Emblem of the Government of Uttarakhand
रुड़की, शनिवार, दिनांक 31 दिसम्बर, 2016 ई0 (पौष 10, 1938 शक सम्वत्)
नियम, कार्य-विधियां, आज्ञाएं, विज्ञप्तियां इत्यादि जिनको उत्तराखण्ड के राज्यपाल महोदय, विभिन्न विभागों के अध्यक्ष तथा राजस्व परिषद् ने जारी किया
December 19, 2016
No. F-(9)14/RG/UERC/2016/1427— In exercise of the powers conferred by clause (zp) of Section 181 read with clause (h) of sub-section (1) of Section 86 of the Act (36 of 2003), the Uttarakhand Electricity Regulatory Commission hereby makes the following Regulations, namely:
(1) These Regulations shall apply to all parties that connect with and/or utilize the IaSTS or those, including SLDC, which are required to abide by the principles and procedures defined in the SGC in so far as they apply to that party. For Inter-State transmission of electricity the Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2010 as amended from time to time shall be applicable.
(2) Persons availing open access, who are connected to and/or use the laSTS, shall comply with UERC (Terms and Conditions of Intra-State Open Access) Regulations, 2015 as amended from time to time.
The SGC brings together a single set of technical and commercial rules, encompassing all the Utilities connected to/or using the intra-State transmission system (laSTS) and provides the following:--
(1) In these Regulations, unless the context otherwise requires:
(n) "Congestion" means a situation where the demand for transmission capacity exceed the Available Transfer Capability;
(o) "Connection Agreement" means an agreement setting out the terms relating to connection to and/or use of the intra-State transmission system;
(p) "Connection Point" means a point at which a User's or Transmission Licensee's Plant and/or Apparatus connects to the intra-State transmission system;
(q) "Connectivity" means the state of getting connected to the Inter-State/Intra state transmission system by a generating station, including a captive generating plant, distribution licensee, a bulk consumer or an inter-State/intra-state transmission licensee;
(r) "Constituent" means a Distribution Licensee or Deemed Distribution Licensee of the State, a Generating Company having an IaSGS, State Transmission Utility, State Transmission Licensees, Open Access Users;
(s) "Control Area" means an electrical system bounded by interconnections (tie lines), metering and telemetry which controls its generation and/or load to maintain its interchange schedule with other control areas whenever required to do so and contributes to frequency regulation of the synchronously operating system;
(t) "Deviation Settlement Mechanism Regulations" means Central Electricity Regulatory Commission (Deviation Settlement Mechanism and related matters) Regulations, 2014 including any subsequent amendments, and/or UERC (Deviation Settlement Mechanism and related matters) Regulations, 2016 (as and when notified by the Commission) whichever is applicable;
(u) "Demand" means the demand of Active Power in MW and Reactive Power in MVar of electricity unless otherwise specified;
(v) "Demand response" means reduction in electricity usage by end customers from their normal consumption pattern, manually or automatically, in response to high deviation charges being incurred by the State due to overdrawal by the State at low frequency, or in response to congestion charges being incurred by the State for creating transmission congestion, or for alleviating a system contingency, for which such consumers could be given a financial incentive or lower tariff;
(w) 'df/dt Relay' means a relay which operates when the rate of change of system frequency (over time) goes higher than a specified limit and initiates load shedding;
(x) "Despatch Schedule" means the ex-power plant net MW and MWh output of a generating station, scheduled to be exported to the Grid from time to time;
(y) "Disturbance Recorder (DR)" means a device provided to record the behavior of the pre-selected digital and analog values of the system parameters during an Event;
(z) "Data Acquisition System (DAS)" means a system provided to record the sequence of operation in time, of the relays/equipments as well as the measurement of pre-selected system parameters;
(aa) "Drawal Schedule" means the ex-power plant, MW that a Distribution Licensee or Open Access User is scheduled to receive from the IaSGS or ISGS, including bilateral exchanges from time to time;
(bb) "Entitlement" means a Share of a beneficiary (in MW / MWh) in the installed capacity/ output capability of an ISGS;
(cc) "Event" means an unscheduled or unplanned occurrence in the intra-State transmission system including faults, incidents and breakdowns;
(dd) "Event Logger" means a device provided to record the sequence of operation in time, of the relays/ equipments at a location during an Event;
(ee) "Ex-Power Plant" means net MW/MWh output of a generating station, after deducting auxiliary consumption and transformation losses;
(ff) "Fault Locator (FL)" means a device provided at the end of a transmission line to measure/ indicate the distance at which a line fault may have occurred;
(gg) "Flexible Alternating Current Transmission (FACT)" means facilities that enable power flows on A.C. lines to be regulated, to control loop flows, line loading etc.;
(hh) "Force Majeure" means any event which is beyond the control of the persons involved which they could not foresee or with a reasonable amount of diligence could not have foreseen or which could not be prevented and which substantially affects the performance by person such being the following including but not limited to :
(ii) "Forced Outage" means an outage of a Generating Unit or a transmission facility due to a fault or other reasons which has not been planned;
(jj) "Generating Company" means any company or body corporate or association or body of individuals, whether incorporated or not, or artificial juridical person, which owns or operates or maintains a generating station;
(kk) "Generating Unit" means an electrical Generating Unit coupled to a turbine within a Power Station together with all Plant and Apparatus at that Power Station which relates exclusively to the operation of that turbo-generator;
(ll) "Good Utility Practices" means any of the practices, methods and acts engaged in or approved by a significant portion of the electric utility industry during the relevant time period which could have been expected to accomplish the desired results at a reasonable cost consistent with good business practices, reliably, safely and with expedition;
(mm) "Governor Droop" means in relation to the operation of the governor of a Generating Unit, the percentage drop in system frequency which would cause the Generating Unit under restricted/free governor action to change its output from zero to full load;
(nn) "Grid Disturbance" means the tripping of one or more power system elements of the grid like a generator, transmission line, transformer, shunt reactor, series capacitor and Static VAR Compensator, resulting in total failure of supply at a sub-station or loss of integrity of the grid, at the level of transmission system at 220 kV and above (132 kV and above in the case of North-Eastern Region);
(oo) "Grid Standards" means the Central Electricity Authority (Grid Standards) Regulations, 2010 as amended from time to time;
(pp) "Extra High Voltage(EHV)" means where the voltage exceeds 33,000 volts under normal conditions, subject, however, to the percentage variation allowed by the CEA;
(qq) "Independent Power Producer (IPP)" means a generating company not owned/ controlled by the Central/State Government;
(rr) "Inter-State Generating Station (ISGS)" means a Central/other generating station in which two or more states have shares and whose scheduling is to be coordinated by the RLDC;
(ss) "Intra-State Generating Station (laSGS)" means a State/other generating station which is connected to/utilises laSTS and whose scheduling is to be coordinated by the SLDC;
(tt) "Inter State Transmission System (ISTS)" means
(uu) "Intra-State Transmission System (laSTS)" means any system for transmission of electricity other than an inter-State transmission system and includes:
Provided that the definition of point of separation between a transmission system and distribution system and between a Generating Station and transmission system shall be guided by the provision of the Regulations notified by the CEA under clause (b) of Section 73 of the Act;
(vv) "Licensee" means a person who has been granted a license under Section 14 of the Act;
(ww) "Load" means the MW/MWh /MVAR/MVARh consumed by a utility/ installation;
(xx) "Long –term Access" means the right to use the inter and/ or intra-State transmission system for a period exceeding 12 years but not exceeding 25 years;
(yy) "Maximum Continuous Rating (MCR)" means the maximum continuous output in MW at the generator terminals guaranteed by the manufacturer at rated parameters;
(zz) "Medium-term Open Access" means the right to use the inter and/or intra- State transmission system for a period exceeding 3 months but not exceeding 3 years:
(ddd) "Open Access Customer" means a consumer, trader, distribution licensee or a generating company who has been granted open access under the UERC (terms and conditions of intra state open access) Regulations, 2015 amended from time to time;
(eee) "Operating Range" means the operating range of frequency and voltage as specified under the operating code (Chapter-6);
(fff) "Planned Outage" means an outage in relation to a laSGS unit for Power Station Equipment or Transmission facility which has been planned and agreed with SLDC, in advance in respect of the year in which it is to be taken.
(ggg) "Power Exchange" means the power exchange which has been granted registration in accordance with CERC (Power Market Regulations), 2010 as amended from time to time;
(hhh) "Power System" means all aspects of generation, transmission, distribution and supply of electricity and includes one or more of the following, namely:
(iii) "Reactor" means an electrical facility specifically designed to absorb Reactive Power;
(jjj) "Regional Power Committee (RPC)" means a Committee established by resolution by the Central Government for a specific region for facilitating the integrated operation of the power systems in that region;
(kkk) "RPC Secretariat" means the Secretariat of the RPC;
(lll) "Regional Grid" means the entire synchronously connected electric power network of the concerned Region;
(mmm) "Regional Load Despatch Centre (RLDC)" means the Centre established under sub-section (1) of Section 27 of the Act;
(nnn) "Share" means percentage share of a beneficiary in a generating station as notified by Appropriate Government or as agreed to in the agreement between the generating stations or trading/distribution licensees and their beneficiaries;
(ooo) "Short-term Open Access" means open access for a period up to one (1) month at one time;
(ppp) "State Energy Account (SEA)" means a State energy account prepared on monthly basis by the SLDC for the billing and settlement of 'Capacity Charge', 'Energy Charge', 'Deviation charge' and 'Reactive energy charge';
(qqq) "State Grid Code (SGC) or Grid Code" means these Regulations specifying the philosophy and the responsibilities for planning and operation of State power system;
(rrr) "State Pool Account" means State account for (i) payments regarding Deviation (State Deviation Pool Account) or (ii) reactive energy exchanges (State Reactive Energy Pool Account), as the case may be;
(sss) "Spinning Reserve" means part loaded generating capacity with some reserve margin that is synchronized to the system and is ready to provide increased generation at short notice pursuant to despatch instruction or instantaneously in response to a frequency drop;
(ttt) "Single Line Diagram" means diagrams which are a schematic representation of the HV/EHV apparatus and the connections to all external circuits at a Connection Point incorporating its numbering nomenclature and labeling;
(uuu) "Site Common Drawing" means drawings prepared for each Connection Point, which incorporates layout drawings, electrical layout drawings, common protection/control drawings and common service drawings;
(ww) "State Load Despatch Centre (SLDC)" means the Centre established under sub-section (1) of Section 31 of the Act;
(www) "State Transmission Utility (STU)" means the Board or the Government Company specified as such by the State Government under sub-section (1) of Section 39 of the Act;
(xxx) "Static VAR Compensator (SVC)" means an electrical facility designed for the purpose of generating or absorbing Reactive Power;
(yyy) "Time Block" means block of 15 minutes each for which Special Energy Meters record values of specified electrical parameters with first time block starting at 00.00 Hrs;
(zzz) "Total Transfer Capability (TTC)" means the amount of electric power that can be transferred reliably over the inter-control area transmission system under a given set of operating conditions considering the effect of occurrence of the worst credible contingency;
(aaaa) "Transmission License" means a License granted under Section 14 of the Act to transmit electricity;
(bbbb) "Transmission Planning Criteria" means the policy, standards and guidelines issued by the CEA for the planning and design of the Transmission system;
(cccc) "User" means a person such as a Generating Company including Captive Generating Plant or Transmission Licensee (other than State Transmission utility) or Distribution Licensee or Open Access Customers;
Words and expressions used in these Regulations and not defined, but defined in the Act or the other Regulations issued by the Commission shall have the same meaning assigned to them respectively in the Act or such Regulations issued by the Commission.
This SGC contains the following:
This Chapter largely deals with scope, objective and definitions.
This Chapter largely deals with compliance and procedure for review & Revision of SGC.
This chapter defines the functions of the various organizations as are relevant to SGC.
This Chapter provides the policy to be adopted in the planning and development of bulk power transfer and associated IaSTS. The Planning Code lays out the detailed information exchange required between the planning agencies and the various participants of the power system for load forecasting, generation availability and power system planning etc. for the future years under study. The Planning Code stipulates the various criteria to be adopted during the planning process.
This Chapter specifies minimum technical and design criteria to be complied with by any agency, connected to the system or seeking connection to the IaSTS, to maintain uniformity and quality across the system. This includes:
This Chapter describes the operational philosophy to maintain efficient, secure and reliable Grid Operation and contains the following parts:--
This part describes the general security aspects to be followed by generating companies and all State Constituents of the Grid.
This part details the procedures to estimate the demand by the various constituents for their systems for the day/week/month/year ahead, which shall be used for operational planning.
This part identifies the methodology to be adopted for demand control by each State constituent as a function of the frequency and deficit generation.
This part provides various provisions for reporting of the operating parameters of the State Grid such as frequency profile, voltage profile etc.
This part sets out the requirement for the exchange of information in relation to normal operation and/or events in the State Grid.
This part indicates procedure for outage planning.
This part contains the procedures to be adopted following a major grid disturbance, for black start and resynchronization of islands, etc.
This part indicates the procedure by which events are reported and the information exchange etc. takes place.
This part deals with the procedure to be adopted for scheduling and despatch of generation of the State Generating Stations (SGS) including complementary commercial mechanisms, on a daily basis with the modality of the flow of information between the laSGS, other Users and the State Load Despatch Centre (SLDC).
Metering Code provides for development of minimum requirements and standards for installation and operation of meters, for commercial and operational purposes, to be provided by user or transmission licensee at the Connection Point.
This chapter specifies the requirements for safe working practices for maintenance of equipment associated with cross boundary operations and lays down the procedure to be followed when the work is carried out on electrical equipment connected to another User's System.
This Chapter deals with the procedure for review/amendment and management of SGC
The State Grid Code (SGC) lays down the rules, guidelines and standards to be followed by various agencies and participants in the intra-State transmission system (IaSTS) to plan, develop, maintain and operate the intra-State transmission system, a part of Northern Region Grid System, in most efficient, reliable, economic and secure manner, while facilitating a healthy competition in the generation and supply of electricity.
Provided that the State Transmission Utility shall not unduly discriminate against or unduly prefer any User or Transmission Licensee.
Provided that the State Load Despatch Centre shall not unduly discriminate against or unduly prefer any User or Transmission Licensee.
Provided that till such time the Commission decides the matter, the direction of the State Load Despatch Centre shall be complied with by the Transmission Licensee or User.
This Chapter defines the management of grid code and role & functions of the various organizations involved in the field of grid operation and management and their organizational linkages so as to facilitate development and smooth operation of State Grid in harmony with Regional and National Grid.
The Government of Uttarakhand, in exercise of powers conferred by sub-section (1) of Section 39 of the Act notified Power Transmission Corporation of Uttarakhand Limited (PTCUL) as the State Transmission Utility (STU) with effect from 01.06.2004 as per GoU Notification No. 85/1/2004-06(3)/259/2003 dated 31.05.2004. Accordingly, PTCUL undertakes transmission activities and business as STU.
3.2.1 As per sub-section (2) of Section 39 of the Act following are the functions of the State Transmission Utility :
3.2.2 Until a government company or any authority or corporation is notified by the State Government, the State Transmission Utility shall operate the State Load Despatch Centre as per Section 31 of the Act.
Provided that in event of State Load Despatch Centre being operated by the State Transmission Utility, as per first proviso of sub-section (2) of Section 31 of the Act adequate autonomy shall be provided to the State Load Despatch Centre for it to be able to discharge its functions in the above mentioned manner.
3.2.3 The STU shall comply with the responsibilities specified in sub-Regulation (1) of Regulation 2.2 of these Regulations.
3.3.6 In case of inter-state bilateral and collective short-term open-access transactions having a State utility or an intra-state entity as a buyer or seller, SLDC shall accord concurrence or no objection or a prior standing clearance, as the case may be, in accordance with the CERC (Open Access in inter-state Transmission) Regulations, 2008 and UERC (Terms & Conditions of Intra-State Open Access) Regulations, 2015 amended from time to time.
3.3.7 Procedures to be developed by State Load Despatch Centre
Procedures and processes developed by State Load Despatch Centre, in discharge of its functions under the provisions of these Regulations, shall clearly provide for the following aspects, wherever applicable:
Provided that such procedures shall be developed in consultation with State Constituents and shall be consistent with SGC to enable compliance with the requirement of this SGC.
Provided further that such procedures shall be submitted, within three (3) months of notification of these Regulations, to the Commission for approval.
3.3.8 The SLDC shall comply with the responsibilities specified in sub-Regulations (2), (4) & (5) of Regulation 2.2 of these Regulations.
3.3.9 SLDC shall prepare document "Procedures for Data/Information exchange with Constituents" and submit the same before the Commission for its approval within 3 months of the notification of Regulations.
The Area Load Despatch Centre (ALDC) shall be a subsidiary of SLDC operating within the State in particular area having main functions:-
(1) The Grid Coordination Committee (GCC) shall be responsible for the following matters, namely:
(f) the intra-State transmission proposals including system strengthening scheme identified on the basis of the planning studies would be discussed, reviewed and finalized in the meetings of Grid Co-ordination Committee. While reviewing the same, GCC shall also take into consideration the report of long term load forecast submitted by distribution licensees for their respective licence areas.
(g) such other matters as may be directed by the Commission from time to time.
(2) The GCC shall comprise of the following members:
Provided that the member from State Transmission Utility shall be the Chairperson of the Committee.
Provided that the Member from State Load Despatch Centre shall be the Convener of the Grid Coordination Committee.
Provided further that the State Transmission Utility shall, in coordination with State Load Despatch Centre, facilitate and manage the functioning of the Grid Coordination Committee.
Provided that the members nominated by each of the organization to the above Committee shall be holding a senior position in their respective organization.
This Chapter comprises various aspects of Planning relating to Intra-State transmission systems.
The Planning Code specifies the policy and procedures to be applied in planning of State Grid and Inter-State links.
The objectives of Planning Code are as follows:
The Planning Code applies to STU, other State Transmission licensees, Intra-State Generating Station (IaSGS), connected to and/or using and involved in developing the IaSTS. This Planning Code also applies to Generating Companies, IPPs, Open Access Users and other licensees, regarding generation and/or transmission of energy to/from the IaSTS.
(1) CEA would formulate perspective transmission plan for inter-State transmission system as well as intra-State transmission system. These perspective transmission plans would be continuously updated to take care of the revisions in load projections and generation scenarios considering the seasonal and the time of the day variations. In formulating perspective transmission plan the transmission requirement for evacuating power from renewable energy sources shall also be taken care of. The transmission system required for open access shall also be taken into account in accordance with National Electricity Policy so that congestion in system operation is minimized.
(2) The STU shall carry out planning process from time to time as per the requirement for identification of intra-State transmission system including transmission system associated with Generation Projects and inter-state transmission system strengthening schemes which shall fit in with the perspective plan developed by CEA. While planning schemes, the following shall be considered in addition to the data of authenticated nature collected from and in consultation with Users by STU:
(3) In addition to the intra-state transmission system, the STU shall plan, from time to time, system strengthening schemes, need of which may arise to overcome the constraints in power transfer and to improve the overall performance of the grid. The intra-State transmission proposals including system strengthening scheme identified on the basis of the planning studies would be discussed, reviewed and finalized in the meetings of Grid Co-ordination Committee.
(4) Based on above, the STU shall come out with a Transmission System Plan, the format of which can be decided by the State Transmission Utility.
(5) The transmission system plan shall describe the plan for the IaSTS and shall include the proposed intra-State transmission schemes and system strengthening schemes for the benefit of all Users. The transmission system plan shall include information related intra-State transmission lines, additional equipment including transformers, capacitors, reactors, Static VAR Compensators and Flexible Alternating Current Transmission Systems. Further, the transmission system plan shall also include information on targets set in the preceding plans and progress achieved on the identified intra-State/inter-State transmission schemes and system strengthening schemes.
(6) As voltage management plays an important role in transmission of energy, special attention shall be given by STU for planning of capacitors, reactors, SVC and FACTs etc. to optimize the use of the integrated transmission network.
(7) The State Transmission Utility may, for the purpose of preparing the transmission system plan under these Regulations, seek such information as may be required by it from State Constituents, including generation capacity addition, system augmentation and long-term load forecast and all (approved/pending) applications for open access.
Provided that the Distribution Licensees shall have the primary responsibility for developing long term load forecasts for their respective license areas. The provisions related to load forecasting as provided in the Distribution Code shall be applicable.
Provided also that the State Transmission Utility shall consider, but not be bound by, the information provided under this Regulation in preparing the transmission system plan.
(1) The planning criteria shall be based on the security philosophy on which the laSTS has been planned. The security philosophy may be as per the Transmission Planning Criteria and other guidelines as given by the CEA. Provided that State Transmission Utility shall carry out appropriate system studies while developing the transmission system plan.
(2) The laSTS, as a general rule, shall be capable of withstanding and be secured against the following contingency outages without necessitating load shedding or rescheduling of generation during Steady State Operation:
Outage of a 132kV S /C line or,
(3) The laSTS, as a general rule, shall be capable of withstanding and be secured against the following contingency outages without necessitating load shedding but could be with rescheduling of generation during steady state operation:
Outage of a 400 kV S/C line with TCSC or,
(4) The above contingencies shall be considered assuming a pre-contingency system depletion (Planned outage) of another 132kV D/C, 220 kV D/C line or 400 kV S/C line in another corridor and not emanating from the same substation. The planning study would assume that all the Generating Units operate within their reactive capability curves and the network voltage profile are also maintained within voltage limits specified.
(5) All the Generating Units may operate within their reactive capability curves and the network voltage profile shall be maintained within voltage limits specified.
(6) The intra-State transmission system shall be capable of withstanding the loss of most severe single infeed without loss of stability.
(7) Any one of the events defined above shall not cause:
(8) In all substations (132 kV and above), atleast two transformers shall be provided.
(9) State Transmission Utility shall carry out planning studies for Reactive Power compensation of laSTS including reactive power compensation requirement at the existing generators switchyard and for connectivity of new generators to the intra-state transmission system.
(10) The maximum permissible thermal line loadings for different types of line configurations, employing various types of conductors shall be considered according to the Table II, Annexure-V of CEA Manual on Transmission Planning Criteria, 2013 as amended from time to time.
The actual program of implementation of transmission lines, Inter-connecting Transformers, reactors/capacitors and other transmission elements will be determined by STU in consultation with the concerned agencies. The completion of these works, in the required time frame, shall be ensured by STU through the concerned agency.
STU, Transmission Licensees & Users shall comply with CEA (technical Standards for connectivity to the Grid) Regulations, 2007 and open access customers shall also comply with UERC (Terms and Conditions of the Intra-State Open Access) Regulations, 2015 as amended from time to time for connectivity to the Grid.
The Connection Code specifies the minimum technical and design criteria which shall be complied with by STU and any User/Transmission Licensee connected to, or seeking connection to laSTS. They also set out the procedures by which STU shall ensure compliance by any agency with the above criteria as pre-requisite for the establishment of an agreed connection.
The Connection code applies to all State Constituents (STU, laSGS etc.) and any other agency/licensees connected to and involved in developing the laSTS. This Connection Code also applies to all agencies, which are planning to generate/transmit and/or are generating/transmitting energy to/from laSTS. Such entities shall abide by the CEA (Technical Standards for connectivity to the Grid) Regulations, 2007, as amended from time to time, in order to ensure that the integrated grid is not adversely affected.
The applicable technical standards for construction of electrical plants, electric lines and connectivity to the laSTS shall be as per CEA (Technical Standards for Construction of Electrical Plants & Electric Lines) Regulation, 2010 and CEA (Technical Standards for Connectivity to the Grid) Regulation, 2007 amended from time to time.
The applicable safety requirements for construction, operation and maintenance of electrical plants and electric lines shall be as per the CEA (Safety Requirements for construction, operation and maintenance of electrical plants and electric lines) Regulations, 2011 and CEA (Measures Relating to Safety and Electric Supply) Regulations, 2010 and amendments from time to time shall also be applicable.
(1) Prior to an agency being connected to the laSTS, all necessary conditions outlined in the SGC, in addition to other mutually agreed requirements to be complied with, must be fulfilled by the agency.
(2) Application for establishing new arrangement or modifying existing arrangement of connection to and/or use of the laSTS shall be submitted by the concerned Transmission Licensee or User to the State Transmission Utility. In case of consumer connecting/connected to laSTS/ distribution licensee network the application shall be submitted to the Distribution licensee who inturn shall coordinate with the STU in accordance with UERC (Release of new HT & EHT Connections, Enhancement and Reduction of Loads) Regulations, 2008 amended from time to time.
Provided that for Generating Units embedded in the Distribution systems, and not connected to the laSTS, shall be finalized by the respective Distribution Licensees in accordance with applicable Regulation of UERC Tariff and Other Terms for Supply of Electricity from Renewable Energy Sources and non-fossil fuel based Co-generating Stations Regulations, 2013 amended from time to time.
Provided further, that the standard format for application shall be developed by State Transmission Utility and shall be made available at its website within two (2) months of notification of these Regulations.
(3) The application mentioned in sub-Regulation (2) of this Regulation shall be submitted along with the following details:--
Report stating the purpose of the proposed connection and/or modification, transmission licensee to whose system connection is proposed, connection point, description of apparatus to be connected or modification of the apparatus already connected and beneficiaries of the proposed connection;
(4) The State Transmission Utility shall forward a copy of the application to the Transmission Licensee in whose system the connection is being sought, to State Load Despatch Centre and to every Transmission Licensee within the State whose Transmission System is likely to be affected by such application.
(5) The State Transmission Utility or Transmission Licensee, in whose system the connection is being sought, shall carry out the power system studies as considered appropriate before allowing any new connection.
(6) The State Transmission Utility shall, within Thirty (30) days, from the receipt of an application under sub-Regulation (2) of this Regulation and after considering all suggestions and comments received from the parties identified under sub-Regulation (4) of this Regulation:
Accept the application with such modification or such conditions as may be specified by the State Transmission Utility;
(7) In case of acceptance of an application as per clause (a) of sub-Regulation (6) of this Regulation, the State Transmission Utility shall make a formal offer to the applicant.
Provide that the State Transmission Utility shall forward a copy of the offer to the appropriate Transmission Licensee.
(8) The voltage level at which the applicant is offered to be connected to the laSTS shall be governed by the standards notified by the CEA and prevailing guidelines adopted by the State Transmission Utility.
(9) The State Transmission Utility shall, upon compliance of the required conditions by the concerned Transmission Licensee/User, shall notify the concerned Transmission Licensee/User that it can be connected to the laSTS.
(10) The applicant and the Appropriate Transmission Licensee, in whose system the connection is being sought, shall finalise a Connection Agreement on acceptance of the offer by the applicant.
Provided that the State Transmission Utility shall be provided with a copy of the Connection Agreement by the Appropriate Transmission Licensee:
Provided further the State Load Despatch Centre shall also be provided with a copy of the above mentioned Connection Agreement by the Appropriate Transmission Licensee.
Provided that all Users or Transmission Licensees connected to laSTS shall provide protection systems as specified in the Connection Agreement.
Reliable and efficient speech and data communication systems shall be provided to facilitate necessary communication and data exchange, and supervision/control of the grid by the SLDC, under normal and abnormal conditions. All agencies shall provide Systems to telemeter power system parameter such as flow, voltage and status of switches/ transformer taps etc. in line with interface requirements and other guideline made available to SLDC. The associated communication system to facilitate data flow up to SLDC, as the case may be, shall also be established by the concerned agency as specified by STU in connection agreement. All agencies in coordination with STU shall provide the required facilities at their respective ends and SLDC as specified in the Connection Agreement.
Transmission Licensees and the Users shall be responsible for safety as indicated in Site Responsibility Schedules for each connection point.
Provided that the State Transmission Utility shall put up the information related to above mentioned format, principles and procedures on its Website.
Provided that the Transmission licensee shall also furnish the above information to the SLDC.
Necessary details shall be provided by the agencies to STU.
All utilities shall have in place, a cyber security framework to identify the critical cyber assets and protect them so as to support reliable operation of the Grid.
The procedure for international Connection to IaSTS and the execution of agreement for the same shall be done by STU in consultation with CEA and Ministry of Power (MOP).
STU shall submit annually to the Commission by 30th September a schedule of transmission assets, which constitute the State Grid as on 31st March of that year indicating ownership on which SLDC has operational control and responsibility.
The primary objective of integrated operation of the State Grid is to enhance the overall operational economy and reliability of the entire electric power network spread over the geographical area of the entire State.
Provided that such procedures shall be specified in consultation with State Constituents and shall be consistent with the provisions included in this Chapter to enable compliance with the requirement of these Regulations.
Provided further that such procedures shall be submitted to the Commission for approval within three (3) months from the date of notification of these Regulations.
(1) All State Constituents shall endeavor to operate their respective power systems and power stations in synchronism with each other at all times, such that the entire system within the State operates as one synchronized system.
(2) No part of the State Grid shall be deliberately isolated from the rest of the State Grid, except (i) under an emergency and conditions in which such isolation would prevent a total grid collapse and/or would enable early restoration of power supply, (ii) for safety of human life (iii) when serious damage to a costly equipment is imminent and such isolation would prevent it and (iv) when such isolation is specifically instructed by SLDC. Complete synchronization of grid shall be restored as soon as the conditions again permit it. The restoration process shall be supervised by SLDC, in coordination with RLDC, as per operating procedures separately formulated by SLDC.
(3) No important element of the State Grid shall be deliberately opened or removed from service at any time, except when specifically instructed by SLDC or with specific and prior clearance of SLDC. The list of such important grid elements on which the above stipulations apply shall be prepared by the SLDC in consultation with the constituents and be available at SLDC. In case of opening/removal of any important element of the grid under an emergency situation, the same shall be communicated to SLDC at the earliest possible time after the event.
(4) Any tripping, whether manual or automatic, of any of the above elements of State Grid shall be precisely intimated by the concerned ALDC/agency to SLDC as soon as possible, say within ten minutes of the event. The reason (to the extent determined) and the likely time of restoration shall also be intimated. All reasonable attempts shall be made for the elements' restoration as soon as possible. SLDC shall inform the tripping of the important elements of the State Grid, to RLDC.
(5) Maintenance of their respective power system elements shall be carried out by Users, STUs in accordance with the provisions in CEA (Grid Standards) Regulations, 2010. Any prolonged outage of power system elements of any User/STU, which is causing or likely to cause danger to the State Grid or sub-optimal operation of the State Grid, shall regularly be monitored by SLDC. SLDC shall report such outages to RLDC.
(6) All thermal generating units of 200 MW and above and all hydro units of 10 MW and above (except those with upto 3 hours pondage), which are synchronized with the Grid, irrespective of their ownership, shall have their governors under restricted mode of operation at all times. The restricted governor mode of operation shall have the following features:
Provided that if the above generating unit cannot be operated under restricted governor mode operation, then it shall be operated in free governor mode operation with manual intervention to operate in the manner required under restricted governor mode operation.
Provided further that if the above generating unit is required to be operated without its governor in normal operation as above the SLDC shall be immediately advised about the reason and duration of such operation.
(9) Facilities available with/in load limiters, Automatic Turbine Run-up System (ATRS), Turbine supervisory control, coordinated control system, etc., shall not be used to suppress the normal governor action in any manner. No dead bands and/or time delays shall be deliberately introduced.
(10) All thermal Generating Units of 200 MW and above and all hydro units of 10 MW and above, operating at or up to 100% of their Maximum Continuous Rating (MCR) shall normally be capable of (and shall not in any way be prevented from) instantaneously picking up to 105% and 110% of their MCR, respectively, when frequency falls suddenly. After an increase in generation as above, a Generating Unit may ramp back to the original level at a rate of about one percent (1%) per minute, in case continued operation at the increased level is not sustainable. Any Generating Unit not complying with the above requirements shall be kept in operation (synchronized with the State grid) only after obtaining the permission of SLDC and SLDC while giving such permission shall consider the type/age of plant, hydro condition, discharge availability etc. However, SLDC can make up the corresponding short fall in spinning reserve by maintaining an extra spinning reserve on the other Generating Units of the State.
(11) The recommended rate for changing the governor setting, i.e., supplementary control for increasing or decreasing the output (generation level) for all generating units, irrespective of their type and size, would be one (1.0) per cent per minute or as per manufacturer's limits.
(12) Except under an emergency or to prevent an imminent damage to a costly equipment, no constituent shall suddenly reduce his generating unit output / injection by more than 30MW without prior intimation to and consent of the SLDC. Similarly, no User shall cause a sudden variation in its drawl by more than 30MW without prior intimation to and consent of the SLDC. All State constituents shall ensure that temporary over voltage due to sudden load rejection and the maximum permissible values of voltage unbalance shall remain within limits specified under CEA (Grid standards) Regulations, 2010.
(13) All generating units shall normally have their automatic voltage regulators (AVRs) in operation, with appropriate settings. In particular, if a generating unit of thirty (30) MW and above size is required to be operated without its AVR in service, the SLDC shall be immediately intimated about the reason and duration, and its permission obtained. Power System Stabilizers (PSS) in AVRs of generating units (wherever provided), shall be got properly tuned by the respective generating unit owner as per a plan prepared for the purpose by the STU from time to time. STU will be allowed to carry out checking of PSS and further tuning it, wherever considered necessary.
(14) Provision of protections and relay settings shall be coordinated periodically throughout the State grid, by Grid Coordination Committee assisted by the STU in accordance with the plan separately finalized by the protection sub-committee of the RPC from the time to time. All State constituents shall ensure that installation and operation of protection system shall comply with the provisions of CEA (Grid Standards) Regulations, 2010 amended from time to time.
(15) All State constituents shall take all possible efforts to ensure that the grid frequency always remains within the 49.90 – 50.05 Hz band.
(16) Users and Transmission Licensees shall provide automatic under-frequency and df/dt relay-based load shedding/islanding schemes in their respective systems, wherever applicable, to arrest frequency decline that could result in a collapse/disintegration of the State grid, as per the plan separately finalized by the RPC and shall ensure its effective application to prevent cascade tripping of generating units in case of any contingency. Users and Transmission Licensees shall ensure that the under-frequency and df/dt relay-based load shedding/islanding schemes, are always functional.
The provisions regarding under frequency and df/dt relays of CEA (Grid Standards) Regulations, 2010 amended from time to time shall be complied.
(17) State Transmission Utility shall carry out periodic inspection of the under frequency relays and produce the report to State Load Despatch Centre. State Load Despatch Centre shall maintain the record of under frequency relay and/or df/dt relay operation and shall furnish monthly report of under frequency relay and df/dt relay operation in their system to the RPC.
(18) All State Constituents shall also facilitate identification, installation and commissioning of System Protection Schemes (including inter-tripping and run-back) in the power system to operate transmission system closer to their limits and to protect against situations such as voltage collapse and cascading tripping, tripping of important corridors/flow gates etc. Such schemes would be finalized by the STU and shall be kept in service. SLDC shall be promptly informed in case any of these are taken out of service.
(19) Procedures shall be developed to recover from partial/total collapse of the grid and periodically updated in accordance with CEA (Grid Standards) Regulations, 2010 and with the requirements given under Regulation 6.9. These procedures shall be followed by all State constituents to ensure consistent, reliable and quick restoration.
(20) Each State Constituent shall provide & maintain adequate and reliable communication facility internally and with other Constituents/SLDC to ensure exchange of data/information necessary to maintain reliability and security of the grid. Wherever possible, redundancy and alternate path shall be maintained for communication along important routes, e.g., ALDC to SLDC.
(21) The State Constituents shall send information/data including disturbance recorder/sequential event recorder output etc., within 24hrs to SLDC for purpose of analysis of any grid disturbance/event. No State constituent shall block any data/information required by the SLDC for maintaining reliability and security of the grid and for analysis of an event.
(22) All State Constituents shall make all possible efforts to ensure that the grid voltage always remains within the following operating range:
| VOLTAGE-(kV rms) | ||
|---|---|---|
| Nominal | Maximum | Minimum |
| 765 | 800 | 728 |
| 400 | 420 | 380 |
| 220 | 245 | 198 |
| 132 | 145 | 122 |
| 66 | 72 | 60 |
This part is concerned with the provisions to be made by SLDC to effect a reduction of demand in the event of insufficient generating capacity, and inadequate transfers from external interconnections to meet demand, or in the event of breakdown or congestion in intra/inter State transmission system or other operating problems (such as frequency, voltage levels beyond normal operating limit, or thermal overloads etc.) or overdrawal of power by the licensee and open access consumer beyond the limits mentioned in Deviation Settlement Mechanism Regulation on any part of the grid
(1) SLDC/ State constituents shall initiate action to restrict the drawal of its control area, from the grid, within the net drawal schedule.
(2) The SLDC/State constituents shall ensure that requisite load shedding is carried out in its control area so that there is no overdrawal.
(3) Each State constituent shall formulate contingency procedures and make arrangements that will enable demand disconnection to take place, as instructed by the SLDC, under normal and/or contingent conditions. These contingency procedures and arrangements shall be regularly updated by the State constituent and monitored by SLDC. SLDC may direct any State constituent to modify the above procedures/arrangement, if required, in the interest of grid security and the concerned State constituents shall abide by these directions.
(4) The SLDC through the Distribution Licensees, shall also formulate and implement state-of-the-art demand management schemes for automatic demand management like rotational load shedding, demand response (which may include Time of Day Tariff and/or lower tariff for interruptible loads) etc. to reduce over drawal in order to comply with clause (1) & (2) of sub-Regulation 6.5.1 of these Regulations. A report detailing the scheme and periodic reports on progress of implementation of the schemes shall be sent to the State Commission by the SLDC.
(5) In order to maintain the frequency within the stipulated band and maintaining the network security, the interruptible loads shall be arranged in four groups of loads:
The aforesaid loads shall be grouped in such a manner, that there is no overlapping between different groups of loads.
A daily report covering the performance of the State grid shall be prepared by SLDC based on the inputs received from constituents and shall be put on its website. This report shall also cover the wind / solar power generation and injection into the grid.
A weekly report shall be issued by SLDC to all Constituents of the State and shall cover the performance of the State Grid for the previous week. Such weekly report shall also be available on the website of the SLDC for at least 12 weeks. The weekly report shall contain the following:
The objective of this part is:
This part is applicable to all State Constituents including SLDC, ALDCs, Transmission Licensees/ Users, laSGS and STU.
Provided that the State Load Despatch Centre shall inform the concerned State constituents about the revised outage plan, with appropriate reasons for revisions in the outage plan, as soon as possible.
(1) Detailed plans and procedures for restoration of the State Grid under partial/total blackout shall be developed by SLDC in consultation with all State Constituents and shall be reviewed / updated annually.
(2) Detailed plans and procedures for restoration after partial/total blackout of each Constituent's system within the State will be finalized by the concerned Constituent in co-ordination with the SLDC. The procedure will be reviewed, confirmed and/or revised once every subsequent year. Mock trial runs of the procedure for different sub-systems shall be carried out by the Constituents at least once in every six months under intimation to the SLDC. Diesel Generator sets for black start would be tested on weekly basis and test report shall be sent to SLDC on quarterly basis.
(3) List of generating stations with black start facility, inter-State/inter regional ties, synchronizing points and essential loads to be restored on priority, shall be prepared by and be available with SLDC.
(4) The SLDC is authorized during the restoration process following a black out, to operate with reduced security standards for voltage and frequency as necessary in order to achieve the fastest possible recovery of the grid.
(5) All communication channels required for restoration process shall be used for operational communication only, till grid normalcy is restored.
(6) Once an outage has commenced, if any delay in restoration is apprehended, concerned user shall inform SLDC promptly together with revised estimation of restoration time.
This part deals with reporting procedures in writing of reportable events in the system to all State Constituents and SLDC/ALDCs.
The objective of this part is to define the incidents to be reported, the reporting route to be followed and information to be supplied to ensure consistent approach to the reporting of incidents/ events.
This part covers all State Constituents, SLDC and ALDCs.
Any of the following events require reporting by SLDC/State Constituent:
(a) Violation of security standards;
(b) Grid indiscipline;
(c) Non-compliance of SLDC's instructions;
(d) System islanding/system split;
(e) State black-out/partial system black-out;
(f) Protection failure on any element of laSTS;
(g) Power system instability; and
(h) Tripping of any element of the State grid;
(i) Sudden load rejection by any State constituent.
In the case of an event, which was initially reported by a State Constituent or an ALDC to SLDC orally, the Constituent/ALDC will give a written report to SLDC in accordance with this part.
In the case of an event, which was initially reported by SLDC to a Constituent/ALDC orally, the SLDC will give a written weekly report to the Constituent/ALDC in accordance with this part.
A written report shall be sent to SLDC or a State Constituent/ALDC, as the case may be, and will confirm the oral notification together with the following details of the event:
(a) Time and date of event;
(b) Location;
(c) Plant and/or Equipment directly involved;
(d) Description and cause of event;
(e) Antecedent conditions of load and generation, including frequency, voltage and the flows in the affected area at the time of tripping including Weather Condition prior to the event;
(f) Demand and/or Generation (in MW) interrupted and duration of interruption;
(g) All Relevant system data including copies of records of all recording instruments including Disturbance Recorder, Event Logger, DAS etc.;
(h) Sequence of trippings with time;
(i) Details of Relay Flags; and
(j) Remedial measures.
(4) Events affecting a generation capacity of more than 300 MW or load of more than 500 MW for more than 3 hours shall be reported in writing to the Commission by the State Load Despatch Centre, Transmission Licensee or User, as the case may be.
Provided that a summary document including brief detail of the event, extent and probable causes of the event shall be sent across to the Commission within 24 hours of occurrence of such event.
This Chapter sets out the:
This code deals with the procedures to be adopted for scheduling of the intra-State generating stations (laSGS) and net drawals of concerned Constituents on a day a head basis with the modality of the flow of information between the laSGS/SLDC/beneficiaries of the State. The procedure for submission of capability declaration by each laSGS and submission of drawal schedule by each beneficiary is intended to enable SLDC to prepare the despatch schedule for each laSGS and drawal schedule for each beneficiary. It also provides methodology of issuing real time despatch/drawal instructions and rescheduling, if required, to laSGS and beneficiaries along with the commercial arrangement for the deviations from schedules, as well as, mechanism for reactive power pricing. This code also provides the methodology for re-scheduling of wind and solar energy, on one and half hour basis. For this, appropriate meters and Data Acquisition System facility shall be provided for accounting of deviation charges and transfer of information to concerned SLDC and RLDC. The provisions contained in this chapter are without prejudice to the powers conferred on SLDC under Section 32 and 33 of the Act.
This Code shall be applicable to SLDC/ALDCs, laSGS, Transmission Licensees/STU and other beneficiaries in the State Grid.
(1) The State Load Despatch Centre is responsible for coordinating the scheduling of a generating station, within the State control area. The SLDC shall also be responsible for such generating stations for (1) real-time monitoring of the station's operation, (2) checking that there is no gaming (gaming is an intentional mis-declaration of a parameter related to commercial mechanism in vogue, in order to make an undue commercial gain) in its availability declaration, (3) revision of availability declaration and injection schedule, (4) switching instructions, (5) metering and energy accounting, (6) issuance of deviation settlement within the control area, (7) collections/disbursement of deviation charges, (8) outage planning etc., (9) Any other activity directed by the Commission.
(2) The following generating stations shall come under the laSTS control area and hence, SLDC shall coordinate the scheduling of the following generating stations:
(3) There may be exceptions with respect to above provisions, for reasons of operational expediency, subject to approval of CERC, irrespective of the control area of the jurisdiction. If a generating station is connected both to the ISTS and the STU, the load despatch centre of the control area under whose jurisdiction the generating station falls, shall take into account grid security implication in the control area of the other load despatch centre.
(4) The State Grid shall be operated as power pool (with decentralized scheduling and despatch), in which the Users shall have full operational autonomy and Users, through their concerned ALDCs, shall have the total responsibility for:
(5) The system of each beneficiary shall be treated and operated as a notional control area. The algebraic summation of scheduled drawal from laSGs/ISGS and from contracts through long-term access, medium-term and short-term open access arrangements shall provide the drawal schedule of each beneficiary, and this shall be determined in advance on day-ahead basis. The beneficiaries shall regulate their embedded generation and/or consumers' load so as to maintain their actual drawal from the State Grid close to the above schedule. The beneficiaries may, at their discretion, deviate from the drawal schedule, as long as such deviations do not cause system parameters to deteriorate beyond permissible limits and/or do not lead to unacceptable line loading. Inadvertent deviations, if any, from net drawal schedule shall be priced through the Deviation Settlement Mechanism Regulations. Every beneficiary shall ensure reversal of sign of deviation from schedule at least once after every twelve time blocks.
(6) The SLDC, distribution licensee shall always restrict the net drawal of the State from the grid within the drawal schedules keeping the deviations from the schedule within the limits specified in the Deviation Settlement Mechanism Regulations. The concerned User and SLDC shall ensure that their Automatic Demand Management Scheme mentioned in sub-Regulation 6.5.1 of these Regulations acts to ensure that there is no over-drawal. If the Automatic Demand Management Scheme (ADMS) has not yet been commissioned, then action shall be taken as per manual demand management scheme to restrict the net drawal from grid to within schedules and all actions for early commissioning of ADMS shall be initiated.
(7) The SLDC/STU/Distribution Licensee shall regularly carry out the necessary exercises regarding short-term and long-term demand estimation for the State, to enable them to plan in advance as to how they would meet their consumers' load without overdrawing from the grid.
(8) The laSGS shall be responsible for power generation generally according to the daily schedules advised to them by the SLDC on the basis of the contracts/requisitions received from the beneficiaries/ALDCs/power exchanges and for proper operation and maintenance of their generating stations such that these stations achieve the best possible long-term availability and economy.
(9) The laSGS is normally expected to generate power according to the daily schedules advised to them barring any inadvertent deviations. Maximum deviation allowed during a time block shall not exceed the limits specified in the Deviation Settlement Mechanism Regulations. Such deviations should not cause system parameters to deteriorate beyond permissible limits and should not lead to unacceptable line loadings. Inadvertent deviations, if any, from the ex-power plant generation schedules shall be appropriately priced in accordance with Deviation Settlement Mechanism Regulations. In addition, deviations from schedules causing congestion, shall also be priced in accordance with the Central Electricity Regulatory Commission (Measure to relieve congestion in real time operation) Regulations, 2009.
(10) The treatment of injection of infirm power by generating stations during testing shall be in accordance with Deviation Settlement Mechanism Regulations amended time to time.
(11) Notwithstanding the above, SLDC may direct the beneficiaries/ ALDCs/laSGS to increase/decrease their drawal/ generation in case of contingencies; e.g. overloading of lines/ transformers, abnormal voltages, threat to system security. Such directions shall immediately be acted upon. In case the situation does not call for very urgent action and SLDC has some time for analysis, it shall be checked whether the situation has arisen due to deviations from schedules, pursuant to short-term open access. These shall be terminated first, before any action, which would affect the scheduled supplies to the long term and medium term customers, is initiated in accordance with Uttarakhand Electricity Regulatory Commission (Terms and Conditions of Intra-state Open Access) Regulations, 2015 as amended from time to time. In case Short Term/Medium Term Open Access or Long Term Access are curtailed, SLDC shall submit a report within three days to the defaulting open access consumer, regarding the reasons due to which it was not able to curtail deviations from Schedule and agencies which had not taken necessary actions.
(12) For all outages of generation and transmission system, which may have an effect on the State Grid, all Constituents shall cooperate with each other and co-ordinate their actions through Grid Coordination Committee (GCC) for outages foreseen sufficiently in advance and through SLDC (in all other cases), as per procedures finalized separately by GCC. In particular, outages requiring restriction of laSGS generation and/or restriction of laSGS/ISGS share which a beneficiary can receive (and which may have a commercial implication) shall be planned carefully to achieve the best optimization.
(13) The State Constituents shall enter into separate joint/bilateral agreement(s) to identify the beneficiary's shares in laSGS/ISGS projects (based on the allocations by Appropriate Government/Commission, where applicable), scheduled drawal pattern, tariffs, payment terms etc. All such agreements shall be filed with the SLDC for being considered in scheduling and State energy accounting. Any bilateral agreements between Constituents for scheduled interchanges on long-term/medium-term/short-term basis shall also specify the interchange schedule, which shall be duly filed in advance with the SLDC, as the case may be about these agreements in accordance with UERC (Terms and conditions Intra-state open access) Regulations, 2015 amended from time to time.
(14) The laSGS shall make an advance declaration of ex-power plant MW and MWh capabilities foreseen for the next day, i.e., from 0000 hrs to 2400 hrs. During fuel shortage condition, in case of thermal stations, they may specify minimum MW, maximum MW, MWh capability and declaration of fuel shortage. The generating stations shall also declare the possible ramping up / ramping down in a block. In case of a gas turbine generating station or a combined cycle generating station, the generating station shall declare the capacity for units and modules on APM gas, RLNG and liquid fuel separately, and these shall be scheduled separately.
(15) While making or revising its declaration of capability, except in case of Run off the River (with up to three hour pondage) hydro stations, the laSGS shall ensure that the declared capability during peak hours is not less than that during other hours. However, exception to this rule shall be allowed in case of tripping/re-synchronisation of units as a result of forced outage of units.
(16) It shall be incumbent upon the laSGS to declare the plant capabilities faithfully, i.e., according to their best assessment. In case, it is suspected that they have deliberately over/under declared the plant capability contemplating to deviate from the schedules given on the basis of their capability declarations (and thus make money either as undue capacity charge or as the charge for deviations from schedule), the SLDC may ask the laSGS to explain the situation with necessary backup data.
(17) The laSGS shall be required to demonstrate the declared capability of its generating station as and when asked by the SLDC. In the event of the laSGS failing to demonstrate the declared capability, the capacity charges due to the generator shall be reduced as a measure of penalty. In case of revision of schedule of a generating unit, the schedules of all transactions under the long-term access, medium-term open access and short-term open access (except collective transactions through power exchange), shall be reduced on pro-rata basis.
(18) The quantum of penalty for the first mis-declaration for any duration/block in a day shall be the charges corresponding to two days fixed charges. For the second mis-declaration the penalty shall be equivalent to fixed charges for four days and for subsequent mis- declarations, the penalty shall be multiplied in the geometrical progression over a period of a month.
(19) The STU shall install special energy meters on all inter connections between State Constituents the and other identified points for recording of actual net MWh interchanges and MVarh drawals. The installation, operation and maintenance of special energy meters shall be in accordance with CEA (Installation and Operation of Meters) Regulations, 2006 as amended from time to time.
(20) The SLDC shall be responsible for computation of actual net MWh injection of each laSGS and actual net drawal of each beneficiary, 15 minute-wise, based on the above meter readings and for preparation of the State Energy Accounts as per Deviation Settlement Mechanism Regulations as amended from time to time.
(21) The operating log books of the generating station shall be available for review by the SLDC. These books shall keep record of machine operation and maintenance.
(22) SLDC shall periodically review the actual deviation from the despatch and net drawal schedules being issued, to check whether any of the constituents are indulging in unfair gaming or collusion. In case any such practice is detected, the matter shall be reported to the STU for investigation and STU shall furnish a report in the matter to the Commission.
(23) In case the Distribution Licensee having an area of supply in which an laSGS is located has a predominant share in that laSGS, the concerned parties may mutually agree (for operational convenience) to assign the responsibility of scheduling of the laSGS to the concerned ALDC. The role of the SLDC, in such a case, shall be limited to consideration of the schedule for intra-State exchange of power on account of this laSGS while determining the net drawal schedules of the respective beneficiaries.
Provided that a beneficiary's entitlements for plant-wise drawal/bilateral exchanges through the inter-State connections can be determined in lump sum by the SLDC if it is operationally convenient and feasible to do.
(5) Scheduling of collective transaction:
(6) The beneficiaries may also give standing instructions to the SLDC such that the SLDC itself may decide the drawal schedules for the beneficiaries.
(7) After considering the despatch schedule and net drawal schedule for the State as intimated by RLDC, by 6 PM each day, the SLDC shall convey:
(8) The beneficiaries/IaSGS may inform any modifications/changes to be made in station-wise drawal schedule & bilateral interchanges /foreseen capabilities, if any, to SLDC by 9 PM.
(9) Upon receipt of such information, the SLDC after consulting the concerned Constituents shall issue the final 'drawal schedule' to each beneficiary and the final 'despatch schedule' to each IaSGS by 11.30 PM.
(10) Also, based on the surpluses foreseen for the next day, if any, the Constituents may arrange for bilateral exchanges. The schedules for such arrangements shall be intimated latest by 9 PM to SLDC, who in turn will take into account these agreed exchanges while issuing the final despatch/drawal schedules at 11.30 PM provided they would not lead to a transmission constraint and are not objected to by RLDC.
(11) The declaration of the generating capability by hydro laSGS should include limitation on generation during specific time periods, if any, on account of restriction(s) on water use due to irrigation, drinking water, industrial, environmental considerations etc. The SLDC shall periodically check that the generating station is declaring the capacity and energy sincerely, and is not manipulating the declaration with the intent of making undue money through Deviation Settlement mechanism.
(12) Since variation of generation in run-of-river power stations shall lead to spillage, these shall be treated as must run stations. All renewable energy power plants, except for biomass power plants, and non-fossil fuel based cogeneration plants whose tariff is determined by the Commission shall be treated as "MUST RUN" power plants and shall not be subjected to "Merit order despatch" principles.
(13) Run-of-river power station with pondage and storage type power stations are designed to operate during peak hours to meet system peak demand. Maximum capacity of the station declared for the day shall be equal to the installed capacity including overload capability, if any, minus auxiliary consumption, corrected for the reservoir level. The State Load Despatch Centers shall ensure that generation schedules of such type of stations are prepared and the stations despatched for optimum utilization of available hydro energy except in the event of specific system requirements/constraints.
(14) The schedule finalized by the State load despatch centre for hydro generating station, shall normally be such that the scheduled energy for a day equals the total energy (ex-bus) expected to be available on that day, as declared by the generating station, based on foreseen/planned water availability/release. It is also expected that the total net energy actually supplied by the generating station on that day would equal the declared total energy, in order that the water release requirement is met.
(15) While finalizing the above daily despatch schedules for the laSGS, SLDC shall ensure that the same are operationally reasonable, particularly in terms of ramping-up/ramping-down rates and the ratio between minimum and maximum generation levels. A ramping rate of upto 200 MW per hour should generally be acceptable for an laSGS and for a State Constituent except for hydro-electric generating stations which may be able to ramp up/ramp down at a faster rate.
(16) While finalizing the drawal and despatch schedules as above, the SLDC shall also check that the resulting power flows do not give rise to any transmission constraints. In case any constraints are foreseen, the SLDC shall moderate the schedules to the required extent, under intimation to the concerned Constituents. Any changes in the scheduled quantum of power which are too fast or involve unacceptably large steps may be converted into suitable ramps by the SLDC.
(17) In case of forced outage of a unit, the SLDC shall revise the schedules on the basis of revised declared capability. The revised declared capability and the revised schedules shall become effective from the 4th time block, counting the time block in which the revision is advised by the laSGS to be the first one.
(18) In the event of bottleneck in evacuation of power due to any constraint, outage, failure or limitation in the transmission system, associated switchyard and sub-stations owned by the State Transmission Utility or any other transmission licensee involved in intra-state transmission (as certified by the SLDC) necessitating reduction in generation, the SLDC shall revise the schedules which shall become effective from the 4th time block, counting the time block in which the bottleneck in evacuation of power has taken place to be the first one. Also, during the first, second, third, time blocks of such an event, the scheduled generation of the laSGS shall be deemed to have been revised to be equal to actual generation and the scheduled drawals of the beneficiaries shall be deemed to have been revised to be equal to their actual drawals.
(19) In case of any grid disturbance, scheduled generation of all the laSGS and scheduled drawal of all the beneficiaries shall be deemed to have been revised to be equal to their actual generation/drawal for all the time blocks affected by the grid disturbance. Certification of grid disturbance and its duration shall be done by the SLDC.
The declaration of disturbance shall be done by the SLDC at the earliest. A notice to this effect shall be posted at its website by the SLDC of the area in which the disturbance occurred. Issue of the notice at SLDC web site shall be considered as declaration of the disturbance by SLDC. All State constituents shall take note of the disturbance and take appropriate action at their end.
Provided that the schedule of the buyers and sellers shall be revised after forced outage of a unit, only if the source of power for a particular transaction has clearly been indicated during short-term open access application and the said unit of that generating station goes under forced outage.
(23) In case of revision of schedule of a generating unit, the schedules of all transactions under the long-term access, medium-term open access and short-term open access (except collective transactions through power exchange), shall be reduced on pro-rata basis
(24) If, at any point of time, the SLDC observes that there is need for revision of the schedules in the interest of better system operation, it may do so on its own, and in such cases, the revised schedules shall become effective from the 4th time block, counting the time block in which the revised schedule is issued by the SLDC to be the first one.
(25) To discourage frivolous revisions, SLDC may, at its sole discretion, refuse to accept schedule/capability changes of less than two (2) percent of the previous schedule/capability. The schedule of thermal generating stations indicating fuel shortage while intimating the Declared Capacity to the SLDC shall not be revised except in case of forced outage of generating unit. Provided that in case of gas based laSGS, for optimum utilization of gas, this shall be permitted, i.e. in case of tripping of a unit, this gas may be diverted to another unit using the same gas.
(26) The State Load Despatch Centre shall also formulate the procedure for meeting contingencies both in the long run and in the short run (Daily scheduling).
(27) Wind and Solar generators:
(b) Forecasting shall be done by wind and solar generator as well as the SLDC. The SLDC may engage forecasting agency (ies) and prepare a schedule for such generating stations. The forecast by the SLDC shall be with the objective of ensuring secure grid operation. The forecast by the wind and solar generator shall be generator centric. The wind and solar generators which are State constituents will have the option of accepting SLDC's forecast for preparing its schedule or provide the SLDC with a schedule based on its own forecast. Any commercial impact on account of deviation from schedule based on the forecast chosen by the wind and solar generator shall be borne by it.
(28) Generation schedules and drawal schedules issued/revised by the State Load Despatch Centre shall become effective from designated time block irrespective of communication success.
(1) Reactive power compensation should ideally be provided locally, by generating reactive power as close to the reactive power consumption as possible. The beneficiaries are, therefore, expected to provide local VAR compensation/generation such that they do not draw VARs from the EHV grid, particularly under low-voltage condition. However, considering the present limitations, this is not being insisted upon. Instead, to discourage VAR drawals by Beneficiaries, VAR exchanges with laSTS shall be priced as follows:
(a) The Beneficiary pays for VAR drawal when voltage at the metering point is below 97%.
(b) The Beneficiary gets paid for VAR return when voltage is below 97%.
(c) The Beneficiary gets paid for VAR drawal when voltage is above 103%.
(d) The Beneficiary pays for VAR return when voltage is above 103%.
Provided that there shall be no charge/payment for VAR drawal/return by a Beneficiary on its own line emanating directly from an laSGS.
Provided that such requirements shall be consistent with the Regulations as may be specified by the CEA under Section 55 of the Act.
Provided further that such requirements shall be applicable to any other point that may be internal to the power system of the User or Transmission Licensee if information captured by such meter shall be required for commercial or operational purposes.
This chapter specifies the requirements for safe working practices for maintenance of equipment associated with cross boundary operations and lays down the procedure to be followed when the work is carried out on electrical equipment connected to another User's System.
The objective of this section is to achieve an agreement on the principles of safety prescribed in the CEA (Measures Relating to Safety and Electric Supply) Regulations, 2010 and CEA (Safety Requirements for construction, operation and maintenance of electrical plants and electric lines) Regulations, 2011 when working across a control boundary between the STU/ Transmission Licensee and the Users.
(1) STU/ Transmission Licensee and all the Users shall nominate suitably authorized and technically qualified persons to be responsible for the co-ordination of safety across their boundary. These persons shall be referred to as "Control Persons".
(2) STU/ Transmission Licensee shall issue a list of Control Persons with their names, designations, addresses and telephone numbers, to all the Users having direct control boundary with it. This list shall be updated promptly whenever there is any change of name, designation or telephone number of any Control Person named in the list.
(3) All Users having a direct control boundary with STU/ Transmission Licensee shall issue a similar list of their Control Persons to STU/ Transmission Licensee. This list shall be updated promptly whenever there is any change of name, designation or telephone number of any Control Person named in the list.
(4) Whenever any work across a cross boundary is to be carried out by the user or STU/ Transmission Licensee, the Control Person of the user or STU/Transmission Licensee as the case may be, who has to carry out the work, shall directly contact his counterpart. Code words shall be agreed to, at the time of work, to ensure correct identification of both the parties. Contact between Control Persons shall normally be made by direct telephone.
(5) If the work extends beyond one shift, the Control Person shall hand over charge to the relief Control Person and fully brief him on the nature of work and the code words in the operation.
(6) The Control Persons shall cooperate to establish and maintain the precautions necessary to be taken for carrying out the required work in a safe manner. Both the established isolation and the established earth shall be kept in the locked positions wherever such facilities exist, and these shall be clearly identified and entered into the log sheet.
(7) The Control Person in charge of the work shall satisfy himself that all the safety precautions to be taken are established before commencing the work. He should issue the safety documentation to the working party to allow the work to commence.
(8) After completion of the work, the Control Person in charge of the work being carried out, should satisfy himself that the safety precautions taken are no longer required, and shall make a direct contact with his counterpart Control Person and request removal of the safety precautions. The equipment shall be declared as suitable for return to service only after confirmation of removal of all the safety precautions, by direct communication, using the code word contact between the two Control Persons, and the return of agreed safety documentation from the working party.
(9) STU shall develop an agreed written procedure for Cross Boundary Safety and continuously update the same.
(10) Any dispute concerning Cross Boundary Safety shall be resolved at the level of STU, if STU is not a party. In case where STU is a party, the dispute shall be referred to the Commission for resolution of the dispute.
The Commission may, at anytime, vary, alter, modify or amend any provisions of these Regulations.
If any difficulty arises in giving effect to the provisions of these Regulations, the Commission may, by general or specific order, make such provisions not inconsistent with the provisions of the Act, as may appear to be necessary for removing the difficulty.
[refer sub-Regulation (4) of Regulation 7.1]
(Applicable w.e.f. such date as may be decided by Commission for introduction of Intra-State ABT)
(1) The beneficiaries shall pay to the respective laSGS Capacity Charges corresponding to plant availability and Energy Charges for the scheduled despatch, as per the relevant notifications and orders of the Commission. The bills for these charges shall be issued by the respective laSGS to each beneficiary on monthly basis.
(2) The sum of the above two charges from all beneficiaries shall fully reimburse the laSGS for generation according to the given despatch schedule. In case of a deviation in actual generation from the despatch schedule, the concerned laSGS shall receive or shall pay in accordance with Deviation Settlement Mechanism Regulations. Similarly, the deviation of actual drawl by any Beneficiary from the net drawl schedule shall be treated as Deviation from the schedule. All 15-minute energy figures (net scheduled, actually metered and Deviation from the schedule) shall be rounded off to the nearest 0.01 MWh. The Deviation charges and the modalities of settlement of Deviation shall be in accordance with Deviation Settlement Mechanism Regulations.
(3) Complementary Commercial Mechanism for wind and solar generators shall be according to the Indian Electricity Grid Code (IEGC), 2010 and as amended from time to time.
(4) The summation of station-wise ex-power plant despatch schedules from each laSGS/ISGS and any bilaterally agreed interchanges of each beneficiary shall be adjusted for transmission losses, and the net drawal schedule so calculated shall be compared with the actual net drawal of the beneficiary. In case of excess drawal, the beneficiary shall be required to pay through the Deviation Settlement Mechanism for the excess energy. In case of under-drawal, the beneficiary shall be paid back through the Deviation Settlement mechanism, for the energy not drawn.
(5) When requested by a constituent, SLDC shall assist the constituent in locating a buyer/seller and arranging a scheduled interchange within the State or across the State boundary. The SLDC shall act only as a facilitator (not a trader/broker), and shall assume no liabilities under the agreement between the two parties, except.
(6) State Energy Accounts shall be prepared on monthly basis and the statement of Deviation charges and Reactive Energy Charges shall be prepared by the SLDC on a weekly basis and these shall be issued to all State constituents by Tuesday for the seven-day period ending on the previous Sunday mid-night. Payment of Deviation charges shall have a high priority and the concerned State constituent shall pay the indicated amounts within 7 (seven) days of the statement issue into a State Deviation pool account operated by the SLDC. The State constituents who have to receive the money on account of Deviation charges would then be paid out from the State Deviation pool account, within five (5) working days from the receipt of payment in the State Deviation Pool account.
(7) The SLDC shall also issue the weekly statement for VAr charges to all Beneficiaries who have a net drawal/injection of reactive energy under low/high voltage conditions. These payments shall also have a high priority and the concerned Beneficiaries shall pay the indicated amounts into State Reactive Energy Pool account operated by the SLDC within 7 (seven) days of statement issue. The Beneficiaries who have to receive the money on account of VAr charges would then be paid out from the State Reactive Energy Pool account, within five (5) working days from the receipt of payments in the State Reactive Energy Pool account.
(8) If payments in State Pool accounts (State Deviation Pool Account & State Reactive Energy Pool Account) against the above Deviation and VAr charges are delayed by more than two days, i.e., beyond nine (9) days from statement issue, the defaulting Constituent shall have to pay simple interest @ 0.04% for each day of delay. The interest so collected shall be paid to the Constituents who had to receive the amount, payment of which got delayed. Persistent payment defaults, if any, shall be reported by the SLDC to the STU, for initiating remedial action.
(9) The money remaining in the State Reactive Energy Pool account after pay-out of all VAr charges upto 31st March of every year shall be utilized for training of the SLDC operators and other similar purposes which would help in improving/streamlining the operation of the State Grid, as decided by the STU from time to time.
(10) In case the voltage profile of State Grid improves to an extent that the total pay-out from the State VAr charges account for a week exceeds the total amount being paid-in for that week and if the State reactive account has no balance to meet the deficit, the pay-outs shall be proportionately reduced according to the total money available in the above account.
(11) The SLDC shall table the complete quarterly statement of the State Deviation Pool account and the State Reactive Energy Pool account in the GCC meeting, for audit by the latter.
[refer clause (c) of sub-Regulation (7) of Regulation 7.6]
Interconnecting line owned by Beneficiary-A
Metering Point: Substation of Beneficiary-B
Diagram for Case 1: Interconnecting line owned by Beneficiary-A. Two circles represent Beneficiary A and Beneficiary B. A horizontal line connects them, with a meter symbol (a vertical line with a horizontal bar and a circle) located within Beneficiary B's circle.
Interconnecting line owned by State-B
Metering point: Substation of Beneficiary-A
Diagram for Case 2: Interconnecting line owned by State-B. Two circles represent Beneficiary A and Beneficiary B. A horizontal line connects them, with a meter symbol (a vertical line with a horizontal bar and a circle) located within Beneficiary A's circle.
Beneficiary-B pays to Beneficiary-A for
Note: Net VARh and net payment may be positive or negative
Interconnecting line is jointly owned by Beneficiary-A and -B.
Metering points: Substations of Beneficiary -A and Beneficiary -B
Diagram showing two overlapping circles representing Beneficiary A and Beneficiary B. Inside Beneficiary A's circle is a substation symbol labeled S/S-A. Inside Beneficiary B's circle is a substation symbol labeled S/S-B. A horizontal line connects the two substations, passing through the intersection of the two circles, representing a jointly owned interconnecting line.
Net VARh exported from S/S-A, while voltage < 97% = X1
Net VARh exported from S/S-A, while voltage > 103% = X2
Net VARh imported at S/S-B, while voltage < 97% = X3
Net VARh imported at S/S-B, while voltage > 103% = X4
(i) Beneficiary -B pays to Beneficiary -A for
X1 or X3, whichever is smaller in magnitude, and
(ii) Beneficiary -A pays to Beneficiary -B for
X2 or X4, whichever is smaller in magnitude.
(To be furnished by the generating company to STU)
| General | |
|---|---|
| Site | Furnish location map (schematic) showing roads, railway lines, transmission lines, rivers, and reservoirs, if any. |
| Approximate period of construction | |
| Annual generation in million kWh | |
| Connection | |
| Connection Point /Interface Point | Furnish single line diagram of the proposed connection with the Transmission System with clear indication of possibility for right-of-way for unobstructed outlet |
| Step up voltage for connection kV | |
| Station Capacity | |
| Total generating station capacity (MW) | |
| No. of units and unit size MW | State whether development will be carried out in phases and if so, furnish details. |
| Generating Unit Data | |
| (1) Generator | |
| (a) Make and Type | |
| (b) Rating(MVA) | |
| (c) Terminal Voltage (kV) | |
| (d) Rated Power Factor | |
| (e) Rated Power capability (MVA r ) in the range 0.95 leading and 0.85 lagging | |
| (f) Short Circuit Ratio | |
| (g) Direct axis transient reactance(% on MVA rating) |
| (h) Direct axis sub-transient reactance (% on MVA rating) |
|
| (i) Auxiliary power Requirement | |
| (2) Generator Transformer | |
| (a) Type | |
| (b) Rated Capacity(MVA) | |
| (c) Voltage Ratio(HV/LV) | |
| (d) Tap Change range (+%to -%) | |
| (e) Percentage Impedence (Positive Sequence at Full load) |
(as applicable to hydro generating stations mentioned above)
(as applicable to hydro generating stations mentioned above)
(as applicable to hydro generating stations mentioned above)
(as applicable to hydro generating stations mentioned above)
(i) In relation to Interconnecting Transformers between EHV / HV Transmission System and the Generator Transformer Voltage System:
(ii) In relation to switchgear including circuit breakers, isolators on all circuits connected to the points of connection:
(iii) Lightning arresters, technical data.
(iv) Communication- Details of PLCC and other communication equipment installed at Connection Point(s)/ Interface Point(s).
(v) Basic insulation level (kV):
(i) Parameters of Generating Units:
(x) Number of terminals brought out
(y) Rated speed (rpm)
(z) Rated Frequency (Hz.)
(ii) Parameters of Excitation Control System:
(m) Details of excitation loop in block diagrams showing transfer functions of individual elements using IEEE symbols along with set values.
(n) Dynamic characteristics of over-excitation limiter
(o) Dynamic characteristics of under-excitation limiter
(p) Exciter IEEE model I type no.
(q) Exciter response time
(iii) Parameters of Governor/ Turbine:
(iv) Operational Parameters:
| Daily Demand Profile (Last Year) | Half-hourly integrated demand throughout the day |
|---|---|
| Units Generated (Million kWh) | |
| Units consumed in Auxiliaries (Million kWh) | |
| Units supplied from system to Auxiliary Load | |
| Seasonal Generation |
(As applicable to thermal generating stations mentioned above)
(As applicable to thermal generating stations mentioned above)
(As applicable to thermal generating stations mentioned above).
(As applicable to thermal generating stations mentioned above)
(As applicable to thermal generating stations mentioned above)
(For submission by generator on request by STU)
(As applicable to thermal generating stations mentioned above)
(To be furnished by the distribution company to STU)
| General | |
|---|---|
| SingleLine Diagram | Licensee-wise up to 33 kV substations. |
| Consumer Data | Furnish category wise number of consumers, their connected loads to the best judgment of the Distribution Licensee |
| Reference to area offices presently in charge of the distribution | |
| Connection | |
| Connection Points/ Interface Points: | Furnish single line diagram showing Connection Points/ InterfacePoints. |
| Voltage of supply at Connection Points/ Interface Points: | |
| Names of Grid Substation feeding the Connection Points/ InterfacePoints: | |
| Lines and Substations: | |
| 1. Line Data: | Furnish length of line and voltages (EHV level) |
| 2. Substation Data: | Furnish transformer details for substations, capacitor installations. |
| Loads | |
| Loads drawn at Connection Points/ Interface Points: | If the Distribution Licensee receive power at a number of connection points in a compact area, which are interconnected in a ring, then such a Distribution Licensee shall forward the overall load drawn for overall Area of Supply, as well as at each connection point with the variation or tolerance as mutually discussed and agreed upon with the STU |
| Details of load fed at EHV if any; | Give name of consumer, voltage of supply, contract demand and name of grid substation from which line is drawn, length of EHT line from grid substation to the consumer's premises. |
| Type of Load & Rating in HP or kW | State whether furnace loads, rolling mills traction loads, other industrial loads, pumping loads. |
| Rated voltage | |
| Electrical loading of equipment: | |
| Sensitivity of load to voltage and frequency of supply | State number and size of motors, rating of arc furnaces/induction furnace, types of drive and control arrangements. |
| Maximum harmonic content of load | |
| Average and maximum phase unbalance of load | |
| Nearest substation from which load is to be fed | |
| Location map to scale | Map shall show the location of load with reference to lines and sub-stations in the vicinity |
| Peak load for Connection Point/ Interface Point as well as peak load and energy forecast for Area of Supply for each of the succeeding five years. | |
| Details of methodology and assumptions on which forecasts are based. | |
Details of load 5 MW and above.
|
| Schematic single line diagram of Distribution System (showing distribution lines from Connection Points/ Interface Points with Transmission System at various voltage levels, consumer bus if fed directly from Transmission system) | |
| Numbering and nomenclature of lines and substations (identified with feeding grid substations of the Transmission System at various voltage levels. |
| Connection Points/ Interface Points (furnish details of existing arrangement of connection) | |
| Details of metering of Connection Points/ Interface Points. |
Connection Points/ Interface Points as applied for
|
|
| Changes in metering at Connection Points/ Interface Points |
| Details of major loads of 1 MW and above to be contracted for next three years. | |
| --------------------------------------------------------------------------------- | -- |
(To be furnished to the user by STU/ Transmission Licensee.)
| Name of the line (indicating generating station and substation to be connected) | |
| Voltage of line KV: | |
| No of circuits | |
| Route length CKM | |
| Conductor Size | |
| Line parameter (PU on 100MVA base or ohmic value): | Resistance /KM Inductive reactance/KM Suceptance /KM |
| Approximate Load flow MW & MVAR | |
| Line route (topographic sheet) |
| General | |
|---|---|
| Single line diagram of the Transmission System at grid sub-station | |
| Name of substation | |
| Generating station connected | |
| Number and length of circuits | |
| Interconnecting transformers | |
| Substation bus layouts | |
| Power transformers | |
Reactive compensation equipment
|
|
| Lightning arresters | |
| Bus and/or line reactors |
| Bus bar layouts | |
| Electrical circuitry, lines, cables, transformers, switchgear etc. | |
| Phasing arrangements | |
| Earthing arrangements | |
| Switching facilities and interlocking arrangements |
| Operating voltages | |
| Numbering and nomenclature | |
| • Transformers | |
| • Circuits | |
| • Circuit breakers | |
| Isolating switches | |
| Line Parameters: (For All Circuits) | |
| Name of line | |
| Length of line (KM) | |
| No. of circuits, size and type of conductor, thermal rating | |
| Per circuit values | |
| • Operating voltage (kV) | |
| • Positive phase sequence reactance ohms/KM | |
| • Positive phase sequence resistance ohms/KM | |
| • Positive phase sequence suceptance mhos/KM | |
| • Zero Phase Sequence Reactance Ohms/Km | |
| • Zero phase sequence resistance ohms/KM | |
| • Zero Phase sequence suceptance mhos/KM | |
| Transformer Parameters: (For All Transformers Substation-wise) | |
| Rated MVA | |
| Voltage ratio | |
| Vector group | |
| Positive sequence reactance on rated MVA base (Max., min. & normal) | |
| Positive sequence resistance on rated MVA base (max., min. & Normal) | |
| Zero sequence reactance on rated MVA base | |
| Tap change range (+% to -%) and steps | |
| Details of tap changer (OFF/ON) | |
| Neutral grounding transformer/resistor values 10. % Impedance (Max/Min/Normal Tap) |
| Circuit breakers | |
| Isolating switches | |
| Current transformers | |
| Potential transformers | |
| Lightning arresters | |
| Earthing switches |
| Relay protection installed for all transformers and feeders along with their settings and level of coordination with other Users. | |
| Metering Details |
| Demand Profile (peak and off peak load) | |
| Forecast for next five years |
| Type of equipment (fixed or variable) | |
| Capacities and/or inductive rating (voltage and MVar) or its operating range. | |
| Details of control | |
| Connection Point/ Interface Point to the system. |
| Single Line Diagram showing position of connection | |
| Substation layout diagram | |
| New | |
| Addition and alteration | |
| Revised system studies with changed parameters | |
| Connection Point/ Interface Point: | |
| • Voltage | |
| • Length of circuit | |
| • Circuit parameters | |
| • PLCC facilities | |
| • Relaying with inter tripping arrangements to inter trip system. breaker at Connection Point/ Interface Point to isolate on fault | |
| • Metering at Connection Point/ Interface Point. | |
| • Other communication facility |
| ABCB | Air Break Circuit Breaker |
| ABT | Availability Based Tariff |
| ACSR | Aluminium Conductor Steel Reinforced |
| APM | Administered Pricing Mechanism |
| AVR | Automatic Voltage Regulator |
| BIS | Bureau of Indian Standards |
| CEA | Central Electricity Authority |
| CERC | Central Electricity Regulatory Commission |
| CPP | Captive Power Plant |
| CVT | Capacitive Voltage Transformer |
| D/C | Double Circuit |
| DISCOMs | Distribution Companies |
| DSM | Demand Settlement Mechanism |
| EFR | Earth Fault Relay |
| EHV | Extra High Voltage |
| EHT | Extra High Tension |
| EMPT | Electromagnetic Potential Transformer |
| FACTS | Flexible AC Transmission System |
| HVDC | High Voltage Direct Current |
| ICT | Inter Connected Transformer |
| ID | Induced Draft |
| IEC | International Electro-Technical Commission |
| IEC Standard | Standard approved by International Electro-technical Commission |
| IEEE | Institution of Electrical and Electronic Engineering |
| IPP | Independent Power Producer |
| IS | Indian Standards |
| MB-1 | Maneri Bhali Hydro Electric Project |
| MNRE | Ministry of New and Renewable Energy Sources |
| MU | Million Unit |
| OCR | Over Current Relay |
| PLCC | Power Line Carrier Communication |
| PLF | Plant Load Factor |
| PMU | Phasor Measurement Unit |
| REA | Regional Energy Account |
| RLDC | Regional Load Despatch Centre |
| RLNG | Re-Liquefied Natural Gas |
| ROR | Run of River |
| RPC | Regional Power Committee |
| S/C | Single Circuit |
| SCADA | Supervisory Control and Data Acquisition |
| SEA | State Energy Account |
| SVC | Static VAr compensator |
| Submitted to | ||||||
|---|---|---|---|---|---|---|
| Agency | SLDC | STU | State Constituents | Transmission Licensee/USERS | RPC/RLDC | Commission |
| SLDC | 7.4 (22) | 6.6 6.7.2 6.8.4 (4) & (7) 6.10.4 (1) 6.10.6 (2) & (3) 7.4 (11) Annexure-I clause (6) |
6.2 (4) (5) & (17) 6.4 (8) 6.8.4 (3) |
3.3.9 6.1.1 (4) 6.5.1 (4) 6.10.6 (4) Annexure-I clause (11) |
||
| STU | 6.2 (17) | 4.6 (2) 5.13 (3) 9.3 (2) |
2.2 (3) (7) 4.4 (12) 5.19 7.4 (22) 8.1 (1) 10.1 (4) |
|||
| State Constituents | 6.2 (3), (4), (18) & (21) 6.4 (4) 6.5.1 (3) 6.8.4 (2) 6.9 (2) & (6) 6.10.4 (2) 6.10.6 (1) & (3) |
4.5 (4) | 3.8.2 | |||
| Transmission Licensee/USERS | 4.6 (1) & (4) 9.3 (3) |
5.15 (2) & (3) 5.17 (3) |
2.3 (1) | |||
| GCC | 10.1 (3) | 2.3 (3) |
Submitted by
By Order of the Commission,
NEERAJ SATI,
Secretary,
Uttarakhand Electricity Regulatory Commission.