 Appendix H CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. APPENDIX H H: AEP SCADA RTU Requirements at Transmission Interconnection Facilities TRANSMISSION PLANNING GUIDELINE TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 71 of 98 Appendix H CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. AEP SCADA RTU Requirements at Transmission Interconnection Facilities 1.0 Table of Contents 1.0 Table of Contents ............................................................................................................................................................. 72 2.0 Purpose:............................................................................................................................................................................ 72 3.0 Scope:............................................................................................................................................................................... 72 4.0 References: ....................................................................................................................................................................... 73 5.0 Revision History............................................................................................................................................................... 73 6.0 Definition of Terms Used in this Document .................................................................................................................... 73 7.0 RTU Requirements at Transmission Interconnection Facilities owned and operated by AEP......................................... 73 7.1 Data Requirements.................................................................................................................................................. 73 7.1.1 Interconnection-Specific Data from Revenue Metering............................................................................. 73 7.1.2 Other Interconnection-Specific Data .......................................................................................................... 74 7.2 Supervisory Control Requirements......................................................................................................................... 74 7.3 Communication Requirements................................................................................................................................ 74 7.4 Data and Control Verification................................................................................................................................. 74 7.5 Functional Verification ........................................................................................................................................... 74 7.6 Cost Requirements.................................................................................................................................................. 74 8.0 RTU Requirements at Transmission Interconnection Facilities not owned or operated by AEP ..................................... 74 8.1 Data Requirements.................................................................................................................................................. 74 8.1.1 Interconnection-Specific Data from Revenue Metering............................................................................. 74 8.1.2 Other Interconnection-Specific Data .......................................................................................................... 75 8.2 Supervisory Control Requirements......................................................................................................................... 75 8.3 Communication Requirements................................................................................................................................ 75 8.4 Data and Control Verification................................................................................................................................. 75 8.5 Functional Verification ........................................................................................................................................... 75 8.6 Cost Requirements.................................................................................................................................................. 75 9.0 RTU Requirements at Generation Facilities Connected to the AEP Transmission Grid.................................................. 75 9.1 Data Requirements.................................................................................................................................................. 75 9.1.1 Generation-Specific Analog Data............................................................................................................... 75 9.1.2 Generation-Specific Digital (Status) Inputs ............................................................................................... 76 9.2 Supervisory Control Requirements......................................................................................................................... 76 9.3 Communication Requirements................................................................................................................................ 76 9.4 Data Verification..................................................................................................................................................... 77 9.5 Functional Verification ........................................................................................................................................... 77 9.6 Cost Requirements.................................................................................................................................................. 77 2.0 Purpose: This document serves as a guideline for AEP’s Planning Engineers, Project Managers, Asset Engineers, Design Teams, and Field Support personnel, who are assigned to projects involving non-AEP Transmission customers connecting to the AEP Transmission grid. This document is intended to be used as a complement the System Planning connection criteria. 3.0 Scope: This document may be employed as a general guideline for the SCADA/RTU requirements for new interconnectionspecific applications involving the AEP Transmission Grid. AEP’s internal station standards (SS) documents shall be used for the actual engineering and design. Requirements by the regional operators (ERCOT, SPP, or PJM) shall take precedence, where applicable in this document. Note: This document has been prepared by, and is the property of, American Electric Power Company, Inc. This document may be changed by AEP. Users should consult the OASIS site at http://www.aep.com/about/codeofconduct/OASIS/default.asp to determine the latest effective version AEP SCADA RTU Requirement at Transmission Interconnection Facilities Responsible Engineer: Dennis R. Jones Rev. 1 SS-500000 Page 72 of 98 Appendix H CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 4.0 References The following is a list of documents from (PMAE) Protection and Measurements Asset Engineering, which are intended to be used as a compliment to the System Planning connection criteria: SS-490011 AEP Metering Requirements for Transmission Interconnection Facilities SS-451001 AEP Protection Requirements for Connection to AEP Transmission Grid SS-500000 AEP SCADA RTU Requirements at Transmission Interconnection Facilities (This Document) 5.0 Revision History Rev. Description of Change(s) By Date 0 Initial Release D.R Jones 04/19/07 1 Added one status point to required Generation data point list (Section 9.1.2) D.R Jones 05/18/07 Approved JS 2 3 4 6.0 Definition of Terms Used in this Document AEP = AEP Transmission Transmission Interconnection Facility = Physical location (substation) of Interconnection Revenue Metering Generation Facility = Generator or Generating Plant connected to AEP Transmission Grid 7.0 RTU Requirements at Transmission Interconnection Facilities owned and operated by AEP A Transmission-Specific Supervisory Control and Data Acquisition (SCADA) remote terminal unit (RTU), specified by AEP, shall be installed at all new Transmission Interconnection facilities that are owned and operated by AEP. This Transmission-Specific RTU shall be procured, engineered, installed, commissioned, and maintained by AEP or its authorized agents. See “Transmission Interconnection Station” in Figure 1. 7.1 Data Requirements Data sent to the AEP SCADA Master from the transmission-specific RTU shall include interconnection-specific data from the interconnection revenue metering (see SS-490011). In addition, the non-AEP interconnect company may request a communication port from AEP’s transmission-specific RTU to obtain interconnectionspecific data. Interconnection-specific data shall include the following quantities for each interconnecting power line: 7.1.1 Interconnection-Specific Data from Revenue Metering 1) MWh “Out” (Out = delivered from AEP to non-AEP company) 2) MWh “In” (In = received from non-AEP company to AEP) 3) MVARh “Out” 4) MVARh “In” 5) MW +/- (plus = instantaneous MW from AEP to non-AEP company) (minus = instantaneous MW from non-AEP company to AEP) 6) MVAR +/7) Instantaneous per phase Voltages (pertaining to each Interconnection Circuit) 8) Instantaneous per phase Currents (pertaining to each Interconnection Circuit) STATION MAINTENANCE GUIDELINES TITLE: AEP SCADA RTU Requirements at Transmission Interconnection Facilities Rev. 1 SS-500000 Page 73 of 98 Appendix H CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. The MWh, MVARh, MW, and MVAR units may be displayed in terms of kWh, kVARh, kW, and kVAR at the energy meter. Refer to SS-490011 for more information on Interconnection Metering Requirements. 7.1.2 Other Interconnection-Specific Data 1) Breaker Status Digital Inputs (pertaining to each Interconnecting Power Line) 2) Alarm Digital Inputs (pertaining to each Interconnecting Power Line and related equipment) 7.2 Supervisory Control Requirements Control Points, as specified by AEP, from the AEP SCADA RTU shall be provided to the AEP SCADA Master. The non-AEP interconnect company is not permitted to perform controls through the AEP SCADA RTU. 7.3 Communication Requirements A communications circuit including associated interface equipment, as specified by AEP, shall be provided from the RTU to the AEP SCADA Master. An additional communication circuit may be provided by the non-AEP interconnect company to provide interconnection-specific data (as described in Section 7.1) to their SCADA Master at their cost. 7.4 Data and Control Verification An RTU Point Assignment (RPA) shall be compiled by AEP (or its authorized agent). All data and control points mapped to the SCADA Master(s) shall be completely checked out and verified. 7.5 Functional Verification Prior to placing the interconnecting power line(s) in service to the requesting interconnecting company, the RTU shall be fully operational with all data and control points fully commissioned as described in Section 7.4 above. 7.6 Cost Requirements All costs for the procurement, engineering, installation, and commissioning of the RTU and its communication circuit shall be paid by the company requesting the transmission interconnection. In addition, any on-going monthly charges for the required communication circuit shall be paid by the company requesting the transmission interconnection. 8.0 RTU Requirements at Transmission Interconnection Facilities not owned or operated by AEP A Supervisory Control and Data Acquisition (SCADA) remote terminal unit (RTU) shall be installed at all new non-AEP transmission facilities, which are connected to the AEP Transmission Grid. AEP may require that AEP’s standard RTU (as described in Section 7.0) be installed at the non-AEP Transmission facility. This transmission-specific RTU shall be procured, engineered, installed, commissioned, and maintained by AEP or its authorized agents. As an alternative to installing AEP’s standard RTU, AEP may request to have a modem installed and connected to a communication port from the non-AEP RTU. See Transmission Interconnection Station in Figure 1.0. 8.1 Data Requirements If AEP’s standard RTU is installed, RTU inputs shall be supplied from an IED (Intelligent Electronic Device) via an AEP-approved interface device, unless otherwise specified as hardwired. The communication method between the RTU and IED(s) shall be Ethernet or RS-485 serial. The communication protocol shall be DNP 3.0. Data provided from the transmission-specific RTU (or com port of the non-AEP RTU) to the AEP SCADA Master) shall include the following interconnection-specific data for each interconnecting power line: 8.1.1 Interconnection-Specific Data from Revenue Metering 1) MWh “Out” (Out = delivered from AEP to non-AEP company) 2) MWh “In” (In = received from non-AEP company to AEP) 3) MVARh “Out” STATION MAINTENANCE GUIDELINES TITLE: AEP SCADA RTU Requirements at Transmission Interconnection Facilities Rev. 1 SS-500000 Page 74 of 98 Appendix H CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 4) MVARh “In” 5) MW +/- (plus = instantaneous MW from AEP to non-AEP company) (minus = instantaneous MW from non-AEP company to AEP) 6) MVAR +/7) Instantaneous per phase Voltages (pertaining to each Interconnection Circuit) 8) Instantaneous per phase Currents (pertaining to each Interconnection Circuit) The MWh, MVARh, MW, and MVAR units may be displayed in terms of kWh, kVARh, kW, and kVAR at the energy meter. Refer to SS-490011 for more information on Interconnection Metering Requirements. 8.1.2 Other Interconnection-Specific Data 1) Breaker Status Digital Inputs (pertaining to each Interconnecting Power Line) 2) Alarm Digital Inputs (pertaining to each Interconnection Power Line and related equipment) 8.2 Supervisory Control Requirements If the AEP SCADA Master is to have supervisory control capability at the non-AEP interconnection facility, then the standard AEP SCADA RTU shall be installed at the facility for controls and data to the AEP SCADA Master. AEP shall not perform controls through non-AEP SCADA RTUs. 8.3 Communication Requirements A communications circuit including associated interface equipment, as specified by AEP, shall be provided from the RTU to the AEP SCADA Master. 8.4 Data and Control Verification An RTU Point Assignment (RPA) shall be compiled for this transmission-specific RTU and posted by AEP (or its authorized agent). All data and control points mapped to the SCADA Master(s) shall be completely checked out and verified. 8.5 Functional Verification Prior to placing the interconnecting power line(s) in service to the requesting interconnecting company, the RTU shall be fully operational with all data and control points fully commissioned as described in Section 8.4 above. 8.6 Cost Requirements All costs for the procurement, engineering, installation, and commissioning of the RTU and its communication circuit shall be paid by the company requesting the transmission interconnection. In addition, any on-going monthly charges for the required communication circuit shall be paid by the company requesting the transmission interconnection. 9.0 RTU Requirements Generation Facilities Connected to the AEP Transmission Grid In addition to the transmission-specific RTU at the Transmission facility, a generation-specific RTU (specified by AEP) may be required at interconnected generation facilities to provide generation-specific Supervisory Control and Data Acquisition (SCADA) to the AEP SCADA Master. This generation-specific RTU shall be procured, engineered, installed, commissioned, and maintained by AEP or its authorized agents. See Generation Facility in Figure 1. 9.1 Data Requirements Except where specified at hardwired, RTU inputs shall be supplied from an IED (Intelligent Electronic Device) via an AEP-approved interface device. The communication method between the RTU and IED(s) shall be Ethernet or RS-485 serial. The communication protocol shall be DNP 3.0. Data sent to the AEP SCADA Master from the generation-specific RTU shall include the following: 9.1.1 Generation-Specific Analog Data 1) Gross MW + (instantaneous MW for each Generator) STATION MAINTENANCE GUIDELINES TITLE: AEP SCADA RTU Requirements at Transmission Interconnection Facilities Rev. 1 SS-500000 Page 75 of 98 Appendix H CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 2) Gross MVAR +/- (instantaneous MVAR for each Generator) 3) Aux MW +/- (instantaneous MW for each AUX transformer) 4) Aux MVAR +/- (instantaneous MVAR for each AUX transformer) 5) Frequency (Hz) 6) Voltage (instantaneous Voltage for each phase at transmission interconnection point) 7) Voltage (instantaneous Voltage for each phase at each winding of each transformer) 8) Current (instantaneous Current for each phase for each winding of each transformer) 9) MW+/- (instantaneous MW for each winding of each transformer) 10) MVAR +/- (instantaneous MVAR for each winding of each transformer) 9.1.2 Generation-Specific Digital (Status) Inputs 1) Generator Breaker Status (Hardwired for each breaker where Supervisory Control is also required) 2) Circuit Switcher / line switch status (“a” and “b” contacts) 3) Transformer high-side Breaker Status (Hardwired for each breaker where Supervisory Control is required) 4) Transformer high-side motor operated switch status (“a” and “b” contacts) 5) AUX Breaker Status 6) Capacitor Bank Breaker/Switch Status 7) Supervisory Cutoff (Hardwired for each breaker where Supervisory Control is required). 8) Breaker Failure Lockout Status (Hardwired for each breaker where Supervisory Control is required) 9) Breaker Critical Alarm (Required for each breaker where Trip control is required, combine critical alarms for each breaker). 10) Transformer Critical Alarm (Group Critical Alarms for each transformer) 11) Transformer Primary Lockout Relay Operated 12) Transformer Primary Lockout Relay Failure 13) Transformer Backup Lockout Relay Operated 14) Transformer Backup Lockout Relay Failure 15) IED Failure (required for each IED that provides data to RTU) 16) IED Communications Failure (required for each IED that provides data to RTU) 17) Battery Charger Trouble (Required for battery which powers the RTU) 18) Battery Charger AC Power Failure (Required for the battery which powers the RTU) 19) Smoke Alarm (Required for the structure housing the RTU) 20) Fire or High Temperature Alarm (Required for the structure housing the RTU) 21) Generator Automatic Voltage Regulator (AVR) Status 22) Fault Recorder Trouble Alarm 23) Transmission line lockout relay operated 24) Transmission line lockout relay failure 9.2 Supervisory Control Requirements A Trip control shall be provided for one or more of the generation or transmission line breakers to provide the AEP SCADA Master with the ability to trip all generation units during system emergencies. This trip control shall be hardwired and have a corresponding Digital (Status) Input that is also hardwired (see Section 9.1 for Status Inputs). 9.3 Communication Requirements A communications circuit including associated interface equipment, as specified by AEP, shall be provided from the generation-specific RTU to the AEP SCADA Master. STATION MAINTENANCE GUIDELINES TITLE: AEP SCADA RTU Requirements at Transmission Interconnection Facilities Rev. 1 SS-500000 Page 76 of 98 Appendix H CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 9.4 Data Verification An RTU Point Assignment (RPA) for the generation-specific RTU shall be compiled by AEP (or its authorized agent). All data and control points mapped to the SCADA Master(s) shall be completely checked out and verified. 9.5 Functional Verification Prior to placing the interconnecting power line(s) in service to the requesting interconnecting company, the generation-specific RTU shall be fully operational with all data and control points fully commissioned as described in Section 9.4 above. 9.6 Cost Requirements All costs for the procurement, engineering, installation, and commissioning of the generation-specific RTU and its communication circuit shall be paid by the company requesting the transmission interconnection. In addition, any on-going monthly charges for the required communication circuit to this generation-specific RTU shall be paid by the company requesting the transmission interconnection. STATION MAINTENANCE GUIDELINES TITLE: AEP SCADA RTU Requirements at Transmission Interconnection Facilities Rev. 1 SS-500000 Page 77 of 98 Appendix H CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. To AEP Transmission Grid 138 kV Communications To AEP SCADA Master Bus Com 2 Com 1 Transmission Interconnection Station Breaker H1 Meter Meter Primary (1) Back-Up (11) Communications To non-AEP SCADA Master (if required) 115 v H2/3 H4/5 H6 Direct Connection Generation Facility 138 kV Communications To AEP SCADA Master GT-1 GT-2 Com 2 Com 1 Communications To Generation Company (if required) Figure 1 Transmission-Specific and Generation-Specific RTU’s For AEP Transmission Interconnections STATION MAINTENANCE GUIDELINES TITLE: AEP SCADA RTU Requirements at Transmission Interconnection Facilities Rev. 1 SS-500000 Page 78 of 98 Appendix I CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. APPENDIX I I: AEP Protection Requirements for Connecting To the AEP Transmission Grid TRANSMISSION PLANNING GUIDELINE TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 79 of 98 Appendix I CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. AEP PROTECTION REQUIREMENTS FOR CONNECTING TO THE AEP TRANSMISSION GRID TABLE OF CONTENTS – TABLE OF CONTENTS - .................................................................................................................................................... 80 PURPOSE - ........................................................................................................................................................................... 81 SCOPE - ................................................................................................................................................................................ 81 REFERENCES - ................................................................................................................................................................... 81 REVSION HISTORY ............................................................................................................................................................ 81 General - ................................................................................................................................................................................ 82 Requester Protection - .......................................................................................................................................................... 82 Grounding of Requester’s Facilities - ................................................................................................................................... 82 Transmission Line Protection Pilot Channel Requirements - ................................................................................................ 82 AEP Terminals at Remote End of The Requester’s Station - ................................................................................................ 83 Customer Tapped Stations And Fused Transformer Applications - ...................................................................................... 83 Tapped Stations Added To Lines With Carrier - ................................................................................................................... 83 Automatic Underfrequency Load Shedding - ........................................................................................................................ 83 SCADA Considerations - ...................................................................................................................................................... 83 Remote Relay Access............................................................................................................................................................. 84 Environmental Considerations - ............................................................................................................................................ 84 Fault Disturbance Monitoring - ............................................................................................................................................. 84 Power Supply For Protective Relaying - ................................................................................................................................ 84 High Speed Ground Switch Applications (HSGS) - ............................................................................................................. 84 Testing and Maintenance - .................................................................................................................................................... 84 Voice Communications - ....................................................................................................................................................... 85 Requester With Facilities That Are Generation Source - ...................................................................................................... 86 Ground Current Sources - ................................................................................................................................................. 86 Automatic Reclosing - ...................................................................................................................................................... 86 Frequency Protection ....................................................................................................................................................... 86 SUPPLEMENTAL NOTES AND CLARIFICATIONS FOR AEP INTERNAL USE ......................................................... 86 Direct Transfer Trip (DTT) Requirements - ..................................................................................................................... 87 Timeline For Coordinating Area Protection Study and Development Of Relay Settings For Customer Projects ............ 87 Note: This document has been prepared by, and is the property of, American Electric Power Company, Inc. This document may be changed by AEP. Users should consult the OASIS site at http://www.aep.com/about/codeofconduct/OASIS/default.asp to determine the latest effective version STATION STANDARDS TITLE: AEP Protection Requirements For Connecting To The AEP Transmission Grid Responsible Engineer: Hank Miller Copyright 2007 American Electric Power Company, Inc Rev. 3 SS-451001 Page 80 of 98 Appendix I CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. PURPOSE – This document is intended to guide AEP Engineers who are involved in the process of connecting any facilities to the AEP Transmission grid. This serves as minimum requirements for both internal AEP and external customer facilities. This provides Planning Engineers, Project Managers, Asset Management personnel, Design Teams and Field Services personnel with the minimum Protection and Control (P&C) requirements. These requirements are vital in establishing a reliable connection to the AEP grid in a manner that is cost-effective, and compatible with the rest of the AEP transmission grid. This document is intended to complement the System Planning connection criteria. This document addresses the specifics of protection requirements while the Planning Connection Guide addresses protection in very general terms. SCOPE – This document addresses not only the general protection and control requirements, but also addresses specific protection and control applications and protection requirements for more specific circumstances. However, this does not address the requirements at a schematic or relay model level. Design and testing requirements are addressed for not only protection but also data systems, Supervisory Control and Data Acquisition (SCADA), telecommunications, and reclosing. It also addresses a few schedule coordination and other logistical considerations between the customer and AEP. REFERENCES – There was no legacy AEP or CSW P&C standard that this supercedes. However, the following Transmission Planning Documents were used as starting points for development, and this standard is compatible and complements these Planning Guides: o CSW Guidelines for Generation, Transmission and Transmission Electricity End-Users Interconnection Facilities. March 2000. o AEP Requirements For Connection of Non-Generation Facilities To The AEP Transmission System. March, 2000 o AEP Requirements for Connection of Generation facilities to the AEP Transmission System. May, 1999. o AEP “In-Line” Facility Policy and Guideline for Generation and Non-Generation Transmission Customers. May 2002. Other References Include: o Station Standard #SS 420410. P&C Testing and Maintenance. o AEP Metering Requirements for Transmission Interconnection Facilities SS# 490011 o AEP SCADA RTU Requirements at Transmission Interconnection Facilities SS# 500000 o Substation Data Repository System SS# 501103 o ANSI/IEEE Standard C37.90 REVSION HISTORYRev. Description of Change(s) By Date Approved 0 Original Issue Dan Recker 1-24-03 DJR 1 Page 3, SCADA CONSIDERATION section, added clarifying sentence. PURPOSE, pg 1, clarified. Dan Recker 4-19-03 DJR STATION STANDARDS TITLE: AEP Protection Requirements For Connecting To The AEP Transmission Grid SS-451001 Page 81 of 98 Appendix I CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 2 Page 3, added a section that explicitly addresses fuses Dan Recker 9-10-05 DJR 3 Revised the Frequency Protection section on page 6, made some small editing changes, and added some new references. Henry Miller 3-25-07 JS 4 General– AEP will provide functional specifications and relay settings for all protective relays at the Requester’s facility that have a potential impact on the reliability of the AEP transmission system. The criteria for these functional specifications and settings will be based on existing AEP protection practices and standards. AEP reserves the right to specify the type and manufacturer for these protective relays to ensure compatibility with existing relays. The specific recommendations and requirements for protection will be made by AEP based on the individual station location, voltage and configuration. AEP further reserves the right to modify relay settings when deemed necessary to avoid safety hazards to utility personnel or the public and to prevent any disturbance, impairment, or interference with AEP’s ability to serve other customers. All relays specified for the protection of the AEP system, including time delay and auxiliary relays, shall be approved by AEP, and shall be utility grade devices. Utility grade relays are defined as follows: o Meet ANSI/IEEE Standard C37.90, “Relays and Relay Systems Associated with Electric Power Apparatus” o Have relay test facilities to allow testing without unwiring or disassembling the relay. o Have appropriate test plugs/switches for testing the operation of the relay. o Have targets to indicate relay operation. Requester Protection – It is the Requester’s responsibility to assure protection, coordination and equipment adequacy within their facility for conditions including but not limited to: o Single phasing of supply o System faults o Equipment failures o Deviations from nominal voltage or frequency o Lightning and switching surges o Harmonic voltages o Negative sequence voltages o Separation from AEP supply o Synchronizing generation. Grounding of Requester’s Facilities – Requester’s protection and control equipment interfacing with AEP protection and controls must be solidly tied to a common ground. Grounding of equipment must be consistent with IEEE standards. Transmission Line Protection Pilot Channel Requirements – High speed transmission line protection and transfer trip functionality requires pilot channel communication links between the line terminals. The types of pilot channel communication links can include, but are not limited to the following: Power line carrier, fiber optic cable, radio, and pilot wire. Critical and sensitive portions of the transmission grid commonly require transfer trip and/or dual high-speed protection, which requires two separate pilot channel links. The specific recommendations and requirements for these pilot channels will be based on AEP protection practices and standards. AEP reserves the right to determine when transfer trip is necessary and to select either single or dual highspeed systems and to specify the type and characteristics of the pilot channel to ensure compatibility with the existing protection. STATION STANDARDS TITLE: AEP Protection Requirements For Connecting To The AEP Transmission Grid SS-451001 Page 82 of 98 Appendix I CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. AEP Terminals at Remote End of The Requester’s Station – The protection at all ends of a transmission line must be compatible and function as a system. Thus, the installation or modification of transmission line protection at the Requester’s station may require the upgrade or replacement of protection at the remote terminals. Such upgrades or replacements at the remote terminals shall be considered within the project scope for the requester’s station, and funded, accordingly. Customer Tapped Stations And Fused Transformer Applications – For public safety and the protection of the grid infrastructure, AEP sets line protection to clear line faults as fast as possible, and thus, does not intentionally delay this line protection to coordinate with down line tapped fuses. Similarly, AEP has an obligation to have a fuse connection policy that ensures reliable zone-to-zone relay coordination for the reliability of all AEP customers connected to the grid. To achieve this, transformer fuses are generally not applied on tapped lines with pilot protection or lines with short circuit fault current above 15kA (to stay under the short circuit fault limit of most fuses). To achieve this, fuses are not permitted at transmission line voltages of 138kv and above. At subtransmission voltages, fuses sized to carry more than 15 MVA transformer load rarely coordinate with AEP line protection, and therefore, are not permitted. For all other potential fuse application requests, AEP will recommend a fuse size that will coordinate with the existing line protection, if one can be found. It will be the connecting customer's responsibility to coordinate and operate below this specified fuse limit. If AEP cannot find a fuse that reliably coordinates with the existing line protection, or if the recommended fuse size is unacceptable to the customer, then the customer will need to upgrade the transformer high-side interrupting device to a circuit switcher or breaker. AEP reserves the right to require the customer to replace the fuse with an upgraded interruption device if the fuse performance is found to adversely impact grid reliability or if grid and line protection conditions change. Tapped Stations Added To Lines With Carrier – Carrier signals can be degraded by tapped load and load that is electrically located at the ¼ wavelength of the carrier frequency on the line. It is not practical to accurately predict in advance whether newly tapped load will create this condition. A wave trap installed at the new tap is one way of insuring that newly tapped load will not adversely affect the line carrier signal. It is the responsibility of the delivery point requester to insure that the new delivery point does not degrade the power line carrier signal(s) or protection scheme on the tapped line. This may require a wave trap to be installed on the appropriate phase at the tap to the requester’s station and tuned to the carrier frequency. The requester can choose to install this wave trap in advance or determine at the point of energizing the newly tapped station whether a wave trap is necessary. If the requester elects not to install the wave trap in advance, and it is later determined that the tapped installation has degraded the carrier signal(s), then the delivery point will be de-energized until such time that the tapped station has been modified to eliminate the source of carrier signal degradation. Automatic Underfrequency Load Shedding – AEP may require an automatic load shedding scheme on connected load to comply with North American Electric Reliability Corporation (NERC) standards or other system stability considerations. AEP is obligated to have an automatic underfrequency load shedding plan in effect, which meets these NERC standards. Connecting parties without an automatic underfrequency load shedding plan for meeting these NERC requirements may need to install underfrequency relaying and have a load shedding program in place as required by AEP. The amount of load to be shed and frequency setpoints will be specified by AEP as set forth in the underfrequency load shedding compliance requirements of NERC and the applicable Regional Reliability Organization. SCADA Considerations – Supervisory Control and Data Acquisition (SCADA) is an essential tool for reliably controlling and monitoring the transmission grid. There are a number of factors and considerations in determining the specific SCADA requirements at a given site. Generally, if the connecting facility has a circuit breaker(s) or other automatically operated switching device(s) in the bulk power transfer path, then AEP generally requires the connecting party to provide SCADA. AEP reserves the right to specify the type, manufacturer and characteristics of the SCADA equipment used at facilities STATION STANDARDS TITLE: AEP Protection Requirements For Connecting To The AEP Transmission Grid SS-451001 Page 83 of 98 Appendix I CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. connected to the AEP transmission grid. The specifications and requirements for this SCADA equipment and sitespecific application will be based on AEP design practices and standards. Alarm inputs into the SCADA system shall be categorized as either “emergency” alarms requiring immediate response, or “maintenance” alarms requiring next-day response. Remote Relay Access o o Tap Connected Facilities - Remote relay access is not normally required at tap connected facilities. Loop or Network Connected Facilities - All digital relays which have the capability of recording system disturbance information and are used for protection of AEP transmission facilities shall be provided with the equipment necessary to allow AEP to remotely retrieve this data via Requester supplied commercial telecommunications link. The type of communications circuit will need to meet all NERC Critical Infrastructure Protection (CIP). Environmental Considerations – The performance and durability of modern protective relays is impacted by their surrounding environment, and can be especially impacted by extreme high and low ambient temperatures. Consequently, protection that can potentially impact the AEP transmission grid must be installed in a climate controlled environment consistent with AEP specifications. Fault Disturbance Monitoring – AEP is responsible to meet NERC fault disturbance monitoring requirements, and AEP reserves the right to specify the type, model and specifications of the fault monitoring equipment necessary to meet all applicable regulatory requirements. Power Supply For Protective Relaying – All protection systems, disturbance monitors and SCADA system at the requester’s facilities that can potentially impact the AEP transmission grid must have a source of power independent from the AC system or immune to AC system loss or disturbances (e.g. DC battery and charger) to assure proper operation of the protection schemes. Loss of this source shall require the immediate disconnection from the AEP transmission grid until the source is restored. High Speed Ground Switch Applications (HSGS) – HSGS’s shall not be used as the primary means of fault clearing. Under certain rare conditions, it may be permissible to apply HSGSs as a backup means of fault clearing provided that the requester pays for any resulting damages or liabilities created by the operation of the HSGS. Approval of HSGS applications on requester’s facilities connected to the AEP transmission grid will be at the discretion and approval of AEP after factoring all of the reliability and operational considerations. Testing and Maintanance – All Requester owned equipment up to and including the first protective fault interrupting device is to be maintained to AEP standards. Maintenance specifications are detailed in the Station Standard #SS 420410, P&C Testing and Maintenance, and Station Standard #SS 420310, Circuit Breaker Maintenance. The Requester shall have an organization approved by AEP test and maintain all devices and control schemes provided by the Requester for the protection of the AEP system. Included in the testing and maintenance will be any initial set STATION STANDARDS TITLE: AEP Protection Requirements For Connecting To The AEP Transmission Grid SS-451001 Page 84 of 98 Appendix I CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. up, calibration, and check out of the required protective devices, periodic routine testing maintenance, and any testing and maintenance caused by a Requester or AEP change to the protective devices. If the Requester’s testing and maintenance program is not performed in accordance with AEP’s “Guidelines for Transmission and Distribution Maintenance and Frequencies,” AEP reserves the right to inspect, test, or maintain the protective devices required for the protection of the AEP System. All costs associated with the testing and maintenance of devices provided by the Requester for the protection of the AEP system, including costs incurred by AEP in performing any necessary tests or inspections, shall be the responsibility of the Requester. AEP reserves the right to approve the testing and maintenance practices of a Requester when the End-User’s system is operated as a network with the AEP transmission system. Voice Communications – At AEP’s request, the Requester shall provide a dedicated voice communication circuit to the AEP System Control Center. Such a dedicated voice communication circuit would originate from the Requester’s office staffed 24 hours a day and would be typically required for connected transmission facilities that significantly affect the AEP transmission network capacity and operations. STATION STANDARDS TITLE: AEP Protection Requirements For Connecting To The AEP Transmission Grid SS-451001 Page 85 of 98 Appendix I CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Requester With Facilities That Are Generation Source – Generating sources present some unique considerations as follows: Ground Current Sources – Protective relays must be able sense line-to-ground faults. Ground fault protection is predicated upon having an adequately grounded transmission grid with suitable zero sequence ground fault current levels. This requires that transformers connected to the transmission grid be specified and connected in a manner that provides for adequate zero sequence ground fault current. AEP reserves the right to specify the zero sequence impedance requirements that must be met by the transformer and its connection to the transmission grid, and reserves the right to require a delta tertiary winding on the transformer for providing a compatible configuration. Automatic Reclosing – Automatic reclosing is normally applied to transmission and distribution circuits. When the AEP source breakers trip and isolate the requester’s facilities, the requester shall insure that their generator is disconnected from AEP prior to automatic reclosure by AEP. Automatic reclosing out-of-phase with the requester’s generator may cause damage to the requester’s equipment. The requester is solely responsible for the protection of their equipment from automatic reclosing by AEP. Frequency Protection – Generator underfrequency protection must be set to coordinate with the settings of the NERC-mandated automatic load shedding protection. Thus, the generator underfrequency protection must not operate before the system underfrequency load shed protection has a chance to respond. The requester is responsible for setting their generator underfrequency protection to comply with the local Area Reliability council’s requirements for generator underfrequency protection. As an example, the requirements for the ECAR Area Council are shown in the table below: FREQUENCY TIME BEFORE GENERATION UNIT ISOLATION 60.0 to 59.5 Hz Unlimited 59.5 to 58.5 Hz 30.0 minutes before unit isolation can be expected 58.5 to 58.2 Hz 7.0 minutes before unit isolation can be expected Below 58.2 Hz Unit isolation without time delay can be expected. The frequency values shown above change from time to time and it is responsibility of the Requestor to modify their generator underfrequesncy setting when notified of changes in order to stay compliant with the current requirements of NERC and the applicable Regional Reliability Organization. STATION STANDARDS TITLE: AEP Protection Requirements For Connecting To The AEP Transmission Grid SS-451001 Page 86 of 98 Appendix I CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. SUPPLEMENTAL NOTES AND CLARIFICATIONS FOR AEP INTERNAL USE Direct Transfer Trip (DTT) Requirements – DTT is commonly installed to protect against breaker failure scenarios. In general, if the failure of a customer’s breaker places the AEP transmission grid at risk (e.g. risk of voltage collapse) or if it presents a significant risk to other customers connected to the AEP transmission grid, then the requester should be required to install direct transfer trip to protect against this breaker failure scenario. Transmission Planning has the responsibility for determining this risk. This DTT requirement does not consider the protection of the requester’s own facilities, and it is assumed that the requester will specify DTT if they find it necessary to protect their facilities. Timeline For Coordinating Area Protection Study and Development Of Relay Settings For Customer Projects – Before AEP enters into a commitment with a customer on a plan of service, it is essential that a detailed area protection study be performed to ensure that the plan of service can be adequately protected. To ensure that the project scope is complete relative to the protection, the preliminary area protection study needs to occur (performed by Protection Measurements Asset Engineering - PMAE) before requesting a detailed estimate from Station Projects Engineering. Once the project is scoped, the design team engineers the project. Once the T-Line engineering and station schematics are complete, and the Requester defines their setting requirements, and provides any necessary data for their facilities, then final settings can be developed for the rest of the impacted AEP system. These settings may take 2-6 weeks to develop depending on the size and complexity of the project. The settings are then issued to the field approximately two to four weeks prior to the service date. STATION STANDARDS TITLE: AEP Protection Requirements For Connecting To The AEP Transmission Grid SS-451001 Page 87 of 98 Appendix J CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. APPENDIX J J: Transmission Switching Guidelines for In-line Stations TRANSMISSION PLANNING GUIDELINES TITLE: Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP West Transmission System TP-0002 Rev. 3 Page 88 of 98 Appendix J CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. AEP Guide for Application of In-Line Manual Air Break Switches, Automatic Air Break Switches or Circuit Breakers September 2005 Note: This document has been prepared by, and is the property of, American Electric Power Company, Inc. , is intended for AEP use only, is not to be used for any purpose detrimental to AEP’s interest, and is not to be furnished to, or copied or reproduced by, parties not affiliated with the AEP system without the express written consent of AEP, and is to be returned upon request. TRANSMISSION PLANNING GUIDELINE TITLE: AEP Guide for the Application of In-Line Manual Switches, Automatic Switches or Circuit Breakers Responsible Engineer: M. Ahmed Copyright 2007 American Electric Power Company, Inc Rev. 0 TP-000004 Page 89 of 98 Appendix J CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. REVISION HISTORY Rev. 0 Description of Change(s) Original Issue Prepared or Revised By M.Ahmed Date Approved September 2005 B.M. Pasternack 1 2 3 4 TRANSMISSION PLANNING GUIDELINE TITLE: AEP Guide for the Application of In-Line Manual Switches, Automatic Switches or Circuit Breakers Rev. 0 TP-000004 Page 90 of 98 Appendix J CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Table Of Contents 1.0 2.0 3.0 4.0 5.0 6.0 7.0 8.0 8.1 8.2 8.3 Introduction………………………………………………………………………………………………….............90 Background………………………………………………………………………………………………………….92 Scope………………………………………………………………………………………………………………...92 Objectives…………………………………………………………………………………………….……………...93 References………………………………………………………………………………….......................................93 In-Line Tap Connection Definition…………………………………………………………. ……………………...93 In-Line Switching Facilities Definition and Requirements……………………………….….……………………...94 Selection of In-Line Switching Device(s) to Connect LOAD to the Transmission System… ……………………...95 Basic Service Plan ..................................................................................................................................................95 Justification for In-Line MOAB Switches..............................................................................................................95 Justification for In-Line Circuit Breaker (CB)........................................................................................................96 Appendix A TRANSMISSION PLANNING GUIDELINE TITLE: AEP Guide for the Application of In-Line Manual Switches, Automatic Switches or Circuit Breakers Rev. 0 TP-000004 Page 91 of 98 Appendix J CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. 1.0 INTRODUCTION American Electric Power Service Corporation, acting on behalf of the eleven American Electric Power (AEP) Electric Operating Companies1, has prepared this document which outlines the methodology for determining the minimum switching/sectionalizing equipment requirements for an in-line connection of all transmission load facilities to the AEP Transmission System below 200 kV. In-line connection refers to the connection of load at a point located in series with the through path of a transmission circuit. Transmission Load (load)2 facilities refer to the facilities that need to be installed to establish connections between AEP and the radially served loads (direct connections to End-Users or the delivery points of wholesale customers such as munis, co-ops or AEP Distribution), by tapping the transmission circuit and installing sectionalizing facilities. 2.0 BACKGROUND In the present electric utility environment characterized by deregulation, open access to the transmission network, wholesale and retail competition, etc., there is a wide recognition that electric system reliability, safety and quality of service are to be maintained. Maintaining reliability, safety and quality of service in this changing environment presents additional challenges to those involved in the planning and operation of electric systems. As a result of this environment, there are an increasing number of requests to connect to and use the AEP Transmission System. Each request is reviewed by AEP to identify the impacts and necessary system improvements on the AEP Transmission System. The purpose of this document is to ensure that comparable treatment is given to all users, and that reliability, safety, and quality of service are maintained. 3.0 SCOPE This report conveys information about the in-line switching requirements for connection to parties seeking connection of load to the AEP Transmission System. The methodology and the requirements are applicable to all radially connected load including AEP Distribution load as well as the load served by wholesale and retail customers, connecting to AEP transmission lines below 200 kV. These requirements are not a substitute for specific Service Agreements between AEP and non-affiliated entities connecting to the AEP Transmission System. The requirements described in this document do not apply to generation facility connections, interconnection tie lines with other Utilities, or connection of a radial customer directly to an AEP Transmission Station. Furthermore, a separate document3 covers the operational and technical requirements at the point of connection. 1 Appalachian Power Company, Columbus Southern Power Company, Indiana Michigan Power Company, Kentucky Power Company, Kingsport Power Company, Ohio Power Company, Public Service Company of Oklahoma, Southwestern Electric Power Company, Texas Central Company, Texas North Company and Wheeling Power Company. 2 Transmission Load is hereinafter referred to as load. 3 Connection Guidelines “Requirements for Connection of New Facilities or Changes to Existing Facilities Connected to the AEP East Transmission System”. TRANSMISSION PLANNING GUIDELINE TITLE: AEP Guide for the Application of In-Line Manual Switches, Automatic Switches or Circuit Breakers Rev. 0 TP-000004 Page 92 of 98 Appendix J CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. This report contains guidelines for the minimum switching requirements that should be adhered to when connecting load facilities to AEP’s Transmission System operated below 200 kV. Connections to the Transmission System above 200 kV are not included and will be addressed on a case-by-case basis. Reliability, power quality and operational concerns may impose the need to install additional “in-line” sectionalizing facilities. The need for appropriate switching requirements can only be evaluated once certain details of a proposed load facility are made known and studies have been conducted. The requirements for initial facility connection also apply to any upgrades, additions, enhancements, or changes of any kind to an existing connected facility. This document does not cover transmission service or deliverability. The load connection entities requiring transmission service should refer to the AEP, PJM, ERCOT, and SPP Open Access Transmission Tariffs. 4.0 OBJECTIVES AEP, in its role as a transmission owner, has prepared this document to accomplish the following objectives: 1. Inform those entities that request electric service to their loads from the AEP Transmission System of the need for minimum in-line sectionalizing facilities required at the point of connection. 2. Maintain adequate system reliability, safety of personnel/equipment, and quality of service. 3. Ensure comparability in the requirements imposed upon the various load-serving entities, including individual customers, seeking to connect to the AEP Transmission System for service. 4. Facilitate uniform and compatible minimum sectionalizing equipment requirements and installation practices to promote and/or maintain a basic level of service reliability. 5.0 REFERENCES The following documents were used to develop these guidelines, which are compatible with and complement the reference Guides: 6.0 1. Requirements for Connection of Non-Generation Facilities to the AEP East Transmission System. (TP-000001; June 2004) 2. Motor Operated Air Break Switches. (SS-476010; January 2003) TAP CONNECTION DEFINITION Any connection to the AEP Transmission System that results in only the associated load passing through the connecting facilities under all conditions is considered a tap connection. If the TRANSMISSION PLANNING GUIDELINE TITLE: AEP Guide for the Application of In-Line Manual Switches, Automatic Switches or Circuit Breakers Rev. 0 TP-000004 Page 93 of 98 Appendix J CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Requesting Entity's4 facilities are located near an existing AEP station, the connection from the AEP Transmission System may be provided by constructing a radial line from the AEP station to the Requester's facility. If the Requester's facilities are located near an existing AEP transmission line, the connection from the AEP Transmission System may be provided by tapping the nearby AEP line and constructing a radial line to the Requester's facility. This arrangement will provide a radial connection to the Requester but will also result incidentally in creating in-line facilities at the tap point. The in-line facilities will not only carry customer load but also the transmission system power flows. For facilities below 200 kV, Figures 1 and 2 in the Appendix B illustrate typical radial line supply configurations and some of the basic connection requirements to the AEP transmission line. Other possibilities exist depending on the particular situation. Typically, a manual three-phase air break line switch (switch) on either side of the tap location point is the minimum requirement. The tap line switch can disconnect the load connection without deenergizing the supply line. Additionally, in-line air break switches allow for manually sectionalizing the line without supply interruption to the load. Automatic motor operated mechanisms (with or without supervisory control) can be added to in-line switches, when justified, to minimize the time required for restoration following a failure of the AEP supply line. 7.0 IN-LINE SWITCHING FACILITIES DEFINITION AND REQUIREMENTS Any connection to the AEP Transmission System would require, as a minimum, line disconnect switches, commonly referred to as “Group Operated Air Break (GOAB)” switches. These switches are manually operated and not part of the overall system automatic relaying sectionalizing scheme. The only exceptions to this minimum requirement where switches are not required are the following situations: 1) the connection established to serve load is temporary and is required for a period less than a year; 2) the topography of the tap location is such that the tap is not accessible by road, in which case the in-line switches could be placed elsewhere in a more accessible location, or 3) the tapped inline connection is required temporarily under emergency system conditions. A GOAB switch that is equipped with automatic line sectionalizing capability is commonly referred as a “Motor Operated Air Break (MOAB)” switch. A MOAB is simply an air break switch whose blade moves by action of a motor. If the motor turns in one direction, the blade moves to an open position. If the motor turns in the opposite direction, the blade moves to a closed position. MOABs are frequently used on the AEP System below 200 kV as “automatic sectionalizing devices” in addition to their application in the isolation of transformers or lines emanating from the station busses. In some applications, MOABs can be operated remotely by supervisory control. The MOAB is more expensive to install than a GOAB because of the added cost of relaying, supervisory control capability and automatic sectionalizing capability. The Circuit Breaker (CB), as used in a Transmission System, is a device that provides high-speed automatic sectionalizing capability to make or break circuits under normal conditions. A CB can also 4 Requesting Entity – can refer to either a Transmission Interconnection Requester or a Transmission Load Connection Requester and hereinafter is referred to as a Requester. TRANSMISSION PLANNING GUIDELINE TITLE: AEP Guide for the Application of In-Line Manual Switches, Automatic Switches or Circuit Breakers Rev. 0 TP-000004 Page 94 of 98 Appendix J CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. interrupt fault currents. This automatic sectionalizing by CBs is done with as little disturbance as possible to the system. In general, a CB is inherently more reliable than a MOAB in protecting against false trips, particularly for intermittent line faults. The cost to install a CB is greater than that of a MOAB or GOAB due its more sophisticated sectionalizing capability and function, as well as greater land requirements. 8.0 Selection of In-Line Switching Device(s) to Connect LOAD to the Transmission System Any plan to serve load from an AEP Transmission Line involves establishing a connection point. At the connection point, appropriate facilities are required to provide adequate service to the new customer while maintaining service reliability and quality to other customers served from the subject transmission line. Several factors are considered in determining the in-line facilities requirement over and above the minimum requirement of GOAB switches. The factors that influence the decision include: 1) the magnitude of load affected; 2) the exposure to fault conditions, i.e. the line length between two automatic sectionalizing devices; and 3) the probability of an outage of the transmission line involved. 8.1 Basic Service Plan AEP requires that any new plan to connect load to the transmission system typically must include in-line GOAB switches at the point of connection. This is referred to as the “Basic Plan” and therefore, is the minimum accepted switching arrangement for new connections. The only exceptions to this minimum requirement are described in Section 7.0. 8.2 Justification for In-Line MOAB Switches Installation of in-line MOAB switches at the point where load is connected to a transmission system improves the automatic line sectionalizing capability of the circuit and reliability of service to the load from a permanent forced outage standpoint. In order to determine if the MOAB switches are required, a factor referred to as the ‘Forced Outage Index (FOI)” is calculated and compared with the established threshold index values. The FOI is defined as: FOI = Load (Lf) X Miles of Exposure X Permanent Forced Outage Rate (Pf)—see explanation below Where; Lf = Peak load (in MW) that is directly jeopardized by the forced outage of the subject line Miles of Exposure = Number of miles between two existing automatic sectionalizing devices (MOABs or CBs) plus new tap line length Pf = Permanent forced outage rate of the subject line (outages/year/mile). If the outage rate of the subject line is not available, a five year system average outage rate can be used. TRANSMISSION PLANNING GUIDELINE TITLE: AEP Guide for the Application of In-Line Manual Switches, Automatic Switches or Circuit Breakers Rev. 0 TP-000004 Page 95 of 98 Appendix J CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. Install MOAB switches if the “FOI” is equal to or greater than six (6.0) The following exceptions apply: 1. The P&C guidelines (“Motor Operated Air Break Switches SS-476010”) require that the number of in-line MOAB switches be limited to three (3) on a transmission circuit. If more than three automatic sectionalizing devices are required, installation of a CB is to be considered. 2. AEP reserves the right to disallow application of in-line MOABs where the existing protection system is incompatible with in-line MOABs. 3. AEP reserves the right to request the installation of a Circuit Switcher instead of a MOAB if deemed necessary when considering P&C, physical location, or the critical nature of the transmission line. 8.3 Justification for In-Line Circuit Breaker (CB) Installation of an in-line CB(s) at the point where load is connected to a transmission system improves the automatic line sectionalizing capability of the circuit and reliability of service to the load, both from the momentary as well as from the permanent forced outage standpoints. In order to determine if a CB is required, a factor referred to as the ‘Momentary Permanent Outage Index (MPOI)” is calculated and compared with the established threshold index value. The MPOI is defined as: MPOI = Load (Lf) X Miles of Exposure X Forced Outage Rate {Permanent Forced Outage Rate (Pf) + Momentary Forced Outage Rate (Mf)} Where; Lf = Peak load (MW) directly jeopardized by the forced outage of the subject line Miles of Exposure = Number of miles between two existing automatic sectionalizing CBs, plus new tap line length Forced Outage Rate (outages/year/mile) = Permanent forced outage rate (Pf) + Momentary forced outage rate (Mf) Install a CB if the “MPOI” is equal to or greater than two hundred (200). TRANSMISSION PLANNING GUIDELINE TITLE: AEP Guide for the Application of In-Line Manual Switches, Automatic Switches or Circuit Breakers Rev. 0 TP-000004 Page 96 of 98 Appendix J CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. The following exceptions apply: 1). In situations where the calculated MPOI is less than 200 and power quality is a concern due to forced momentary outages, installation of a CB can be considered. 2). If the FOI calculation (Section 8.2) indicates a justification for a MOAB installation on a circuit that already contains three (3) in-line MOAB switches, a CB installation should be considered. 3). If a circuit is critical for overall system reliability or as an outlet for generation, installation of a CB should be considered. TRANSMISSION PLANNING GUIDELINE TITLE: AEP Guide for the Application of In-Line Manual Switches, Automatic Switches or Circuit Breakers Rev. 0 TP-000004 Page 97 of 98 Appendix J CAUTION: Printed copies of this document are uncontrolled and may be obsolete. Always check for the latest revision prior to use. APPENDIX A A - Typical In-Line Transmission Tap Supply & Line Looped Supply Configurations Typical Transmission Tap Supply Configurations Figure 1 Radial Line Supply Alternatives - For Facilities below 200 kV Non-Generators - Connected to an Existing Station Typical Transmission Line Looped Supply Configurations Figure 2 Loop Supply Alternatives - For Facilities below 200 kV Non-Generators - Looped Service [Note: Figrue 1 and 2 are also included in Appendix B of the main document (TP-000001) and were therefore removed from this copy of document TP000004] Note: This document has been prepared by, and is the property of, American Electric Power Company, Inc. , is intended for AEP use only, is not to be used for any purpose detrimental to AEP’s interest, and is not to be furnished to, or copied or reproduced by, parties not affiliated with the AEP system without the express written consent of AEP, and is to be returned upon request. TRANSMISSION PLANNING GUIDELINE TITLE: AEP Guide for the Application of In-Line Manual Switches, Automatic Switches or Circuit Breakers Responsible Engineer: M. Ahmed Copyright 2007 American Electric Power Company, Inc Rev. 0 TP-000004 Page 98 of 98