Petroleum and Natural Gas Regulatory Board (Technical Standards and Specifications including Safety Standards for Petroleum Installations) Regulations, 2020

Petroleum and Natural Gas Regulatory Board (Technical Standards and Specifications including Safety Standards for Petroleum Installations) Regulations, 2020[1]

[11th November, 2020]

In exercise of the powers conferred by Section 61 of the Petroleum and Natural Gas Regulatory Act, 2006 (Act 19 of 2006), the Petroleum and Natural Gas Regulatory Board hereby makes the following Regulations, namely:—

Regulation - 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 Petroleum Installations) Regulations, 2020.

(2)     They shall come into force on the date of their publication in the Official Gazette.

Regulation - 2. Definitions.

(1)     In these regulations, unless the context otherwise requires,

(a)      “Act” means the Petroleum and Natural Gas Regulatory Board Act, 2006 (Act 19 of 2006);

(b)      “Board” means the Petroleum and Natural Gas Regulatory Board established under sub-section (1) of Section 3 of the Act;

(c)      “Bonding” means the process by which two electrical conducting bodies are connected using a conductor to maintain electrical continuity to prevent sparking;

(d)      “Clean agent” means electrically nonconductive, volatile or gaseous fire extinguishing medium that does not leave a residue upon evaporation and meets the requirements given in the latest NFPA 2001 on clean agent fire extinguishing systems in line with environmental considerations of Kyoto and Montreal Protocol and latest MOEF regulations (Government of India, Ministry of Environment, Forest and Climate Change);

(e)      “corrosion” means all forms of wastage, and includes oxidation, scaling, mechanical abrasion and corrosion;

(f)       “design pressure” means the pressure used in the design of equipment, a container, or a vessel for the purpose of determining the minimum permissible thickness or physical characteristics of its different parts and where applicable, static head shall be included in the design pressure to determine the thickness of any specific part;

(g)      “Dyke” means an area that may be defined through the use of structure or the topography at the site for the purpose of containing any accidental spill of petroleum products;

(h)     “Earthing” means the provision of a safe path of electrical current to ground, in order to protect structures, plant and equipment from the effects of stray electrical current, and electrostatics discharge;

(i)       “Effluent Treatment Plant (ETP)” means a mechanism and process used to treat waters that have been contaminated due to presence of Oil or sludge or Grease or chemicals or sewage generated of different activities or operations in petroleum installations;

(j)       “Emergency Shutdown System” means a system that safely and effectively stops whole plant or an individual unit before unrecoverable incidents occurs;

(k)      “Explosive mixture” means a mixture of combustion agent (oxidising product gas, vapour, liquid or solid) and a fuel (oxidisable product - gas, liquid or solid) in such proportions that it could give rise to a very rapid and lively oxidization reaction liberating more energy than is dissipated through conduction and convection; and—

(i)       “Lower explosive Limit (LEL)” means the minimum concentration of a vapour in air (or other oxidant) below which propagation of flame does not occur on contact with an ignition source and such limit is usually expressed as volume percentage of the vapour in air;

(ii)      “Upper Explosive Limit (UEL)” means the maximum concentration of a vapour in air (or other oxidant) above which propagation of flame does not occur on contact with an ignition source and such limit is usually expressed as a volume percentage of vapours in air;

(l)       “Failsafe” means design features which will maintain or result in safe operating conditions in the event of a malfunction or failure of power, instrument air, components or control devices;

(m)    “Fixed-Length Dip Tube” means a pipe that has a fixed open end fitted inside a container at a designated elevation that is intended to show a liquid level;

(n)     “flammability range” means the difference between the minimum and maximum percentage by volume of the gas in mixture with air that forms a flammable mixture at atmospheric pressure and ambient temperature;

(o)      “Flash Point” means the lowest temperature at which the liquid yields vapour in sufficient concentration to form an ignitable mixture with air and gives a momentary flash on application of a small pilot flame under specified conditions of test as per IS : 1448 (Part-I);

(p)      “Hazardous Fluid” means a liquid or gas that is flammable or toxic;

(q)      “Hazardous Area” means the locations classified according to Zone System which defines the probability of the hazardous material, gas or dust, being present in sufficient quantities to produce explosive or ignitable mixtures which require special precautions for the construction, installation and use of electrical apparatus as specified below:

(i)           “Zone 0” means ignitable concentrations of flammable gases or vapours which are present continuously or for long periods of time;

(ii)         “Zone 1” means ignitable concentrations of flammable gases or vapours which are likely to occur under normal operating conditions; and

(iii)       “Zone 2” means ignitable concentrations of flammable gases or vapours which are not likely to occur under normal operating conditions and do so only for a short period of time;

(r)      “Intrinsically Safe” means a circuit or part of a circuit, which is intrinsically safe when any spark or thermal effect produced normally (that is, by breaking or closing the circuit) or accidentally (for example, by short circuit or earth fault) is incapable, under specific test conditions for such purpose, of causing ignition of a specific gas or vapour and an intrinsically safe apparatus is one in which all electrical circuits are intrinsically safe;

(s)      “Non-Hazardous area” means an area in which an explosive gas atmosphere is not expected to be present in quantities such as to require special precautions for the construction, installation and use of electrical apparatus;

(t)       “Ignition Source” means any item or substance capable of an energy release of type and magnitude sufficient to ignite any flammable mixture of gases or vapours that could occur at the site;

(u)     “Maximum Allowable Working Pressure” means the maximum gauge pressure permissible at the top of equipment, a container or a pressure vessel while operating at design temperature;

(v)      “NDT” means Non-Destructive Testing methods like Dye Penetration Inspection, Wet Fluorescent Magnetic Particle Inspection, Ultrasonic thickness checks, Ultrasonic Flaw Detection, Radiography, Hardness Test and other relevant Inspection procedures carried out to detect the defects in the welds and parent metal of the pressure vessel;

(w)     “Oil water separator (OWS)” means a system designed to separate gross amount of oil and suspended solids from the oily water effluent generated due to different activities or operations in Petroleum Installations;

(x)      “onshore” means areas other than offshore which shall form the scope of these regulations and Feeder lines from or to jetty or other storage points shall also form a part of the onshore pipelines;

(y)      “petroleum” means any liquid hydrocarbon or mixture of hydrocarbons and any inflammable mixture (liquid, viscous or solid) containing any liquid hydrocarbon, including crude oil and liquefied petroleum gas, and the expression ‘petroleum product’ shall mean any product manufactured from petroleum and Petroleum products are classified according to their closed cup flash points as given below; namely:—

(i)           Class-A Petroleum : Liquids which have flash point below 23 °C;

(ii)         Class-B Petroleum : Liquids which have flash point of 23 °C above but below 65 °C;

(iii)       Class-C Petroleum : Liquids which have flash point of 65 °C and above but below 93 °C;

(iv)       Excluded Petroleum : Liquids which have flash point of 93 °C and above; and

(v)        Liquefied gases including Liquified Petroleum Gas (LPG) do not fall under this classification but form separate category;

(z)      “Petroleum Installation” means a depot or terminal having facilities for storing, handling, distribution, transportation, loading or unloading of petroleum, oil and lubricants;

(aa) “pressure vessel” means any closed metal container of whatever shape, intended for the storage and transport of any compressed gas which is subjected to internal pressure and whose water capacity exceeds one thousand liters and includes inter connecting parts and components thereof up to the first point of connection to the connected piping and fittings, but does not include containers wherein steam or other vapour is or is intended to be generated or water or other liquid is or is intended to be heated by the application of fire or the products of combustion or by electrical means, heat exchangers, evaporators, air receivers, steam type digestors, steam type sterilizers, autoclaves, reactors, calorifiers, pressure piping components such as separators or strainers and vessels containing a liquid under a blanket of compressed inert gas;

(bb) “Pumpable Capacity (Net Capacity)” means the capacity of the tank during operation after subtracting the volume of tank bottom contents up to the top of pump out nozzle from safe filling capacity of the tank;

(cc) “Safe Capacity of a Tank” means the capacity of the tank up to the maximum safe filling height (safe filling level) of the tank as per statutory requirements and the safe fill level shall be established for each specific tank that will depend on the type of tank, diameter, its internal configuration and condition, rate of filling and the operating practices;

(dd) “Safety relief device” means an automatic pressure relieving device actuated by the pressure upstream of the valve and characterized by fully opened pop action, intended to prevent the rupture of a pressure vessel under certain conditions of exposure;

(ee) “Schedule” means the schedule appended to these regulations;

(ff)   “Service Building” means building housing facilities for inspection or maintenance or other supporting services which are directly required for operation of the installation;

(gg) “Shall” indicates a mandatory requirement;

(hh) “Should” indicates a recommendation or that which is advised but not mandatory;

(ii)   “Slop” means off-specification products obtained from market that is to say Retail Outlet and like other outlets, during any disturbance in operation and draining and like other activities from various equipment or tanks or pumps containing oil-water mixture, but does not include interface generated during pipe line transfer operations;

(jj)   “Source of ignition” means naked lights, fires, exposed incandescent materials, electric welding arcs, lamps, other than those specially approved for use in flammable atmosphere, or a spark or flame produced by any means;

(kk) “Stabling Line” means an additional railway line or spur reserved for additional rake or stabling;

(ll)   “Utilities” means buildings consisting of administrative building, QC Laboratory, canteen, parking shed, air compressors with or without dryers, dryers and like other device which shall be separated from other POL facilities and located as per the separation distance as specified in the standard in this regard.

(2)     Words and expressions, used and not defined, in these regulations, but defined in the Act or in the rules or regulations made there under, shall have the meanings respectively assigned to them in the Act or in the rules or regulations, as the case may be.

Regulation - 3. Application.

Definitions, layout, design, standard operating procedures, maintenance, inspection, competence assurance, fire protection, safety management plan and vehicle management system of Petroleum Installations shall be in accordance with the requirements of these regulations. These regulations do not apply to petroleum installations with aggregate storage capacity less than 1000 KL.

Regulation - 4. Scope.

(1)     Requirements of these regulations shall apply to all existing and new Petroleum Installations.

(2)     These regulations cover safety in design, material and equipment, piping system components and fabrication, installation and testing, commissioning, corrosion control, operation and maintenance and safety of Petroleum Installations.

(3)     These regulations also cover engineering considerations in design and installations including fire protection and safety systems.

(4)     These regulations do not cover the requirements in respect of liquified petroleum gas (LPG) installations.

Regulation - 5. Objective.

These standards are intended to ensure uniform application of design principles in layout, material and equipment selection, construction, operations, maintenance and like other process, as mentioned in Regulation 3 above for safe operation at the facilities associated with Petroleum Installations.

Regulation - 6. The standard.

The technical standards and specifications including safety standards (hereinafter referred to as standards) for Petroleum Installations are as specified in Schedule which cover layout, design, standard operating procedures, maintenance, inspection, competence assurance, fire protection, safety management plan and vehicle management system.

Regulation - 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 regulations applicable for such purpose on third party conformity assessment.

(2)     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

(3)     Any entity intending to set up a Petroleum installation shall make available its detailed plan including design consideration conforming to these regulations to Petroleum and Explosives Safety Organisation (PESO) for their approval.

(4)     If an entity before the commencement of these regulations, has laid, built, constructed, kept under construction or expanded the Petroleum Installation based on some other standard or is not meeting the requirements specified in these regulations, the entity shall carry out a detailed Quantitative Risk Analysis (QRA) of its infrastructure and the entity shall thereafter take approval from its highest decision making body or its board for non-conformities and mitigation measures and the entity's board approval along with the compliance report, mitigation measures and implementation schedule shall be submitted to Petroleum and Natural Gas Regulatory Board by such entity within six months from the date of commencement of these regulations.

Regulation - 8. Default and Consequences.

(1)     There shall be a system maintained by the entity concerned for ensuring compliance to the provision of these regulations through conduct of technical and safety audits during the construction, commissioning and operation phase.

(2)     In case of any deviation or shortfall in compliance with the provision of these regulations, the entity shall be given time limit for rectification of such deviation, shortfall, default and in case of non-compliance thereafter, the entity shall be liable for the penal action under the provisions of the Act or termination of operation or termination of authorization.

Regulation - 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 Petroleum Installations.

Regulation - 10. Miscellaneous.

(1)     If any dispute arises with regard 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, by notification in the Official Gazette, effect appropriate modifications in these regulations.

(3)     The Board may issue guidelines consistent with the Act to meet the objective of these regulations as if deems fit.

SCHEDULE — 1

Technical Standards and Specifications including Safety Standards for Petroleum Installations

(See Regulation 6)

—PART-A

(Design and Layout)

1.0 INSTALLATION LAYOUT:

1.1 LAYOUT PHILOSOPHY.—Following philosophy, which is fundamental in the implementation of these regulations relating to lay out of installation, should be adopted in layout of an installation:

(1)     Presence of ignition source shall always be contemplated beyond the boundary wall of installation;

(2)     Quantitative Risk Analysis or Assessment shall be carried out at the layout stage with an objective to arrive at any specific mitigation measures required for Hazards identified. Risk reduction or mitigation measures shall be given due credit as below:

(i)       Risk assessment shall include Unconfined Vapour Cloud Explosion (UVCE). The outcome shall guide in preparation of onsite or off-site emergency plan; and

(ii)      Quantitative Risk Assessment (QRA) shall be done whenever major addition in facilities or major change in the surrounding areas, operating parameters, product grade takes place or once in every five years, whichever is earlier;

(3)     Approaches from the highway or major road should be provided for normal or emergency movement with minimum road width of 3.5 metres for one-way movement;

(4)     Roads inside the hazardous area of Installation shall be restricted to vehicles required for operational, maintenance and safety or security reasons and allowed only with proper safety fittings and authorization from location in-charge or designated safety officer, except tank trucks coming inside for filling or decantation;

(5)     Alternative access shall be provided for each facility so that it can be approached for firefighting in the event of blockage on one route;

(6)     Road widths, gradient and turning radii at road junctions shall be designed to facilitate movement of the fire-fighting vehicle envisaged in the event of emergency. Minimum road width of 3.5 M should be maintained for each way. The turning radius at the gantry shall be designed to facilitate the smooth movement of the tank trucks (including trailer mounted);

(7)     Rail spur should be located close to the boundary of the installation to minimise road or pipe crossings and blockage of roads during shunting. The rail spur should be designed in line with the Railway Guidelines;

(8)     Layout should consider the space requirements for—

(i)       Maintenance and inspection of each equipment or facility;

(ii)      Dedicated area for construction or fabrication activities; and

(iii)     Future expansion for addition of facilities;

(9)     Vehicles with spark ignition engine shall not be allowed in the hazardous area. Vehicles with internal combustion engine (compression ignition) such as tank truck (fuelled by HSD) required to be permitted for business shall have Petroleum and Explosives Safety Organization (PESO) approved tank body with approved spark arrestor fitted on the vehicle; and

(10)   Layout drawing indicating hazardous and non-hazardous area segregation or demarcation shall be available. Hazardous area segregation or demarcation shall be as per IS 5572 : 2009.

1.2 LAYOUT OF FACILTIES.—To prepare a layout, information should be collected on all applicable affecting aspects and not limiting to following, namely:—

(1)     Storage tanks, utility requirements;

(2)     Town planning;

(3)     Product receipt or dispatch and mode of transport (Rail, Road, Pipeline and Tanker or Barge);

(4)     Warehouses, storage areas for bitumen or asphalt, lube and like other lubricants and other open storage areas like scrap yards and dumping ground;

(5)     Chemicals or Toxic chemicals storage, Sludge, hazardous waste storage or disposal facilities and like other facilities;

(6)     Service buildings, fire station and allied facilities;

(7)     Site topography including elevation, slope, and drainage;

(8)     Meteorological data;

(9)     Bathymetric data (high tide level, surge wave height and like other tidal surge) for installations in coastal areas;

(10)   Seismic data and probability of Tsunami in coastal areas;

(11)   Highest flood level in the area, water table, natural streams or canals;

(12)   Approach roads for functional areas;

(13)   Aviation considerations to and from adjacent facilities;

(14)   Environmental considerations including water treatment plant and reuse of treated water, rain water harvesting and roof top solar system with connectivity to grid; and

(15)   Statutory requirements.

1.2.1 GENERAL CONSIDERATION.—While locating the various facilities the following should be considered, namely:—

(1)     Tank farm, loading or unloading gantry, utilities, Effluent Treatment Plant (ETP) or mechanised OWS, Drains and culverts and approach roads should be suitably constructed to prevent flooding;

(2)     Control room should be located in a non-hazardous area, upwind (Majority of the year) of hydrocarbon storage and handling facilities and at a distance from potential leak sources. It shall not be located on a lower level than surrounding plants and tank farms. There shall be no structure in close vicinity that would fall on the control room in case of a blast. Control Room should be situated at such a place in the layout from which most of the facilities or activities of the location are visible;

(3)     In case, it is unavoidable to comply with inter distance requirements for control room, the control room shall be made blast resistant;

(4)     The control room for Pipeline Tap off Point (TOP) (if applicable) at the same location of the same company, shall be in the same building where the Control room for Depot or installation is located;

(5)     Utility block should be located outside the hazardous area;

(6)     Overhead power transmission lines shall not pass over the installation including the tank truck parking areas. Horizontal clearance shall be in line with the Central Electricity Authority;

(7)     High Tension (HT) line and HT sub-station shall be terminated or located outside the hazardous area as per distance as specified in Table-1 in this Part;

(8)     Tank truck movement inside the installation shall be kept to minimum and for this purpose the truck loading or unloading facilities should be located at a safe distance near the gate meant for its movement and should be oriented to provide one-way traffic pattern for entrance and exit. Tank truck in the gantry shall always be in drive out position for easy escape in case of emergency;

(9)     Rail loading or unloading facilities should be located along the boundary of the installation. In case Tank wagon (TW) unloading facilities are located outside of installation boundary that should also have a boundary wall as per MOHA or Government Guidelines;

(10)   Drain shall be provided around the TT gantry loading platform area to collect product due to accidental spill over or leakage and shall be routed to OWS or ETP. The drains shall always be maintained clean;

(11)   Effluent Treatment Plant should be located at a distance as per distance as specified in Table-1 in this Part. This should be closer to disposal point by the side of the boundary and at lower grade to facilitate gravity flow of effluent;

(12)   Roads should be provided in a symmetric manner to serve all areas requiring access for the operation, maintenance and firefighting;

(13)   Smoking booths shall not be provided in Petroleum Installations, but, drinking water booths can be provided at prominent work stations like TLF, TW siding and like other places;

(14)   Firewater storage and firewater pump house should be located upwind of hydrocarbon storage area with straight approach from outside area to enable easy receipt of mutual aid and make up water;

(15)   The provision shall be made to receive water from external sources directly into fire water storage tanks and this can be from mutual aid members, fire brigade and like other devices;

(16)   All buildings which are not related to terminal operation should be located at upwind of hydrocarbon storage and handling facilities and they shall be located outside the hazardous area, and such areas include administration, canteen with a separate entry and special care needs to be taken for canteen location where any spark or open flame is likely to exist;

(17)   Congestion inside the hazardous area because of buildings, structures, pipelines, trees and like other things shall not be allowed. The location of such addition of facilities in existing installation shall be decided based on Risk Assessment;

(18)   Room for storing hydrocarbon samples shall be provided with bottom exhaust for release of flammable vapours. The racks and flooring should be made of fire resistant material. Electrical fittings as well as electrical equipment shall be flame-proof. Adequate number of portable fire extinguishers should be placed, where required;

(19)   The additives or blue dye and like other substances should be stored at the designated or segregated area as per respective Material Safety Data Sheet; and

(20)   Special precautions should be taken as required where ambient temperatures or the handling temperatures are higher than the flash point of the product or where product handled is artificially heated to a temperature above its flash point.

1.2.2 LAYOUT OF STORAGE TANKS:

1.2.2.1 Dyked Enclosures.—

(1)     Petroleum storage tanks shall be located in dyked enclosures. Each dyke shall have roads all around for access for normal operation and maintenance as well as for emergency handling. Aggregate capacity (Combined safe capacity) of tanks located in one dyked enclosure shall not exceed following values, namely:—

(i)       60,000 KL for a group of fixed roof tanks.

(ii)      120,000 KL for a group of floating roof tanks

Safe Capacity limits do not apply to a single tank in a dyke.

Fixed cum floating roof tanks shall be treated as fixed roof tanks but, in case these tanks are provided with windows opening on the shell and these windows will not get blocked in any case, then they shall be considered as floating roof tanks.

If a group of tanks contains both fixed and floating roof tanks, then, it shall be treated as a group of fixed roof tanks for the purpose of above limits specified in clauses (i) and (ii).

(2)     Dyked enclosure shall be able to contain the complete contents of the largest tank in the dyke in case of any emergency. A free board of 200 mm above the calculated liquid level or 10% of calculated dyke capacity, whichever is higher, shall be provided for fixing the height and capacity of the dyke.

Enclosure capacity shall be calculated after deducting the following volumes, namely:—

(i)       Volume of the tanks other than largest tank up to enclosure height without free board;

(ii)      Volume of all tank pads;

(iii)     Volume of fire breaks walls; and

(iv)    Volume of pipes/supports or steps and like other volume.

(3)     The height of tank enclosure dyke (including free board) shall be at least 1.0 M and shall not be more than 2.0 M above average inside grade level, and—

(i)       Tank farm area shall be covered through CCTV surveillance system and same shall be continuously monitored;

(ii)      The dyke wall made up of earth, concrete or solid masonry shall be designed to withstand the hydrostatic load and shall be impervious;

(iii)     Dyke enclosure area (inside area of the dyke) shall be also impervious to prevent the ground water pollution;

(iv)    Dyke enclosure (entire area of the dyke) shall have impervious layer of suitable material such as EPDM (ethylene propylene di-monomer) liner or polyethylene sheet to prevent the ground water contamination in addition to brick or stone pitching PCC and like other materials;

(v)      The dyke and the enclosures will be inspected for cracks, visible damage and like other deficiencies. every six months (pre and post monsoons) and after every major repair in the tanks or dykes and like other appliances so as to keep it impervious;

(vi)    The dyke area shall have proper slope outward of tank pad towards the inner periphery of the dyke enclosure to prevent reverse flow;

(vii)   Earth-pits shall be provided outside of Dyke area and strips buried under the earth except at termination points from a shortest possible distance. The earthing lay out diagram of each facility should be displayed near each facility for reference;

(viii)  For excluded petroleum, the capacity of the dyked enclosure should be based on spill containment and not for containment on tank rupture. The minimum height of dyke wall in case of excluded petroleum shall be 600 mm;

(ix)    Pump stations and piping manifold should be located outside dyke areas by the side of roads;

(x)      Horizontal above ground tanks mounted on pedestals shall meet separation distances and shall have dyked enclosure;

(xi)    The construction of dyke exceeding 2 M may be considered where there is severe constraint on space availability. In such case, additionally following conditions must be fulfilled, namely:—

(a)      Total dyke capacity shall be based on containment of largest tank capacity;

(b)      Monitors on raised platforms, if required, shall be provided so that throw of the monitors are not restricted;

(c)      All the tanks inside such dyke shall be provided with sprinkler system, irrespective of the tank dia; and

(d)      Tank farm area shall be covered through CCTV surveillance system and same shall be continuously monitored.

(xii)   In case of Under Ground Tanks:—

(a)      kerb wall of minimum 300 mm height shall be provided in the UG tank Farm Area to contain accidental overflow;

(b)      a minimum of 3 M clear distance around the tank shall be maintained (from structures or boundary wall);

(c)      vents shall be located/terminated at a distance of 15 M from electrical hazards.

(d)      pressure or Vacuum vents for —a class intends that a product and free vents for other class of products shall be provided and vent shall be at minimum 4 M height from the grade level;

(e)      the open end of free vent pipe shall be covered with two layers of non-corrodible metal wire gauze having not less than 11 meshes per linear centimetre and shall be further protected from rain by hood or by suitably bending it downward;

(f)       the petroleum products shall enter a tank through closed piping system or coupled electrically continuous and sound hose;

(g)      under Ground tanks for Ethanol service shall be provided with Silica Gel Traps in the Vents to prevent moisture ingress;

(h)     the manholes should be 30 cm above the grade level; and

(i)       corrosion control measures shall be undertaken.

1.2.2.2 Grouping of Storage tanks.—

(1)     Grouping of tanks in a dyke should be made by grouping the storage tanks in a dedicated dyke according to their respective classification of petroleum product;

(2)     In case, different class of products are stored in any combination of product classification, the following shall, be applicable, namely:—

(i)       Grouping of petroleum products for storage shall be based on the product classification. Class-A and Class-B petroleum may be stored in the same dyked enclosure and such Class—A and Class—B are stored in common dyke, so that fixed water spray system shall be provided on all tanks except for small installations as mentioned in paragraph 5.1.2 (8) of this schedule and the Rim seal fire detection and extinguishing system shall be applicable only to floating roof tanks on Class — A service.

(ii)      Class-C petroleum should preferably be stored in separate enclosure;

(iii)     Where Class-C petroleum is stored in a common dyke along with Class-A and/or Class-B petroleum, the fixed water spray system shall be provided on all Class C tanks irrespective of diameter except for small installations as mentioned in paragraph 5.1.2 (8) of this schedule;

(3)     Excluded petroleum shall be stored in a separate dyked enclosure and shall not be stored along with Class-A, Class-B or Class-C petroleum. In case, it is stored in the same dyke, the requirements that is to say Firefighting, interlocks, alarms, foam and like other requirements shall be in line with the requirements for the Class of product that is to say Class-A or Class-B or Class-C stored in the same dyke.

(4)     Tanks shall be arranged in maximum two rows so that each tank is approachable from the road surrounding the enclosure and such arrangements need not be applied to tanks storing excluded petroleum class;

(5)     Tanks having 50,000 KL capacities and above shall be laid in single row.

(6)     For tertiary containment, provision shall be made to prevent escape of spills due to failure of secondary containment for any reasons and not to allow such spill over to outside of the boundary of the installation that may lead to any damage to outside; and to meet the objective, all installations shall be provided with boundary wall with gates and sluice gates on drain. Pipe line openings and like openings shall be sealed. Efforts should be made to minimize such openings for drainage.

1.2.2.3 Fire walls inside dyke enclosure.

(1)     In a dyked enclosure where more than one tank is located, firewalls of minimum height of 600mm shall be provided to prevent spills from one tank endangering any other tank in the same enclosure;

(2)     A group of small tanks each not exceeding 9 meters in diameter and in all not exceeding 5,000 KL in capacity shall be treated as one tank for the provision of firewall; and

(3)     For excluded petroleum product storage, firewall of height not less than 300 mm shall be provided by limiting the number of tanks to 10 or the capacity of group of tanks to 5,000 KL, whichever is lower.

1.2.2.4 General.

(1)     The tank height shall not exceed one and half times the diameter of the tank or Maximum 20 m, whichever is less;

(2)     Every Piping from or to any tank including connected sprinkler or foam line shall comply the following, namely:—

(i)       It shall not pass through any other dyked enclosure;

(ii)      It shall run directly to outside of dyke to minimise piping within the enclosures; and

(iii)     It shall not pass through other tank areas or fire walls.

(3)     Piping layout design inside tank dyke area should ensure easy accessibility for any operations in the tank farm and wherever necessary, well designed, cross-overs shall be provided to cross the pipelines running within the dyke area. Elevated Catwalks connecting the tank manifold to the dyke wall above the height of the dyke wall shall be provided for safe access and exit in case of normal or emergency situations. The catwalks shall run at the same level and terminate directly outside the dyke;

(4)     No part of the dyked enclosure shall be below the level of surrounding ground immediately around the outside of dyke area;

(5)     The minimum distance between a tank shell and the inside toe of the dyke wall shall not be less than half the height of the tank; and

(6)     Properly laid out road shall be provided for easy access on all four sides of each dyke.

1.2.2.5 Protection of facilities.

(1)     Properly laid out roads around various facilities shall be provided within the depot or terminal for smooth access of fire tenders and like other trends in case of emergency;

(2)     The boundary wall shall be constructed as per the directives of the Ministry of Home Affairs or any other Government directive. In any case the boundary wall shall be of minimum 3 M height from either side of boundary wall with V/U shaped barbed wire fencing on the wall with 600 mm diameter concertina coil on top;

(3)     There shall be a pedestrian patrolling track along the inside perimeter of the boundary wall for security patrolling. Security watchmen tower (if provided) shall have clear access;

(4)     The emergency gate shall be away from the main gate for evacuation of vehicles and personnel in emergency and shall always be kept available and free from obstruction;

(5)     CCTV shall be installed in depot or terminal locations covering entry or exit gate, periphery of installation and all critical operating areas (such as Tank farm, TT or TW operating area, product pump house, fire water pump house and like other places) which shall be monitored continuously;

(6)     The CCTV monitoring station shall be provided in control room, Security cabin and in-charge room. The CCTV data shall be stored for a minimum period of 60 days or in line with prevailing IB norms;

(7)     Proper sized TT parking area based on fleet size shall be provided with following facilities, namely:—

(i)       Well laid out hydrant system with alternate double headed hydrant post and water or water cum foam monitors covering the parking area;

(ii)      Segregation of parking area through chain link fence or boundary wall;

(iii)     Separate entry and exit gate with access control; and

(iv)    Parking lane demarcation or slotting to ensure independent and quick evacuation in emergency.

(8)     Hydrocarbon (HC) detectors shall be installed near all potential leak sources of class “A” petroleum products that is to say that tank dykes, tank manifolds and pump house manifold and such detectors shall be placed in a way that entire possible source of leaks and collection of products are continuously detected and alarm is set at 20% of lower explosive limit of class “A” petroleum products. (Refer clause 5.8.1 for details).

1.2.2.6 Separation distances.

(1)     Minimum separation distances between various facilities specified in preceding paragraph 1.2.2.5 shall be as per Table-1 in this part and the table shall be read in conjunction with the notes specified with the table.

(2)     The layout shall also take into account findings or recommendations Risk Analysis or Assessment study, which shall be carried out at all the stages of facility development process.

1.2.2.7 Separation Distances between tanks or offsite facilities.—The following conditions shall apply for the separation distances for above ground tanks storing petroleum products, namely:—

(1)     For larger installation, minimum separation distances shall be as specified in Table- 2 and Table-3 in this part and the Tables are applicable where total storage capacity for Class-A and Class-B petroleum products is more than 5000 KL or the diameter of Class-A or Class-B product tank is more than 9 meters;

(2)     For smaller installation, minimum separation distances shall be as specified in Table-4 in this part and the Table is applicable where total storage capacity of Class-A and Class-B petroleum is less than 5000 KL and diameter of any tank storing Class-A and Class-B petroleum product does not exceed 9 meters. Table-4 in this Part shall also be applicable for the installation storing only Class-C petroleum;

(3)     Excluded petroleum should be treated as Class-C petroleum for the purpose of separation distances and Table—4 in this Part shall be applicable for their separation distances; and

(4)     Separation distances between the nearest tanks located in separate dykes shall not be less than the diameter of the larger of the two tanks or 30 meters, whichever is more.

TABLE — 1

SEPARATION DISTANCES BETWEEN FACILITIES

General Notes to Table-1:

(a)      All distances are in meters. “T” indicates the Table number in this part to be referred;

(b)      All distances shall be measured between the nearest points on the perimeter of each facility except (i) in case of tank vehicle loading or unloading area where the distance shall be from the centre of nearest bay;

(c)      Service building shall have minimal manning and normally no hot work would be done there;

(d)      “X” means any distance suitable for constructional or operational convenience; and

(e)      Fire station shall be in safe area or at least 60 m from other facilities.

Specific Notes to Table-1:

Note-1 : These distance norms are applicable to the locations where product receipt is through cross country pipelines. At all other locations, the building or room housing, the automation equipments or system shall be treated as utility building for the purpose of separation distance;

Note-2 : The distance shall be 60 meters for non-blast resistant construction and 30 meters for blast resistant construction;

Note-3 : The distance shall be 45 meters for non-blast resistant construction and 30 meters for blast resistant construction;

Note-4 : Separation distances between the nearest tanks located in two dykes shall be equivalent to the diameter of the larger tank or 30 M, whichever is more. For distances within a dyke, it shall be as per Table-2 and Table-3 in this part;

Note-5 : Separation distance between—

(i)       tank truck gantry and tank wagon gantry shall be 50m;

(ii)      distance between two Tank trucks gantries shall be 15 M; and

(iii)     distance between two tank wagon gantries shall be 50 M.

Note-6 : Separation distance between tank truck gantry and rail spur-stabling line shall be 50 M.

TABLE – 2

SEPARATION DISTANCES BETWEEN TANK OR OFFSITE FACILITIES

Applicable for large installations where total storage capacity for Class-A and Class-B petroleum products is more than 5000 kl or the diameter of Class-A or Class-B product tank is more than 9 meters.

TABLE — 3

SEPARATION DISTANCES BETWEEN STORAGE TANKS WITHIN A DYKE

(For large installations where total storage capacity for Class-A and Class-B petroleum products is more than 5000 cum, or, the diameter of Class-A or Class-B product tank is more than 9 meters)

General notes to Table - 2 and 3

(a)      All distances are in meters;

(b)      “x” indicates suitable distance as per good engineering practices to meet construction, operational and maintenance requirements;

(c)      D and d stands for diameter of larger and smaller tanks;

(d)      In Table - 2 all distances shall be measured between the nearest points on the perimeter of each facility except in the case of tank vehicle loading or unloading area where the distance shall be measured from the centre of each bay;

(e)      In Table -3, distances given are shell to shell in the same dyke;

(f)       For different combination of storage tanks, the stringent of the applicable formulae shall be considered for minimum separation distance;

(g)      The distance of storage tanks from boundary wall is applicable for;

(i)       floating roof tanks having protection for exposure; and

(ii)      tanks with weak roof-to-shell joint having approved foam or inert gas system and the tank diameter not exceeding 50 meters;

(h)     Distances mentioned in Table-2 are for electric pump motor located outside dyke, but, for side entry mixer attached to tank shell, the motor can be mounted on the tank shell; and

(i)       For the facilities not covered in Table- 2, refer Table-1.

TABLE — 4

SEPARATION DISTANCES BETWEEN TANKS OR OFFSITE FACILITIES

(For small installations where total storage capacity of Class-A petroleum and Class-B petroleum is less than 5000 kl and diameter of any tank storing Class-A and Class-B petroleum product does not exceed 9 meters. This Table shall also be applicable for the installation storing only Class-C Petroleum and Excluded Petroleum)

General notes to Table —4:

(a)      All distances are in meter and the table specifies the minimum requirement;

(b)      “x” indicates suitable distance as per good engineering practices to meet construction, operational and maintenance requirements;

(c)      “D” indicates the diameter of the larger tank;

(d)      Distances given for the tanks are shell to shell in the same dyke;

(e)      Where alternate distances are specified (like 0.5 D/6.0), the minimum thereof shall be used;

(f)       All distances shall be measured between the nearest points on the perimeter of each facility except in case of tank truck loading or unloading area where the distance shall be from the centre of each bay;

(g)      Pig launcher or receiver at liquid hydrocarbon handling pipeline installations should be located at least 5 m from boundary wall; and

(h)     Distances mentioned in the Table-4 for electric pump motor located outside dyke, but for side entry motor attached to tank shell, the mixer can be mounted on the Tank Shell.

PART — B

(Design Considerations)

2.0 DESIGN CONSIDERATIONS.

(1)     External Floating roof tanks (EFRT) with single deck pontoon roof or Double deck or Internal Floating Roof Tanks shall be designed as per API STD 650;

(2)     Atmospheric or low pressure fixed roof tanks shall be designed as per API STD 650 or API STD 620;

(3)     Selection of type of tank generally depends on ambient conditions and the product handled;

(4)     The external floating roof storage tanks with Pan Roof shall not be used as they are considered unsafe;

(5)     IFRT and EFRT shall be provided with double seal with minimum vapour recovery of 96%;

(6)     Primary seal shall be liquid or shoe mounted for EFRT and vapour mounted for IFRT. Maximum seal gap width should be 4 cm and maximum gap area should be 200 cm2/m of tank diameter;

(7)     Secondary seal shall be rim mounted. Maximum seal gap width should be 1.3 cm and maximum gap area should be 20 cm2/m of tank diameter; and

(8)     Tank bottoms shall be of cone up or cone down (“Apex down”).

2.1 TANK APPURTENANCES.

(1)     Ladders and Handrails shall be such that individual tank shall be provided with access to the roof. A platform with railing should be provided from the top of the stairway to gauge well and roof ladder. On floating roof tanks, non-sparking self-levelling tread type rolling ladder with suitable double earthing connection are to be provided;

(2)     Stairs should be made of grating. All staircases shall have resting or landing platform for every 5m height;

(3)     Number of manholes shall depend on diameter of the tank as per API650; and

(4)     Walkway with handrail on the roof of the tank should be provided to facilitate inspection or checking of vents or flame arrestor and like other devices so that movement of personnel on roof is safer.

2.2 TANK FARMS OR MANIFOLDS:

2.2.1 Tank Farm Drains.

(1)     The dyke drain shall be provided along the inside periphery of the dyke enclosure wall and in case circular drain around tank pad is provided, the same needs to be connected to the peripheral drain;

(2)     The outlet from dyke shall have the provision to either divert to the effluent Treatment plant or OWS or to main storm water drain; and

(3)     Dyke drain Valves shall be provided with position indication and alarm system in the event of opening the valve.

2.2.2 Tank Manifold.

(1)     The number of inlet or outlet connections to the tank shell should be kept minimum;

(2)     Tank body valves on process lines (inlet, outlet and recirculation) of all storage tanks storing class-A and class-B products shall be remote operated shut off valves. Mitigation measures due to sudden closure of shut off valve shall be incorporated in the design;

(3)     The second valve which is motor operated valve (MOV)on inlet, outlet and recirculation lines should be outside the dyke;

(4)     Tank body valves including remote operated shut off valves should remain shut after closure of day operations.

(5)     For positive isolation a suitable Valve other than Hammer Blind shall be provided so that under no circumstances the product is exposed to atmosphere from the valves and in any case Hammer blind valves of any type shall not be used in the depot or terminals.

(6)     ROSOV shall be fail safe and fire safe (shall close in case of signal failure) and the actuator shall be failsafe. The cables leading to the control room shall be fire resistant;

(7)     ROSOV shall have only close operation from control room or at a strategic remote location;

(8)     The Open or Close push buttons of ROSOV shall also be provided in field that is to say just outside the dyke and such push buttons shall have distinctive feature so that opening is different than action required for closing (such as pull type and push type). The push button assembly shall be mounted at a place where it is easily visible and accessible to the operator;

(9)     MOV or DBBV shall have open and close remote operation from control room and at field outside of dyke;

(10)   Tank manifold, if provided, shall be located outside the dyke area. The floor underneath the manifold shall be paved and have Kerb walls and connected to oil water drainage system leading to ETP or OWS;

(11)   Thermal safety valve (TSV) or Expansion line shall be provided for blocked portion of pipe line to take care of the thermal expansion of product due to rise of temperature;

(12)   TSV outlet line or expansion line shall be connected back to tank or tank inlet or outlet line before ROSOV is connected with suitably positioned isolation valve. One isolation valve on TSV outlet line or expansion line shall be installed close to the tank shell or inlet or outlet line to the maximum extent possible;

(13)   The expansion lines to be connected at roof tops in case of CRVTs and through combined gauge well in case of FRVTs or IFRVTs and shall be extended inside up to the tank bottom to avoid freefall of product through vapour space with provision of siphon breaker on top and expansion lines should be provided with class 800 flanged gate valves;

(14)   Termination of expansion line on tank roof top shall not be allowed as free fall through vapour space is unsafe;

(15)   At existing locations where ever the arrangement specified in the paragraph 2.2.2(13) does not exist, the same shall be provided on all tanks during scheduled tank maintenance or cleaning;

(16)   Any electrical fittings and fixtures inside the dyke shall be as per the hazardous area classification. but, such fittings and fixtures except for actuators of ROSOV or MOVs or HC detectors or PESO approved ex-proof water flow switch or ex-proof pressure transmitter should be above the dyke height.

2.2.3 Tank Settlement.—Settlement of tanks takes place over a period of time and a depression is formed on tank pad along the circumference and the same should be effectively made up with proper slope to avoid rain water accumulation and subsequent corrosion of the bottom plate and where large settlement is anticipated, supporting arrangement for the connected piping shall be suitably designed to take care of the settlement.

2.3 TANK HEATERS.—Tank heating can be accomplished either by steam heating or electric tracing or hot oil circulation and Heating flues using fired burners shall not be permitted.

2.3.1 Heaters.—Tank heaters shall be designed to hold the product at the specified storage temperature when tank is filled up to safe filling height. For design calculations, it is necessary to specify average wind velocity and minimum ambient temperature over extended period of time.

2.3.2 Steam Heating.—Manway and such heaters consist of a tube bundle, usually of hairpin type, fixed through a manhole of the tank and such heaters shall be designed so that its removal can be done without the requirement of person entering in the tank. Steam coils should have no flange connections inside the tank and provision should exist in condensate outlet lines to check for oil leak. Gradient of the coil bundle inside the tank should be such that condensate accumulation is avoided.

2.3.3 Electric Heating.—Electric tracing of one or more courses of shell can be provided, but, the classification and thermal rating of electric tracing should be verified before application and the electric conduits and cabling should conform to Classification of Areas for Electrical Installations.

2.3.4 Crude tanks : Crude tanks may be provided with side entry swivel angle type mixers.

2.4 DRAINS FROM THE TANKS:

2.4.1 Bottom Drains.

(1)     Drains should be provided in all tanks for draining water and also for emptying out the tank for cleaning and such arrangement would also be useful for draining water after a hydro test or initial flushing during a start-up operation. Number and details of the drains shall be as per the applicable tanks design standard.

(2)     Each drain line shall have minimum two isolation valves separated by spool piece and pipe shall be extended beyond tank pad up-to drain point. One of such valves shall be of quick closing type. Ends of each drain point should have provision of blind flange or capping arrangement.

2.4.2 Floating Roof Drains.

(1)     Roof drain shall be of robust design to prevent oil coming out during draining operation. Maximum hourly rainfall rate during the past 15 years shall be considered for designing the number and size of drains for open floating roof tank. Rain water should not be taken directly into the tank;

(2)     The roof drain system shall have provision for connection to the drain through a suitably designed robust system and shall include a suitable outlet valve;

(3)     Due care shall be taken while designing to ensure the system integrity and performance when roof is resting on the low legs; and

(4)     The inlet of roof drain shall have a check valve to prevent product from flowing to the roof in the event of failure of the system.

2.4.3 Emergency Roof Drain.—Emergency drain for floating roof tank shall be provided on the roof to take care of disposal of water in case of choking or malfunctioning of the primary roof drain. It shall have water seal arrangement to prevent oil spill on the roof.

2.5 VENTS:

2.5.1 Open Vents.—Flash Back Arrester (Flame arrester) should be fitted to Vents as per IS 11006 : 2011. For sizing the vents API STD 2000 is to be referred and the following are the basic guidelines need to be considered, namely:—

(1)     Maximum and minimum ambient temperatures;

(2)     Vapour pressure of the product at operating or design temperature;

(3)     Maximum pumping in and out rates. In the event of change in any operating parameters involving change in pumping rates complete end to end system check shall be done in line with Management of Change; and

(4)     Blending components likely to be handled in the tank.

2.5.2 Breather Valve.

(1)     The breather valves for the blanketed tanks and low-pressure tanks shall be provided as per API STD 650 and API STD 620 respectively and the tank breathes - in air will be when the tank pressure is lower than the atmospheric pressure and breathes-out will be when tank pressure is greater than the set pressure;

(2)     Pressure and Vacuum Relieving Valves (PVRVs) provided on cone roof tanks usually have 20% accumulation and while designing, it is necessary to ensure that under full relieving conditions, the design pressure or vacuum in the tank is not exceeded. Set pressure of PVRV shall be decided according to API STD 2000.

(3)     Breather vents or flame arrestors are known to fail through the formation of crystalline waxy or heavy hydrocarbon deposits or ice on the seats of valve diaphragms or inside the nozzle connection upon which the valve is mounted, as such Breather vents or flame arrestors shall not be recommended on these services, instead only open vents should be provided; and

(4)     Where tanks are blanketed, breathing-in will be from the blanketing gas system and necessary control valve shall be provided for supply of blanketing gas at constant pressure. The tank shall be provided with a safety valve by way of lift disc or diaphragm or any other suitable device. Gauge hatch and other manholes shall be of gas tight construction.

2.5.3 Emergency Vents.—Emergency Vents shall be provided for the tanks as per API STD 2000.

2.6 DIP HATCH OR SAMPLING.

(1)     Dip hatch or gauge hatch is used for gauging the height of the liquid in a tank as well as to take out samples for testing as such, the gauge hatch shall be non-sparking (or lined with non-sparking material) and self-closing type;

(2)     Gauge well pipe should be provided with slots; and

(3)     The gauge well shall be properly supported by means of angles or strips with bottom plate of the tank and such arrangement also makes the tank safer with respect to dissipation of static charge accumulation.

2.7 INSTRUMENTATION:

2.7.1 Safety Integrity Level (SIL).—The SIL classification study shall be carried out to determine the required SIL level. SIL of the safety instrumented function for the tank including overfill protection shall meet the requirement of Part 1 of IEC 61511. The SIL level of the entire interlock loop shall also meet the requirement of IEC 61511.

2.7.2 Level controls on Tanks.—For all storage tanks storing Class A/B products, the following instruments or alarms shall be provided, namely:—

(1)     High Level (H), High High Level (HH) alarms, that is to say that each tank shall have provision of level instruments for sending audio visual alarms to the control rooms. All the alarms shall be of different type so that the “H” level alarm and “HH” alarms can be distinctively identified;

(2)     Level for “H” and “HH” alarms shall be decided based on site specific operating parameter that is to say diameter of tank, flow rate and operators response time for corrective measures to stop product level reaching curb angel or maximum floating position, but such, these levels shall be lower than the level corresponding to PESO approved safe filling capacity;

(3)     Independent level switch shall be provided at the “HHH” which in any case shall not be above the level corresponding to PESO approved safe filling capacity of the tank;

(4)     The level switch shall enable initiation of action for closure of the respective inlet valve that is to say the ROSOVs, MOVs and product pumps so that the entire receipt operation closes on safe mode and the product does not over flow;

(5)     Two nos. independent level instruments shall be provided out of which one instrument shall be of radar gauge type and each of the instruments shall have provision both for “H” and “HH” alarms. Provision shall be made in the system configuration for transmitting only two signals (one for “H” and one for “HH”). The signals that is to say the “H” and “HH” from each level instrument shall be available parallel in the control room using OR gate PLC logic;

(6)     Over spill Level switch, that is to say that an independent hardwired level switch like Vibrating Fork and like other switches shall be provided for actuating remote operating shut off valve. Over spill level switch should be connected to remote operating shut off valve through safety PLC for SIL loop compliance;

(7)     For tanks storing class that is to say that C products two nos. independent level instruments shall be provided out of which one instrument shall be of radar gauge type. Each of the level instruments shall have provision for both “H” and “HH” alarms and the signal transmitting shall be as so explained;

(8)     There shall be exchange of signals between the receiving and dispatch location in case of receipt of product through cross country pipe lines and provision shall be made for monitoring of level of the receiving tank along with pressure in the pipe line and ROSOV status and to ensure safe shut down of the system in case of any abnormal situation; and

(9)     Care need to be taken for tanks receiving product from ship or cross country pipeline at high flow rates for surge pressures due to sudden closures of valves and accordingly where ever required, suitably designed Surge relief system or pump tripping to be provided.

2.7.3 Tank farm management system integration.—TAS (terminal automation system) including TFMS (tank farm management system) shall be integrated with software for back up at remote location (DRC) with provision for recording of all critical events in the system and back up data shall be retained for a minimum period of 30 days and if in the event, the backup data is proposed to be stored within the same installation then, and if in the room for storing the backup data shall be blast resistant at a secured place.

2.7.4 Temperature and Insulation.—When product storage temperatures are likely to be higher than 100°C, a remote temperature indicator with alarm should be provided in addition to local indicators. For tank capacity higher than 5000 kl a minimum of two numbers of local temperature indicators should be so located (within 500 mm above the inlet or outlet nozzle) as not to sense the direct heat of the coil. Insulation shall be provided for heat conservation. The tanks having higher surface temperature shall have insulation up to minimum 2 meters high for personal protection and also, patch insulation should be provided on the shell along with spiral stairway and provision for inspection.

2.8 PIPING OR VALVES OR FLANGES:

2.8.1 Piping.

(1)     Piping shall be designed for handling of hydrocarbon liquid as per “ASME B 31.3 : Process Piping” or ASME B 31.4 (for cross country pipelines only entering the terminal) or API 5L or equivalent as applicable;

(2)     Pipe joints should be welded as far as practicable with full penetration weld and number of flanged or threaded joints should be kept to a minimum;

(3)     In case sampling point is provided on receipt line for operational requirement, the same should be provided outside of dyke in the manifold;

(4)     Sectionalizing of the pipe lines with isolation valves and arrangements for injection or draining of water shall be provided for facilitating hydro-testing of the pipe lines;

(5)     Buried piping shall be protected against physical damage and corrosion with suitable protective coating;

(6)     At road crossings, in addition to protective coating, pipes should pass through secondary encasing with properly sealed at both the ends;

(7)     The pipe lines should be provided with low point's drains and high point vents to facilitate emptying or hydro-testing and like other testings and ends of each drain point shall have provision of blind flange or capping arrangement; and

(8)     Jetty lines should be provided above ground properly spaced and approachable to maintain the lines.

2.8.2 Valves.—Steel valves conforming to relevant API standards shall be used. Cast iron valves should not be used.

2.8.3 Fittings.

(1)     Steel flanges and flanged fittings shall conform to relevant ASME or ASTM or ANSI or equivalent;

(2)     Slip on or weld neck flanges should be used;

(3)     Screwed flanges for sizes 50 mm or smaller may be used;

(4)     Steel flanges should conform to the applicable provisions of ASME B 16.5 or equivalent;

(5)     Steel screwed fittings and couplings shall conform to ASME B 16.11 or equivalent;

(6)     Steel unions shall have ground metal to metal seats. Gasket type unions shall not be used;

(7)     Plugs shall be of steel. Cast iron or brass plugs shall not be used; and

(8)     Electrical continuity across flange joints shall be maintained by providing metallic gaskets or jumpers.

2.9 BULK LOADING OR UNLOADING OPERATIONS:

2.9.1 Loading or unloading Pumps.

(1)     Pumps conforming to relevant API standards shall be used;

(2)     Product pumps shall be provided with suitable sized strainers on suction and NRVs on discharge lines. All drain points of strainers shall be provided with double isolation valve and ends having provision for blind flange or screw capped;

(3)     Pumps shall be located in an exclusive paved area with drainage facilities routed to OWS or ETP;

(4)     Tank lorry loading or unloading pump house shall be positioned at an elevated level and shall be well ventilated on all four sides;

(5)     Open roof Pump house are to be provided with suitable IP protection for the equipment;

(6)     In case of sunken pump house for Tank Wagon unloading facilities, Pump house shall be so positioned that it ensures proper ventilation and efficient disposal arrangements of accumulated products;

(7)     To avoid wide variation in pressure, leading to a ‘kick’ or ‘hammering’ in header and hoses, it is necessary to choose pumps with flat characteristic curves;

(8)     Locations having automation shall be provided ESD feature through Automation system;

(9)     Dedicated pumps for individual products shall be provided. Minimum one stand by pump for each product shall be provided;

(10)   Separate pumps shall be provided for Tank truck loading/unloading and wagon loading or unloading; and

(11)   All closed sections of pipings shall be provided with thermal safety relief device to relieve pressure due to ambient temperature rise. Thermal Safety relief device may vent into a tank or piped to OWS located in safe area and when connected to tank, TSV shall be provided with isolation valves. One isolation valve shall be installed close to the tank shell to the maximum extent possible. The vent should be piped to closed blow-down system.

2.9.2 Tank truck and tank Wagon Loading Gantries.

(1)     Loading points shall have quick shut-off valves such as Cast steel Plug or Ball Valves;

(2)     No vehicle shall be loaded at a rate exceeding (volumetric flow rate corresponding to linear velocity one meter per second at the delivery (at the least dia fitting) and of the filling pipe until the filling pipe is completely submerged in petroleum and thereafter the loading rate should be gradually increased but it shall at no point of time exceed six meters per second at the delivery end of the filling pipe;

(3)     Location should be provided with facilities where loading and unloading of Tank trucks is possible in a closed loop system that is to say top or bottom loading provisions with Vapour Recovery System;

(4)     Where flow indicators or totalizers are provided for gantries, vapour eliminators shall be incorporated;

(5)     The provision for Kerosene and MS or Naptha loading in TT (tank truck) loading gantry shall not be in the same bay;

(6)     For safety reason the level adjustment in the tank lorry compartments should be done through suitable system wherein product is not exposed in open atmosphere at any point of time;

(7)     In case of loading hoses, only neoprene impregnated hoses having electrical continuity between nozzle and flange shall be used;

(8)     All tank wagons and tank trucks shall have a fill pipe extended up to the bottom to avoid splash filling;

(9)     The splash filling is permissible for asphalt loading in tank truck or tank wagons;

(10)   Where bottom loading is done, deflector plates in the trucks to be ensured;

(11)   Bottom flameproof lighting shall be provided for night time checking of wagon bottom leaks and also for proper sealing and inspection, wherever loading or unloading during night is required to be done;

(12)   Loading gantry should be provided with at least one suitable explosion-proof telephone or paging device for communication with pump house, control room and like other communication in normal and emergency operations and in addition, operating personnel shall be provided with intrinsically safe walky-talky suitable for use in oil installations;

(13)   Tank wagon and truck loading gantries shall be suitable for all weather conditions;

(14)   Tank Truck loading gantries shall be provided with safety harness to protect the operating crew against fall from height;

(15)   Swing type loading ladders with counter weight and hand railing shall be light in construction. Neoprene packing shall be provided at the bottom rest to avoid spark generation due to impact.

(16)   Proper handrail arrangement shall be provided on platforms and stairs for safe movement of personnel;

(17)   Adequate safe escape ladders including from overhead platform shall be provided at intervals on the gantry for emergency use and escape ladders shall be prominently identified from distant view;

(18)   Protection against pressure surge in the loading header due to sudden change in loading rate need to be considered and provision of shock absorber as one of the surge protection method at suitable locations on rail or road loading header should be considered;

(19)   Provision shall be made for quick isolation of main product headers in case of emergency and for such purpose, suitable type hand operated valves or remote operated valves shall be considered as per the site conditions and overall automation system in the installation;

(20)   Loading gantry area including areas below railway lines shall be paved for smooth draining and collection of spillages into drains;

(21)   Open drains along the railway line or gantry shall be covered with gratings so as not to endanger movement of personnel;

(22)   All trucks entering truck loading gantry shall be PESO approved and provided with approved spark arrestor or flame arrestors at the exhaust. The Vehicle conforming to emission level BS IV and beyond are exempt from fitment of spark arrestor;

(23)   Oil and water collected from loading or unloading areas shall be routed to Oil water separator system or Effluent Treatment Plant or similar facility and a slop tank should be earmarked for storing separated oil;

(24)   The tank truck gantry shall be so designed that all the compartments of the tank truck are filled at one bay only. The layout shall ensure that all operations are planned in a manner so that no zigzag movement of the tank truck around the gantry should take place;

(25)   For tank wagon gantry where placement of tank wagon is by electrical LOCO, traction line must terminate 15 M short of the first loading or unloading point at all Installations;

(26)   For placement, brake van or dummy wagons shall be used. Separate segregation gate shall be provided at terminating point and area between boundary wall and segregation gate should be declared de-licensed;

(27)   Main railway track shall be isolated from wagon gantry siding at least 15 meters from 1st loading or unloading point by providing insulation joint at terminating point and loco shall stop before the insulation joint; and

(28)   Sampling points shall be provided as per requirement of Industry Quality Control Manual (IQCM).

2.10 Design layout for handling of sick wagon.—When a wagon is found leaking during loading, provision shall be kept for safe handling of such wagons and such methods should include the following, namely:—

(1)     Arresting of leaks using cold weld as a first aid measure till the wagon is unloaded safely at the gantry itself and in no case such wagons to be used for transportation;

(2)     A dedicated drain header for instantaneous unloading of the sick wagons shall be provided and alternately, the existing headers may be utilized for immediate decantation of product from sick wagons by providing suitable arrangements in the manifold; and

(3)     A portable pump with flame proof or explosion proof motors and other electrical fittings to be used with suitable flexible hose connection for quick withdrawal of products into sump tanks and such drained products to be handled further as per IQCM (Industry Quality Control Manual).

2.11 Design Layout for handling slop:

2.11.1 Collection and Drainage.—A network of drainage system shall be provided to collect oil drains from various equipments, gantry areas, pump houses and like other passages and they should also collect surface drains from places where oil spillages are likely to occur and such drainage shall lead to OWS or ETP as the case may be.

2.11.2 Mechanised OWS.—The receiving sump of the OWS shall have suitable arrangement for skimming off upper layer of accumulated oil and provision shall be made for directing the collected oil to the slop tank.

2.12 Layout and Selection of electrical equipment.

(1)     Electrical equipment including the lighting system shall conform to hazardous area classification. The hazardous area shall be classified as per IS : 5572. The electrical fittings or equipment in the respective classified area or zone shall be of a type suitable for the particular area or zone as per classification in line with IS : 5571;

(2)     Electrical equipment shall be selected, sized and installed so as to ensure adequacy of performance, safety and reliability and the equipment in general shall conform to relevant Indian Standards and shall be suitable for installation and satisfactory operation in the service conditions envisaged;

(3)     The protective system shall be designed to ensure Protection of Personnel and plant equipment against damage which can occur due to internal or external short circuits, overloading, abnormal operating conditions, switching, lightning surges, and like other damages accordingly, relays and protective devices shall be suitably selected and installed. All the protective relays for the Generator, Transformer, Motors and Switchgears shall be tested at least once in a year and test records maintained;

(4)     The outer PVC sheath of all cables used inside the dyke shall be fire retardant type conforming to category AF as per IS : 10810;

(5)     All cables shall be laid in proper cable trenches or cable trays suitably designed to ensure their protection and identification at all times;

(6)     All power and control cables shall have extruded inner and outer sheaths and such cables should be Aluminium or Copper Conductor, PVC or XLPE insulated, PVC sheathed and armoured type;

(7)     Instrument and signal communication cables shall not be laid in the same trench or tray along with electrical cables and the overall cable layouts shall be designed for minimum interference between signal and power cables; and

(8)     Cable route markers shall be installed at every 30 metres intervals all along the cable routes and also at cable joints and locations where the direction of cable trench changes.

2.12.1 Earth resistance.

(1)     Earth resistance can be directly read through an earth resistance tester which has associated Test, auxiliary Current and Potential electrodes and such instrument shall be a combination of ohmmeter and generator works on ‘fall of potential’ principle and the test voltage shall be derived from the generator of the earth resistance tester. Earth resistance also can be measured through Direct Earth Clamp Tester (DECT);

(2)     The testing of the Earth Pits shall be done six monthly, once in dry and once in wet weather and records thereof shall be maintained;

(3)     Removable link shall be provided to allow measurement of an earth electrode-resistance;

(4)     The resistance value of an earthing system to general mass of the earth should not exceed,—

(i)       4 Ohms for electrical systems and metallic structures;

(ii)      7 Ohms for storage tanks;

(iii)     1 Ohm for main earth grid, and bonding connections between joints in pipelines and associated facilities; and

(iv)    2 Ohms for each electrode to the general mass of the earth.

(5)     Earth resistance can be directly read through an earth test Megger which has associated Test, auxiliary Current and Potential electrodes and such instrument shall be a combination of ohmmeter and generator works on ‘fall of potential’ principle and the test voltage shall be derived from the generator of the Megger.

2.12.2 INSTALLATION EARTHING.

(1)     Installation earthing design shall be carried out in accordance with the requirements of Central Electricity Authority Regulations -2010 and IS : 3043 or equivalent system recognised by statutory authorities under the law in force relating petroleum and electricity and all earth connections should be visible for inspection to the extent possible. The earthing system shall have an earthing network with required number of earth electrodes connected to it.

(2)     Earthing system shall be designed for the following, namely:—

(a)      System neutral earthing;

(b)      Protective Equipment Earthing for personnel safety;

(c)      Protection against Static discharges;

(d)      Lightening Protection; and

(e)      Earthing for Data Processing system.

2.12.2.1 Electrically independent earth electrodes.

(1)     Earth electrodes shall be located at such a distance from each other so that the maximum current likely to flow through one of them does not significantly affect the potential of the other;

(2)     The Lightning Arrestor (LA) of the Two Pole or Four Pole structure shall be connected to two distinct earth pits. The strips shall run on insulators or isolators so as not to come in contact with the Pole structure. Connections shall be made to the pit directly and then pits will be connected to each other to form a grid. The Grid of LA shall be distinct and shall not be connected to any other earth Grid;

(3)     The Two Pole or Four Pole structure shall be earthed with two distinct earth connections. The Gang Operated Switch shall also be earthed;

(4)     Fencing of Two Pole or Four Pole, Transformer yard shall be earthed and also electrical continuity between various structures the fencing shall be ensured;

(5)     The Neutral of the Transformer shall be earthed with two distinct earth pits separately. Connections will be made to the pit directly and then pits will be connected to each other to form a grid and such Grid shall be distinct and shall not be connected to any other earth Grid;

(6)     The Neutral of the Diesel Generator shall be connected to two distinct earth pits separately. Connections shall be made to the pit directly and then pits will be connected to each other to form a grid and such Grid shall be distinct and shall not be connected to any other earth Grid;

(7)     The transformer body shall be earthed at two points separately leading to earthing system;

(8)     All Metallic non-current carrying parts of all electrical apparatus shall be earthed to ensure that the exposed metallic parts do not become dangerous by attaining high voltages i.e. exceeding 650 volts in case of faults.

(9)     All the electrical equipment operating above 250 volts shall have two separate connections to the earth Such as Sub Station Panels, Motors, FLP JBs and like other separate connections;

(10)   All Steel structures, loading platform or gantries and like other structures shall have two separate and distinct connections and such connections will be made to the pit directly and then pits will be connected to each other to form a grid; and

(11)   Product Storage Tanks and like other storage chamber shall have two separate and distinct connections and each connection will be made to the respective earth pit directly, then, such earth pits should be inter-connected to form a dedicated grid for Tank Farm. The number of earth pits or connections to be increased for large tanks so that the distance between the connections does not exceed 30 meters on the tank perimeter.

2.12.3 Bonding.

(1)     All flanged connections shall be effectively bonded by strips of suitable material.

(2)     Continuity between rail spur and gantry in tank wagon loading or unloading gantry shall be ensured by checking at a suitable frequency. The gantry structure to be suitably earthed in earthing pits of standard specifications and the tank wagon siding to be insulated from main running track.

(3)     In tank truck loading and unloading gantry, 6 mm Sq. braided copper wire with one end firmly bolted to the Loading Unloading Arm or hoses and the other end provided with G.I or Copper or Non-corrodible metal crocodile clips shall be used and the crocodile clips being attached to the tank-truck under loading or discharging, for External Bonding of Loading unloading arms or hose with the Tank Truck.

(4)     For sampling jars to be inserted into product tanks, use only manila or sisal ropes.

2.12.4 Static earthing.

(1)     Static earthing (earthing for static charge dissipation) shall be provided at Tank Lorry or Wagon Filling or Decantation Gantries, to prevent building up of Static Charges; and

(2)     Earthing connections for static charge dissipation, electrical system, structure and instrumentation system shall be separate from each other, but such separate leading strips can be connected with main grid below the ground.

2.12.5 Lightning Protective System.

(1)     Lightning protection shall be provided for the equipment, structures and buildings which are higher than 20 meters or as per the risk index analysis worked out as per IS 2309;

(2)     Self-conducting structures (having min thickness 4.8 mm) do not require lightning protection with aerial rod and down conductors and they shall be connected to the earthing system at two points of the base; and

(3)     If lightning arrester is provided an independent earthing network shall be provided for lightning protection.

2.12.6 Earthing for data processing system.

(1)     Low noise earthing is required for critical data processing equipments and such earthing shall be independent of any other earthing of the Building. The RFI (Radio frequency interference) suppression filters fitted to the data processing equipment may produce high earth leakage current and in such cases failure of protective earth connection may lead to high touch voltages; and

(2)     Where ever isolation transformers are used the output neutral of the transformer shall be independently earthed so as to ensure that the Earth-Neutral Voltage is less than 1 volt.

2.12.7 Minimum Permissible Sizes of the Earthing Conductors:

Size of the conductor shall be selected, based on the fault current that is required to be dissipated during emergencies.

2.12.8 No of earth pits.—The earth is a minimum requirement and additional earth pits shall be made such as to maintain Grid Values below 1 Ohm.

2.12.9 General.

(1)     Fail safe Interlock or change over switch shall be provided between the Grid Power and the DG power to ensure that the equipments get supply from one source only;

(2)     Insulation mats shall be provided in the Sub Station, control panels and like other points;

(3)     Relays/Cables shall be tested once in a year and records maintained.

(4)     Transformer oil shall be tested once in a year and records maintained.

2.12.10 Emergency Feeder.—Emergency Feeder shall host the Jockey Pump, Critical lighting, Fire Siren, Borewell, Gate Barrier, safety instrumentation and interlocks such as CCTV, Hydro Carbon detector, Dyke drain valve system, UPS of automation and supply to essential fire-fighting equipment.

2.13 INSTALLATION LIGHTING.

(1)     Sufficient lighting shall be provided so as to enable terminal operators to move safely within the accessible areas of installation and to perform routine operations. In the event of normal power failure, emergency lighting shall be provided in critical areas;

(2)     Normal lighting system shall be on 415/240V AC supply. Emergency lighting shall be provided in critical areas like Sub-Station, D G Room, Control Room and Security cabin;

(3)     Under normal operation, both emergency and normal lighting shall be fed by normal power source. On failure of normal supply, emergency lighting shall be available until the start of D.G.;

(4)     Lighting shall be provided for the various facilities in the Depot or Terminal as per good engineering practice;

(5)     The Illumination in the operational areas including inside the dyke and manifold shall be such that adequate visibility is there at all times for emergency and normal operations;

(6)     Lighting requirements provided during the failure of power supply is intended broadly to such failure;

(7)     Facilitate carrying out of specified operations, for safe shutdown of the installation;

(8)     Gain access and permit ready identification of firefighting facilities such as fire water pumps, fire alarm stations and like other facilities;

(9)     To gain access to escape route for safe evacuation of operating personnel; and

(10)   Depending on the nature of job activities carried out, the minimum illumination levels for various areas shall be as specified in the table below, namely:—

Notes:

(a)      The lighting fixtures on various circuits shall be suitably designed so that failures of any one circuit do not result in complete darkness.

(b)      Switches controlling the lighting fixtures and exhaust fan shall be installed outside the battery room.

(c)      Switches of lighting panels installed in hazardous area, shall have a pole to break the neutral, in addition to the poles for phases.

(d)      Low pressure sodium vapour lamps shall not be installed in hazardous areas.

PART — C

(Safe Operating Practices)

3.0 Safe Operating Practices.

(1)     Operational safety aspects for Petroleum Product terminal or depot shall be built into the design which should also be reviewed during the construction phase from safety or maintenance point of view and only skilled and trained personnel shall be deployed for effective operation, inspection, maintenance and like other work for the installation;

(2)     The operating procedures shall provide plant specific instructions on what steps to be taken or followed while carrying out Start-up, Normal operation, Temporary operation, Normal shut-down and Emergency operation and shut-down;

(3)     Manuals of operating procedures shall be made available to the employees. Training shall be imparted to the operators on operating procedures and should be certified as competent;

(4)     When changes are made in facilities, operating procedures should be reviewed as part of the management of change procedure. In addition, operating procedures should be reviewed periodically to verify that they reflect current and actual operating practices. Operating manuals should be certified as updated by authorized or competent person every year; and

(5)     The Safe Operating Practices (SOPs) mentioned in paragraph 3.1 shall outline the general guidelines and are not intended to override sound engineering practices and safety parameters regarding when and where the operating procedures should be used and any additional steps that may be sought to be included to ensure process safety.

3.1 Safe Operating Practices (for general guidelines), namely.—Safe Operating Practices to outline the general guidelines shall include the following

(1)     Terminal or depot Control room where ever provided shall be manned on continuous basis during operations and in emergency;

(2)     No Person shall be allowed to smoke, carry matches, lighters, flammable material or any other appliances capable of producing ignition or explosion inside the licensed area of the installation;

(3)     Non-flame proof or Non-intrinsically safe Mobile phones and any other source of ignition shall not be allowed inside the Petroleum Installation operational areas where petroleum products are stored pumped and handled;

(4)     Site specific Standard Operating Procedures (SOPs) for each operation or activity shall be developed and complied with;

(5)     SOPs shall be periodically reviewed, updated and records and maintained especially whenever any changes or modifications to the facilities are made as per Management of Change procedure (MOC);

(6)     The critical operating steps based on Safe Operating Practices (SOPs) shall be displayed on the board near the location wherever applicable. In local language also and shall be made simple and user friendly;

(7)     All operations shall be carried out under supervision of designated personnel;

(8)     All precautions shall be taken to ensure isolation of sources of ignition during maintenance (such as welding, cutting, and other process) from potential sources of flammable vapours. Presence of vapour at location of maintenance and its surrounding shall be constantly monitored by suitable portable device for flammable gas detection;

(9)     Maintenance or repair work or entry into confined space including closed drains or manholes shall be carried out in accordance with the Work Permit System;

(10)   Non-Sparking tools shall be used to carry out the maintenance jobs in operational areas where flammable materials are handled or stored;

(11)   Check list for operators for monitoring and checking safety system and equipment shall be prepared, followed and records maintained thereof;

(12)   Roads inside the hazardous area of Installation shall be restricted to vehicles required for operational, maintenance and safety or security reasons and allowed only with proper safety fittings and authorization from designated officer;

(13)   Vehicles with internal combustion engine (compression ignition) such as tank truck required to be permitted for business shall have Petroleum and Explosives Safety Organization (PESO) approved spark arrestor fitted on the vehicle. Vehicles with spark ignition engine shall not be allowed inside hazardous area;

(14)   TTs to be parked in drive-out position in parking area having separate entry and exit gates;

(15)   All electrical equipment shall be maintained to ensure its integrity and type of protection as well as electrical area classification;

(16)   Suitable interlocks shall be provided for tripping or alarm or remote valves operation based on the events such as low level, high level, high-high level, high pressure, low pressure and like other events;

(17)   The contents of the dyke drain generated from draining of tanks, any other spillage or effluent containing oil shall be diverted to Oil Water separator (OWS) or Effluent Treatment Plant for safe disposal;

(18)   Personnel protective equipment such as safety shoe, hand gloves, apron, safety goggles, safety belt, helmet, ear muff, dust respirator, self-contained breathing apparatus (SCBA), resuscitator, fire proximity suits and like other protection equipments as applicable shall be worn while carrying out operations in normal and emergency situations;

(19)   Intrinsically safe handsets working on VHF or UHF or any other acceptable frequency band shall be used in operating areas;

(20)   Manning level in the shift shall be adequate to ensure coverage for normal and emergency operations;

(21)   The Petroleum Installation shall have provisions for handling leakage or spills at high risk areas, tank lorries and tank wagons;

(22)   Hydrocarbon Gas detection system shall be installed with audio or video alarm system in the control room as well as in the effective risk zones or areas;

(23)   All personnel who are handling petroleum products shall be suitably trained on use of firefighting, equipment and first aid. Thorough training shall be incorporated to all personnel on various levels of emergency response;

(24)   All other contract personal and supervisors entering the premises shall have basic safety training and should be aware about emergency duty and knowledge of the emergency exit route at all work locations;

(25)   The Petroleum Installation shall have effective CCTV system covering the entry or exit gate roads, periphery of installation and all critical operating areas (such as Tank farm, TT or TW operating area, product pump house, Fire water pump house and TT Parking area and like other areas) which shall be monitored continuously; and

(26)   The CCTV monitoring station shall be available in Control room, Security cabin and Depot in-charge room. The CCTV data shall be stored for a minimum period of 60 days.

3.2 Tank Farm area.

(1)     Ladders and Handrails of the product tank shall be free from any obstruction and to be in impeccable condition. The platform and railing on the top of the stairway to gauge well and roof ladder should have free access. Walkway with handrail on the roof of the tank should be inspected or checked, so that movement of personnel on roof is safe;

(2)     The tank farm management system shall be integrated with Enterprise Resource Planning (ERP) or Terminal Automation System (TAS) with provision of recording and display of real time inventory levels and ensure the effectiveness at regular interval and whenever the system is by pass, all necessary record shall be maintained;

(3)     Dyke drain Valves shall be provided with position indication and alarm system in the event of opening the valve. The dyke drain shall be provided along the inside periphery of the dyke enclosure wall and in case circular drain around tank pad is provided, the same needs to be connected to the peripheral drain. The outlet from dyke shall have the provision to either divert to the effluent Treatment plant or OWS or to main storm water drain;

(4)     Dyke drain valves shall be in closed condition and shall be operated only under supervision of an authorized person and log book maintained. Piping through dyke wall, if any, shall be sealed to make dyke impervious;

(5)     All electrical fittings and fixtures inside the dyke shall be as per the hazardous area classification and its integrity maintained;

(6)     The dyke and the enclosures shall be inspected for cracks, visible damage and like other damages every six months (pre and post monsoons) and after every major repair in the tanks or dykes and like other devices so as to keep it impervious;

(7)     All the tanks inside the dyke shall have fire-fighting system in operating condition;

(8)     There shall be ensured “No” chocking of water spray nozzles.

(9)     The dyke area shall have proper slope outward of tank pad towards the inner periphery of the dyke enclosure to prevent reverse flow;

(10)   The Remote Operated Shut Off Valve (ROSOV) and Motor Operated Valve (MOV) of the tanks and pipeline manifold (inlet, outlet and recirculation) of all storage tanks storing class A and class B products shall be operational and should remain shut after closure of day operations;

(11)   ROSOVs and MOVs shall be fail safe and fire safe (shall close in case of signal failure). The actuator shall be fail-safe. The cables leading to the control room shall be fire resistant and the ROSOVs shall be operational from the field and also from control room;

(12)   Thermal safety valve (TSV) and Expansion line shall be connected for blocked portion of pipe line to take care of the thermal expansion of product due to rise of temperature. Temperature Safety Valves (TSV's) and downstream valves shall be always kept open and its discharge should be routed to slop collection system and alternatively, the discharge may be connected to a common header and back to the tank through NRV;

(13)   The area floor underneath of the pipeline manifold shall be paved and the Kerb walls or drain connected to oil water drainage system leading to ETP or OWS;

(14)   Product storage Tanks must be periodically inspected and checked for leakages or sweating. Repairs must be immediately carried out, whenever scaling or pitting are observed;

(15)   Movement of floating roof must be smooth during operation. Free movement of rolling ladder must be ensured by proper lubrication of moving parts and ensure free movement of wheels;

(16)   Floating roof deck must be kept clean and free from all foreign materials or dust and like other materials so as to avoid clogging of roof drain sump;

(17)   Tank farm area shall be covered through CCTV surveillance system and monitored;

(18)   Water seal must be maintained in the emergency drain in floating roof tanks and it shall be ensured that adequate water is maintained in the water pot of the emergency drains;

(19)   Proper earthing and bonding shall be maintained and ensured at all times for the tank body, electrical continuity from shell to ladder and from ladder to floating roof;

(20)   Safe Operating Practices (SOPs) for entry on floating roof or confined spaces for maintenance and inspection (when the tank is with product for normal operation) shall consider the following, namely:—

(i)       Floating roof is levelled, free of oil and excessive water and is at higher operating level;

(ii)      Adequate manpower with a canister mask or breathing apparatus and like other apparatus is deputed;

(iii)     A life line with safety belt to be used for entering into confined space and the other end of the line held by the standby person at the top of platform; and

(iv)    In case of requirement of going on floating roof deck for inspection during normal operation, at least one person should accompany the person making the inspection.

(21)   No gauging or sampling of tanks shall be undertaken during thunder or hail storms;

(22)   Water draining from tanks should be done under close supervision as per approved Safe Operating Practices (SOPs);

(23)   Receipt and withdrawal rate from the tanks shall be limited to the design parameters of the tank below and the flow velocity at tank inlet shall not exceed 1 m/s until the inlet is completely submerged;

(24)   Breather vents provided on cone roof tanks shall be checked to ensure normal operation and ensure its effectiveness;

(25)   Special attention shall be given during receipt as well as transfer from the floating roof tanks when roof is in semi floating condition that is to say operating in erroneous zone;

(26)   Safety shoe (Conductive type) shall be worn while gauging, sampling or taking temperatures;

(27)   Tank dip pipes shall be extending to tank bottom and if dip pipes are not provided, give a settling time of 30 minutes after receipt or discharge before sampling or gauging;

(28)   Synthetic fibre cord shall not be used for sampling, dipping, gauging and like other process If in the sampling, gauging, dipping, like other process, equipment is a conductor, the cord must be conductive, such as a metal wire. Metal chains shall not be used, instead Natural fibres such as sisal and manila which have sufficient conductivity to prevent the operator from becoming charged by handling it, can be used;

(29)   There shall be ensured that gauge tapes and other sampling equipment are of non-sparking type;

(30)   During receipt, tank level shall be monitored at regular intervals. Effective communication shall be provided in the tank farms, which may include Intrinsically safe VHF or UHF or any other acceptable frequency band handset and like other devices and such system can also be utilised for communication during emergency;

(31)   Cleaning of tanks should be carried out as per plan in line with the approved Safe Operating Practices (SOPs). Gas oil spray and steam shall not be used for cleaning of Class A and class B tanks;

(32)   Earthing and bonding connections shall be ensured during the entire operating process. The earthing system shall be checked for bonding and earth continuity as required and the records maintained thereof;

(33)   Hydrocarbon (HC) detectors shall be installed near all potential leak sources of class “A” petroleum products that is to say tank dykes, tank manifolds and pump house manifold And such detectors shall be placed in a way that entire possible source of leaks and collection of products is continuously detected and alarm is set at 20% of lower explosive limit of class A petroleum products; Further, hydrocarbon detectors shall be installed near all potential leak sources of class “B” petroleum products as and when such effective and proven detectors are available.

(34)   Fire-fighting system provided for above ground Tanks shall be operational, and the effectiveness of the system to be ensured checked periodically for operation as per design capacity;

(35)   The tank farm must be kept clean and shall be free from dry vegetation;

(36)   OWS system shall be maintained clear by periodic cleaning. End of the vent of Inspection chamber of the OWS system shall be provided with wire mesh. The accumulated oil from the OWS sumps shall be collected and sent to slop tanks at regular intervals;

(37)   Disposal of sludge collected during cleaning of the tanks shall be done as per the applicable guidelines; and

(38)   The product storage tanks shall have level indicators as well level alarms and interlocking with MOV and ESD. The effectiveness of the system or interlocking shall be checked regularly. The interlocking or ESD shall not be bypassed. In case of any such exigency, the approval from authorised person in this behalf shall be taken with requisite precautions and records maintained thereof.

3.3 Bulk handling:

3.3.1 Tank Truck (TT) Loading or Unloading.—Transportation of petroleum products by road is regulated by PESO in accordance with the provisions of the Petroleum Rules, 2002 the carriage by Road act, 2007 (Act 4 of 2007) and the rules made thereunder and the Central Motor Vehicle Rules, 1989, Legal Metrology Act, 2009 (Act 1 of 2010).

3.3.1.1 Before Commencement of Loading or Unloading.

(1)     Open source of ignition shall not be allowed in any part of the Petroleum Installation operational area including tank lorry loading or unloading area;

(2)     The following shall be ensured in a tank truck as per statutory regulations before accepting it for filling, namely:—

(i)       Provision of PV vent, emergency vent, Master valve and other safety fittings;

(ii)      Fire screen between cabin and tank is provided and for such purpose, cabins with metallic back cover without any opening will be considered as fire screen;

(iii)     Provision of 2 nos. of Fire Extinguishers of ISI mark (1 No. × 10 or 9 kg DCP and 1 No. 1 kg CO2 or DCP or equivalent approved fire extinguisher);

(iv)    Spark arrestors of the approved designed shall be welded with the exhaust in front of the vehicle and the vehicle shall have valid Explosive License and RTO certificate along with PESO approved drawings of the tank and such arrangement in case of BS-IV and future models may not be required if exempted by PESO;

(v)      Availability of brazed copper strip for earthing or bonding connection; and

(vi)    Tank trucks should be equipped with ABS.

(3)     The Double pole master switch shall be put off immediately after parking the truck in the position. No electrical switch on the truck shall be turned “on” or “off” during the loading or unloading operation;

(4)     Wheel choke shall be placed at wheels to prevent accidental movement of the truck and hand brakes should also be applied during the entire loading or unloading operation;

(5)     The first process after positioning the truck shall be to provide appropriate earthing and after the loading or unloading operation, earthing shall be disconnected just before the release of the truck;

(6)     Vapour Space of 3% of its capacity shall be kept in each tank truck in respect of Petroleum Class A and Class B products and 2% vapour space in tank trucks in respect of Petroleum class C products;

(7)     No repairs shall be made on the Tank Lorries, while it is in the loading or unloading area;

(8)     Personnel deployed in the loading or unloading area shall make use of Personal Protective equipment and wear all throughout the working period;

(9)     Loading or unloading area pipeline manifold shall have provision of quick shut-off valves;

(10)   No tank vehicle shall be loaded at a rate exceeding (volumetric flow rate corresponding to linear velocity) one meter per second at the delivery (at the least dia fitting) and of the filling pipe until the filling pipe is completely submerged in petroleum and thereafter the loading rate should be gradually increased, but it shall at no point of time exceed six meters per second at the delivery end of the filling pipe;

(11)   Oil and water collected from loading or unloading areas shall be routed to Oil water separator system or Effluent Treatment Plant or similar facility. A slop tank should be earmarked for storing separated oil;

(12)   The tank truck gantry shall be so designed that all the compartments of the tank truck are filled at one bay only and the layout shall ensure that all operations are planned in a manner so that no zigzag movement of the tank truck around the gantry should take place; and

(13)   The maximum safe carrying capacity in weight of Petroleum that can be carried in a tank vehicle shall not exceed the difference between the unladen weight of the vehicle and the maximum gross weight permitted for the class of vehicle under the appropriate transport regulations.

3.3.1.2 During Loading or Unloading Operation.—The following shall be ensured during the loading and unloading operation, namely:—

(1)     Move truck to the loading or Unloading bay and position the TT in the loading or unloading bay and place wheel chokes at front and rear wheels of the vehicle. Keep the TT in neutral mode with hand brakes;

(2)     Certified ISI Mark fire extinguishers shall be placed near the tank trucks, during loading or unloading operations at a designated marked place;

(3)     Stop the engine of TT and “Switch off” Master switch, so that the TT cannot be started incidentally, and the TT electrical supply shall be disconnected totally;

(4)     The TT driver and cleaner shall be outside the vehicle to meet any exigency, and “no” person shall be in the driver's cabin;

(5)     Provide earthing connections of the vehicle at specified point on tanker tank to the fixed grounding system;

(6)     Ensure that TTs manifold valve are closed and capped;

(7)     Test the connections for any product leakages;

(8)     Loading of TTs shall be through dedicated loading arms and through flow meters. The correctness of the mass flow meter shall be ascertained periodically. Splash loading shall be avoided;

(9)     Start the loading operations with initially loading rate which shall not exceed 1 m/s till fill pipe is completely submerged with petroleum products and there after gradually increased loading rate but shall not exceed 6 m/s (should preferably not exceed 4 m/s);

(10)   The quantity loaded into the truck can be assessed by—

(i)       Liquid level through manual dipping; and

(ii)      Filling through Flow meter;

(11)   Filling or transfer operations shall be suspended immediately in the event of—

(i)       Uncontrolled leakage occurring; or

(ii)      A fire occurring in the vicinity; or

(iii)     Lightning and thunder storm;

(12)   The personal working engaged in loading unloading operation, shall use fall protection system designed for the purpose;

(13)   An authorized person of the company shall supervise the filling operation and respond immediately in the event of an emergency; and

(14)   Trucks meant for loading may be inducted in line with approved acceptance checklist, Filling Checklist and records thereof shall be maintained.

3.3.2 Tank Wagon (TW) Loading or Unloading.—Before Commencement of Loading/Unloading, the following shall be complied with, namely:—

(1)     Ensure that the loco is at least at a distance of 15 metre from the first loading/unloading point when the wagons are being placed or removed in the gantry for loading or unloading;

(2)     Main railway track shall be isolated from wagon gantry siding at least 15 meters from 1st loading or unloading point by providing insulation joint at terminating point and loco shall stop before the insulation joint using adequate number of dummy wagons;

(3)     The loading or unloading operation shall be carried out under close supervision of authorized person;

(4)     After the wagons have been placed at the gantry for loading or unloading breaks are to be applied before detaching the loco;

(5)     Open source of ignition shall not be allowed in any part of the area where product transfer operations are being carried out. Use of mobile phone is prohibited in the zone or area;

(6)     Ensure that all fittings on the tank wagons are checked physically that is to say before and after loading or unloading;

(7)     Always use gantry platform for movement from one wagon to other wagon. Movement from wagon to wagon is prohibited, but moment from wagon to wagon with adequate Fall protection system or Safety harness shall be permitted;

(8)     The first operation after positioning the wagon shall be to provide appropriate earthing of all the tank wagons. Ensure that electrical continuity of the system is intact by providing bonding in flanges and checking of continuity;

(9)     Ensure all the firefighting equipments are in good working condition, and the fire fighting ring main system is pressurized and maintained;

(10)   The loading unloading system or equipment's shall not operate more than its designing capacity;

(11)   Any non-routine work in the operational area shall be permitted with work permit only;

(12)   Every individual working in the Tank Wagon operating area must be familiar with all the firefighting equipment, their care and their use in the event of fire;

(13)   Use of right kind of equipment to handle loading or unloading operation. After using the equipment or material or tools shall not be placed at rail track;

(14)   Maintenance jobs on rail track during placement or removal of rake are strictly prohibited;

(15)   Oil and water collected from loading or unloading areas shall be routed to Oil water separator system or Effluent Treatment Plant or similar facility. A slop tank should be earmarked for storing separated oil;

(16)   Open drains along the railway line or gantry shall be covered with gratings so as not to endanger movement of personnel;

(17)   Minimum Vapour space for tank wagons carrying different classes of petroleum products shall be for Petroleum Class A - 4% and for Petroleum Class B and C - 2.5%;

(18)   Tank wagon loading or unloading operations shall be suspended immediately in the event of uncontrolled spill, or fire in the vicinity;

(19)   Before the wagons are moved from the spur, brakes on all the wagons shall be released;

(20)   The railway siding railway track shall be properly insulated from the main line and grounded, vis-a-vis main rail track;

(21)   Wagon to be checked for mechanical condition, dents, and leaks and the report of defective wagons to be provided to Railways;

(22)   All drain and vent point in pipe line shall be kept closed and caped; and

(23)   Good housekeeping to be ensured all the time in Railway siding or gantry and all the personnel working in the area shall wear Personal Protective equipment.

3.3.2.1 During Tank Wagon Loading Operation.—During tank wagon loading operation, the following shall be observed, namely:—

(1)     Accept the tank wagons for loading only after the railway staff declares the tank wagons are fit for loading or unloading operation;

(2)     Before loading of a wagon, a bonding connection shall be made before opening of manhole cover and shall remain in place until filling is completed and all dome covers shall be closed and secured;

(3)     Dip tape or sampler shall not be lowered during loading time or just after completion of loading in a wagon to permit relaxation of charges; and

(4)     No Wagon shall be loaded at a rate exceeding (volumetric flow rate corresponding to linear velocity) one meter per second at the delivery or at the least smallest pipe fitting and of the filling pipe until the filling pipe is completely submerged in petroleum and thereafter the loading rate shall be gradually increased but it shall at no point of time exceed six meters per second at the delivery end of the filling pipe.

3.3.2.2 During Tank Wagon Un-Loading Operation.—During tank wagon un-loading operation, the following shall be observed, namely:—

(1)     Ensure health of unloading pumps required for unloading of wagons;

(2)     Ensure mobilization of required hoses, gaskets, adapters, nuts, bolts and like other devices at the site;

(3)     Ensure correct line up from unloading pump discharge to product tank;

(4)     Record all seals numbers, density and DIP in “sick wagon unloading register”;

(5)     Confirm the correctness of the line-up hoses and product pipeline connections. Recheck and ensure that product exchange shall not take place;

(6)     Ensure earth continuity from Wagon to unloading point by providing required copper jumpers at flange joints;

(7)     Measure the initial dip of the tank wagon prior to unloading;

(8)     Record the initial dip of the tank wagon and the designated tank dip prior to unloading;

(9)     Open air vent valve and filling pipe cover for air breathing;

(10)   Open the master valve and bottom valve of the tank wagon; and

(11)   Monitor the physical dip of the product in the Tank wagon, particularly towards end of the unloading.

3.3.3 Handling and Unloading of Sick Tank Wagon.—While handling and unloading Sick Tank Wagon, the following shall be observed, namely:—

(1)     In case of minor leak, try to arrest the leak at the site with the help of railway staff only through cold repair methods only;

(2)     When a wagon is found leaking during loading or unloading, provision shall be kept for safe handling of such wagons and as a first aid measure arresting of leaks using cold weld compounds at gantry itself and in no case such wagon to be used for transportation;

(3)     If the leak is minor and not stopped by TXR staff or Maintenance, then, make arrangements to decant the wagon into Product Tank;

(4)     If the leak is major, then, immediately inform the concerned Railway staff and in the meantime try to contain the spill using container or drums;

(5)     Connect the un-loading hose to wagon's unloading flange and nearest sick wagon unloading point of the gantry;

(6)     Product should be then transferred to suitable storage and leakage shall be arrested by cold repair methods and in case leakage cannot be arrested, wagon shall be declared sick in concurrence with the railways staff and emptied out completely;

(7)     A dedicated drain header shall be provided for instantaneous unloading of the sick wagons and alternately, the existing headers may be utilized for immediate decantation of product from sick wagons by providing suitable arrangements in the manifold; and

(8)     A portable pump with flame proof or explosion proof motors and other electrical fittings to be used with suitable flexible hose connection for quick withdrawal of products into sump tanks and such drained products to be handled further as per IQCM (Industry Quality Control Manual).

3.3.4 Tank Wagon Unloading in Slop Tank.—While Tank Wagon unloading in Slop Tank, the following shall be observed, namely:—

(1)     Ensure earth continuity from Wagon to unloading point by providing required copper jumpers at flange joints and appropriate earthing connection shall be made before the start of unloading activity;

(2)     Ensure that required ullage is present in the slop vessel to accommodate the quantity to be unloaded from the sick tank wagon and check the dip of product in the slop vessel physically and record it;

(3)     Ensure mobilization of required hoses, gaskets, adapters, nuts, bolts and like other devices near the sick wagon;

(4)     Ensure that the all other stub or branch pipe of the sick wagon unloading header throughout the gantry are properly blinded;

(5)     Record the product specification and density and DIP in “sick wagon unloading register”;

(6)     Confirm the correctness of the line up to the slop vessel;

(7)     Connect the un-loading hose to wagon's unloading flange and nearest sick wagon unloading point of the gantry;

(8)     Open air vent valve and filling pipe cover of wagon for air breathing;

(9)     Open the master valve and wagon bottom valve of the wagon;

(10)   Continuously monitor the dip level of the wagon during unloading operation;

(11)   Check and ensure that there is no leakage of product from other flanges of the unloading header in the gantry area;

(12)   Monitor level of product in the slop vessel;

(13)   Monitor the physical dip of the product in the Tank wagon, particularly towards end of the unloading;

(14)   Check the emptiness of the wagon;

(15)   Disconnect the flexible hose carefully; decant the remaining material of the hose into slop vessel;

(16)   Close bottom valve as well as master valve of the tank wagon;

(17)   Place the unloading hoses and other material at designated place;

(18)   Check the closing stock or physical dip of product in slop vessel and record it; and

(19)   Reconcile the quantity unloaded from Tank Wagon and quantity received in the slop vessel.

3.4 Transfer of Product through Pipeline.—Where ever pipe line transfer is envisaged between various entities, a mass flow meter with integrator shall be installed on receipt line at both ends that is to say dispatch and receipt ends and signal shall be provided in the control rooms of both dispatching and receiving companies or locations for monitoring.

The following safe practices to be followed, namely:—

(1)     Gauging procedure shall be completed and line shall be made through;

(2)     Physical inspection shall be carried out up to the exchange manifold for any leakage or damage and like other harms;

(3)     Monitoring systems such as SCADA shall be installed in cases of cross country pipeline transfers;

(4)     Seal the pressure relief lines of receipt nozzles of product tanks connected to the same common receipt header;

(5)     After ensuring that there are no leaks, pumping shall be commenced;

(6)     Pumping shall be commenced initially at low flow rate and only after stabilizing of flow and the flow rate may be increased;

(7)     Product shall not be pumped beyond safe filling height of the tank and necessary alarms and interlocks in the automation shall be put in place to ensure the safe filling;

(8)     After completion of the receipt, pumps must be stopped;

(9)     In case of Emergency Shutdown, care shall be taken so that back pressure is not developed in the pipelines and pump head;

(10)   Sampling shall be carried out as per provisions of Industry Quality Control Manual (IQCM);

(11)   Pipe Line transfer (PLT) shall not be taken simultaneously in more than one tank; and

(12)   In case product is required to be taken into more than one tank, tank shall be switched over after completion of operation in first tank, close all valves to the first tank, make line through for the second tank as per procedure.

3.5 Marine Loading or Unloading.

(1)     Marine facilities handling petroleum products shall have clearly marked out escape route, and at the same time have sufficient access to fire fighting.

(2)     Fire fighting facility for a marine facility handling petroleum products shall be provided as per design standard.

(3)     Vessels berthed at the wharf shall be fastened with mooring ropes, ensuring that the vessel is well secured to the wharf.

(4)     Before commencement of loading or discharge of the vessel, shore and vessel representatives to jointly sign off safety check list covering all aspects of the vessel loading or discharge shall be ensured and such safety Check list shall also cover emergency evacuation measures in event of emergency on shore and on board the vessel.

(5)     Clear communication channel shall be established between vessel and shore terminal.

(6)     Loading pumps capable of building up pressures that exceed the safe working pressure of cargo hose or loading arms shall be provided with bypasses, relief valves, or other arrangements to protect the loading facilities against excessive pressure. Relief devices shall be tested at least annually to determine that they function satisfactorily at their set pressure.

(7)     Vessel tanks nominated for loading petroleum products shall have oxygen content below 8% to ensure safe loading operation and such safe loading operation has to be ensured in all vessel or tanks nominated for loading, before any product loading can commence into any of the vessel tanks.

(8)     Loading or unloading arms or hoses connected to the vessel for loading or unloading shall have facility for emergency shut off and break away.

(9)     Loading or unloading quantity and rates shall be monitored on an hourly basis and corresponding ship and shore figures shall be hourly compared.

(10)   Loading or unloading arms or hoses shall be inspected hourly for leakages during the operations.

(11)   Vessel shall ensure and confirm to shore on hourly basis and the status of various vessel tanks shall ensure that no product migration is taking place between vessel tanks.

(12)   Abnormalities observed during operations shall be immediately communicated between ship and shore. In case of abnormality in operations, operations shall be stopped immediately. Operations shall only commence after conditions have been restored to normal. Abnormalities which shall be considered are the following, namely:—

(a)      Large differences between vessel and shore tank hourly quantity;

(b)      Variation in product densities from the certified density of the product under operation; and

(c)      Leakages observed on board vessel or shore pipelines or hoses or spillage observed in the sea water.

(13)   Mechanical work shall not be performed on the wharf during cargo transfer, except under special authorization based on a review of the area involved, methods to be employed, and precautions necessary.

3.6 Ethanol Handling.—In case ethanol is used for blending with Motor Spirit at the petroleum installation, facilities for storing and handling of ethanol shall be provided and all practices as being followed in handling Class ‘A’ Petroleum Products are required shall be adhered to while handling Ethanol and Ethanol Blended Motor Gasoline.

3.6.1 Receipt, storage and handling of ethanol.

(1)     Ethanol shall be received at installations/depots in dedicated tank trucks and all care shall be taken to prevent ingress of water into the compartments during transportation.

(2)     The fittings in tank trucks used for transportation of Ethanol to receiving locations shall be the same as used for storage and handling of Class ‘A’ Petroleum products.

(3)     Ethanol can be stored in above ground or underground tanks depending on local requirement.

(4)     The unloading operations shall be carried out through special Nitrile rubber or any other compatible hoses. Hose shall have external bonding wire to ensure electrical continuity.

(5)     Ethanol being hygroscopic in nature, utmost precaution needs to be taken to ensure that there is no ingress of water or humidity. Both the ends of the hoses after use shall be capped and 80 mesh strainers shall be provided before the pump or tank inlet, as the case may be.

(6)     Appropriate recommended dosage of Corrosion inhibitor shall be added during the decantation of Ethanol from tank truck into the storage tank, so as to ensure homogeneity of additives with ethanol in the storage tank.

(7)     Storage tanks and allied facilities for Ethanol shall be positively segregated and the tank shall be absolutely free from water at all times.

(8)     Ethanol, being hygroscopic, will absorb moisture from the air and Silica Gel trap shall be provided in the vent pipe of the tank to prevent ingress of moisture into the tank. Regular check on the colour of silica gel shall be maintained (Blue Colour) and shall need immediate replacement on showing signs of saturation by way of change of colour.

(9)     Ethanol storage tanks shall be cleaned once in two years or more frequently depending on the need.

(10)   Storage tank openings or pipeline fittings shall be airtight and the threaded connections if any shall be tightened with the help of Teflon paste or Teflon tapes and Bolted connections shall have gaskets of Teflon.

(11)   To ensure uniform doping of Ethanol with Motor Gasoline, on line doping of Ethanol shall be carried out through a closed system, with proper interlocks, while maintaining efficacy of mixing Ethanol in the right proportion of % v/v as per specification.

(12)   An 80-mesh filter shall be provided on the delivery side of Ethanol storage tank that is to say between pump and tank lorry filling (TLF) Gantry point.

(13)   Safety requirements as specified in Material safety data Sheet (MSDS) shall be ensured.

(14)   “Safe Operating Practices (SOP)” shall be displayed. Persons handling ethanol shall be trained for handling of ethanol.

(15)   Emergency instructions and hazardous instruction shall be displayed and PPE as per MSDS requirement shall be in place.

PART – D

(Commissioning or De-commissioning of facilities)

4.0 Commissioning or De-commissioning of facilities.—Commissioning is the process of assuring that all systems and components of a facility, a process, or a plant are installed, tested, and operated according to the design parameters and operational requirements. Decommissioning is the process of assuring that all systems and components of a facility, a process, or a plant are tested and confirmed that there is no Hazard available or balance, which may cause any potential damage to the personal and also equipment or facilities installed in the vicinity before shutdown of the facility. The commissioning or de-commissioning process shall include the following aspects, namely:—

(1)     Standard operating procedures for commissioning or decommissioning of the equipment and facility shall be formulated, reviewed and approved by designated personnel;

(2)     Only experienced and trained personnel shall be deployed for commissioning or de-commissioning activities;

(3)     The de-commissioning or commissioning of the facility shall be carried out under the close supervision of the experienced and expert supervisors;

(4)     The role and responsibilities of each personnel associated with the commissioning or de-commissioning activities shall be clearly defined and approved;

(5)     The commissioning process comprises the integrated application of a set of engineering techniques and procedures to check, inspect, test, and verify every operational component of the project, from individual functions, such as stand-alone equipment and instrumentation to complex combinations of modules, subsystems and systems;

(6)     There shall be an approved commissioning or de-commissioning plan for each facility or process unit of the project;

(7)     The procedures shall be developed taking into account the various hazards that are likely to be encountered during the commissioning process and shall also address the prevention or mitigation systems that need to be in place prior to commencing each activity;

(8)     The procedure referred to in clause (7) should also take into account any risks to the operators, facility, and environment based on a risk assessment;

(9)     Procedures shall ensure that all necessary checks or safeguards are correctly addressed. Procedures shall be supported with proper checklists for verifying compliance;

(10)   Pre-commissioning activities like vessel entry, work at height, hot work, and all commissioning or decommissioning activities shall be carried out complying with work permit system;

(11)   Compliance to work permit requirements should be monitored via regular safety inspection;

(12)   All staff and the associated contractors, vendor representatives at site shall use Personal Protective Equipment (PPE) as specified for such purpose;

(13)   In the event of an emergency occurring in the Project site or area, the emergency response shall be in accordance with the established Emergency Response Procedures;

(14)   Hazardous waste and non-hazardous waste produced in the pre-commissioning or commissioning activity (that is to say flushing lube oil, oil contaminated water or soil) shall be handled in accordance with established environmental procedures of waste management;

(15)   A comprehensive testing procedure shall be developed which address the safety of all personnel involved therein and include the provision of specific work instructions and related training and induction for all personnel involved in testing operations. The testing must be supervised by trained and experience personnel. Coordination and team work between Construction, QA or QC, Safety, and Contractor is very important;

(16)   Any pressure test activity shall have approved pressure test Certificates of relevant testing equipment or instruments, work permit and job safety analysis;

(17)   The hydrostatic and pneumatic test pressure utilized for testing of systems shall be as indicated in the data sheet and the relevant Codes and Specifications for the system shall be used for determining the hydrostatic or pneumatic test pressures;

(18)   Test facility shall be set up with provision of a relief valve and calibrated pressure gauge (at least two units in the test loop) shall be deployed;

(19)   Prior to commencement of any pressure test, the relief valves shall be correctly set and not isolated, and the pressure gauges shall be functional;

(20)   Equipment or piping system isolation spades, gaskets, flanges and like other devices should be checked for correct size, thickness and rating;

(21)   All vents and other connections which can serve as vents shall be open during filling, so that all air is vented prior to applying test pressure to the system;

(22)   Temporary spades and blanks installed for testing purposes shall be designed to withstand the test pressure without distortion;

(23)   Piping shall be tested prior to installation of inline items such as rupture discs, displacement and turbine meters, orifice plates, flow nozzles, level gauges, rotameters, strainers and like other devices; and

(24)   Many potential hazards can be realized during start-up or shut-down of a plant or a process unit. Specific Emergency procedures should be provided which take into account all possible eventualities.

PART — E

(Fire Protection and Prevention Facilities)

5.0 Fire Protection and Prevention Facilities:

5.1 Fire Protection Philosophy.—Fire protection philosophy is based on loss prevention and control. It considers that a depot or terminal carries an inherent potential hazard due to flammable nature of petroleum products stored therein. A fire in one facility can endanger other facility of the depot or terminal, if not controlled or extinguished as quickly as possible to minimize the loss of life and property and to prevent further spread of fire.

5.1.1 Fire protection.—Depending on the nature of risk, following fire protection facilities shall be provided in the installation, namely:—

(i)       Fire Water System-(storage or pumps or distribution piping network with hydrant or monitors);

(ii)      Fixed Water Spray System;

(iii)     Foam System;

(iv)    First Aid Fire Fighting Equipment;

(v)      Trolley mounted or Mobile Fire Fighting Equipment;

(vi)    Carbon Dioxide System or Clean Agent Fire Fighting System or Dry Chemical Fire Fighting System;

(vii)   Dry Chemical Extinguishing System;

(viii)  Clean Agent Protection System;

(ix)    Leak detection System and Alarm System;

(x)      Fire Detection and alarm systems; and

(xi)    Communication System.

5.1.2 Design criteria for fire protection system.

(1)     Facilities shall be designed on the basis that city fire water supply is not available close to the installation. The Installation or Depot should have its own independent Fire Fighting System. Pipeline installation co-located with Refinery or Marketing installation may be covered by fire fighting system of later and need not require independent fire fighting system.

(2)     The fire water pumps shall be provided with auto start facility with pressure drop in fire water network.

(3)     The fire water system shall be based on single contingency for all locations where total storage capacity in the location is up to 30,000 KL (Including storage of Class C products if stored with Class A and/or Class B). Wherever water replenishment @ 50% or more is available, the storage capacity can be reduced to 3 hours aggregate rated capacity of main pumps.

(4)     The fire water system shall be provided based on two largest fire contingencies simultaneously for all locations where total storage capacity in the location is above 30,000 KL (Excluding Class-C products stored in a separate dyke conforming to prescribed separation distances) and wherever water replenishment @ 50% or more is available, single fire contingency shall be considered for Fire water storage. This clause shall not be applicable for locations exclusively storing class C and/or excluded products.

(5)     At locations where cluster of OMCs exist, fire water shall be shared. Water requirement shall be worked out based on fire scenario of single largest tank, CR or FR tank, as the case may be. At locations where single OMC exist, it shall have water requirement for 4 hours.

(6)     For location or dyke storing exclusively Class C or excluded or combination of Class-C and excluded products, the water requirement shall be based on 1 monitor of 144 k1/hr and 4 hose streams of 36 k1/hr that is to say a total of 288 kl per hr for four hrs.

(7)     The hazardous areas shall be protected by a well laid combination of hydrants and monitors and the installations having aggregate above ground storage capacity of less than 1000 KL (Class A+B+C) are exempted from such protection.

(8)     The installations storing Class A petroleum in above ground tanks shall have fixed water spray system, but the installations above 1000 KL storage fulfilling the following both conditions are exempted from the provision of fixed water spray system, namely:—

(i)       Aggregate above ground storage of Class A and Class B petroleum up to 5000 KL; and

(ii)      Floating roof tank storing Class A petroleum having diameter up to 9 M.

(9)     Class ‘B’ above ground Petroleum storage tanks (fixed roof or floating roof) of diameter larger than 30 m shall be provided with fixed water spray system.

(10)   Fixed foam system or Semi-fixed foam system shall be provided on all tanks (floating roof or fixed roof) exceeding 18 m diameter storing Class A or Class B petroleum.

(11)   When Class A and Class B above ground storage tanks are placed in a common dyke then, the fixed water spray system shall be provided on all tanks except for small installations as mentioned in sub-para (8).

(12)   Installations where inter distances between tanks in a dyke or within dykes are not conforming to these regulations, the following additional facilities shall be provided to enhance safety namely:—

(i)       The fixed water sprays system on all tanks, irrespective of diameter in the installations; and

(ii)      The Fixed or semi fixed foam system on all tanks, irrespective of diameter in the installation.

(13)   Tank Truck (TT) or Tank Wagon (TW) loading or unloading gantries or facilities, Manifold area of product pump house and Exchange pit shall be fully covered with alternate hydrant and water cum foam monitors of approved make having multipurpose combination nozzles for jet, spray and fog arrangement and located at a spacing of 30 M on both sides of gantry ensuring minimum foam application rate of 6.5 lpm/sq.m (in line with NFPA-11 for spill fire more than 1 inch deep) to the target zone (3 adjacent segments of 15 meters each for TW gantry and 08 bays for TT gantry) of the relevant facility.

(14)   The hydrants and monitors shall be located at a minimum distance of 15 m from the hazard (such as TW and TT loading or unloading facilities) to be protected.

(15)   Tank wagon loading gantries shall be provided with manually operated fixed water spray or sprinkler system. The gantry shall be divided into suitable number of segments (each segment having minimum length of 15 m length and width of 12 m) and three largest segments operating at a time shall be considered as single risk for calculating the water requirement and accordingly, a provision shall be made to actuate the water spray system from a safe approachable central location that is to say affected zone and adjoining zones.

(16)   Portable monitors or foam hose streams shall be provided for fighting fires in dyke area and spills.

(17)   Medium expansion foam generators shall be provided for dyke area to arrest vapour cloud formation from spilled volatile hydrocarbons.

(18)   Installation of medium expansion foam generator shall be as per following criteria, namely:—

(i)       Class A tanks : Two Nos. Fixed type foam generators (minimum) for each tank dyke, and

(ii)      Class B tanks : Two Nos. Portable foam generator (minimum) for each location.

(19)   Remote or manually operated high volume long range water cum foam monitors (capacity 500/750/1000 GPM and above) to fight tank fires shall be provided at petroleum installations. Numbers and Capacity of monitor or foam pourer shall be provided in such a way that the foam delivery rate from the monitors' meets requirement of foam application rate (8.1 LPM/m2) for full surface tank fire.

(20)   The location of HVLRs monitors shall be planned in such a way that the very purpose of such monitors is served and throw of the monitors is safely delivered at the aimed object and such high volume long range monitors shall be positioned located at a distance of 15 m to 45 m from the hazardous equipment subject to the following, namely:—

(i)       Monitors shall be positioned in such a way that throw of monitors are safely directed to the target tank under full surface fire without damaging tank shell, tank pad and other objects; and

(ii)      The throw is directed on the inner upper surface of the tank and not in the middle of the tank to prevent splash over.

(21)   Fixed or mobile HVLRs shall be used for fighting full surface fire on external floating roof tanks.

(22)   Care need to be taken for petroleum installations located in habituated areas or adjoining to other objects such as High tension line and like other objects and there should not be any High tension line passing through the depot or installation.

(23)   Water cum foam monitors shall be installed in such a way that all the tanks in the installation are within the horizontal range of foam throw.

(24)   Additional monitors shall be provided in such a way that each tank is in the coverage area of at least two monitors.

(25)   Provision for connecting or hooking the portable monitor shall be made in the hydrant system around the fixed roof tanks at various strategic points.

(26)   Well laid procedures and plans shall be made and put into use for use of HVLRs to combat emergencies without loss of much time.

(27)   For determining the total foam solution requirement, potential foam loss from wind and other factors shall be considered while designing.

(28)   Adequate foam drum or tank or reliable replenishment for foam induction system shall be provided.

(29)   Automatic actuated rim seal fire detection and extinguishing system shall be provided on all existing as well as new external floating roof tanks storing Class A petroleum. The detection and extinguishing system shall have the following features, namely:—

(i)       The system must detect fire in Rim Seal area immediately but not later than 10 seconds and extinguish the fire in its incipient stage that is to say within 40 seconds of its indication;

(ii)      The system must be robust, such as it should not be affected by environmental conditions like low or high ambient temperature, dust, external corrosion, hydrocarbon vapour, rain and like other environmental conditions;

(iii)     The extinguishing foam must apply in the seal area @18 LPM per square meter in a uniform manner in maximum of 40 seconds; and

(iv)    The detection and extinguishing system shall be coupled with fire control panel with audio-visual alarm for necessary fire alert.

(30)   In alternative to the system specified in sub-paragraph (29), the following system can be provided, namely:—

(i)       The detection system shall detect the fire immediately but not later than 10 seconds;

(ii)      The actuation system shall be actuated immediately on detection of fire;

(iii)     Minimum 10 minutes foam discharge for below seal application or minimum 20 minutes discharge for above seal application shall be undertaken; and

(iv)    The application rate shall be 20.4 lpm/m2 of the area.

(31)   In addition, the individual components shall have certification from competent authority for suitability for applicable hazardous zone.

(32)   Fixed water spray system shall also be provided in lube oil drum areas if located in hazardous area.

(33)   Clean Agent (Halon substitute) based flooding system should be provided for control rooms, computer rooms or repeater station and pressurized rooms in major locations having automated pipeline receipt or dispatch or TW or TT loading facilities. Selection of clean agent and design of fire protection system for control rooms, computer rooms and pressurized rooms should follow the Standard on “Clean Agent Extinguishing systems NFPA Standard 2001 including its safety guidelines with respect to “Hazards to Personnel”, electrical clearance and environmental factors in line with environmental considerations of Kyoto and Montreal Protocol and MOEF&CC regulations.

5.1.3 In case, combined Petroleum and LPG facilities have been provided in the same premises, the common water storage facility for fire fighting purpose may be shared between Petroleum Installation and LPG Plant under following conditions, namely:—

(1)     If both locations are located within same premise, then, one largest fire scenario to be considered and water requirement shall be worked out accordingly. In case, the premises are separate, water requirement to be worked out for independent location;

(2)     Each Petroleum or LPG facility shall independently meet the design, layout and fire protection system requirements of PNGRB regulations and have common boundary wall and ownership of both the facilities under same company; and

(3)     The pump house may be common or separate and in case common pump house is provided the control of the pump house shall remain with group whose premises such pump house is situated.

5.2 Fire water system design.—Fire water system shall be designed for a minimum residual pressure of 7 kg/cm2 at hydraulically remotest point in the installation considering the design flow rate, namely:—

(1)     A fire water ring main shall be provided all around perimeter of the location facilities with hydrants or monitors spaced at intervals not exceeding 30 M when measured aerially. Fire hydrants and monitors shall not be installed within 15 Meters from the facilities or equipment to be protected, and

(2)     The installation shall have facilities for receiving and diverting all the water coming to the installation to fire water storage tanks in case of an emergency.

5.2.1 Fire water design flow rate.—

(1)     Fire water flow rate for a tank farm shall be aggregate of the following, namely:—

(i)       For water flow calculations, all tanks farms having Class A or Class B petroleum storage shall be considered irrespective of diameter of tanks, whether fixed water spray system is provided or not;

(ii)      Water flow calculated, for cooling a tank on fire at a rate of 3 lpm/sqm of tank shell area;

(iii)     Water flow calculated, for exposure protection for all other tanks falling within a radius of (R +30) m from centre of the tank on fire (R-Radius of tank on fire) and situated in the same dyke, at a rate of 3 lpm/sq.m of tank shell area;

(iv)    Water flow calculated, for exposure protection for all other tanks falling outside a radius of (R+30) m from centre of the tank on fire and situated in the same dyke, at a rate of 1 lpm/m2 of tank shell area;

(v)      Water flow required for applying foam on a single largest tank by way of fixed foam system, where provided, or by use of water or foam monitors whichever is higher (Foam solution applicable rate for cone roof tanks shall be taken as 5 lpm/sqm and for floating roof rim seal protection it shall be 12 lpm/sqm); and

(vi)    Various combinations shall be considered in the tank farm for arriving at different fire water flow rate and the largest rate to be considered for design.

(2)     For location or dyke storing exclusively Class C or excluded products, the water requirement shall be based on 1 monitor of 144 kl/hr and 4 hose streams of 36 kl/hr that is to say a total of 288 kl per hr for four hrs.

(3)     Fire water flow for product pump house shed for depot or terminal and cross country pipe line installations with or without tankage shall be at a rate of 10.2 lpm/sqm.

(4)     Pumps of volatile products located under pipe rack fire water flow rate shall be calculated at a rate of 20.4 lpm/sqm.

(5)     Fire water flow rate for TT and TW loading Gantry in a depot or terminal shall be calculated at a rate of @ 10.2 lpm/sq.m. The gantry shall be divided into suitable number of segments (each segment having minimum length of 15 m length and width of 12 m) and three largest segments operating at a time shall be considered as single risk for calculating the water requirement. Design flow rate shall be largest of 5.2.1.a, 5.2.1.b, 5.2.1.c, 5.2.1.d and 5.2.1.e. Design flow rate for roof sinking case of largest tank shall be calculated and wherever, the design flow rate of roof sinking case is higher than single or two contingencies, as the condition applicable, the same shall be considered for calculating water requirement.

(6)     Fire water flow rate for supplementary streams shall be based on using 4 single hydrant outlets simultaneously. Capacity of each hydrant outlet as 36 k1/hr shall be considered at a pressure of 7 kg/cm2 and the supplementary water stream requirement shall be in addition to the design flow rates.

5.2.2 Fire water storage.

(1)     Water for the fire fighting shall be stored in easily accessible surface or underground or above ground tanks of steel, concrete or masonry.

(2)     The effective capacity of the reservoir or tank above the level of suction point shall be minimum 4 hours aggregate rated capacity of pumps. Subject to the design criteria specified in sub-paragraph (3) and sub-paragraph (4) of paragraph 5.1.2.

(3)     Fresh water should be used for fire fighting purposes and in case sea water or treated effluent water is used for fire fighting purposes, the material of the pipe selected shall be suitable for the service.

(4)     Storage reservoir (RCC) shall be in two equal interconnected compartments to facilitate cleaning and repairs and in case of steel tanks there shall be minimum two tanks and all the tanks shall be of equal height or depth to prevent any migration or overflow due to difference in height or depth. During maintenance of water tanks, availability of at least 50% of the water capacity shall be ensured.

(5)     Large natural reservoirs having water capacity exceeding 10 times, the aggregate fire water requirement can be left unlined.

5.2.3 Fire water pumps.

(1)     Fire water pumps having flooded suction shall be installed to meet the design fire water flow rate and head. If fire water is stored in underground tanks, an overhead water tank of sufficient capacity shall be provided for flooded suction and accounting for leakages in the network, if any and pumps shall be provided with suitable sized strainers on suction and NRVs on discharge lines.

(2)     The pumps shall be capable of discharging 150% of its rated discharge at a minimum of 65% of the rated head. The Shut-off head shall not exceed 120% of rated head for horizontal centrifugal pumps and 140% for vertical turbine pump.

(3)     At least one standby fire water pump shall be provided up to 2 nos. of main pumps. For main pumps 3 nos. and above, minimum 2 nos. standby pumps of the same type, capacity and head as the main pumps shall be provided. Fire water pumps shall be of equal capacity and head.

(4)     The fire water pump including the standby pump shall be of diesel engine driven type. Where electric supply is reliable, 50% of the pumps can be electric driven. The diesel engines shall be quick starting type with the help of push buttons located on or near the pumps or located at a remote location. Each engine shall have an independent fuel tank adequately sized for 6 hours continuous running of the pump. Fuel tank should be installed outside of fire pump house and shall have provision for venting. If tanks are located inside the pump house, the vent shall have provision for venting outside the pump house.

(5)     Fire water pumps and storage shall be located far away from the potential leak sources or tankage are and shall be at least 60 M (minimum) away from equipment or where hydrocarbons are handled or stored.

(6)     Fire water pumps shall be exclusively used for fire fighting purpose only.

(7)     Suction and discharge valves of fire water pumps shall be kept full open all the times.

(8)     Jockey pump shall be provided for keeping the hydrant system or line pressurized at all times. The capacity of the pump shall be sufficient to maintain system pressure in the event of leakages from valves and like other devices and besides the main jockey pump the stand by pump of same capacity and type shall be provided.

(9)     Auto cut-in or cut-off facility should be provided for jockey pumps to maintain the line pressure.

(10)   The fire water pumps shall be provided with auto start facility which shall function with pressure drop in hydrant line and specified logic even if initial pump does not start or having started, fails to build up the required pressure in the fire water ring main system and the next pump shall start and so forth and so on.

(11)   The fire hydrant system should be able to maintain a pressure of minimum 7 kg/cm2 in the line at the farthest end.

5.2.4 Fire hydrant network.

(1)     The fire water network shall be laid in closed loops as far as possible to ensure multi-directional flow in the system. Isolation valves shall be provided in the network to enable isolation of any section of the network without affecting the flow in the rest. The isolation valves shall be located normally near the loop junctions. Additional valves shall be provided in the segments where the length of the segment exceeds 300 M.

(2)     Fire hydrant ring main shall be laid above ground ensuring that—

(i)       the pipe line shall be laid at a height of 300 mm to 400mm above finished ground level;

(ii)      the pipe support shall have only point contact. The mains shall be supported at regular intervals;

(iii)     for pipeline size shall be less than 150 mm and support interval shall not exceed 3 meters;

(iv)    the pipe line size shall be 150mm and above not exceeding 6 meters or design approved; and

(v)      the system for above ground portion shall be analysed for flexibility against thermal expansion and necessary expansion loops where called for shall be provided.

(3)     Fire hydrant ring main may be laid underground at the following places, namely:—

(i)       At road crossings;

(ii)      Places where above ground piping is likely to cause obstruction to operation and vehicle movement;

(iii)     Places where above ground piping is likely to get damaged mechanically; and

(iv)    Where Frost conditions warrant and ambient temperature is likely to fall below zero degree Centigrade, then, underground piping at least 1 meter below the ground level should be provided and alternatively, in such cases for above ground pipelines, water circulation to be carried out.

(4)     Fire water ring main laid underground shall ensure the followings, namely:—

(i)       Pipes made of composite material shall be laid underground;

(ii)      The Ring main shall have at least one-meter earth cushion in open ground, 1.5 m cushion under the road crossings and in case of crane movement area pipeline shall be protected with concrete or steel encasement as per design requirement and in case of rail crossing, provisions stipulated by Indian Railways shall be complied;

(iii)     The Ring main shall be suitably protected against soil corrosion by suitable coating or wrapping with or without cathodic protection; and

(iv)    In case of poor soil conditions it may be necessary to provide concrete/masonry supports under the pipe line.

(5)     Size of hydrant pipeline shall be as specified below, namely:—

(i)       The hydraulic analysis of network shall be done at the design time and whenever fire water demand increases due to addition of facilities or extensive extension of network, fresh hydraulic analysis shall be carried out;

(ii)      The velocity of water shall not exceed 5 meter per second in fire water ring main;

(iii)     Fire water ring main shall be sized for 120% of the design water flow rate and design flow rates shall be distributed at nodal points to give the most realistic way of water requirements in an emergency. It may be necessary to assume several combinations of flow requirement for design of network; and

(iv)    The stand post for hydrants and monitors shall be sized to meet the respective design water flow rates.

(6)     The following requirements shall be complied with, namely:—

(i)       Fire water mains shall not pass through buildings or dyke areas. In case of underground mains the isolation valves shall be located in RCC or brick masonry chamber of suitable size to facilitate operation during emergency and maintenance;

(ii)      Associated Sprinkler or foam riser or branch connections meant for storage tanks, if applicable, shall be taken directly to the outside of tank dyke and shall not pass through fire wall of any adjacent tanks; and

(iii)     The riser connections shall be taken directly from the mains and provided with separate isolation valve outside of dyke. Suitable strainer shall be provided on sprinkler branch connection and shall be located outside of dyke.

5.2.5 Hydrant or monitors.

(1)     Hydrants or monitors shall be located considering various fire scenario at different sections of the premises to be protected and to give most effective service.

(2)     At least one hydrant post shall be provided at every 30 mtrs. of external wall measurement or perimeter of battery limit in case of high hazard areas and for non-hazardous area, the hydrant post shall be spaced at 45 mtrs. intervals. The horizontal range and coverage of hydrants with hose connections shall not be considered beyond 45 mtrs.

(3)     Hydrants shall be located at a minimum distance of 15 mtrs. from the periphery of storage tank or equipment under protection and in case of buildings such distance shall not be less than 2 mtrs. and not more than 15 mtrs. from the face of building.

(4)     Provision of hydrants within the building shall be provided in accordance with IS : 3844.

(5)     Hydrant or Monitors shall be located along road side berms for easy accessibility.

(6)     Fixed water or water cum foam monitors on the network shall be provided with independent isolation valves and Double headed hydrants with two separate landing valves. Hydrants or Monitors shall be located with branch connection.

(7)     Double headed hydrants and monitors on suitably sized stand post shall be used. All hydrant outlets or monitor isolation valves shall be situated at workable height from ground or hydrant or monitor operating platform level.

(8)     Monitors shall be located to direct water on the object as well as to provide water shield to firemen approaching a fire. The requirement of monitors shall be established based on hazards involved and layout considerations.

(9)     Hydrants and monitors shall not be installed inside the dyked areas, but, as an additional requirement, oscillating monitors shall be provided in inaccessible area within the dyke with isolation valve or ROV outside the tank farm (in cases inter distances between tanks in a dyke or within dykes are not meeting the requirements).

(10)   TW or TT loading and unloading facilities shall be provided with alternate hydrant or water cum foam monitor of suitable capacity and size to ensure adequate coverage and located at a spacing of 30 M on both sides of the gantry.

(11)   The hydrants and monitors shall be located at a minimum distance of 15 M from the hazard (such as TW and TT loading or unloading facilities) to be protected.

5.2.6 Material specifications.—The materials used in fire water system shall be of approved type as indicated below, namely:—

(1)     In respect of pipes, Carbon Steel as per IS : 3589/IS : 1239/IS : 1978 or Composite Material or its equivalent for fresh water service and in case saline, brackish or treated effluent water is used, the fire water ring main of steel pipes, internally cement mortar lines or glass reinforced epoxy coated or pipes made of material suitable for the quality of water able to withstand the temperature and pressure shall be used and alternately, pipes made of composite materials shall be used. The composite material to be used may be as per API 15LR/API 15HR/IS12709. In case composite pipes are used they shall be used underground;

(2)     In respect of Isolation Valves, Gate valve or quick shut off type isolation valves made of Cast Steel having open or close indication shall be used and other materials such as cupro-nickel for saline or brackish water can be used and the material of the valve shall be suitable for the service.

(3)     In respect of Hydrants post—

(i)       Stand post made of Carbon Steel shall be used; and

(ii)      Outlet valves made of Gunmetal or Aluminium or Stainless or Steel or Al-Zn Alloy shall be used.

(4)     Monitors or High Volume Long Range Water Cum Foam Monitors (HVLR) or Rim seal shall be approved or listed by any of the national or international certifying agencies like UL, FM, VdS or LPC, BIS or any other like agency and the electrical or hydraulic remote control mechanism shall be in line with Hazardous Area Classification;

(5)     In respect of Fire Hoses, Reinforced Rubber Lined Hose shall be as per IS 636 (Type A) or Non-percolating Synthetic Hose (Type B) or Equivalent Standard.

(6)     In respect of Painting,—

(i)       Fire water mains, hydrant and monitor stand posts, risers of water spray system shall be painted with “Fire Red” paint as per of IS : 5;

(ii)      Hose boxes, water monitors and hydrant outlets shall be painted with “Luminous Yellow” paint as per IS : 5; and

(iii)     Corrosion resistant paint shall be used in corrosion prone areas.

5.2.7 Fixed water spray system.

(1)     Fixed water spray system is a fixed pipe system connected to a reliable source of water supply and equipped with water spray nozzles for specific water discharge and distribution over the surface of area to be protected and the piping system is connected to the hydrant system water supply through an automatically or manually actuated valve which initiates the flow of water and in case the system is manually actuated, the isolation valve shall be located outside the dyke for ease of access and operation.

(2)     Spray nozzles shall be directed radially to the tank at a distance not exceeding 0.6 M from the tank surface.

(3)     While calculating the water rates for spray application for cases other than tanks such as pump house and tank wagon gantry, the area should be divided into suitable segments so that maximum water requirement can be optimized.

(4)     For TW loading gantry, sprinklers shall be provided to ensure full surface coverage and three largest segments shall be considered for water requirement.

(5)     For Tank Truck loading gantries specifically for those cases which have obstructions in water throw, sprinklers should be provided.

(6)     The flow rate in the sprinkler system shall be either 1 lpm or 3 lpm depending upon whether tank is outside or within a distance of R+30 m from the tank on fire.

5.3 Foam protection system:

5.3.1 Storage tank:

5.3.1.1 Floating roof tank.—For floating roof tank, foam shall be poured at the foam dam to blanket the roof seal and the features of foam system for floating roof tank protection shall be as follows, namely:—

(i)       The system shall be designed to create foam blanket on the burning surface in a reasonably short period;

(ii)      The foam shall be applied to the burning hazard continuously at a rate high enough to overcome the destructive effects of radiant heat; and

(iii)     The foam makers or foam pourers shall be located not more than 24 M apart on the shell perimeter based on 600 mm foam dam height. The height of foam dam shall be at least 51 mm above the top of metallic secondary seal.

5.3.1.2 Fixed roof tank.—Foam conveying system shall have same features as of floating roof tank as specified in paragraph 5.3.1.1 excepting that a vapour seal chamber is required before the foam discharge outlet and features of the foam system for fixed roof protection shall be as follows, namely:—

(1)     The vapour seal chamber shall be provided with an effective and durable seal, fragile under low pressure, to prevent entrance of vapour into the foam conveying piping system and

(2)     Where two or more pourers are required such pourers shall be equally spaced at the periphery of the tank and each discharge outlet shall be sized to deliver foam at approximately the same rate. Tanks should be provided with foam discharge outlets or pourers as indicated below, namely:—

In case foam pourers are provided on tanks having diameter up to 18 m, minimum 2 nos. foam pourers shall be provided.

5.3.1.3. Floating cum fixed roof tank.—Protection facilities shall be provided as required for fixed roof tank.

5.3.1.4 Protection for dyke area or spill fire.

(1)     Portable monitors or foam hose streams shall be provided for fighting fires in dyked area and spills; and

(2)     In addition to as specified in clause (i), Medium expansion foam generators shall be provided to arrest vapour cloud formation from spilled volatile hydrocarbons and the installation of medium expansion foam generator shall be as per following criteria, namely:—

(i)       Class A tanks : 2 nos. Fixed type foam generators (minimum) for each tank dyke;

(ii)      Class B tanks : Two nos. portable foam generators (minimum) for each location.

5.3.2 Foam application:

5.3.2.1 Application rate.—The minimum delivery rate for primary protection based on the assumption that all the foam reaches the area being protected shall be as indicated below, namely:—

(1)     For cone roof tanks containing liquid hydrocarbons, the foam solution delivery rate shall be at least 5 lpm/sqm of liquid surface area of the tank to be protected and for floating roof tanks containing liquid hydrocarbons foam solution, delivery rate shall be at least 12 lpm/sqm of seal area with foam dam height of 600 mm of the tank to be protected; and

(2)     The height of foam dam shall be at least 51 mm above the top of metallic secondary seal. In the case of Floating roof tank roof sinking, the application rate shall be considered as 8.1 lpm/sqm. In determining total solution flow requirements, potential foam losses from wind and other factors shall be considered.

5.3.2.2 Duration of foam discharge.—The equipment shall be capable of providing primary protection at the specified delivery rates for the following minimum duration namely:—

(1)     Tanks (fixed roof or floating roof) containing Class ‘A’ and Class ‘B’, the minimum duration shall be 65 minutes, and

(2)     Where the system's primary purpose is for spill fire protection such as dyked area and non dyked area (TT and TW and like other non dyked) the minimum duration shall be 30 minutes.

5.3.2.3 Water for foam making.—Water quantity required for making foam solution depends on the percent concentration of foam Compound and foams in normal use shall have a 1% to 6% proportioning ratio, but foam supplier data shall be used for determining water requirement.

5.3.2.4 Foam quantity requirement.—The foam quantity requirement shall be based on the following, namely:—

(1)     Foam solution application shall be at the rate of 5 lpm/sqm. for the liquid surface of the single largest cone roof tank;

(2)     Foam solution application shall be at the rate of 12 lpm/sqm. of seal area of the single largest floating roof tank;

(3)     Floating roof sinking case also shall be considered for foam compound requirement and storage. Application @ 8.1 lpm/sq.m by required Nos. HVLR of installed capacity and minimum aggregate foam storage shall be total of (1) + (2) or (3), whichever is higher; and

(4)     In case of Aviation Fuelling Stations, where aggregate product storage capacity is less than 1000 KL, foam quantity for spill fire protection of 30 minutes shall be made.

5.3.2.5 Foam compound storage.

(1)     Foam compound should be stored as explained in IS-4989 or equivalent standard. Type of foam compound to be used can be protein, fluro-protein or AFFF. Alcohol Resistant Foam shall be used for handling methanol or ethanol or furfural fires. Minimum 1000 litres of Alcohol Resistant Foam compound shall be maintained at the installation to handle methanol or ethanol or furfural fire.

(2)     Shelf life of foam compound shall be taken from manufacturer's data. Foam compound shall be tested periodically as per OEM guidelines to ensure its quality and the deteriorated quantity shall be replaced. The deteriorated foam compound can be used for fire training purposes.

(3)     Care shall be taken to avoid mixture of two or more different grades or batches of foam in a foam storage tank. In such cases foam shall be tested on yearly basis to check its efficacy and record shall be maintained thereof.

(4)     For details of type of tests and their periodicity, IS 4989 or equivalent Standard shall be referred.

(5)     Quantity of foam compound as per paragraph 5.3.2.4, should be stored in the Installation. At locations where cluster of OMC exists, foam requirement can be uniformly distributed at respective location. The stored quantity shall be made available to needy company in case of any emergency.

(6)     Foam may be stored either in storage tanks of fixed type or mounted on mobile trolleys.

5.4 Control room and computer room protection.

(1)     Control room and computer room should be protected by Clean Agent Fire Extinguishing System.

(2)     In order to minimize the exposure to Clean Agent Fire Extinguishing System, persons should be evacuated from the areas before the system comes into operation.

(3)     Clean agent fire extinguishing system as per NFPA-2001 shall be provided for the protection system. Each hazard area to be protected by the protection system shall have an independent system. The time needed to obtain the gas for replacement to restore the systems shall be considered as a governing factor in determining the reserve supply needed and 100% standby containers shall be considered for each protected hazard. Storage containers shall be located as near as possible to hazard area, but they shall not be exposed to fire. Storage containers shall be carefully located so that they are not subjected to mechanical, chemical or other damage.

(4)     All the components of the system shall be capable of withstanding heat of fire and severe weather conditions.

5.5 First aid fire fighting equipment:

The fire extinguishers shall be provided as per the Table given below, namely:—

Notes:

(1)     All fire extinguishers shall conform to respective BIS or equivalent codes, such as 9 Kg DCP Type (IS : 15683), 4.5/6, 8 Kg CO2 Type (IS : 2878) and 25/50/75 Kg DCP Type (IS : 10658) and bear ISI mark. BIS or Equivalent certificates of all extinguishers shall be maintained at the location;

(2)     While selecting the Extinguisher, due consideration should be given to the factors like flow rate, discharge time and throw in line with IS : 2190 or equivalent;

(3)     The Dry Chemical Powder used in extinguisher and carbon dioxide gas used as expelling agent shall be as per relevant BIS or Equivalent code;

(4)     While selecting the dry chemical powder, due consideration should be given to the typical properties such as Apparent Density (0.65 +/-0.05), Fire Rating (144B), Thermal Gravimetric Analysis (with decomposition at around 250°C) and foam compatibility;

(5)     Siliconised Potassium bicarbonate DCP powder (IS 4308 : 2003) or Mono-ammonium phosphate based DCP powder (IS : 14609) can also be used for recharging DCP fire extinguishers;

(6)     Spare CO2 cartridges and DCP refills as required based on their shelf life should be maintained, but minimum 10% of the total charge in the extinguishers should be maintained at the location;

(7)     Portable fire extinguishers shall be located at convenient locations and are readily accessible and clearly visible at all times;

(8)     The sand buckets shall have round bottom with bottom handle having 9 litre water capacity conforming to IS : 2546. The sand stored in bucket shall be fine and free from oil, water or rubbish;

(9)     Rain protection of suitable design should be provided for all extinguishers and sand buckets;

(10)   The maximum running distance to locate an extinguisher shall not exceed 15 m; and

(11)   The extinguisher shall be installed in such a way that its top surface is not more than 1.5m above the floor or ground level.

5.6 Emergency trolley and emergency kit.

(1)     A trolley containing Fire Proximity Suit, B.A. Set, Water Jel Blanket, Resuscitator, First Aid Box, Stretcher with blanket, Spare fire hoses, Special purpose nozzles, Foam branch pipes, Explosive meter, P.A. System shall be readily available at the location and positioned to have easy access to it during emergency situation.

(2)     An emergency kit shall be provided consisting of safety items shall be readily available at the terminals. All the items of the kit shall be kept on a trolley specifically designed for the purpose.

5.7 Motorable arrangement for towing or carrying mobile fire fighting equipment such as Foam trolleys, Portable water-cum-foam monitors and like other monitors should be made and available on sharable basis.

5.8 Hydrocarbon detection and annunciation, dyke drain valve annunciation system and emergency shutdown logic:

5.8.1 Hydro carbon detection and annunciation system.—Hydrocarbon detectors shall be installed near all potential leak source of class-A that is to say tank dykes, tank manifolds, pump house manifold and like other manifolds and Hydrocarbon detector of proper type shall be selected and also shall be proof tested and shall be maintained in good condition. The other details are specified as below, namely:—

(1)     General:

(i)       The best method of prevention of explosion is to avoid basic build-up of Explosive Vapour concentration immediately on occurrence of leakage, and such method would require basically a reliable and continuous Hydro Carbon detection system with warning annunciation to alert the operating personnel to take timely corrective action;

(ii)      The Hydro Carbon Detection System shall provide early warning on build-up of Vapour concentration below the LFL limits.

(2)     Application:

(i)       Hydrocarbon (HC) detectors shall be installed near all potential leak sources of Class-A Petroleum products such as tank dykes, tank manifolds and pump house manifold and such detectors shall be placed in a way that entire possible source of leaks and collection of products is continuously detected and alarm is set at 20% of lower explosive limit of Class-A petroleum products;

(ii)      The detection control equipment should be provided in the control room and the field for continuous monitoring should be provided even during power failure.

(3)     Power Supply:

The supply to the system shall be through a reliable on line uninterrupted power supply. (online UPS).

(4)     Architecture Components:

The main components shall be as specified below, namely:—

(i)       Hydro Carbon Detectors;

(ii)      Field Transmission units or Signal scanners;

(iii)     Control system or PC;

(iv)    Display;

(v)      Annunciation System and like other system;

(vi)    Cables, hooters, repeater, Power Supplies and like other devices; and

(vii)   All the components installed in the hazardous area shall confirm to the Hazard Area Classification applicable and shall be certified by PESO or Authorized lab by the country of the origin.

(5)     Annunciation System:

(i)       Appropriate annunciation system shall be available to ensure that all the alarms generated, both, audio and visual are reported to the installation personnel at local and remote control panel. The alarms both, audio and visual can be repeated at additional location to ensure corrective action is taken;

(ii)      Hydro Carbon Detectors should be available as per requirement;

(iii)     The detectors shall be able to detect the presence of Hydro Carbon Vapours well below the LEL level;

(iv)    Any one or more in combination from the following types can be provided Namely:—

(a)      Catalytic detectors;

(b)      Infra-red detectors; and

(c)      Line or Path detectors;

(v)      The system shall be available at all times;

(vi)    The control equipment should have data logging facilities to provide print outs of the history of the events with date and time of leakages; and.

(vii)   The control equipment should be able to generate at least two alarms at different levels of LEL concentration of Hydro Carbons.

(6)     Inspection and Testing:

(i)       Calibration of the detectors shall be done as per OEM recommendation or once in six month, whichever is earlier;

(ii)      The drift in the sensitivity of the individual detectors shall be recorded in maintenance history log book during calibration and the detectors with abnormal or wide drift in sensitivity shall be rectified or replaced; and

(iii)     Standard calibration kit must be available in the location for periodic performance test of hydrocarbon detectors.

5.8.2 Dyke Drain valve Annunciation system.

(1)     All the dyke valves will be fitted with a proximity switch or sensor for indication of the position of the valve. The valves of the Dyke shall remain in closed position. In case any valve is open, then, Audio alarm and visual indication shall come at control panel for suitable corrective measures.

(2)     In case of automated locations existing PLC can be used, but where the locations are not automated, a standalone system shall be provided.

5.8.2.1 Power Supply.—The supply to the system shall be through a reliable on line uninterrupted power supply/(Online UPS). The main components in the Architecture Components shall be as below, namely:—

(i)       Proximity Switches or Sensors;

(ii)      Field transmitter unit or Signal Scanners;

(iii)     Control System or PC or TAS;

(iv)    Display;

(v)      Annunciation System and like other systems; and

(vi)    Cables, hooters, Mimic, Power Supplies and like other systems.

5.8.2.2 All the components installed in the hazardous area shall confirm to the Hazard Area Classification applicable and shall be certified by Central Institute of Mining and Fuel Research (CIMFR) or Petroleum and Explosive Safety Organization (PESO) or Authorized lab by the country of the origin.

5.8.2.3 Appropriate annunciation system shall be available to ensure that all the alarms generated, both, audio and visual are reported to the installation personnel at local and remote control panel on real time basis and the alarms both, audio and visual should be repeated at additional location to ensure corrective action is taken.

5.8.2.4 The control system shall be available at all times and the control equipment should have data logging facilities to provide print outs of the history of the events with date and time of open and close position of the valves.

5.8.2.5 Inspection and Testing:

(i)       The system shall be checked by the safety officer on a daily basis.

(ii)      The system shall be thoroughly inspected every month by opening and closing the valves and verifying that the Audio Video alarms are generated at local and remote panel and records maintained.

5.8.3 Emergency shut Down (ESD) logic for Terminal Automation System (TAS).—The ESD for TAS enabled locations shall be provided in control room as well as at various strategic locations. ESD system shall be only through push buttons with wired connection. The other details are specified as below, namely:—

(1)     Actuation or/pressing of any ESD shall initiate following actions, namely:—

(a)      Process Shutdown;

(b)      Power Shutdown; and

(c)      Process Shutdown shall include the following, namely:—

(i)       To stop product loading pumps;

(ii)      Barrier gates to open;

(iii)     All ROSOVs and MOVs to close;

(iv)    Tank lorry filling (TLF) or tank wagon filling (TWF) operations through the batch controllers to stop; and

(v)      Fire siren to blow;

(2)     Power Shutdown shall initiate the following, namely:—

(i)       Trip all the panels other than Emergency panel. The Emergency panel should host fire siren, bore wells, jockey pumps, critical High Mast tower lights outside the licensed area, security cabin, fire pump house, Critical lights in TLF, Admin block, MCC room and power to the control room or Automation system;

(ii)      There should be interlock between ESD for Process shut down and ESD for Power shut down so that full power shut down takes after a time lag required for closing the ROSOV or MOVs and full closure of valves shall be ensured. The time lag shall be location specific; and

(iii)     At pipe line locations alarm signal shall be exchanged between the two control rooms so that necessary actions are taken by the operating personnel at both ends;

(3)     Inspection and Testing:

The system shall be checked during each fire drill conducted with full system shut down and records shall be maintained.

5.9 Mock drills and Mutual aid.

(1)     Instructions on the action to be taken in the event of fire should be pasted at each siren point and familiarity with such instructions ensured and recorded.

(2)     Monthly fire drills considering various scenarios shall be conducted regularly with full involvement of all employees of the installation. The mock drill shall include the full shut down system activation once in six months.

(3)     The offsite disaster mock drills shall be conducted periodically as per local statutory requirements.

(4)     The company should approach and coordinate with the district authority for conducting “Offsite Mock Drills”.

(5)     The post drill analysis should be carried out and discussed emphasizing areas of improvements.

(6)     The record of such drills should be maintained at the location.

(7)     Mock drill scenarios shall include all probable scenarios and the key areas like tank Farm, Rim seal fire, Gantry, Pump House, Tank Wagon gantry and like other key areas, shall be covered at least once in six months.

(8)     Security staff should be trained as first responders for fire fighting and rescue operation along with plant operating personnel.

(9)     Installation shall have a ‘Mutual Aid’ arrangement with nearby industries to pool in their resources during emergency.

(10)   Mutual Aid agreements shall be prepared and signed by all Mutual Aid members. Fresh agreement shall be made on expiry of 2 years or whenever there is change in the signatories to the agreement. Quarterly meeting of Mutual Aid members shall be conducted and the minutes shall be recorded and the minutes shall be reviewed in the subsequent meetings.

5.10 ERDMP (Emergency Response and Disaster Management Plan).

(1)     A comprehensive ERDMP shall be developed in accordance to the Petroleum and Natural Gas Regulatory Board (Codes of Practices for Emergency Response and Disaster Management Plan (ERDMP)) Regulations, 2010 and the copies of the ERDMP shall be available to all personnel in the installation.

(2)     The key action points of the comprehensive ERDMP referred in sub-paragraph (1) shall be displayed at strategic locations in the installation for ready reference.

5.11 Fire Protection system : Inspection and Testing.

(1)     The fire protection equipment shall be kept in good working condition all the time.

(2)     The fire protection system shall be periodically tested for proper functioning and logged for record and corrective actions.

(3)     One officer shall be designated and made responsible for inspection, maintenance and testing of fire protection system.

(4)     The responsibilities of each officer shall be clearly defined, explained and communicated to all concerned in writing for role clarity.

5.11.1 Fire water pumps.

(1)     Every pump shall be test run for at least half an hour or as per OEM guidelines, whichever is higher twice a week at the rated head and flow.

(2)     Each pump shall be checked, tested and its shut-off pressure observed once in a month.

(3)     Each pump shall be checked and tested for its performance once in six months by opening required nos. of hydrants or monitors depending on the capacity of the pump to verify that the discharge pressure, flow and motor load are in conformity with the design parameters.

(4)     Each pump shall be test run continuously for 4 hours at its rated head and flow using circulation line of fire water storage tanks and observations relating thereto shall be logged once a year.

(5)     The testing of standby jockey pump, if provided shall be checked weekly. Frequent starts and stops of the pump indicate that there are water leaks in the system which should be attended to promptly.

5.11.2 Fire water ring mains.

(1)     The ring main shall be checked for leaks once in a year by operating one or more pumps and keeping the hydrant points closed to get the maximum pressure.

(2)     The ring mains, hydrant, monitor and water spray header valves shall be visually inspected for any missing accessories, defects, damage and corrosion every month and records thereof shall be maintained.

(3)     All valves on the ring mains, hydrants, monitors and water spray headers shall be checked for leaks, smooth operation and lubricated once in a month.

5.11.3 Fire water spray system.

(1)     Water spray system shall be tested for performance that is to say its effectiveness and coverage once in six months.

(2)     Spray nozzles shall be inspected for proper orientation, corrosion and cleaned, if necessary at least once a year.

(3)     The strainers provided in the water spray system shall be cleaned once in a quarter and records thereof shall be maintained.

5.11.4 Fixed and semi fixed foam system.—Fixed or Semi fixed foam system on storage tanks should be tested once in six months and such testing shall include the testing of foam maker or chamber. The foam maker or chamber should be designed suitably to facilitate discharge of foam outside the cone roof tank and after testing foam system, piping should be flushed with water.

5.11.5 Clean agent system.—Clean agent fire extinguishing system should be checked as below, namely:—

(1)     Agent quantity and pressure of refillable containers shall be checked once every six months; and

(2)     The complete system should be inspected for proper operation once every year (refer latest NFPA 2001 for details of inspection of various systems).

5.11.6 Hoses.—Fire hoses shall be hydraulically tested once in six months to a water pressure as specified in relevant IS/UL/equivalent codes.

5.11.7 Communication system.—Electric and hand operated fire sirens should be tested for their maximum audible range once a week.

5.11.8 Fire water tank or reservoir.

(1)     Above ground fire water tanks should be inspected externally and internally.

(2)     The water reservoir shall be emptied out and cleaned once in 3 years, but floating leaves, material or algae, if any, shall be removed once in 6 months or as and when required.

5.11.9 Fire extinguishers.—Inspection, testing frequency and procedure for fire extinguishers should be in line with design standard.

PART — F

(Maintenance and Inspection)

6.0 MAINTENANCE AND INSPECTION.—Each facility shall have a documented operating manual including operations, maintenance, training procedures, purging and record keeping based on experience and conditions under which the Petroleum Installation is operated, and a documented maintenance manual and such facility shall also have written operating, maintenance, and training procedures based on experience, knowledge of similar facilities, and conditions under which they will be operated.

6.1 Basic Requirements.—Each facility shall meet the following requirements, namely:—

(1)     Have written procedures covering operation, maintenance, and training;

(2)     Keep up-to-date drawings of plant equipment, showing all revisions made after installation;

(3)     Revise the plans and procedures as operating conditions or facility equipment require;

(4)     Establish a written emergency plan;

(5)     Establish liaison with appropriate local authorities such as police, fire department, or hospitals and inform them of the emergency plans and their role in emergency situations;

(6)     Analyze and document all safety-related malfunctions and incidents for the purpose of determining their causes and preventing the possibility of recurrence;

(7)     As per maintenance philosophy, the activities should be identified that would be contracted to third party contractors for maintenance and support;

(8)     The activity supervisors shall be identified according to the level of supervision required;

(9)     The supervisors referred to in clause (8) shall be given safe supervisor training by designated staff and then they shall be put on the job;

(10)   The contractors staff shall be engaged in toolbox talk given on relevant topics are held with the Contract holders and owners; and

(11)   OEM service engineers are involved in critical overhauls for better quality assurance and for first time activities.

6.2 The operating manual for petroleum storage, handling and loading or unloading facilities shall include standard operating procedures which shall include procedures for the following, namely:—

(1)     Handling, maintenance, inspection and fire protection facilities;

(2)     Determining the existence of any abnormal conditions, and the response to such conditions in the plant;

(3)     The safe transfer of petroleum including prevention of overfilling of vessels;

(4)     For the proper startup and shutdown of all components;

(5)     To ensure that each control system is adjusted to operate within its design limits;

(6)     For monitoring operations; and

(7)     Emergency preparedness and handling

6.3 The operating procedures manual shall be accessible to all plant personnel and shall be kept readily available in the operating control room. The operating manual shall be updated when there are changes in equipment or procedures. All petroleum plant components shall be operated in accordance with the standard operating procedures as per operating manual.

6.4 The periodic inspections and tests shall be carried out in accordance with generally accepted engineering practice or recommendations of Original Equipment Manufacturer to ensure that each component is in good operating condition.

6.5 Each facility operator shall ensure that when a component is served by a single safety device only and the safety device is taken out of service for maintenance or repair, the component is also taken out of service.

6.6 It shall be ensured that where the operation of a component that is taken out of service could cause a hazardous condition, a tag bearing the words “Do Not Operate,” or the equivalent thereto, is attached to the controls of the component, and wherever possible, the component shall be locked out.

6.7 Stop valves for isolating pressure shall be locked or sealed open and such stop valves shall not be operated except by an authorized person.

7.0 Maintenance Manual:

7.1 Each facility operator shall prepare a written manual that sets out an inspection and maintenance program for each component that is used in the facility.

7.2 The maintenance manual for facility components shall include the following, namely:—

(1)     The manner of carrying out and the frequency of the inspections and tests as specified in this behalf;

(2)     All procedures to be followed during repairs on a component that is operating while it is being repaired to ensure the safety of persons and property at the facility; and

(3)     Each entity shall conduct its maintenance program in accordance with its written manual for facility components, and in addition, the history card of all critical equipments, instruments and systems shall be maintained.

7.3 Maintenance Work flow.

(1)     The objective of the work flow is to provide an integrated proactive and reactive work plan so that repair work is minimized and reliability and availability are optimized. Maintenance execution begins with the receipt of a work request and concludes with the close out of the work order.

(2)     Correct prioritization of work and proactively preparing activities through high quality work preparation, combined with accurate scheduling, will lead to a more stable work environment and reduce deferments and breakdowns, improve integrity and safety, and provide additional job satisfaction and ownership to technicians.

(3)     The management and control of day-to-day maintenance on all process units and utilities of a site is to provide—

(a)      support for a maintenance strategy based on doing programmed maintenance on time;

(b)      safe, healthy and environmentally sound execution of maintenance work;

(c)      availability of equipment; and

(d)      business efficiency.

(4)     The designated person for issue of work permit shall verify the execution of preparation activities before issue of the work permit.

(5)     Maintenance work shall be undertaken in accordance with work permit requirements.

(6)     Inspection personnel should be notified on time at which moment witnesses or hold points set.

(7)     A verification of the HSE requirements should be carried as the maintenance execution includes HSE review and a toolbox talk as outlined in the work permit or work pack.

(8)     The maintenance supervisor should ensure that a toolbox talk is held before work commences.

(9)     Upon completion of the job, the job site should be left safe, clean and tidy and any excess materials should be returned to the stores and tools should be cleaned and returned to the workshop or put away in the correct storage place.

(10)   On a daily basis, the progress of work should be reported. If the work is not completed, it should continue the next working day after taking requisite permission and approval from work permit issuing personnel.

(11)   The work permit duly signed shall be returned to issuing authority on completion of job, removal of all material from site and handing over of facilities to user and like other events.

7.4 Maintenance Strategy.

(1)     The facilities should be designed for minimum maintenance intervention.

(2)     The maintenance requirements should be clearly defined and further optimized based on maintenance strategy reviews using tools such as reliability centred maintenance, Risk Based Inspection and Risk Assessment Matrix (RAM), after detailed equipment specifications are known.

(3)     The criticality of the equipment shall be taken into account during the maintenance strategy selection.

(4)     Appropriate diagnostic tools and staff competencies shall be provided to facilitate rapid fault finding and rectification and also to provide opportunistic maintenance during outages.

(5)     Maintenance strategies shall maximize non-intrusive and on line data acquisition to support planning and analysis.

(6)     Special Critical Equipment shall have OEM defined performance standards which shall be periodically tested and verified.

(7)     Structural and pipeline survey and painting shall be done on a regular basis.

7.5 The entity shall prepare a written plan for preventive maintenance covering the scope, resources, periodicity and like other particulars. The corrective measures should include the preventive maintenance, scheduling, execution and closure.

7.6 Each facility should have well defined system for identification of spare part; rationalization and optimization to minimize any supply chain or logistics constraints and risks.

7.7 Well defined Roles and Responsibilities matrix should be available made for each machine as well as activity to be carried out in the workshop and the procedure for Audits and Review of the workshop shall be documented and adhered to.

8.0 Inspection.

(1)     Each facility shall have written inspection, testing and commissioning program in place. Inspection shall include before commissioning during installation as well as during regular operation of the Petroleum Installation.

(2)     All documents related to design, installation procedure of the respective vendors and the manufacturer's instruction for pre-commissioning and commissioning of the equipment, systems, instruments, control systems and like other devices shall be properly stored and followed.

(3)     Inspection shall cover the review of test protocols and acceptance criteria that such procedures are in accordance with the protocols and acceptance criteria specified in line with OEM specific requirements

(4)     Inspection shall cover that the equipment is installed in accordance with design, and any deviations documented and approved.

(5)     All safety systems are installed inspected and tested as per design or OEM requirement.

(6)     Inspection shall cover that all safety devices are installed and are in working condition as per the design or OEM requirements.

(7)     Inspection shall cover the verification of various safety interlocks and ESD provided in the design.

(8)     Inspection shall cover the adequacy of sealing systems.

(9)     Inspection shall cover the electrical systems, check its integrity, earthing resistance, bonding and like other requirements.

(10)   Inspection shall cover the integrity of mechanical and rotating equipment.

(11)   The integrity and efficacy of gas detection, fire protection and fighting system and connected equipments shall be covered in the inspection.

(12)   Inspection shall cover the efficacy of corrosion system.

(13)   Inspection shall cover and review the mechanical completion records that the PSVs are of the correct type and sizing as per the P and IDs/data sheets.

(14)   Inspection shall cover location of inlet pipe-work to relieving devices in relation to potential restrictions (such as above liquid levels, vessel internals, and like other potential restrictions).

(15)   Inspection shall cover and review P and IDs to check the position of isolation valves for relieving devices, their capacities. Inspection to confirm by review of all vent locations (atmospheric vent from drums or equipment seals) that they vent to safe location and in the event of liquid carry over will not discharge to areas that may cause a hazard to personnel.

(16)   Inspection shall review the area classification layouts and associated studies to confirm that all possible hazards have been appropriately considered (including possible migration) and the hazardous area drawings correctly account for the actual location of the sources of release the hazardous areas have been appropriately defined.

(17)   Inspection shall cover that all ESD devices move to their safe condition on loss of system output, hydraulic power or instrument air. All ESD Valves and actuators shall remain functional following an explosion or under fire conditions for a sufficient time period to perform their intended function.

(18)   The maximum allowable back pressure and minimum design temperature of the relief system shall be checked for suitability for the highest identified flow rate.

(19)   Control System shall include all status monitoring and actions to and from the Control Rooms.

(20)   Inspection shall cover the escape and evacuation passages.

(21)   Inspection shall cover the emergency communication system for its effectiveness during emergency situations.

PART – G

(Competence Assurance and Assessment)

9.0 COMPETENCE ASSURANCE AND ASSESSMENT:

9.1 Every entity shall develop, implement, and maintain a written training plan to instruct all Petroleum installation personnel with respect to the following, namely:—

(1)     Carrying out the emergency procedures that relate to their duties at the petroleum installation as set out in the procedure manual and providing first aid;

(2)     Permanent maintenance, operating, and supervisory personnel with respect to the following, namely:—

(i)       The basic operations carried out at the petroleum installation;

(ii)      The characteristics and potential hazards of petroleum and other hazardous fluids involved in operating and maintaining the petroleum installation;

(iii)     The methods of carrying out their duties of maintaining and operating the petroleum installation as set out in the manual of operating, maintenance and transfer procedures;

(iv)    Fire prevention, including familiarization with the fire control plan, fire fighting, the potential causes of fire, the types, sizes, and likely consequences of a fire at petroleum installation; and

(v)      Recognizing situations when it is necessary for the person to obtain assistance in order to maintain the security of the petroleum installation.

9.2 Each entity shall develop, implement, and maintain a written plan to keep its personnel up-to-date on the function of the systems, fire prevention, and security at the petroleum installation.

9.3 The Refresher programs for training of all personnel shall be conducted an interval not exceeding 3 years to keep personnel updated on the knowledge and skills.

9.4 Every entity shall maintain a record for each employee that sets out the training given to the employee under this Part.

9.5 Each entity shall ensure that petroleum installation personnel receive applicable training and have experience related to their assigned duties. Any person who has not completed the training or received experience shall work under the control of trained personnel.

9.6 For the design and fabrication of components, each entity shall use personnel who have demonstrated competence by training or experience in the design of comparable components and for fabrication who have demonstrated competence by training or experience in the fabrication of comparable components.

9.7 Supervisors and other personnel utilized for construction, installation, inspection, or testing shall have demonstrated their capability to perform satisfactorily the assigned function by appropriate training in the methods and equipment to be used or related experience and accomplishments and further their capability shall be assessed periodically.

9.8 Each entity shall utilize for operation or maintenance of components only such personnel who have demonstrated their capability to perform their assigned functions by successful completion of the training as specified in this behalf and possess experience related to the assigned operation or maintenance function.

9.9 Corrosion control procedures including those for the design, installation, operation, and maintenance of cathodic protection systems, shall be carried out by, or under the direction of, a person qualified by experience and training in corrosion control technology.

9.10 Personnel having security duties shall be qualified to perform their assigned duties by successful completion of the training as specified in this behalf.

9.11 There shall be a minimum level maintained with men apart from the security personnel for monitoring the facilities even during non operational hours.

9.11.1 During all operations even after the general shift, a dedicated fire fighting team should be present. Alternatively, the security personnel shall be trained and certified for operation of fire fighting and emergency handling.

9.11.2 A dedicated, qualified and experienced officer should be designated as ‘Safety Officer’ of the Terminal after training. He shall be given exposure to Hazop, Risk Assessment, Safety Audit and upkeep of fire fighting facilities and conducting Safety Meetings.

9.12 Each entity shall follow a written plan to verify that personnel assigned operating, maintenance, security, or fire protection duties at the petroleum installation do not have any physical condition that would impair performance of their assigned duties. The plan shall be designed to detect both readily observable disorders, such as physical handicaps or injury, and conditions requiring professional examination for discovery.

9.13 Operations and Maintenance training.—Each entity shall provide and implement a written plan of initial training to instruct, the personnel as specified in succeeding paragraph 9.13.1 to 9.13.3.

9.13.1 All permanent maintenance, operating, and supervisory personnel;—

(1)     about the characteristics and hazards flammable fluids used or handled at the facility, including, flammability of mixtures with air, odourless vapour, boil off characteristics, and reaction to water and water spray;

(2)     about the potential hazards involved in operating and maintenance activities; and

(3)     to carry out aspects of the operating and maintenance procedures that relate to their assigned functions.

9.13.2 All personnel of petroleum installation shall be trained to carry out the emergency procedures that relate to their assigned functions; and to give first-aid;

9.13.3 All operating and appropriate supervisory personnel of petroleum installation shall be trained to understand detailed instructions on the facility operations, including controls, functions, and operating procedure.

9.14 Security Training.—Personnel responsible for security at petroleum installation shall be trained in accordance with a written plan of initial instruction to—

(1)     recognize breaches of security;

(2)     carry out the security procedures that relate to their assigned duties;

(3)     be familiar with basic plant operations and emergency procedures, as necessary to effectively perform their assigned duties; and

(4)     recognize conditions where security assistance is needed.

9.15 Fire Protection and Fighting Training.—All personnel including officers, operators, security, T/T drivers and contract workmen, clericals who are likely to be present/working in the petroleum installation shall be trained in accordance with a written plan of initial instruction, including plant fire drills, to —

(1)     know and follow the fire prevention procedures as specified in this behalf;

(2)     know the potential causes and areas of fire determined;

(3)     know the types, sizes, and predictable consequences of fire determined;

(4)     know and be able to perform their assigned fire control duties according to the procedures and by proper use of equipment provided;

(5)     each employee who undergo a refresher course once in every three years after initial training; and

(6)     every employee or authorized person of contractor working in the installation who shall be familiarized with fire siren codes and the location of fire siren operating switch nearest to his place of work.

9.16 Training Records.—Each entity shall maintain a system of records which—

(1)     Shall provide evidence that the training programs required under this part have been implemented;

(2)     Shall provide evidence that personnel have undergone and satisfactorily completed the required training programs; and

(3)     Shall ensure that the records maintained for one year after personnel are no longer assigned duties at the petroleum installation.

PART — H

(Vehicle Management System)

10.0 Vehicle Management System.—The transportation management document shall describe the procedures for effective day-to-day management of Road Transport and such management shall include driver selection, recruitment and training, health screening, working hours and other terms and conditions relating thereto.

10.1 Driver Management.—The selection and training of drivers shall be in consonance with conditions as specified in succeeding paragraph 10.1.1 and 10.1.2.

10.1.1 Qualification of driver.

(1)     The driver shall hold a valid driving license for type of vehicle to be driven and shall be authorized to drive vehicles carrying specific class of product under local Dangerous Goods regulations.

(2)     The age of the driver shall not be less than 25 years with minimum of 3 years' experience of driving vehicles for which he is licensed to drive.

(3)     The driver can demonstrate knowledge of local road or highway regulations.

(4)     The driver can able to read and write in local language and comply with local legal regulations in terms of qualifications and requirements for him.

(5)     Competence assessment of the driver should be carried out by a company-approved driving examiner with on-road test.

10.1.2 Training and communications.—The following shall be ensured, namely;—

(1)     That the driver has completed induction training on company rules and emergency response procedures;

(2)     That the driver has attended defensive driving course within last two years;

(3)     That the driver has undergone training on first aid procedures;

(4)     That the driver has completed necessary training as per hazardous good transportation procedures;

(5)     That the driver should attend regular tool box meeting, safety meetings; and

(6)     That the driver should attend daily/trip wise counselling on journey management.

10.2 Journey Management:

10.2.1 Journey management plans and controls shall have the following elements, namely:—

(1)     Routes between supply point and major destination shall be drawn up using effective journey management system in order to avoid unsuitable roads and congested areas as far as practicable;

(2)     Journey time shall be established for such routes and rest and reporting points designated on the long routes which exceed normal driver shift time;

(3)     Resting points where suitable accommodation is available to be designated by management;

(4)     Competent person supervise the journey management plan and procedures;

(5)     System to be in place for deployment of emergency response procedures;

(6)     Known en-route hazards, such as steep gradients, narrow bridges, poor road surface to be identified and recorded in the journey management plan;

(7)     Route hazards maps to be produced and made available to drivers; and

(8)     Trip time and other special route hazard information to be given to driver with customer invoice paperwork.

10.2.2 Driving and duty hours.

(1)     Comply to legal requirements, if any, irrespective of any limits specified in the succeeding sub-paragraph and the drivers shall not drive or be requested to drive when feeling tired and effective fatigue management procedures should be in place.

(2)     The continuous driving shall not exceed three hours and it should be followed by minimum 15 minutes rest. The rest shall be taken on continuous block and either away from vehicle or, if taken in a sleeper cab, while vehicle shall be stationary and alternatively, two drivers can be used with a monitoring system for rest after every three hours.

(3)     Tachograph or in vehicle monitoring system to be fitted for vehicles.

10.3 Vehicle Management.—All vehicles shall comply with local legal requirements and respective company standards and the vehicles shall be designed and equipped for local environments and intended range of operation and the following shall be ensured, namely:—

(1)     The tank truck shall be visually “well maintained “and capable of meeting basic safety inspection consistent with safe manoeuvering at low speeds within confines of loading or delivery location. The inspection includes brake operation and tyre inspection. (tie having a visible tread pattern and no obvious damage);

(2)     Three-point inertia reel seat belts to be fitted for crew;

(3)     The tank truck shall be fitted with an external engine cut-off device;

(4)     The tank truck shall be fitted with audible reversing alarm;

(5)     The tank truck should have product tank with an internal valve to prevent product leakage if an external outlet valve is damaged;

(6)     The tank truck shall have an exhaust system adequately shielded from direct contact with fuel from overfilled tanks leaks;

(7)     The tank truck shall have overfill protection system (compatible with loading rack facilities);

(8)     The tank trucks shall be loaded and operated within maximum permissible gross weight and in accordance with national regulation and approved limits by RTO for both rigid chasis and trailer body;

(9)     Trailer tank to be fitted with overturn protection that gives effective protection to man lids in the event of vehicle roll-overs;

(10)   Tank top safety rail or harness system to prevent driver from falling when or if working on tank top;

(11)   Tank truck shall be provided with a spill kit capable of dealing with small spills < 10 ltrs.”; and

(12)   In case of Dangerous Goods, HGVs to be fitted with at least three number of dry powder fire extinguisher two of which are easily accessible on either side of tank and CO₂ is an acceptable alternative for an extinguisher.

PART – I

(Safety Management System)

11.0 Safety Management System.—The organization should establish a safety management system which shall be an integral part of the overall management system. Safety Management System (SMS) should be based on PDCA (Plan, Do, Check and Act) cycle which comprises of-(

(1)     Policy setting which includes policy, corporate acceptance of responsibility, objectives, requirements, strategies;

(2)     Organization which includes structure, accountability and safety culture, involvement of the workforce, systems for performing risk assessment;

(3)     Planning and execution which includes operational standards and procedures for controlling risks, permit to work, competence and training, selection and control over contractors, management of change, planning and control for emergencies and occupational health;

(4)     Measuring and evaluating which includes active monitoring, recording and investigation of incidents or accidents, auditing and handling of non-conformities; and

(5)     Continuous improvement which includes review and application of the lessons learnt and Safety management system should not degenerate into a paper exercise only, conducted solely to meet regulatory requirements.

11.1 Elements of Safety Management system.—Safety management system should include at least the basic elements as specified in the succeeding paragraph 11.2 to 11.15.

11.2 Safety Organization.—Leadership and Management Commitment should be clearly visible in the SMS. Management should develop and endorse a written description of the company's safety and environmental policies and organizational structure that define responsibilities, authorities, and lines of communication required to implement the management program. Management should review the safety and environmental management program to determine if it continues to be suitable, adequate and effective at predetermined frequency. The management review should address the possible need for changes to policy, objectives, and other elements of the program in light of program audit results, changing circumstances and the commitment to continual improvement. Observations, conclusions and recommendations of management review should be documented.

11.3 Safety Information.—Comprehensive safety and environmental information for the facility, which includes documentation on process, mechanical and facility design, should be developed and maintained throughout the life of the facility.

11.4 Process Hazard Analysis.—The purpose of Process Hazard Analysis (PHA) is to minimise the likelihood of the occurrence and the consequences of a dangerous substance release by identifying, evaluating and controlling the events that could lead to the release. Process hazards analysis should be performed for any facility to identify, evaluate, and reduce the likelihood or minimize the consequences of uncontrolled releases and other safety or environmental incidents and human factors should also be considered in this analysis. The process hazard analysis should be updated and revalidated by a team, having requisite back ground, at least every 5 years after the completion of initial process hazard analysis. Recommendations resulting from the PHA should be completed before start-up for a new process or facility, or modification in existing facility.

11.5 Operating Procedures.—Written down operating procedures shall be available describing tasks to be performed, data to be recorded, operating conditions to be maintained, samples to be collected and safety and health precautions to be taken for safe operation. Operating procedures should be based on process safety information so that all known hazards are taken care of. The human factors associated with format, content, and intended use should be considered to minimize the likelihood of procedural error.

11.6 Safe Work Practices.—The entity shall maintain procedures that address safe work practices to ensure the safe conduct of operating, maintenance, and emergency response activities and the control of materials that impact safety and such safe work practices may apply to multiple locations and will normally be in written form (safety manual, safety standards, work rules, and like other written forms) but site-specific work practices shall be prepared and followed. In cases where an employee believes that following a procedure will cause an unsafe condition, he shall have authority to stop work and get permission from appropriate level to deviate and deviations should be documented for future analysis.

11.7 Training.—The training program shall establish and implement programs so that all personnel including contractors are trained to work safely and are aware of environmental considerations, in accordance with their duties and responsibilities. Training shall address the operating procedures, the safe work practices, and the emergency response and control measures and any change in facilities that requires new or modification of existing operating procedures may require training for the safe implementation of such procedures and the training should be provided by qualified instructors and documented.

11.8 Management of Change (MOC).—There should be procedures to identify and control hazards associated with change and to maintain the accuracy of safety information and for each MOC, the operator shall identify the potential risks associated with the change and any required approvals prior to the introduction of such changes. The types of changes that a MOC procedure addresses shall include—

(i)       technical;

(ii)      physical;

(iii)     procedural; and

(iv)    organizational,

and such procedure shall consider permanent or temporary changes and the process shall incorporate planning for the effects of the change for each situations relating thereto and the procedures should cover the following, namely:—

(i)       The process and mechanical design basis for the proposed change;

(ii)      An analysis of the safety, health, and environmental considerations involved in the proposed change, including, as appropriate, a hazards analysis;

(iii)     The necessary revisions of the operating procedures, safe work practices, and training program;

(iv)    Communication of the proposed change and the consequences of that change to appropriate personnel and the necessary revisions of the safety and environmental information;

(v)      The duration of the change, if temporary; and.

(vi)    Required authorizations to effect the change.

11.9 Contractors.—When selecting contractors, operators should obtain and evaluate information regarding a contractor's safety and environmental management policies and practices, and performance there under, and the contractor's procedures for selecting subcontractors. The entities shall communicate their safety and environmental management system expectations to contractors and identify any specific safety or environmental management requirements which they have for contractors. Interfacing of SMS of various entities (operator, contractor or service provider, subcontractor and third-party) should be ensured through a well written bridging document. Entity shall document the clear roles and responsibilities with its contractors.

11.10 Assurance of quality and mechanical integrity of critical equipment.—Procedures should be in place and be implemented so that critical equipment for any facility is designed, fabricated, installed, tested, inspected, monitored, and maintained in a manner consistent with appropriate service requirements, manufacturer's recommendations, or industry standards. Entity shall maintain inspection and testing procedures for safety-related equipment. Human factors should be considered, particularly regarding equipment accessibility for operation, maintenance and testing.

11.11 Pre-startup Safety Review.—Before a new or modified unit is started, a systematic check should be made to ensure that the construction and equipment are in accordance with specifications; operating procedures have been reviewed; hazards analysis recommendations have been considered, addressed and implemented; and personnel have been trained. It should be ensured that programs to address management of change are in place.

11.12 Permit to Work (PTW) System.—PTW system is a formal written system used to control certain types of work which are identified as potentially hazardous. Essential features of permit-to-work systems are as specified below, namely:—

(i)       Clear identification of who may authorize particular jobs (and any limits to their authority) and who is responsible for specifying the necessary precautions;

(ii)      Training and instruction in the issue, use and closure of permits;

(iii)     Monitoring and auditing to ensure that the system works as intended;

(iv)    Clear identification of the types of work considered hazardous; and

(v)      Clear and standardized identification of tasks, risk assessments, permitted task duration and supplemental or simultaneous activity and control measures.

11.13 Emergency Planning and Response.—A comprehensive Emergency Response and Disaster Management Plan (ERDMP) shall be developed in accordance with the Petroleum and Natural Gas Regulatory Board (Codes of Practices for Emergency Response and Disaster Management Plan (ERDMP)) Regulations, 2010. The copies of the ERDMP shall be maintained at each petroleum installation. The emergency response planning shall have clear written procedures for expected actions during anticipated emergencies and emergency response plan shall include operational and procedural requirements for various emergency scenarios that are relevant for the installation and the emergency procedures shall contain inter alia as specified below, namely:—

(i)       The emergency procedures shall include, at a minimum, emergencies that are anticipated from an operating malfunction of any component of the petroleum storage, handling and transportation facilities, personnel error, forces of nature, and activities carried on adjacent to the facilities;

(ii)      The emergency procedures shall include but not be limited to procedures for responding to controllable emergencies, including the following, namely:—

(a)      The notifying of personnel;

(b)      The use of equipment that is appropriate for handling of the emergency;

(c)      The shutdown or isolation of various portions of the equipment; and

(d)      Other steps to ensure that the escape of gas or liquid is promptly cut off or reduced as much as possible;

(iii)     The emergency procedures shall include procedures for recognizing an uncontrollable emergency and for taking action to achieve the following, namely:—

(a)      Minimize harm to the personnel at the petroleum storage, handling and loading or unloading facilities and to the public;

(b)      Provide prompt notification of the emergency to the appropriate local officials, including the possible need to evacuate persons from the vicinity of petroleum installation;

(c)      The emergency procedures shall include procedures for coordinating with local officials in the preparation of an emergency evacuation plan that sets forth the steps necessary to protect the public in the event of an emergency, including the following, namely:—

(i)       Quantity and location of fire equipment throughout the petroleum installation;

(ii)      Potential hazards at the petroleum installation; and

(iii)     Communication and emergency-control capabilities at the petroleum installation.

11.14 Incident Investigation and Analysis.—Procedures for investigation of all incidents as per the Petroleum and Natural Gas Regulatory Board (Codes of Practices for Emergency Response and Disaster Management Plan (ERDMP)) Regulations, 2010 shall be developed. Incident investigations should be initiated as promptly as possible, considering the necessity of securing the incident scene and protecting people and the environment. The intent of the investigation should be to learn from the incident and help to prevent similar incidents. A corrective action program should be established based on the findings of the investigation to prevent recurrence.

11.15 Compliance Audit.—Safety Audits are the periodic examination of the functioning of safety system and it gives an idea about how effectively the safety system is implemented and how they are being accomplished and it is the feedback mechanism that provides management with the status and measurement of effectiveness of the various safety system elements and activities and leads to the appropriate control over such efforts. The audit program and procedure should cover the following, namely:—

(i)       The activities and areas to be considered in audits;

(ii)      The frequency of audits

(a)      Internal Audit : Every year (including those years in which External Audit is undertaken);

(b)      External Audit : Once in three year;

(iii)     The audit team;

(iv)    How audits will be conducted; and

(v)      Audit Reporting;

and the findings and conclusions of the audit should be provided to the management and the management should establish a system to determine and document the appropriate response to the findings and to assure satisfactory resolution. The audit report should be retained at least until the completion of the next audit.

11.15.1 Internal and External Safety Audits.—Audit conducted by Internal Audit teams of the organization shall be categorized as Internal Safety Audit. Internal Safety Audits shall be coordinated by local management under the overall direction from the respective Corporate Offices. External Safety Audits shall be carried out through PNGRB empanelled third party agency or multidisciplinary team constituted by PNGRB.

Annexure 1 — List of Applicable Standards and References