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CES Department Record of Revision Sr.No 1 2 3 4 5 6 7 8 9 10 Revision No R1 R1 R1 R1 R1 R1 R1 R1 R1 R1 Item/Clause No Nature of Change Approved By D E I.VIII Anexxure1.1 to 1.8 Annexure 2.1 to 2.7 Annexure5.8 to 5.24 & Note Annexure6 Annexure-3.1 To 3.5 Annexure-4 (10th Count) Annexure-7 Table Addition Addition Added Added and Edited Added and Edited Added and Edited Addition Addition and Edited Deletion Addition DSP/AM DSP/AM DSP/AM DSP/AM DSP/AM DSP/AM DSP/AM DSP/AM DSP/AM DSP/AM Technical Guidelines for Grid Tied Distributed Generation (Solar) . i CES Department Content: Sr. No. Description Page No A Introduction 1 B Salient Stipulations in MERC Reg. 2015 1 C Codes and Standards 2 D E F IEEE 519 Harmonic Standards and IEC 61000-3-3 Flicker Standards Technical requirement of the Grid Connected Roof Top Solar Equipment Features 3 3 6 i Solar PV modules and array 6 ii Module mounting structure 7 iii Power Conditioning Unit/Inverter 7 iv ACDB (LT Panel) 8 v DC & AC Switches 8 vi Cables and installation accessories 8 vii Earthing and lightning protection 8 G Preliminary Site Visit Check List 9 H Pre Commissioning Check List 9 I Safety 9 Annexure – 1: SLD for < 8 kW , single-phase 12 Annexure – 2: SLD for > 8 kW but < 150 kW, 3-phase 13 Annexure – 3: SLD for > 150 kW , 3-phase 15 Annexure – 4: Preliminary Survey Check-Sheet 16 Annexure – 5: Commissioning Check-Sheet 17 Annexure – 6: Dimensions of equipment 17 Annexure---7: Sample Documents 20 Technical Guidelines for Grid Tied Distributed Generation (Solar) . ii CES Department List of Tables Sr. No. Description Page No 1 Codes and Standards 2 2 Harmonic Voltage Distortion Limits in Percent of Nominal Fundamental Frequency Voltage ( IEEE Standard 5191992, table 11.1) 2 3 Basis for Harmonic Current Limits 2 4 Harmonic Current Distortion limits (Ih) in percent of IL 2 5 Flicker standard IEC 61000-3-3 3 6 Grid Connectivity technical requirement Technical Guidelines for Grid Tied Distributed Generation (Solar) 3-6 . iii CES Department List of Figures Sr. No. Description Page No 1 Standard Shutdown Procedure Signage content 10 2 Specification on the Meter Cabin 11 3 Signage on/near the components in the meter cabin 11 4 Signage near Inverter 11 A.1 A.2 A.3 Typical SLD of grid Connected Roof Top PV with capacity below 8kW Typical SLD for grid Connected Roof Top PV with capacity above 8kW and below 150kW Typical SLD grid Connected Roof Top PV with capacity above 150kW Technical Guidelines for Grid Tied Distributed Generation (Solar) . 12 13 15 iv CES Department A. Introduction The depleting sources of fossil fuels, sharp increase in power tariffs to industrialists due to heavy subsidies to Agriculture, very high T&D losses, decrease in reliability of power required, leads one to think of the alternative soco-economic, efficient, environment friendly and reliable sources of energies. The Power crises in Maharashtra is increasing day by day with a peak demand shortfall of 2000 MW. Maharashtra is having a total installed capacity of 15085 MW (including Central sector share) of centralized power plants and 623 MW of decentralized non-conventional power plants. Still there is a large potential in the non-conventional energy sources sector which can be tapped. This distributed potential can be harnessed to meet increasing power demand and to improve the techno-economic scenario. Setting up of large solar power projects requires huge land space whereas availability of land is a major constraint in Mumbai city limits. The prevailing scenario of declining trend in solar prices and increasing retail power tariff across most consumer categories like residential, commercial and industrial consumers would encourage consumers to install roof top solar systems. . Therefore, roof top solar is set to witness appreciable scaling of capacities in Mumbai. With the new regulation (Net Metering for Roof-top Solar PV Systems Regulations 2015) issued by MERC, RInfra has decided to issue Technical policy document for NET-metering and LT connectivity. B. Salient Stipulations in MERC (Net Metering for Roof-top Solar PV Systems) Regulations, 2015 – at a Glance 1. Shall be permitted on “first come first serve” basis (Cl. 3.1) 2. Cumulative Capacity of all Roof-top Solar PV (RT-SPV) Systems under Net Metering connected to a particular DT of RInfra shall not exceed 40 % of its Capacity (Cl.4.1) 3. RInfra shall provide information on Website regarding Solar capacity available against each DT within 3 months of this notification (Cl. 4.2) 4. Roof-top Solar PV System Capacity shall not exceed the Consumer’s Contract Demand (in kVA) or Sanctioned Load (in kW) (Cl. 5.1) 5. AC Voltage level of Solar Injection shall be as below: (Cl. 5.2) a. 230 / 240 V (single-phase) -------------------- for capacity less than 8 kW / 40 Amp b. 400 / 415 V (three-phase) -------------------- for cap. less than 150 kW /187 kVA c. 11 kV and above --------------------------------- for cap. above 150 kW / 187 kVA 6. HT (11 kV & above) Consumers may inject at LT Bus-bar, provided that Net Meter is installed on the HT side of Transformer.(Cl.5.4) Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 1 of 24 CES Department 7. Consumer may install RT-SPV with or without Battery back-up provided that if battery is present, separate back-up wiring to prevent the battery Power from flowing into the RInfra Grid in absence of Grid supply. (Cl.6.2) 8. Consumer shall provide adequate protection for Islanding the RT-SPV from RInfra Network in the event of grid supply failure (Cl.6.4) 9. RInfra shall ensure that the inter-connection of the RT-SPV System with it’s Network conforms to Specifications , Standards and other provisions specified in the CEA (Technical Standard for Connectivity of the Distributed Generation Resources) Regulations, 2013, the CEA (Measures Relating to Safety & Electric Supply) Regulations 2010 and the MERC (State Grid Code) Regulations 2006 or as may be specified in future.(Cl. 6.1) 10. Metering arrangement shall have Net Meter (procured and installed by RInfra) and also Solar Generation Meter (procured & installed by Consumer or RInfra, who desires that such energy be counted towards meeting its RPO) (Cl. 7) C. Codes and Standards The installation shall meet the requirements of Indian Electricity rules, CEA and MERC Guidelines for grid connectivity. The materials, equipment and methods used in the installation shall conform to the latest edition of IS and IEC standards, and other national and international applicable standards including the following. If standard other than IS/IEC are used in design, manufacturing and testing, a copy of the same in English shall be submitted. IEEE 929-2000 Recommended Practice for Utility Interface of Photovoltaic (PV) Systems IEC 61730 Part 1- Requirements for construction & requirements for testing, for safety qualification 2 IEEE 519 Power Quality Standards IEC 61000 Flicker Standard IEC 61683 Photovoltaic systems - Power conditioners - Procedure for measuring efficiency IEC 62093 Balance-of-system components for photovoltaic systems - Design qualification natural environments EMC EN 61000-6-2, EN 61000-6-4, EN 61000-3-11, EN 61000-3-12, EN 50178 IEC 62109-2 Safety of power converters for use in photovoltaic power systems - Part 2: Particular requirements for inverters IEC 62116 Test procedure of islanding prevention measures for utility interconnected photovoltaic inverters IEC 60269 / IS- Low voltage fuses 13703 IS 15707 Testing, Evaluation, Installation and Maintenance of ac Electricity Meters - Code of Practice. IEC 60947 Low Voltage Switchgear and Control-gear IS 1554 PVC Insulated Cable for working voltages up to and including 1100V IS 2551 Signage Requirement Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 2 of 24 CES Department IS 3043 IEC 62305 IEC 62446 IS 732 CEA -2007 CEA-2013 MERC -2013 Earthing Standards Lightning Protection Operation , Maintenance and Documentation Wiring Rules Technical Standards for connection to grid 2007 ( amendment 2013) Technical standard for Connectivity of the Distributed generation resources regulation 2013 Maharashtra Electricity Regulatory Commission ( Net Metering for Roof Top Solar Phot0 Voltaic Systems) Regulation 2013 Table 1: Codes and Standards D. IEEE 519 Harmonic Standards and IEC 61000-3-3 Flicker Standards Bus Voltage at PCC Vn (kV) Vn ≤ 69 69 ≤ Vn ≤161 Individual Harmonic Distortion (%) 2 1.5 Voltage Total Voltage Distortion, THDVn (%) 5 2.5 Vn > 161 1.0 1.5 Table 2: Harmonic Voltage Distortion Limits in Percent of Nominal Fundamental Frequency Voltage ( IEEE Standard 519-1992, table 11.1) 20 Max individual frequency Related Assumption voltage harmonic (%) 2.5-3.0 Dedicated system 2-2.5 1-2 Large customer 50 100 1000 1-1.5 0.5-1.0 0.05-0.10 Short Circuit ratio at PCC 10 A few relatively large customer 5-20 medium size customer Many small customer Table 3 Basis for Harmonic Current Limits Isc/IL h<11 11≤ h ≤17 17≤ h ≤23 23≤ h ≤35 35 ≤h TDD <20 20-50 4 7 2 3.5 1.5 2.5 0.6 1 0.3 0.5 5 8 50-100 10 4.5 4 1.5 0.7 12 100-1000 12 5.5 5 2 1 15 >1000 15 7 2.5 1.4 6 Table 4: Harmonic Current Distortion limits (Ih) in percent of IL 20 Note: IL: is fundamental component of the maximum demand load current Isc: Short circuit current at PCC Ih: Magnitude of individual harmonic component (rms amps) Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 3 of 24 CES Department Value Pst (Short term "perceptibility" value) Plt (Long term "perceptibility" value) flicker flicker Observation Interval Limiting Value 10 min 1.0 2h 0.65 Table 5: Flicker standard IEC 61000-3-3 E. Technical requirement of the Grid Connected Roof Top Solar Sr.No 3 Parameter Overall conditions of service Overall Grid Standards Equipment 4 Meters 5 Safety and supply 6 Harmonic Requirements Harmonic Current 1 2 7 8 9 10 11 Reference Requirement State Distribution/Supply Code Reference to State Distribution Code CEA Regulation 2010 Reference to regulations BIS / IEC / IEEE Central Electricity authority (Installation & operation of meters) Regulation 2006 Central Electricity authority (measure for safety and electricity supply) Regulation 2010 IEEE 519, CEA (Technical Standards for Connectivity of the Distributed Generation Resources) Regulations 2013 Reference to standards Reference to regulations and additional conditions issued by the Commission. Reference to regulations Harmonic current Injections from a generating station shall not exceed the limits specified in IEEE 519 (indicated in Section D) Photovoltaic system must be equipped with CEA (Technical Standards a grid frequency synchronization device. for Connectivity of the Every time the generating station is Synchronization Distributed Generation synchronized to the electricity System, It Resources) Regulations shall not cause voltage fluctuation greater 2013 than +/- 5% at point of connection. The voltage-operating window should CEA (Technical Standards minimize nuisance tripping and should be for Connectivity of the lie in operating range 80% to 110% of the Voltage Distributed Generation nominal connected voltage. Beyond a Resources) Regulations clearing time of 2 second, the photovoltaic 2013 system must isolate itself from the grid. CEA (Technical Standards Operation of Photovoltaic system should for Connectivity of the not cause voltage flicker in excess of the Flicker Distributed Generation limits stated in IEC 61000 standards or Resources) Regulations other equivalent Indian standards, if any. 2013 (indicated In Section C) When the Distribution system frequency CEA (Technical Standards deviates outside the specified conditions for Connectivity of the (50.5 Hz on upper side and 47.5 Hz on Frequency Distributed Generation Lower side), There should be Over and Resources) Regulations under frequency trip Functions with a 2013 clearing time of 0.2 seconds. CEA (Technical Standards for Photovoltaic system should not inject DC DC injection Connectivity of the current more than 0.5% of full rated output. Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 4 of 24 CES Department 12 13 14 15 16 17 18 19 20 21 Distributed Generation Resources) Regulations 2013 IEC 61727/ CEA (Technical Standards for Connectivity of the Distributed Generation Resources) Regulations 2013 CEA (Technical Standards for Connectivity of the Distributed Generation Resources) Regulations 2013 CEA (Technical Standards for Connectivity of the Distributed Generation Resources) Regulations 2013 CEA (Technical Standards for Connectivity of the Distributed Generation Resources) Regulations 2013 While the output of the inverter is greater than 50%,it should operate in the range of Power Factor 0.9 lag and lead (IEC)./ The inverter should dynamically operate in the range of 0.95 lag- to lead(CEA) The photovoltaic system in the event of Islanding and fault, voltage or frequency variation must Disconnection island/disconnect itself as per IEC standard in stipulated period. The inverter should have the facility to Overload and automatically switch off in case of Overheat overload or overheating and should restart when normal conditions are restored Paralleling device of photovoltaic system Paralleling shall be capable of withstanding 220% Of Device the normal voltage at the interconnection point. The total capacity of Solar Power connected to the distribution Transformer Capacity of should be below 40% of Utility transformer MERC regulation 2015 Plant capacity. Moreover, individual Solar Plant capacity should not exceed its customers approved contract demand Solar Capacity below 8KW can be injected at single phase. Moreover above 8kW and Connection MERC Regulation 2015 below 150kW it should be at three Phase Voltage Level clause 5.2 415 Volt. However above 150kW and below 1MW it should be at 415 V, while net meter will be installed at 11kV. The Reconnection of the Distributed CEA (Technical Standards for Generation to Grid in the event of Connectivity of the Reclosing disconnection prior, should happen only if Distributed Generation frequency and voltage are stable for atResources) Regulations 2013 least 1 minute. Capable of being Locked in open position, Manual Isolating May not be rated for Load Break nor may CEA (Technical Standards for Switch between have feature of over current protection. It Connectivity of the grid and should be reached quickly and Distributed Generation Distributed conveniently. Should be located at height Resources) Regulations 2013 generation of at least 2.44 meter above the ground level. CEA (Technical Standards for Inspection, test, Calibration and Connectivity of the Maintenance prior to connection shall be Test Certificate Distributed Generation done by applicant in consultation with the Resources) Regulations 2013 appropriate licensee is required. (clause 10) CEA (Technical Standards for The applicant shall prepare Single Line Schematic Connectivity of the Schematic Diagram in respect of its Diagrams Distributed Generation system facility and make the same Resources) Regulations 2013 available to the appropriate licensee Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 5 of 24 CES Department (clause 9) 22 Power Quality Measurement 23 Protection 24 Solar meter Location 25 Statutory Approval 26 Certification of Equipments 27 Voltage Standards DC current injection, Flicker and harmonic shall be done with calibrated meters before commissioning of the project and once a year in presence of parties concerned and indicative date shall be communicated. Circuit Breakers or other interrupting equipment shall be suitable for their indented application with the capability of CEA (Technical Standards for interrupting the maximum available fault Connectivity of the current. The DG (distributed generation) Distributed Generation and associated equipment shall be Resources) Regulations 2013 designed so that the failure of any single (clause 7.a,b) device or component shall not potentially compromise the safety and reliability of the system. The Net Meter and the Solar Generation Meter shall be installed at such locations in the premises of the Eligible Consumer as would enable easy access to the MERC Regulation 2015 Distribution Licensee for meter reading. clause 7.8, Annexure 3.2.3 Annexure-3 The Licensee shall specify the and 3.8.3 interface/inter-connection point and metering point. The uni-directional and bidirectional or pair of meters shall be fixed in separate meter boxes in the same proximity. The Eligible Consumer shall obtain any statutory approvals and clearances that may be required, such as from the MERC Regulation 2015 Electrical Inspector or the municipal or clause Annexure -3 .4 other authorities, before connecting the Roof-top Solar PV System to the distribution Network. The equipment connected to the Licensee’s Distribution System shall be compliant with relevant International (IEEE/IEC) or Indian Standards (BIS), as MERC Regulation 2015 the case may be, and the installation of clause Annexure-3.1 electrical equipment shall comply with the requirements specified by the Central Electricity Authority regarding safety and electricity supply. CEA (Technical Standards for Connectivity of the Distributed Generation Resources) Regulations 2013 (clause 8.2) Maharashtra Electricity Regulation Committee “Standards of Performance of Distribution Licensees”. The Grid voltage maximum limit is 250 Volt (i.e. 433 Volt) and ± 6% variation in voltage. Table 6: Grid Connectivity technical requirement Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 6 of 24 CES Department F. Equipment Features I. Solar PV modules and array 1. Crystalline PV modules type. 2. The mechanical structure to withstand gusts of wind / cyclonic wind up to 120km/hr. 3. The offered modules conform to the latest edition of any of the following IEC/ equivalent BIS Standards for PV module design qualification and type approval: - Crystalline Silicon Terrestrial PV Modules : IEC 61215/IS14286 4. PV modules also qualify Salt Mist Corrosion Testing as per IEC61701/IS61701. 5. PV modules used in solar power plants warranted for output wattage, which should not be less than 90% at the end of 10 years and 80% at the end of 25 years. II. Module mounting structure The PV modules will be mounted on fixed metallic structures of adequate strength and appropriate design, which can withstand load of modules and high wind velocities up to 120 km per hour. The support structure used in the power plants will be hot dip Galvanized Iron (G.I). Note: Point F.I and F.II are guidelines for Applicant, it is not RInfra requirement III. Power Conditioning Unit/Inverter 1. The Inverter shall have internal protection arrangement against any sustained fault in the feeder line and against lightning in the feeder line 2. The inverter shall have the required protection arrangements against earth leakage faults 3. DC lines shall have suitably rated isolators to allow safe start up and shut down of the system 4. Circuit breakers used in the DC lines must be rated suitably 5. The inverter shall preferably have provision for galvanic isolation. 6. Each solid state electronic device shall have to be protected to ensure long life of the inverter as well as smooth functioning of the inverter 7. The inverter shall include appropriate self protective and self diagnostic feature to protect itself and the PV array from damage in the event of inverter component failure or from parameters beyond the inverter’s safe operating range due to internal or external causes. 8. Maximum Power tracking facility should be present.. 9. Protection against I. Over current II. Sync loss III. Over temp. IV. DC bus over voltage. Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 7 of 24 CES Department V. Cooling Fan failure(If provided) VI. Grid Under/Over voltage and frequency 10. Dynamic Reactive Power Support to be present in inverter. 11. Integrated protection in the DC and three phase system. 12. Ground Fault and Arc protection should be there for DC (PV array). Moreover, insulation monitoring of PV array should be there. 13. AC and DC side disconnect switch / MCCB /ACB should be there for protection/isolation. 14. Power regulation in the event of thermal failure. 15. The Inverter should have functionally to limit the fault current contribution from the Distributed generation to its full load limit. The protection equipments should be designed to protect against system abnormality. IV. ACDB (LT Panel) 1. All outdoor devices/equipment to be IP65 as minimum V. DC & AC Switches 1. DC SIDE a. FUSE /MCB of suitable rating should be provided for array input b. The Input of the Inverter should have DC isolation switch. 2. AC SIDE a. MCB/MCCB /ACB of suitable rating shall be provided for connection and disconnection of Inverter & load. b. Isolating switches (No load Break) should be provided at incoming of the meter cabin. c. Isolating switches should be provided at the output of the inverter. d. The Phase and Earth fault protection embedded switches should be provided at output of the inverter and also in the meter cabins corresponding to solar circuit. VI. Cables and installation accessories The size of the cables between array interconnections, array to junction boxes, junction box to PCU, PCU to AC Distribution Box etc shall be so selected to keep the voltage drop and losses to the minimum. Permissible Wire Drop on DC side shall be <= 2% All cabling on the roof to be provided with suitable mechanical protection (i.e. cable trays with top cover or metal conduits). PVC conduits or pipes are not be used. To minimize the impact of the voltage rise variables such as inverter location, inverter output-circuit length and conductor size are to be selected accordingly. Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 8 of 24 CES Department VII. Earthing and lightning protection Earthing: The array structure of the PV yard shall be grounded properly using adequate number of earthing kits. All metal casing or shielding of the power plants shall be thoroughly grounded to ensure safety of the solar power plants. Lightning: The PV plants shall be provided with lightning & over voltage protection. Lightning protection to be as per Indian or relevant IEC standard. Surge Protection Device Type 1 and 2 to be provided for lightning and surge protection respectively. G. Preliminary Site Visit Check List As given in Annexure – 4 H. Pre-Commissioning Check List As given in Annexure - 5 I. I. Safety The equipment connected to the Licensee’s Distribution System shall be compliant with relevant International (IEEE/IEC) or Indian Standards (BIS), as the case may be, and the installation of electrical equipment shall comply with the requirements specified by the Central Electricity Authority regarding safety and electricity supply. II. The design, installation, maintenance and operation of the Roof-top Solar PV System shall be undertaken in a manner conducive to the safety of the Roof-top Solar PV System as well as the Licensee’s Network. III. If, at any time, the Licensee determines that the Eligible Consumer’s Roof-top Solar PV System is causing or may cause damage to and/or results in the Licensee’s other consumers or its assets, the Eligible Consumer shall disconnect the Roof-top Solar PV System from the distribution Network upon direction from the Licensee, and shall undertake corrective measures at his own expense prior to re-connection. IV. The Licensee shall not be responsible for any accident resulting in injury to human beings or animals or damage to property that may occur due to back- feeding from the Roof-top Solar PV System when the grid supply is off. The Licensee may disconnect the installation at any time in the event of such exigencies to prevent such accident. Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 9 of 24 CES Department V. The Isolating switches should be provided at output and the input of the Inverter. Moreover, protection switches as indicated in Annexure should have Phase and earth Fault Protection. VI. The Meter cabin and corresponding switchgear should be easily accessible. VII. The Body Earthing of each and every equipment should be followed as per standards. (Atleast at two separate points for each equipment viz. solar panel, inverter etc should be done from two separate connected earth pits). VIII. Standard shutdown procedure to be located close to the inverter. Each circuit switches should be indicated by the red colored signage (Aluminum plate). Fig 1: Standard Shutdown Procedure Near Inverter (Laminated Paper fixed to Wall- Font size 16 Arial) Note: All Signage should be engraved (red color letter and height 7mm) on Aluminum plate with rivet for fitting at relevant locations. Points I-IV Refer MERC Regulation -2015 Annexure-3 clause 3. 1. Date Of Commissioning 2. Contact Number responsible for O&M of Plant 3. Peak Plant Capacity (KW) 4. No of Inverters with each rating 5. Inverter AC voltage and current 6. Inverter DC input Voltage and current 7. Short Circuit current fed by Inverter during fault 8. No of PV Panels 9. No of Strings 10. No of PV Panel in each Strings 11. Voc of a PV Panel 12. Isc of a PV panel Fig 2: Specification on the Meter Cabin (Laminated Paper and Fixed in meter cabin-Font size 16 Arial) Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 10 of 24 CES Department CAUTION SOLAR ELECTRIC SYSTEM LOAD SWITCH SOLAR SWITCH NET SWITCH RINFRA SWITCH SOLAR METER NET METER Fig 3: Signage to be fitted near the components in the meter cabin INVERTER AC DISCONNECT SWITCH INVERTER DC DISCONNECT SWITCH Fig 4: Signage near Inverter Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 11 of 24 CES Department Annexure - 1 SLD are categorized accordingly to Generating capacity of PV(Photo Voltaic) plant and voltage level (Refer: MERC regulation clause 5.2). Case1:: Typical SLD of grid Connected Roof Top PV with capacity below 8kW – single-phase B DC A Solar meter Rinfra MCB/Fuse Grid Net Meter Solar Inverter Surge protection Load Load Fig A.1: Typical SLD of grid Connected Roof Top PV with capacity below 8kW 1. The solar circuit switch “B” should have provision for Phase and earth fault protection. 2. On DC input side and AC output side of the Inverter, should have isolation switch. 3. Rinfra MCB will be of same rating as per existing policy guidelines. 4. The Inverter AC side (as indicated in SLD) and DC side (after DC connector box but input of inverter) should have isolation switch. 5. If applicant needs to operate in islanded mode during grid failure. The provision should be made by the customer to automatically trip switch A (shown in SLD) to avoid flow of power in to the grid/utility. Otherwise, customer should make provision for manual isolation switch A. 6. The separate meter boxes should be there to accommodate solar meter and bidirectional meter. Moreover, both meters should be in close proximity. The Net Meter and the Solar Generation Meter shall be installed at such locations in the premises of the Eligible Consumer as would enable easy access to the Distribution Licensee for meter reading. 7. Rating of all switches viz inverter, consumer and switch A will be selected based upon rating/ capacity of load and generation. It shall be procured by customers only. 8. In case of multiple injections from single-phase DG connected to the same upstream DT, RInfra shall ensure that they are on alternate phases to prevent undue Voltage imbalance. Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 12 of 24 CES Department Annexure – 2 Case-2 :: Typical SLD for grid Connected Roof Top PV with capacity above 8kW and below 150kW – for Three-phase Solar Panel Inverter Switch Solar Inverter ACDB (AC Distribution Board) Isolating Transformer Star /Delta Switch B A Solar Meter DC fuse Inverter Rinfra Switch Net Meter Consumer ACDB Surge protection Load Switch Load Fig A.2: Typical SLD for grid Connected Roof Top PV with capacity above 8kW and below 150kW 1. Rinfra Switch should be as per our existing policy: 2. The Inverter AC side (as indicated in SLD) and DC side (after DC connector box but input of inverter) should have isolation switch. 3. The isolating Transformer (Galvanic Isolation) is advisable in case of load above 8KW solar generation. 9. If applicant needs to operate in islanded mode during grid failure. The provision should be made by the customer to automatically trip switch A (shown in SLD) to avoid flow of power in to the grid/utility. Otherwise, customer should make provision for manual isolation switch A. Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 13 of 24 CES Department 4. The size of the ACDB should be able to accommodate the switch A, and B (along with manual isolation switch, as per MERC Regulation). The ACDB should be provided by the applicant. 5. The Net Meter and the Solar Generation Meter shall be installed at such locations in the premises of the Eligible Consumer as would enable easy access to the Distribution Licensee for meter reading. Moreover they should be in separate boxes and in close proximity. 6. If Isolation transformer is not there, then corresponding solar side transformer switch may not be present. 7. Rating of all switches viz inverter, consumer and switch A will be selected based upon rating capacity of load and generation. Moreover, the inverter switch and switch A, B should have earth fault and phase protection i.e 50-50N and 51-51N relay. Note: 1. 50-50N Instantaneous Phase and earth fault relay 2. 51-51N Over current Phase and Earth fault relay. Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 14 of 24 CES Department Annexure – 3 Case 3:: Typical SLD grid Connected Roof Top PV with capacity above 150kW – Three-phase Inverter DC fuse Solar Panel Two winding Isolating 415/415 Volt Delta/Star ACB 50-50N and 51-51N ACB 50-50N and 51-51N Surge protection Solar meter ACDB ACB 50-50N and 5151N ACB 50-50N and 51-51N 0.415/11kV Star/Delta Load Net meter A Consumer 11kV Breaker 50-50N and 51-51N RInfra RMU Fig A.3:; Typical SLD grid Connected Roof Top PV with capacity above 150kW 1. Rinfra 11kV Switchgear should be as per our existing policy: 2. The Inverter AC (as indicated in SLD) and DC side (after DC connector box but input of inverter) should have isolation switch. 3. Inverter Main SFU/MCCB (switch B) should be in accordance with total capacity of Solar generation (i.e. it may be 110% of the full load rating of the inverter). The ACB should have with 50-50N and 51-51N protection relay. Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 15 of 24 CES Department 4. If applicant needs to operate in islanded mode during grid failure. The provision should be made by the customer to automatically trip switch A (shown in SLD) to avoid flow of power in to the grid/utility. 5. The Net Meter and the Solar Generation Meter shall be installed at such locations in the premises of the Eligible Consumer as would enable easy access to the Distribution Licensee for meter reading. Moreover they should be in separate boxes and in close proximity. Annexure – 4 Preliminary Site Survey Check List (after Application) Sr.No Description 1 Capacity of the proposed PV Plant Contract Demand (Sanctioned Load) of 2 Consumer Existing Network SLD details up to the Consumers Point of Supply and Last mile connectivity. The SLD should Indicate existing 3 protection equipment (Fuse Rating, Voltage, MCB/MCCB, ACB rating), cable size, transformer size and loading of equipments uptil Point of supply i.e. Upstream network Existing protection (MCB/Fuse/Breaker) details 4 and SLD after Meter – of Consumer AC Voltage Level at which connectivity is 5 sought Rated output AC Voltage of the proposed Solar 6 Plant (230,415 Volt). Available cumulative capacity of relevant DT 7 and substation Name Space availability/feasibility to commission new 8 Meter cabin /Panel accommodating Net meter, Solar Meter and Isolating switches. Consumer advised to ensure readiness of the meter cabin of adequate size to accommodate equipment as per relevant SLD along with work 9 completion report (Plant Setup Intimation). Moreover, intimation to furnish the documents prior to commissioning test. Y/N/Value Remarks Note: Preliminary Site Survey Activity to be done by Divisional Load remark and Business team Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 16 of 24 CES Department Annexure - 5 Commissioning Check List Sr. No 1 Description Y/N/Value Remarks New Meter Cabin of requisite dimensions ready Automation-compliant motorized Islanding Switch (A – as per concept SLD) is installed. 2 (In case Anti-islanding is not there or for Island operation with Battery or Diesel Generator is planned by applicant). Protection switch ‘B’ (as per SLD) installed is 3 having Phase & Earth Fault protection The switches are there as per SLD shown in 4 Annexure 1,2 and 3 5 Solar /Net Meter is installed Danger Board/Signage as Shown in Section I are 6 incorporated at suitable locations. 7 Voltage magnitude at point of connection with grid. 230V/420 V 8 Full Load output Power of Plant in KW AC and DC side manual isolating switches located 9 near inverter. Surge Protection (Type-II) device is installed on 10 AC/DC side of Inverter 11 Voltage magnitude at the output of inverter 230V/420V The DC/AC Ground Fault monitoring Feature in 12 Inverter Is Isolation Transformer (if applicable) installed -- to 13 avoid DC current injection, harmonic injection and protect inverter from grid disturbances. Under (80%) /Over (110%) Voltage and Under (47.5)/Over (50.5) frequency protection for 14 Islanding is inbuilt in Inverter with minimum clearing time 2 sec(for voltage) and 0.2 sec (for frequency) respectively (as per section C) Power Quality Norms viz. harmonic limits, flicker and DC current (refer Section C). The customer 15 should provide test report from the government/NABL accredited Labs. a TDD Harmonic level in (5%) b DC Injection (0.5 % of FLC) c Flicker – Interval / Value (Plt/Pst) Inverter should be configured to provide Dynamic Reactive support. The settings should be 0.95 16 Power factor (capacitive and inductive) (for 8KW to 150KW) and 0.90 power factor for (150 KW and above) according to grid voltage variation. 17 The reconnection time should be 1 minute The document indicating details of fault 18 contribution by inverter ( time, voltage and current magnitude in tabular form) 19 Anti-islanding feature available in inverter as tested Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 17 of 24 CES Department 20 21 22 21 22 23 24 IEC62116 or IEE1547 Is Earthing of Solar PV followed as per IS 3043 Is Lightning Protection provided If PV is Single Phase, whether load balancing is Y/N required to be done by RInfra. Has Customer provided single document to indicate single line drawing with protection details/ratings, Load Connectivity/Details, earthing details, Lightning protection, Inverter(protection features and make) and Solar PV panel details (ratings and connectivity). Undertaking by applicant for internal Power Quality check every year for the PV output above 150kW and every 2 years for less than 150 kW to 8kW. The Solar Installation approved by PWD Electrical Inspector. Responsibility matrix /ownership of Equipment Maintenance Undertaking furnished by the applicant. Note: 1. Points 11 to 19 are the inverter features likely to be present /configured. The documents indicating its presence should be submitted to Business team and verified by Load remark team. Moreover, its need should be communicated /explained to consumer during application itself. Furthermore, the compliance of documents indicating the details of inverter from point 11 to 19 should be checked /confirmed prior to commissioning visit. 2. Point’s 21, 22, 23 and 24 document compliance need to be checked/confirmed by Business team prior to commissioning visit. After Submission of Test report (harmonics, flicker, DC injection and reactive Support) by the Applicant to Businees team, RInfra Divisional Load remark team may check its validity by performing on site testing. 3. Commissioning Check Activity to be done by Divisional Load remark and Business team. 4. Applicant’s Power factor degradation may occur due to lowering Active power import from grid. (it needs to communicated to consumer) Annexure - 6 Dimensions of Equipments Sr.No 1 2 3 4 5 6 7 Description of Equipment Single phase meter Three Phase meter (in built CT) Single phase MCB Single Phase MCB with casing Neutral Link-63AMp Neutral Link-100AMp Single Phase with Neutral MCB Technical Guidelines for Grid Tied Distributed Generation (Solar) Height 140 200 100 130 100 140 100 Width 140 200 20 50 90 110 40 Depth 100 100 80 80 40 40 80 Page 18 of 24 CES Department 8 Three Phase MCB 100 60 80 9 Three Phase Neutral MCB 100 80 80 10 100 Amp Fuse unit 250 330 155 11 200 Amp Fuse unit 350 375 180 12 400 Amp Fuse unit 440 425 180 13 On load sitch Disconnector-400A 1000 400 275 14 630Amp SDF 1300 500 370 15 800Amp SDF 1300 500 370 16 63Amp SDF 400 250 200 17 100Amp SDF 400 350 250 18 200Amp SDF 750 350 260 19 400Amp SDF 850 400 275 20 800 Amp MCCB 400 300 150 21 1250 Amp MCCB 400 300 150 All dimensions in mm Note 1 Wire should be clipped at 50mm interval at regular interval 2 The Height of LT Incoming switchgear shall be 0.9 meters above the ground level. 3 Board wiring shall be carried out only on Fire retardant plywood of 19 mm thickness provided by the applicant. 4 Current capacity for 10sqmm wire is 51A and for 4sqmm is 29A as per IS:3961 5 Safety operating clearance from the wall on which meters are installed shall be 1.5m 6 LT Switchgear earthing to main GI strip by means of 25X3 GI flat at diagonally opposite ear thing bolts to be provided on FU / SDF 7 Single phase ELCB is twice the width of Single Phase MCB 8 Three phase ELCB size is same for Three phase and Neutral MCB Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 19 of 24 CES Department Annexure – 7 Sample Documents---- NEED NOT BE OF SAME FORMAT Documents 1, 2 and 3 should be Type test report or from NABL accredited lab report 1. Harmonics Report 2. Flicker 3. DC Current Injection 4. Fault current contribution Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 20 of 24 CES Department 5. Voltage and Frequency protection The Routine test report available from inverter manufacturer indicating protection features present in inverter. However, it should be configured as per CEA Guidelines 6. Routine Test report indicating Reconnection time settings, it has to be configured as per CEA Guidelines. 7. Reactive Support routine test report, it should be reconfigured as per CEA guidelines. At 240 volt (Nominal Voltage) to 245 Volt it should operate at unity power factor. However, grid voltage reduces, inverter should operate in leading power factor with linearly increasing trend up to 230 Volt, and then it becomes fixed with 0.95 lead (i.e. 30% capacitive). Similarly, for voltage range from 245 to 255 Volt the Inverter should absorb reactive power gradually with maximum power factor 0.95 (i.e. Inductive 30%). Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 21 of 24 CES Department 8. DC side ground fault monitoring feature in the inverter. It can confirm from datasheet of the inverter. Similar for AC side ground fault monitoring feature. 9. Sample Data Sheet of Inverter Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 22 of 24 CES Department 10. Detail drawing of Plant Setup Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 23 of 24 CES Department 1. 2. 3. 4. 5. 6. Voc =36 Volt Isc =8Amp Vdc =600 Volt Vac=415 volt I= 20 Amp Inverter output=20KW Manual Switch 100 Amp MCCB + 100 milliamp ELCB Technical Guidelines for Grid Tied Distributed Generation (Solar) Page 24 of 24