The Petroleum and Natural Gas Regulatory Board (Technical Standards and Specifications including Safety Standards for Natural Gas Pipelines) Regulations, 2009
Published vide Notification No. G.S.R. 808(E), dated 11th November, 2009
Last Updated 23rd July, 2020 [act2569]
Petroleum and Natural Gas Regulatory Board
G.S.R. 808(E). - In exercise of the powers conferred by section 61 of the Petroleum and Natural Gas Regulatory Act, 2006 (19 of 2006), the Petroleum and Natural Gas Regulatory Board hereby makes the following regulations, namely:- 1. Short title and commencement. - (1) These regulations may be called the Petroleum and Natural Gas Regulatory Board (Technical Standards and Specifications including Safety Standards for Natural Gas Pipelines) Regulations, 2009. (2) They shall come into force on the date of their publication in the Official Gazette. 2. Definitions. - (3) In these regulations, unless the context otherwise requires,(a) "Act" means the Petroleum and Natural Gas Regulatory Board Act, 2006;
(b) "active regulator" means a regulator in Pressure Regulating Station (PRS) that normally controls the outlet pressure;
(c) "active and monitor regulator system" means an arrangement of two regulating devices in series, one (Active) normally to control the outlet pressure and the other (Monitor) of assume control in the event of failure of the active, regulator;
(d) "ASME B 31.8" means standard covering Gas Transmission and Distribution Piping System referred to in Annexure VI.
(e) "Board" means the Petroleum and Natural Gas Regulatory Board established under sub-section (1) of section 3 of the Act;
(f) "city gas distribution entity" means an entity authorised by the Board to lay, build, operate or expand the city or local natural gas distribution network;
(g) "compressor station" means an installation on the pipeline having compressor units to boost gas pressure;
(h) "creep relief valve" means a relief valve installed to relieve over pressure caused by creep in the system and having maximum 1% flow capacity of such a system;
(i) "intermediate pigging station" means an installation having facility for receiving and launching of pigs for pigging operations;
(j) "onshore" means areas other than offshore which shall form the scope of these standards. Feeder lines from jetty or other storage points shall also form a part of the onshore pipelines. The offshore and onshore coverage as per this standard is depicted at Annexure-I;
(k) "operating company or operator" means an entity engaged in the operation of natural gas pipeline network with the authorization of the Board;
(l) "owner" means an entity that owns the natural gas pipeline network and has been authorized by the Board;
(m) "natural gas pipeline" means any pipeline including spur lines for transport of natural gas and includes all connected equipments and facilities, such as, compressors storage facilities metering units etc. and gas pipelines for offshore and onshore coverage depicted at Annexure I but excludes-
(i) dedicated pipeline laid to transport natural gas to a specific customer to meet his requirement and not for resale;
(ii) pipelines in a city or local natural gas distribution network which are regulated by the Petroleum and Natural Gas Regulatory Board (Authorizing Entities to Lay, Build, Operate or Expand City or Local Natural Gas Distribution Networks) Regulations, 2008;
(n) "positive isolation" means the isolation with blind or spectacle blind in case of flanged joints or with welding the cap in case of welded joints;
(o) "right of user or right of way" means the area or portion of land within which the pipeline operator or owner has acquired the right through the Petroleum and Minerals Pipelines Act, 1962 or in accordance with the agreement with the land owner or agency having jurisdiction over the land to lay and operate the natural gas pipelines;
(p) "slam shut valve" means a valve that is designed to close quickly in the event of an abnormal pressure (whether excess or low) being detected at a selected point in a gas pipeline system;
(q) "sub transmission pipeline" means a high pressure pipeline connecting the main natural gas pipeline to the city gate station but is owned by the CGO entity;
(r) "transmission system" means one or more segments of pipeline usually interconnected to form a network that transports gas from a gathering system the outlet of a gas processing plant or a storage field to a high medium or low-pressure pipeline system a large-volume customer or another storage field;
(4) Words and expressions used and not defined in these regulations, but defined in the Act or in the rules or regulations made thereunder, shall have the meanings respectively assigned to them in the Act or in the rules or regulations as the case may be. 3. Application. - (1) These regulations shall apply to all the entities authorised by the Board to lay, build, operate or expand natural gas pipelines under the Petroleum and Natural Gas Regulatory Board (Authorizing Entities to Lay, Build, Operate or Expand Natural Gas Pipelines) Regulations, 2008 and any other natural gas pipelines including dedicated pipelines notified by the Board from time to time. (2) Definitions of design, material and equipment, welding, fabrication, installation, testing, commissioning, operation and maintenance and corrosion control of natural gas pipeline network shall be in accordance with the requirements of ASME B31.8 except in so far as such requirements are specifically cancelled, replaced or modified by the requirements specified in these regulations. 4. Scope. - (1) Requirements of these regulations shall apply to all existing and new natural gas pipelines including dedicated pipelines. (2) These regulations shall cover pipeline design, materials and equipment, welding, fabrication, insta1lation, testing, commissioning, operation and maintenance and corrosion control of common carrier or contract carrier natural gas pipelines (Transmission or Sub transmission) including safety requirements for natural gas pipelines. The pipelines coverage shall be as per Annexure I and includes dedicated pipelines for specific consumers. 5. Intent. - These standards are intended to ensure uniform application of design principles and to guide in selection and application of materials and components, equipment and systems and uniform operation and maintenance of the natural gas pipeline system and shall primarily focus on safety aspects of the employees and public and facilities associated with natural gas pipelines. 6. The standard. - Technical Standards and Specifications including Safety Standards (hereinafter referred to as standard) for natural gas pipelines are at Schedule I which cover Material and Equipment (Schedule 1A), Welding (Schedule 1B), Piping System Components and Fabrication (Schedule 1C), Design, Installation and Testing (Schedule 1D), Operating and Maintenance Procedures (Schedule 1E), Corrosion Control (Schedule 1F), Miscellaneous (Schedule 1G) as read with Annexure I to Annexure VI. 7. Compliance to these regulations. - (1) The Board shall monitor the compliance to these regulations either directly or through an accredited third party as per separate regulations on third party conformity assessment. [(1A) The Board of the concerned entity, within ninety days of the commencement of these regulations shall appoint one of its directors, who shall be responsible for ensuring compliance to these regulations.] (2) If an entity has laid, built, constructed or expanded the natural gas pipeline network based on some other standard or is not meeting the requirements specified in these regulations, the entity shall carry out a detailed technical audit of its infrastructure through a Board authorized or approved third party agency. The entity thereafter shall submit the compliance report prepared by the third party along-with its time-bound mitigation plan and implementation schedule to the Board for authorization within six months from the date of notification of these regulations. (3) The continuation of operation of existing natural gas pipeline network shall be allowed only if it meets the following requirements, namely:-(i) The natural gas pipeline system shall have been tested initially at the time of commissioning in accordance with ASME B 31.8. The entity should have proper records of the same such test record shall have been valid for the current operation. Alternatively, if such a record is not available, the entity should produce in service test record of the natural gas pipeline network having been tested as per ASME B 31.8;
(ii) The natural gas pipeline system has leak detection system in position compressor station, gas receiving and terminal station and is operative;
(iii) There shall be protection of the system against third party damages:
Provided that-(a) the entity shall submit self-certification in support of meeting the above requirements within a month of notification of these regulations;
(b) certifications referred to in para (a) shall be done for natural gas pipeline in construction and commissioning, operation and maintenance. The self certification shall be submitted to the Board with mitigation plan and implementation schedule;
(c) the critical components of the system as identified by the Board for such existing networks shall be complied with these regulations within a period specified at Appendix I and the authorized entity shall maintain the integrity of the existing natural gas pipeline system at all times; and
(d) provisions of these regulations related to operation and maintenance procedures shall also be applicable to all such existing installations.
8. Default and consequences. - (1) There shall be a system for ensuring compliance to the provision of these regulations through conduct of technical and safety audits during the construction, commissioning and operation phase, as well as on an on-going basis as may be specified from time to time. (2) In the event of any default in sub regulation (1), the entity shall qualify as defaulting entity under the regulation 16 (1) the of Petroleum and Natural Gas Regulatory Board (Authorizing Entities to Lay, Build, Operate or Expand Natural Gas Pipelines), Regulations, 2008. (3) In case of any deviation or shortfall including any of the following defaults, the entity shall be given time limit for rectification of such deviation, shortfall, default and in case of non-compliance, the entity shall be liable for termination of operation or termination of authorization apart from any penal action under the provisions of the Act, namely:-(a) if an entity fails to comply within the specified time limit of critical activities at Appendix I.
(b) the entity defaults three times under sub-regulation (1) of regulation 16 of the Petroleum and Natural gas Regulatory Board (Authorizing Entities to lay, Build, Operate or Expand Natural Gas Pipelines), Regulations, 2008.
(c) the entity is found operating the pipelines beyond the maximum allowable operating pressure (MAOP) conditions (either the original or de-rated pressure).
(d) the entity is found operating the pipeline system without conducting the hydro test as mentioned in these regulations;
(e) in the event of installations is found unsafe to be operated as per the third party periodic inspection assessment and compliance is not achieved within the notice period by the Board.
9. Requirements under other statutes. - It shall be necessary to comply with all statutory rules, regulations and Acts in force as applicable and requisite approvals shall be obtained from the relevant competent authorities for the natural gas pipeline system. 10. Miscellaneous. - (1) If any dispute arises with regards to the interpretation of any of the provisions of these regulations, the decision of the Board shall be final. (2) The Board may at any time effect appropriate modifications in these regulations.Appendix-I
List of Critical Activities in Natural Gas Pipelines
Sr. No. |
Critical Infrastructure/ Activity/ Processes |
Time period for Implementation |
Implementation plan |
1 |
Test record for radiograpy, ultrasonic test or other applicable NDT methods (as carried out before commissioning) |
6 months |
can be submitted in stages within 6 months |
2 |
Hydro-test (as carried out before commissioning) Report |
6 months |
can be submitted in stages within 6 months |
3 |
Pipeline cathodic protection record |
6 months |
can be submitted in stages within 6 months |
4 |
Pipeline As-built records |
6 months |
can be submitted in stages within 6 months |
5 |
Intelligent pigging shall be carried out to detect metal loss for the pipelines of size NPS of 12 inches and above and length of 10 Km and above. |
2 years |
If the pigging has not been done for more than 5 years for sour gas and 10 years for sweet gas pipeline, then the intelligent pigging shall be carried out within two years, otherwise relevant records shall be submitted. |
6 |
HSE Management System (including fire protection system) |
6 months |
To be implemented |
7 |
Height of the vent shall be minimum 3 meters above working level |
6 months |
Increase height of vent |
8 |
Gas detectors shall be installed at compressor station, gas receiving and delivery terminals |
1 year |
Install gas detectors for SCADA backed up system, elsewhere hand held gas detector shall be provided |
9 |
Environmental friendly fire extinguishing flooding system for closed space |
2 years |
For control room, switch gear and battery room, etc. (CO2 is acceptable only for unmanned station) |
10 |
HAZOP shall be done for all the pipeline facilities |
1 year |
HAZOP report to be submitted along with mitigation plan |
Schedule I
Technical Standards and Specifications including Safety Standards for Natural Gas Pipelines
Schedule-1A |
Material And Equipment |
Schednle-1B |
Welding |
Schedule-1C |
Piping System Components And Fabrication Details |
Schednle-1D |
Design, Installation And Testing |
Schedule-1E |
Operating And Maintenance Procedures |
Schedule-1F |
Corrosion Control |
Schednle-1G |
Miscellaneous |
Schedule 1A
Materials and Equipment
Materials and Equipments - All materials and equipments forming a permanent part of any piping system constructed according to this standard shall comply with the design and service requirements and shall be suitable for the intended fabrication or construction methods. For sour gas service requirements as per Schedule 1G shall be complied with. Materials for use in Cold Climates. - Materials to be used in facilities exposed to low ambient or low operating temperatures shall have adequate impact properties to prevent brittle fracture at such low temperatures. Material Specifications. - In addition to standards and specification covered in ASME B31.8, standards and specifications listed in Annexure II shall also be acceptable for manufacturing of various piping Components forming part of the natural gas pipelines and associated facilities. Steel Pipe. - Carbon steel line pipe [as per Line Pipe Specification API 5L, shall be Seamless, High Frequency Welded (HFW) including Electric Resistance Welded pipes or Longitudinal or Helical Submerged Arc Welded (SAWL/SAWH) conforming to Product Specification Level-2 (PSL 2).]. Electric welded pipes manufactures to API Specification 5L shall also meet additional requirements specified under Annexure III of this standard. Carbon Equivalent. - Maximum limits on Carbon Equivalent (CE) for steel line pipes shall be as follows: For pipes having Carbon Content > 0.12%CE(IIW) = | C + | Mn 6 |
+ | Cr+Mo+V 5 |
+ | Ni+Cu 15 |
CE(Pcm) = | C + | Si 30 |
+ | Mn 20 |
+ | Cu 20 |
+ | Ni 60 |
+ | Cr 20 |
+ | Mo 15 |
+ | V 10 |
+ | 5B |
Schedule IB
Welding
Preparation For Welding Butt Welds - Notches or laminations on pipe ends are not permitted and must be removed by cutting the pipe as a cylinder and re-beveling of pipe end or by grinding prior to welding. Re-beveled ends shall be re-examined by Ultrasonic or magnetic particle methods if cut section is more than previously examined length. Seal Welds - As far as practical seal welding of threaded joints should be avoided. Qualification of Procedures and Welders Requirements for Piping Systems Operating at Hoop Stresses of 20% or more of the Specified Minimum Yield Strength Welding procedures and welders for welding of gas pipelines shall be qualified as per API 1104 and shall include toughness testing requirements as applicable for the material to be welded. Welding procedures and welders, for station piping shall be qualified as per ASME Boiler and Pressure Vessel (BPV) Code Section IX or API 1104. Inspection of Welds Inspection and Tests for Quality Control of Welds on Piping System intended to Operate at Hoops Stress Levels of 20% or more of the Specified Minimum Yield Strength All Non Destructive Testing (NDT) including radiographic examination shall be performed in accordance with the requirements of API 1104 except that no root crack shall be permitted. Regardless of operating hoop stress as well as location class all carbon steel butt welds in natural gas pipelines shall be subjected to 100% radiographic examination and/or ultrasonic testing. The weld joints in vent and drain piping open to atmospheric pressure need not be radiographed ultrasonically tested. Such welds however shall be visually examined and root pass of at least 10% of such welds shall be examined by Liquid Penetrant Testing. All butt welded golden joints (i.e. welds joints which are not subjected to pressure testing, shall be subjected to 100% radiography as well as examination by ultrasonic techniques. Socket welded golden joins shall be tested by using Liquid Penetrant Inspection (LPI) method or wet Magnetic Particle Inspection (MPI) method Repair or Removal of Defective Welds in Piping Intended to Operate at Hoop Stress Levels of 20% or More of the Specified Minimum Yield Strength Welds having defects shall be removed or repaired in accordance with API 1104. Repaired weld areas shall be subjected to additional radiography or ultrasonic testing after repair.Schedule 1C
Piping System Components and Fabrication Details
Piping System Components and Fabrication Details General - In addition to standards and specifications covered under ASME B 31.8 for various piping components, piping components manufactured conforming to standards and specifications listed under Annexure II of this standard shall be acceptable. Valves and Pressure Reducing Devices - Valves having pressure containing components including body, bonnet, cover, end flanges etc. made of cast iron or ductile iron shall not be used Flanges - Flanges made of cast iron, ductile iron and non-ferrous materials (brass or bronze) shall not be used. Flanges and flanged components shall not be used in buried piping unless entire flange assembly is encapsulated in water tight and electrically insulating materials Bolting - All stud bolts and nuts used in natural gas pipelines shall meet the design conditions as per applicable ASTM standards. Cast iron, brass or bronze materials are not permitted. Fittings other than Valves and Flanges - Fittings made of cast iron and ductile iron shall not be used. Gaskets - Plain and compressed asbestos gaskets shall not be used.Schedule 1D
Design, Installation and Testing
Design Installation Testing General Provisions - The selection of design for natural gas pipelines shall be based properties, on the gas properties, required flow rate operating pressure and pressure and the environment conditions. All components of the pipeline shall be designed to be suitable and fit for purpose throughout the design life. Cross country pipeline of size less than NPS 4 shall not be used. Other design Requirements - Necessary calculations shall carried out to verify structural integrity and stability of the pipeline for the combined effect of pressure, temperature, bending, soil/pipe interaction, external loads and other environmental parameters as applicable, during all phases of work from installation to operation. Such calculation shall include but not limited to the following:- Buoyancy control and stability analysis for pipeline section to be installed in areas subjected to flooding/submergence,
- Crossing analysis of major rivers.
- Evaluation of potential for earthquake occurrence along pipeline route and carrying out requisite seismic analysis to ensure safety and in integrity of the pipeline system.
Buildings Intended for Human Occupancy and Location Classes for Design and Construction - For the purpose of determining number of buildings for human occupancy and Location Class, 1 - mile distance shall be replaced by 1600m and fractions thereof. When a cluster of buildings intended for human occupancy, indicates that a basic mile (1600m) of pipeline should be identified as location class 2 or location class 3, maybe terminated 200m from the nearest building in the cluster on either side (i.e. at start of cluster and at end of cluster). The boundary between location class 1 and location class 2 or location class 3 shall be at least 200m away from the building closest to the boundary. Steel Pipe Additional Requirement for Nominal Wall Thickness - Consideration shall also be given to loading due to following while selecting nominal wall thickness as per ASME B31.8 as appropriate:- Overburden loads
- Dynamic and seismic loads
- Cyclic and vibratory loads
- Internal pressure fluctuations
- Geo-technical loads (including slides, differential settlement of piping, loss of support, and thermal effect of the pipeline on soil properties).
Design Factors (f) and Location Classes - All exceptions to basic design factors to be used in design formula shall be as per Table 1 given herein this standard. The minimum wall thickness for cross country pipelines of size NPS 4" and above shall be 6.4 mm. Pipelines or Mains on Bridges - Pipelines on railroad and vehicular bridges dedicated bridges shall be designed with should be avoided. Pipeline installed on dedicated bridges shall be designated with design factor as indicated in Table 1.Table 1 - Design Factors for Steel Pipe Construction
Facility |
Location Class |
|||
1 |
2 |
3 |
4 |
|
Pipelines [Also See para. 840.21(b) of ASME B31.8] |
0.72 |
0.60 |
0.50 |
0.40 |
Crossings of roads, without casing:- (a) Private roads (a) Unimproved public roads (b) Roads, highways, or public streets, with hard surface |
0.72 0.60 0.60 |
0.60 0.60 0.50 |
0.50 0.50 0.50 |
0.40 0.40 0.40 |
Crossings of roads, with casing: (a) Private roads (b) Unimproved public roads (c) Roads, highways, or public streets, with hard surface and Railway crossings |
0.72 0.72 0.72 |
0.60 0.60 0.60 |
0.50 0.50 0.50 |
0.40 0.40 0.40 |
Pipelines on bridges |
0.60 |
0.60 |
0.50 |
0.40 |
Parallel Encroachment of pipeline on roads and railways (a) Private roads (b) Unimproved public roads (c) Roads, highways, or public streets, with hard surface and Railway crossings |
0.72 0.72 0.72 |
0.60 0.60 0.60 |
0.50 0.50 0.50 |
0.40 0.40 0.40 |
River Crossing open cut [1] |
0.72 |
0.60 |
0.50 |
0.40 |
Horizontal Direction Drilling (HDD)[1] |
0.72 |
0.60 |
0.50 |
0.40 |
Compressor station piping |
0.50 |
0.50 |
0.50 |
0.40 |
Fabricated assemblies (scraper traps, SV stations, pressure/flow control and metering facilities, etc) [Also See para. 841.121 of ASME B31.8] |
0.60 |
0.60 |
0.50 |
0.40 |
Near concentration of people in Location Classes 1 and 2[2] |
0.50 |
0.50 |
0.50 |
0.40 |
Notes:
(1) Higher thickness may be used if required to control stresses or stability during installation and operation.
(2) Wherever, Table 841.114B is referred in ASME B 31.8 it shall be read as per Table 1 of this standard.
[Transportation of Natural Gas in Class 1 and 2 locations:1. PE pipes can be laid to transport natural gas off spec gas produced from marginal or isolated fields, CBM and like other sources if it meets the following requirements, namely: -
(a) PE pipeline shall be laid complying with all the provisions of the PNGRB (Technical standards and specifications including safety standards for City or local gas distribution network) Regulations, 2008. These provisions inter alia include odourisation, route markers, warning mat and the likes;
(b) Quantitative risk analysis shall be carried out by the entity for the pipeline network and risk mitigation measures shall be taken accordingly to minimize the risk;
(c) The cover of 1.5 meter or the cover as specified in these Regulations for steel pipelines, whichever is higher, shall be maintained;
(d) The pressure shall not exceed 7 Kg/cm2 in the PE Pipeline Network;
(e) The material shall confirm to IS 14885 or ISO 4437 or ASTM D2513-14e1 and the fittings shall as per ISO 8085 Part 3; and
(f) The proposal for using PE pipelines for transportation of gas in Class 1 and 2 locations shall be approved by Board of the entity with complete disclosures on associated risk.]
Location and Layout of Pipeline InstallationsI. Functional and pipeline hydraulic requirements.
II. Environmental consideration based on Environmental Impact Assessment (EIA) and Risk Assessment (RA) pipeline and stations.
III. The HAZOP and risk analysis.
IV. The availability of space for future augmentation of facilities.
V. Approachability, water table and flood level and natural drainage.
In addition to above, compressor station should be located at such clear distances from adjacent property not under control of the pipeline owner / operator so as to minimize the hazard of communication of fire to the compressor station from structures on adjacent property.I. Station equipment and their sizes
II. Utility requirement.
III. Flaring / cold venting requirements.
IV. Operation and maintenance philosophy of station equipment.
V. Requirement of space and access around the compressor shed / house and other equipment
VI. High Tension (HT) pole structure, Transformers, Breakers and Motor Control Centre (MCC) etc shall be located in non hazardous area.
VII. Over Head power lines shall not be allowed to pass directly above the process piping/equipment area and buildings.
Minimum Inter-distances between various station facilities and utilities shall be as per Annexure IV.a. Supervisory Control and Data Acquisition (SCADA) System.
b. Leak detection system with provision for identification / location of leak and isolation of affected section.
c. Communication facilities
d. Emergency Response and Disaster Management Plan (ERDMP)
Scada & Telecom Requirements - Gas pipeline system should be monitored and controlled using SCADA or equivalent monitoring and control system to ensure effective and reliable control, management and supervision of the pipeline. Compressor Stations, Intermediate Pigging Stations, Dispatch and Receiving Stations, Sectionalizing Valve stations with remote operation capabilities as well as Telecom Repeater Stations including voice communication facilities/Cathodic Protection Stations (in case located independent of other facilities) should have suitable field signals' connectivity with the control system. Application software modules / functions should be based on the requirement of pipeline operating company. Provision shall be made for transmitting the Pressure, Temperature, Flow measurement & gas composition data etc. through SCADA system to Central Gas Management Systems (as and when it is established) pertaining to gas entry, gas exit and compressor stations. Board shall allow a suitable time period to the entities for implementation of this system Pipeline System and Component Utility Piping - All utility piping at Station shall comply with the requirement of ASME B31.3a) Limit the hazard and damage from accidental discharge from pipeline/ piping;
b) Facilitate repair and maintenance of pipeline/ Piping facilities and critical equipments.
Stations Block valves with remote shut off provision from the control room shall be provided at the inlet and outlet of the compressor station piping to isolate the pipeline from compressor station facilities in case of emergency at compressor station Mainline /Sectionalizing valves shall be insta1led on the pipeline for the operation and maintenance and control of emergencies. Spacing between mainline valves / sectionaiizing valve in various Location Classes shall not exceed values given in Table 2.Table 2
Location Class |
Maximum Distance in Kms |
1 |
32 |
2 |
24 |
3 |
16 |
4 |
8 |
[Note. - Block or Sectionalizing valves shall be provided at continuously accessible locations at interval distances mentioned in "Table-2", based on predominant location class along the pipeline. Valve spacing adjustments should not exceed 10% of the applicable distance as specified in "Table-2", so to permit a valve to be installed in a more accessible location, with continuous accessibility being the primary consideration. However, the total number of valves as per the design requirement shall remain the same.]
Overhead power lines shall not be allowed to cross directly over the process area of the valve station facilities. The provisions of remote operation should be as per the operation and control philosophy adopted for the pipeline by the owner/operating company. Mainline /Sectionalizing valve should preferably be installed below ground and be provided with suitable stem extension for ease of operation. Sectionalizing block valve in the piggable section of pipeline shall be full bore type to allow safe passage of pigs. The bore size shall conform to API 6D/ISO-14313. Actuator for the actuated valves may be selected based on type of valve, availability of power and project philosophy preferably operating on the fluid in the pipeline system. As far as practical, all mainline isolation valves should be with butt weld ends. Flanged end valves shall not be used in buried piping except at the locations where hot tapping operation is to be carried out for which, buried valve with flanged ends may be used to facilitate mounting of hot tapping machine. Valve surface shall be applied with suitable corrosion protection coating. Sectionalizing Valve (s) station shall have blow down or vent line connection to evacuate the isolated pipeline section in case of an emergency and / or repair. The size of the connections for blowing down the mainline line shall be not be less than 1/3rd of the mainline size. All joints between the mainline pipe and the first valve on the branch, including the inlet to first valve, should be welded joint in order to restrict possible leakage which cannot be isolated by the closure of the valve.Table 3
Nominal Pipe Size (inch) |
Minimum Bend Radius |
12 and below |
21D |
14 to 16 |
30D |
18 and above |
40D |
Table 4 - Minimum Cover Requirements for Pipelines
SI. No |
Locations |
Minimum Cover in meters(i) |
i) |
Normal /rocky terrain |
1.0 |
ii) |
Drainage, ditches roads /railway crossing at |
1.0 |
iii) |
Minor river crossings, tidal areas and other watercourses (ii) |
1.5 |
iv) |
Major river crossings(ii) |
2.5 |
v) |
River with rocky bed |
1.5 |
vi) |
lined canals /drains / nalas etc. |
1.5 |
vii) |
Cased/uncased road crossing(iii) |
1.2 |
viii) |
Cased railway crossing(iii) |
1.7 |
Notes:
i. Cover shall be measured from the top of coated pipe to the top of the undisturbed surface of soil or the top of graded working strip, whichever Lower. The fill material in the working strip shall not be considered in the depth of cover.
ii. For river/watercourses that are prone to scour and/or erosion, the specified cover shall be measured from the expected lowest bed profile after scouring / erosion. Where scour level is not known, an additional cover of at least 1 meter (Over and above the cover mentioned as above in the Table 4) shall be provided from the existing bed of the river/water course except in case of Rocky bed.
iii. The cover shall be measured from the top of road or top of rail, as the case maybe.
iv. Whenever the above provisions of cover cannot be provided due to site constraints, additional protection in form of casing/concreting, soil bags, etc. shall be provided.
v. When insisted by authorities, the depth shall be maintained as per the directions of the concern authorities.
The location of a new buried pipeline, when running parallel to an existing buried pipeline, should be at a minimum clear distance of 5.0 meters from the existing underground pipeline when heavy conventional construction equipment is expected to be utilized. This distance may be reduced after careful assessment of construction methodologies so that it does not result in unsafe conditions during construction. In any case the minimum clear distance shall not be less than 3.0 meters. Existing pipeline should be clearly marked on the ground during construction. Bi-language (local language and Hindi/English) caution signs should be installed while working in such areas. While laying more than one new pipeline in the same trench, clear separation of minimum 500mm shall be maintained between adjacent pipelines. No pipeline should be located within 15.0 meters of any private dwelling or any industrial building or place of public assembly in which persons work, congregate or assemble, unless it is provided with at least 300 mm of cover over and above minimum cover specified in Table 4, or the other mitigation measure provided like higher pipe wall thickness/protection with RCC Slab.Table 5: Minimum Test Pressure
Location Class |
Pressure Requirement |
1 |
1.25 x Design Pressure |
2 |
1.25 x Design Pressure |
3 |
1.40 x Design Pressure |
4 |
1.40 x Design Pressure |
a. Gauging and cleaning
b. Hydro testing
c. Installation of Mainline/Sectionalizing Valve stations
d. All tie-ins.
e. Completion of all facilities on the pipeline
a. Commissioning Procedure in place
b. Pressure testing is completed for entire pipeline and associated station piping.
c. Low pressure leak check of the above ground piping/flanged joints completed
d. Pipeline has been cleaned and debris etc. removed.
e. All mainline/sectionalizing valves are installed as per requirement.
f. All Golden joints are inspected and accepted.
g. Geometric survey of pipeline section is carried out, if applicable.
h. Trained and experience personnel are available/deployed to carry out commissioning.
Documentation - Besides the details mention in the ASME B31.8 clause 867, the Pipeline owner shall also maintain following records/ documents:I. Design & Engineering documents.
II. Route maps, alignment sheets, crossings, drawings, Piping and Instrumentation Diagrams, Station layouts,
III. Vendor and subcontractor assessments and records
IV. Inspection and maintenance reports
V. Material certification including dimension, metallurgy, performance and functional report
VI. A complete pipe book.
VII. Pressure test records include location of leaks or failures, if any, and description of repair under taken.
IX. As built drawings including pipeline
IX. Strength, tightness and leak test reports
X. Complete asset of each location with identification.
XI. NDT records of welds
XII. Geometric survey reports, if applicable.
XIII. Cleaning and drying records
XIV. Commissioning reports
XV. Non-conformance deviation reports
XVI. Calibration records of Inspection, Measuring & Metering and Test equipment
XVII. Audit compliance reports
XVIII. Statutory clearances
XIX. Approved drawings/documents
XX. International practices
XXI. Equipment and operations manuals.
Schedule 1E
Operating and Maintenance Procedures
Operating and maintenance of natural gas pipeline shall be in accordance with requirements of ASME B31.8 except insofar as such requirements are specifically cancelled, replaced or amended by the requirements specified herein this standard. Operating and Maintenance Procedures Affecting the Safety of Gas Transmission and Distribution Facilities Basic Requirements - The entity operating natural gas pipeline shall have an effective Health, Safety and Environment Management System (HSE Management System) and Management of Change System in place to ensure overall safety during option and emergencies. The HSE Management System shall cover the following key elements.a. System Description
b. Operational set points
c. Initial start up
d. Temporary operations
e. Normal operations
f. Normal shut down procedure
g. Emergency Shut Down (ESD) procedures including conditions causing ESD
h. C.P Systems
2. Maintenance Philosophy and Procedure - A maintenance philosophy document clearly indicating the Preventive Maintenance Plan, and various procedures required shall be developed. A detailed maintenance procedure shall be developed for entire pipeline system considering the recommendations given by the Original Equipment Manufacturer (OEM) keeping in mind the local conditions. The manual should include preventive maintenance schedule with periodicity i.e. daily, weekly, monthly, half yearly and yearly. Procedures for emergency repair of piping/pipelines using leak clamps, hot tapping and stopple plugging, and other repair methods should also be included as part of manual. 3. Management of Change Plans - For Safe Control of Operations (SCO), a systematic Management of Change process shall be developed to identify and consider the impact of changes to pipeline systems and their integrity. Management of Change shall address technical, physical, procedural and organizational changes of the system, whether permanent or temporary. Operating and Maintenance procedure should also address the following:-(i) Necessary operational data;
(ii) Pipeline patrolling records;
(iii) Corrosion monitoring or survey records;
(iv) Leak or tapping records;
(v) Routine or unusual inspection records;
(vi) Pipeline repair records]
1. Written Emergency procedures - Special attention should also be given to following while preparing Emergency Response and Disaster Management Plan (ERDMP):a. By cutting out cylindrical piece of pipe containing the defect and replacing the same with a pretested pipe of minimum 2 meter length meeting the required pipe specification.
b. By installing full encirclement welded split sleeves or leak clamps to contain internal pressure and shall have a design pressure of not less than the maximum allowable operating pressure. This shall be fully welded both circumferentially and longitudinally.
c. All repairs performed as per (a) and (b) above shall be testes by radiography examination and/or ultrasonic examination.
d. In case of repair of coated pipe, all damaged coating shall be removed and new coating shall be applied.
Permanent Field Repairs of Injurious Dents and Mechanical Damage 1. Defect Assessment - Effective defect detecting systems like, line walk surveys, surveillance, patrolling, leak detection tests, internal audits, external audits, etc. should be put in place for detection of defects and damages of pipe work. Defective or damaged pipelines should be identified and restored to safe operating conditions by the use of appropriate repair methods. The defects should be categorized into, superficial damage, moderate damage, severe damage, extreme damage etc. as per standard practice. The selection of the most appropriate repair method, consistent with safety of operation, should be selected be based on assessment of the defect. 2. Modification on the pipeline system - Provision of this code shall also apply for any modification on the pipeline system for the purpose of expansion or extension of the pipeline. Modifications should be carried out either by isolating the pipeline system or by hot-tap method. To the extent possible the pipeline system shall not stopped for the purpose of modification and shall try to adopt the other methods so as to supply the uninterrupted gas. The hot tap shall be carried out as per APIRP 2201 Abandoning of Transmission Facilities Requirements for Abandoning, Disconnecting, and Distribution and Reinstalling Facilities - Besides the details mentioned in the ASME B31.8, Abandoning, Disconnecting, or Reinstalling of natural gas pipeline shall also include the following: A pipeline system that is no longer required for transportation of gas should be taken out of service with all hazardous fluids removed from the system. In case operating company decides to abandon full or part of the pipeline system permanently or temporarily after obtaining necessary approval from the statutory authority (if required), it shall prepare a detailed plan considering the following.a. Large scale venting of natural gas should be avoided. It should be ensured that most of the natural gas contained in the system is utilized by consumer.
b. Pipeline section and facilities shall be disconnected with positive isolation from all source of supply of gas prior to abandonment.
c. Pipeline system and facilities to be abandoned should be purged with nitrogen gas or inert materials and ends sealed. If the facilities are purged with air, it shall be ensured that combustible mixture is not present in the system.
Decommissioning of Transmission Facilities - Plans and procedures shall be developed for safe decommissioning, dismantling, demolition, and disposal of the pipeline. Maintenance of the facility shall continue till dismantling of facilities has been completed. Cathodic protection system shall be maintained with periodic inspection. Environmental impact assessment be carried out on account of decommissioning. Safety and Fire Protection General - All installation shall have following fire protection facilities:- ⇒ Fire and Gas Detection System[(a) Compressor area
One (1) number 9 kg Dry Chemical Powder (DCP) based
One (1) number 6.5 kg CO2 based per two compressors and
One (1) number mobile 75 kg DCP based.
(b) Pigging Area, Metering Area and Gas Filtration Area
One (1) number 9 kg DCP based at each location
(c) Air compressors
One (1) number 2 kg CO2 and one number 5 kg DCP based.
(d) Office/ Canteen/ Stores
Two (2) number 9 kg DCP based in each building.
(e) MCC/DG Room/HT room
Two (2) number 4.5 kg CO2 based in each room or per 100 m2 floor area.
4 sand buckets with stand shall be provided near to DG room.
A trolley containing first aid fire protective accessories shall also be provided.
Intermediate pigging station: One (1) number 75 kg and one (1) 9 Kg DCP based and one (1) number 2 kg CO2 based.
100% spares for CO2 cartridges and 50% spares for DCP cartridges shall be stored.
Sectionalizing Valve stations: One (1) number 9 kg DCP based and one (1) number 2 kg CO2 based.
100% spares for CO2 cartridges and 50% spares for DCP cartridges shall be stored.
Gas receipt / delivery terminals: One (1) number 75 kg and one (1) 9 kg DCP based and one (1) number 2 kg CO2 based.;]
100% spares for CO2 cartridges and 50% spares for DCP cartridges shall be stored
All fire extinguishers shall bear ISI or equivalent mark. Manuals of each fire extinguisher shall be provided at every location. The quantity and size of fire extinguishers required shall be provided based on the nature of occupancy and class of fire/risk to be protected.
[***] The following shall also be considered1. Where cleanliness and contamination of sensitive electrical equipment are of importance or likely to get affected only CO2 or Clean Agent (Halon 1211) fire extinguishers shall be provided. (Fire size of fire extinguisher refer BIS-2190).
2. Extinguishers shall be installed within 15 m of the equipment so that travel distance for person is not more than 15m.
⇒ First Aid and Safety Equipment - First Aid and Safety Equipment shall be provided at Compressor Stations, Intermediate Pigging Station, Sectionalising Valve Stations, Gas receipt Delivery terminals and Metering Stations ⇒ Windsock - Windsock shall be provided on an appropriately elevated structure like the control room/fire-water pump house in such a manner so as to avoid blind areas. ⇒ Emergency Power Supply - Emergency lighting shall be provided for operating areas and control room. ⇒ Communication System - Communication system like telephone/PA or paging, walkie-talkie, optical fiber cable based communication system shall be provided. All intermediate stations including IP stations/Repeater station shall be provided with proven communication system. Security at unmanned station shall be trained to deal with communication and emergency handling. ⇒ Fire Water System - [The Firefighting system with fire water network shall be provided at gas compressor stations and shall consist of:]a. Fire water storage
b. Fire water Pumps (Main and Jockey)
c. Fire water distribution piping network
d. Fire hydrant/Monitors
e. Water sprinkler/deluge system.
Facilities should be designed on the basis that the city fire water supply is not available close to the installation. Fire water system shall be designed to fight two major fires simultaneously anywhere in the installation.(a) Compressor area: 20.4 Lpm/ m2 of area;
(b) Scraper area / Metering area / filter area: 10.2 Lpm/ m2 of area; and
(c) Other area: 3 Lpm/m2 of area]
In case the any of the above facilities is within 30 meter, same shall be considered as single risk area or zone for calculation of the fire water requirement. [Gas after cooler area, pigging area, filtration area, metering area, condensate collection area and similar other areas of the Compressor station shall be covered with medium velocity water spray system.]a. Pipes - Carbon Steel (CS) IS: 3589 / IS: 1239 / IS: 1978 or Composite materials as per API 15 LR / API 15 HR or its equivalent shall be used.
b. In case saline / brackish water / treated effluent water is used, the fire water main of steel pipes shall be internally cement mortar lined or glass reinforced epoxy coated or made of pipe material suitable for the quality of water. Alternatively, pipes made of composite materials shall be used.
c. Cast iron pipes shall not be used for fire water services.
d. Isolation/deluge valves shall be either gate valve or butterfly valves with open and closed indication. Material shall be cast steel for normal water and copper nickel for saline/brackish water service.
e. Hydrant Stand post shall be Carbon Steel. Monitors - carbon steel / Gunmetal
f. Outlet valves / landing valves Gunmetal / Aluminium Stainless steel / Aluminium Zink alloy
g. Fire Hose - Reinforced rubber lined hoses (63 mm), 15 mtr standard length conforming to IS: 636 (type A) or Non percolating synthetic hose (Type B) / UL or equivalent standard.
h. The above ground fire water main, hydrant post shall be painted with corrosion resistant "Fire Red" paints as per IS: 5
a. Design/specification documents
b. Route maps, alignment sheets, crossings, drawings, Piping and Instrumentation Diagrams, station layouts Pipe Book/Installation Records
c. Surveillance inspection and maintenance reports
d. Records and maps showing the location of CP facilities and piping
e. CP Monitoring report
f. Leak burst and repair records
g. History cards of equipment
h. Pipeline Pigging Report
i. Material certification including dimension, metallurgy, DT and NDT, strength, tightness, performance and function report
j. Welding records
k. PQR, WPS & Welder qualification records
l. Third Party technical audit report of infrastructure before Gas-IN.
m. Commissioning reports
n. Non-conformance/deviation reports
o. Calibration records of inspection Measuring & Metering and Test equipment.
p. Audit compliance reports
q. Statutory clearness
r. approved drawing/documents
s. HAZOP/ Risk assessment studies/ compliance to recommendations
t. All operation & maintenance manuals
Schedule 1F
Corrosion Control
External Corrosion Control New Installation/Buried Steel Facilities Coating Requirements - Coating shall fulfill following requirements:Schedule 1G
Miscellaneous
Requirements For Sour Gas Service - Gaseous hydrocarbon considered as sour inline with NACE standard MR-01-75. At lower concentrations of H2S, as the presence of other constituents in the gas e.g. CO2 and salts in water etc. can also cause stress corrosion, hence the concentration of such constituents shall also be evaluated in gaseous hydrocarbon. All materials used in sour gas service shall conform to the material requirements specified in NACE standard MR-01-75. Depending upon service and materials involved, additional tests for Sulphide Stress Corrosion Cracking (SSCC) and Hydrogen Induced cracking (HIC), as specified in NACE standards MR-01-75 and TM 02-84 respectively, shall also be conducted for long & short term behaviour of material under corrosive environments.Annexure I
Offshore and Onshore Coverage
Annexure II
List of Specifications of Piping Materials used in Natural Gas Pipelines
Steel Pipe |
|
API 5L |
Specification for Line pipes |
ASTM A106 |
Seamless Carbon Pipe for High Temperature Service |
ASTM A333 |
Seamless and Welded Steel Pipe for Low-Temperature Service |
Values |
|
API 6D |
Pipeline Valves |
ASME B16.34 |
Valves Flanged, Threaded and Welding End |
BS 5352 |
Specification for steel wedge gate, globe and check valves 50 mm and smaller for the petroleum, petrochemical and allied industries |
BS 5351 |
Specification for steel ball valves for the petroleum, petrochemical and allied industries.- Small Floating ball valve |
BS 1873 |
Specification for Steel globe and globe stop and check valves (flanged and butt-welding ends) for the petroleum, petrochemical and allied industries |
Flanges and Blanks |
|
ASME B16.5 |
Steel pipe flanges and flanged fittings - Size up-to 24" NB. |
ASME B16.36 |
Orifice Flange |
MSS SP-44 |
Steel Pipeline Flanges |
API S90 |
Steel Line Blanks |
Fittings |
|
ASME B16.9 |
Factory-Made Wrought Steel Butt welding Fittings |
MSS SP-75 |
Specification for High Test, Wrought, But Welding Fittings |
MSS SP 97 |
Integrally Reinforced Forged Branch Outlet Fittings - Socket Welding, Threaded and Butt welding Ends |
Stud Bolts and Nuts |
|
ASTM A194 |
Standard Specification for Carbon and Alloy Steel Nuts for Bolts for High Pressure or High Temperature Service, or Both. |
ASTM A193 |
Standard Specification for Alloy-steel and Stainless Steel Bolting Materials for High Temperature or High Pressure Service and Other Special Purpose Applications |
ASTM A153 |
Standard Specification for Zinc Coating (Hot-Dip) on Iron and Steel Hardware. |
ASME B18.2.1 |
Square and Hex Bolts and Screws, Inch Series |
ASME B18.2.2 |
Square and Hex Nuts |
ASME B31.8S |
managing system Integrity of gas pipeline |
Gaskets |
|
ASME B16.20 |
Metallic gaskets for pipe flanges: Ring joint, Spiral wind and Jacketed. |
High Pressure SS Tubing and Fittings |
|
ASTM A269 |
Standard Specification for Seamless and welded Austenitic Stainless Steel Tubing for General Service |
List of Specifications for Equipment used in natural gas pipeline System
Pressure Safety Equipment (Regulators, Slam Shut Valves and Creep Relief Valves)
EN 334 |
Gas pressure regulators for inlet pressures up to 100 bar |
EN 14382 |
Safety devices for gas pressure regulating stations and installations - Gas safety shut-off devices for inlet pressures up to 100 bar |
API 526 |
Flanges Steel Pressure Relief Valves |
Filters |
|
ASME Section VIII |
Boiler and Pressure Vessel Code |
Metering Equipment
|
|
AGA Report No.3 |
Orifice Metering of Natural Gas and Other related Hydrocarbon fluids |
Measurement of Gas by Multi-path Ultrasonic Meters and OIML R 137 Parts 1 and 2, Part1: Metrological and technical requirements, Part2: Metrological controls and performance tests] |
|
EN 12480 |
Gas meters - Rotary displacement gas meters |
OIML R32 |
Rotary piston gas meters and turbine gas meters |
AGA Report No.7 |
Measurement of Gas by Turbine Meters. |
EN 12261 |
Gas meters - Turbine gas meters |
Pressure Measuring Equipment |
|
BS EN 837-1 |
Pressure gauges - Part 1: Bourdon tube pressure gauges; dimensions, metrology, requirements and testing |
BS EN 837-2 |
Pressure Gauges - Part 2: Selection and Installation Recommendations for Pressure Gauges. |
BS EN 837-3 |
Pressure gauges - Part 3: Diaphragm and capsule pressure gauges; dimensions, metrology, requirements and testing |
Annexure III
Additional Requirements for Electric Welded Pipes
Electric Welded pipes shall meet following requirements. Reverse Bend Tests - Reverse bend tests shall be performed on the pipe piece cut from the crop end, selected from the front end of the first length and the back end of the last length produced from each coil. The specimen shall be 100mm to 115mm long and shall be reverse bend tested in accordance with procedure and figure given hereinafter.A = | 2R = | 1.4 (D-t)t e(D-2t) - 1.4t |
- t |
Grade of Steel |
Mine 'e' value |
API 5L Gr. B |
0.1425 |
API 5L X-42 |
0.1375 |
API 5L X-46 |
0.1325 |
API 5L X-52 |
0.1275 |
API 5L X-60 |
0.1225 |
Annexure IV
Minimum Inter Distances for Various Station Facilities
S.No. |
From/To |
1 |
2 |
3 |
4 |
5 |
6 |
7 |
8 |
9 |
10 |
1 |
Small Compressor/ Pump House |
- |
15 |
15 |
15 |
16 |
30 |
15 |
15 |
15 |
16 |
2 |
Main Compressor House |
15 |
- |
15 |
15 |
30 |
30 |
15 |
15 |
30 |
30 |
3 |
Gas Handling System (PB/GC) |
15 |
15 |
- |
5 |
16 |
30 |
15 |
15 |
5 |
16 |
4 |
Equipment Room |
15 |
15 |
5 |
- |
- |
30 |
15 |
15 |
5 |
16 |
5 |
Control Room/ Office building |
16 |
30 |
16 |
- |
- |
30 |
15 |
15 |
5 |
- |
6 |
Fire Pump House/ Fire water storage tanks |
30 |
30 |
30 |
30 |
30 |
- |
- |
30 |
12 |
- |
7 |
Water Spray Deluge Valve |
15 |
15 |
15 |
15 |
15 |
- |
- |
15 |
- |
16 |
8 |
Cold Blow Down |
15 |
15 |
15 |
15 |
15 |
30 |
15 |
- |
5 |
30 |
9 |
Compound wall |
15 |
30 |
5 |
5 |
5 |
12 |
- |
5 |
- |
5 |
10 |
Elect Sub station |
16 |
30 |
16 |
16 |
- |
- |
16 |
30 |
5 |
- |
Annexure V
Annexure VI
List of Applicable Standards and References
This standard shall be read in conjunction with the following standards, codes and publications:
(i) |
ASME B31.8 |
Gas Transmission and Distribution Piping Systems. (ASME 3 Park Avenue, New York, NY USA 10016. www.asme.org) |
|
(ii) |
API - 617 |
Centrifugal Gas Compressors |
|
(iii) |
API - 618 |
Reciprocating Gas compressors |
|
(iv) |
API- 11P |
Other gas compressors |
|
(v) |
API 1102 |
Recommended Practice for Steel Pipelines Crossing Railroads and Highways. |
|
(vi) |
API 1104 |
Standard for Welding Pipelines and Related Facilities. |
|
(vii) |
API 1107 |
Recommended Pipeline Maintenance Welding Practices. |
|
(viii) |
API 1109 |
Recommended Practice for Marking Liquid Petroleum Pipeline Facilities. |
|
(ix) |
API 1110 |
Recommended Practice for Pressure Testing of Liquid Petroleum Pipelines. |
|
(x) |
API 500C |
Classification of Locations for Electrical Installations at Pipeline Transportation Facilities. |
|
(xi) |
API - 5L |
Specification for Line pipes |
|
(xii) |
API - 6D |
Pipeline Valves |
|
(xiii) |
ASME Section VIII |
Boiler and Pressure Vessel Code |
|
|
|
Division I |
Pressure Vessels |
|
|
Division 2 |
Alternate Rules for Pressure Vessels |
(xiv) |
ASME Section IX |
Welding Qualifications |
|
(xv) |
MSS-SP-50 |
Pipe Hangers and Supports Materials, Design and Manufacture. |
|
(xvi) |
MSS-SP-69 |
Pipe Hangers and Supports - Selection and Application. |
|
(xvii) |
NACE-RP-01-69 |
Recommended Practice Control of External Corrosion on Underground or Submerged Metallic Piping Systems. |
|
(xviii) |
NACE-RP-01-75 |
Recommended Practice - Control of Internal Corrosion in Steel Pipelines Systems. |
|
(xix) |
ISA S-75.01 |
Flow evaluation fur sizing control valve |
|
(xx) |
ISA S-75.02 |
Control valve test procedure |
|
(xxi) |
IEC-79 |
Electrical Apparatus for Explosive Gas Atmosphere |
|
(xxii) |
IEC-529 |
Degree of protection Provided by Enclosures. |
References
ASME B31.8- |
Gas Transmission and Distribution Piping Systems |
API 1104- |
Welding procedures and welders for welding of gas pipelines. |
IS-5572- |
Electrical area classification of Installation for selection of Electrical Equipment |
IS-5571- |
"Guide for selection of Electrical Equipment for Hazardous Area". |
IS 3043- |
For earthing of all electrical equipment, systems, structures and fencing, etc. |
IS:2309- |
Lightening protection |
ISO 14313 |
Valves |
NACE SP-0177 |
Mitigation of AC and lightening effects |