Information

  • Audit Title

  • Document No.

  • Client / Site

  • Conducted on

  • Prepared by

  • Location
  • Personnel

POLLUTION

  • 30 CFR 250.300 (a) Clean Water Act 311(b)(5) During exploration, development, production and transportation is the lessee preventing pollution of offshore waters by preventing sheens, slicks, waste and other pollutants?

  • 30 CFR 250.300 (a) State Wide Order 29B (d)(f) Is there an excessive buildup of fluid in the instrument supply system that will cause pollution in the Gulf waters when the ESD is activated?

  • 30 CFR 250.300 (b)(4) State Wide Order 29B VIII(c)(2) Is proper containment provided under all water sampling points, fuel nozzles, and hose ends to prevent pollution of offshore waters?

  • 30 CFR 250.120 (a) Does the lessee perform all operations in a safe and workmanlike manner and take all necessary precautions to correct any hazardous oil and gas accumulation or other health, safety, or fire hazard?

  • 30 CFR 250.300 (b)(4) State Wide Order 29B VIII(c)(2) Is the facility equipped with the curbs, gutters, and drip pans necessary to collect all contaminates not authorized for discharge?

  • 30 CFR 250.300(b)(4) Is each drain piped to a sump system that automatically maintain the oil at a level to prevent discharge of oil into offshore waters?

  • 30 CFR 250.300 (b)(4) 67(m)(14) Are all gravity drains (including engine skids) equipped with a water trap or other means to prevent gas in the sump system from escaping through the drains?

  • 30 CFR 250.300 (b)(6) Is the disposal of equipment, cables, chains, containers, and other materials into offsore waters prevented?

  • 30 CFR 250.300 (l) Are all loose materials, small tools, and other small objects kept in a storage area or a marked container when not in use?

  • 30 CFR 250.300 (c) (3)(4) Are skid mounted equipment, portable containers, spools or reels, and drums marked with the owner's name prior to use or transport over offshore waters and are the markings durable enough to withstand the environment exposed to?

  • 30 CFR 250.300 (b) (4) Are sump piles not used as processing devices?

  • 30 CFR 250.300 (b) (1) Is the lessee adhering to prohibition on the addition of petroleum-based substances to the mud system?

  • 30 CFR 250.301 (a) Are daily inspections made to determine if pollution is occurring and are records of such inspections (Daily Pollution Report) being maintained at the facility or at a nearby manned facility for 2 years?

  • 30 CFR 250.303 (a) Does the person-in-charge know the reporting requirements for pollution and have the telephone numbers available?

  • 30 CFR 250.302 (b) Is pollution control equipment on hand or on location and inspected at least monthly with records of such inspection kept for at least 2 years at a site designated in the Oil Spill Contingency Plan (OSCP)?

  • 30 CFR 250.303 (a) Are the records of the pollution control equipment training class available?

  • 30 CFR 250.303 (b) Are the results of the pollution control equipment drills available for inspection?

  • 30 CFR 250.302 Is a current Oil Spill Contingency Plan available on location and is it reviewed and updated annually?

  • 30 CFR 250.301(a) Is a file of previous spill events available on location? Have correct follow ups shown on GO-140 report been implemented?

  • 40 CFR 435.122 Clean Water Act Sec 402 Are the daily NPDES/LWDPS reports filled out and up to date?

  • 40 CFR 435.122 NPDES General Permit Is a static sheen test kit available, used, and maintained in good condition whenever appropriate discharges are initiated during inclement weather and at night?

  • 40 CFR 435.122, NPDES General & LWDPS Permit Does the Person-in-Charge (PIC) have copies of NPDES/LWDPS permit(s) which cover their operations and understand permit requirements?

  • 40 CFR 435.122, NPDES General & LWDPS Permit Are the NPDES/LWDPS reports up to date and accurately completed?

  • 40 CFR 435.122, NPDES General & LWDPS Permit Are noncompliance reports attached for each exceedance of permit limits (i.e., sheens, numerical limits, etc.)?

  • 40 CFR 435.122, NPDES General & LWDPS Permit Does the PIC have, use and maintain the appropriate equipment required for field testing of discharges (i.e., HACH kit, Static sheen test kit, pH peter, etc.,)?

  • 40 CFR 435.122, NPDES General & LWDPS Permit Is the PIC familiar with proper sampling location and procedures for field and laboratory test samples required by the permit(s)?

  • 40 CFR 435.122, NPDES General & LWDPS Permit Is the published sample schedule (used to ensure representative samples) being followed?

  • 40 CFR 435.122, NPDES General & LWDPS Permit Are the results of all field and laboratory testing maintained at the facility for at least 3 years?

  • 40 CFR 435.122, NPDES General & LWDPS Permit Are procedures in place to ensure non-operations personnel working in the field understand permit requirements and complete appropriate NPDES/LWDPS reports (i.e., construction reps, workover reps, etc.)?

  • 40 CFR 435.122, NPDES General & LWDPS Permit Are procedures in place to notify E & S personnel before changes are made to discharge point or new discharge point are added?

  • 40 CFR 435.122, NPDES General & LWDPS Permit Is each discharge point covered under the applicable NPDES/LWDPS permits?

  • 40 CFR 435.122 NPDES General Permit Are the results of the static sheen test recorded on the NPDES/LWDPS reports as required ?

  • 40 CFR 435.122 NPDES General Permit Are the overboard water discharges checked and the oil and grease limits within tolerances set up by the general permits?

  • 40 CFR 435.122 NPDES General Permit Are the results of the required monthly gravimetric overboard water tests available and up to date?

  • 40 CFR 435.122 NPDES General Permit Are quarterly samples of the potable water sent in and the results available?

  • 40 CFR 435.122 NPDES General Permit Do noncompliance reports coincide with data reported on the NPDES/LWDPS reports?

  • 40 CFR 435.122 NPDES General Permit Do the temporary quarters and work area have adequate sewage treating equipment as required by applicable permits ?

NORM

  • LAC 33 XV 1404 Is NORM expected to be encountered on this location? Are proper detection meters and other equipment available and calibrated within last 6 months? Is a copy of Chevron's NORM Worker Protection Plan available?

  • CPDN NORM Field Implementation Guide Are tubulars that are removed from a well monitored for NORM contamination. Is appropriate action taken to prevent spread of contamination?

  • CPDN NORM Field Implementation Guide Is produced sand recovered, containerized, and monitored for NORM contamination?

  • CPDN NORM Field Implementation Guide Do additional state of LA or TX NORM regulations apply at this location?

  • CPDN NORM Field Implementation Guide Are contract personnel that handle NORM properly licensed as necessary?

OFFSHORE WASTE

  • LDNR 29-B, LAC 33 Part VII, MARPOL 73/78 Annex 5, LAC 33 Part V, 40 CFR 260 Are all wastes generated at the facility stored in appropriately labelled containers in a contained area?

  • LDNR 29-B, 40 CFR 260, LAC 33 Part V Are waste manifests properly completed?

  • 30 CFR 250.300 Is the lessee preventing the disposal of equipment, cables, chains, containers and other material into offshore waters?

  • 33 CFR 151.57, 151.73 Does the facility have a USCG required waste management plan?

  • MARPOL 73/78 Annex 5 Is garbage generated at facilities located within the 12 mile nautical limit stored and shipped to the shorebase for proper disposal?

  • MARPOL 73/78 Annex 5 Is garbage generated at facilities located beyond the 12 mile nautical limit ground to 1" pieces and disposed overboard or shipped to the shorebase for proper disposal?

  • 30 CFR 250.300 (b) (2) Is the lessee disposing of drill cuttings, sand, and other well solids as approved?

  • Is the contractor (in lieu of CUSA) properly disposing of the following: 1) Used engine oil including that generated by the boat contractor 2) Paint, solvent and chemicals used to maintain contractor equipment?

FIRE EXTINGUISHERS

  • 33 CFR 145 29 CFR 1910.157 46 CFR 108.495 (a) Are approved portable and/or semiportable fire extinguishers installed and maintained?

  • 33 CFR 145.05 (d) 29 CFR 1910.157 Do all portable and semi-portable extinguishers have permanently attached durable name plates giving name, rated capacity, name and address of firm for whom approved and identifying mark of the actual manufacturer?

  • 33 CFR 145.10 (a) 46 CFR 108.493 (c) Are portable and semi-portable extinguishers installed in accordance with CFR 33 145.10(a)? (COPY ATTACHED)

  • API PR 14G 7.7 (a) 29 CFR 1910.157 46 CFR 108.493 Are extinguishers inspected monthly to ensure they are in their designated places, that they have not been actuated or tampered with and to detect any obvious physical damage, corrosion or other impairments?

  • API RP 14G 7.7 (c) 46 CFR 97.15-60 Are extinguishers thoroughly examined at regular intervals, not more than one year apart, with deficient extinguishers repaired, recharged or replaced as appropriate?

  • API RP 14G 7.4(a)(1) 46 CFR 108.493 Are fixed dry chemical extinguishing systems and other associated equipment annually inspected and checked for proper operation by qualified personnel?

  • API RP 14G 7.4(a)(2) 46 CFR 91.25.20 (a)(2) Are all expellant gas containers checked semi-annually by pressure or weight against required minimums?

  • API RP 14G 7.4(a)(3) 46 CFR 91.25-20 (a)(2) Are all stored pressure dry chemical containers checked by pressure and weight against specified minimums?

FIRE PROTECTION

  • 46 CFR 108.423-425 Fire stations properly equipped with (hose, nozzle, spanner wrench, hose rack, low velocity applicator, if required).

  • 30 CFR 250.803 (8)(i) Is a firewater system of rigid pipe with firehose stations or fixed firewater monitors installed in areas where production handling equipment is located?

  • API RP 14G 7.2(a)(1) 30 CFR 250.803 (b) (8)(i) At least weekly are drivers and pumps for firewater systems started and run long enough to bring to normal operating temperature and do they run smoothly at rated speed and load?

  • API RP 14G 7.2(a)(2) 30 CFR 250.803 At least monthly is water from a firewater system discharged from enough fire water hoses to determine the pump continues to have adequate pumping capacity?

  • 30 CFR 250.803 (b)(8)(iii) If a chemical firefighting system is installed in lieu of a firewater system, has written approval from the MMS District Supervisor been secured and is documentation available for inspection?

  • 30 CFR 250.803 (b)(8)(i) Is a fixed waterspray system install in enclosed well-bay areas where hydrocarbon vapors may accumulate?

  • 30 CFR 250.803 (b)(8)(ii) Is fuel or power for firewater pump drivers available for at least 30 minutes of run time during a platform shut-in?

  • 30 CFR 250.803 (b)(8)(iv) Is a diagram of the firefighting system showing the location of all firefighting equipment posted in a prominent place?

  • 46 CFR 108.631 (a) Are instructions for the operation of a fixed fire extinguishing system posted next to each cabinet or space that contains a valve, control, or manifold ?

  • 46 CFR 108.459 (a)(b)(1)(2)(c) Is foam fire system maintained properly?

  • 46 CFR 107.235 (2)(i)(ii)(iii) Is each foam system except premix system submitted to the manufacturer or his authorized representative for determination of specific gravity, PH, percentage of water dilution and solid content and certification as a suitable firefighting foam?

  • 46 CFR 108.497 46 CFR 109.337 Are fireman's outfits maintained, fully equipped and in proper locations?

  • 46 CFR 108.497 46 CFR 109.301 Are all 30-minute air packs and spare bottles fully charged ?

  • 46 CFR 109.301 46 CFR 95.10 46 CFR 108.417 Fire main system - Check operation of all fire pumps. Fire pump relief valves should relieve 125 PSI.

STATION BILL

  • 33 CFR 146.130 (a) 46 CFR 109.505 (b) Are copies of the station bill signed by the person-in-charge and posted in a conspicuous location on the platform?

  • 33 CFR 146.130 (b) 46 CFR 109.501(a) Does the station bill set forth duties and set forth duty stations for each person aboard for any emergency which involves the use of emergency equipment?

FIRE SUPPRESSION

  • 30 CFR 250.803 (b)(9)(i) Are fire sensors installed in all enclosed classified areas(flame, heat, or smoke)?

  • 30 CFR 250.803 (b)(9)(ii) Is each fire detection system of the manual reset type and capable of continuous monitoring?

  • 30 CFR 250.803 (b)(9)(i) Are buildings in which personnel regularly or occasionally sleep equipped with smoke and/or thermal detectors?

  • 30 CFR 250.803 (b)(9)(v) Are rooms containing a heat source such as a hot water heater, clothes dryer, kitchen range, oven, space heater, etc. equipped with smoke and/or thermal detectors?

  • 30 CFR 250.803 (b)(9)(v) Are smoke detectors placed in individual sleeping rooms or spaced in corridors?

  • 30 CFR 250.803 (b)(9)(v) Are audible/visual fire alarm signals distinctive from any other signal on the platform?

  • 30 CFR 250.801(i), 250.802(b) Does the fire loop system and other fire detection devices initiate surface and subsurface shut-in?

  • 30 CFR 250.804 (8) Is each fire detection system tested for operation and recalibrated at least once every 3 months and documented?

  • 30 CFR 250.804 (8) Are open flame or devices operating at temperatures which could ignite a methane air mixture not used for testing?

  • 46 CFR 108.497 (c) Are oxygen/methane detectors operational and calibrated?

  • 46 CFR 109.213 (a)(b)(c)(d) Are fire drills conducted at least once each week and do all personnel report to their stations, and demonstrate their ability to perform the duties assigned to them in the station bill ?

  • 46 CFR 108.405 (a)(1)(2)(b)(c)(1) (2)(3) 30 CFR 250. 804(9) Are fire detection system and smoke detectors fully operational?. Test TSH devices every 12 mos.

NOISE POLLUTION

  • 29 CFR 1910.95 Has a sound level survey been completed within the last 5 years or since the last modifications to the structure?

  • 29 CFR 1910.95 Is annual audiometric testing current and documentation available?

  • 29 CFR 1910.95 Are high noise areas designated and hearing protection available?

LOCK OUT TAG OUT

  • 33 CFR 142.90 (a)(b)(c)(1)(2)(d) 29 CFR 1910.145/ .147 Are lockout and tagout procedures used when working on equipment that may cause injury?

  • 29 CFR 1910.147 Is annual lockout and tagout inspection completed and documented and are personnel familiar with the lockout/tagout procedures?

RESPIRATORY PROTECTION

  • 29 CFR 1910.134 33 CFR 142.39 Do personnel use respirators as required by the Respiratory Protection Program?

  • 29 CFR 1910.134 33 CFR 142.39 Is a copy of the Respiratory Program available in the field?

  • 29 CFR 1910.134 33 CFR 142.39 Are respirators clean and in good condition with proper particulate cartridges (such as dust, paint fumes, etc.) for the hazards found in this location?

H2S SAFETY

  • 30 CFR 250.417 (h)(1) Is a copy of the approved H2S Contingency Plan available in the field area?

  • 30 CFR 250.417 (h)(1)(iv) Are at least two Safe Briefing areas established?

  • 30 CFR 250.417 (h)(2)(vi) Does each person receive a training session upon arrival at the facility?

  • 30 CFR 250.417 (h)(2)(vi) Has a weekly H2S drill and training session been held and are records of attendance maintained at the facility?

  • 30 CFR 250.417 (h)(2)(vi) Is wind direction equipment installed and operational?

  • 30 CFR 250.417 (h)(2)(vi) Are operational danger signs and rectangular red flags available for use?

  • 30 CFR 250.417 (h)(5)(ii) Is the H2S detection and H2S monitoring equipment calibrated and records available for inspection?

VISITORS

  • 33 CFR 150.751 Do visitors sign the visitors log book and are they briefed on emergency procedures upon boarding the platform?

OTHER

  • 33 CFR 142.30 (a)(b) 29 CFR 1910.135 Do personnel in areas where there is a hazard of falling objects or of contact with electrical conductors wear a head protector meeting the specifications of ANSI Z89.1?

FOOT PROTECTION

  • 33 CFR 142.33 (a)(b) 29 CFR 1910.136 Do personnel working in areas or engaged in activities where there is a reasonable probability for foot injury to occur wear footwear meeting the specifications of ANSI Z41?

EYE PROTECTION

  • 33 CFR 142.27 (a)(b)(c) 29 CFR 1910.133 Do personnel engaged in or observing welding, grinding, machining, chipping, handling hazardous materials, or acetylene burning or cutting wear the eye and face protector specified for the operation according to ANSI Z87.1?

  • 33 CFR 142.40 29 CFR 1910.151 (c) Is portable or fixed eyewash equipment providing emergency relief immediately available near the drill floor, mudrooms and other areas where there is a reasonable probability that eye injury may occur?

PROTECTIVE CLOTHING

  • 33 CFR 146.36 29 CFR 1910.132 Do personnel wear appropriate protective clothing to protect themselves from the hazards of flying particle, radiant energy, molten metal, heavy dust, and hazardous materials?

HAND PROTECTION

  • 29 CFR 1910.134 Are work gloves more readily available?

  • 29 CFR 1910.134 Are gloves mandatory for riggers?

SAFE LIFTING

  • Do personnel practice proper lifting techniques?

SMOKING AREA

  • 29 CFR 1910.132 Are smoking restrictions being practiced and is smoking restricted to designated areas only?

HAZARD AWARENESS

  • 33 CFR 142.4 (a)(b)(c)(1)(2) 29 CFR 1910.22 Does each holder of a lease or permit ensure that all places are maintained in compliance with workplace safety and health regulations of this part and in addition, free from recognized hazards?

  • 29 CFR 1910.144 (a)(3)(3) Did we mark temporary trip hazards with highly visible paint/tape?

  • 29 CFR 1910.144 (a)(3)(3) Do we have "clear walkway" areas designated where no equipment or supplies may be placed/stored?

  • 29 CFR 1910.23 (b) Are all exits and walkways clear of obstructions?

  • Are we maintaining oil free decks, piping and ladders?

  • Are we removing unnecessary standing water and inspecting deck drains?

FALL PROTECTION

  • 33 CFR 142.42 (a)(b) Are personnel engaged in an activity where there is a hazard of falling 10 or more feet required to use a safety belt or harness secured by a lanyard to a lifeline, drop line, or fixed anchorage and do they meet the specifications of ANSI A10.4?

  • 33 CFR 142.45 Are personnel required, when working in a location such that, in the event of a fall, they would likely fall into the water, to wear a work vest (Type V) or a life preserver (Type I), except when using safety belts and lifelines?

  • 33 CFR 142.87 Are openings in decks accessible to personnel covered, guarded or otherwise made inaccessible when not in use. The manner of blockage shall prevent a person's foot or body from inadvertently passing through the opening?

  • 29 CFR 1910.28 Are all scaffolds secured and properly supported?

HAND RAILS

  • 33 CFR 143.110 (a) Are the unprotected perimeter of all floor or deck areas and openings rimmed with guards and rails or wire mesh fence (except helicopter landing decks)?

  • 33 CFR 143.110 (c) Does each catwalk and each stairway have a suitable guard rail or rails, as necessary?

HELIPORT

  • 33 CFR 143.110 (b) Is the perimeter of the helicopter landing deck protected with a device of sufficient strength and size to prevent any person from falling from the deck?

  • 46 CFR 108.239 (a)(b)(c)(d)(e)(f)(g) Is the following equipment provided with each fueling station: a nozzle of the "dead man " type, a storage reel, a static grounding device, and a fuel transfer pump with a control with an indicator light at the pump?

GRINDERS

  • 29 CFR 1910.215 Are proper grinder guards and handles in place?

WARNING SIGNS

  • 29 CFR 1910.145 Are warning signs posted in work areas along with signs promoting good practices?

HOUSEKEEPING

  • Do the Company Rep and job foreman inspect work areas daily for safety hazards and to ensure compliance and good housekeeping?

  • 30 CFR 250.120 Is each operation performed in a safe and workmanlike manner, and are necessary precautions taken to prevent health, safety or fire hazards?

  • Do all personnel practice good helicopter and boat safety?

EXHAUST GASSES

  • 30 CFR 250.803 (b)(5)(i) Is exhaust piping from each diesel engine equipped with spark arrestors? This includes all contract and rental equipment whether temporary or permanent installation. (Straight exhausts are not acceptable.)

  • 30 CFR 250.402 (b) Is each welding machine equipped with a spark arrestor on the exhaust system and no sparks are being discharged while running? Is the welding machine equipped with a drip pan or is it enclosed in an area with curbs and gutters?

  • 30 CFR 250.803 (b)(5)(i) Are engine exhausts or other areas with a normal operating temperature greater than 160 degrees, been covered with an insulation barrier or protected with vapor barriers, water cooling, caution signs, or isolation barriers?

  • 30 CFR 250.803 (b)(5)(i) Are surfaces with a temperature in excess of 400 degrees protected from spillage or leakage of crude oil, and surfaces with temperatures in excess of 900 degrees protected from accumulations of combustible gases?

  • 30 CFR 250.403(a) Are all engines with electrical ignition systems equipped with a low-tension ignition system designed and maintained to minimize the release of sufficient electrical energy to cause ignition of an external, combustible mixture or substance?

  • 30 CFR 250.401 (b)(2) 250.510, 250.610 Are diesel engines which are continually attended provided with either a remote operated or automatic air intake shutdown device?(Continuously attended means a person standing by the engine at all times)

  • 30 CFR 250.401 (b)(2) 250.510, 250.610, 250.803 (b)(5)(ii) Are diesel engines which are not continuously attended equipped with automatic air intake shutdown devices?

ELECTRICAL

  • 29 CFR 1910.304 Has the condition of electrical extension cords been inspected and electrical connection undamaged and in good condition? Is all temporary electrical equipment properly grounded?

  • 29 CFR 1910.307 Is all electrical equipment suitable for the area where it is installed? (Reference structure area classification drawing for Division 1 and 2 areas.)

  • 30 CFR 250.403 (c) 30 CFR 250.508 Are all electrical installations made in accordance with API RP 14 F, (Class I installations in Class I areas)?

  • 30 CFR 250.403 (c) Are all Gai-tronics boxes and electrical boxes completely sealed with all bolts screwed in tight on explosion proof boxes?

  • 30 CFR 250.403 (c) Are all new EYS connections properly installed and poured? Is temporary lighting sufficient for working in an area at night?

  • 30 CFR 250.403 (b) Is each area classified in accordance with API RP 500B?

GENERAL

  • Does equipment show excess signs of wear and tear, poor maintenance, fraying, rust, leaks, cracks, sparks, or other problems?

  • 30 CFR 250.120 (b) In any area of the facility, is there an unsafe accumulation of oil and gas, or other health, safety, or fire hazards?

  • Are overboard lines for the sewage unit in good condition? Are all air line connections free of leaks?

  • Are all choke stems, regulators, hydraulic cylinders, and related equipment free of oil leaks?

  • Are all moving parts of machinery covered or protected with a guard and is the guard in good condition?

  • Are signs showing equipment starts automatically, Hearing Protection Required, and other safety information in good condition and posted in the proper locations?

WORKSITE

  • 33 CFR 143.15 Do the obstruction lights on the facility work?

  • 33 CFR 143.15 Does the fog horn on the facility work?

  • 46 CFR 112.43 Is the emergency lighting system operational?

GAS DETECTORS

  • 30 CFR 250.803 (b)(9)(i) Are gas sensors installed in all inadequately ventilated, enclosed classified areas?

  • 30 CFR 250.803 (b)(9)(ii) Is each gas-detection system capable of continuous monitoring?

  • 30 CFR 250.803 (b)(9)(ii) Are gas detection systems related to the higher gas concentration levels of the manual reset type?

  • 30 CFR 250.803 (b)(9)(iii) Is a fuel-gas odorant or an automatic gas-detection system installed in enclosed, continuously manned areas of the facility which are provided with fuel gas?

  • Is each combustible gas-detection control unit installed outside of the monitored area?

  • 30 CFR 250.803 (b)(9)(v) Does each compressor building have at least two sensors installed?

  • 30 CFR 250.803 (b)(9)(v) Does a gas detection system capable of monitoring more than one area identify the source of the warning signal?

  • 30 CFR 250.804 (a)(8) Is each combustible gas detection system recalibrated at least once every 3 months and documented?

  • Do gas detectors initiate an audible alarm when 20% LSL gas is detected and initiate isolation/shut-in action when 60 LEL gas is detected?

GENERAL ALARM

  • 33 CFR 146.105 Is a general alarm system installed on each manned facility and is it audible in all parts of the structure?

  • 33 CFR 146.135 (b) Are the general alarm switches identified by red letters (GENERAL ALARM) at least one inch high with a contrasting background?

  • 33 CFR 146.135 (c) Are all general alarm bells identified by a sign at each bell in red letters at least one inch high with a sharp contrasting background: General Alarm - - When Bell Rings, Go To Your Station?

  • 46 CFR 109.201 (a)(1)(2)(b) Is the steering gear, whistle, general alarm bells and means of communication between the bridge or control room and the engine room on self propelled units inspected and tested?

PLATFORM PFD

  • 33 CFR 144.10-1 (a)(1)(2)(3)(b) Are all personnel on an unmanned platform equipped with a Type I PFD, and an approved ring life buoy for every two persons? (The ring life buoys may be kept on a manned vessel that remains alongside the platform if no space available)

  • 33 CFR 144.01-20 (a)(b)(c)(d) Is an approved life preserver provided for each person on a manned platform and is it in an easily accessible place?

WORKVESTS

  • 33 CFR 146.20 46 CFR 160.077-29, 160.053 Does each work vest (Type V) have a marking tag giving the U.S.C.G. approval, name of buoyant material, name of manufacturer, lot number, etc.?

  • 33 CFR 146.20 Are the words "WORK VEST ONLY" stenciled in waterproof ink on a front compartment of each work vest, in lettering not less than one inch in height?

  • 33 CFR 146.20 (c) Are work vests (Type V) stowed separately from the regular stowage of approved life preservers (Type I), and stowed in a location that they will not easily be confused with approved life preservers?

LIFE RINGS

  • 33 CFR 144.01-25 Is an approved ring life buoy (Type IV PFD) for every two persons available (No more than four required)? The ring life buoys may be kept on a manned vessel that remains alongside the platform if no space is available on the platform.

  • 33 CFR 144.01-25 Are ring lifebuoys in good and serviceable condition?

  • 33 CFR 144.01-25 Is each ring life buoy supplied with and approved automatic water light?

  • 33 CFR 144.01-25 Are there at least four approved ring life buoys with one life buoy placed on a suitable rack on each side of the platform?

  • 33 CFR 144.01-25 Is each ring life buoy capable of being cast loose and not permanently attached in any way?

  • 33 CFR 144.01-25 Is each ring life buoy in good and serviceable condition?

  • 33 CFR 144.01-25 Is each ring buoy marked with the owners name and location?

  • 33 CFR 144.01-25 Is each water light attached to the ring life buoy by a 12 thread manila or equivalent lanyard of not less than 3 feet nor more than 6 feet in length?

  • 33 CFR 144.01-25 Is each water light mounted on a bracket near the ring life buoy so that when the life buoy is cast loose, the water light will pull free of the bracket?

FIRST AID

  • 33 CFR 144.01-30 Is there a first aid kit approved by the Commandant on the platform? The approved kit is the 24-unit approved by the U.S.C.G. for lifeboats. Is this first aid kit in the custody of the person-in-charge?

  • 33 CFR 144.01-30 Is there a stokes litter or other suitable safety litter accessible and available that is capable of being safely hoisted with an injured person?

  • Who is CPR certified and is there a paramedic on site?

LIFEBOATS

  • 33 CFR 144.01-1 46 CFR Is a person assigned to each life float, lifeboat, life raft, or survival capsule who shall be responsible for launching it in event of an emergency and is there sufficient lifefloat capacity to accommodate all persons at any one time?

  • 33 CFR 144.01-15 Approved lifeboats may be used in lieu of approved life floats for either all or part of the capacity required. When lifeboats are used, approved means of launching will be required.

  • 33 CFR 144.01-5 Are the lifefloats distributed in accessible locations and mounted on the outboard sides in such a manner as to be readily launched?

  • 33 CFR144.01-15 (a) Is each lifefloat provided with a painter of manila rope not less than 2 3/4" in circumference and a length not less than three tines the distance from the deck where stowed to the low water line?

  • 33 CFR144.01-15 (b) Does each lifefloat have an approved electric water light attached to the lifefloat by a 12-thread manila or equivalent lanyard not less than 6 feet or more than 12 feet in length?

  • 33 CFR144.01-15 (b) Is each water light mounted on a bracket so that when the lifefloat is launched, the water light will pull free of the bracket?

  • 33 CFR144.01-15 (c) Are two paddles provided for each lifefloat and is each paddle not less than five feet nor more than six feet long?

  • 33 CFR 144.01-10 (c) Are paddles stowed in such a manner that they will be readily accessible from either side of the lifefloat when in the water?

  • 33 CFR 144.01-15 (b) Are lifeboat(s) equipped with a bailer, boat hook, bucket, hatchet, 'lantern, life line, two life preservers, matches, full complement of oars, and steering oar, painter, plug, and rowlocks?

  • Was the lifeboat(s) serviced within the last year and weight tested at installation?

  • Was the lifeboat(s) put through an operational test within the past 90 days?

  • 46 CFR 107.239 Are lifeboat/capsule launching, elevating mechanism and limit switches operational and lifeboat/capsule fall cables in good condition?

  • 46 CFR 107.231 (b) Are lifeboat/capsule equipment and provisions in good condition? (Check expiration dates on all survival supplies)

  • Are lifeboat/capsule engine and fluid levels checked with fuel and filters changed every 12 months?

  • Are life floats or escape capsules on the structure (and accessible) to accommodate all personnel?

PLATFORM LANDINGS

  • 33 CFR 143.105 Are personnel landings of sufficient size to provide safe access and egress?

  • 33 CFR 143.101 Are personnel landings satisfactorily illuminated? The minimum shall be one foot candle of artificial illumination as measured at the landing floor, guards and rails.

  • Are swing ropes and personnel basket in good shape?

ESCAPE PROCEEDURES

  • Are the "means of escape" suitably accessible to personnel for rapid facility evacuation?

  • When two or more means of escape are provided, are they located as nearly diagonally opposite each other as practicable?

  • Are at least two "primary means of escape" (stairways or fixed ladders of metal construction) extending from the uppermost level that contains living quarters, shops, or offices to each successively lower working level, and to the water surface?

  • Are working levels without living quarters, shops, or offices in manned facility structural appendages, extensions, and installations that personnel occupy only occasionally are provided with at least one "primary means of escape"?

  • 33 CFR 143.101 (d) On unmanned platforms, is at least one "primary means of escape" extending from the uppermost working level to each successively lower working level and to the water surface provided?

  • 33 CFR 143.101 (c) If personnel are aboard, is the platform provided with a "secondary means of escape extending from the uppermost platform working level to each successively lower working level and to the water surface?

  • 33 CFR 143.101 (c) Is a secondary means of escape provided for each 10 people on board the platform and are all emergency exits marked?

MOC

  • Are unsafe working conditions reported to Management and in turn, does Management correct these unsafe conditions?

SAFETY MEETINGS

  • Are daily safety meetings held prior to work and are operations personnel included?

  • Did the Company Rep establish with all the hands that any safety violation will result in ONE warning then termination?

  • Does the Company Rep in charge review the Safe Practices Manual frequently and discuss at safety meetings?

  • Has a copy of the Chevron Safe Practice Manual been distributed to the Contractor?

  • Have we emphasized for everyone to watch out for each other?

  • 30 CFR 250.506 Have crew members been instructed in safety requirements of the operations to be performed, possible hazards and general safety considerations to protect personnel, equipment and the environment prior to engaging in well completion operations?

  • 30 CFR 250.506 30 CFR 250.606 Has the date and time of safety meetings been recorded at the facility and is the information available for review by MMS representatives.

HAZARDOUS COMMUNICATIONS

  • 29 CFR 1910.1200 Are all chemicals on the platform listed on the Chemical Inventory Sheet (available for inspection) and do they have a current MSDS and are all employees familiar with them?

  • 29 CFR 1910.1200 Are MSDS's received with each chemical shipment?

CRANE

  • 30 CFR 250.401 (g) Are records of crane inspection, testing, maintenance, and operator qualifications maintained at the lessee's nearest field office for a period of two years and are they current?

  • 46 CFR 109 & 107 Are crane certificates, crane record books, crane inspections, and crane operator qualification letters available for inspection?

  • GOMPBU Crane Program Are hand signals, load charts and boom angle posted?

  • GOMPBU Crane Program Are all crane safety devices operable?

  • GOMPBU Crane Program Are the weight of load / crane limits known?

  • GOMPBU Crane Program Are proper crane signaling techniques practiced?

  • GOMPBU Crane Program Is crane lighting adequate?

  • GOMPBU Crane Program Does the crane winch have good cable?

  • GOMPBU Crane Program Are the crane handrails and guards in place?

  • GOMPBU Crane Program Are the crane fire extinguishers in place?

  • GOMPBU Crane Program Does the crane hook safety latch work?

  • GOMPBU Crane Program Does the crane horn / radio work?

  • GOMPBU Crane Program Are tag lines used for lifts?

  • API RP 2D Are cranes installed on fixed facilities operated and maintained in accordance with the provisions of API RP 2D?

RIGGING

  • Are wire ropes, slings, cables, hooks, and safety latches inspected and in good condition?

  • Are the crane and slings visually inspected prior to the start of lifting operations and are slings tagged indicating their rated lifting capacity?

  • Do personnel stand clear of crane loads?

WELLHEADS

  • Are wells or other production equipment protected from falling hazards?

  • Has a determination to the effect of the load and crane boom on equipment, piping, and vessels been made and appropriate action taken, i.e. shut in and bled down, or adequate protection provided?

  • Is a safety meeting held and a lifting plan developed prior to commencement of operations and is hot work stopped during major lifts?

EMERGENCY DRILLS

  • 33 CFR 146.125 (d) Are monthly emergency drills conducted by each shift of personnel on this facility?

  • 33 CFR 146.125 (b) Does the person-in-charge instruct all personnel and visitors about their duties and stations in the event of an emergency?

  • 33 CFR 146.125 (d) Is written documentation of all emergency drills conducted during the past 12 months on this facility kept and on file for review?

  • 33 CFR 146.125 (d) Is a copy of written reports to the U.S.C.G. for any calendar month in which an emergency drill was not conducted during the past 12 months kept on file for review?

  • 33 CFR 146.140 (d)(4) Has a list of emergency contact numbers been developed and documented in the Emergency Evacuation Plan?

EMERGENCY COMMUNICATIONS

  • 33 CFR 144.01-40 Is a means provided for communication by radio for contacting the shore or vessels in the vicinity for aid in the event of an emergency?

  • 33 CFR 143.100 (e) Is a standby vessel available as required by the approved EEP 24 hours a day?

  • REQUIRED SIGNAGE

  • 30 CFR 250.115 (a) Is each location that is equipped with helicopter decks identified with at lease one sign of letters and figures not less than 12 inches and do units without helicopter decks have signs with letters and figures not less than 3 inches in height?

  • 30 CFR 250.115 (a) Do the signs mentioned above contain the following information: name of lease operator, OCS location, block number, facility or rig name and are signs visible to approaching traffic?

  • 30 CFR 250.115 (b) Is each singly completed well painted on the wellhead or a sign affixed to the wellhead showing the lease and well number and is the sign maintained in a legible manner?

  • 30 CFR 250.300 (c)(4) Are all markings on skid mounted equipment, portable containers, spools or reels, and drums durable enough to resist the effects of the environmental conditions to which they may be exposed?

  • 30 CFR 250.300 (d) Are all materials, equipment, tools, containers, and other items that are lost overboard recorded on the facility's daily operations report?

PRODUCTION REPORTING

  • 30 CFR 250.510 (e)(2)(i)(ii) Are allocation meters measuring 50 barrels of oil per day or more proven monthly and allocation meters measuring less than 50 barrels of oil per day proven quarterly?

  • 30 CFR 250.1202 (e)(5)(iii) Is the sampler probe on the lact skid located in the center of the flow piping in a vertical run and no less than 3 pipe diameters from an area of turbulent flow?

  • 30 CFR 250.180 (d)(i) Are sales meter provings (for liquid hydrocarbons) conducted monthly not to exceed 6 weeks unless approved by the Regional Supervisor?

  • 30 CFR 250.1203 (g)(3)(iii) Are all gas meters calibrated at reasonable intervals not to exceed 45 days and calibrations retained on location for a period of 2 years?

  • 30 CFR 250.1205 (a) Are wire seals in the proper location and secure, including those on circulating valves (seal will break if valve opened) and are records maintained reflecting seal changes?

  • 30 CFR 250.1205 (a) Are components of temperature devices sealed to preclude tampering?

PIPELINES

  • 30 CFR 250.1004 (b)(1)(2) Are incoming pipelines to a platform equipped with an FSV and are incoming pipelines delivering to a production platform equipped with a SDV immediately upon boarding the platform and is it connected to the automatic and remote emergency shutdown systems?

  • 30 CFR 250.1004 (b)(4) Is each crossing pipeline on production or manned nonproduction platforms which do not receive production from the platform equipped with a SDV immediately upon boarding the platform?

  • 30 CFR 250.1004 (b)(4) Is the SDV on each crossing pipeline operated by a PSHL on the departing pipeline and connected to the platform automatic and remote emergency shut-in systems and is the PSHL set 15% above and below the normal operating pressure range?

  • 30 CFR 250.1004 (b)(3) Are departing pipelines receiving production from production facilities protected by a PSHL to directly or indirectly shut in all production facilities and are the high pilots not set above the pipeline's MAOP?

  • 30 CFR 250.1004 (8) Is each bidirectional pipeline equipped with a PSHL and an SDV immediately upon boarding each platform?

  • 30 CFR 250.1002 (d) If the maximum source pressure exceeds the pipelines MAOP, redundant safety devices per requirement of API RP14C shall be installed and maintained but the primary and redundant safety equipment actuation shall not exceed the MAOP.

  • 30 CFR 250.1003 (a)(4) Are pipeline risers installed after April 1, 1988 protected from physical damage that could result from contact with floating vessels?

  • 30 CFR 250.1006 (a)(1) Are pipelines abandoned in place flushed, filled with seawater, cut and plugged with the ends buried at least 3 feet?

  • 30 CFR 250.1006 (b)(1)(2) Are pipelines taken out of service blind flanged or isolated with a closed block valve at each end and are pipelines taken out of service for a period of more than 1 year flushed and filled with inhibited seawater?

  • 30 CFR 250.1006 (3) Are pipelines taken out of service for returned to service within 5 years or abandoned in accordance with the requirement of 250.156(a) (1) or (2)?

WELDING ON PLATFORM

  • 30 CFR 250.402 (4) Has equipment containing hydrocarbons or other flammable substances been relocated at least 35 feet horizontally from the work site?

  • 30 CFR 250.402 (4) Is similar equipment located at a lower elevation where slag, sparks, or other burning materials could fall relocated at lease 35 feet from the point of impact?

  • 30 CFR 250.402 (4) If relocation is impractical, is the equipment protected with flame-proofed covers or otherwise shielded with metal or fire-resistant guards or curtains or the contents shall be rendered inert?

  • 30 CFR 250.402 (c) 250.507, 250.607 Have established and designated areas determined to be safe welding areas and if so, have these areas been identified in the "Welding, Burning and Hot Tapping Safe Practices and Procedure Plan" and is a drawing showing the location on the facility?

  • 30 CFR 250.402 (d)(1) 250.507, 250.607 Is all welding and burning equipment inspected by the welding supervisor or the lessee's designated person in charge prior to beginning any welding, burning, or hot tapping?

  • 30 CFR 250.402 (d)(2) Prior to the commencement of any welding or burning operation in areas other than approve safe welding or burning areas, has the lessee's designated person in charge inspected qualifications of the welder?

  • 30 CFR 250.402 (2) Does the fire watch maintain a continuous surveillance with a portable gas detector during the welding and burning operation and have no other duties other than fire watch?

PRODUCTION SAFETY PROCESSES

  • 30 CFR 250.803 (b)(3) Do all safety shutdown devices, valves, and pressure sensors function in a manual reset mode?

  • 30 CFR 250.803 (c)(l), 250.1004 (c) Is each surface or subsurface safety device, which is bypassed or blocked out of service, out of service due only to start up, testing, or maintenance?

  • 30 CFR 250.801 (b)(4), 250.803 (c)(l) Is each surface or subsurface safety device, which is temporarily out of service, flagged and monitored by trained personnel?

  • 30 CFR 250.803 (c)(4) Is each open-ended line connected to producing facilities and wells plugged or blind flanged?

  • 30 CFR 250.1503 Is each person engaged in installing, inspecting, testing, and maintaining safety devices currently certified in PSST and records of this training kept in the field area?

PRESSURE RECORDINGS

  • 30 CFR 250.803 (b)(1)(iii), 250.803(b)(2)(i) Are the pressure recorder charts used to determine the current operating pressure ranges maintained at the nearest field office?

  • 30 CFR 250.803 (b)(1)(iii), 250.803(b)(2)(i) Are all pressure safety device ranges documented by pressure recorder charts and are pressure recorder charts dated and test periods identified?

ESD

  • 30 CFR 250.803 (b)(4) Is an operable ESD station located at each helicopter deck?

  • 30 CFR 250.803 (b)(4) Is an operable ESD station located at each exit stairway landing at each deck level?

  • 30 CFR 250.803 (b)(4) Is an operable ESD station located at each boat landing?

  • 30 CFR 250.803 (b)(4) Is an operable ESD station located at the center or each end of a bridge connecting two platforms?

  • 30 CFR 250.803 (b)(4) Is an operable ESD station located at each emergency evacuation station?

  • 30 CFR 250.803 (b)(4) 603,503,401(i) Is an operable ESD station located near the driller's console during drilling, workover, and completion operations?

  • 30 CFR 250.803 (b)(4) Is an operable ESD station located near the main exits of living quarters?

  • 30 CFR 250.803 (b)(4)(iii) Is a schematic of the ESD system maintained on the facility or at the nearest field office?

  • 30 CFR 250.803 (b)(4)(i) Is the ESD system equipped with manually operated, quick opening and nonrestricted valves?

  • 30 CFR 250.803 (b)(4)(ii) Does the SSV close within 45 seconds after automatic detection of an abnormal condition or actuation of an ESD?

  • 30 CFR 250.803 (b)(4)(ii), 250.801(i) Does the SCSSV close within 2 minutes after the ESD shut in signal has closed the SSV?

  • 30 CFR 250.804 (a)(10) Is each ESD system tested for operation at least once each month, but at no time shall more than 6 weeks elapse between tests and repaired or replaced if found defective?

  • Are ESD stations clearly marked and ESD signs in good condition?

  • 30 CFR 250.804 (a)(10) Is each ESD system test conducted by alternating ESD stations monthly to close at least one wellhead SSV and verify surface controlled SSSV closure for that well as indicated by control circuitry actuation?

PLATFORM SCHEMATICS

  • 30 CFR 250.803 (e)(l) Is a schematic flow diagram showing tubing pressure, size, capacity, and design working pressure of all hydrocarbon handling vessels available for inspection?

  • 30 CFR 250.802 (e)(2) Is the SAFE Chart for this structure up to date showing all revisions to the platform available for inspection?

  • 30 CFR 250.802 (e)(4) Are electrical area classification drawings available for each deck of the structure showing hazardous areas classified in accordance with API RP 500B?.

  • Is an elementary electrical schematic of any platform safety shut down system with a functional legend available for inspection? These drawings should include the type, location, and number of

  • detection systems, type and kind of alarms including emergency equipment to be activated, method used for detection, method and frequency of calibration, and a functional block diagram of the detection system, including the electric power supply.

  • Is permission secured from the MMS District Supervisor before changes are made to the platform and the appropriate changes made to the SAFE Charts and submitted to the MMS for approval before any work begins?

PLATFORM TUBING

  • 30 CFR 250.801 (c) Are all tubing installations open to a hydrocarbon-bearing zone which is capable of natural flow equipped with a surface-controlled SSSV?

  • 30 CFR 250.801 (f) Are new completions (perforated but not placed on production) and completions shut-in for more than 6 months equipped with either a pump through type tubing plug, a surface controlled SSSV with the surface control rendered inoperative,

  • or an injection valve capable of preventing backflow?

  • 30 CFR 250.801 (g) Is a surface controlled SSSV or an injection valve capable of preventing backflow installed in each injection well?

  • 30 CFR 250.801 (e)(1) Is a subsurface safety device installed at a depth of 100 feet or more below the seafloor?

  • 30 CFR 250.801 (e)(3) If the SSSV is removed and the zone is open to flow, is flowing necessary for the operation being conducted?

  • 30 CFR 250.801 (e)(2), 801(h)(2), 801(h)(3) Is a person who has current API RP T2 certification in the immediate vicinity of the well if the master valve is open and the subsurface safety device is not installed?

  • 30 CFR 250.801 (i) Are all tubing installations in which a wireline or pumpdown retrievable subsurface safety device is installed equipped with a landing nipple with flow couplings or other protective equipment above and below to provide for the setting of the SSSV?

SUBSURFACE CONTROLS

  • 30 CFR 250.801 (b) Is a list of all certified and uncertified SSV's(both actuator and valve), USV's ( both actuator and valve), and SSSV's(including safety valve locks and landing nipples) kept in the inventory of field equipment and updated?

  • Does the above mentioned list indicate which items of the safety and pollution prevention equipment were manufactured under ANSI or ASME standards?

  • Does this list identify each listed item by manufacturer, serial number, model, the date the item entered the inventory, and whether the item is in service on the OCS or in stock for installation on the OCS?

  • 30 CFR 250.801 (h)(1) When the Subsurface Safety Device has been removed for more than 15 days or more, has MMS approval been given?

  • 30 CFR 250.801 (h)(2) When the subsurface safety device has been removed, is there a sign on the wellhead stating that the subsurface safety device has been removed?

  • 30 CFR 250.801 (h)(3) When the subsurface safety device has been removed for routine operations on a satellite structure, is the well attended?

  • 30 CFR 250.804 (a)(1)(i) Is each SCSSV installed in a well tested when installed or reinstalled and at intervals not exceeding 6 months and removed, repaired, and reinstalled, or replaced, if it does not operate properly?

  • 30 CFR 250.804 (a)(1)(ii) Is each SSCSV installed in a well removed, inspected, and repaired or adjusted, and reinstalled or replaced as necessary at intervals not exceeding 6 months for those valves not installed in a landing nipple?

  • 30 CFR 250.804 (a)(1)(ii) Is each SSCSV installed in a well removed, inspected, and repaired or adjusted, and reinstalled or replaced as necessary at intervals not exceeding 12 months for those installed in a landing nipple?

  • 30 CFR 250.804 (a)(1) (iii) Is each tubing plug installed in a well inspected for leakage at intervals not exceeding 6 months and removed, repaired and reinstalled, or replaced, if it leaks?

  • 30 CFR 250.804 (a)(1) (iv) Is each injection valve installed in a well inspected for leakage at intervals not exceeding 6 months and removed, repaired and reinstalled, or replaced, if it leaks?

PRODUCTION SAFETY EQUIPMENT (TSE)

  • 30 CFR 250.802 (b) Are ESD Stations marked?

  • 30 CFR 250.802 (b) Does each wellhead have a minimum of one TSE located above the wellhead?

  • 30 CFR 250.802 (b) Are there at least 2 (two) fusible plugs on each header?

  • 30 CFR 250.802 (b) Is there at least one fusible plug for each 10 (ten) feet of header?

  • 30 CFR 250.802 (b) Is there at least one fusible plug for each vertical vessel?

  • 30 CFR 250.802 (b) Is there at least one fusible plug for each 12 (twelve) inches of OD to a maximum of five plugs on vertical vessels?

  • 30 CFR 250.802 (b) On horizontal vessels less than 48 (forty eight) inches OD, are there at least two fusible plugs with at least one plug for each 5 (five) feet of length?

  • 30 CFR 250.802 (b) On horizontal vessels greater than 48 (forty eight) inches in diameter are there at least 4 (four) fusible plugs with at least two fusible plugs for each 5 (five) feet of length in two parallel rows?

  • 30 CFR 250.802 (b) Is there one fusible plug above each process inlet, process outlet, and each hatch?

  • 30 CFR 250.802 (b) Is there one fusible plug outside of each flame arrestor on fired components?

  • 30 CFR 250.802 (b) Is a TSE located over each end of each heat exchanger?

  • 30 CFR 250.802 (b) Is a TSE located above each rod packing on reciprocating pumps?

  • 30 CFR 250.802 (b) Is a TSE located over each packing box on centrifugal pumps?

  • 30 CFR 250.802 (b) Is a fusible plug located over each rod cylinder on reciprocating pumps?

  • 30 CFR 250.802 (b) Is a fusible plug located over the compressor case of each centrifugal pump?

  • 30 CFR 250.802 (b) Is at least one TSE located over each carburetor and each fuel injector on engines with spark ignition?

  • 30 CFR 250.802 (b) For diesel engines permanently installed (rental or company owned), is one fusible plug over each fuel injector pump?

  • 30 CFR 250.802 (b) For combustion turbines (rental or company owned and permanently installed), is there one fusible plug over each solenoid valve, governor valve, and PTO pump?

PRODUCTION SAFETY EQUIPMENT (LOOPS)

  • 30 CFR 250.804 (a)(3) Is each PSH tested for operation at least once each month, with no more than 6 weeks elapsing between tests, and repaired or replaced if found defective?

  • 30 CFR 250.804 (a)(3) Is each PSL tested for operation at least once each month, with no more than 6 weeks elapsing between tests, and repaired or replaced if found defective?

  • 30 CFR 250.804 (a)(3) Is each LSH tested for operation at least once each month, with no more than 6 weeks elapsing between tests, and repaired or replaced if found defective?

  • 30 CFR 250.804 (a)(3) Is each LSL tested for operation at least once each month, with no more than 6 weeks elapsing between tests, and repaired or replaced if found defective?

  • 30 CFR 250.804 (a)(3) Is each automatic inlet SDV and each liquid discharge SDV tested for operation at least once each month, with no more than 6 weeks elapsing between tests, and repaired or replaced if found defective?

  • 30 CFR 250.804 (a)(4) Is each SSV/USV tested for operation at least once each month, with no more than 6 weeks elapsing between tests, and repaired or replaced if found defective?

  • 30 CFR 250.804 (a)(5) Is each flowline FSV tested for operation at least once each month, with no more than 6 weeks elapsing between tests, and repaired or replaced if found defective?

  • 30 CFR 250.804 (a)(6) Is each TSH on compressor installations tested for operation at least once every 6 months and repaired or replaced if found defective?

  • 30 CFR 250.804 (a)(9) Is each TSH on noncompressor installations tested for operation at least once every 12 months and repaired or replaced if found defective?

  • 30 CFR 250.804 (a)(9) Is each BSL tested for operation at least once every 12 months and repaired or replaced if found defective?

  • 30 CFR 250.804 (a)(9) Is each FSL tested for operation at least once every 12 months and repaired or replaced if found defective?

  • 30 CFR 250.804 (a)(2) Is each PSV tested for operation at least once every 12 months and repaired or replaced if found defective?

PLATFORM OTHER

  • 30 CFR 250.804 (b) Are records maintained for a period of two (2) years at the nearest field office for each subsurface and surface safety device installed?

  • 30 CFR 144 Are records maintained for the life of the platform of the results of platform structural inspections?

  • 30 CFR 250.802 (b) Is each nonpipeline pump equipped with a PSHL?

  • 30 CFR 250.802 (b) Is each nonpipeline pump equipped with a FSV?

  • 30 CFR 250.802 (b) Is each glycol powered glycol pump equipped with a SDV?

  • 30 CFR 250.802 (b) Is each wellhead injection line and gas lift line equipped with a PSHL?

  • 30 CFR 250.802 (b) Is each wellhead injection line and gas lift line equipped with a FSV?

  • 30 CFR 250.803 (b)(2)(i) Does the PSH on each flowline segment activate no higher than 15 percent or 5 PSI, whichever is greater, above the highest pressure in the operating range and below the SITP or the gas lift supply pressure? Note: API test tolerance does not apply.

  • 30 CFR 250.803 (b)(2)(i) Does the PSL on each flowline segment activate no lower than 15 percent or 5 PSI. whichever is greater, below the lowest pressure in the operating range? Note: API test tolerance does not apply.

  • 30 CFR 250.803 (b)(2)(ii) If the maximum allowable WP of the flowline is less than the SITP, is a PSV, or additional SSV activated by an independent PSH, installed?

  • 30 CFR 250.802 (b) Is an operable FSV installed in the final flowline segment?

  • 30 CFR 250.517 (d) 617(d) Does the wellhead, tree, and related equipment have a pressure rating greater than the SITP?

  • 30 CFR 250.517 (c) 617(c) Has the wellhead been equipped so that all annuli can be monitored for sustained pressure?

  • 30 CFR 250.517 (c) 617(c) If sustained casing pressure is observed, has the MMS District Supervisor been notified?

  • 30 CFR 250.517 (d), 517(e), 617(d) Is each wellhead completion equipped with a minimum of one master valve and an operable SSV or USV located above the master valve in the vertical run of the tree?

  • 30 CFR 250.112 (b) Is each pressure vessel equipped with an operable LSH, LSL (oil), LSL (water)?

  • 30 CFR 250.112 (b) Is each pressure vessel equipped with a FSV(oil), (water), (gas)?

  • 30 CFR 250.803 (b)(1)(iii) Are pressured and fired vessels code stamped in accordance with the ASME boiler and pressure vessel code?

  • 30 CFR 250.803 (b)(1)(iii) Does each pressure vessel stamp have in each stamp the ASME Boiler and Pressure Vessel Code symbol, the manufacturer's name, the maximum working pressure at a specified temperature, the manufacturer's serial number, and the year built?

  • If a vessel is unstamped, has specific approval to use this vessel been secured from the District Supervisor of the MMS?

  • Does the PSH on each pressure vessel activate no higher than

  • 30 CFR 250.803 (b)(1)(iii) 15 percent or 5 psi, whichever is greater, above the highest pressure in the operating range and at least 5 percent or 5 PSI, whichever is greater, below the PSV's activation pressure? Note: API test tolerance does not apply.

  • 30 CFR 250.803 (b)(1)(iii) Does the PSL on each pressure vessel activate no lower than 5 percent or 5 PSI, whichever is greater, below the lowest pressure in the operating range? Note: API test tolerance does not apply.

  • CFR 30 250.803 (b)(1)(i) Does each PSV activate no higher than the maximum allowable working pressure?

  • CFR 30 250.803 (b)(1)(i) 123(b)(6) Is each PSV and vent piped in such a way as to prevent fluid from striking personnel or ignition sources?

  • 30 CFR 250.802 (b) Is each atmospheric vessel equipped with an operable LSH?

  • 30 CFR 250.802 (b) Is each atmospheric vessel equipped with an operable LSL (water), (oil)?

  • 30 CFR 250.802 (b) Is each atmospheric vessel equipped with an operable PSV and a vent or two independent vents?

  • 30 CFR 250.802 (b) Is each atmospheric vessel equipped with an operable flame arrestor on vents?

  • 30 CFR 250.802 (b) Is each atmospheric vessel equipped with an operable flame arrestor on vents?

  • 30 CFR 250.802 (b) Is each fired component fuel supply equipped with an operable PSH?

  • 30 CFR 250.802 (b) Is each fired component fuel supply equipped with an operable SDV?

  • 30 CFR 250.802 (b) Is each fired component fuel supply equipped with an operable TSL or BSL in the fire chamber?

  • 30 CFR 250.802 (b) Is each fired or exhaust heated component equipped with an operable TSH in the stack and in the medium or process fluid?

  • 30 CFR 250.802 (b) Is each fired or exhaust heated component equipped with an operable LSL in the medium or process fluid?

  • 30 CFR 250.802 (b) Is each natural draft fired component equipped with an operable intake flame arrestor?

  • 30 CFR 250.802 (b) Is each natural draft fired component equipped with an operable stack arrestor?

  • 30 CFR 250.802 (b) Is each forced draft fired component equipped with an operable PSL in air intake?

  • 30 CFR 250.802 (b) Is each forced draft fired component equipped with an operable PSL in fuel supply line?

  • 30 CFR 250.802 (b) Is each forced draft component equipped with an operable motor starter interlock?

  • 30 CFR 250.802 (b) Is each direct fired tube type component equipped with an operable FSL in the medium or process fluid when it is combustible?

  • 30 CFR 250.802(b) Is each direct fired tube type component equipped with a FSV in each medium outlet piping?

  • 30 CFR 250.802 (b) Is each direct fired tube type component equipped with an operable PSV in each medium outlet piping?

  • Is the PSV in the medium outlet piping installed so that it cannot be isolated?

  • Is the PSV in the medium outlet piping set to activate no higher than the maximum allowable working pressure?

GENERATOR SAFETY

  • 30 CFR 250.802 (b) Is each steam generator equipped with an operable PSH or TSH? Note: A TSH is not required on a steam generator protected by a PSH sensor to detect high pressure caused by high temperature.

  • 30 CFR 250.802 (b)(1)(ii) Is each steam generator equipped with an operable LSL?

  • 30 CFR 250.802 (b)(1)(ii) Is each steam generator equipped with an operable water feeding device which will automatically control the water level if operating at more than 15 PSIG?

HEAT EXCHANGERS

  • 30 CFR 250.802 (b) Is each heat exchanger (shell-tube) equipped with two PSH's?

  • 30 CFR 250.802 (b) Is each heat exchanger (shell-tube) equipped with two PSL's?

COMPRESSORS

  • 30 CFR 250.803 (b)(7)(i) Is each compressor suction and interstage scrubber equipped with an operable LSH?

  • 30 CFR 250.803 (b)(7)(i) Is each compressor suction and interstage scrubber equipped with an operable LSL?

  • 30 CFR 250.802 Is each final stage discharge equipped with a FSV outside of building?

  • 30 CFR 250.803 (b)(7)(iv) Is each final stage discharge equipped with a BDV if over 1,000 HP?

  • 30 CFR 250.803 (b)(7)(ii) Is each compressor discharge cylinder protected by an operable TSH?

  • 30 CFR 250.803 (b)(7)(iii) Do the automatic SDV's installed in compressor suction and fuel gas piping actuated by the PSH, PSL, and LSH installed on the compressor suction and interstage scrubbers allow each compressor unit and associated vessels to be isolated from input sources?

  • 30 CFR 250.803 (b)(7)(iii) Is each automatic SDV installed in compressor suction and fuel gas piping also actuated by the shutdown of the prime mover?

  • 30 CFR 250.803 (b)(7)(iii) Is gas well gas, affected by the closure of the automatic SDV on compressor suction, either diverted to the pipeline or shut in at the wellhead?

  • 30 CFR 250.803 (b)(7)(iii) Does the PSH on each compressor suction, interstage scrubber, and final stage discharge activate no higher than 15 percent or 5 psi, whichever is greater, above the highest pressure in the operating range and at least 5 percent or 5 psi, whichever is grea

  • 30 CFR 250.803 (b)(7)(iii) Does the PSL on each compressor suction, interstage scrubber, and final stage discharge activate no lower than 15 percent or 5 psi, whichever is greater, below the lowest pressure in the operating range?

PIPELINE PUMPS

  • 30 CFR 250.1004 (b)(9) Is each pipeline pump equipped with an operable PSV, located on the pump discharge piping upstream of any block valve and installed to sense pressure throughout the pump discharge piping?

  • 30 CFR 250.1004 (b)(9) Is each pipeline pump equipped with an operable SDV, located in the pump suction line as near the storage component or surge as possible?

  • 30 CFR 250.1004 (b)(9) Is each pipeline pump equipped with an FSV?

  • 30 CFR 250.1004 (b)(9) Does the PSH on each pipeline pump activate no higher than 15 percent above the highest pressure in the operating range and below the MAOP of the pipeline?

  • 30 CFR 250.1004 (b)(9) Does the PSL on each pipeline pump activate no lower than 15 percent below the lowest pressure in the operating range?

WIRELINE OPERATIONS

  • Are wirleline operations conducted so as to minimize leakage of well fluids? Any leakage that does occur shall be contained to prevent pollution.

  • Are all wireline perforating operations and all other wireline operations where communication exists between the completed hydrocarbon bearing zone(s) and the wellbore using a lubricator assembly containing at least one wireline valve?

  • When the lubricator is initially installed on the well, has it been successfully pressure tested to the expected shut-in surface pressure?

  • When the lubricator is initially installed on the well, has it been successfully pressure tested to the expected shut-in surface pressure?

  • Has 24 hour supervisory coverage been provided for all simultaneous operations and has a person-in-charge (PIC) been assigned to the location and is a record of all personnel on board maintained?

  • Has a simultaneous operations audit of the operations been performed prior to commencement and is a copy of the Simultaneous operations plan located on location?

  • Have all personnel on the platform reported to the PIC and been instructed in: Sim-Op procedures such as emergency procedures, use location of alarms and fire fighting equipment and use and location of emergency shutdown systems?

PLATFORM WELDING SAFETY

  • Are pressures checked prior to breaking flanges/disconnecting hoses/cutting into pipelines, etc. and are wind screen erected around grinding and/or cutting areas?

  • Have all disposal cigarette lighters been collected at arrival at the job site (to be returned when leaving - matches to be provided)?

  • Are skillets and/or plugs in place and all piping to be modified flushed of hydrocarbons or otherwise rendered inert?

  • Are all drains equipped with vapor traps and/or check valves to prevent migration of gases and are all open ended lines plugged or blind flanged unless designed to be open?

  • Is each open-ended line connected to producing facilities and wells plugged or blind flanged?

  • Are all air line and fuel gas line connections free of leaks and are all vents piped to a safe area or flare boom?

  • Are all wells which produce greater than 0.1% sand evaluated to determine if they should be shut-in or production rate reduced to produce sand below this limit and are all flowlines equipped with a sand probe to alarm when cut?

  • Are vessels and equipment within 10 feet of hot work shut in and bled down and are all wells shut in when performing hot work in well bays?

  • Has status of high pressure well (1000 psig service) been reviewed?

  • Has status of wells which produce greater than 10 ppm of H2S been reviewed?

  • For welding and burning operations in areas other than approved safe welding and burning areas:

  • 30 CFR 250.402 (d) Has the designated person in charge verified that all piping, containers, tanks, or other vessels which have contained a flammable substance been rendered inert and determined to be safe for welding or burning?

  • 30 CFR 250.402 Has one or more persons, with no other duties during welding and burning operations, been designated as a fire watch?

  • 30 CFR 250.402 Does the fire watch maintain a continuous surveillance with a portable gas detector during the welding and burning operation if the operation is to be in an area which is not equipped with a gas detector?

  • 30 CFR 250.402 Does the fire watch have usable fire fighting equipment in its possession?

  • 30 CFR 250.402 Does the fire watch remain on duty for a period of 30 minutes after welding or burning operations have been completed?

  • 30 CFR 250.402 Does the well(s) in the area where drilling operations are in progress contain non combustible fluids and is the entry of formation hydrocarbons into the wellbore precluded during welding operations?

  • 30 CFR 250.402 Are all producing wells in the well-bay or production area shut-in at the surface safety valve if welding or burning operations are conducted in or within 10 feet of a well-bay or production area?

  • 30 CFR 250.402, 250.507, 250.607 Are all water-discharge-point sources from hydrocarbon-handling vessels monitored in order to stop welding and burning operations in case flammable fluids are discharged as a result of equipment upset or malfunction?

  • 30 CFR 250.402, 250.507, 250.607 Are all water-discharge-point sources from hydrocarbon-handling vessels monitored in order to stop welding and burning operations in case flammable fluids are discharged as a result of equipment upset or malfunction?

  • 30CFR 250.402 (b) Are oxygen and acetylene bottles secured in a safe area and equipped with proper fittings, gauges, regulators and hoses and supplied with caps when being shipped ?

  • Are welding machines located in unclassified locations and tied into the platform ESD system?

  • Are the shut down controls on welding machines, air compressors, etc. marked?

  • 33 CFR 250.403 (d) Are all engines with electrical ignition systems equipped with a Low-Tension Ignition System? (A shielded ignition system is not an alternative!)

  • 30 CFR 250.401 (b)(2) Are diesel engines which are continually attended provided with either a remote operated or automatic air intake shutdown device? (Continuously attended means a person standing by the engine at all times)

  • Do all engines contain spark arresting exhausts, suitable electric starters and alternators, and an automatic device that shuts down the engine on an ESD?

  • Is all welding and burning equipment inspected by the welding supervisor or a designated person in charge before beginning any welding, burning, or hot tapping?

  • 30 CFR 250.402 Are welding leads completely insulated and in good condition?

  • 30 CFR 250.402 Are welding leads completely insulated and in good condition?

  • Has proper protection of flammable materials been taken and are fire resistant tarpaulins available?

  • Are firewalls in place to protect production equipment from adjacent wells or flowlines from fire or sand impingement and is curbing installed to prevent migration of flammable liquids?

  • Are firewalls in place to protect production equipment from adjacent wells or flowlines from fire or sand impingement and is curbing installed to prevent migration of flammable liquids?

  • If welding is to be done outside the approved safe welding area, has any well with wireline or workover work being done been shut in by closing the SSSV or installing a tubing plug and the wellbore filled above the SSSV/Tubing plug with seawater?

  • Is hot work on the platform suspended during an ALERT status?

  • Is the ESD system tested for proper operation prior to commencing sim-op and then monthly afterwards?

  • Is the simultaneous operations log filled out daily?

  • Are the conditions of the daily hot work permit followed: a. The area adjacent to and under the hot work inspected for potential hazards? b. Combustible gas detector tests are conducted before and continuously during hot work? c. A firewatch

  • is present with no other duties? d. Sufficient portable fire extinguishers are located at the work site? e.. A fire water system is available with one hose discharging at the work site? f. The area is checked within 30 minutes after completion

  • of the work, to assure it is fire and danger free, and the daily Hot Work Permit signed at the bottom?

  • In welding areas 10-35 feet from equipment which is in service, have the following additional precautions been taken: a. Visual inspection and non-destructive testing (ultrasonic or x-ray) of vessels and piping within the area to determine their

  • condition? b. Soaping of flanges, valve bonnets, tubing fittings, or other connections for leek detection?. The use of wetted tarpaulins, metal, or fire resistant shields?

SHIPPING SAFETY

  • 49 CFR 171.2 Do Shipping Notices contain only non hazardous materials?

  • Do Straight Bill of Ladings contain proper shipping name and description of the material, name of the shipper, and emergency response telephone number? Are all entries printed in English and legible?

  • 49 CFR 172.400 29 CFR 1910.1200 30 CFR 250.300 Are containers for Hazardous Material on the location properly marked and labeled for transportation?

DRILLING SAFETY SYSTEMS

  • 30 CFR 250.121 Does the lessee make the facility available for inspection by MMS personnel?

  • Prior to rig moves the follow will be performed;

  • Notice to Lessees and Operators No. 83-3 A survey to determine location of all pipelines and other hazards, including anchor patterns.

  • The survey should cover 150 meters in the vicinity of the rig, from the point where the legs of the rig were first intended to be lowered, to the rig's final destination.

  • Notice to Lessees and Operators No. 83-3 A plat prepared from the survey depicting the location of the proposed activity. Provided to personnel on the rig.

  • Notice to Lessees and Operators No. 83-3 Are all existing pipelines and other potential hazards located within 150 meters of operation buoyed, including anchor patterns.

  • Notice to Lessees and Operators No. 83-3 Adequate tug horsepower to control the movement of the rig without utilizing the rig legs to contact bottom at a potentially dangerous location.

  • 30 CFR 250.400, 250.511, 250.611 Is the drilling unit equipped with a traveling block safety device by May 31, 1989?

  • 30 CFR 250.400, 250.511, 250.611 Are the results of the operational checks of the traveling block safety device entered in the driller's report?

  • 30 CFR 250.401 Are all wells in the same well-bay which are capable of producing hydrocarbons shut-in below the surface with a pump-through type tubing plug and at the surface with closed master valve prior to moving drilling rigs and related equipment?

  • 30 CFR 250.406, 250.515, 250.615 Does the accumulator system provide sufficient capacity to supply 1.5 times the volume of fluid necessary to close and hold closed all BOP equipment units with a minimum

  • pressure of 200 PSI above the precharge pressure without assistance from a charging system?

  • 30 CFR 250.406, 250.515, 250.615 Do accumulator regulators, supplied by rig air and without a secondary source of pneumatic supply, been equipped with manual overrides or alternately, other devices provided to ensure capability of hydraulic operations if rig air is lost?

  • 30 CFR 250.406, 250.515, 250.615 Is an automatic backup accumulator charging system, supplied by a power source independent from the power source to the primary accumulator-charging system, and possessing sufficient capability to close all BOP components and hold them closed, provided?

  • 30 CFR 250.406, 250.515, 250.615 Is at least one operable remote BOP control station in addition to the one on the drilling floor provided in a readily accessible location away from the drilling floor?

  • 30 CFR 250.406 Is a drilling spool with side outlets provided if side outlets are not provided in the body of the BOP stack to provide for separate kill and choke lines?

  • 30 CFR 250.406, 250.515, 250.615 Is there a choke and a kill line each equipped with two full opening valves?

  • 30 CFR 250.56, 250.85, 250.105 Is at least one of the valves on the choke line and on the kill line remotely-controlled?

  • 30 CFR 250.406, 250.514, 250.614 Is a fill-up line installed above the uppermost preventer?

  • 30 CFR 250.406, 250.515, 250.615 Does the choke manifold and choke equipment subject to well and/or pump pressure have a rated working pressure at least as great as the rated working pressure of the ram-type BOPS?

  • 30 CFR 250.406, 250.514, 250.615 Are all components of the choke manifold system protected from the danger, if any, of freezing by heating, draining, or filling with proper fluids?

  • 30 CFR 250.406, 250.514, 250.615 If buffer tanks are installed downstream of the choke assemblies for the purpose of manifolding the bleed lines together, are isolation valves installed on each line?

  • 30 CFR 250.406, 250.515, 250.615 Do valves, pipes, flexible steel hoses, and other fittings upstream of, and including the choke manifold have pressure ratings at least as great as the rated working pressure of the ram-type BOPS?

  • 30 CFR 250.406, 250.515, 250.615 Does the wellhead assembly have a rated working pressure that exceeds the anticipated surface pressure to which it may be subjected?

  • 30 CFR 250.406 Does the working-pressure rating of all BOP components exceed the anticipated surface pressure to which they may be subjected?

  • 30 CFR 250.406 On a top-drive system equipped with a remote-controlled valve, is a second and lower strippable valve installed?

  • 30 CFR 250.406, 250.515, 250.615 Are locking devices installed on the ram-type preventers.

  • 30 CFR 250.406, 250.515, 250.615 Prior to commencing tapered drill-pipe operations, is the BOP stack equipped as required?

  • 30 CFR 250.406, 250.515, 250.615 Is at least one of the valves on the kill line remotely controlled, or is a check valve installed on the kill line in lieu of the remotely controlled valve?

  • 30 CFR 250.406, 250.515, 250.615 If a check valve is installed in lieu of a remotely controlled valve in the kill line, are two readily accessible manual valves in place and is the check valve placed between the manual valves and the pump?

  • 30 CFR 250.407, 250.516, 250.616 Prior to conducting high-pressure tests, are all BOP systems tested to low pressure of 200 to 300 psi?

  • 30 CFR 250.407, 250.516, 250.616 Are the choke manifold valves, upper and lower kelly cocks, top-drive, inside-BOP, and the drill-string safety valves pressure tested to pipe-ram test pressures?

  • 30 CFR 250.407, 250.516, 250.616 If the pressure tests were postponed due to stuck drillpipe or pressure control operations, was the reason for postponing pressure testing entered in the driller's report?

  • 30 CFR 250.407, 250.516, 250.616 Is pressure testing performed at intervals to allow each drilling crew to operate the equipment?

  • 30 CFR 250.407, 250.516, 250.616 Are blind and blind-shear rams actuated at least once every 7 days?

  • 30 CFR 250.407, 250.516, 250.616 Are variable-bore pipe-rams pressure tested against all sizes of pipe in use?

  • 30 CFR 250.407, 250.516, 250.616 Are surface and subsea BOP systems pressure tested following the disconnection or repair of any well-pressure containment seal in the wellhead/BOP stack assembly, but limited to the affected component?

  • 30 CFR 250.407 Are the BOP systems and marine risers visually inspected at least once each day?

  • 30 CFR 250.407, 250.516, 250.616 Are the results of all pressure tests, actuations, and inspections of the BOP system, system components, and marine risers recorded in the driller's report?

  • 30 CFR 250.407, 250.516, 250.616 Are surface BOP systems pressure tested when installed?

  • 30 CFR 250.407, 250.516, 250.616 Are ram-type BOPs and the choke manifold pressure tested with water to rated working pressure?

  • 30 CFR 250.407, 250.516, 250.616 Is the annular-type BOP pressure tested with water to 70 percent of its rated working pressure?

  • 30 CFR 250.407, 250.516, 250.616 Are surface BOP systems pressure tested at least once each week, but not exceeding 7 days between pressure tests, alternating between control stations or as approved in APD?

  • 30 CFR 250.408 Are well-control drills conducted for each drilling crew in accordance with 250.58?

  • 30 CFR 250.408 Is a copy of the complete well control drill plan posted on the rig floor and/or bulletin board?

  • 30 CFR 250.408 Are drills conducted in accordance with the well-control plan?

  • 30 CFR 250.408 Are well control drills recorded in the driller's report?

  • 30 CFR 250.410 For each casing string, is the maximum pressure to be contained under the BOP posted near the driller's station?

  • 30 CFR 250.410, 250.514, 250.614 When coming out of the hole with drill pipe, is the annulus filled with mud before the change in mud level decreases the hydrostatic pressure by 75 psi, or every 5 stands of drill pipe, whichever gives a lower decrease in hydrostatic pressure?

  • 30 CFR 250.410, 250.514, 250.614 Has the number of stands of drill pipe and drill collars that may be pulled prior to filling the hole and the equivalent mud volume been calculated and posted near the driller's station?

  • 30 CFR 250.410, 250.514, 250.614 From the time drilling operations are initiated and until the well is completed or abandoned, is the well continuously under surveillance unless the well is secured with BOPs, bridge plugs, packers, or cement plugs?

  • 30 CFR 250.111, 250.413 Are lessee and drilling contractor personnel trained and qualified in accordance with the provisions of Subpart O of 30 CFR 250?

  • 30 CFR 250.111, 250.413 Are records of specific training which lessee and drilling contractor personnel have successfully completed, the dates of completion, and the names and dates of the courses maintained at the drill site?

  • 30 CFR 250.503, 250.603 Is an emergency shutdown system (ESD) manually controlled station installed near the driller's console or well-servicing unit operator's station where there are hydrocarbon-producing wells or other hydrocarbon flow on the platform?

  • Are operations conducted in accordance with: 1) Lease stipulations? 2) Approved applications? 3) Approved plans?

  • 30 CFR 250.414, 250.513, 250.613 Does the lessee have written or oral approval to perform the well operations?

  • 30 CFR 250.414, 250.513, 250.613 Does the lessee have written or oral approval to change plans, make changes in major drilling equipment, deepen or plug back a well, or engage in similar activities?

  • 30 CFR 250.414, 250.513, 250.613 Does the lessee have written or oral approval to change plans, make changes in major drilling equipment, deepen or plug back a well, or engage in similar activities?

  • 30 CFR 250.401 Are inclinational surveys obtained on all vertical wells at intervals not exceeding 1,000 feet during the normal course of drilling?

  • 30 CFR 250.401 Are directional surveys giving both inclination and azimuth obtained:

  • 30 CFR 250.401 On all directional wells at intervals not exceeding 500 feet during the normal course of drilling?

  • 30 CFR 250.401 On all directional wells at intervals not exceeding 100 feet in all portions of the hole when angle changes are planned?

  • 30 CFR 250.401 At intervals not exceeding 500 feet prior to or upon setting surface or intermediate casing, liners, and at total depth on all wells?

  • 30 CFR 250.404 Is casing set as approved?

  • 30 CFR 250.404 Has a pressure integrity test been run below the surface casing, the intermediate casing(s), and line(s), used as intermediate casing(s)?

  • 30 CFR 250.404 Are drilling operations suspended when the safe margin between the mud weight in use and the equivalent mud weight at the casing shoe is not maintained?

  • 30 CFR 250.404 Are the results of all tests and of hole behavior observations made during the course of drilling related to formation integrity and pore pressure recorded in the driller's report?

  • 30 CFR 250.404 If the hole for the drive or structural casing was drilled, was a quantity of cement sufficient to fill the annular space back to the mud line used?

  • 30 CFR 250.404 Is cement fill in the annular spaces of the conductor casing verified by the observation of cement returns, or in the event that observation of cement returns is not feasible is a quantity of cement used to assure fill to the mud line?

  • 30 CFR 250.404 Is surface casing cemented with a quantity of cement that fills the calculated annular space to at least 200 feet inside the conductor casing?

  • 30 CFR 250.405 Have all casings, except the drive or structural casing been pressure tested to 70 percent of the minimum internal-yield pressure of the casing or as approved in APD?

  • 30 CFR 250.405 Are the results of all casing pressure tests recorded in the driller's report?

  • 30 CFR 250.405 Is each production liner lap tested to a minimum of 500 psi above formation fracture pressure at the shoe of the casing into which the liner is lapped?

  • 30 CFR 250.405 Is the drilling liner lap pressure test equal to or greater than the pressure that will be encountered at the liner lap when conducting planned pressure integrity tests below the liner shoe?

  • 30 CFR 250.405 Are the results of the liner seal tests recorded in the driller's report?

  • 30 CFR 250.405 Has the casing been pressure-tested, calipered, or otherwise evaluated every 30 days during prolonged operations?

  • 30 CFR 250.405 Is there proper waiting-on-cement time before drilling was resumed?

  • 30 CFR 250.406 On a conventional drilling rig, is an essentially full-opening kelly cock installed below the swivel (upper kelly cock)?

  • 30 CFR 250.406 On a conventional drilling rig, is an essentially full-opening valve of such design that it can be run through the BOP stack (strippable) installed at the bottom of the kelly?

  • 30 CFR 250.406 With a mud motor in service and while using drill pipe in lieu of a kelly, is one kelly cock located above and one strippable kelly cock located below the joint of drill pipe employed in lieu of a kelly?

  • 30 CFR 250.406 On a top-drive system equipped with a remote-controlled valve, is a second and lower strippable valve installed?

  • 30 CFR 250.406 Is a wrench to fit each manually-operable valve in a conventional drilling rig, mud motor, and top-drive system stored in a location readily accessible to the drilling crew?

  • 30 CFR 250.406 Is a safety valve available on the rig floor assembled with a compatible connection to fit the casing string being run in the hole?

  • 30 CFR 250.406 Prior to drilling below surface or intermediate casing, is a BOP system installed consisting of at least four remote-controlled , hydraulically-operated BOPS including at least two equipped with pipe rams, one with blind rams, and one annular type?

  • 30 CFR 250.407 Are safety valves assembled with connections actuated prior to running casing?

  • 30 CFR 250.407 Are surface and subsea BOP systems pressure tested before drilling out each string of casing or before continuing operations in cases where the cement is not drilled out?

  • 30 CFR 250.407 Is the annular-type BOP pressure tested with water to 70 percent of its rated working pressure?

  • 30 CFR 250.410 Is an operable mud-gas separator and operable degases installed in the mud system prior to commencement of drilling operations and maintained for use throughout the drilling of the well?

  • 30 CFR 250.410 Has mud been properly conditioned by circulation before starting out of the hole with drill pipe, or is there proper documentation in the driller's report that circulation was not necessary?

  • 30 CFR 250.410 Is the mud in the hole circulated or reverse-circulated prior to pulling the drill-stem test tools from the hole?

  • 30 CFR 250.410 Is mud testing equipment maintained on the drilling rig at all times?

  • 30 CFR 250.410 Are mud tests performed once each tour or more frequently, as conditions warrant?

  • 30 CFR 250.410 Are results of mud tests recorded in the driller's report?

  • 30 CFR 250.410 Is a recording mud-pit level indicator with audible and visual warnings installed and used?

  • 30 CFR 250.410 Is a mud volume measuring device used to determine the mud volumes required to fill the hole on trips?

  • 30 CFR 250.410 Are mud-return indicator devices which indicate the relationship between mud-return flow rate and pump discharge rate installed and used?

  • 30 CFR 250.410 Is operable gas-detecting equipment installed to monitor drilling mud returns, with indicators located on the rig floor or in a continuously manned mud-logging unit having immediate communication with the rig floor?

  • 30 CFR 250.410 Are minimum quantities of mud and mud materials maintained at the drill site as necessary to ensure well-control?

  • 30 CFR 250.410 Are records of daily inventories of mud and mud materials maintained at the well site?

  • 30 CFR 250.410 Are all enclosed mud-handling areas; ventilated and equipped with gas detectors and alarms?

  • 30 CFR 250.410 If not continuously activated, are mechanical ventilation systems activated on signal from gas detectors that are operational at all times indicating the presence of 1 percent or more of gas by volume?

  • 30 CFR 250.410 Equipped with high capacity mechanical ventilation systems?

  • 30 CFR 250.410 Maintained at a negative pressure relative to an adjacent area if mechanical ventilation is installed and discharges may be hazardous?

  • 30 CFR 250.410 Protected with at least one of the following: A pressure-sensitive alarm;

  • 30 CFR 250.410 Protected with at least one of the following: Open-door alarms on each access to the area;

  • 30 CFR 250.410 Protected with at least one of the following: Automatic door-closing devices; or

  • 30 CFR 250.410 Protected with at least one of the following: Air locks?

  • 30 CFR 250.410 Protected with at least one of the following:Fitted with gas detectors and alarms?

  • 30 CFR 250.410 Equipped with either explosion-proof or pressurized electrical equipment to prevent the ignition of explosive gases?

  • 30 CFR 250.410 Where air is used for pressuring, is the air intake located outside of, and as far as practicable from, hazardous areas?

  • 30 CFR 250.410 Are mechanical ventilation systems fitted with alarms which are activated upon a failure of the system?

  • 30 CFR 250.410 Are gas detection systems tested for operation and recalibrated at a frequency such that no more than 90 days shall elapse between tests?

  • 30 CFR 250.411 Is a downhole safety device such as a cement plug, bridge plug, or packer installed when drilling operations are interrupted by events such as those which force evacuation of the drilling crew, prevent station keeping, or require repairs to major

  • drilling or well-control equipment?

  • 30 CFR 250.409 When drilling a conductor or surface hole, is the drilling unit equipped with a diverter system consisting of a diverter sealing element, diverter lines, and control systems?

  • 30 CFR 250.409 Is the diverter system equipped with remote-controlled valves in the flow and vent lines that can be operated from at least one remote-control station in addition to the one on the drilling floor?

  • 30 CFR 250.409 Are the diverter sealing element, diverter valves, and diverter control systems, including the remote-control system, actuation tested and the vent lines flow tested when first installed?

  • 30 CFR 250.409 Are subsequent actuation tests of the diverter sealing element, diverter valves, and diverter-control systems, including the remote-control system conducted at least once every 24-hour period alternating between control stations?

  • 30 CFR 250.409 Are all valves used in the diverter system full-opening?

  • 30 CFR 250.409 Are all right-angle and sharp turns in the diverter lines targeted?

  • 30 CFR 250.409 If flexible hose is used for diverter lines instead of rigid pipe, does the flexible hose have integral end couplings?

  • 30 CFR 250.409 Is the entire diverter system firmly anchored and supported to prevent whipping and vibration?

  • 30 CFR 250.409 Are all diverter control instruments and lines protected from physical damage from thrown and falling objects?

  • 30 CFR 250.409 Are all pressure test, flow test, and actuation results recorded in the driller's report?

  • 30 CFR 250.409 If the diverter system utilizes only one spool outlet, are branch lines installed to provide downwind diversion capability.

  • 30 CFR 250.409 If the diverter system utilizes only one spool outlet, is the minimum spool outlet and diverter line internal diameter at least 10 inches?

  • 30 CFR 250.409 If dual spool outlets are utilized, does each outlet have a minimum internal diameter of at least 8 inches?

  • 30 CFR 250.409 If dual spool outlets are utilized, are both outlets piped to overboard lines?

  • 30 CFR 250.409 If dual spool outlets are utilized, does each line downstream of the changeover nipple at the spool have a minimum internal diameter of 10 inches?

  • 30 CFR 250.409 Are diverter sealing elements and diverter valves pressure tested to a minimum of 200 psi when nippled up on a conductor casing, with no more than 7 days elapsed time between subsequent tests?

  • 30 CFR 250.414 After setting the drive pipe or structural casing, is there a diverter system and or an approved contingency plan for moving off location?

  • 30 CFR 250.409 After setting the conductor casing, is there at least one remotely controlled annular BOP, and is the diverter system installed?

  • 30 CFR 250.409 For floating / semisubmersible where drilling fluids are circulated to the drilling vessel, are all spool outlets and diverter line internal diameters at least 12 inches?

  • 30 CFR 250.409 On dynamically-positioned drill ships, is vessel heading maintained to allow for downwind diversion?

  • 30 CFR 250.409 On dynamically-positioned drill ships, is vessel heading maintained to allow for downwind diversion?

  • 30 CFR 250.406 Prior to drilling below surface and intermediate casing, are there at least four remote-controlled, hydraulically operated BOPs, including at least two equipped with pipe rams, one with blind-shear rams, and one annular type?

  • 31 CFR 250.406 Is a subsea accumulator closing unit installed?

  • 32 CFR 250.406 Does the BOP system include operable dual-pod control systems?

  • 30 CFR 250.407 Are subsea BOP system components stump pressure tested at the surface with water to their rated working pressure?

  • 31 CFR 250.407 Are subsea annular-type BOPs stump pressure tested at the surface with water to 70 percent of their rated working pressure?

  • After the installation of the BOP stack on the seafloor:

  • 31 CFR 250.407 Are the ram-type BOPs and choke manifold pressure tested to rated working pressure?

  • 32 CFR 250.407 Is the annular preventer pressure tested to 70 percent of its rated working pressure.

  • 33 CFR 250.407 Are subsea BOP systems pressure tested at least once each week, but not exceeding 7 days between pressure tests, alternating between control stations and pods?

  • 33 CFR 250.407 Are subsea BOP systems pressure tested at least once each week, but not exceeding 7 days between pressure tests, alternating between control stations and pods?

  • 30 CFR 250.515, 250.615 Dual pipe rams installed on one of the pipe-ram preventers, when dual tubing strings are being handled simultaneously?

  • 30 CFR 250.615 Does the minimum BOP-system components for well-workover operations with the tree in place and performed by coiled-tubing operations include:

  • One set of pipe rams hydraulically operated?

  • 30 CFR 250.615 One two-way slip assembly hydraulically operated?

  • 31 CFR 250.615 One pipe-cutter assembly hydraulically operated?

  • 32 CFR 250.615 One set of blind rams hydraulically operated?

  • 33 CFR 250.615 One pipe -stripper assembly?

  • 34 CFR 250.615 One spool with side outlets?

  • 35 CFR 250.615 Does the minimum BOP-system components for well workover operations with the tree in place and performed by snubbing operations, include the following:

  • One set of pipe rams hydraulically operated?

  • 35 CFR 250.615 Two sets of stripper-type rams hydraulically operated with spacer spool?

  • 36 CFR 250.615 Is an inside BOP or spring-loaded, back-pressure safety valve and an essentially full-opening, work-string safety valve in the open position being maintained on the rig floor at all times during well-workover operations when the tree is removed or

  • during well-workover operations with the tree installed and using small tubing as the work string?

  • 36 CFR 250.615 Is a wrench to fit the work-string safety valve readily available?

  • 36 CFR 250.615 Are connections readily available for inserting valves in the work string?

  • 30 CFR 250.517, 250.617 Has the wellhead been equipped so that all annuli can be monitored for sustained pressure, when the tree is installed?

  • 31 CFR 250.517, 250.617 Have new wells completed as flowing or gas-lift wells been equipped with a minimum of one valve and one certified surface safety valve in the vertical run of the tree?

DRILLING OPERATIONS FLUIDS

  • NPDES Permit GMG290000 Drilling fluids: Has weekly static sheen test been documented when discharging?

  • NPDES Permit GMG290000 Is vendor certification for Mercury & Cadmium in stock Barite available for each shipment received?

  • NPDES Permit GMG290000 Is inventory of chemical additives in drilling fluids discharged available?

  • NPDES Permit GMG290000 Drill Cuttings: Has weekly static sheen test been documented when discharging?

  • NPDES Permit GMG290000 If drilling cuttings have been discharged, has monthly sample of drilling fluid been taken for LC-50 toxicity test?

  • NPDES Permit GMG290000 Well Treatment, Completion & WO fluids: has monthly oil and grease sample been taken when discharging?

  • NPDES Permit GMG290000 Have daily static sheen test results of well treatment, completion, and WO fluids been documented when discharging?

  • NPDES Permit GMG290000 Have priority pollutants in well treatment, completion or WO fluids that have been discharged limited to trace amounts? Is information on the specific chemical composition of any additives recorded?

  • NPDES Permit GMG290000 Have BOP fluids, uncontaminated sea water, excess cement slurry, and mud, cuttings, and cement at the sea floor, if discharged, been documented at 7. OTHER DISCHARGES on NPDES form.

  • NPDES Permit GMG290000 Is an annual test of the Marine Sanitation Device (sewage unit) documented? If not, are monthly measurements of residual chlorine of sanitary waste and daily observations for floating solids documented?

  • NPDES Permit GMG290000 Is the NPDES Report - Drilling and Workover current and complete?

  • 40 CFR (Mixture Rule) Are hazardous, non hazardous oil field, and solid waste contained separately?

  • 40 CFR 261.4 Is rig contractor managing his waste (non drilling related paint, solvents, sand blast grit, etc.) separately and apart from Chevron's wastes,

  • LAG330000 LA0060224 If this location is in state waters are all discharges monitored for the applicable state discharge permit?

DRILLING OPERATIONS EMERGENCY EQUIPMENT

  • 46 CFR 109.217 (b)(d) Lifeboat/capsule clean and in good condition (All equipment to be removed and cleaned every 12 months.)

  • 46 CFR 109.221 (a) Lifeboat/capsule launching, elevating mechanism and limit switches operational.

  • 46 CFR 108.507 Lifeboat/capsule fall cables in good condition.

  • 46 CFR 108.503, 109.217 (b), 94.20-10 Lifeboat/capsule equipment and provisions (expiration dates in compliance).

  • 46 CFR 109.217 (a) Lifeboat/capsule engine and fluid levels (fuel and filters to be changed every 12 months).

  • 46 CFR 109.217 (b) Breathing air bottles in lifeboats fully charged. (min. 90%)

  • 46 CFR 109.217 (a), 109.215 Lifeboat/capsule to be run in water once every three months.

  • 46 CFR 109.215 Boat drill - Review station bill duties & organization.

  • 46 CFR 108.53 Rescue boat operational and in good condition with proper equipment.

  • 46 CFR 109.217 (e) Rescue boat fuel replaced every 12 months.

  • 46 CFR 108.511 Life rafts properly mounted and secured.

  • 46 CFR 108.510, 109.219 Life rafts, Hydro-Static releases, and/or hooks inspected within the past 12 months.

  • 46 CFR 108.503 (g)(2) Life raft instructions posted at rafts.

  • 46 CFR 107.239 Davit launched rafts - Weight test davit & release hook. Test wt. 165 lbs. x persons + wt. of raft.

  • 46 CFR 107.243 Precheck lifeboat/capsule limit switches & controllers for corrosion or internal water damage.

  • 46 CFR 108.525 Emergency escape fixed ladders in good condition (on legs, columns, hull, etc.)

  • 46 CFR 108.515, 108.649 (e) Condition of ring buoys (minimum qty. 8 and lines).

  • 46 CFR 108.515 33 CFR 144.01-25 Ring life buoys and water lights in proper mounting racks.

  • 46 CFR 108.515 Ring life buoy water lights operational. (min. qty. 4, and 2 of these must have approp. smoke sig.)

  • 46 CFR 108.515 (d) (1) Buoy smoke signals in good condition (not expired).

  • 46 CFR 108.514 All life jackets have lights (not expired), whistle, and reflective tape.

  • 46 CFR 108.514, 108.649 (b) Life jackets clean and properly stored in living quarters and in storage boxes around rig.

  • 46 CFR 109.335 Work vests clean and stored in storage boxes separate from life jackets.

  • 46 CFR 108.514 Life jacket and work vest storage boxes marked and in good condition.

  • 46 CFR 108.523, 109.208 Emergency position indicating radio beacon (EPIRB). Check for proper operation.

  • 46 CFR 108.513 Survival suits - Check for condition, proper storage, and quantity (125% of max, persons on board).

  • 46 CFR 108.521 Rig distress signals - 12 hand held parachute flares & 2 life ring floating smoke signals.

  • 46 CFR 108.645 Boat/capsule markings - Check vessel name, home port, capacity, boat number, release gear lever red.

  • 46 CFR 112.43 Is the entire emergency lighting system operational?

  • 46 CFR 58.10-10 Emergency generator in good working condition.

  • 33 CFR 67 Obstruction lights operational.

  • 33 CFR 66.10-35 46 CFR 111.75-17 Navigation lights operational.

  • 46 CFR 40-60 Bilge system fully operational.

  • 33 CFR 159 Sewage unit operating properly and no overboard discharge.

  • 33 CFR 142 Goggles, gloves, aprons, and respirators at all chemical mixing locations.

  • 46 CFR 108.235 (d)(e)(f) Heliport equipment in good condition (wind sock, lights, safety nettings, non-skid surface, markings)

  • 46 CFR 108.237, 108.239, 108.487 Helicopter refueling system and equipment in good operating condition.

  • 46 CFR 108.239 Fuel hoses in good condition. (Must be hydro tested once a year.)

  • 33 CFR 155.720 Fuel, oil transfer procedures.

  • 46 CFR 56.50-85 Venting for spaces in which liquid is carried as fuel.

  • 46 CFR 40-60 Fuel, water, and/or mud hose have manual valves on hose end.

  • 46 CFR 111.33-7, 111.33-9, 112.50-1 Are all ventilation systems and alarms operational?

  • 46 CFR 109.320, 109.207, 109.433 (m) Line throwing gun and equipment operational.

  • 46 CFR 109.321 Emergency and portable radios operational. (Check radios on life boats.)

  • 33 CFR 67 Rule #33 Fog horn operational.

  • 46 CFR 111 Emergency batteries in good condition and labeled according to service.

  • 46 CFR 107-109 Hand rails up around Texas deck and are clean and free of hazards.

  • 46 CFR 108.217 Check all stairs, ladders & walkways for loose or missing hand rails or safety chains.

  • 46 CFR 58.01-20 Machinery & equipment guards. All machinery & equipment capable of injuring personnel should have adequate covers or guards.

  • 33 CFR 142 Derrick riding belt and associated equipment in good condition.

  • 33 CFR 142 Derrick & drill floor eqpt.: crown block, kelly, slips, tongs, rotary table, draw works, etc.

  • 33 CFR 142 Monkey board and derrickman's equipment in good condition.

  • 46 CFR 108.707 Forklift and motion alarm operational.

  • 46 CFR 108.615 Electric forklifts charging system requirements. Break away plug with no bare conductors.

  • 46 CFR 109.535, 109.537 Diesel forklifts - Check refueling area, weather deck or well ventilated area. Port fire ext. required. Min. 4 lbs.

  • 46 CFR 107.109 First aid equipment and supplies in good condition.

  • 46 CFR 107.109 All eye wash stations operational and in good condition.

  • 33 CFR 142 Safety belts, lanyards, work vests, safety glasses, goggles, hard hats, and other safety equipment in good condition and used when required.

  • 46 CFR 108 Safety signs posted as necessary, clean and in good condition.

  • 46 CFR 107-109 MODU log book is kept up-to-date.

  • 33 CFR 141.1-35 USCG & ABS paperwork properly posted or on file as necessary. (including proof of citizenship papers)

  • 33 CFR 150.751 Personnel sign-in book logged daily & visitors briefed on emergency procedures upon boarding rig. Also upon boarding, medication notification forms completed and filed.

  • Need improvement Good Excellent General condition of housekeeping on rig. Needs improvement, good, excellent (circle one).

  • 46 CFR 108.661.663 Rig markings - Check rig name; home port on stern, rig name on bow, draft marks & loadlines port/stbd.

  • 46 CFR 108.161 Check that mud pit room doors have door closures that automatically close doors completely.

  • 46 CFR 58.50-10 (a) Fuel/lube oil tanks with level gages - Tubes must be heat treated glass, should have guard over glass.

  • 46 CFR 108.170.187, 46 CFR 111.105-9 Classified area electrical inspection - Check for new installations improperly installed. All electrical equipment explosion proof.

  • 33 CFR Pollution - Check all fuel tank vent flame screens. Remove all fuel or oil in pollution containers.

  • 46 CFR Subchapter E Loadline certificate available for inspection.

  • Life raft annual servicing certificates available for inspection

  • 46 CFR 109.435 Fire equipment annual servicing certificate available for inspection

  • 46 CFR 109.107 Person-in-charge designation letter available for inspection

  • 46 CFR 109.563 USCG, stability letter available for inspection.

  • USCG 46 CFR 66.69 USCG certificate of documentation (CB1270) available for inspection

  • 33 CFR Financial responsibility certificate (pollution) available for inspection

  • 46 CFR 109.431 MODU Logbook (unofficial) available for inspection.

  • 46 CFR 107.305 USCG approved construction portfolio available for inspection.

  • 46 CFR 107.231 USCG certificate of inspection (CG-041) available for inspection.

  • 46 CFR 109.527, 437, 439, 107.259 (a), 107.258-260 Crane certificates, crane record books, crane inspections, and crane operator qualification letters available for operation. Brakes should be freed up if necessary.

  • API RP 2.0 Wire ropes, slings, cables, hooks, and safety latches.

  • 46 CFR 107.231 (p) Check all watertight closures for proper closing: Gaskets and free bolts/dogs. Test remote controls.

  • ABS Rules Anchor winches -Check anchor winches for proper operation. Brakes should be freed up if necessary.

ENVIRONMENTAL CONTROLS

  • Is skid mounted unit equipped with drip pans?

  • Is skid mounted power packs equipped with drip pans?

  • Is each person engaged in installing, inspecting, testing, and maintaining safety devices qualified and is a record of this qualification maintained in the field area?

  • Is the well to which a concentric rig or related equipment is to be moved equipped with a back pressure valve prior to removing the tree and installing and testing the BOP system?

  • Have crew members been instructed in the safety requirements of the operation to be performed, possible hazards to be encountered, and general safety considerations to protect personnel, equipment, and the environment prior to engaging in

  • well-workover operations?

  • Has the date and time of safety meetings been recorded at the facility and is the information available for review by MMS representatives?

  • Does the minimum BOP - system components with the tree in place and performed through the wellhead inside conventional tubing using small-diameter jointed pipe as a work string include two sets of pipe rams and one set of blind rams?

  • Have surface BOP systems been pressure-tested with water?

  • Has each valve in the choke-and-kill manifold been successfully, sequentially pressure-tested to the ram-type BOP test pressure?

  • Have the BOP systems been tested at the following times:

  • When installed?

  • At least every seven (7) days?

  • At least once every 30 days for the blind or blind-shear rams?

  • Following repairs that require disconnecting a pressure seal in the assembly, the affected seal will be pressure tested?

  • Do the tests alternate between control stations and at staggered intervals to allow each crew to operate the equipment?

  • Are all personnel engaged in well-workover operations participating in a weekly BOP drill to familiarize crew members with appropriate safety measures?

  • Have the times, dates, and the results of BOP tests, actuations, and crew drills been recorded in the operations log?

  • If sustained casing pressure is observed, has the lessee notified the District Supervisor?

  • Are operations conducted so as to minimize leakage of well fluids?

  • Is any leakage occurring contained to prevent pollution?

  • Is lubrications assembly containing as least one wireline valve installed on all wells where communications exists between hydrocarbon-bearing zones and the well bore?

  • When initially installed, is the lubricator assembly successfully pressure tested to the expected shut-in surface pressure of the well?

  • Where there is an open hole below the casing, is isolation achieved?

  • For each perforated interval is isolation achieved?

  • If casing is cut and recovered leaving a stub, is the stub plugged?

  • Is any annular space communicating with any open hole and extending to the mud line plugged with at least 200 feet of cement?

  • Is a cement surface plug which is at least 150 feet in length set within the first 150 feed below the mud line?

  • Is a cement surface plug which is at least 150 feet in length set in the smallest string of casing which exceeds to the mud line?

  • Is the setting and location of the first plug below the surface plug verified?

  • Is each of the respective intervals of the hole between the various plugs filled with fluid that exerts a hydrostatic pressure exceeding the greatest formation pressure in the intervals between the plugs at time of abandonment?

  • Are all wellheads, casing, pilings and other destructions removed to a depth of at least 15 feet below the mud line?

  • Does the abandonment meet the requirements for a permanent abandonment except for a surface plug and clearance requirements?

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