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Three Park Avenue New York, New York 10016-5997, USA All rights reserved. This document is an unapproved draft of a proposed IEEE Standard. As such, this document is subject to change. USE AT YOUR OWN RISK! Because this is an unapproved draft, this document must not be utilized for any conformance/compliance purposes. Permission is hereby granted for IEEE Standards Committee participants to reproduce this document for purposes of IEEE standardization activities only. Prior to submitting this document to another standards development organization for standardization activities, permission must first be obtained from the Manager, Standards Licensing and Contracts, IEEE Standards Activities Department. Other entities seeking permission to reproduce this document, in whole or in part, must obtain permission from the Manager, Standards Licensing and Contracts, IEEE Standards Activities Department. IEEE Standards Activities Department Standards Licensing and Contracts 445 Hoes Lane, P.O. Box 1331 Piscataway, NJ 08855-1331, USA Abstract: Introduction (This introduction is not part of IEEE P DOCPROPERTY "Designation" \* MERGEFORMAT xxxx/D DOCPROPERTY "DraftNumber" \* MERGEFORMAT 6, Draft  DOCPROPERTY "OptTrialUse" \* MERGEFORMAT  DOCPROPERTY "GorRPorSTD" \* MERGEFORMAT Guide for  DOCPROPERTY "PAR" \* MERGEFORMAT the Specification of Fixed Series Capacitor Banks for Transmission System Applications.) The purpose of this Guide is to provide general guidelines toward the preparation of a functional specification of transmission fixed series capacitor banks (FSC) using overvoltage protection based on three technologies: metal oxide varistors, metal oxide varistors with a forced bypass gap and thyristor valve bypass. This document is dedicated to memory of Stan Miske our friend and colleague. Patents Attention is called to the possibility that implementation of this  DOCPROPERTY optTrialUse \*Lower \* MERGEFORMAT  DOCPROPERTY GorRPorSTD \*Lower \* MERGEFORMAT guide may require use of subject matter covered by patent rights. By publication of this  DOCPROPERTY optTrialUse \*Lower \* MERGEFORMAT  DOCPROPERTY GorRPorSTD \*Lower \* MERGEFORMAT guide, no position is taken with respect to the existence or validity of any patent rights in connection therewith. The IEEE shall not be responsible for identifying patents or patent applications for which a license may be required to implement an IEEE standard or for conducting inquiries into the legal validity or scope of those patents that are brought to its attention. Participants This standard was revised by a working group sponsored by the Capacitor Subcommittee of the Transmission and Distribution Committee of the IEEE Power Engineering Society. At the time this standard was approved, the Capacitor Subcommittee consisted of the following membership: J. H. Nelson (Jeff), Chairman T. Grebe (Tom), Vice-Chairman C. L. Fellers, Secretary I. Ares S. EdmondsonS. B. LaddD. R. Ruthman S. AshmoreC. ErvenG. E. LeeJ. SamuelssonB. BhargavaK. FenderA. S. MehrabanE. SanchezJ. A. BonnerC. GouglerJ. ManeatisR. SevignyS. CesariP. GriesmerM. A. McVeyP. SteciukB. ChaiJ. E. HarderS. A. Miske, Jr.R. S. ThallamS. ChanoL. HollomanW. E. ReidS. ColvinI. HorvatS. Rios-Marcuello At the time this draft  DOCPROPERTY "OptTrialUse" \* MERGEFORMAT \*Lower DOCPROPERTY "GorRPorSTD" \* MERGEFORMAT \*Lowerguide was completed, the  DOCPROPERTY "WorkingGroup" \* MERGEFORMAT Series Capacitor Working Group of the Capacitor Subcommittee had the following membership:  DOCPROPERTY "WkGrpChair" \* MERGEFORMAT Bruce English, Chair  DOCPROPERTY "WkGrpViceChair" \* MERGEFORMAT Mark McVey, Vice-chair Bharat BhargavaClay Fellers Carlet LangfordR. Vittal RebbapragdaPierre BilodeauKarl FenderGerald LeeJan. SamuelssonMarcello CapistranoLuther HollomanPer LindbergRichard SevignyBill ChaiIvan HorvatBen MehrabanKeith StumpStuart EdmonsonJohn JoyceRichard PiwkoRao Thallam The following members of the balloting committee voted on this  DOCPROPERTY "OptTrialUse" \*Lower \* MERGEFORMAT  DOCPROPERTY "GorRPorSTD" \*Lower \* MERGEFORMAT guide. Balloters may have voted for approval, disapproval, or abstention. (to be supplied by IEEE)  COMMENTS \* MERGEFORMAT  CONTENTS  TOC \t "Heading 1,1,Heading 2,2,IEEEStds Level 1 Header,1,IEEEStds Level 2 Header,2" \* MERGEFORMAT 1. Overview  PAGEREF _Toc125011370 \h 1 1.1 Scope  PAGEREF _Toc125011371 \h 1 1.2 Purpose  PAGEREF _Toc125011372 \h 1 1.3 Application  PAGEREF _Toc125011373 \h 1 2. Normative references  PAGEREF _Toc125011374 \h 2 3. Definitions and acronyms  PAGEREF _Toc125011375 \h 2 3.1 Definitions  PAGEREF _Toc125011376 \h 2 3.2 Acronyms and abbreviations  PAGEREF _Toc125011377 \h 6 4. FSC project description  PAGEREF _Toc125011378 \h 7 5. Scope of supply and schedule  PAGEREF _Toc125011379 \h 9 5.1 Scope of supply  PAGEREF _Toc125011380 \h 9 5.2 Schedule  PAGEREF _Toc125011381 \h 10 6. Site and environmental data  PAGEREF _Toc125011382 \h 11 7. Power system characteristics  PAGEREF _Toc125011383 \h 11 8. Main FSC characteristics  PAGEREF _Toc125011384 \h 12 8.1 Overall FSC bank ratings  PAGEREF _Toc125011385 \h 12 8.2 Protection and control philosophy  PAGEREF _Toc125011386 \h 12 8.3 Watts loss evaluation  PAGEREF _Toc125011387 \h 13 8.4 Reliability, availability, and maintainability  PAGEREF _Toc125011388 \h 13 9. FSC main component requirements  PAGEREF _Toc125011389 \h 13 9.1 Capacitors  PAGEREF _Toc125011390 \h 13 9.2 Varistors  PAGEREF _Toc125011391 \h 13 9.3 Triggered bypass gaps  PAGEREF _Toc125011392 \h 14 9.4 Thyristors and thyristor reactors  PAGEREF _Toc125011393 \h 14 9.5 Insulation and air clearances  PAGEREF _Toc125011394 \h 14 9.6 Discharge current limiting and damping equipment  PAGEREF _Toc125011395 \h 14 9.7 Bypass switches  PAGEREF _Toc125011396 \h 14 9.8 External bypass disconnect switches  PAGEREF _Toc125011397 \h 14 9.9 Protection, control, and monitoring  PAGEREF _Toc125011398 \h 14 9.10 Steel platforms, support structures, seismic design requirements  PAGEREF _Toc125011399 \h 15 10. Spare parts and special tools  PAGEREF _Toc125011400 \h 15 11. Engineering studies  PAGEREF _Toc125011401 \h 15 12. Tests and quality assurance  PAGEREF _Toc125011402 \h 15 13. Safety  PAGEREF _Toc125011403 \h 15 14. Documentation  PAGEREF _Toc125011404 \h 16 15. Training  PAGEREF _Toc125011405 \h 16 16. Balance of plant  PAGEREF _Toc125011406 \h 16 Annex A (informative) Bibliography  PAGEREF _Toc125011407 \h 17 Annex B (informative) Notes for a functional specification  PAGEREF _Toc125011408 \h 18 B.1 FSC project description, see Clause 4  PAGEREF _Toc125011409 \h 18 B.2 Scope of supply and schedule, see Clause 5  PAGEREF _Toc125011410 \h 20 B.3 Site and environmental data, see Clause 6  PAGEREF _Toc125011411 \h 21 B.4 Power system characteristics, see Clause 7  PAGEREF _Toc125011412 \h 21 B.5 Main FSC characteristics, see Clause 8  PAGEREF _Toc125011413 \h 22 B.6 FSC main component requirements, see Clause 9  PAGEREF _Toc125011414 \h 33 B.7 Spare parts and special tools, see Clause 10  PAGEREF _Toc125011415 \h 35 B.8 Engineering studies, see Clause 11  PAGEREF _Toc125011416 \h 35 B.9 Tests and quality assurance, see Clause 12  PAGEREF _Toc125011417 \h 36 B.10 Safety, see Clause 13  PAGEREF _Toc125011418 \h 36 B.11 Documentation, see Clause 14  PAGEREF _Toc125011419 \h 36 B.12 Training, see Clause 15  PAGEREF _Toc125011420 \h 36 B.13 Balance of plant, see Clause 16  PAGEREF _Toc125011421 \h 36 Annex C (informative) Subsynchronous resonance risk on turbine generators  PAGEREF _Toc125011422 \h 37 C.1 Subsynchronous Resonance (SSR)  PAGEREF _Toc125011423 \h 37 C.2 Interaction Between Electrical and Mechanical Resonant Systems  PAGEREF _Toc125011424 \h 39 C.3 SSR Instability  PAGEREF _Toc125011425 \h 40 C.4 Transient Torque Amplification  PAGEREF _Toc125011426 \h 40 C.5 SSR Mitigation and Protection  PAGEREF _Toc125011427 \h 41 C.6 SSR Protection  PAGEREF _Toc125011428 \h 42 C.7 Conclusions:  PAGEREF _Toc125011429 \h 43 Annex D (informative) Effects of series capacitors on line breaker TRV  PAGEREF _Toc125011430 \h 44 Annex E (informative) Impact of series capacitors on line overvoltages and secondary arc extinction  PAGEREF _Toc125011431 \h 45 Annex F (informative) Power system modeling for use in FSC equipment rating studies  PAGEREF _Toc125011432 \h 46 F.1 Defining a Power System Equivalent Circuit and Associated Fault Currents for Use in Defining the Fault Withstand Requirements of Series Capacitor Protective Devices.  PAGEREF _Toc125011433 \h 46 F.2 Discussion of system studies for determining the ratings for varistors and thyristor valves  PAGEREF _Toc125011434 \h 47 Annex G (informative) Impact of line harmonics on the design and protection of FSC banks  PAGEREF _Toc125011435 \h 49 Annex H (informative) Fault current discussion  PAGEREF _Toc125011436 \h 50 H.1 Waveforms and analytical expressions of fault currents in inductive and series compensated networks  PAGEREF _Toc125011437 \h 50 H.2 Modeling of series capacitors in traditional short circuit calculations.  PAGEREF _Toc125011438 \h 55 H.3 Modeling of series capacitors in transient short circuit calculations.  PAGEREF _Toc125011439 \h 55 H.4 Definition of Total Fault Current and Through Fault Current (Partial Fault Current)  PAGEREF _Toc125011440 \h 56  Draft  DOCPROPERTY "OptTrialUse" \* MERGEFORMAT  DOCPROPERTY "GorRPorSTD" \* MERGEFORMAT Guide for  DOCPROPERTY "PAR" \* MERGEFORMAT the Specification of Fixed Series Capacitor Banks for Transmission System Applications Overview Scope This Guide provides general guidelines toward the preparations of a functional specification of transmission fixed series capacitor banks (FSC) using overvoltage protection based on three technologies: metal oxide varistors metal oxide varistors with a forced triggered bypass gaps thyristor valve bypass The commercial aspects of the specification for a particular project are outside the scope of this Guide. This Guide does not apply comprehensively to Thyristor Controlled Series Capacitors. A more complete reference is IEEE 1534-2002. The Standard for Fixed Series Capacitors is reference IEEE 824- 2004. Purpose Starting at Clause 4, this document presents technical clauses that may be used as the basis of a functional FSC specification. Within this document “should” is deliberately used rather than “shall” because this is a Guide, not a specification. However if these clauses are used in the specification for a specific project, the wording should be adjusted accordingly. The Annexes of this Guide include related explanatory information. The same numbering as the main part of the document references this information. Application This Guide should be considered a general purpose resource and does not include all details needed for a specific application. In addition, since transmission FSC banks are typically designed to address a specific application, not every part of this guide may be applicable. The user of this guide should evaluate how and to what extent each clause applies to the development of a specification for a specific application. Normative references The following referenced documents are indispensable for the application of this document. For dated references, only the edition cited applies. For undated references, the latest edition of the referenced document (including any amendments or corrigenda) applies. IEEE Std 824-2004, IEEE Standard for Series Capacitor in Power Systems. IEEE Std 1534-2002, IEEE Recommended Practice for Specifying Thyristor-Controlled Series Capacitors IEEE Std 693-1997, IEEE Recommended Practices for Seismic Design of Substations Definitions and acronyms For the purposes of this draft  DOCPROPERTY optTrialUse \*Lower \* MERGEFORMAT  DOCPROPERTY GorRPorSTD \*Lower \* MERGEFORMAT guide, the following terms and definitions apply. The Authoritative Dictionary of IEEE Standards, Seventh Edition, should be referenced for terms not defined in this clause. Definitions The meaning of other terms used in this standard shall be as defined in The Authoritative Dictionary of IEEE Standards Terms, Seventh Edition [B1]2 ambient temperature: The temperature of the air into which the heat of the equipment is dissipated. asymmetrical fault current: Total Symmetrical current plus DC component bypass current: The current flowing through the bypass switch, protective device, or other devices, in parallel with the series capacitor. bypass gap: A system of specially designed electrodes arranged with a defined spacing between them in which an arc is initiated to form a low impedance path around one segment or a sub-segment of the series capacitor bank. The conduction of the bypass gap is typically initiated to limit the voltage across the series capacitors and/or limit the duty to the varistor connected in parallel with the capacitors. The bypass gap includes the electrodes that conduct the bypass current, the triggering circuit (if any) and an enclosure. (See  REF _Ref125003152 \w \h Figure 1) bypass switch: A device such as a switch or circuit breaker used in parallel with a series capacitor and its protective device to bypass or insert the series capacitor bank for some specified time or continuously. This device shall also have the capability of bypassing the capacitor during specified power system fault conditions. . The operation of the device is initiated by the capacitor control, remote control or an operator . The device may be mounted on the platform or on the ground near the platform. (See  REF _Ref125003152 \w \h Figure 1) capacitor unit: See “power capacitor”. capacitor element: The basic component of a capacitor unit consisting of two electrodes separated by a dielectric. capacitor rack: A frame that supports one or more capacitor units. discharge current limiting reactor: A reactor to limit the current magnitude and provide damping of the oscillatory discharge of the capacitors during a closing operation of the bypass switch or the start of conduction of the bypass gap. (See  REF _Ref125003152 \w \h Figure 1) discharge device: An internal or external device permanently connected in parallel with the terminals of a capacitor for the purpose of reducing the trapped charge after the capacitor bank is disconnected from the energized power system. external fuse (of a capacitor unit): A fuse located outside of the capacitor unit that is connected in series with the unit. external line fault: A fault that occurs on adjacent lines or equipment other than on the transmission line that includes the series capacitor installation. fixed series capacitors (FSC): A series capacitor bank that has a reactance or reactances that are defined by the discrete reactances of the capacitors and are not variable. forced-triggered bypass gap: A bypass gap that is designed to operate on external command on quantities such as varistor energy, current magnitude, or rate of change of such quantities. The spark over of the gap is initiated by a trigger circuit. After initiation, an arc is established in the power gap. Forced-triggered gaps typically spark over only during internal faults. fuseless capacitor bank: A capacitor bank without any fuses, internal or external, which is constructed of (parallel) strings of capacitor units. Each string consists of capacitor units connected in series. insertion: The opening of the capacitor bypass switch to insert the series capacitor bank in series with the line. insertion current: The rms (root mean squared) current that flows through the series capacitor bank after the bypass switch has opened. This current may be at the specified continuous, overload or swing current magnitudes. insertion voltage: The peak voltage appearing across the series capacitor bank upon the interruption of the bypass current with the opening of the bypass switch. insulation level: The combination of power frequency and impulse test voltage values that characterize the insulation of the capacitor bank with regard to its capability of withstanding the electric stresses between platform and earth, or between platform-mounted equipment and the platform. internal fuse (of a capacitor): A fuse connected inside a capacitor unit, in series with an element or a group of elements. internally fused capacitor (unit). A capacitor unit, which includes internal fuses. internal line fault: A fault that occurs on the transmission line section that includes the series capacitor installation. platform: A structure that supports one or more segments of the bank and is supported on insulators compatible with line-to-ground insulation requirements. platform-to-ground communication insulator: An insulator that encloses communication signal paths between platform and ground level. power capacitor (capacitor, capacitor unit): An assembly of dielectric and electrodes in a container (case), with terminals brought out, that is intended to introduce capacitance into an electric power circuit. protective device: A bypass gap, varistor, or other device that limits the voltage on the capacitor segment or sub-segment to a predetermined level when overcurrent flows through the series capacitor. protective level: The magnitude of the maximum peak of the power frequency voltage allowed by the protective device during a power system fault. The protective level may be expressed in terms of the actual peak voltage across a segment or sub-segment or in terms of the per unit of the peak of the rated voltage across the segment or sub-segment. reinsertion: The restoration of load current to the series capacitor from the bypass path. reinsertion current: The transient current, power frequency current, or both, flowing through the series capacitor bank after the opening of the bypass path. reinsertion voltage: The transient voltage, steady-state voltage, or both, appearing across the series capacitor after the opening of the bypass path. series capacitor bank: A three-phase assembly of capacitor units with the associated protective devices, discharge current limiting reactors, protection and control system, bypass switch and insulated support structure that has the primary purpose of introducing capacitive reactance in series with an electric circuit. series capacitor installation: An installed series capacitor bank complete with disconnect switches. sub-segment: A portion of a segment that includes a single-phase assembly capacitor units and associated protective device, discharge current limiting reactor, and selected protection and control functions but does not have a dedicated bypass switch. (See  REF _Ref125003152 \w \h Figure 1) segment: A single-phase assembly of capacitor units and associated protective device, discharge current limiting reactor, protection and control functions and one phase of a bypass switch. (see  REF _Ref125003152 \w \h Figure 1). Segments are not normally separated by isolating disconnect switches. More than one segment can be on the same insulated platform. switching step: A three-phase assembly that consists of one segment per phase, with a three phase operating bypass switch for bypassing or inserting the capacitor segments (see  REF _Ref125003152 \w \h Figure 1). This is sometimes referred to as a capacitor module. thyristor protected series capacitor bank (TPSC): A fixed series capacitor bank equipped with thyristor valve configured to fast bypass and/or provide capacitor overvoltage protection. (see Annex  REF _Ref125003557 \w \h B.5.1) The thyristor valve circuit consists of a services of anti-parallel thyristor levels and a current limiting reactor. In a TPSC application the thyristor is switched to a conductive condition at the specified protection level by the control and protection system. When the line current returns to nominal value or bypass switch closes the thyristor valve is blocked. valve element (of a varistor unit): A single nonlinear resistor disc used in a surge arrester or varistor unit. varistor: An assembly of varistor units that limit overvoltages to a given value. In the context of series capacitor banks, the varistor is typically defined by its ability to divert fault current around the series capacitor units, limiting the voltage to a specified protective level while absorbing energy. The varistor is designed to withstand the temporary overvoltages and continuous operating voltage across the series capacitor units. varistor coordinating current: The varistor current magnitude associated with the protective level. The varistor coordinating current waveform is considered to have a virtual front time of 30-50 (s. The tail of the waveform is not significant in establishing the protective level voltage. varistor energy rating: The maximum energy the varistor can absorb within a short period of time without being damaged due to thermal shock or due to thermal runaway during the subsequent applied voltage. This rating is based on the duty cycle defined by the purchaser. This is the useable rating after taking into account factors such as current sharing among parallel columns. The additional energy absorption capability of the spare units is not normally included in this rating. varistor maximum continuous operating voltage: The rated rms voltage of the capacitor segment that the varistor is connected across. varistor unit: A single insulated enclosure containing one or more valve elements in series and possibly in parallel. voltage-triggered bypass gap: A bypass gap that is designed to spark over on the voltage that appears across the gap terminals. The spark over of the gap is normally initiated by a trigger circuit set at a specified voltage level. A voltage-triggered bypass gap may be used for the primary protection of the capacitor and may spark over during external as well as internal faults. trigger circuit: The part of the bypass gap that initiates the spark over of the bypass gap at a specified voltage level or by external command. —Typical FSC Installation Nomenclature NOTES1Segment (1F)7Bypass switch2Switching step (3F)8Additional switching steps when required3Capacitor units9External bypass disconnect switch4Discharge current limiting reactor10External isolating disconnect switch5Varistor11External grounding disconnect switch6Bypass gap12Subsegment Acronyms and abbreviations BIL basic impulse level CT current transformer EMI electromagnetic interference ETT electrically triggered thyristors FACTS flexible AC transmission systems FSC fixed series capacitor GTO gate turn-off HV high-voltage HVDC high-voltage direct current LTT light-triggered thyristors LV low-voltage MSC mechanically switched capacitor MSR mechanically switched reactor PCC point of common coupling PT potential transformer RI radio interference RMS root-mean-square SSR subsynchronous series resonance STATCOM static compensator SVC static var compensator SVS static var system SWC surge withstand capability TCSC thyristor controlled series capacitor TIF telephone influence factor TPSC thyristor protected series capacitor TNA transient network analyzers TSC thyristor-switched capacitor TSR thyristor-switched reactor TVI television interference V/I voltage/current FSC project description This specification is for the design, manufacture of equipment, construction, installation, test, commission, warranty, training, and placement into commercial operation of a FSC bank(s) at ___________ substation on the ___________ kV transmission line(s) connecting ___________ to ___________. The FSC bank(s) will provide ___________ % reactive compensation on these lines. The purpose of the FSC is to (1) increase power flow capacity of ___________ kV transmission lines, (2) increase transient stability of ___________ kV transmission system, (3) balance and/or control power flow through multiple adjacent lines through the use of FSC banks with multiple switching steps. The nominal ratings of the FSC bank(s) are ___________ Amps continuous, ___________ Ohms capacitive reactance, and ___________ MVAR per bank. The regional and local site location map is shown in Figure ___________. A proposed one-line diagram of the substation after installation of the FSC bank is shown in Figure ___________. The area for the FSC facility is shown in Figure ___________. The points of electrical interconnection of the supplier-furnished FSC facilities are shown on the following figures:  REF _Ref125003055 \w \h Figure 2,  REF _Ref125003059 \w \h Figure 3, and  REF _Ref125003060 \w \h Figure 4 show examples of typical FSC bank one-line diagrams. ___________ (power system) ___________ (ground grid, soil resistivity) ___________ (station service power) ___________ (control and protection) ___________ (fencing) ___________ (site sub-surface and geotechnical data) ___________ (other)  —Example Single-Line Diagram, FSC Bank with MOV Plus Triggered Air Gap  —Example Single Line Diagram, “Gapless” FSC Bank with MOV and Bypass Switch  —Example Single Line Diagram, TPSC See Annex  REF _Ref124994786 \w \h B.1 for additional discussion of the FSC specification overall project description. Scope of supply and schedule Scope of supply Supplier-furnished scope of supply The equipment, materials, and services to be furnished by the supplier include, but are not limited to, the following: Capacitor units, mounting racks, and protective fusing (if applicable) Metal oxide varistors Discharge current limiting reactors Parallel damping resistors (if applicable) Triggered bypass gaps (if applicable) Bypass switches Bypass switch interpole wire and cable Wire and cable from bypass switch to ground-based control systems Equipment support insulators Steel platform assemblies Platform support insulation Removable maintenance ladders for each platform Current transformers and optical signal (e.g. A/D) converters and transmitters Fiber optic signal column(s) Fiber optic cabling from signal column to ground-based control systems Ground-based protection and control systems Set of external motor operated disconnect switches including a bypass disconnect and two isolating disconnect switches with grounding blades. Wire and cable from disconnect switches to ground-based control systems Electical buswork, fittings, and connectors Digital fault recorder Sequence of events recorder Installation supervision Special maintenance equipment and tools Training program for operation and maintenance personnel Spare parts Testing and commissioning services Documentation including instruction manuals Engineering and design calculations and equipment ratings studies Other system studies as applicable (e.g. SSR, TRV, system stability) For turnkey supply, the following are added: Civil works for the FSC bank, including the cable trenching, fencing, drainage, access, rock coverings, and lighting. FSC bank control building, including grounding. Ground grid. FSC bank foundations and structures to mount bus support insulation and disconnect switches, including grounding and ground mat connections. Construction and erection of all equipment up to, but not including, line drops (connections from disconnect switches to transmission line). User-furnished scope of supply The equipment, materials, information, and services to be furnished by the user include, but are not limited to, the following: The nonelectrical data to be supplied by the user is given in Clause 6; the electrical data is in Clause 7, Clause 8, and Clause 9. Site for the FSC bank will be available _________ calendar days after contract start Source of water for construction Source of temporary station service power for construction at ________ kV, available ________ calendar days after contract start ________ sources of permanent station service power for the FSC bank equipment at _________ kV, available _________ calendar days after contract start Existing facilities and equipment Timely approval of design reports and drawings and release for manufacture and construction, as applicable, _________ calendar days after document submittal. Line drop connection services. See Annex  REF _Ref124995724 \n \h B.2.1 for guidance on developing a scope split section to the specification. Technical clarifications and exceptions All equipment should be designed as needed to meet the requirements of this specification. All exceptions from the requirements in the specification shall be clearly stated by the supplier in a separate list of deviations in the bid documentation. All technical exceptions and clarifications should list the clause of this specification they do not meet or that applies to the clarification being made, a description of the exception or clarification, and a reason for not meeting the requirement as applicable. Schedule Project completion is ________ calendar days after contract start. The supplier’s project schedule is due _______ calendar days after contract start and should include such details as dates for commencement and completion of work on several key features of the project, dates for user-furnished services, dates on which supplier-furnished drawings will be provided and approval given, dates for any required design and production testing of all major equipment, and dates and length of time of any required power outages. Design review meetings should be held between the user and supplier to review and discuss progress of the design and supply of the FSC bank(s). The first design review should be held within ______ calendar days after contract start. Subsequent design reviews should be held every __________ calendar days. Site and environmental data The FSC bank(s) should be designed to meet all rating and performance requirements specified in this document while operating in the following site and environmental conditions: Site elevation above sea levelMMaximum ambient dry-bulb temperature(CMaximum ambient wet-bulb temperature(CMinimum ambient air temperature(CMaximum daily average ambient air temperature(CMinimum daily average ambient air temperature(CIce loading conditionskg/m2Maximum ground snow depthmMaximum frost depthmMaximum steady wind velocitym/sMaximum wind gustm/sSeismic zone and withstand dataDust concentration level or pollution levelmg/cm2Salt concentrationmg/cm2Solar radiation levelW/cm2Earth resistivityOhm-m Power system characteristics The following AC power system characteristics apply. Nominal AC system voltage, line-to-linekVMaximum continuous AC system voltage, line-to-linekV Maximum short-term AC system voltage, line-to-linekVLightning impulse protective level for line-to-ground insulationkV peakSwitching surge withstand insulation level for line-to-ground insulationkV peakWet-withstand (10-second AC) insulation level for line-to-ground insulationkVCreepage distance requirement for insulatorsmm/kVSystem power frequencyHzMaximum three-phase symmetrical fault currentkA Maximum three-phase asymmetrical fault currentkA peakMaximum single-phase symmetrical fault currentkA Maximum single-phase asymmetrical fault currentkA peakMaximum three-phase short-circuit strength at terminals of FSC bankMVAImpedance angle of above short-circuit strengthdegreesSignificant system harmonic current magnitudeAFrequencies of significant harmonic currentsHz Main FSC characteristics Overall FSC bank ratings Protection and control philosophy Protection and control functions The purchaser should include in his specification that the following functions be provided for the bank. Further discussion is included in IEEE Protection Guide. In addition the purchaser should indicate if automatic reinsertion should be provided. Protection functions against overstress from system conditions Capacitor overload protection This is a function of the specified overload current requirements for the bank and utility practices. Varistor fault energy protection This function is achieved by measuring varistor current and deducing varistor energy. This function may also include monitoring the magnitude of the varistor current. Varistor overtemperature protection This function is achieved by measuring varistor current and deducing varistor temperature. Bypass gap protections Bypass gap protections typically include detection of prolonged gap conduction. Discharge current limiting reactor harmonic overcurrent protection (optional) This function detects excessive harmonic current in the reactor. Protection functions associated with equipment failure or malfunction Capacitor unbalance Platform fault Bypass gap failure Varistor failure Bypass switch failure Pole disagreement Protection & control system failure Control functions Bypassing Insertion (automatic or manual) and reinsertion Lockout Temporary block insertion Operation of disconnect switches Degree of redundancy It is important that the the purchaser carefully specify the desired level of redundancy. Items that may be specified to have redundancy are shown in the following list. It may also be specified by the purchaser that the two protection systems be physically separate, each in its own cabinet. The purchaser may specify if the protection system is to be operated from one or two station batteries and the degree of separation between the supplies that is required within the series capacitor bank protection and control system. Digital controllers and relays Power supplies Platform-to-ground communication insulators Current transformers and current sensors Circuits to trigger the forced triggered gap Closing coils for the bypass switch Control of the external disconnect switches The disconnect switches associated with the series capacitor bank can be controlled by the series capacitor control system or by the control system of the associated substation. If these switches are to controlled by the series capacitor bank control system that desire should be stated in the specification. The following additional functions are often provided and should be specified if desired. Interlocking so that the bypass switch and an the three switches will only operate in the proper sequences. Automatic isolation of the bank via the disconnect switches for certain equipment contingencies for which the bank should be isolated from the power system. Monitoring requirements (DFR, SER) Watts loss evaluation Reliability, availability, and maintainability FSC main component requirements Capacitors Capacitor fusing Varistors Triggered bypass gaps Thyristors and thyristor reactors Thyristor valves Thyristor valve reactors Insulation and air clearances Discharge current limiting and damping equipment Current limiting reactors Parallel damping circuits Bypass switches External bypass disconnect switches Protection, control, and monitoring Current transformers Location of protection and control equipment Series capacitor installations usually have the protection and control equipment located in one of two possible locations: in an outdoor building near fence surrounding the series capacitor bank or indoor in a building associated with the substation at which the bank is installed. Outdoor building: The supplier may be required to provide and install the outdoor building. The building is usually built to the standards of the purchaser. In addition to the series capacitor protection and control system the building may include: Ac and dc distribution panels Battery for control power Heating and cooling for the building Motor generator set for back up power Substation building: The supplier may be required to provide equipment to be installed in the substation building in the space allotted by the purchaser. In this case the purchaser may prefer that the supplier’s equipment have the same physical size and appearance as the other protection and control equipment in the building. Such preferences are usually achievable but this requires the supplier to deviate from his optimized arrangement. Extent and format for remote indications Series capacitor protection systems provide alarm and indication outputs for the purchaser to transmit to remote locations. Since the number of protection functions included in a series capacitor bank is typically extensive, the purchaser should specify if the information must be provided: To identify which segment has the alarm condition or is it sufficient to provide the alarm on a bank basis via dry contacts is one contact per indication sufficient or are multiple contacts required via a digital protocol and if so what type Available supply voltages The purchaser should indicate in the specification the ac and dc supply voltages that will be provided for the protection and control system and the bypass switch and disconnect switches. Fiber optic signal columns, fiber optic cable, and connector requirements Wire, cable, terminal blocks, and control circuit connection requirements Steel platforms, support structures, seismic design requirements Spare parts and special tools The supplier shall furnish recommended spare parts for of the SC system as well as all special tools needed for the trouble shooting, maintenance and parts exchange within the SC, as required. The scope of spare parts and special tools must be coordinated with the requirements and guarantees for reliability and availability. Engineering studies Tests and quality assurance Safety Safety is commonly not the first consideration when building or designing a series capacitor bank. The electrical specification in standard 824 is written to provide electrical safety for key components but does not deal with the practical aspects of working on the series capacitor bank. Components that are sized and placed in the series capacitor bank may have proper electrical clearances but may not have practical space considerations for maintenance. Allow plenty of room to properly work with tools or movement around components. Lack of space on the catwalk may provide a fall hazard, depending on how the railing is designed. Attachments for fall harness may be required by OSHA regulations if ladder access is required on equipment. Make sure proper harness attachments are available for maintenance personnel. Make sure that grounding points are located on the structure that can handle the amount of fault current that can be supplied in the event of accident. Even the location of the foundation may be a safety consideration if a bucket truck is required for installation or maintenance. The design of a series capacitor bank is more than just electrical specification. The design must involve a working knowledge of how the devise will be maintained and operated. The IEEE standard 824 section 10 provides guidance on many issues dealing with specific codes and protection. Documentation Supply of the following documentation shall be part of the supplier’s Scope of Work: All drawings, instructions and manuals necessary to operate and maintain the SC and associated equipment. The drawings shall include the complete set of plans, elevations, sections, details, wiring, schematics, piping, etc. of the complete SC system. Training The supplier shall provide training for the SC system. The suppler shall determine the content duration of each training session. The training should include training for the customer’s engineers, operators and maintenance personnel. Balance of plant (informative) Bibliography Goldsworthy, D. L.: “A linearized model for MOV-protected Series Capacitors” . IEEE Transactions on Power systems, Vol. 2, No. 4, pp 953-958, November 1987. J.W. Butler and C. Concordia, “Analysis of Series Capacitor Application Problems,” IEEE Transactions, Vol.56, 1937, pp.975-988. D.E. Walker, C. Bowler, R. Jackson, D. Hodges, “Results of SSR Tests at Mohave,” IEEE Transactions, Vol. PAS-94, No. 5, Sept/Oct 1975, pp.1878-1889. R.G. Farmer, B.L. Agarwal, “Use of Frequency Scanning Techniques for Subsynchronous Resonance, ” IEEE Transactions, Vol. PAS-98, No. 2, March/April 1979, pp. 341-348. J.F. Tang, J.A. Young, “Operating Experience of Navajo Static Blocking Filter,” IEEE PES Special Publication, 81TH0086-9-PWR, pp. 23-26. C.E.J. Bowler, D.H. Baker, “Operation and Test of the Navajo SSR Protective Equipment, ” IEEE Transactions, Vol. PAS-97, July/August 1978, No. 4, pp. 1030-1035. IEEE Subsynchronous Resonance Working Group, “Series Capacitor Controls and Settings as Countermeasures to Subsynchronous Resonance,” IEEE Transactions, Vol. PAS-101, No. 6, June 1982, pp1281-1287. R.J. Piwko, C.A. Wegner, S.J. Kinney, J.D. Eden, “Subsynchronous Resonance Performance Tests of the Slatt Thyristor-Controlled Series Capacitor,” IEEE Transactions on Power Delivery, Volume 11, Issue 2, April 1996 pp. 1112 – 1119. C.E.J. Bowler, “Understanding Subsynchronous Resonance,” IEEE PES Special Publication 76CH 1066-0, PWR, July 1976, pp. 66-73. IEEE Subsynchronous Resonance Working Group, “Terms, Definitions, and Symbols for Subsynchronous Oscillations,” presented at IEEE/PES 1984 Summer Meeting, IEEE Transactions on Power Apparatus and Systems, Vol. PAS-104, No. 6, June 1985, pp. 1326-1333. (informative) Notes for a functional specification This annex provides comment and discussion on the preparation of a FSC bank specification. Reference is made throughout this annex to the corresponding specification clauses. For ease of reference, the corresponding clauses from the main text have been referenced. The term “user” may include purchaser and consultant. FSC project description, see Clause  REF _Ref124994451 \r \h 4 The basic “high-level” functionality of a transmission line FSC bank is to compensate the inductive reactance of overhead lines. Planning and system configurations Capacitive Reactance per line : Typically, the series compensation in a transmission line is selected as a fixed percentage of the line inductive reactance. This percentage is selected from system power flow, system stability, short circuit and SSR studies based on: System stability requirements (more detail) Voltage profile Power flow on parallel paths Short circuit considerations SSR considerations on near by generators. Locationof series capcitor bank due to fault duty and economic comparison of bypass located in the middle of the line or end of line. Additional Growth Power Transfer Targets Finally, the economic/cost considerations, as the cost of series compensation will increase as the series compensation level is increased. Higher series compensation can improve system performance e.g. increase power flows on long lines, improve system stability and improve voltage profile. (*** Add voltage profile figure ***) The addition of series compensation will result in higher short circuit duties and may require costly mitigation measures for SSR, if they are close to generators with SSR risk. Based on these considerations, a fixed level of series compensation is selected. Where there are several parallel paths or transmission lines, the level of series compensation should be selected to either equalize the flows on the parallel circuits or to the optimize the power flow based on each circuits thermal capability. This fixed percentage can be anywhere from 20 to 80 percent of the line impedance. Series compensation is generally needed on long transmission lines for improving system stability and voltage profiles. It may be applied on short lines to balance the power flows. The series compensation range is kept below 100 percent (i) as it is desirable to keep the line to appear as net inductive (ii) to limit the short circuit duty contributions from other substations, (iii) to keep the resonant frequency (Xc/Xl x 60 Hz) of the transmission line below the system synchronous frequency. A fifty percent line compensation on a 200 mile long line with 0.6 ohms line impedance per mile would require 60 Ohms of series capacitive impedance (0.5 x 200miles x 0.6 Ohms = 60 Ohms). This is the “Capacitive Reactance”, of the series capacitors installed for the series compensating the line. Number of Series Capacitor Banks in a Transmission Line: This reactance per line is generally installed either as two sections at close to each line terminal or as a single capacitive reactance in the mid section of the line. More than two banks may be required on very long transmission lines. This is done to limit the design voltage of the series capacitor bank and to maintain a reasonable acceptable voltage profile on the transmission line. Series capacitors generally cause a step increase of voltage on the transmission line. Basically, the line inductive reactance causes a voltage drop when the power, which most of the time has a lagging power factor, flows on the transmission line. The capacitive reactance causes a step voltage increase with the lagging line current power factor. By splitting the line capacitive reactance, the step voltage increase can be split into half, thereby avoiding sudden voltage jumps in the line voltage profile and avoid the exceeding the maximum operating voltage of the transmission line. The number of capacitor banks in a transmission line are dependent on the line length, percent compensation, rated line current etc. Basically, the intent is to maintain the bank RMS voltage and transient voltages to a manageable design level. For a typical 500 kV system It is desirable to keep the series capacitor bank RMS voltages below 100 kV ( less than 25 %) and the transient voltages below 300kV( 3.00 per unit or below 50 %). Another reason for splitting the capacitive reactance is, simplifying design and manufacturing the series capacitor banks. For a 60 Ohms capacitor bank, with 3000Ampere RMS line current, the voltage developed across the series capacitor bank will be 180 kV rms. This may require transient voltages of up to four times the 180 kV, that is 720 kV peak voltages. By splitting the bank into two capacitor banks, this will be reduced to 90 kV RMS and 360 kV transient peak voltage thereby simplifying design and manufacturing. Additional banks at additional locations may be necessary if the voltage results in exceeding the maximum operating voltage of the transmission line. Number of Switching Steps in a Capacitor Bank: In late sixties and early seventies, when the series capacitors banks were installed, the series capacitor bypass and insertion technology used spark gaps which required that each bypassing step be limited to 15-18 kV RMS or 70-75 kV peak transient voltage across the switching step. This was necessary to meet the performance requirements of the spark gap and to ensure that the series capacitors would reinsert successfully, when a line fault on an adjacent lines is cleared. This required multiple switching steps for the typical series capacitor installed on a long transmission line and also complicated the reinsertion of the series capacitor switching segments. It also required higher spark gap levels (4.5 per unit) to ensure successful reinsertion. Thus anywhere from 3 to six switching steps were required in a series capacitor bank. This not only increased the cost of the series capacitor banks, but also degraded the performance of the series capacitor bank and the system by increasing the reinsertion time. Reinsertion of the switching step was also complicated by the dc offset which developed across each capacitor segment, when it reinserted. It was also necessary to allow enough time before reinsertion, to clear the ionized gases from spark over so that the gap developed voltage withstand strength. Improvements and developments in the bypass technology, today enables us to design and manufacturing series capacitor banks with bank voltages of up to 100 kV rms and 300 kV peak transient voltages. This enables majority of series capacitor banks to be manufactured as a single switching/step bank and has resulted in substantially reduced costs and superior performance. This has also reduced the risk of SSR on the generating machines as number of SSR probabilities that can occur with the multiple switching steps has been reduced. Future requirements for series capacitors When selecting the rating of the series capacitors, the future requirements such as higher percentage compensation, higher current rating, higher short circuit duties etc. should be considered. Some of the protective schemes require matched components and upgrading them may require complete replacement. It may be feasible to replace the series capacitors with higher size capacitor cans, but the bypass protective equipment which may cost 30 to 40 percent of the cost of the series capacitors may have to be replaced completely. Sometimes, it may be feasible to increase the current rating or the percent compensation using the existing bypass equipment, if a lower spark-over/bypass voltage protective system is acceptable. Some additional space on platform may also be provided to future increases. Bank topology and connection orientation The purchaser should decide if the reactor is in series with the capacitors or in the bypass path. Outline the advantages and disadvantages of each: Table  STYLEREF 1 \s B. SEQ Table \* ARABIC \s 1 1—Comparison of reactor connection strategy ConsiderationReactor in series withbypass pathcapacitorsOperating losses if the bank is normally insertedLowerHigherOperating losses if the bank is normally bypassedHigherLowerTransient oOvervoltages on the capacitorsLowerHigherRecovery voltage on bypass disconnect switchHigherLowerThe purchaser should decide on the orientation of the connection of the series capacitor bank into the power system. If the bank has one switching step, then one terminal of the bank is connected to the platform. Whether this terminal is connected to the substation side of the bank or the line side has implications for the voltages that appear from platform to ground and for the stress on the bank protective device if there is a fault from platform to ground. Discuss Scope of supply and schedule, see Clause  REF _Ref124994478 \r \h 5 Scope of supply, see Clause  REF _Ref124994495 \r \h 5.1 With the exception of the equipment, material and services furnished by the user, the supplier shall be responsible for the design, engineering, manufacturing, delivery, civil works, erection, installation, testing, commissioning and field verification of the SC. Project scopes can take a variety of forms ranging from a complete turnkey to supplying equipment based on a jointly developed design. Any equipment and/or function of the SC not specifically specified herein should be designed as required by the overall design of the SC system in order to ensure the satisfactory operation of the same. Site and environmental data, see Clause  REF _Ref124994521 \r \h 6 Normal service conditions (environmental) A series capacitor banks shall be capable of operation at their specified current, voltage, frequency ratings and specified fault operational sequences under the following conditions as specified in IEEE 824 section 4.1 : The elevation does not exceed 1000 m above sea level. The indoor and outdoor ambient temperatures are within the limits specified by the purchaser. The ice load does not exceed 19 mm(if applicable) Wind velocities are no greater than 128 km/h. The horizontal seismic acceleration (if applicable)of the equipment does not exceed 0.2 g and the vertical acceleration does not exceed 0.16 g when applied simultaneously at the base of the support insulators. For the purposes of this requirement, the values of acceleration are static. This is the “low seismic qualification level” defined in IEEE Std 693-1997. The seismic acceleration and the maximum wind do not have to be considered to occur simultaneously. The snow depth (if applicable) does not exceed the height of the foundations for the platform support insulators or in any fashion reduce clearance with respect to ground. (A typical maximum height is 1 m.) Abnormal service conditions (environmental) Service conditions that would compromise the operation of the series capacitor bank must be considered. Each purchaser must look at the cost to benefit and determine under all or specific conditions the series capacitor bank must operate. Generally the worst-case scenario must be planed for. The application of series capacitor banks at other than the normal service conditions shall be considered as special and should be identified in the purchaser’s specification. Examples of such conditions are as follows as specified in IEEE 824 Section 4.2: Service conditions other than those listed in B.3.1 Exposure to excessively abrasive and conducting dust Exposure to salt, damaging fumes, or vapors (Example Industrial Pollution) Swarming insects Flocking birds Conditions requiring over-insulation or extra leakage distance on insulators Seismic accelerations at the “moderate or high seismic qualification levels” as defined in IEEE Std 693-1997. Power system characteristics, see Clause  REF _Ref124994543 \r \h 7 Normal power system conditions The capacitor bank shall be designed to withstand the specified continuous rated current, emergency loading, swing current and power system faults with the capacitor bank bypassed. There are no standard current ratings for series capacitor banks. The current ratings of capacitor banks are based on power transfer requirements or thermal line loading considerations. Consider both initial and future Continuous current Based on power transfer or line thermal loading considerations. Emergency overload currents and durations. Based on power transfer or line thermal loading considerations. Typical range is 1.25 to 1.6 pu for 30 minutes. 1.35 is inherent, higher values impact design. Swing current and duration Explain swing current and its importance to the design of the protective device. Determined in transient stability study. The capacitor bank shall be designed to withstand the specified continuous rated current, emergency loading, swing current and power system faults with the maximum capacitor unbalance condition for which the control and protection system will allow the bank to remain in service. The FSC bank is normally inserted into the line, and it is bypassed only for protective actions and maintenance periods. Abnormal power system conditions As is also described in Annex  REF _Ref125011183 \n \h B.3.2, the application of series capacitor banks at other than the normal service conditions shall be considered as special and should be identified in the purchaser’s specification. Here are some examples of abnormal power system conditions that may require additional analysis. Such conditions should be brought to the attention of all potential suppliers during the bidding stage of the project. The transmission line on which the series capacitor bank is located does not have phase transpositions so the reactance’s of each phase of the line are not approximately equal. The FSC bank is normally bypassed, and it is only inserted for short-term overload conditions or other specific system needs. Unusual transportation or storage conditions (e.g. mobile capacitor bank) Short time or overload rating due to abnormal switching or reduced capacity of bank due to capacitor unit failure Presence of any significant system currents other than at fundamental power frequency (e.g. harmonic or subharmonic currents). Significant and/or frequent deviations in system power frequency beyond a narrow band (+/-0.1Hz) of nominal frequency. Main FSC characteristics, see Clause  REF _Ref124994563 \r \h 8 Major equipment considerations Capacitor units The capacitance of the segment is realized by connecting capacitor units in series and parallel to provide the required capacitive reactance with the continuous current rating. The capacitors shall be designed to withstand higher currents such as those experienced during emergency loadings (typically the 30-min. rating), system swings and during faults as specified by the purchaser The capacitor units shall be designed to withstand the specified continuous rated current, emergency loading, swing current and power system faults. with the maximum capacitor unbalance condition for which the control and protection system will allow the bank to remain in service. If capacitor fuses are used, either internally or externally, the fuses should be designed to operate correctly for bank currents of 50% of rated current up to and including power system fault conditions. Discharge current limiting reactor Typically the discharge current limiting reactor is connected as shown is  REF _Ref125003055 \n \h Figure 2 and hence does not carry current when the bank is inserted. However in some applications the discharge current limiting reactor is connected in series with the capacitors (see  REF _Ref125003060 \n \h Figure 4). This arrangement is infrequently used to reduce losses where the segment is frequently bypassed and may be used to eliminate the potential for harmonic current magnification where the reactor is paralleled with the capacitor during bypassed operation. It is also used to reduce the duty on the disconnect switch typically used in parallel with the bank. If the discharge current limiting reactor is in series with the capacitors, the reactor shall be rated to withstand the same current magnitudes and durations as required for the capacitor segment. Varistor Current through the capacitor segment produces a voltage stress across the varistor. The varistor shall be designed to withstand these stresses. The varistor protective level shall be sufficiently above the voltage produced during a system swing to avoid excessive energy absorption during the swing. Bypass switch As in the case of the varistor, the interrupter of the bypass switch are exposed to voltages resulting from currents through the capacitors. In addition this equipment is exposed to protective level voltage during power system faults. This equipment shall be designed to withstand these voltages. Bypass gap As in the case of the varistor, the bypass gap is exposed to voltages resulting from currents through the capacitors. In addition this equipment is exposed to protective level voltage during power system faults. This equipment shall be designed to withstand these voltages. Considerations for the selection of protective level of the overvoltage protective device Since the series capacitors are in series of the line impedance, they can be subjected to large faults currents and thus must be protected against the over voltages. Some of the protection schemes commonly used in past forty years are: Spark gaps (1960s-70s, 3.0-4.5 per unit protective levels, multiple steps required) Silicon carbide resistors with gaps (1970s, 2.5-3.5 per unit protective levels, multiple steps required) Metal oxide resistors (1980s- 1990s, 2.00-3.0 per unit bypass levels, multiple steps, but with large voltage levels, reduced the number of steps required) Protective thyristor switches. (2000-, 1.8-2.6 per unit bypass levels, single step feasible, voltage per step increased substantially) Selection of a suitable spark over or bypass voltage level is very important as it impacts the system stability performance and SSR that can be caused by the series capacitors. The spark gap/bypass should be high enough to insert the series capacitors when needed for a system swing Since, the series capacitors are a vital element in improving and maintaining the system stability on a transmission line, they must reinsert before the system swing occurs in that line. The occurrence of the system swing is dependent on the system swing frequency and can happen after quarter second for a fast swing (1 Hz swing) to half second for a (0.5 Hz swing). Also, the capacitors should not bypass during the system swing. The spark over voltage should be above the system swing current level. From the SSR standpoint, lower spark-over/bypass voltages are desirable as the energy stored in the series capacitors which ultimately gets discharge into the system and the nearby generating machines is dependent as square of the spark over/ bypass voltage level. With the improved reinsertion/bypass technology, the spark-over or the bypass voltage required for protection and reinsertion has gradually reduced as the technology has evolved from 4.5 per unit required in the spark gaps to 2.0 required in the metal oxide or thyristor protected series capacitors. With some schemes, the lower bypass voltage would require more energy absorption capability and would increase the cost of that bypass scheme. The following is a discussion of the influence of the protective level on various aspects of the design of a modern series capacitor bank. The discussion ends with a recommendation that the purchaser not specify the protective level except in certain cases. Influence of protective level on the insulation levels required on the platform The insulation levels applied on the series capacitor platform are dependent on the protective level established by the protective device. IEEE Std. 824-2004 requires that: VPFW >= 1.2 VPL / where VPFW is the power frequency wet rms voltage withstand level VPL is the peak voltage magnitude of the protective level Influence of protective level on capacitor design The protective level is also factor in the design of the capacitor. The choice of protective level can affect the terminal-to-terminal dielectric production test on the capacitor units. This test must be performed with a dc test voltage of at least 1.2 times the prorated protective level voltage. The minimum voltage level for this test is 4.3 times the rated rms voltage of the units. These two requirements dictate the test level for the capacitor units as indicated in the following table. For protective levels above 2.5 pu, higher protective levels result in higher test voltages. Protective level in per unitDC test voltage on the capacitor units in per unit of the rms rated voltage of the unit2.04.302.254.302.54.302.64.412.74.58Influence of protective level on varistor design The voltage associated with the power system swing is often the highest non-fault voltage that the series capacitor and the varistor must withstand. As such, it can be the determining factor in establishing the protective level. A low varistor protective level may mean the varistor will exhibit significant conduction and energy absorption during the swing, necessitating a varistor with a greater energy rating. Increasing the protective level of the varistor can reduce varistor energy absorption. However, the capacitor design is subject to change because of the higher overvoltages. The choice of protective level can also be influenced by its relationship to the varistor energy requirements for external faults. Typically, a lower protective level increases varistor energy absorption for external faults. Conversely, a higher protective level requires less energy absorption. For internal faults a higher protective level can, in some applications, increase the varistor energy absorption (if the varistor is not bypassed with a forced triggered bypass gap). Influence of protective level on SSR, TRV, and system stability The protective level can have some impact on SSR, line breaker TRV, and system stability. Protective level and SSR In the case of SSR (subsynchronous resonance), the voltage magnitude of large subsynchronous oscillations is limited by the varistor. In applications where subsynchronous oscillations are a concern, there is a preference for a lower protective level. However the protective level only affects the transient torque aspect of SSR not the damping of steady state torsional oscillations. Protective level and TRV A second power system consideration is the affect that series capacitors have on the transient recovery of the transmission line circuit breakers (TRV) of the line on which the series capacitors are planned. Series capacitors can increase this recovery voltage. The voltage is reduced by lower protective levels. Both of these phenomena are affected by the varistor voltage at currents lower than those associated with an external fault. Protective level and system stability Recommendation on protective level Since the supplier is in the best position to optimize the bank design including the varistors and capacitors, it is recommended that the purchaser not specify the protective level unless the purchaser has power system application reasons for doing so. Typical fault duty cycles The purchaser should define the desired operation of the protective device during and following faults on the power system. The following are examples of typical fault duty cycles for the three protective devices described above. Metal oxide varistor Normal external fault The bank is initially assumed to be in the inserted condition with rated continuous current. An external fault occurs that is cleared within normal clearing time.. The varistor will typically be required to withstand the duty associated with the fault. Bypass with the bypass switch is not normally permitted. The restoration of all the current back in the series capacitor units following the clearing of the external line fault is immediate. The bank is exposed to the swing current followed by the post fault power current as specified by the purchaser. The post fault power current may be at rated current or at the 30 minute overload current followed by rated current. The bank returns to operation at rated current. Typical normal fault clearing times are 4 to 5 cycles. Three phase faults usually result in higher energy absorption than single-phase faults. If the power system has one or more parallel lines that are to be compensated, the varistor duty during an external fault is usually greater if one of the parallel lines is assumed to be out-of-service. In some cases, ungrounded phase-to-phase faults and heavy load current through the bank can combine to cause varistor energies higher than those for three-phase faults. The type of fault may be important if grass fires are probable under the transmission lines. The magnitude of the swing current is not a significant factor if the value is 1.7 pu of rated bank current or less. For values much higher, the swing condition can impact the energy rating and the protective level of the varistor. It is important that the specified swing current be related to the specified external fault condition. If the swing current is an important factor, a table of swing currents versus time must be provided so that the bidder can calculate the energy absorbed by the varistor during the swing. Normal internal fault The bank is initially in the inserted condition with rated continuous current. An internal fault occurs. Bypass with the bypass switch is permitted. The varistor must withstand the duty that occurs during a normally cleared and/or the bypass time via the bypass switch. fault prior to the completion of the bypass. The bypass switch shall withstand the resulting capacitor discharge and power frequency fault current. The line circuit breakers interrupt the fault. The line remains open until it is reclosed within the time specified by the purchaser. The bank must reinsert within the time specified by the purchaser. The possible reinsertion scenarios are: Prior to the first line breaker to recluse After the first line breaker to reclose by before the second Immediately after the second line breaker recluses Some time after the second line breaker recloses as directed by the system operator If the line reclosing is successful and the fault is not present, the bank returns to operation at rated current. If the line reclosing is not successful and the bank was inserted prior to reclosure, the varistor must be capable of withstanding this additional duty until bypassing occurs. The internal fault usually results in more energy absorption than single-phase faults. This energy absorption is highest if the bank is located at the end of the line and the substation has a low short circuit impedance. If the bank is located at the end of the transmission line, the degree of grounding at the terminating substation will dictate whether single phase or three-phase faults result in higher varistor duty for a fault located at the line side of the bank. The varistor duty for internal faults is much less for banks located out on the line than at a substation with a low short-circuit impedance. For three-phase faults near the far end of the line or for single-phase faults out on the line, the varistor protection functions may not close the bypass switch since the duty to the varistor is not high. If the purchaser wishes the bank to be bypassed prior to line reclosure, the control system of the bank must have additional logic and inputs. Possible inputs for the logic may include: Line current Line voltage Line status from the line relays Metal oxide varistor with forced triggered bypass gap Normal external fault The performance requirements for this protective device will be essentially identical to that described for the varistor in  REF _Ref125006804 \w \h B.5.2.1.1. Typically neither the bypass gap nor the bypass switch are permitted to operate during the normally clear external fault. Normal internal fault The bank is initially in the inserted condition with rated continuous current. An internal fault occurs. Bypass with the bypass gap and the bypass switch is permitted. The varistor must withstand the duty that occurs prior to the completion of the bypass. The bypass gap must withstand the resulting capacitor discharge and power frequency fault current. The line circuit breakers interrupt the fault. The line remains open until it is reclosed within the time specified by the purchaser. The bank must reinsert within the time specified by the purchaser. The possible reinsertion scenarios are: Prior to the first line breaker to reclose After the first line breaker to reclose by before the second Immediately after the second line breaker recloses Some time after the second line breaker recloses as directed by the system operator If the line reclosing is successful and the fault is not present, the bank returns to operation at rated current. If the line reclosing is not successful and the bank was inserted prior to reclosure, the varistor must be capable of withstanding this additional duty until bypassing occurs. For three-phase faults near the far end of the line or for single-phase faults out on the line, the varistor protection functions may not trigger the bypass gap since the duty to the varistor is not high. If the purchaser wishes the bank to be bypassed prior to line reclosure, the control system of the bank must have additional logic and inputs. Possible inputs for the logic may include: Line current Line voltage Line status from the line relays Description of overvoltage protective devices The practical application of series capacitor banks on transmission systems almost always requires that the bank include a protective device to limit the overvoltages that occur during power system faults. The purchaser should indicate in his specification the type or types of protective devices that are desired. The following is a description of each type. Metal oxide varistor Overview Metal oxide varistors are one type of overvoltage protective device. A simplified one-line diagram is shown in  REF _Ref125007625 \h Figure B.1. The varistor is usually connected in parallel with the capacitors. The bypass switch in also connected in parallel via a current limiting reactor. The varistor is constructed of a series and parallel array of metal oxide non-linear resistor elements. These elements or organized into enclosures for protection against the outdoor environment.  Figure  STYLEREF 1 \s B. SEQ Figure \* ARABIC \s 1 1—Metal oxide varistor overvoltage protection Principle of Operation The varistor limits temporary overvoltages across the capacitors by conducting the excess transmission line current, usually due to faults, that would otherwise cause excessive capacitor voltage. This conduction occurs on each half cycle of the power frequency current of the overcurrent condition or until the parallel bypass switch closes or the fault is cleared by the line circuit breakers. The maximum voltage that results across the series capacitor is dependent upon the nonlinear voltage-current characteristics of the varistor and the magnitude of the overcurrent. Because the varistor voltage increases with current, the protective level is usually defined at a coordinating current representative of expected varistor current during a power system fault. Energy is absorbed by the varistor during conduction. The selection of the varistor energy capability and protection of the varistor against overstress are important aspects of the series capacitor protection system. When the line breaker clears the fault, the varistor naturally stops conduction and all the current is in the capacitors. The varistor is designed with current and energy absorption capabilities that shall be consistent with anticipated power system fault conditions. In addition to the protective level, critical factors determining varistor requirements are the equivalent impedance of the power system, the duration of the fault, and transmission line circuit breaker reclosure sequence. With this information, the varistor current and energy absorption can be determined. Computer simulations are needed to adequately determine varistor duty. The power system studies to establish these requirements are discussed in  REF _Ref125007683 \n \h Annex F. Typically, for the protective device consisting of the varistor but no forced bypass gap, the varistor will be designed to withstand the current and energy associated with specified internal line section faults. Internal line section faults near the series capacitor bank can cause much higher varistor current and energy. This is especially true if the installation is located at the end of the line near a substation with a high short-circuit current. However it is also important that the varistor duty during external faults be established. For the latter condition, the series capacitor in the unfaulted line remains in service during the fault and the critical post-fault period to enhance power system stability. Varistor with forced triggered bypass gap Overview In many applications the protective device also includes a forced triggered bypass gap. This gap is fired for power system fault conditions that result in higher duty to the varistor. The gap does not normally spark over on the voltage that appears across series capacitors since that voltage is limited by the varistor. Rather the spark over of the bypass gap is triggered based on the duty to the varistor. A one line diagram of this protective device is shown in  REF _Ref125007862 \h Figure B.2. Note that the bypass gap is connected in parallel with the bypass switch. The electrodes of the gap are contained in an enclosure that limits the ingress of precipitation.  Figure  STYLEREF 1 \s B. SEQ Figure \* ARABIC \s 1 2—MOV with forced triggered bypass gap overvoltage protection Principle of Operation Even though this system includes a forced bypass gap, the varistor performs the primary overvoltage limitation in a manner identical to that described above for the varistor only system. IN this case the varistor is normally designed to withstand the duty associated with specified external faults and the gap is triggered during more severe faults to limit varistor duty especially during internal faults. The varistor with forced bypass gap is most often applied on banks located at the end of the line and especially if the fault current is greater than 10 to 20 kA rms. For a close-in fault on the line side of the series capacitor bank, the potential duty to a varistor can be quite high. In this case the gap is triggered based on the high duty to the varistor at the start of the fault. Firing thresholds are selected to avoid firing the gap during normal external fault. In most designs the gap will be conducting within 2 ms after the thresholds are exceeded. The logic for the triggering and the equipment to achieve it are different among the various suppliers. However, the conduction is not instantaneous so the varistor is exposed to high current for a finite time. The varistor must be designed withstand the high fault current until bypass occurs. Once the bypass gap conducts, most designs used with varistors do not have much ability to interrupt the current. In general this is not an important factor since the gaps are normally triggered only when the varistor duty exceeds that associated with and internal fault. For an internal fault, the line along with the series capacitor bank are temporarily removed from service. This eliminates the gap current and the gap de-ionizes and regains its voltage withstand capability prior to normal line reclosure. Thyristor bypass Capacitor overvoltage protective function is to be provided by a thyristor valve assembly placed across the fixed series capacitor and is referred to as a Thyristor Protected Series Capacitor (TPSC), refer to Figure 4. At normal operating voltages across the capacitors the thyristor valve is blocked and line current flows through the capacitor. The thyristor valve commutates fault current around the capacitors during line faults. The fault protection strategy involves monitoring ac-line current through the TPSC bank. When the ac-line current exceeds a threshold value, a fault condition is assumed and protective valve firing sequence initiated. The protection sequences for internal and external faults are similar to conventional gap or MOV protection schemes. For internal faults the thyristor valve continues to conduct line fault current on each half cycle until the parallel bypass switch closes. Typical internal fault would involve 2 to 3 cycles of fault current. The thyristor valve needs to be designed to withstand maximum line fault duty for operation of the backup line protection of up to 10 cycles.  Figure  STYLEREF 1 \s B. SEQ Figure \* ARABIC \s 1 3—Thyristor bypass overvoltage protection If the fault current is above the overload rating and lower than a specified threshold for an internal fault, the event is interpreted to be an external fault and the valve can be fired to limit the voltage across the capacitors and blocked during the following negative current swing. The specific parameters of the swing current limiting are established in the system design studies. The bypass breaker remains open during the event. The thyristor valve differs from the varistors protection in that the varistors absorb energy during conduction and experience a corresponding temperature rise not experienced by the thyristor during conduction. Under normal fault clearing conditions the thyristor modules will experience limited temperature rise and are able to return to service in minutes after a series of line faults. Thyristor cooling is performed by a simple air-cooled mechanical heat sink. The valve-damping reactor is designed to limit the capacitor discharge current through the valve and designed with relatively high impedance, typically 4 MHz. The thyristor levels include internal grading resistors and limited MOV arresters for over-voltage protection during turn-on turn-off sequence. The valve is located on the platform in an enclosed valve house that is a semi-weatherproof structure with wall bushing penetration. Firing pulses are transmitted via redundant fiber optic circuits from the ground based control and protection system. Current ratings for the bank bypassed mode Current ratings for the bypassed mode should also be specified. They are not necessarily the same as for the inserted mode. Bypass current rating will be determined by system conditions. Consider both initial and future Continuous current Based on power transfer or line thermal loading considerations. Sometimes a standard ANSI rating is selected for the bypass switch. Reactor current rating should be specified by the manufacture. Emergency overload currents and durations Based on power transfer or line thermal loading considerations. Overload currents are often not specified for the bypass mode since such overloads are not possible with the series capacitor bypassed. Swing current and duration Equipment must withstand this but it is not usually specified as not decisive for the reactor or bypass switch. Can be determined in transient stability study Fault current ratings and durations Based on short circuit study with the bank bypassed. Only the component of fault current in the bypassed bank is of interest not the total current in the fault. Duration based on the extended fault clearing time on the power system or nominal 1 or 3 second duration. Equipment Considerations The continuous, emergency, swing and fault currents specified for this mode of operation may be different than those selected for the bank inserted mode based on power system operational considerations. Thus the purchaser should also specify the current ratings for this operating mode. Discharge current limiting reactor When the discharge current limiting reactor is in the typical position in the bypass path as shown in Figure 1, the circuit is exposed to the continuous, emergency, swing and fault currents specified for this mode of operation. The circuit shall be designed for these conditions. The maximum duration of the fault current will be the extended fault clearing condition (backup power system relaying) defined as part of the fault duty cycle for the bank unless the purchaser specifies a 1, 2 or 3 second requirement. If there are significant harmonic currents anticipated in the transmission line, these currents should be specified by the purchaser as an abnormal service condition. Harmonic current can be important because, if the bypass switch is in the closed position, the reactor is in parallel with the capacitors. This parallel inductor/capacitor circuit can circulate harmonic currents that are greater in magnitude than those present in the transmission line. This amplification can be significant for harmonic frequencies that are near the natural frequency of the parallel inductor/capacitor circuit. Under such circumstances, it is necessary that the inductive reactance be selected to minimize harmonic current amplification and the reactor designed to withstand harmonics in addition to the power frequency requirements. In addition, a protection function can be implemented to close the bypass disconnect switch in case of excess harmonic current in the reactor. If the bank is often in the bypassed condition and the harmonic current in the transmission line is significant, it may be desirable to eliminate the amplification of the harmonic current by the parallel inductor/capacitor by locating the discharge current limiting reactor in series with the capacitors. However this arrangement can affect the magnitude of the voltage across the capacitors during power system faults. The discharge damping device shall be designed for permanent insertion in the line with the Capacitor Bank by-passed. It shall have a continuous current rating equal to that of the Capacitor Bank. The start of conduction of the bypass gap or the closure of the bypass device will result in a capacitor discharge current. The parameters of the discharge current limiting reactor shall be selected to limit the magnitude of the discharge current and provide sufficient damping of the oscillations so that the discharge is within the capabilities of all the equipment of the bank. All of the equipment included in the discharge path shall be designed for the magnitude and duration of the capacitor discharge current resulting from bypass with protective level voltage on the capacitors. This includes the bypass gap, the discharge current limiting reactor, the capacitors and fuses and the interconnecting bus. If there is no bypass gap and the bypass switch operates during the fault, the design of the discharge current limiting reactor shall be consistent with the capabilities of the switch. The capacitor discharge current can combine with the power frequency fault current. The bypass gap, discharge current limiting equipment and the bypass switch shall be designed to withstand this combined current. Table  STYLEREF 1 \s B. SEQ Table \* ARABIC \s 1 2—Summary of Current Ratings Current RatingNormal In service modeBypassed ModeNormal line current: ...... ArmsRated continuous current: ....... ArmsEmergency, 30 minute, overload current: ....... Arms.Maximum swing current: ....... Arms. / Hz *Maximum fault currents through Capacitor Bank equipment3-( internal*, max. ...... kA rms1-( internal*, max. ...... kA rms3-( external*, max. ...... kA rms1-( external*, max. ...... kA rmsNumber of reclosures 1-( or 3-(  Capacitors When the bank is in the bypassed mode, the power frequency current in the capacitors is very small. However if the harmonic current conditions discussed in the previous paragraph prevail, the capacitors can also carry significant harmonic current. The capacitor design shall take this into account.(???? Needs beter explanation ) Bypass Switch The bypass switch is exposed to the continuous, emergency, swing and fault currents specified for this mode of operation. The switch shall be designed for these conditions. Disconnect Switches During normal conditions the expected maximum current through the series capacitors and disconnecting switches is the conductor rating. During line outage conditions the expected maximum current through the series capacitors and disconnecting switches is the 30 minute rating. It is unlikely that the bypass switch will experience these maximum currents because of the increase series impedance in the line when the series capacitors are bypassed. It is recommended that the capacitor bank 30 minute rating be established as the continuous current rating for all 3 disconnect switches for the capacitor banks. Bypassing of the bank (***Include Swing Current curve, if available***) Users need to provide data as listed in  REF _Ref125009840 \h Table B.1 above. If user has an initial current requirement with plans for future increase in current ratings, a separate column should be provided for the future ratings. FSC main component requirements, see Clause  REF _Ref124994591 \r \h 9 Capacitor fusing and unit arrangement, see Clause  REF _Ref125008318 \n \h 9.1.1 Three different types of fusing are being applied on series capacitor banks. The following outlines these types and the associated arrangement of the capacitor units. Refer to  REF _Ref125008729 \h Figure B.4. Externally Fused Capacitor Bank The typical arrangement used with externally fused capacitors involves the connection of groups of fused capacitors in parallel as necessary to meet the current rating of the bank. These groups are connected in series to realize the voltage and impedance ratings of the bank. The failure of a capacitor unit results in increased current in the external fuse and blowing of the fuse. This results in increased voltage on the parallel units. The magnitude of this voltage increase is dependent on number of units in parallel in the manufacture’s design. Dual element fuses consisting of two fuses in series are typically applied. One of these fuses is a current limiting type that is used because of the high stored energy in the parallel capacitors. The second fuse is an expulsion type which will operate for lower current conditions and provides a visible break. The total fuse is designed to operate satisfactorily at voltages from 0.5 p.u. up to the protective level. The capacitor units typically have one insulated terminal. The capacitor units of each segment or sub-segment are split into two or more parallel strings to allow capacitor current unbalance detection. The failure of a capacitor unit results in increased current in the external fuse and blowing of the fuse. This in turn results in increased voltage on the parallel capacitor units. For the purposes of establishing the thresholds for the capacitor unbalance protection, it is typically assumed as a worst case that additional capacitor units will fail and fuses blow in the same parallel group. The thresholds for alarm and bypass for the capacitor current unbalance protection function are typically based on calculations of the increasing voltage across this worst capacitor group with an increasing number of blown fuses. Typically, an alarm occurs when the unbalance current is indicative of greater than a 1.05 pu unbalance factor and bypass occurs when the unbalance current is indicative of factor of greater than a 1.1 pu. The objective of these thresholds is to restrict the operation of the capacitors and fuses to within their tested capabilities. Fuseless Capacitor Bank The typical arrangement used with fuseless capacitors involves strings of series connected capacitor units. The number of units connected in series is as required to achieve the necessary voltage capability. These strings of capacitors are connected in parallel as necessary to realize the current and impedance ratings of the bank. The failure of a capacitor element results in a short circuit of the associated series section of that capacitor unit. This results in an increase in current through and increased voltage on the remaining elements within that capacitor unit and the other capacitor units in the associated string. The degree of this increase is dependent on the total number of elements in series in the string. The discharge energy and current increase are both small since there are no capacitor units connected directly in parallel. The capacitor unit with the shorted element remains in continuous operation. Capacitor units used in fuseless applications have an all-film dielectric system. The capacitor units are usually designed with two insulated bushings. The capacitor units of each segment or sub-segment are split into two or more parallel groups of strings to allow capacitor current unbalance detection. For the purposes of establishing the thresholds for the capacitor unbalance protection, it is typically assumed as a worst case that additional capacitor elements will fail in the same string of capacitor units. The thresholds for alarm and bypass for the capacitor current unbalance protection function are typically based on calculations of the increasing voltage across the remaining capacitor elements in the worst capacitor string with an increasing number of shorted elements. Typically, an alarm occurs when the unbalance current is indicative of unbalance factor of 1.05 to 1.1pu or when the equivalent of more than 50 percent of the elements of a unit are shorted. Bypass typically occurs when the unbalance current is indicative of an unbalance factor greater than 1.15 to 1.2 pu or when the equivalent of all the elements of a unit have shorted. The objective of these thresholds is to restrict the operation of the capacitors to within their tested capabilities. Internally Fused Capacitor Bank The typical arrangement used within an internally fused capacitor unit involves groups of fused elements connected in parallel. These groups are then connected in series to realize the rating for the unit. The units are connected in series and parallel as necessary to meet the overall ratings of the bank. A number of different arrangements are possible. The failure of a capacitor element results in discharge current from the parallel elements through the associated internal fuse and blowing of the fuse. This results in increased voltage on the parallel elements within the unit and a much smaller increase in the voltage across the associated unit. The magnitudes of these voltage increases are highly dependent on number of elements in parallel in the manufacture’s design. Element failure is most likely to occur when the current in the bank is high. Internal fuses are designed to operate correctly for bank currents that are greater than 0.5 pu of rated current and for voltages up to and including the protective level. The capacitor units may have one or two insulated bushings. The failure of a capacitor element results in increased current in the associated internal fuse and blowing of the fuse. This results in a important increase in the voltage across the parallel elements and a much smaller increase in the voltage across the group of capacitor units that are in parallel with the affected unit. The capacitor units of each segment or sub-segment are split into two or more parallel strings to allow capacitor current unbalance detection. These strings are sometimes interconnected via a current transformer in a bridge arrangement. The typical unbalance protection strategy has two parts: one for situations involving groups of capacitors and one for situations within a unit. Group of capacitor units: For a group of capacitor units, typically an alarm will be initiated when the unbalance current is indicative of an unbalance factor of 1.05 pu and bypass occurs when the unbalance current is indicative of a factor of greater than 1.1 pu. The objective of these thresholds is to restrict the operation of the capacitors and fuses to within their tested capabilities. Within one unit: For a situation within a capacitor unit, the worst condition involves increasing numbers of shorted elements and blowing fuses in the same group of parallel elements. In this case bypass typically occurs when the unbalance current is indicative of a unbalance factor of greater than 1.5 to 2.0 pu with an alarm initiated when the unbalance current is indicative of an unbalance factor of half of the bypass level.. The objective of these thresholds is to restrict the operation of the fuses to within their tested capabilities. It is not expected that the affected capacitor elements will withstand these high overstresses continuously at rated current in the bank or during a 30 minute overload condition or a power system fault that results in protective level voltage.  Figure  STYLEREF 1 \s B. SEQ Figure \* ARABIC \s 1 4—Capacitor unit and fusing: (a) externally-fused, (b) internally-fused, (c) fuseless Spare parts and special tools, see Clause  REF _Ref124994607 \r \h 10 Engineering studies, see Clause  REF _Ref124994624 \r \h 11 Tests and quality assurance, see Clause  REF _Ref124994644 \r \h 12 Safety, see Clause  REF _Ref124994659 \r \h 13 Documentation, see Clause  REF _Ref124994673 \r \h 14 Training, see Clause  REF _Ref124994690 \r \h 15 Balance of plant, see Clause  REF _Ref124994710 \r \h 16 (informative) Subsynchronous resonance risk on turbine generators Application of series capacitors in long electric power transmission lines is a cost-effective method to increase power transfer. However, use of series capacitors has sometimes been limited because of the concerns for subsynchronous resonance (SSR), a detrimental interaction between series capacitors and nearby turbine-generators. With today’s understanding of the SSR phenomenon and proven methods for SSR mitigation and protection, series capacitors can be applied while effectively managing the risks associated with SSR. Subsynchronous Resonance (SSR) Subsynchronous resonance is an interaction between series capacitors and the torsional natural frequencies of turbine-generator rotors. In 1937, Concordia reported the potential for adverse interactions between a series capacitor and a turbine-generators  REF _Ref125004886 \w \h [B2], but such interactions never materialized until 1970 when the first known SSR event occurred at the Mohave plant  REF _Ref125004910 \w \h [B3].  REF _Ref125004197 \h  \* MERGEFORMAT Figure C.1 illustrates the elements of the interaction, using the Mohave generating station as an example. The series compensated transmission lines have line inductance, resistance and series capacitance which result in electrical resonant frequencies (fe) below the fundamental power frequency. (In North America, the fundamental power frequency is 60 Hz. This is also called the synchronous frequency. Resonant frequencies below the fundamental frequency are called subsynchronous.) Turbine-generators have rotating shaft systems comprised of large inertial masses that are interconnected with shafts that act as springs. These large masses and shafts create torsional resonant frequencies, fm, some of which are also subsynchronous. If the transmission line resonant frequency, fe, is close to the complementary mechanical system frequency (60-fm) of the generating machine, then the two oscillatory systems can interact with each other. In some operating conditions, the interaction can result in damaging shaft torques on a turbine-generator shaft. This interaction is called SSR, and it occurs because of the interchange of energy between the series capacitors on the transmission lines and the mass-spring system of the turbine-generator shaft. This interchange occurs at the subsynchronous resonance frequency by modulating the 60 Hz wave form. The SSR phenomenon actually occurred at the Mohave generating plant in southern Nevada, USA, resulting in shaft failures in 1970 and 1971.  Figure  STYLEREF 1 \s C. SEQ Figure \* ARABIC \s 1 1—Interaction between electrical transmission resonant frequency (fe) and the turbine-generator mechanical resonant system (60-fm). Interaction Between Electrical and Mechanical Resonant Systems A series compensated transmission line in a simple electrical power system as shown in  REF _Ref125004142 \h  \* MERGEFORMAT Figure C.2, has line reactance (X line), transformer reactance (Xt) and the machine dynamic reactance (Xm). Generally, the series compensation reactance (Xc) in the line is maintained between 25 to 75 percent. The ratio of the capacitive reactance to the total line, machine and transformer reactance is expected to be between 15 to 50 percent. The electrical resonant frequency for a simple transmission system can be calculated as sqrt(Xc/(Xline+Xt+Xm))x60 Hz. The natural electrical frequency (fe), in this case, would be between 23.2 Hz for 15 percent total reactance to 42.5 Hz for 50 percent total reactance. The complementary mechanical frequencies for this range of natural electrical frequencies will be 17.5 Hz to 36.8 Hz. If there are multiple series compensated transmission lines in proximity to the generators, they will create additional electrical resonant frequencies. Also, higher the compensation in the lines raises the electrical resonant frequencies and lowers the complementary mechanical frequencies. Nearby uncompensated transmission lines can also change the electrical resonant frequencies.  Figure  STYLEREF 1 \s C. SEQ Figure \* ARABIC \s 1 2—Simple series-compensated transmission system For typical large nuclear or fossil-fueled steam turbine-generators, there are four to eight large masses with interconnecting shafts. Such machines are likely to have 3 to 6 natural torsional frequencies below 60 Hz. The mechanical frequencies may range from 7 Hz to 50 Hz. Thus there are multiple electrical frequencies and mechanical frequencies that may interact with each other depending on the system configuration. In general, lower torsional frequencies are more likely to interact with the electrical transmission system than higher torsional frequencies. This is due to the mode shapes and torsional interaction factors that result from the inherent geometry and physical nature of the shaft system. In view of this consideration, SSR problems are more likely to occur with high levels of series compensation. Conversely, the SSR problem may be avoided by keeping the series compensation levels low. Mechanical damping for torsional vibrations is always positive but small. It is mainly due to friction, wind losses, and steam flow (or gas flow) around the rotor. It is minimum when a turbine-generator is at no-load, and increases with the load. Measured no-load damping for steam turbine-generator torsional modes is typically in the range of 0.02 to 0.05/sec. It is very small due to small amount of steam flowing in the turbine at no-load. The full-load damping is around 0.2/sec or more. No-load damping is significantly higher for a gas turbine-generator because the coaxial compressor operating at the rated speed is a significant shaft-load (typically 20 to 25 % of rated generator output). There is significant gas flow (or airflow) in both the turbine and compressor stages even at no-load. Measurement on a particular gas turbine-generator yielded no-load damping of 0.1/sec, and estimated full load damping is 0.3/sec. Shaft torques due to SSR are caused by two types of interaction mechanisms; SSR instability and SSR transient torque amplification. SSR Instability Series capacitor compensation has a tendency to act as a negative damping on torsional vibrations of nearby turbine generator units. When this negative damping effect overcomes the inherent mechanical damping of one of the shaft torsional vibration modes, the vibration will grow exponentially and lead to damage on a shaft. Generally, such growth in shaft torsional vibrations occurs with a long time constant on the order of many seconds. This negative damping effect was the cause of the Mohave shaft failures. Torsional interaction with the negative damping effect becomes unstable and excessive if the electrical and torsional resonance frequencies nearly coincide as fundamental frequency (50/60 Hz) complements and if the inherent mechanical damping is lower than the negative damping effect of series capacitor.  REF _Ref125004317 \h  \* MERGEFORMAT Figure C.3 shows the growth of torques from an EMTP simulation of a SSR instability event. The shaft torque on the critical shaft (generator-exciter) reaches about .08 per unit in 1.6 seconds. For this shaft, the endurance torque level where significant fatigue life expenditure starts to occur is about 0.36 per unit. The slow growth of torques in this case enables adequate time to trip a transmission line, bypass series capacitors, or trip the turbine-generator to prevent damage to the shaft. This type of SSR instability phenomenon resulted in shaft failure on the Mohave turbine-generators in the early 1970’s.  Figure  STYLEREF 1 \s C. SEQ Figure \* ARABIC \s 1 3—SSR Instability showing shaft torques on generator-exciter Shaft. EMTP simulation of a critically tuned system. Transient Torque Amplification Series capacitors also have a tendency to amplify the shaft stress during major network transient events over above the stress level that would exist without the series capacitors. The transient torque on the turbine-generator shaft should be evaluated as well as the resulting loss of life of the shaft due to the cumulative fatigue. The critical measure of the transient torque is the magnitude of the shaft vibration excited during each network transient event typically lasting on the order of one second. Figure 3 shows an example of SSR transient torque amplification where the resulting shaft torques are higher with 70% series compensation than with 60%. The electrical torque and HP-IP shaft torque are shown. Transient torque amplification becomes important only when the generator becomes nearly radial on lines that are heavily compensated with series capacitors. Although there is no record of severe damage due to transient torque amplification, the anticipation of this problem has led to a number of system design and operating criteria to limit the exposure of a turbine-generator to radial feed configurations through highly compensated lines after a system fault clearance. A solution is to limit the voltage across the series capacitor with metal-oxide varistors or protective gaps and hence to reduce the transient energy involved in the transient torque amplification. An alternative solution is to block the SSR current from flowing into a generator. A similar type of shaft torque amplification can occur with automatic high speed reclosing of transmission lines. Reclosing (particularly when the fault still exists) can result in a second electrical torque stimulus to the shaft system, that dependent upon timing, can increase the torsional oscillations which have not decayed sufficiently from the first fault clearing. While indiscriminant three-phase reclosing would be the worst reclosing practice, single-pole reclosing can also provide extra torsional stimulus.  REF _Ref125004404 \h  \* MERGEFORMAT Figure C.4 shows the growth of transient torques from a simulation of a system event. The system is excited by a low impedance line fault on a series compensated transmission line, which is cleared in about five cycles. The torques, in this case, grow very rapidly to over 3.0 per unit in less than 0.6 seconds. In fact they approach critical levels in less than 100 milliseconds. This rate of growth requires a very fast acting SSR mitigation system to prevent damage to the shafts.  Figure  STYLEREF 1 \s C. SEQ Figure \* ARABIC \s 1 4—Subsynchronous Resonance Transient Torque Amplification SSR Mitigation and Protection Numerous methods for mitigating SSR have been developed and implemented. The type of mitigation selected for a particular application depends on the severity of the SSR, the performance required, and economics. System studies are performed to quantify the level of SSR and to develop appropriate mitigation and protection schemes for a given application  REF _Ref125004971 \w \h [B4].  REF _Ref125004527 \h  \* MERGEFORMAT Table C.1 lists selected sites of SSR mitigation and protection scheme installations. At the Navajo power plant of the Salt River Project, passive SSR blocking filters were installed to block the currents at SSR frequencies flowing through the generator step-up transformer neutral connections to ground  REF _Ref125004994 \w \h [B5]  REF _Ref125004996 \w \h [B6]. Also supplemental excitation damping controls (SEDCs) were installed to provide damping at the SSR frequencies  REF _Ref125004996 \w \h [B6]. The Navajo units have been able to tolerate higher level of series compensation without risking an SSR problem since 1976. They are protected with redundant torsional relays against SSR conditions and possibly other potentially damaging operating conditions. Presently, the rotating exciters on the units are being replaced with bus-fed excitation systems, and the SSR mitigation and protection schemes are being upgraded. At Jim Bridger power plant, the series capacitors in three lines are segmented into two stages, and the compensation level is changed according to the load level of both the lines and the generators. This switched capacitor section scheme together with SEDCs for SSR damping has performed very well since 1979  REF _Ref125005037 \w \h [B7]. The Jim Bridger units are protected with redundant torsional relays. At Slatt in Northern Oregon, USA, site tests demonstrated that a well-designed TCSC control could eliminate SSR affecting the Boardman generating plant  REF _Ref125005045 \w \h [B8]. At many other sites, the level of series compensation was carefully selected such that no SSR mitigation was needed. In these cases, torsional relay protection was all that was needed. Table  STYLEREF 1 \s C. SEQ Table \* ARABIC \s 1 1—Examples of SSR Solutions Generating PlantUnits x MVALine kV% CompSSR Mitigation and ProtectionMohave2 x 90950070 > 26Reduced compensation Torsional relaysNavajo3 x 89250070SSR blocking filter SEDC Redundant torsional relays Jim Bridger4 x 59034545Load-switched series capacitor SEDC Redundant torsional relaysColstrip2 x 377 2 x 81950035Torsional relaysWyodak1 x 40223050Torsional relaysBoardman1 x 59050029TCSC Torsional relaySan Juan2 x 410 2 x 61734530-34Torsional relay Dynamic stabilizer (no longer needed after the 1990s)La Palma1 x 19234550Switched series capacitor segments via SSR current monitoringSSR Protection A torsional relay is designed to continuously monitor the turbine-generator’s shaft for torsional oscillations, and provide trip output contacts when shaft fatigue reaches predetermined levels. Relays were first developed in the 1970’s, and have continuously evolved and improved since then. A torsional relay can be configured to protect a single turbine-generator with multiple torsional modes, or it can be configured to protect multiple turbine-generator units (eg., in multi-shaft combined cycle plants). A torsional relay typically monitors shaft speed at one or two locations, and filters the signals to isolate individual torsional modes. For each mode, an amplitude-versus-time trip curve is used to trip the unit or a line that isolates the affected turbine-generator from the source of torsional stimulus. Torsional relays are the most wide-used technique for addressing risks due to SSR. For most systems, SSR risk is low during normal operation or low-level contingency situations (i.e., N-1 or N-2 line outages). SSR risk typically becomes significant during rare multiple-outage contingencies, where continued operation is not critical to the overall power grid. For these applications, torsional relays are used to detect conditions with excessive torsional stress and trip the turbine-generators if necessary. Conclusions: Series capacitors can significantly increase the power transfer capability of ac transmission systems. However, in some applications, series capacitors may introduce detrimental side effects, including SSR and transient torque amplification. Several proven methods exist for mitigating the effects of SSR, including: SSR blocking filters Supplemental exciter damping controls (SEDC) Thyristor-controlled series capacitor (TCSC) Dynamic stabilizer at generator Switching of series capacitor segments Limiting the total amount of compensation to a tolerable level In addition, torsional relays are used to protect turbine-generators from damage in the event that mitigations fail or unanticipated system events occur. Power system engineers have designed, installed, and safely operated numerous series-compensated transmission systems. For some systems, the best SSR mitigation schemes have been relatively simple (e.g., limiting maximum compensation to avoid SSR). In other systems, a combination of SSR mitigation measures was implemented to enable secure operation at higher compensation levels (e.g., blocking filter + SEDC + torsional relays). Selection of the best mitigation scheme for given transmission system depends on many factors, including: Value of power transfer Cost of SSR mitigation equipment Operational constraints imposed by SSR mitigation Cost of alternatives to series compensation (e.g., additional transmission line) System studies performed early in the evolution of a transmission system can lead to a design with the best overall balance of performance, reliability, and cost. (informative) Effects of series capacitors on line breaker TRV During fault current interruption on a line with series capacitors, a breaker will often experience a substantial increase in transient recovery voltage (TRV). This is particularly true for modern series capacitor installations that employ metal-oxide varistors (MOV) for capacitor overvoltage protection. The effect of the MOV is to keep the series capacitor in the circuit for the duration of the fault, unlike the older sparkover gap protection that would normally bypass a series capacitor early in the fault. Upon fault current interruption, the line voltage rings down to zero and the bus side rises to approximately prefault level, with both voltages overshooting their final value. With modern series capacitors, current interruption leaves a trapped charge on the bank approximately equal to the MOV clipping level. This trapped charge adds substantial voltage to the breaker TRV. The high TRV can exceed the capabilities of an older breaker or even a new breaker with standard ratings. Series capacitors between the breaker and the fault increase the breaker TRV by the full level of the trapped charge, whereas on the source side of the breaker, other uncompensated lines will attenuate the trapped charge effect. If the MOV is protected by a triggered gap, then the high-TRV faults would be at locations that do not cause the gap to fire. Series capacitors also compensate part of the fault impedance and cause an increase in the fault current. The higher TRVs and fault current are largest for multi-phase faults. One of the simplest methods to decrease the TRV is to apply arresters on the line side of the breaker, thereby limiting the line voltage to the arrester clipping level. Under certain configurations it may also be necessary to have an arrester on the bus side of the breaker. Unfortunately, even with arresters, the resulting TRV can exceed the breaker standards and require a special purpose breaker. Although seldom employed, opening resistors or arresters across the breaker contacts will control the TRV to acceptable levels. For systems with series capacitors, detailed transient analysis is required to determine breaker requirements. (informative) Impact of series capacitors on line overvoltages and secondary arc extinction (informative) Power system modeling for use in FSC equipment rating studies Defining a Power System Equivalent Circuit and Associated Fault Currents for Use in Defining the Fault Withstand Requirements of Series Capacitor Protective Devices. As noted in Annex  REF _Ref124971196 \r \h B.5.1.5, it is recommended that the purchaser perform studies to define the varistor requirements for the specification. However it is useful to include in the specification, an equivalent circuit for the power system from which the supplier may perform confirming studies or the bidder may ascertain the fault current requirements of the bypass path. Equivalent circuit The minimum extent of the power system would include the lines to be compensated and equivalent impedances at the line terminals. It is preferable to include at least one line segment between the actual compensated line and the source impedance(s). It is also preferable to include transfer impedances representing the underlying network. A one-line diagram should be provided. The transmission line data should include the positive and zero sequence series impedances and shunt capacitances. This applies if the lines are transposed. If the lines are not transposed, a parameter matrix is required. Data on line shunt reactors must be provided. At the terminals of the lines, the equivalent positive and zero sequence impedances must be provided. The data can be provided in written form but a data file in the EMTP/ATP format is preferred. Fault currents The definition of fault currents for series capacitor bank specification is problematic. The fault current that affects a series capacitor bank is only the component of current through the bank and not the total fault current. In addition, the impedance of the bank to through fault currents is multi-faceted. The bank may be bypassed with the bypass switch or with the bypass gap. In this mode the bank is usually a very low inductive reactance and the current can be determined. If the bank is inserted it is possible to calculate a very high fault current through the bank if the fault is assumed to be located on the power system where the inductive reactance of the power system is canceled by the capacitive reactance of the bank. Such a condition is only theoretical since with an actual bank the high current would result in high voltage across the bank protective device and the conduction of that device. This conduction fundamentally changes the apparent impedance of the bank and the calculated very high current does not occur. If the protective device includes a varistor, the only way to determine the current through an inserted bank is to use a program like EMTP/ATP. See  REF _Ref124971088 \r \h Annex H for a further discussion of Fault currents in connection with series capacitors. It is recommended that the specification should include the equivalent circuit and associated impedances as discussed above. The specification can also include calculated fault current through the bank for the bypassed condition (inductive supply network). The results of linear calculations with the bank inserted should not be included in a specification as these results are meaningless unless the fault current is less than two times the rated current of the bank. Discussion of system studies for determining the ratings for varistors and thyristor valves General As Section 10 indicates a varistor is provided in most modern series capacitor design to control the voltage across the capacitor units to within the tested capability of the capacitor. In doing this the varistor is exposed, during faults, to significant duties which could affect the survivability of the device. Computer simulations are required to accurately identify these duties and properly size the varistor. These simulations include assumptions regarding the type, location and duration of a fault(s) and following faults the temporary (system swings and 30-min. ratings) and the continuous voltage stresses that are present. The duties which the varistor are exposed to during faults can be controlled by bypassing the varistor through the use of a triggered gap, bypass breaker or thyristors. In some cases such as a fault external to the line section being compensated, bypassing may not be allowed. If bypassing is not allowed or delayed either intentionally or due to the operating time of the bypass device, the varistor must be sized to withstand this duty and be thermally stable for other stresses following this duty. Bypassing As indicated above, varistor sizing must account for the time to bypass and the duty cycle that the bank is expected to withstand. The following provides typical values which have been assumed: Bypass breaker 50-70 msec, Triggered gap 4 msec and thyristor bypassing in 1msec. In must be recognized that the above times to bypass only apply after the protective threshold has been exceeded. Typically with varistor current being monitored the threshold will be associated with varistor current magnitude, accumulated energy based on monitored current and assumed protective level and/or rate of rise of current. Modeling Varistor sizing studies also require that a number of assumptions must be made about the power system, the possible series cap future modifications, and the criteria for bank bypassing and lock out. These assumptions are described below. System Configuration – Must be based on the generation, transformation and line additions expected during the life of the project. Series Capacitor Ratings – Must account for the initial and ultimate continuous current rating, 30-min overload rating, and expected protective level (pu). Although there are other considerations, which must be addressed by and coordinated with the manufacturer, typically the protective level is 0.5 pu above the 10-sec system swing. Other Banks All other series capacitors banks in the vicinity must also be modeled as is or with their final characteristics to determine the greatest varistor duty. External Fault Criteria This criteria has been used to define the system configurations and types of faults which the series capacitor will be required to "ride through" without bypassing. These faults are external to the line containing the series capacitor and determine the minimum possible MOV energy requirements and bypass current and energy threshold levels. The following items summarize this criteria. One piece of equipment or one transmission line could be out of service prior to a fault. Single phase or multi phase faults are used at any external location. The maximum normal breaker clearing time is four cycles and the minimum is two cycles. This allows a maximum of two cycles of "stagger" between line ends in clearing a fault A Breaker failure condition is used only for single phase faults. The clearing time for breaker failure is 12 cycles from the time of fault. The maximum MOV energy and current for any fault case are found with any pre fault loading level up to the 30 minute rating. Internal Fault Criteria This criteria has also been used to determine the MOV energy requirements for faults internal to the line containing the series capacitor bank. The purpose of this criteria is to insure that the bank has adequate MOV energy capability to handle the worst case internal fault event prior to a bypass operation. The following items summarize this criteria. Any system configuration is allowed. Any type of fault at any location is allowed for internal faults, including closing into the fault manually, or reclosing automatically (SL G faults). The maximum normal breaker clearing time is four cycles and the minimum is two cycles, allowing a maximum of two cycles of "stagger" between line ends in clearing a fault. Reclosing is done only for single phase faults. Single phase and three phase breaker failures are allowed with a clearing time of 12 cycles from initiation of the fault. MOV protection will be from a triggered gap or bypass breaker. The control system bypass thresholds will be set at 120% of both the peak MOV current and highest MOV energy from all external faults consistent with the criteria above. The bank bypassing delay times after crossing MOV current or energy thresholds will be assumed to be the following: triggered gap: 3 ms, bypass breaker: 4 cycles Discussion From past experience, the most economical series capacitor bank next to a strong bus will use a triggered gap to protect the varistor. Recently some designs have significantly reduced the varistor size by using a thyristor as a bypass device. Gapless design, near a strong bus, typically require a significantly larger varistor, to survive a 3-ph internal fault with breaker bypass protection. Gapless designs may be economical for mid-line applications. (informative) Impact of line harmonics on the design and protection of FSC banks (informative) Fault current discussion In this Annex we will discuss some important aspects regarding fault currents in Series Compensated networks. We will also discuss how modeling of the Series Capacitor will affect the result of a fault current calculation. The following aspects will be discussed: Waveforms and analytical expressions of fault currents in inductive (non-series-compensated) and series compensated networks. Modelling of Series Capacitors in traditional short circuit calculations Modelling of Series Capacitors in transient short circuit calculations Definiton of Total Fault Current and Through Fault Current (Partial Fault Current). Waveforms and analytical expressions of fault currents in inductive and series compensated networks Transmission lines are inherently inductive. In a network without series capacitors, fault currents are inductive in character and the line current always lags the voltage by some angle. With the series compensation of the transmission lines, capacitive elements are introduced and the resulting network is no longer only inductive under all fault conditions. The degree of this change depends on the line and network parameters, the extent of series compensation, the type of fault, and the fault location. We will use the reduced and simplified network shown in  REF _Ref124968824 \h  \* MERGEFORMAT Figure H.1 to illustrate above.  Figure  STYLEREF 1 \s H. SEQ Figure \* ARABIC \s 1 1——Simplified representation of a fault in a series compensated network Here C = Xc / (, R = RSL + dзRl, and L = LSL + dзLl. As usual, Xc [(] is the reactance of the series capacitor, ( is the angular frequency of the source EMFs, RSL [(] is the resistance of the source, Rl [(] is the resistance of the power transmission line, LSL [H] is the inductance of the source, Ll [H] is the inductance of the power line, d [-] is the relative distance from the relay point to the fault location F. We assume that the fault occurs at t = 0 and that ( is the fault inception angle.  REF _Ref125011876 \h  \* MERGEFORMAT Equation 1 defines the source EMF:  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 1  REF _Ref125011938 \h  \* MERGEFORMAT Equation 2 gives the voltage relations for the non-series-compensated line:  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 2  REF _Ref125011942 \h  \* MERGEFORMAT Equation 3 defines the fault current if (t) for the non-series-compensated line:  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 3 Here ifs(t) [A] is the steady-state part of the fault current and ift(t) [A] is the transient part.  REF _Ref125011944 \h  \* MERGEFORMAT Equation 4,  REF _Ref125011945 \h  \* MERGEFORMAT Equation 5, and  REF _Ref125011947 \h  \* MERGEFORMAT Equation 6 define the steady-state part of the fault current:  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 4  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 5  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 6  REF _Ref125011949 \h  \* MERGEFORMAT Equation 7 and  REF _Ref125011951 \h  \* MERGEFORMAT Equation 8 define the transient part of the fault current:  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 7  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 8 Here It=0 is the current through the inductance at t = 0 The fault current for a fault in a non-series-compensated network consists of a steady-state part and a transient part. The transient part consists of a damped DC-current. The latter dies out with a time-constant equal to L/R.  REF _Ref124970132 \h  \* MERGEFORMAT Figure H.2shows a typical waveform of a fault current in a non-series-compensated network The fault inception angle has been varied in order to obtain maximum value of the transient fault-current.  Figure  STYLEREF 1 \s H. SEQ Figure \* ARABIC \s 1 2—Maximum transient fault-current in a non-series-compensated (inductive) network  REF _Ref125011952 \h  \* MERGEFORMAT Equation 9 defines the voltage loop for the series compensated line:  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 9  REF _Ref125011956 \h  \* MERGEFORMAT Equation 10 defines the fault current if (t) in the series compensated line:  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 10 Here ifs (t) [A] is the steady-state part and ift (t) [A] is the transient part of the fault current.  REF _Ref124970735 \h  \* MERGEFORMAT Equation 11,  REF _Ref124970724 \h  \* MERGEFORMAT Equation 12, and  REF _Ref124970715 \h  \* MERGEFORMAT Equation 13 define the steady-state part of the fault current:  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 11  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 12  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 13  REF _Ref124970691 \h  \* MERGEFORMAT Equation 14,  REF _Ref124970680 \h  \* MERGEFORMAT Equation 15, and  REF _Ref124970668 \h  \* MERGEFORMAT Equation 16 define the transient part of the fault current:  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 14  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 15  Equation  SEQ Equation \* ARABIC 16 Here It=0 is the current through the inductance at t = 0, and Vt=0 is the voltage across the capacitor at t = 0.  REF _Ref124970650 \h  \* MERGEFORMAT Equation 17 and  REF _Ref124970640 \h  \* MERGEFORMAT Equation 18 define the parameters ( and (:  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 17  EMBED Equation.2  Equation  SEQ Equation \* ARABIC 18 The fault current for a fault in a series compensated network consists of a steady-state part and a transient part. The transient part consists of a damped oscillation. The latter has an angular frequency ( and dies out with a time-constant of 1/(. This oscillating transient part corresponds to the DC transient part in a non-compensated network. The short-circuit current has a slow increase dependent on the degree of compensation. A particularly characteristic feature is the delayed beginning of the oscillations and the overshooting beyond the steady-state value after a few cycles.  REF _Ref124971337 \h  \* MERGEFORMAT Figure H.3 shows a typical waveform of a fault current in a series-compensated network. The fault inception angle has been varied in order to obtain maximum value of the transient fault-current.  Figure  STYLEREF 1 \s H. SEQ Figure \* ARABIC \s 1 3—Maximum transient fault-current in a series-compensated network. Ideal series capacitor without MOV overvoltage protection. The waveform in  REF _Ref124971337 \h  \* MERGEFORMAT Figure H.3 is applicable for faults remote from the SC for which the protective level voltage of the overvoltage protection device will not be reached. For close-in faults, the high fault current will produce a high voltage across the series capacitor which will cause the overvoltage protection device to operate.  REF _Ref124971597 \h  \* MERGEFORMAT Figure H.4 shows the waveform of the fault-current if the SC is equipped with a MOV overvoltage protection device. The fault inception angle has been varied in order to obtain maximum value of the transient fault-current. Note that the transient part of the fault current is heavily damped by the MOV. The result is that the asymmetry in the fault-current is very small and steady state condition is reached after only 1-2 cycles.  Figure  STYLEREF 1 \s H. SEQ Figure \* ARABIC \s 1 4— Maximum transient fault-current in a series-compensated network. Series capacitor equipped with MOV overvoltage protection. Note. If the SC is equipped with a bypass gap, the SC will be short-circuited when the bypass gap operates. This will immediately transform the fault circuit from an R-L-C-circuit to an R-L-circuit. Modeling of series capacitors in traditional short circuit calculations. Use of traditional software for ordinary short-circuit calculations (like PSS/E) will give false results when applied to a series compensated network. Depending upon the fault location, fault currents which are 2-5 times too large may result. The reason is, that the series capacitors are represented as ideal capacitors during the fault calculation and no regard is taken to the overvoltage protection of the series capacitor. To overcome this, a software for ordinary short-circuit current calculations should be complemented with e.g. a linear MOV model  REF _Ref124971882 \r \h  \* MERGEFORMAT [B1] for approximate calculation of fault currents in a series compensated network. Spark gaps may be represented by current-controlled switches. Modeling of series capacitors in transient short circuit calculations. The only way to calculate the actual fault current and the partial fault-currents when the SC is operated in the inserted mode with the varistor conducting, is to use an electromagnetic transient computer software like EMTP/ATP. The SC must be modeled together with the MOV and the bypass gap if applicable. The current limiting damping equipment shall also be included in the model. The MOV overload relay protection and spark gap relay protection should be modeled in TACS (EMTP/ATP). Note. It should be observed, that care must be exercised when the partial fault-current through the current limiting damping reactor is going to be calculated when the SC is in the bypassed mode. If Series Capacitors are installed in the adjacent lines, the partial fault current through the current limiting damping reactor will not be inductive. Hence, the calculation of the partial fault-current also in the bypassed mode has to be performed by EMTP/ATP. The SCs in the adjacent lines must be modeled together with their MOVs and the bypass gaps if applicable. Definition of Total Fault Current and Through Fault Current (Partial Fault Current) The fault current which affects the SC is only the component of the fault current that flows through the SC bank and not the total fault current. See  REF _Ref124971989 \h  \* MERGEFORMAT Figure H.5 below. The component of the the fault current which flows through the SC bank is called “through fault current” or “partial fault current” (I1 or I2). The total fault current is denoted If . See also  REF _Ref124971337 \h  \* MERGEFORMAT Figure H.3.  Figure  STYLEREF 1 \s H. SEQ Figure \* ARABIC \s 1 5—Definition of “through fault current” ( I1 & I2 ) and “total fault current” ( If ). For convenience, some useful definitions related to classical (inductive) fault currents (short-circuit currents) are included below. Reference is made to the attached  REF _Ref124972258 \h  \* MERGEFORMAT Figure H.6 and  REF _Ref124972274 \h  \* MERGEFORMAT Figure H.7. Some of these definitions might also be applied to “capacitive” fault currents. A. Fault current : over-current resulting from a short circuit in an electric system B. Symmetrical fault current: r.m.s. value of the a.c. symmetrical component of a fault current , the aperiodic component of current, if any, being neglected. C. Decaying (aperiodic) component i d.c. of short circuit current: mean value between the top and the bottom envelope of a short circuit current decaying from an initial value to zero according to  REF _Ref124972258 \h  \* MERGEFORMAT Figure H.6. D: Peak fault current I p : maximum possible instantaneous value of the fault current (see  REF _Ref124972258 \h  \* MERGEFORMAT Figure H.6) NOTE. The magnitude of the peak fault current varies in accordance with the moment at which the short circuit occurs. E. Steady state fault current Ik : r.m.svalue of the fault current which remains after the decay of the transient phenomena (see  REF _Ref124972258 \h  \* MERGEFORMAT Figure H.6). Remark. Definitions A, B, D and E may be applied also for fault currents supplied by series compensated networks.  Figure  STYLEREF 1 \s H. SEQ Figure \* ARABIC \s 1 6—Short-circuit current of a far-from-generator short circuit with constant a.c. component (schematic diagram)  Figure  STYLEREF 1 \s H. SEQ Figure \* ARABIC \s 1 7—Characterization of short circuits and their currents  IEEE publications are available from the Institute of Electrical and Electronics Engineers, 445 Hoes Lane, P.O. Box 1331, Piscataway, NJ 08855-1331,USA. IEEE P DOCPROPERTY "Designation" \* MERGEFORMAT xxxx/D DOCPROPERTY "DraftNumber" \* MERGEFORMAT 6,  DOCPROPERTY "MonthOfDraft" \* MERGEFORMAT January  DOCPROPERTY "YearOfDraft" \* MERGEFORMAT 2006 PAGE 58 Copyright Љ  DOCPROPERTY "YearOfDraft" \* MERGEFORMAT 2006 IEEE. All rights reserved. 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џTimes New Roman-№ 2 0Уfs=W 2 YmЂћ@ўSymbol-№ 2 РЊ=і 2 Р~зp 2 РM зp 2 Рі +і 2 РЬ-іћ@ўTimes New Roman-№ 2 Р'sinЏ{рћ@ўSymbol-№ 2 РД w1 2 РUlі 2 Рfы & џџџџћМ"System-№2 рыw1 2 рўџ џџџџРFMicrosoft Equation 2.0 DS Equation Equation.2Э G6˜O7(O7 ƒi ƒfƒs ƒtCompObjџџџџTZObjInfoџџџџџџџџVEquation Native џџџџџџџџџџџџWМ_882530563&џџџџ!РF ЯYiAЦ ЯYiAЦ–(–)˜†=˜ƒE ƒm ƒZ†з‚s‚i‚n„w†зƒt˜†+˜„l˜†-˜„f–(–)ƒt˜†+˜„l–(–LОИ\шшОИH Ѓ џџџ.1  `` &џџџџРџЁџ  & MathType€ћИ§рSymbol„-2 yнOle џџџџџџџџџџџџZPIC  #џџџџ[LMETA џџџџџџџџџџџџ]hCompObj"$џџџџkZ(ћИ§рSymbol„-№2 yв )њ-$.iњ - iїО-їЦg2g2g ћ@ўTimes New Roman-№ 2 `@Zљ 2 `cR 2 `Ю Lљћ@ўSymbol-№ 2 `О=і 2 `‹+і 2 `ћ зpћ џTimes New Roman-№ 2 —Š2p 2 Wk 2pћ@ўSymbol-№ 2 `bw1 & џџџџћМ"System-№Times New Romanўџ џџџџРFMicrosoft Equation 2.0 DS Equation Equation.2*Ь`'@Є7?47? ƒZ˜†=˜ ƒR ˆ2 ˜†+˜„w†зƒL–(–) ˆ2ObjInfoџџџџ%џџџџmEquation Native џџџџџџџџџџџџn|_882530562џџџџџџџџ(РFћ`iAЦћ`iAЦOle џџџџџџџџџџџџpL2 вШМшш2 в–< G џџџ.1  `@ &џџџџРџЌџ  & MathTypeаћИ§рSymbol„-2 й™(ћИ§рSymbol„-№2 й.)њ-L†Lќћ@ўPIC '*џџџџqLMETA џџџџџџџџџџџџsЈCompObj)+џџџџ~ZObjInfoџџџџ,џџџџ€Times New RomanЖ -№ 2 Р2tg{р 2 ЄюLљ 2 УRћ@ўSymbol-№ 2 Р#fы 2 Є‚w1ћ@ўSymbol-№ 2 Р=і 2 Єзp & џџџџћМ"System-№2 Рі t{ўџ џџџџРFMicrosoft Equation 2.0 DS Equation Equation.2ўџџџ‚ўџџџўџџџ…ўџџџ‡ˆ‰Š‹ŒŽ‘’“”ўџџџ–ўџџџўџџџ™šўџџџўџџџўџџџŸ ЁЂЃЄЅІЇЈЉЊЋЌ­ЎўџџџАўџџџўџџџГДўџџџўџџџЗўџџџЙўџџџўџџџМНОПўџџџўџџџТўџџџФўџџџўџџџЧШўџџџўџџџЫўџџџЭЮЯабвгдежзийклмнўџџџпўџџџўџџџтуўџџџўџџџцўџџџшщъыьэюя№ёђѓєѕіїўџџџљўџџџўџџџќ§ўџџџўџџџЭ@G6РO7@O7 ƒtƒg„f–(–)˜†=˜„w†зƒLƒRL hршш hH И џџџ.1   &џџџџРџЋџР Ћ &Equation Native џџџџџџџџџџџџ\_882513916џџџџџџџџ/РFpqjiAЦpqjiAЦOle џџџџџџџџџџџџƒPIC .1џџџџ„LMETA џџџџџџџџџџџџ†ЈCompObj02џџџџ•ZObjInfoџџџџ3џџџџ—Equation Native џџџџџџџџџџџџ˜œ MathType€ћИ§рSymbol„-2 v(ћИ§рSymbol„-№2 Г)њ- oМ Q$ QЕ ћ@ўTimes New Roman-№ 2 $i{ 2 t{ 2 K* 2 НeХћ џTimes New RomantG-№ 2 pУft== 2 §Ц t= 2 7B L| 2 7 Rˆћ@ўSymbol-№ 2 Ѓ=і 2 зpћ џSymbol-№ 2 ‹•-{ћ џTimes New Roman-№ 2 p@0p & џџџџћМ"System-№џџџџџџџџџџ џџџџ ўџ џџџџРFMicrosoft Equation 2.0 DS Equation Equation.2*Ь€'@Р7?@7? ƒi ƒfƒt ƒt–(–)˜†=˜ƒK ˆ0 †зƒe †-ƒt)ƒLƒR.1L'вм Мшш'вю  џџџ.1  ``&џџџџРџЌџ   &_882530946џџџџџџџџ6РF`qiAЦ`qiAЦOle џџџџџџџџџџџџ›PIC 58џџџџœLMETA џџџџџџџџџџџџž( MathTypeањ-LдLђ ћЅ§ Symbol-2 о4 (ћЅ§ Symbol-№2 о)ћ@ўTimes New Roman‚ -№ 2 РNK* 2 РхI• 2 ЄE 2 ^Zљћ џTimes New RomanSy-№ 2 0Žt= 2  mЂћ џTimes New Roman‚ -№ 2 0u0p 2 0s0pћ@ўSymbol-№ 2 Рo=і 2 Рm-і 2 РJ-іћ џSymbol-№ 2 0ъ={ћ@ўTimes New Roman‚ -№ 2 Р, sinЏ{рћ@ўSymbol-№ 2 Рг lі 2 Р’fы & џџџџћМ"System-№№ 2 0u0p 2 0sўџ џџџџРFMicrosoft Equation 2.0 DS Eq§џџџƒ„…†‡ˆ‰ŠŒ‹Ž’‘”•а–˜—™š›œŸžЂ ЁЃЄЅЇІЉЈЯЊЋЮ­ЎЏАБВГДЕЖЗИЙКЛМНОПРСТУФХЦЧШЩЪЫЬЭЮўџџџв§вгдежрийклмнопбстуфхцчшщъыьэюя№ёђѓєѕіїљ§џџџњћќ§ўџCompObj79џџџџЏZObjInfoџџџџ:џџџџБEquation Native џџџџџџџџџџџџВМ_882518204џџџџџџџџ=РFP:{iAЦP:{iAЦuation Equation.2Э G6P'O7р(O7 ƒK ˆ0 ˜†=˜ƒI ƒt†=ˆ0 ˜†-˜ƒE ƒm ƒZ‚s‚i‚n„l˜†-˜„f–(–)Times New Roman‚ -Lд#PфшшOle џџџџџџџџџџџџЕPIC <?џџџџЖLCompObjџџџџџџџџџџџџИZObjInfo>@џџџџКўџ џџџџРFMicrosoft Equation 2.0 DS Equation Equation.2ЭG6x%O7'O7 ƒLƒd ˆ2 ƒi ƒf ƒdƒt ˆ2 ˜†+˜ƒRƒdƒi ƒf ƒdƒt˜†+˜ˆ1ƒCƒi ƒf ƒt–(–)˜†=˜ƒE ƒm †з„w†з‚c‚o‚s„w†зƒt˜†+˜„l–(–)-Equation Native џџџџџџџџџџџџЛ_882518859NCРF0А„iAЦ0А„iAЦOle џџџџџџџџџџџџРPIC BEџџџџСLLTИшшўџ џџџџРFMicrosoft Equation 2.0 DS Equation Equation.2xЭ O?ˆ&_>Ш*_> ƒi ƒf ƒt–(–)˜†=˜ƒi ƒfƒs ƒt–(–)˜†+˜ƒi CompObjџџџџџџџџџџџџУZObjInfoDFџџџџХEquation Native џџџџџџџџџџџџЦМ_882519482џџџџџџџџIРF MŽiAЦ MŽiAЦƒfƒt ƒt–(–)-№2 й7 )Lщвl Мшшщв~8  џџџ.1  `р&џџџџРџЌџ   & MathTypeаћИ§рSymbol-2 й}(ћИ§рSymbol-№2 йИOle џџџџџџџџџџџџЩPIC HKџџџџЪLMETA џџџџџџџџџџџџЬHCompObjJLџџџџоZ)њ-LL.ћЅ§ Symbol-№2 о- (ћЅ§ Symbol-№2 о)ћ@ўTimes New Roman-№ 2 Р$i{ 2 Рt{ 2 Є>E 2 šZљ 2 Рє t{ћ џTimes New Roman-№ 2 0Уfs=W 2 WmЂћ@ўSymbol-№ 2 РЈ=і 2 Р|зp 2 РK зp 2 Рђ +і 2 РШ-іћ@ўTimes New Roman-№ 2 Р%sinЏ{рћ@ўSymbol-№ 2 РВ w1 2 РQlі 2 Рqы & џџџџћМ"System-№ ўџ џџџџРFMicrosoft Equation 2.0 DS Equation Equation.2ObjInfoџџџџMџџџџрEquation Native џџџџџџџџџџџџсМ_882519571GUPРF4šiAЦ4šiAЦOle џџџџџџџџџџџџфxЭ O?р&_>є*_> ƒi ƒfƒs ƒt–(–)˜†=˜ƒE ƒm ƒZ†з‚s‚i‚n„w†зƒt˜†+˜„l˜†-˜„q–(–)$i{ 2 РL8 pшш8Ž9 э џџџ.PIC ORџџџџхLMETA џџџџџџџџџџџџчCompObjQSџџџџјZObjInfoџџџџTџџџџњ1  €@&џџџџРџОџ> & MathTypeњ-ьЫ ьK`.?iњ -GiО-ЦJ2J2Jщћ@ўTimes New Roman- 2 `@Zљ 2 `cR 2 ` Lљ 2 ИC*ћ@ўSymbol-№ 2 `О=і 2 `‡+і 2 `: зp 2 `d -і 2 И`зp 2 rпцЋ 2 пшЋ 2 пчЋ 2 rVіЋ 2 VјЋ 2 VїЋћ џTimes New Roman-№ 2 —†2p 2 :<2pћ@ўTimes New Roman-№ 2 D"1рћ@ўSymbol-№ 2 `Ёw1 2 ИЧ w1 & џџџџћМ"System-№ ЕЕž:№@wV1ЊTЦPўџ џџџџРFMicrosoft Equation 2.0 DS Equation Equation.2xЭ€O?р&_> +_> ƒZ˜†=˜ ƒR ˆ2 ˜†+˜„w†зƒL˜†-˜ˆ1„w†зƒC–(–) ˆ2=і L$ ќшшEquation Native џџџџџџџџџџџџћœ_882519816џџџџcWРFрЉЃiAЦрЉЃiAЦOle џџџџџџџџџџџџўPIC VYџџџџџLўџџџ     ўџџџўџџџўџџџўџџџўџџџўџџџ !"#$%&'()*+,-./0ўџџџ2ўџџџўџџџ567ўџџџўџџџ:ўџџџ<=>?@ABCDEFGHIJKўџџџMўџџџўџџџPQўџџџўџџџTўџџџVWXYZ[\]^ўџџџ`ўџџџўџџџcўџџџўџџџfўџџџhijklmnopqrstuўџџџwўџџџўџџџz{ўџџџ}~€Ž9 Ї џџџ.1  ` &џџџџРџЃџ` & MathTypeаћИ§рSymbol-2 й™(ћИ§рSymbol-№2 й-)њ-OЋ O+њ-L…LKћ@ўTimes New RomanSy-№ 2 Р2tg{р 2 УфLљ META џџџџџџџџџџџџhCompObjXZџџџџZObjInfoџџџџ[џџџџEquation Native џџџџџџџџџџџџ|2 ї C* 2 l Rћ@ўSymbol-№ 2 Рqы 2 Уw1 2 Ї w1ћ@ўSymbol-№ 2 Р=і 2 Узp 2 УD -і 2 @ зpћ@ўTimes New Roman-№ 2 ­ 1р & џџџџћМ"System-№Tw^2ЊјЦЂ ўџ џџџџРFMicrosoft Equation 2.0 DS Equation Equation.2xЭ`O?ь&_>,+_> ƒtƒg„q–(–)˜†=˜„w†зƒL˜†-˜ˆ1„w†зƒCƒR ї LH+МЬшшH+>  џџџ._882514198-j^РFаеЊiAЦаF­iAЦOle џџџџџџџџџџџџPIC ]`џџџџLMETA џџџџџџџџџџџџH1  р`&џџџџРџЎџ Ž & MathType€ћИ§рSymbol-2 љv(ћИ§рSymbol-№2 љГ)ћИ§рSymbol-№2 љp (ћИ§рSymbol-№2 љГ)ћИ§рSymbol-№2 љЭ(ћИ§рSymbol-№2 љ)ћp§Symbol-№2 Ќ(ћp§Symbol-№2 Ђ)ћ@ўTimes New Romanр-№ 2 р$i{ 2 рt{ 2 р§eХ 2 рЋK* 2 рt{ 2 рK* 2 рnt{ћ џTimes New RomanSy-№ 2 PУft== 2 6t=ћ@ўSymbol-№ 2 рЃ=і 2 рŠ зp 2 рhзp 2 рЃ+і 2 рзp 2 рХзpћ џSymbol-№ 2 е-{ 2 з8ћ џSymbol-№ 2 ]aћ@ўSymbol-№ 2 рbі 2 рpbіћ џTimes New Romanр-№ 2 PФ 1p 2 PA2pћ@ўTimes New RomanSy-№ 2 р3 cosХрЏ 2 рХsinЏ{р & џџџџћМ"System-№ўџ џџџџРFMicrosoft Equation 2.0 DS Equation Equation.2ЭрG6˜%O7('O7 ƒi ƒfƒt ƒt–(–)˜†=˜ƒe †-„a†зƒt ˜ƒK ˆ1 †з‚c‚o‚s„b†зƒt–(–)˜†+˜ƒK ˆ2 †з‚s‚i‚n„b†зƒt–(–)–(–)2 љЭ(CompObj_aџџџџ1ZObjInfoџџџџbџџџџ3Equation Native џџџџџџџџџџџџ4ќ_882524288џџџџџџџџeРFАМЖiAЦАМЖiAЦOle џџџџџџџџџџџџ8PIC dgџџџџ9LMETA џџџџџџџџџџџџ;(CompObjfhџџџџLZLвШ МшшвО<  џџџ.1  `@&џџџџРџЌџ  & MathTypeањ-LИLж ћЅ§ Symbol-2 о (ћЅ§ Symbol-№2 о)ћ@ўTimes New Roman@-№ 2 РNK* 2 РЩI• 2 ЄцE 2 BZљћ џTimes New RomanSy-№ 2 0rt= 2 џmЂћ џTimes New Roman@-№ 2 0g1p 2 0W0pћ@ўSymbol-№ 2 РS=і 2 РQ-і 2 Р.-іћ џSymbol-№ 2 0Ю={ћ@ўTimes New Roman@-№ 2 Р sinЏ{рћ@ўSymbol-№ 2 РЗ lі 2 Рvfы & џџџџћМ"System-№ўџ џџџџРFMicrosoft Equation 2.0 DS Equation Equation.2Э G6ш%O7x'O7 ƒK ˆ1 ˜†=˜ƒIObjInfoџџџџiџџџџNEquation Native џџџџџџџџџџџџOМ_882515285џџџџqlРF YРiAЦ YРiAЦOle џџџџџџџџџџџџR ƒt†=ˆ0 ˜†-˜ƒE ƒm ƒZ‚s‚i‚n„l˜†-˜„f–(–)ањ-L*вМшш*в&2  џџџ.1  `€&џџџџРџЌџ@  & MathTypeањ-L-L5ћPIC knџџџџSLMETA џџџџџџџџџџџџUhCompObjmoџџџџ_ZObjInfoџџџџpџџџџa@ўSymbol6- 2 Рaћ@ўSymbol-№ 2 РХ=і 2 _зpћ@ўTimes 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`„˜ў.3„„Ц8^„`„56789;<B*CJH*OJQJS*TXo(Table 6„„Цh^„`„56789:;<B*H*CJOJQJS*TXY( „а„˜ўЦ8^„а`„˜ўo(3.1.„ „˜ўЦ ^„ `„˜ўo()‚„p„LџЦp^„p`„Lџ.€„@ „˜ўЦ@ ^„@ `„˜ў.€„„˜ўЦ^„`„˜ў.‚„р„LџЦр^„р`„Lџ.€„А„˜ўЦА^„А`„˜ў.€„€„˜ўЦ€^„€`„˜ў.‚„P„LџЦP^„P`„Lџ.„h„˜ўЦh^„h`„˜ўCJOJQJo(q№„А„PўЦА^„А`„Pўo([]€„ „˜ўЦ ^„ `„˜ў.‚„p„LџЦp^„p`„Lџ.€„@ „˜ўЦ@ ^„@ `„˜ў.€„„˜ўЦ^„`„˜ў.‚„р„LџЦр^„р`„Lџ.€„А„˜ўЦА^„А`„˜ў.€„€„˜ўЦ€^„€`„˜ў.‚„P„LџЦP^„P`„Lџ.3„‹„˜ўЦ‹^„‹`„˜ў56789:;<B*H*CJOJQJS*TX)3„ѓ„˜ўЦѓ^„ѓ`„˜ў56789:;<B*H*CJOJQJS*TX)3„„ы§Ц^„`„ы§56789:;<B*H*CJOJQJS*TX)3„+ „н§Ц+ ^„+ `„н§56789:;<B*H*CJOJQJS*TX)3„@ „ы§Ц@ ^„@ `„ы§56789:;<B*H*CJOJQJS*TX)џ3„„^„`„56789:;<B*H*CJOJQJS*TXџ3„„^„`„56789:;<B*H*CJOJQJS*TXџ3„„^„`„56789:;<B*H*CJOJQJS*TXџ3„„^„`„56789:;<B*H*CJOJQJS*TX„а„˜ўЦа^„а`„˜ўo()€„ „˜ўЦ ^„ `„˜ў.‚„p„LџЦp^„p`„Lџ.€„@ „˜ўЦ@ ^„@ `„˜ў.€„„˜ўЦ^„`„˜ў.‚„р„LџЦр^„р`„Lџ.€„А„˜ўЦА^„А`„˜ў.€„€„˜ўЦ€^„€`„˜ў.‚„P„LџЦP^„P`„Lџ.3„„Ца^„`„56789;<B*CJH*OJQJS*TXo([B]h „а„˜ўЦа^„а`„˜ўOJQJo(З№h „ „˜ўЦ ^„ `„˜ўOJQJo(oh „p„˜ўЦp^„p`„˜ўOJQJo(Ї№h „@ „˜ўЦ@ ^„@ `„˜ўOJQJo(З№h „„˜ўЦ^„`„˜ўOJQJo(oh „р„˜ўЦр^„р`„˜ўOJQJo(Ї№h „А„˜ўЦА^„А`„˜ўOJQJo(З№h „€„˜ўЦ€^„€`„˜ўOJQJo(oh „P„˜ўЦP^„P`„˜ўOJQJo(Ї№C„„Ц8^„`„56789;<@ˆB*CJEHH*KHOJQJRHdS*TXo(Annex „„Цh^„`„.„„Ц^„`„..„„Ц^„`„... „„Ц^„`„ .... „„Ц^„`„ ..... „„Ц^„`„ ...... „„Ц^„`„....... „„Ц^„`„........„„Цh^„`„.„„Цh^„`„.„„Ца^„`„..„„Ц8^„`„... „„Ц8^„`„ .... „„Ц ^„`„ ..... „„Ц ^„`„ ...... „„Ц^„`„....... „„Ц^„`„........6„„Цh^„`„56789:;<B*H*CJOJQJS*TXY( „а„˜ўЦа^„а`„˜ўB*OJQJo(phџЗ№ „„˜ўЦ^„`„˜ўOJQJo(o „и „˜ўЦи ^„и `„˜ўOJQJo(Ї№ „Ј „˜ўЦЈ ^„Ј `„˜ўOJQJo(З№ „x„˜ўЦx^„x`„˜ўOJQJo(o „H„˜ўЦH^„H`„˜ўOJQJo(Ї№ „„˜ўЦ^„`„˜ўOJQJo(З№ „ш„˜ўЦш^„ш`„˜ўOJQJo(o „И„˜ўЦИ^„И`„˜ўOJQJo(Ї№6„„Цh^„`„56789:;<B*H*CJOJQJS*TXY( „„Цh^„`„.„„Цh^„`„.„„Ца^„`„..„„Ц8^„`„... „„Ц8^„`„ .... „„Ц ^„`„ ..... „„Ц ^„`„ ...... „„Ц^„`„....... „„Ц^„`„........h „а„˜ўЦа^„а`„˜ўOJQJo(З№h „ „˜ўЦ ^„ `„˜ўOJQJo(oh „p„˜ўЦp^„p`„˜ўOJQJo(Ї№h „@ „˜ўЦ@ ^„@ `„˜ўOJQJo(З№h „„˜ўЦ^„`„˜ўOJQJo(oh „р„˜ўЦр^„р`„˜ўOJQJo(Ї№h „А„˜ўЦА^„А`„˜ўOJQJo(З№h „€„˜ўЦ€^„€`„˜ўOJQJo(oh „P„˜ўЦP^„P`„˜ўOJQJo(Ї№6„„Ц8^„`„56789:;<B*CJH*OJQJS*TXY(NOTE  @1„1„Я§^„1`„Я§) „h„˜ўЦh^„h`„˜ўOJQJo(О№3„„Ца^„`„56789;<B*CJH*OJQJS*TXo([A]"„„˜ўЦ^„`„˜ў789;<B*CJ H*S*TX„а„˜ўЦа^„а`„˜ўo()„ „˜ўЦ ^„ `„˜ў.„p„LџЦp^„p`„Lџ.€„@ „˜ўЦ@ ^„@ `„˜ў.€„„˜ўЦ^„`„˜ў.‚„р„LџЦр^„р`„Lџ.€„А„˜ўЦА^„А`„˜ў.€„€„˜ўЦ€^„€`„˜ў.‚„P„LџЦP^„P`„Lџ.6„„Цh^„`„56789:;<B*H*CJOJQJS*TXY( :„‹„˜ўЦ‹^„‹`„˜ў56789:;<B*CJH*CJOJQJS*TXo()=„ѓ„˜ўЦѓ^„ѓ`„˜ў56789:;<>*B*CJH*CJOJQJS*TXo():„„ы§Ц^„`„ы§56789:;<B*CJH*CJOJQJS*TXo():„+ „н§Ц+ ^„+ `„н§56789:;<B*CJH*CJOJQJS*TXo():„@ „ы§Ц@ ^„@ `„ы§56789:;<B*CJH*CJOJQJS*TXo()џ:„„^„`„56789:;<B*CJH*CJOJQJS*TXo(џ7„„^„`„56789:;<B*CJH*CJOJQJS*TXџ7„„^„`„56789:;<B*CJH*CJOJQJS*TXџ7„„^„`„56789:;<B*CJH*CJOJQJS*TX3„„ Ц№^„`„ 56789;<B*CJH*OJQJS*TXo(Figure h „а„˜ўЦа^„а`„˜ўOJQJo(З№h „ „˜ўЦ ^„ `„˜ўOJQJo(oh „p„˜ўЦp^„p`„˜ўOJQJo(Ї№h „@ „˜ўЦ@ ^„@ `„˜ўOJQJo(З№h „„˜ўЦ^„`„˜ўOJQJo(oh „р„˜ўЦр^„р`„˜ўOJQJo(Ї№h „А„˜ўЦА^„А`„˜ўOJQJo(З№h „€„˜ўЦ€^„€`„˜ўOJQJo(oh „P„˜ўЦP^„P`„˜ўOJQJo(Ї№"„„PўЦ^„`„Pў789;<B*CJ H*S*TX„а„˜ўЦа^„а`„˜ўo()€„ „˜ўЦ ^„ `„˜ў.‚„p„LџЦp^„p`„Lџ.€„@ „˜ўЦ@ ^„@ `„˜ў.€„„˜ўЦ^„`„˜ў.‚„р„LџЦр^„р`„Lџ.€„А„˜ўЦА^„А`„˜ў.€„€„˜ўЦ€^„€`„˜ў.‚„P„LџЦP^„P`„Lџ.џ„„Ц8^„`„56CJOJQJo( Abstract:„„PўЦ^„`„Pў789;<CJ H*S*TXџ„„Ц8^„`„56CJOJQJo( Keywords:„а„˜ўЦа^„а`„˜ўo()€„ „˜ўЦ ^„ `„˜ў.‚„p„LџЦp^„p`„Lџ.€„@ „˜ўЦ@ ^„@ `„˜ў.€„„˜ўЦ^„`„˜ў.‚„р„LџЦр^„р`„Lџ.€„А„˜ўЦА^„А`„˜ў.€„€„˜ўЦ€^„€`„˜ў.‚„P„LџЦP^„P`„Lџ.@1„њ„Я§^„њ`„Я§)„а„PЦˆ^„а`„P 3„„^„`„56789;<B*CJH*OJQJS*TXo(.6„„^„`„56789;<>*B*CJH*OJQJS*TXo(.3„„^„`„56789;<B*CJH*OJQJS*TXo(..3„„^„`„56789;<B*CJH*OJQJS*TXo(... 3„„^„`„56789;<B*CJH*OJQJS*TXo( .... 3„„^„`„56789;<B*CJH*OJQJS*TXo( ..... 3„„^„`„56789;<B*CJH*OJQJS*TXo( ...... 3„„^„`„56789;<B*CJH*OJQJS*TXo(....... 3„„^„`„56789;<B*CJH*OJQJS*TXo(........:„‹„˜ў^„‹`„˜ў56789:;<B*CJH*CJOJQJS*TXo()=„ѓ„˜ў^„ѓ`„˜ў56789:;<>*B*CJH*CJOJQJS*TXo():„„ы§^„`„ы§56789:;<B*CJH*CJOJQJS*TXo():„ „ы§^„ `„ы§56789:;<B*CJH*CJOJQJS*TXo():„2 „ы§^„2 `„ы§56789:;<B*CJH*CJOJQJS*TXo()џ:„„^„`„56789:;<B*CJH*CJOJQJS*TXo(џ3„„^„`„56789:;<B*H*CJOJQJS*TXџ3„„^„`„56789:;<B*H*CJOJQJS*TXџ3„„^„`„56789:;<B*H*CJOJQJS*TX@1„1„Я§^„1`„Я§)„ „˜ўЦ ^„ `„˜ўo(.’„p„LџЦp^„p`„Lџ.„@ „˜ўЦ@ ^„@ `„˜ў.„„˜ўЦ^„`„˜ў.’„р„LџЦр^„р`„Lџ.„А„˜ўЦА^„А`„˜ў.„€„˜ўЦ€^„€`„˜ў.’„P„LџЦP^„P`„Lџ.„а„˜ўЦа^„а`„˜ўo()„ „˜ўЦ ^„ `„˜ў.„p„LџЦp^„p`„Lџ.€„@ „˜ўЦ@ ^„@ `„˜ў.€„„˜ўЦ^„`„˜ў.‚„р„LџЦр^„р`„Lџ.€„А„˜ўЦА^„А`„˜ў.€„€„˜ўЦ€^„€`„˜ў.‚„P„LџЦP^„P`„Lџ.„„Цh^„`„.„„Цh^„`„.„„Ца^„`„..„„Ца^„`„... „„Ц8^„`„ .... „„Ц8^„`„ ..... „„Ц ^„`„ ...... „„Ц ^„`„....... „„Ц^„`„........„а„˜ўЦа^„а`„˜ўo()„ „˜ўЦ ^„ `„˜ў.„p„LџЦp^„p`„Lџ.€„@ „˜ўЦ@ ^„@ `„˜ў.€„„˜ўЦ^„`„˜ў.‚„р„LџЦр^„р`„Lџ.€„А„˜ўЦА^„А`„˜ў.€„€„˜ўЦ€^„€`„˜ў.‚„P„LџЦP^„P`„Lџ.„ˆ„PўЦˆ^„ˆ`„PўCJOJQJo( „„Цh^„`„.„„Цh^„`„.„„Ца^„`„..„„Ц8^„`„... „„Ц8^„`„ .... „„Ц ^„`„ ..... „„Ц ^„`„ ...... „„Ц^„`„....... „„Ц^„`„........6„„Цh^„`„56789:;<B*H*CJOJQJS*TXY( „а„˜ўЦа^„а`„˜ўo()€„ „˜ўЦ ^„ `„˜ў.‚„p„LџЦp^„p`„Lџ.€„@ „˜ўЦ@ ^„@ 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xџ œ.xџ $ xџT ѕxџ! xџ œ.xџ $ xџT ѕxџ! xџ œ.xџ $ xџT ѕxџ! xџ œ.xџ $ xџ0 ќЦ˜  0 ќЦи  0 ќЦ  0 ќЦX  0 ќЦ˜  0 ќЦи  T ѕxџ! xџ œ.xџ $ xџT ѕxџ! xџ œ.xџ $ xџT ѕxџ! xџ œ.xџ $ xџT ѕxџ! xџ œ.xџ $ xџX$ˆ/l§œxџ0$1 2xџ$$ xџ0 ќЦX  0 ќЦ˜  0 ќЦи  0 ќЦ  0 ќЦX  0 ќЦ˜  0 ќЦи  0 ќЦ  0 ќЦX  0 ќЦ˜  0 ќЦи  0 ќЦ  0 ќЦX  0 ќЦ˜  0 ќЦи  Шd lќјpџlџ! №Qlџhџ'(џ:XџNHџHџhџ а6Hџ(џ'(џ:XџNHџHџhџ а6Hџ(џќcќјhџlџ! єQlџ$џ'(џ:XџNHџHџ$џ а6Hџ(џ'(џ:XџNHџHџ$џ а6Hџ(џ'(џ:XџNHџHџ$џ а6Hџ(џ'(џ:XџNHџHџ$џ а6Hџ(џќcќј$џlџ! 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This sdiџџџџ€џџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџ џџџџџџџџјTahomaue,Р р Xџџџџџџџџџџџџ` џџџџ   џџџџџџџџ€ џџџџџџџџџџџџџџџџџџџџЈџџџџјџџџџџџџџџџџџџџџџџџџџџџџџШџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџXp@pџџџџlџџџ џџ bas€XdeveloшџџџџEE StaџџџџXo assist Worng@ўџџџџџhџџџ џџ per џџџџўџџџџџdџџџр`s, a4%џџџџШEE Sta@ўџџџџџTџџџ џџ н&@ўџџџџџDџџџ џџ џџџџаџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџаџџџџџџџџ  toolbar thaisџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџ` џџџџшџџџџHџџџџџџџџџџџџџџџџИџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџˆиџџџџXnО^Иred In" @ўџџџџџxџџџ џџ on tўџџџџџtџџџа`al l4%џџџџИcument@ўџdџџџ џџ rall@ўџ0Tџџџ џџ upd@ўџxDџџџ џџ rm. @ўџ4џџџ џџ form@ўџџџџџ0џџџџџ king@ўџџџџџ,џџџџџ .." @ўџџџџџџџџ џџ he f@ўџџџџџ џџџ џџ tds џџџџАџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџPџџџџџџџџК„stdo>џџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџ8џџџџџџџџи џџџџџџџџџџџџџџџџXИџџџџ џџџџ`џџџџџџџџџџџџџџџџpџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџ@ @Рџџџџlџџџ џџ8F-102608C4џџџџ#0#C:\џџџџXмem32\FM20.L#@ўџаhџџџ џџ Objeўџџџџџdџџџˆ`*\G{4%џџџџp-0000-@ўџTџџџ џџ #@ўџDџџџ џџ M@ўџш@џџџ џџ *\@ўџH<џџџ џџ -B73@ўџ0,џџџ џџ 0#D:@ўџџџџџџџџ џџ OCAL@ўџџџџџ џџџ џџ .exd@ўџџџџџџџџ џџ Obj@ўџџџџџџџџџџ рџџџџрџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџPџџџџ8џџџџ€Аџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџ џџџџџџџџМrfpюшїюшїюшшя@ўџ˜lџџџ џџ ><:ї@ўџhhџџџџџ џџџџ@ўџџџџџdџџџџџ џџџ@ўџџџџџTџџџ џџ џџџџ@ўџDџџџ џџ РРР@ўџШBџџџ џџ РРРР@ўџр@џџџ џџ РРРР@ўџј>џџџ џџ РРРР@ўџџџџџ<џџџ џџ РРРР@ўџџџџџ,џџџ џџ tиаЫџџџџаџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџаџџџџџџџџ 00РРРРРРРРРџџџџpџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџJ €YЎXЫР! 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For dated references, only the edition cited applies. For undated ЖEreferences, the latest edition of the referenced document (including Ж&any amendments or corrigenda) applies. О ОЖIEEEStds Paragraph fA@pџ џџA@roџџ–@ џџA@roџџШ–€ЌA@~oџџЈџџџџ џџџџВAttribute VB_Name = "add_references_headˆ" ЈBasЈ0{D6241EE3-D66E-4796-A081-B6F2057583E0}{5D5(39-C0A6-4D5A-B9FB-3A2B2CB9104E} dGlob„al•Spaco False ŠCr@eatablP€redeclaDIdоTru BE`xpose0TemplateDeriv–Cus tomiz‹DP Sub OK_Click() CheckWhГƒInsFmtText €"Normat7 Ф" & vbCr, "IEEEStds Le€vel 1 H€бer", wdCollapseE”nd2'пer1 The f€owing‡d documents РL indispens6for btapp€2@(on С%_У"of‰€isЦ. 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ClientHeight = 3090 ClientLeft = 45 ClientTop = 435 ClientWidth = 5415 StartUpPosition = 1 'CenterOwner TypeInfoVer = 15 End   }К" ј‹(ѕ€2HLabel1д х€hallE$х€Tscope1 ,х€@add_overviewџџџџџџџџіpћаiAЦpћаiAЦfџџџџџџџџџџџџ§&oѕїџџџџœ CompObjџџџџјџџџџ1aўџџџ      !"#$%&'()*+,-./0ўџџџ2ўџџџ4567ўџџџ9:;<=ўџџџ?@ABCDEFўџџџHўџџџJKLMNўџџџPQRSўџџџUVWXYZ[\]^_`abcdefghiўџџџkўџџџmnopўџџџrstuўџџџwxyz{|}~€InsertHeadingss:Ъ&(ѕ€;8cancel&,ѕ €0ДinstructionsдЅ (ѕ€2XLabel3Щ14ѕ€2~style_manual_linkdЩй(ѕ€ 2pLabel4д‰(ѕ€ 2˜ Label22дд0ѕ€ 2Ž PARapproval_linkд" (€Then choose one:? Ј ї€@ЅМTahomaHGР€€,€€€€w•0Overview, Scope and Purpose5€УTahoma4FР€€€€ €3 А0Scope onlye 5€УTahoma (€Insert Headings:ь Ou€ЅTahoma(€Cancelь Ou€ЅTahoma”)џ€€After inserting headings, to add body text to a section, position cursor at end of header, click Return, and type or paste text.!Аu€ЅTahoma0)џ€IEEE Standards Style Manual:њЇ ї€@ЅМTahoma@iџ'€cџџhttp://standards.ieee.org/guides/style/њXRу ‘ЮуЊKИQltў ш( @€€€€€€€€€€€€€РРРџџџџџџџџџџџџЬDDD@ЬDDD@ЬDDD@ЬDDD@ЬDDD@Dџџјџџјџџџџ€џџџџ€џџџџџјџџџџџјџџџџџјџџџџџџ€џџџџџџџ€џˆџџџџџ€јџџџџџ€€џџџџ€јџїј€pј€ј€ј€јpј€јј€wјpјјјјwџџџџџџџџџрџџрџџрџџрџџрџџ№џџ№џџ№џџрџџРџџ€џџ€џџџџџўџўџќџќ џј`џјрџџрџџрџџрџџрџџсџџџсџџџсџџџсџџџѓџџџџџџ ї€@ЅМTahomaP(?€Consult the Style Manual for further details on these sections.џ!Јu€ЅTahomax(f€Get or check the correct Overview, Scope and Purpose (if applicable) using the PAR Approval History: !Nu€ЅTahomaPmџ€1€cџџhttp://standards.ieee.org/board/nes/approved.htmls!XRу ‘ЮуЊKИQltў ш( @€€€€€€€€€€€€€РРРџџџџџџџџџџџџЬDDD@ЬDDD@ЬDDD@ЬDDD@ЬDDD@Dџџјџџјџџџџ€џџџџ€џџџџџјџџџџџјџџџџџјџџџџџџ€џџџџџџџ€џˆџџџџџ€јџџџџџ€€џџџџ€јџїј€pј€ј€ј€јpј€јј€wјpјјјјwџџџџџџџџџрџџрџџрџџрџџрџџ№џџ№џџ№џџрџџРџџ€џџ€џџџџџўџўџќџќ џј`џјрџџрџџрџџрџџрџџсџџџсџџџсџџџсџџџѓџџџџџџ ї€@ЅМTahomaўџ џџџџMicrosoft Forms 2.0 FormEmbedded Objectє9ВqVERSION 5.00 Begin {C62A69F0-16DC-11CE-9E98-00AA00574A4F} add_overview Caption = "Overview, Scope and Purpose" ClientHeight = 4065 ClientLeft = 45 ClientTop = 435 ClientWidth = 5040 StartUpPosition = 1 'CenterOwner TypeInfoVer = 18 End VBFrameџџџџџџџџџџџџ39change_def_level"єўћpћаiAЦpћаiAЦfџџџџџџџџџџџџ8Foњќџџџџ>$H @ }ы†$х€tlevel3Oq$х€tlevel2Oі х€4OKх{“ (ѕ€;8cancel“ (ѕ€2TLabel1"Ї0ѕ €0\prompt_selectsЇO ѓTFР€€€€€ €›a0Level 3 (#.#.#; as in 3.1.1)change_to#.#5€ЅTahomaTFР€€€€€ €›a0Level 2 (#.#; as in 3.1)change_to(#.5€ЅTahoma(€OKхь Ou€ЅTahoma(€Cancelь Ou€ЅTahoma4(#€Set or update term numbering level:Ј5€ЅTahoma<-џ€#€Please select a level, and click OKSЇu€ЅTahomaўџ џџџџMicrosoft Forms 2.0 FormEmbCompObjџџџџ§џџџџGaVBFrameџџџџџџџџџџџџICadd_references_head(џџџџpћаiAЦpћаiAЦfџџџџџџџџџџџџO:edded Objectє9ВqVERSION 5.00 Begin {C62A69F0-16DC-11CE-9E98-00AA00574A4F} change_def_level Caption = "Definitions: Term numbering level" ClientHeight = 2310 ClientLeft = 45 ClientTop = 435 ClientWidth = 3855 StartUpPosition = 1 'CenterOwner TypeInfoVer = 13 End    }O% †(ѕ€2АLabel1ЇЇ(ѕ€2tLabel2Ї (ѕ€2XLabel3Їі4ѕ€2~style_manual_linkЪ х€4OKхqg $х€8cancelиg (€€References should be listed in alphanumerical order by designation, including full year and title. See Style Manual for details.ц!O5€ЅTahomaT(B€Please also note that the References clause typically is Clause 2.onoџџџџџTfCompObjџџџџџџџџjaVBFrameџџџџџџџџџџџџl:add_definitions_head*џџџџџџџџpћаiAЦpћаiAЦц!{5€ЅTahoma0)џ€IEEE Standards Style Manual:ц!Ї ї€@ЅМTahoma@iџ'€cџџhttp://standards.ieee.org/guides/style/ЂXRу ‘ЮуЊKИQltў ш( @€€€€€€€€€€€€€РРРџџџџџџџџџџџџЬDDD@ЬDDD@ЬDDD@ЬDDD@ЬDDD@Dџџјџџјџџџџ€џџџџ€џџџџџјџџџџџјџџџџџјџџџџџџ€џџџџџџџ€џˆџџџџџ€јџџџџџ€€џџџџ€јџїј€pј€ј€ј€јpј€јј€wјpјјјјwџџџџџџџџџрџџрџџрџџрџџрџџ№џџ№џџ№џџрџџРџџ€џџ€џџџџџўџўџќџќ џј`џјрџџрџџрџџрџџрџџсџџџсџџџсџџџсџџџѓџџџџџџ ї€@ЅМTahoma(€OKхь Ou€ЅTahoma(€Cancelь Ou€ЅTahomaўџ џџџџMicrosoft Forms 2.0 FormEmbedded Objectє9ВqVERSION 5.00 Begin {C62A69F0-16DC-11CE-9E98-00AA00574A4F} add_references_head Caption = "Add References Clause" ClientHeight = 2475 ClientLeft = 45 ClientTop = 435 ClientWidth = 5415 StartUpPosition = 1 'CenterOwner TypeInfoVer = 11 End $H @ }м&…"ф…(ѕ€2XLabel3ЇЮ4ѕ€2~style_manual_linktepu(ѕ€2шLabel4Їд х€4OKхEФ(ѕ€;8cancelзФ ѓ0)џ€IEEE Standards Style Manual:#Ї ї€@ЅМTahoma@iџ'€cџџhttp://standards.ieefџџџџџџџџџџџџq&oџџџџv*CompObjџџџџџџџџ“aVBFrameџџџџџџџџџџџџ•<‚ƒ„…†‡ˆ‰Š‹ŒŽ‘’ўџџџ”ўџџџ–—˜™ўџџџ›ўџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџe.org/guides/style/њXRу ‘ЮуЊKИQltў ш( @€€€€€€€€€€€€€РРРџџџџџџџџџџџџЬDDD@ЬDDD@ЬDDD@ЬDDD@ЬDDD@Dџџјџџјџџџџ€џџџџ€џџџџџјџџџџџјџџџџџјџџџџџџ€џџџџџџџ€џˆџџџџџ€јџџџџџ€€џџџџ€јџїј€pј€ј€ј€јpј€јј€wјpјјјјwџџџџџџџџџрџџрџџрџџрџџрџџ№џџ№џџ№џџрџџРџџ€џџ€џџџџџўџўџќџќ џј`џјрџџрџџрџџрџџрџџсџџџсџџџсџџџсџџџѓџџџџџџ ї€@ЅМTahomaШ,€Д€After adding the clause, to add terms and definitions: 1) Type or copy and paste terms and definitions text, and be sure -each term is followed by a colon (:), then the definition -each definition ends in a return 2) Select all terms and definitions 3) Click Special -> Terms+Definitions, OR Definitions -> Format Terms+Definitions. To order terms and definitions alphabetically: 1) Select all terms and definitions 2) Click Table -> Sort, and Sort by paragraphs If the Defintions clause number changes, click Document Operations -> Update All Fields to update term numbering. Consult the style manual and template user guide for more details:Ž#&5€ЅTahoma(€OKхь Ou€ЅTahoma(€Cancelь Ou€ЅTahomaўџ џџџџMicrosoft Forms 2.0 FormEmbedded Objectє9ВqVERSION 5.00 Begin {C62A69F0-16DC-11CE-9E98-00AA00574A4F} add_definitions_head Caption = "Add Definitions Clause" ClientHeight = 5010 ClientLeft = 45 ClientTop = 435 ClientWidth = 5640 StartUpPosition = 1 'CenterOwner TypeInfoVer = 11 End ўџ џџџџ РFMicrosoft Word Document MSWordDocWord.Document.8є9Вq      !"#$%&'()*+,-./0123456789:;<=>?@ABўџџџўџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџџўўў0  *@#Bibliographic EntryIEEEStds Bibliographic Entryˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ(Caution/Warning Add WarningNewMacros.AddWarning˜ш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџО *@# Computer CodeIEEEStds Computer Codeˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ(FootnoteRegular FootnoteNewMacros.InsertRegularFootnote˜ш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџО(Single Note or Multiple Notes Add NotesNewMacros.AddNotes˜ш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџО(Terms+DefinitionsDefsNewMacros.FormatDefs˜ш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџО(Equation New EquationNewMacros.InsertNewEquation˜ш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџО *@#Equation Variable ListIEEEStds Equation Variable Listˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ *@#HeaderIEEEStds Headerˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ *@#FooterIEEEStds Footerˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџCustom Popup 46Ÿџџ– Custom Popup 46ўўўўў0   *@# Annex Title (Heading 1) Heading 1ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@#Level 1 (Heading 2) Heading 2ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@#Level 2 (Heading 3) Heading 3ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@#Level 3 (Heading 4) Heading 4ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@#Level 4 (Heading 5) Heading 5ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@#Level 5 (Heading 6) Heading 6ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@# Level 6 (Heading 7) Heading 7ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@# Level 7 (Heading 8) Heading 8ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@# Level 8 (Heading 9) Heading 9ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџCustom Popup 47Ÿџџ– Custom Popup 47ўўўўў0 *@#1Regular Figure CaptionIEEEStds Figure Captionˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ *@#"Regular Table CaptionIEEEStds Table Captionˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ *@#/Annex Figure/Table CaptionCaptionˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџCustom Popup 48Ÿџџ– Custom Popup 48ўўўўў0Custom Popup 49Ÿџџ– Custom Popup 49ўўўўў0 (Start New ListNew ListNewMacros.InsertNewList˜ш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџО" *@#$Apply List Level 1 (a, b, c...)IEEEStds Numbered List Level 1ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@#%Apply List Level 2 (1, 2, 3...)IEEEStds Numbered List Level 2ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@#&"Apply List Level 3 (i, ii, iii...)IEEEStds Numbered List Level 3ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@#'"Apply List Level 4 (i, ii, iii...)IEEEStds Numbered List Level 4ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџ  *@#("Apply List Level 5 (i, ii, iii...)IEEEStds Numbered List Level 5ˆш(џ€€€€€€€€™ЈЌРРРџџџџџищьџџџџџp(џџџџџџџ‰џџэ­џџн‹џџИщџџЭяџџџџџџ‘џџ‘џџ—wџџ‘џџ‘џџ—wџџ‘џџ‘џџџџџџCustom Popup 50Ÿџџ– Custom Popup 50ўўўўў0 (Insert Table... 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