The Himachal Pradesh Electricity Grid Code, 2008

Compendium of HPERC Regulations, March 2021 1 1 [The Himachal Pradesh Electricity Grid Code, 2008] Amended, repealed or otherwise affected by:-

1. (First Amendment) Regulations, 2018 notified vide Not. No. HPERC-Grid Code

(388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p.

5404-5418.

NOTIFICATION Dated: 05 August, 2008 No: HPERC-Grid Code (388).- In exercise of the powers conferred under subsection (1)(h) Section 86 of the Electricity Act, 2003 (Central Act 36 of 2003) and all other powers enabling it in that behalf, the Himachal Pradesh Electricity Regulatory Commission hereby specifies the Himachal Pradesh Electricity Grid Code (hereinafter also referred to as “HPEGC” or “Grid Code”). The HPEGC shall come into effect from the date of its publication in the Rajpatra, Himachal Pradesh.

CHAPTER–1 GENERAL

1.1 Introduction

1.1.1 The Himachal Pradesh Electricity Grid Code lays down the rules, procedures and standards to be followed by the various Users and participants in the Intra -State Transmission System to plan, develop, maintain and operate the Intra -State Transmission System, a part of Northern Region Grid System, in the most efficient, reliable, economic and secure manner.

1.2 Objective

1.2.1 The Grid Code is designed to facilitate the development, and maintenance of an efficient, coordinated, secure and economical Intra-State Transmission System (IaSTS). It accordingly provides the following:

(a) Documentation of the principles and procedures, which define the relationship between the various Users of IaSTS as well as the Regional Load Despatch Centre and the State Load Despatch Centre.

(b) Technical Standards, Rules and Procedures (technical, operational and for information sharing) to be adopted by State Load Despatch Centre (SLDC), State Transmission Utility (STU) and Users connected to the IaSTS.

(c) Common basis of operation of the IaSTS to facilitate open access and trading of electricity, applicable to all the Users of the IaSTS.

1.3 Scope and Extent of Application 2 [1.3.1 This Code shall apply to all parties that connect with and/or utilize the IaSTS, including SLDC, which are required to abide by the principles and procedures

1. Published in R.H.P. dated 11 th August, 2008 at p. 3140-3188.

2 Subs. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “This Code 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 this Code to the extent it applies to them.”[ 2 Compendium of HPERC Regulations, March 2021 defined in this Code to the extent it applies to them and, where the context so permits, shall also apply to those connected to and/or using such component(s) of the State Power Grid as may not form part of IaSTS.]

1.3.2 The Grid Code shall apply for the Intra-State 1 [flow] of electricity. For the Inter-State transmission of electricity the Indian Electricity Grid Code (IEGC) shall be applicable.

1.3.3 This Grid Code shall not affect the obligations of the STU, SLDC and Users as laid down under the Indian Electricity Grid Code notified by the Central Electricity Regulatory Commission, and/or the Electricity Act, 2003 and rules and regulations made thereunder.

1.4 Structure of the HPEGC

1.4.1 The HPEGC is structured in distinct chapters as follows:

(a) Chapter-1: General This chapter outlines the broad features of the HPEGC. The various terms used in the HPEGC are also defined in this chapter.

(b) Chapter -2: Role of various Organizations & their linkages This chapter defines the functions of the various organizations as are relevant to HPEGC.

(c) Chapter -3: Planning Code for Intra-State Transmission This chapter specifies the principles, procedures and criteria that shall be used in the planning and development of the IaSTS.

(d) Chapter -4: Connectivity Conditions Code 2 [This Chapter specifies the minimum technical and design criteria which shall be complied with by STU and any User connected to, or seeking connection to the IaSTS. This chapter also sets out the procedures by which STU shall ensure compliance by all Users with the above criteria as a pre-requisite for the establishment of an agreed connection.]

(e) Chapter -5: Operation Planning and System Security Code This Chapter describes the operational philosophy to maintain efficient, secure, economic and reliable grid operation. This chapter covers the requirement for the exchange of information in relation to security aspects, demand estimation, demand management, outage planning, operational liaisoning, and events occurring in the State Power System and the Northern Grid, which have had or may have an effect on the Regional Grid and/or the State Power Grid and/or 1 Sub. for word “transmission” vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418.

2 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “This chapter specifies minimum technical and design criteria to be complied with by any agency, connected to or seeking connection to the IaSTS, to maintain uniformity and quality across the system.” Compendium of HPERC Regulations, March 2021 3 Users’ System connected to the State Power Grid. This chapter also formulates the recovery and normalization of power supply process to be followed by all the Users connected to the State Power Grid in the event of failure of State Power Grid and/or the Northern Grid (total or partial collapse) causing blackouts.

(f) Chapter -6: Scheduling & Despatch Code This chapter deals with the procedure to be adopted for scheduling and despatch of generation of the State Sector Generating Stations (SSGS) including complementary commercial mechanisms, on a daily basis with the modality of the flow of information between the SSGS, other Users and SLDC.

(g) Chapter -7: Management of HPEGC This chapter deals with the procedure for review/amendment and management of the HPEGC.

1.5 Non-compliance

1.5.1 State Transmission Utility shall be responsible for monitoring the compliance by the Users with the provisions contained in Chapter 3 and Chapter 4 of this Code.

Responsibility for monitoring the compliance by the Users with the provisions contained in Chapter 5 and Chapter 6 of this Code rests with the State Load Despatch Centre.

1.5.2 In monitoring the compliance of the Users with the relevant provisions of the HPEGC, the STU/SLDC shall not unduly discriminate against or unduly prefer any User.

1.5.3 In case of a persistent non-compliance of any of the stipulations of the HPEGC, such matter shall be reported to the Commission.

1[1.6 Restricted Governor Mode of Operation

1.6.1 All thermal and hydro (except those upto three hours pondage) generating units shall operate under Restricted governor mode of operation with effect from 01.04.2019.

1.6.2 Any exemption from the above, other than that already provided for in Chapter-5, may be granted only by the Commission for which the concerned agency shall file a petition in advance.]

1.7 Charge/Payment for Reactive Energy Exchanges

1.7.1 The rate for charge/payment of reactive energy exchanges (according to the scheme specified in section 6.6 shall be at such rate in paise/kVArh w.e.f such date, and shall 1 Subs. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P.

dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “1.6 Free Governor Mode of Operation

1.6.1 All thermal and hydro (except those with zero pondage) generating units shall operate under free governor mode of operation with effect from the date to be separately notified by the Commission.

1.6.2 Any exemption from the above may be granted only by the Commission for which the concerned agency shall file a petition in advance.

1.6.3 Gas turbine/Combined Cycle Power Plants shall be exempted from sections 4.8.3, 4.8.4, 5.3.6, 5.3.7, 5.3.8 and 5.3.9 till the Commission reviews the situation and provides otherwise.” 4 Compendium of HPERC Regulations, March 2021 be escalated at such rate per year thereafter, as the Commission may determine in this behalf.

1.8 Exemptions

1.8.1 Any exemption from provisions of HPEGC shall be allowed by the Commission only on receipt of a petition from the concerned User giving reasons /justification for exemption sought therein. The Commission may invite comments from various stakeholders before allowing any such exemption.

1.9 Definitions after

1.9.1 In the HPEGC, the following words and expressions shall, unless the subject matter or context otherwise requires or is inconsistent therewith, bear the following meaning:

Item Definition Act The Electricity Act, 2003(Central Act No. 36 of 2003), including amendments thereto.

1 [Area Load Despatch Centre (ALDC) A Load Despatch Centre established by the distribution licensee operating in the State to carry out the relevant operating directives issued by SLDC to the distribution licensee and to assist SLDC for safe and integrated operation of the concerned network.]

Agency A term used in various sections of HPEGC to refer to SGS/Licensee that utilize the IaSTS.

Authority Central Electricity Authority referred to in sub-section (1) of Section 70 of the Act.

Automatic Voltage Regulator (AVR) A continuously acting automatic excitation control system to control the voltage of a Generating Unit measured at the generator terminals.

Backing Down Reduction of generation by a Generating Unit on instructions from SLDC under abnormal conditions such as high frequency, low system demand or network constraints.

BBMB Bhakra Beas Management Board Beneficiary A person who has share in an ISGS, SSGS and BBMB generating stations.

Black Start Procedure The procedure necessary to recover the grid from a partial or a total blackout.

BIS The Bureau of Indian Standards 2[Bulk Consumer Any consumer who avails supply at 33 kV or above] 1 Ins. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418.

2 Ins. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 Compendium of HPERC Regulations, March 2021 5 Captive Generating Plant (CGP) A power plant set up by any person to generate electricity primarily for his own use and includes a power plant set up by any co-operative society or association of persons for generating electricity primarily for use of members of such co-operative society or association.

Capacitor An electrical facility provided for generation of reactive power.

CEA Central Electricity Authority.

CERC The Central Electricity Regulatory Commission Central Transmission Utility (CTU) Any Government company, which the Central Government may notify under sub-section (1) of Section 38 of the Act.

Commission / HPERC The Himachal Pradesh Electricity Regulatory Commission Connection Agreement An Agreement setting out the terms relating to a connection to and /or use of the IaSTS.

Connection Point A point at which a User’s Plant and /or Apparatus connects to the Intra-State Transmission System.

Data Acquisition System (DAS) A device provided to record the sequence of operations in time, of the relays /equipments / system parameters at a location.

Demand The demand of Active Power in MW and Reactive Power in MVAR of electricity unless otherwise stated.

Despatch Schedule The, ex-power plant, net MW and MWH output of a generating station, scheduled to be exported/despatched to the Grid from time to time.

Disturbance Recorder (DR) A device provided to record the behaviour of the pre-selected digital and analog values of the system parameters during an Event.

1[Distribution Licensee A licensee authorized under section 14 of the Act to operate and maintain a distribution system for supplying electricity to the consumers in his area of supply. At present "Himachal Pradesh State Electricity Board Limited (HPSEBL)" is the distribution licensee in the State.]

Drawl Schedule The ex-power plant MW that a licensee/ User is scheduled to receive from SSGS/ISGS and BBMB generating stations, including bilateral exchanges from time to time.

Event An unscheduled or unplanned occurrence in the grid including faults, incidents and breakdowns.

Event Logger (EL) A device provided to record the sequence of operation in time, of the relays/equipments at a location during occurrence of an Event.

Ex-Power Plant MW/MWH Net MW/MWH output of a generating station, after deducting auxiliary consumption and transformation losses.

1 Ins. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418.

6 Compendium of HPERC Regulations, March 2021 Extra High Voltage (EHV) Where the voltage exceeds 33,000 volts under normal conditions subject, however, to the percentage variation allowed by the Authority.

Fault Locator (FL) A device provided at the end of a transmission line to measure/ indicate the distance at which a line fault may have occurred.

Flexible Alternating Current Transmission (FACT) Facilities that enable power flows on A.C. lines to be regulated, to control loop flows, line loadings, etc.

Forced Outage An outage of a Generating Unit or a transmission facility due to a fault or other reasons which has not been planned.

Generating Company 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.

Generating Unit An electrical Generating Unit coupled to a turbine within a Power Station together with all Plant and Apparatus at that Power Station (up to the Connection Point).

Good Utility Practices 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.

Governor Droop 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 free governor action to change its output from zero to full load.

Grid Standards Grid Standards specified by the Authority under clause (d) of Section 73 of the Act.

High Voltage (HV) Where the voltage exceeds 650 Volt but not exceeds 33,000 volts under normal conditions subject, however, to the percentage variation allowed by the Authority.

IEC The International Electro-technical Commission Independent Power Producer (IPP) A generating company not owned/controlled by the Central/State Government.

Indian Electricity Grid Code (IEGC) A document describing the philosophy and the responsibilities for planning and operation of Indian power system specified by the CERC in accordance with sub-section 1(h) of Section 79 of the Act.

Inter-State Generating Station (ISGS) A Central/other generating station in which two or more than two States have a share and whose scheduling is to be coordinated by the Regional Load Dispatch Centre.

Compendium of HPERC Regulations, March 2021 7 Inter-State Transmission System (ISTS) Inter-State Transmission System includes:

(i) any system for the conveyance of electricity by means of a main transmission line from the territory of one State to another State.

(ii) the conveyance of electricity across the territory of an intervening State as well as conveyance within the State which is incidental to such Inter-State transmission of energy.

(iii) the transmission of electricity within the territory of State on a system built, owned, operated, maintained or controlled by CTU.

Intra-State Transmission System (IaSTS) The Intra-State Transmission System shall include the entire transmission network within the State excluding the Inter-State Transmission System.

Licensee A person who has been granted a licence under Section 14 of the Act.

Load The MW/MWH consumed by a utility/ installation.

Long-term open access customer A long-term open access customer as defined under the HPERC (Terms and Conditions for Open Access) Regulations, 2005 as amended from time to time.

Maximum Continuous Rating (MCR) The normal rated full load MW output capacity of a Generating Unit which can be sustained on a continuous basis at specified conditions.

National Grid The entire inter-connected electric power network of the country, which would evolve after inter-connection of Regional grids.

Non-Conventional Energy Sources (NCES) NCES shall mean generating plants based on non-conventional energy sources e.g. solar, wind, bagasse, biomass, bio-gas, industrial waste, municipal waste and small hydro generating stations.

Net Drawal Schedule The drawl schedule of a beneficiary after deducting the apportioned transmission losses (estimated).

Operation A scheduled or planned action relating to the operation of a System.

Reactor An electrical plant specifically designed to absorb Reactive Power.

Regional Power Committee (RPC) 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.

Regional Grid The entire synchronously connected electric power network of the concerned Region, comprising of ISTS, ISGS and Intra-state systems.

Regional Load Despatch Centre (RLDC) The Centre established under sub-section (1) of Section 27 of the Act.

Short Term Open Access Customer A short-term open access customer as defined under the HPERC (Terms and Conditions for Open Access) Regulations, 2005 as amended from time to time.

Single Line Diagram 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.

8 Compendium of HPERC Regulations, March 2021 Site Common Drawing Drawings prepared for each Connection Point, which incorporates layout drawings, electrical layout drawings, common protection/control drawings and common service drawings.

Spinning Reserve 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 dispatch instruction or instantaneously in response to a frequency drop.

State Energy Account 1[An Account, in terms of the energy quantum as well as the amounts payable/receivable by various State Entities for the billing and settlement of various charges, to be prepared by SLDC on the basis of transactions during the period to which such account relates.]

2[State Entity Such person who is in the SLDC control area and whose metering and energy accounting is done at the state level and as described in more detail in sub-para 6.5.5 of para 6.5 under Chapter-6 of this Code.

State Power Grid The Intra-State Transmission System/network owned by the State Transmission Utility (STU)/Transmission Licensee(s) and/or the EHV/33 kV Distribution System/network owned by the distribution licensee(s) within the State.]

State Pool Account 3 [The account which shall be opened, maintained and operated by the SLDC for receiving/making payments on account of Charges for Deviation, Additional Charges for Deviation, and interest if any, based on the weekly deviation statements to be prepared by SLDC in accordance with the provisions of Himachal Pradesh Electricity Regulatory Commission (Deviation Settlement Mechanism and related matters) Regulations, 2018.]

State Government Government of the State of Himachal Pradesh.

State Load Dispatch Centre (SLDC) A Centre established by the State Government under sub-section (1) of Section 31 of the Act.

State Transmission Utility (STU) The Board or the Government Company specified as such by the State Government under sub-section (1) of Section 39 of the Act.

1 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “A State energy account, for the billing and settlement of ‘Capacity Charge’, ‘Energy Charge’, ‘UI Charge’ and ‘Reactive Charge.” 2 Ins. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418.

3 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “State account for:

(i) payments regarding unscheduled- interchanges (UI Account) or

(ii) reactive energy exchanges (Reactive Energy Account), as the case may be.” Compendium of HPERC Regulations, March 2021 9 State Sector Generating Stations (SSGS) 1[Generating Stations connected with the State Power Grid including IPP, Captive Generating Plant, Co-Generators and NCES.

However for the purpose of scheduling/dispatching the provisions made in Chapter-6 shall be applicable.]

Static VAR Compensator (SVC) An electrical facility designed for the purpose of generating or absorbing Reactive Power.

Time Block Block of 15 minutes each for which special energy Meters record specified electrical parameters and quantities with first time block starting and 00:00 Hrs;

2[Provided that the Commission may revise the duration of time block to 5 minutes, or any other duration, from the date to be notified by it from time to time.]

Transmission Licensee 3[A licensee authorized under section 14 of the Act to establish or operate transmission lines. At present "Himachal Pradesh Power Transmission Corporation Limited (HPPTCL)" is transmission licensee in the State.]

Transmission Planning Criteria The policy, standards and guidelines issued by the CEA for the planning and design of the Transmission system.

User 4[A term used in various sections of HPEGC to refer to the person/agencies using the IaSTS and shall also include distribution licensee and/or any other person/agency not using IaSTS but using any other component of State Power Grid, as the context may require and as more particularly identified in each section of HPEGC.]

Note: 1. Terms defined in singular shall be considered to apply for plural also.

2. Words and expressions used and not defined in this Code but defined in the Act shall have the same meanings assigned to them in the said Act. Subject to the above, expressions used herein but not specifically defined in this Code or in the Act shall have the meaning as is generally assigned in the electricity industry.

1 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “Generating Stations connected with the IaSTS including IPP, Captive Generating Plant, Co-Generators and NCES. For the purpose of scheduling/dispatching, SSGS shall include Hydroelectric Projects only above 5 MW capacity.” 2 Sub. for sign “.” and added proviso vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418.

3 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “A Licence granted under Section 14 of the Act to transmit electricity.” 4 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “A term used in various sections of the HPEGC to refer to the persons/agencies using the IaSTS, as more particularly identified in each section of HPEGC.” 10 Compendium of HPERC Regulations, March 2021

CHAPTER -2 ROLE OF VARIOUS ORGANSIATIONS & THEIR LINKAGES

2.1 Introduction

2.1.1 In the light of the provisions of the Electricity Act, 2003, it has become necessary to specify the role of State Load Dispatch Centre (SLDC), State Transmission Utility (STU), Regional Load Dispatch Centre (RLDC), Regional Power Committees (RPC), the Central Electricity Authority (CEA), the State Co-ordination Forum, the Central Transmission Utility (CTU) etc. and their organizational linkages so as to facilitate development and smooth operation of State Power Grid and the Regional Grid. This Chapter defines the functions of the various organizations connected with the functioning and operations of the State Power Grid, as envisaged in Electricity Act, 2003 and rules and regulations made thereunder.

2.2 Regional Load Dispatch Centre

2.2.1 The RLDC is the apex body to ensure integrated operation of the power system within the concerned regional grid. In respect of wheeling, optimum scheduling and dispatch of electricity through Inter- State transmission lines, the RLDC shall comply with the principles, guidelines and methodology as specified by the CERC in the IEGC or otherwise. The RLDC may give such directions and exercise such supervision and control as may be required for ensuring integrated Grid operations and for achieving the economy and efficiency in the operation of the power system in the region under its control. All licensees, generating companies, and any other person connected with and/or utilizing the ISTS shall comply with the directions issued by the RLDC.

2.3 Regional Power Committee

2.3.1 Regional Power Committees have been constituted by resolution dated 25.05.2005 of Central Government for all the five regions for facilitating the integrated operation of the power system in each region. Regional Power Committee, established by the Government of India for the region may, from time to time, issue guidelines on matters concerning the stability and smooth operation of the Grid and economy and efficiency in the operation of the power system in that region. Such directions shall be binding on all the entities covered by this Code to the extent they are applicable to the State Power Grid.

2.3.2 RPC would perform the following functions to facilitate the stability and smooth operation of the integrated grid:

(a) To undertake Regional Level operation analysis for improving grid performance.

(b) To facilitate Inter-State/Inter-regional transfer of power.

(c) To facilitate all functions of planning relating to Inter-State/Intra-State Transmission System with CTU/STU.

(d) To coordinate planning of maintenance of generating machines of various generating companies of the region including those of Interstate generating Compendium of HPERC Regulations, March 2021 11 companies supplying electricity to the Region on annual basis and also to undertake review of maintenance programme on monthly basis.

(e) To undertake planning of outage of transmission system on monthly basis.

(f) To undertake operational planning studies including protection studies for stable operation of the grid.

(g) To undertake planning for maintaining proper voltages through review of reactive compensation requirement through system study committee and monitoring of installed capacitors.

(h) To evolve consensus on all issues relating to economy and efficiency in the operation of power system in the region.

2.4 Central Transmission Utility

2.4.1 Power Grid Corporation of India Limited (PGCIL) is the Central Transmission Utility as notified by Government of India. CTU is responsible for the entire Inter- State transmission of electricity and in that context; the relevance of this Code shall be limited to the connectivity between the Intra-State Transmission System and the Inter-State Transmission System.

2.5 Central Electricity Authority

2.5.1 The Central Electricity Authority, established under Section 3 of the Electricity (Supply) Act, 1948, continues to operate as the Central Electricity Authority under the provisions of Section 70(2) of the Act.

2.5.2 Under Section 3(4) of the Act, CEA would prepare and notify once in five years a National Electricity Plan in accordance with the National Electricity Policy notified by the Central Government.

2.5.3 The Central Electricity Authority in accordance with the provisions of Section 177 of the Act may make regulations, which may provide for the following matters:

(a) Grid Standards as stipulated in Section 34 of the Act.

(b) Measures relating to safety and Electricity Supply as stipulated in Section 53 of the Act.

(c) Installation and operation of meters as stipulated in Section 55 of the Act.

(d) Technical standards for construction of electrical plants and electric lines and connectivity to the Grid and all other matters as stipulated in Section 73 of the Act.

(e) The form and manner in which and the time at which the State Government and Licensees shall furnish statistics, returns or other information under Section 74 of the Act.

(f) Any other matter as may be specified under the Act.

2.5.4 Irrespective of whether the provisions under the regulations stated above are explicitly provided for or not in this Code, they shall apply to all the entities covered by this Code to the extent it applies to them.

12 Compendium of HPERC Regulations, March 2021

2.6 State Load Dispatch Centre

2.6.1 The State Government shall establish a center to be known as the State Load Dispatch Centre for the purpose of exercising the powers and discharging the functions under sub- section (1) of Section 32 of the Act. This State Load Dispatch Centre shall be operated by a Government company, or any authority or corporation established or constituted by or under any State Act, as may be notified by the State Government. Till such time the State Government notifies the same, STU shall operate SLDC.

2.6.2 The SLDC shall be the apex body to ensure integrated operation of the power system in the State. The SLDC shall be responsible for:

(a) Optimum scheduling and despatch of electricity within the State, in accordance with the contracts entered into with the licensees or the generating companies operating in the State.

(b) Monitoring of grid operations.

(c) Keeping accounts of the quantity of electricity transmitted through the State Power Grid.

(d) Supervision and control over the Intra-State Transmission System.

(e) Carrying out real time operations for grid control and despatch of electricity within the State through secure and economic operation of the State Power Grid in accordance with the Grid Standards and the Grid Code.

2.6.3 In addition to above functions under the Act SLDC shall also discharge the following function as per the provisions of this Grid Code:

(a) System operation and control covering contingency analysis and operational planning on a real time basis;

(b) Re-scheduling of despatch and drawl schedules as per system conditions and request of Generating Stations and Distribution Licensees;

(c) System restoration following grid disturbances;

(d) Specifying metering points and data collection;

(e) Compiling and furnishing data pertaining to system operation;

1 [(f) Operation of State Deviation pool account and State reactive energy account;]

(g) In case of open access in Intra-State transmission, the SLDC shall be the nodal agency for the short-term open access. The procedure and modalities in regard to short-term Open Access shall be as per the HPERC (Terms and Conditions for Open Access) Regulations, 2005 as amended from time to time.

2.6.4 SLDC may give such direction and exercise such supervision and control as may be required for ensuring the integrated Grid operation and for achieving the maximum 1 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “Operation of State UI pool account and State reactive energy account;” Compendium of HPERC Regulations, March 2021 13 economy and efficiency in the operation of the State Power System. All Users shall comply with the directions issued by the SLDC.

2.6.5 The SLDC shall ensure compliance of the directions of the RLDC by issuing suitable directions to the Users.

2.6.6 If any dispute arises with reference to the quality of electricity or, safe, secure and integrated operation of the State Power Grid or in relation to any direction given by the SLDC, it shall be referred to the Commission for decision. Pending the decision of the Commission, the Licensee or Generating Company shall comply with the directions of the SLDC.

2.6.7 If any licensee, generating company or any other person fails to comply with the directions issued by SLDC, he shall be liable to a penalty, as per the provisions of the Act.

2.7 State Transmission Utility

2.7.1 The State Transmission Utility as notified by the State government shall be deemed to be a transmission licensee under Section 14 of the Electricity Act, 2003.

2.7.2 As per the Act, the STU shall be responsible for:

(a) Transmission of electricity through Intra-State Transmission System.

(b) Discharging all functions of planning and coordination relating to Intra-State Transmission System with:

(i) Central Transmission Utility,

(ii) State Government,

(iii) Generating Companies,

(iv) Regional Power Committee,

(v) Central Electricity Authority,

(vi) All Licensees,

(vii) Any other person notified by the State Government in this behalf.

(c) Ensuring development of an efficient, coordinated and economical system of Intra-state transmission lines for smooth flow of electricity from a generating station to the load centers.

(d) Providing non-discriminatory open access to its transmission system for use by:

(i) any licensee or generating company on payment of the transmission charges, or

(ii) any customer, as and when such open access is provided by the Commission under sub-section (2) of Section 42 of the Act, on payment of the transmission charges and a surcharge thereon, as may be specified by the Commission.

2.7.3 STU, in discharge of its functions under the Act and this Code, shall take into consideration recommendations, if any, of the State Co-ordination Forum.

14 Compendium of HPERC Regulations, March 2021

2.7.4 STU shall act as nodal agency for all long-term open access customers.

2.8 Transmission Licensee

2.8.1 Every Transmission Licensee shall comply with such technical standards of construction of electrical plants, electric lines and connectivity with the grid and safety requirements as specified by the CEA, and follow the principles and procedures as specified in this Code and /or Indian Electricity Grid Code as applicable to the Intra-State Transmission System.

2.8.2 It shall be the duty of the transmission licensee:

(a) to maintain and operate the part of the IaSTS which are licensed to him and comply with the directions of RLDC and SLDC as the case may be;

(b) to provide non-discriminatory open access in pursuance of open access to its transmission system for use by any licensee or generating company or other Users on payment of the charges as determined by the Commission.

2.9 Generating Company

2.9.1 Any generating company may establish, operate and maintain a generating station without obtaining a licence under the Act if it complies with the technical standards relating to connectivity with the grid referred to in clause (b) of Section 73 of the Act.

2.9.2 As per the provisions of Section 10 of the Act, the duties of a generating company shall be:

(a) to establish, operate and maintain generating stations, tie-lines, sub-stations and dedicated transmission lines connected therewith in accordance with the provisions of the Act or the rules or regulations made thereunder;

(b) to supply electricity to any licensee in accordance with the Act and the rules and regulations made thereunder and may, subject to the regulations made under sub-section (2) of Section 42, supply electricity to any consumer;

(c) to submit technical details regarding its generating stations to the Appropriate Commission and the Authority;

(d) to co-ordinate with the Central Transmission Utility or the State Transmission Utility, as the case may be, for transmission of the electricity generated by it.

2.10 Distribution Licensee

2.10.1 Any person granted licence under Section 14 of Act for distribution of electricity in a particular area should develop and maintain an efficient, co-ordinate and economical distribution system for supplying electricity to the consumers in his area of supply in accordance with the provisions of the Act.

2.10.2 It shall also be the duty of the distribution licensee:

Compendium of HPERC Regulations, March 2021 15

(a) to provide open access to the consumers in its area of supply in such phases as may be specified by the Commission on payment of wheeling charge, surcharge and additional surcharge as may be determined by the Commission;

(b) to give supply of electricity, on an application by the owner or occupier of any premises, within a period of one month after receipt of the application requiring such supply:

Provided that where such supply requires extension of distribution mains, or commissioning of new sub-stations, the distribution licensee shall supply the electricity to such premises immediately after such extension or commissioning or within such period as may be specified by the Commission.

2.11 State Coordination Forum

2.11.1 As per Section 166 (4) of the Act, Government of Himachal Pradesh shall constitute a State Coordination Forum for smooth and coordinated development of the power system in the State. State Coordination Forum may give its recommendations on matters related to overall planning and development of the State Power System.

2.12 Himachal Pradesh Electricity Regulatory Commission

2.12.1 The functions of HPERC relevant to HPEGC are:

(a) To determine the rates, charges and terms for the use of the transmission facilities of licensees.

(b) To specify the fees and charges payable to SLDC.

(c) To issue directions on matters of non-compliance of HPEGC or any dispute referred to it regarding interpretation of any provisions of the HPEGC.

(d) To issue transmission/distribution licences.

(e) To issue amendments to the HPEGC as and when required.

2.13 Government of Himachal Pradesh

2.13.1 The State Government may issue directions to SLDC; to take such measures as may be necessary for maintaining smooth and stable transmission and supply of electricity in the State. SLDC shall abide by such directions if they are not inconsistent with the provisions of the Act and this Code.

CHAPTER-3 PLANNING CODE FOR INTRASTATE TRANSMISSION

3.1 Introduction

3.1.1 In accordance with Section 39(2)(b) of Electricity Act, 2003, the State Transmission Utility (STU) shall discharge all functions of planning and coordination relating to Intra-State Transmission System in coordination with CTU, State Governments, Generating Companies, Regional Power Committees, Central Electricity Authority (CEA), licensees and any other person notified by the State Government in this behalf. The Act also envisages role of Generating Companies and CTU, apart from 16 Compendium of HPERC Regulations, March 2021 the Central Government and State Governments in the process of transmission planning at various levels.

3.1.2 This Planning Code comprises various aspects of planning and development relating to Intra-State Transmission System.

3.2 Objective

3.2.1 The objectives of Planning Code are as follows:

(a) To specify the principles, procedures and criteria to be applied in the planning and development of IaSTS.

(b) To promote co-ordination amongst all Users in any proposed development of the IaSTS.

(c) To provide methodology and information exchange requirements amongst SLDC, STU and Users in the planning and development of IaSTS.

3.3 Scope

3.3.1 This Planning Code applies to STU, other licensees, State Sector Generating Stations (SSGS), connected to and/or using and/or involved in developing the IaSTS including those intending to connect their system to IaSTS. This shall also apply to the other Stakeholders like CTU, Generating Stations connected to (or intending to connect) to the Inter State Transmission System by laying transmission lines through the territory of Himachal Pradesh.

3.4 Planning Policy

3.4.1 The STU shall prepare and submit to the Commission a long-term transmission system plan (time span 5 years) for the expansion of the IaSTS to meet the future demand within six months from the date of notification of this Grid Code. In preparing the above plan, the following shall be considered in addition to the data of authentic nature collected from and in consultation with SSGS, licensees, SLDC, etc.:

(a) Perspective plan for development of the electricity system formulated by the CEA under the provisions of clause (a) of Section 73 of the Act.

(b) Electric Power Survey of India report of the CEA.

(c) Transmission Planning Criteria and Guidelines issued by the CEA.

(d) National Electricity Policy issued by the Government of India to the extent applicable for the development of Intra-State Transmission System.

(e) Recommendations/inputs, if any, of the Regional Power Committee and the State Coordination Forum.

(f) Any other information/data source suggested by the Commission.

3.4.2 The STU shall submit to the Commission an updated long-term transmission system plan by 28 th February every year taking care of the revisions in electricity load Compendium of HPERC Regulations, March 2021 17 projections, additions in the generation capacity and all (approved/pending) applications for open access.

3.4.3 The primary responsibility of load forecasting of a particular supply area shall be that of the respective Distribution Licensees. The Distribution Licensees shall forecast the peak load and energy requirement of their areas for each category of loads for the succeeding 5 years and submit the same annually by 31 st December to STU along with forecast methodology, assumptions and daily load curve on which the forecasts are based. These forecasts shall be reviewed annually or whenever major changes are made in the existing system and updated accordingly. While indicating requirements of a single consumer (one MW or higher), the Distribution Licensee shall personally satisfy itself, as to the degree of certainty of the demand materializing. STU shall apply an appropriate diversity factor and also satisfy itself regarding the probability of materialization of bulk loads of consumers with demands above 1MW in consultation with concerned Distribution Licensee.

The Generating Companies intending to connect their stations with the IaSTS and those intending to connect the generating stations with the Inter State Transmission System by erecting transmission lines(whether dedicated or otherwise) during succeeding five years shall also submit complete details to the STU as well as to Government of H.P. at the earliest possible, but in any case before applying for open access to STU/CTU or seeking transmission licence for erection of any line in Himachal Pradesh.

3.4.4 STU in consultation with SLDC and the concerned Distribution Licensee, may review the methodology and assumptions, used in making the load forecast and shall further re-work:

(a) Projected loads and losses of the system, the net energy requirement and peak load requirement at generation end. The installed capacity, peak availability, surplus and deficit both in generation and demand shall also be worked out by STU.

(b) Additional transmission capacity required after taking into account, the existing capacity, projects under construction, proposed projects, availability from captive power plants, co-generators & NCES, bilateral trades and also share of the State from Central sector Power Projects both within and outside the State.

STU shall also examine the economic, technical and environmental aspects of all the available alternatives.

3.4.5 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 planning studies would be finalised by STU based on the inputs received from various stakeholders i.e. generating companies and distribution licensees, SLDC and any committee created for the transmission planning purposes by the Commission.

3.4.6 In case long term open access cannot be allowed due to system constraints, the prospective open access customer may request STU to carry out system studies to identify system strengthening requirements and cost estimates. In case of Long Term 18 Compendium of HPERC Regulations, March 2021 Open Access applications requiring any strengthening in the Inter-State Transmission System to absorb/evacuate power beyond IaSTS, the applicant shall also coordinate with CTU.

3.4.7 The long term transmission system plan prepared by STU shall contain a chapter on additional transmission requirement, which may include not only Intra-State transmission lines, but also additional equipment requirement such as transformers, capacitors and reactors, etc.

3.4.8 The long term transmission system plan shall also indicate the action taken to fulfill the additional requirement and actual progress made on new schemes. The planning report and power map shall be made available to any party interested for making investments decision/ connection decisions to the IaSTS.

3.4.9 As voltage management plays an important role in the Intra- State transmission of energy, special attention shall be accorded to planning of capacitors, reactors, SVC and Flexible Alternating Current Transmission Systems (FACTS), etc.

3.4.10 Based on the Plan prepared by the STU, other Transmission Licensees/ Distribution Licensees shall plan their systems to further evacuate power from the IaSTS.

3.4.11 The Inter-State Transmission System and associated Intra-State Transmission System are complementary and inter-dependent and therefore planning of one affects the planning and performance of the other. The STU shall accordingly plan the development of associated Intra-State Transmission System in line with the development of the Inter-State Transmission System. However, it is expected that CTU shall also duly consider the constraints of transmission corridors in the State while planning the Inter State Transmission System, so as to ensure the optimum utilization of the scarce transmission corridors in the State.

3.4.12 Generating Companies intending to evacuate the power from the generating stations through Intra State Transmission System shall also duly co-ordinate in advance with STU and shall also abide by all such requirements as may be intimated by STU keeping in view the constraints of transmission corridors in the State.

In case of any difference of opinion in this regard for the system to be erected in Himachal Pradesh the matter shall be suitably referred to HPERC.

3.4.13 STU’s planning department shall use load flow, short circuit, transient and steady state stability study, relay coordination study and other techniques for transmission system planning.

3.4.14 STU’s planning department shall simulate the contingency and system constraint conditions for the IaSTS and incorporate the results in the long-term transmission system plan.

3.4.15 STU should maintain a historical database based on operational data supplied by SLDC and use advance software tools for demand forecasting.

3.4.16 STU shall extend full support to CTU to finalise the annual planning corresponding to a 5 year forward term for identification of major Inter-State Transmission System Compendium of HPERC Regulations, March 2021 19 including inter-regional schemes which shall fit in with the long term plan developed by CEA.

3.4.17 STU shall furnish the requisite planning data to CTU as required by it from time to time.

3.5 Planning Criterion

3.5.1 The planning criterion are based on the security philosophy on which the IaSTS has been planned. The security philosophy may be as per the Transmission Planning Criterion and other guidelines as given by CEA. The general criterion shall be as detailed below:

(a) As a general rule, the IaSTS 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:

(i) Outage of 66 kV/132 kV D/C Line or,

(ii) Outage of 220 kV D/C Line or,

(iii) Outage of 400 kV S/C Line or,

(iv) Outage of Single Inter-Connecting Transformer or,

(v) Outage of one pole of HVDC Bipole line or,

(vi) Outage of a 765 S/C line.

(b) The above contingencies shall be considered assuming a pre-contingency system depletion (planned outage) of another 66kV/132 kV D/C line or 220 kV S/C line or 400 kV S/C line in another corridor and not emanating from the same substation. All the Generating Units may operate within their reactive capability curves and the network voltage profile shall also be maintained within voltage limits specified.

(c) In exceptional cases like transmission corridors constraints and environment concerns, the STU may deviate from the above stated criterion provided that the STU shall duly bring out the details of deviations alongwith the reasons thereof in this regard while submitting the long term transmission system plan as per section 3.5.

3.5.2 The IaSTS shall be capable of withstanding the loss of most severe single system in feed without loss of stability.

3.5.3 Any one of the events defined above shall not cause:

(a) Loss of supply;

(b) Prolonged operation of the system frequency below and above specified limits;

20 Compendium of HPERC Regulations, March 2021

(c) Unacceptable high or low voltage;

(d) Unacceptable overloading of IaSTS elements.

3.5.4 The Transmission System should therefore have sufficient additional capacities and redundancies to cater to the above needs.

3.5.5 STU shall carry out planning studies for Reactive Power compensation of IaSTS including reactive power compensation requirement at the SSGS’s Switchyard.

3.6 Planning Data Requirement

3.6.1 To enable the STU to discharge its responsibilities to conduct system studies and prepare long term transmission system plan, Users shall provide the required planning data/information pertaining to their systems in the formats as may be devised by STU. In devising these formats, the STU shall also be guided by the formats, developed under the provisions of the Grid Code specified by the Central Commission under clause (h) of sub-section (1) of Section 79 of the Electricity Act,

2003.

3.6.2 The generating companies connected or those intending to connect their stations to the IaSTS as well as those connected to or intended to connect their stations to the ISTS through transmission lines(dedicated or otherwise) and transmission licensee erecting or intended to erect transmission lines in the territory of Himachal Pradesh shall also provide requisite planning data or information pertaining to their stations in the formats as may be devised by STU. The CTU shall also provide similar data for the system pertaining to its system connected to or to be connected to any of the transmission lines passing through territory of Himachal Pradesh in the formats as may be devised by STU in-accordance with section 3.6.1.

3.6.3 The one time data shall be submitted by all the Users to STU within 4 months from the date of notification of this Grid Code. Users shall thereafter submit yearly data to STU latest by 31 st December for the ensuing year.

3.6.4 STU shall supply the data as may required by the Users for the coordinated planning, design and operation of their plants and systems with the transmission system.

3.7 Implementation of Transmission Plan

3.7.1 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 Users. The completion of these works, in the required time frame, shall be ensured by STU.

1 [3.7.2 Users shall mean any person/agency using IaSTS (or intending to use IaSTS) and shall also include a person/agency using the ISTS(or intending to use the ISTS) through their lines (or otherwise) erected or to be erected in State of Himachal Pradesh.]

1 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “Users shall mean any person/agency using IaSTS (or intending to use IaSTS) and shall also include a person/agency using the ISTS(or intending to use the ISTS) through their transmission lines(or otherwise) erected or to be erected in State of Himachal Pradesh.” Compendium of HPERC Regulations, March 2021 21

CHAPTER-4 CONNECTIVITY CONDITIONS CODE

4.1 Introduction

4.1.1 The Connectivity Conditions specify the minimum technical and design criteria which shall be complied with by STU and any User connected to, or seeking connection to the IaSTS. This chapter also sets out the procedures by which STU shall ensure compliance by all Users with the above criteria as a pre-requisite for the establishment of an agreed connection.

4.2 Objective

4.2.1 The connection conditions are designed to ensure that:

(a) The basic rules for connections are complied with and all Users are treated in a non-discriminatory manner.

(b) Any new or modified connections, when established, shall neither suffer unacceptable effects due to its connection to IaSTS nor impose unacceptable effects on the system of any other connected User.

(c) The ownership and responsibility for all the equipments is clearly specified in a schedule (Site Responsibility Schedule) for every site, where a connection is made.

4.3 Scope

4.3.1 The Connectivity Conditions Code shall apply to STU and all Users connected to and/or involved in developing the State Power Grid and includes Generating Companies/ Transmission Licensee/Distribution Licensee, which are engaged in or are intending to engage in generation/ transmission /distribution of power through the State Power System.

4.4 Procedure for connection

4.4.1 Prior to being connected to the IaSTS, User shall ensure that all the necessary conditions outlined in the HPEGC in addition to mutually agreed requirements have been complied by it.

4.4.2 Any User seeking to establish new or modified arrangements for connection to and/or use of the assets of the Intra-State Transmission System, shall submit the following report, data and undertaking along with an application on standard format to STU along with the following details:

(a) Report stating the purpose of the proposed connection and/or modification, transmission licensee in whose system the connection is proposed, connection point, description of apparatus to be connected or modification to the apparatus already connected and beneficiaries of the proposed connection.

(b) Construction schedule and target completion date.

(c) Undertaking that the User shall abide by HPEGC, Indian Electricity Rules and various standards including Grid Connectivity Standards made pursuant to the Act.

4.4.3 The STU shall forward a copy of the application to the Transmission Licensee in whose system the connection is being sought, to SLDC and to every Transmission 22 Compendium of HPERC Regulations, March 2021 Licensee within the State whose transmission system is likely to be affected by such application.

4.4.4 The STU on receipt of application, complete in all respects and after considering all suggestions and comments from the parties identified in section 4.4.3 make a formal offer to the applicant within thirty days from the date of receipt of all details along with the proposed changes, if any. The offer shall be subject to obtaining the required consents, approvals, and permissions for right of way or any other requirements as per the provisions of this Grid Code, Electricity Act, 2003 and rules and regulations made thereunder. A copy of the offer shall also be furnished to the transmission licensee in whose system the connection is being sought.

4.4.5 The offer shall specify, and take into account, any works required for the extension or reinforcement of the existing transmission system and/or supply system as necessitated by the applicant’s proposal.

4.4.6 The estimated time schedule for completion of such works should also be specified in the offer, taking into account the time required to obtain statutory clearances etc., wherever necessary. In respect of offers for modifications to the existing connections, the offers shall also take into account the terms of the existing Connection Agreement, if any.

4.4.7 A User whose development/connection requires the STU/Transmission Licensee to obtain any consents, approvals, permissions, and right of ways or compliance with any other requirements mentioned in the HPEGC shall:

(a) Provide necessary assistance, supporting information or evidence; and

(b) Ensure attendance by such witnesses as the transmission licensee may reasonably request.

4.4.8 The User shall give its consent to the offer and submit the same to STU within a fortnight from the date the offer was made by the STU. Final decisions on applications for connection to the IaSTS shall be provided by the STU within 45 days from the date of submission of the consent to it by the User.

4.4.9 If the nature of complexity of the proposed development is such that the specified time limit for making the offer is not considered adequate, the STU shall make a preliminary offer within the specified time limit indicating the necessity and the extent of further time required for more detailed analysis of the issues.

4.4.10 The STU shall make a revised offer, upon request by a User, if necessitated by changes in data furnished earlier by the User.

4.4.11 The STU shall, upon compliance of the required conditions by the concerned User, notify that the User can be connected to the IaSTS.

4.4.12 The applicant and the Transmission Licensee, in whose system the connection is being sought, shall enter into a Connection Agreement on acceptance of the offer by the applicant. The copy of the Connection Agreement shall also be provided to the STU and the SLDC by the Transmission Licensee.

4.4.13 All offers (other than preliminary offers) including revised offers shall remain valid for a period of 60(sixty) days from the date of issue of the offer. In the event of an offer becoming invalid or rejected by the applicant, STU shall not be required to consider any further application from the same applicant within twelve months from Compendium of HPERC Regulations, March 2021 23 the date of offer unless the new application is substantially different from the original application with regard to system changes.

4.4.14 The User shall furnish the relevant Planning Data to the STU within thirty days of acceptance of an offer or such longer period as the STU may agree in a particular case.

4.4.15 The STU may reject any application for connection to and/or use of the IaSTS under the following conditions:

(a) If such proposed connection is likely to cause breach of any of the provisions of Transmission Licence/Grid Code/ IEGC/Grid Standards and Technical Standards set out by CEA/Electricity Act, 2003, or any provision of planning criteria/any covenants/deeds/regulations by which the STU is bound, or

(b) If the applicant fails to give the undertakings in accordance with section

4.4.2(c) of this chapter.

4.4.16 In the event of any dispute with regard to rejection of application by the STU, the User may approach the Commission.

4.5 Connection Agreement

4.5.1 All Users connected to or seeking connection to the IaSTS shall enter into a connection agreement with the STU/Transmission Licensee. However, in respect of existing connections a relaxation of one year is allowed so that present arrangement may continue in the interim. The process of re-negotiation of the connection conditions shall be completed within this period of one year. In case it is determined that the compliance of connection conditions would be delayed further, the Commission may consider further relaxation for which a petition will have to be filed by the concerned User along with STUs recommendation/comments. The cost of modification, if any, shall be borne by the concerned User.

4.5.2 A connection agreement shall include (but not limited to), as appropriate, within its terms and conditions, the following:

(a) The basic rules for connections are complied with and all Users are treated in a non-discriminatory manner.

(b) Details of connection, technical requirements and commercial arrangements.

(c) Details of any capital expenditure arising from necessary reinforcement or extension of the system, data communication, RTU etc. and demarcation of the same between the concerned parties.

(d) Details of equipment and plant to be connected.

(e) General philosophy, guidelines, etc., on protection and telemetry.

(f) A “Site Responsibility Schedule” detailing the division of responsibility at Connection Sites in relation to ownership, control, operation and maintenance of plant & apparatus and to safety of persons.

4.6 IaSTS Parameter Variations

4.6.1 General Within the power system, instantaneous values of the system frequency and voltage are subject to variation from their nominal value. All Users shall ensure that their plants and apparatuses requiring service from/ to the IaSTS are of such design and construction that satisfactory operation is not hampered by such variation.

24 Compendium of HPERC Regulations, March 2021

4.6.2 Frequency Variations Rated frequency of the system shall be 50.0 Hz and shall normally be controlled within the limits as per regulations/standards framed by the Authority.

4.6.3 Voltage Variations

(a) The variation of the voltage may not be more than the voltage range specified in the regulations/standards framed by the Authority.

(b) The agencies engaged in sub-transmission and distribution shall not depend upon the IaSTS for reactive energy compensation when connected. The agencies shall estimate and provide the required reactive energy compensation in its transmission and distribution network to meet its full reactive power requirement.

4.7 Equipment at Connection Points

4.7.1 Sub-Station Equipment

(a) All EHV sub-station equipments shall comply with Bureau of Indian Standards (BIS)/IEC/ prevailing Code of practice.

(b) All equipment shall be designed, manufactured and tested and certified in accordance with the quality requirements as per IEC/BIS standards.

(c) Each connection between the User and the IaSTS shall be controlled by a circuit breaker capable of interrupting, at the connection point, the short circuit current as advised by STU in the specific connection agreement.

4.7.2 Fault Clearance Times

(a) The primary protection system shall be such that the fault clearance time of all equipments/lines connected to the IaSTS and for a three phase fault (close to the bus-bars) on IaSTS connected to User's equipment, shall not be more than:

(i) 100 milli seconds (ms) for 400 kV

(ii) 160 milli seconds (ms) for 220 kV &132 kV

(iii) 300 milli seconds (ms) for 66 kV 1[(iv) 400 milli seconds (ms) for 33 kV.]

(b) Back-up protection shall be provided for required isolation/protection in the event of failure of the primary protection systems to isolate the faulty element within the above fault clearance time requirements. If a Generating Unit is connected directly to the IaSTS, it shall have the capability to withstand disturbances, until clearing of the fault by back - up protection on the IaSTS side.

4.7.3 Protection Planning

(a) Protection systems are required to be provided by all Users in coordination with the Protection Committee (to be constituted by STU with the approval of HPERC). In case of installation of any device, which necessitates modification/replacement of existing protection relays/scheme in the network, 1 Ins. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418.

Compendium of HPERC Regulations, March 2021 25 owner of respective part of network shall carry out such modification/ replacement.

(b) Protection systems are required to isolate the faulty equipments and protect the other components of the system against all types of faults, internal/external to them, within the specified fault clearance time with reliability, selectivity and sensitivity.

(c) All Users connected to the IaSTS shall provide protection systems as specified in the connection agreement.

(d) Relay setting coordination shall be done at regional level by RPC.

4.8 Generating Units and Generating Stations

4.8.1 A Generating unit shall be capable of continuously supplying its normal rated active/reactive output within the system frequency and voltage variation range indicated at section 4.6 above, subject to the design limitations specified by the manufacturer.

4.8.2 Generating units must be provided with AVR and protective & safety devices, as set out in connection agreements.

4.8.3 Each Generating Unit must be fitted with a turbine speed governor having an overall droop characteristic within the range of 3% to 6%, which shall always be in service.

1 [4.8.4 All thermal generating units of 200 MW and above, open cycle gas turbine/combined cycle generating stations having gas turbines of more than 50 MW each and all hydro units of 25 MW and above operating at or above 100% of their Maximum Continuous Rating (MCR) shall have the capability of (and shall not in any way be prevented from) instantaneously picking up to 105%, 105% and 110% of their MCR, respectively, when the Grid 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 grid) only after obtaining permission from SLDC.]

4.8.5 No generating units shall be synchronized with the State Power Grid without the necessary instructions from SLDC.

4.9 Reactive Power Compensation

4.9.1 Reactive power compensation and/or other facilities should be provided by the Transmission Licensee/Distribution Licensees, as far as possible close to the load points thereby avoiding the need for exchange of reactive power to/from the IaSTS and to maintain IaSTS voltage within the specified range.

4.9.2 Line Reactors may be provided to control temporary over voltage within the limits as set out in connection agreements.

4.9.3 The additional reactive compensation to be provided by the User shall be indicated by STU in the connection agreement for implementation.

1 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “Each generating unit must be capable of instantaneously increasing output by 5% when the frequency falls, limited to 105% MCR. Ramping back to the previous MW level (in case the increased output level cannot be sustained) shall not be faster than 1% per minute.” 26 Compendium of HPERC Regulations, March 2021

4.10 Data and Communication Facilities 1 [4.10.1 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 Users, including generating stations not falling under the definition of State Entity, shall provide systems to telemeter power system parameter such as power 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, shall also be established by the concerned User as specified by STU in connection agreement. All Users in coordination with STU shall provide the required facilities at their respective ends and SLDC as specified in the connection agreement.]

4.11 System Recording Instruments

4.11.1 Recording instruments such as Data Acquisition System/Disturbance Recorder/Event Logger/Fault Locator (including time synchronization equipment) shall be provided in the IaSTS for recording of dynamic performance of the system. Users shall provide all the requisite recording instruments as specified in the connection agreement according to the agreed time schedule.

4.12 Responsibilities for Operational Safety

4.12.1 STU/Transmission Licensee and the concerned User shall be responsible for safety as indicated in Site Responsibility Schedules for each connection point.

4.13 Site Responsibility Schedule

4.13.1 A Site responsibility schedule shall be produced by STU/transmission licensee and User detailing the ownership responsibilities of each, before execution of the project or connection including, safety responsibilities.

4.13.2 The Site Responsibility Schedule shall be prepared by STU/transmission licensee pursuant to the relevant connection agreement and shall state the following for each item of plant and apparatus installed at the connection point:

(a) Ownership of the Plant/Apparatus.

(b) Responsibility for control of the Plant/Apparatus.

(c) Responsibility for operation of the Plant/Apparatus.

(d) Responsibility for maintenance of the Plant/Apparatus.

(e) Responsibility for all matters relating to safety of any person at the connection point.

4.13.3 All Users connected to or planning to connect to IaSTS would ensure providing of RTU and other communication equipment, as specified by SLDC for sending real- 1 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “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 Users (i.e. all 66kV and above sub-stations and all SSGS) shall provide systems to telemeter power system parameter such as power 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, shall also be established by the concerned User as specified by STU in connection agreement. All Users in coordination with STU shall provide the required facilities at their respective ends and SLDC as specified in the connection agreement.” Compendium of HPERC Regulations, March 2021 27 time data to SLDC at least before date of commercial operation of the generating stations or sub-stations or lines being connected to IaSTS.

4.13.4 The Formats, principles and basic procedure to be used in the preparation of Site Responsibility Schedules shall be formulated by STU and shall be provided to each User seeking connection or modification of existing connection to the IaSTS.

4.14 Single Line Diagrams

4.14.1 Single Line Diagram shall be furnished to SLDC and STU for each connection point by the connected Users. These diagrams shall include all HV connected equipment and the connections to all external circuits and incorporate numbering, nomenclature and labeling, etc. The diagram is intended to provide an accurate record of the layout and circuit connections, rating, numbering and nomenclature of HV apparatus and related plant.

4.14.2 Whenever, any equipment is proposed to be changed, the concerned User shall intimate the necessary changes to STU and to all concerned. When the changes are implemented, revised single line diagram shall be circulated by the User to SLDC and STU.

4.15 Site Common Drawings

4.15.1 Site Common Drawings shall be prepared by STU for each Connection Point and will include site layout, electrical layout, details of protection and common services drawings. Users shall provide the necessary details to STU.

4.15.2 The detailed drawings for the portion of the User and STU/ transmission licensee at each connection point shall be prepared individually and copies of the same shall be made available to the other party.

4.15.3 If any change in the drawing is found necessary, the details will be furnished to the other party as soon as possible.

4.16 Procedure for Site Access, Site Operational Activities and Maintenance Standards Drawings

4.16.1 The Connection Agreement will also indicate any procedure necessary for Site access, Site operational activities and maintenance standards for equipment of the STU/ transmission licensee at User's premises and vice versa.

4.16.2 The User owning the Connection Site shall provide reasonable access and other required facilities for other Users whose equipments are installed /proposed to be installed at the Connection Site for installation, operation, maintenance, etc.

4.16.3 Written procedures and agreements shall be developed between entities to ensure that mandatory access is available to the entity concerned, and at the same time safeguarding the interests of both the entities at the connection site.

4.17 Schedule of Assets of the State Power Grid 28 Compendium of HPERC Regulations, March 2021 1[4.17.1 STU shall submit annually to the Commission by 30th September each year schedule of such transmission assets, indicating ownership also, in electronic form, which constitute a part of State Power Grid as on 31st March of that year and on which SLDC has operational control and responsibility.]

2 [4.18 Cyber Security

4.18.1 All Intrastate 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 grid.]

.

CHAPTER-5 OPERATION PLANNING AND SYSTEM SECURITY CODE

5.1 Introduction

5.1.1 The primary objective of integrated operation of the State Power Grid is to enhance the overall operational economy and reliability of the entire electric power network spread over the geographical area of the State.

5.2 Operating Policy

5.2.1 Participant Utilities shall cooperate with each other and adopt Good Utility Practices at all times for satisfactory and beneficial operation of the State Power Grid.

5.2.2 Overall operation of the State Power Grid shall be supervised from the State Load Dispatch Centre (SLDC). All Users are accordingly required to comply with the directions given by the SLDC.

5.2.3 All Users shall comply with this operation planning and system security code, for deriving maximum benefits from the integrated operation and for equitable sharing of obligations.

5.2.4 A set of detailed internal operating procedures for State Power Grid shall be developed by SLDC in consultation with Users which shall be consistent with the provisions of HPEGC and IEGC to enable compliance with the requirement of the Grid Code and IEGC.

5.2.5 For efficient and secure operation of the State Power Grid the control rooms of the SLDC, power generating plants, sub-stations of 66 kV and above, and any other control centers established by the Transmission Licensee/ Users shall be manned round-the-clock by qualified and adequately trained personnel. Detailed personnel records shall be supplied for evaluation to HPERC by all concerned on an annual basis.

1 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “STU shall submit annually to the Commission by 30th September each year schedule of transmission assets in electronic form, which constitute the State Power Grid as on 31st March of that year indicating ownership on which SLDC has operational control and responsibility.” 2 Add. para “4.18 and sub-para 1.18.1” vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418.

Compendium of HPERC Regulations, March 2021 29

5.3 System Security Aspects

5.3.1 All Users shall endeavor to operate their respective power systems and power generating stations in synchronism with each other at all times, such that the entire system within the State operates as one synchronized mode.

5.3.2 No part of the State Power Grid shall be deliberately isolated from the rest of the State Power Grid, except:

(a) under an emergency, and conditions in which such isolation would prevent a total grid collapse and/or would enable early restoration of power supply;

(b) when serious damage to a costly equipment is imminent and such isolation would prevent it;

(c) when such isolation is specifically instructed by SLDC under operating conditions.

5.3.3 On isolation due to any of the above mentioned causes under section 5.3.2, complete synchronism of grid shall be restored as soon as the conditions again permit it. The restoration process shall be supervised by the SLDC, as per operating procedures separately formulated by it.

5.3.4 No important element of the State Power Grid shall be deliberately opened or removed from service at any time, except when specifically instructed by the 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 STU and Users and shall be available with SLDC, STU and the Users. In case of opening/removal of any important element of the State Power Grid under an emergency situation, the same shall be communicated to SLDC at the earliest possible time after the event.

5.3.5 Any tripping, whether manual or automatic, of any of the above elements of the State Power Grid shall be precisely intimated by the concerned 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.

1 [5.3.6 All thermal generating units of 200 MW and above and all hydro units of 25 MW and above, which are synchronized with the grid, irrespective of their ownership, shall have their governors in operation at all times in accordance with the following provisions; namely :—

(i) all the Thermal generating units having capacity 50 MW and above and Hydro (except those upto three hours pondage) generating units having capacity 25 MW and above shall be operated under Restricted Governor Mode of Operation with effect from 01.04.2019;

1 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “5.3.6 All generating units, which are synchronized with the grid, irrespective of their ownership, type and size, shall have their governors in normal operation at all times. If any Generating Unit of over fifty (50) MW size is required to be operated without its governor in normal operation, the SLDC shall be immediately informed about the reason and duration of such operation. All governors shall have a droop of between 3% to 6%.” 30 Compendium of HPERC Regulations, March 2021

(ii) the restricted governor mode of operation shall essentially have the following features;

(a) there should not be any reduction in generation in case of improvement in grid frequency below 50.05 HZ (for example, if grid frequency changes from 49.9 to 49.95 Hz, there shall not be any reduction in generation). For any fall in grid frequency, generation from the unit should increase by 5% limited to 105% of the MCR of the unit subject to machine capability;

(b) ripple filter of +/- 0.03 Hz shall be provided so that small changes in frequency are ignored for load correction, in order to prevent governor hunting;

(c) if any of these generating units is required to be operated without its governor in operation as specified above, the SLDC shall be immediately apprised about the reason and duration of such operations. All governor shall have a droop setting of between 3% and 6%; and

(d) after stabilization of frequency around 50Hz , the SERC may review the above provision regarding the restricted governor mode of operation and free governor mode of operation may be introduced;

(iii) all other generating units including hydro having the pondage upto 3 hours, Gas turbine/ Combined Cycle Power Plants, wind, solar generators and nuclear power station shall be exempted from the provisions of clauses (i) and (ii) of this para as well as of sub-paras 5.3.7, 5.3.8 and 5.3.9 till the commission review the situation:

Provided that if a 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.]

1 [5.3.7 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:

Provided that periodic checkups by third party should be conducted at regular intervals at least once in two years through independent agencies selected by SLDC.

The cost of such tests shall be recovered by the SLDC from the Generators. If deemed necessary by SLDC, the test may be conducted more than once in two years.]

1 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “5.3.7 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.” Compendium of HPERC Regulations, March 2021 31 1 [5.3.8 All thermal generating units of 200 MW and above and all hydro units of 25MW 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 grid) only after obtaining the permission of SLDC. For the purpose of ensuring primary response, SLDC shall not schedule the generating station or unit(s) thereof beyond ex bus generation corresponding to 100% of the Installed capacity of the generating station or unit (s) thereof. The generating station shall not resort to Valve Wide Open (VWO) operation of units whether running on full load or part load, and shall ensure that there is margin available for providing Governor action as primary response. In case of gas/liquid fuel based units, suitable adjustment in Installed Capacity should be made by SLDC for scheduling in due consideration of prevailing ambient conditions of the temperature and pressure vis-à-vis site ambient conditions on which installed capacity of the generating station or unit (s) thereof have been specified:

Provided that scheduling of hydro stations shall not be reduced during high inflow period in order to avoid spillage:

Provided further that the VWO margin shall not be used by SLDC to schedule Ancillary Services.]

2 [5.3.9 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) percent per minute or as per manufacturer's limits.]

3 [5.3.10 Except under an emergency, or to prevent an imminent damage to a costly equipment, no User shall suddenly reduce his generating unit output by more than 1 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P.

dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “5.3.8 All Generating Units, 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 five percent (5%) extra load when frequency falls due to a system contingency. The generating units operating at above 100% of their MCR shall be capable of (and shall not be prevented from) going at least up to 105% of their MCR 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 of over fifty (50) MW size not complying with the above requirements shall be kept in operation (synchronized with the State Power Grid) onlyafter obtaining the permission of SLDC.” 2 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P.

dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “5.3.9 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) percent per minute or as per manufacturer's limits. However, if frequency falls below 49.5 Hz, all partly loaded generating units shall pick up additional load at a faster rate, according to their capability.” 3 Sub. vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P.

dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- 32 Compendium of HPERC Regulations, March 2021 20% of installed capacity or 10MW whichever is less without prior intimation to and consent of the SLDC. Similarly, no User shall cause a sudden variation in its load by more than 20% or 10MW whichever is less without prior intimation to and consent of the SLDC. All users 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 Central Electricity Authority (Grid Standards) Regulations, 2010.]

5.3.11 All Generating Units shall normally have their AVRs in operation, with appropriate settings. In particular, if a generating unit of over fifty (50 MW) is required to be operated without its AVR in service, the SLDC shall be intimated immediately about the reason and duration of such operation, 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.

1 [5.3.12 Provision of protections and relay settings shall be coordinated periodically throughout the State Power Grid, as per the plan to be separately finalized by the STU in coordination with all Users and the RPC and/or SPC, wherever required. The STU shall also prepare islanding schemes and ensure its implementation in accordance with Central Electricity Authority (Grid Standards) Regulations, 2010.

All users shall ensure that installation and operation of protection system shall comply with the provisions of Central Electricity Authority (Grid Standards) Regulations, 2010.

5.3.13 All Users and SLDC, shall take all possible measures to ensure that the grid frequency always remains within the 49.90 –50.05 Hz band or as may be specified in IEGC from time to time.]

5.3.14 Users shall provide automatic under-frequency & df/dt relay based load shedding in their respective systems, wherever applicable to arrest frequency decline that could result in a collapse/disintegration of the grid, as per the plan separately finalised by the SLDC in consultation with STU/RPC, and shall ensure its effective application to prevent cascade tripping of generating units in case of any contingency. All Users shall ensure that the above under frequency and df/dt relay based load shedding/ islanding schemes are always functional. However, in case of extreme contingencies, these relays may be temporarily kept out of service with prior consent of SLDC. STU shall carry out periodic inspection of the under frequency relays and produce the report to the SLDC. SLDC shall maintain the record of the under-frequency and/or df/dt relay operation.

“5.3.10 Except under an emergency, or to prevent an imminent damage to costly equipment, no SSGS shall suddenly reduce its generating unit output by more than fifty (50) MW without prior intimation to and consent of the SLDC, particularly when frequency is falling or is below 49.0Hz. Similarly, no User shall cause a sudden increase in its load by more than fifty (50) MW without prior intimation to and consent of the SLDC.” 1 Sub. sub-paras “5.3.12 & 5.3.13” vide Not. No. HPERC-Grid Code (388) dated 9 th October, 2018 published in R.H.P. dated 12 th October, 2018 at p. 5404-5418 and before its substitution it stood as under:- “5.3.12 Provision of protections and relay settings shall be coordinated periodically throughout the State Power Grid, as per a plan to be separately finalized by the STU in coordination with all Users and the RPC, wherever required.” “5.3.13 All Users shall make all possible efforts to ensure that the grid frequency always remains within the 49.0 –50.5 Hz band.” Compendium of HPERC Regulations, March 2021 33

5.3.15 All Users shall also facilitate identification, installation and commissioning of System Protection Schemes (including inter-tripping and run-back) in the power system to protect against situations such as voltage collapse and cascading. 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.

5.3.16 Procedures shall be developed to recover from partial/total collapse of the grid and periodically updated in accordance with the requirements given under section 5.8.

These procedures shall be followed by all Users to ensure consistent, reliable and quick restoration.

5.3.17 Each User shall provide adequate and reliable communication facility internally and also with SLDC/other Users 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.

5.3.18 All Users shall send information/data including disturbance recorder/sequential event recorder output etc., to SLDC for purpose of analysis of any grid disturbance/event.

No User shall block any data/information required by the SLDC for maintaining reliability and security of the grid and for analysis of an event.

1 [5.3.19 All Users shall make