API Commonly Used & Relevant Spec's & RP notes: API RP 2D sect C.4.1.2: 4-yearly load test of BOP crane to SWL +5 Ton and NDT inspection post load test. API Spec 4F: Crown Block Data Plate section 4.4.4. API Spec 4F: Sub-structure Data Plate section 4.4.3. API Spec 4F: Mast Data Plate section 4.4.2. API Spec 4F: Guy wire Tension etc, ref Table A1, Fig A. API Spec 4F: Raising cylinders and winches test to 150% W/Press for 10 mins, Sect 10.8.4 API Spec 4F: Mast welding procedures (coded welder AWS D1.1) Section 9. API Spec 6A: Threaded pipe connections HP piping, Section 4.2.1.3 Table 1. API RP 7C: Combustible Engine Exhaust Flanges Flameproof gaskets within 100'. API Spec 7F: Chain elongation. API Spec 7K Drilling & Well service equipment. API Spec7K: sect 6 welding requirements. Section 8: Test load paths written passage for each item. Section 10: Markings for load test equipment. Section 11: Documentation (should be supplied with equipment). API RP 8B: Maintenance repair & remanufacture Hoisting equipment and periodic inspection schedule (Drilling load path inspection frequency) Table 1. Section 5.3.3. Primary load path equipment listed under scope (at beginning of paper). API Spec 8C Drilling and Hoisting equipment API Spec 8C: Drill Line Sheave Depth etc, Section 9.2.4. API Spec 9A Wire ropes. (Drill line should show API on drum for line). API RP 9B: Ton Miles Drill line, section 5. API Spec 16 D BOP drillers panel rig floor. Section: 2: 2.1.7. API Spec 16D Two hand operation for valve control at remote panels: sect 4.3.3.1a. API Spec 16 D Alternate electric power supply required. Section: 4: 3.4.3. & section 2: 2.1.8 & Section 2: 2.2.7.3 for battery / ups supply required. API Spec 16D Pump requirements Section 2 2.1.3 API Spec 16D: BOP Control response times Section: 2. 2.1.1 + 5.1. & API RP 16 E: Section: 2.1 + 5.1. API Spec 16D BOP pump system test time 15 minutes Section: 5.1.2.1 API RP 16E section 2.2.1.2.
API Spec 16D Electrical installation requirements and Ex 3 rd party authority testing. API Spec 16D Control hose flame test Section 4.3.1 API 16D 11.4 MANUFACTURER S IDENTIFICATION MARKINGS Manufacturers shall affix at least one permanent marking containing, as a minimum, the manufacturer s name or mark, and the part number or other suitable unique identification on each control system, subsystem and component provided. Manufacturers may affix other markings at their discretion. API Spec 16E BOP Control hoses flame resistant section 2.7.1 API Spec 16 E Rig floor BOP remote panel required, Section 2.6. API Spec 16 E 2.3.2 Devices used to prevent pump system over-pressurization should be installed directly in the control system supply line to the accumulators and should not have isolation valves or any other means that could defeat their intended purpose. API RP 53 Various BOP and well control. API RP 54: Fire Extinguishers required. API RP 54 Sect 5.5.1 Personnel fall protection Anchor points min rated 5400lbs. API RP 54 Elect hand tools double insulated or grounded Sect 6.8.7. API RP 54: Electrical hand pneumatic tools dead man switch or no lockable ON switch Sect 6.8.8. API RP 54: Lock out tag out Section 6.9.1 API RP 54: Sect 9.15 Engine Emergency shutdown Weekly test (air intake shutdown must be fitted) API RP 54: Mast Ladders 7" clearance etc, Section 9.3.4. API RP 54: Engines within 100' spark arrestor required, Section 9.15.3. and API RP 75, Appendix A. API RP 54 Cables to be installed to protect same from damage. Sect 10.2.3 API RP 54: Cabin placement outside fall area guideline, Section 13.2.1. API RP 54: Engine Kill required at drillers control, Section 18.3.4. API RP 54 Sect:9.3.17 Guardrails, consisting of 42 in. (106.7 cm) high (nominal) top rail, intermediate rail, and posts, should be installed at the outer edge of any floor, platform, or walkway, that is 4 ft (1.2 m) or more above ground level or another floor or working level. A runway of 4 ft (1.2 m) or more above ground level shall be equipped with a guardrail. : Exceptions are as follows: a. Personnel egress (exit and entrance) openings. b. Catwalk and V-door opening when being used. c. Work station being used to rack tubular. d. Alternate arrangements providing equivalent safety are acceptable. API RP 54 Auxiliary Escape (Derrick man s escape) 6.10 API RP 54 (1999) Field welding shall not be permitted tongs, elevators bails etc Sect 6.1.14
API RP 54 Electrical hand tools shall be double insulated or grounded by NFRA70. Sect 6.8.7 API RP 62: MODU emergency power requirements. API RP 500 & 505: Electrical Hazardous area classification, Section 10.4 Fig 29. API RP 574: Yearly Wall thickness testing of HP piping. API RP 576: PRV retest and calibration 2 yearly Sect: 6.1.2. (Safety Valve) API RP 576: 6.2.2 Valve Identification To minimize errors in the testing and handling of pressure relief valves, each should carry an identifying tag, stencil, plate, or other means to show its company equipment number. This number allows ready identification of the device's unit, the equipment that the device should be installed on, the device's set pressure, and the date of its last test (see Figure 37 for an example of an identifying tag). If a relief device cannot already be easily and correctly identified by a marking on it, it should be marked and identified as described above before it is removed from its equipment. Also see ASME Section VIII, Division 1, paragraph UG-129 for instructions on marking nameplates of pressure relieving devices. EX Electrical Equipment to IEC 60079. API S 53 6.5.3.6.4 Test pressure measurement devices (including analogue gauges) shall be calibrated annually in accordance with OEM procedures. API S 53 6.3.5.12 Devices used to prevent pump system over pressurization shall not have isolation valves or any other means that could defeat their intended purpose. API S 53 6.3.5.13 Rupture disc(s) or relief valve(s) that do not automatically reset shall not be installed. API S 53 7.3.5.11 Each pump system shall be protected from over pressurization by a minimum of two devices: One device, such as a pressure switch, to limit the pump discharge pressure so that it will not exceed the RWP of the control system; The second device, such as a certified relief valve, to limit the pump discharge pressure and flow in accordance with API 160. API 16 D 7.5.5 Relief Valve Certificates Relief valves shall be separately tested and adjusted using a low flow rate tester comparable to a dead weight tester. A certificate of the relief valve setting and operation shall be provided indicating the set point and the pressure at which the relief valve reseats. Relief valves shall reseat within twenty five percent. of the set pressure. Relief valves shall additionally be type tested to determine the maximum flow rate through the relief valve without exceeding 11.5% of the relief valve's set pressure. API Standard 526 4.2 SET PRESSURE TEST
All pressure relief valves shall be adjusted to the specified set pressure in accordance with the ASME Boiler and Pressure Vessel Code, the manufacturer s standard practice as published, or as designated by the purchaser. All set pressure adjustments shall be sealed. ASME B 31.3 304.3.4 (h) Identification. The manufacturer shall establish the design pressure and temperature for each extruded outlet header and shall mark the header with this information, together with the symbol B31.3 (indicating the applicable Code Section) and the manufacturer s name or trademark. MSS SP 25 This standard marking system applies to valves, fittings, flanges, and unions used in piping connections which include (but are not limited to) flanged, soldered, brazed, threaded, or welded joints. IHS Standard The markings specified within this Standard Practice serve to identify the manufacturer, the rating designation, materials of construction, and special service limitations imposed by the manufacturer. They are used for product identification and to assist in proper application API RP 64: 2001 Recommended practice for diverter systems equipment and operations. - 2nd edition. API RP 7L: 1995 Procedures for inspection, maintenance, repair, and remanufacture of drilling equipment. - 1st edition. API Spec 16A: 2004 Specification for drill-through equipment. - 3rd edition. API Spec 16C: 1993 Specification for choke and kill systems. - 1st edition. API Spec 16D: 2004 Specification for control systems for drilling well control equipment and control systems for diverter equipment. - 2nd edition. API Spec 16D: 2004 5.1.2 Pump Systems 5.1.2.1 The manifold pumping unit provides power fluid for all of the control system hydraulic functions. The same pumping unit may be used to provide fluid power for the control of both the BOP and diverter system. The manifold pumping unit shall comprise a minimum of two (2) pump systems with at least two (2) independent power systems. API STANDARD 53 6.3.5.6 The same pump system(s) may be used to provide control fluid to control both the BOP stack and the diverter system. API Spec 16D 2004. 3.107 Water-based hydraulic fluid: A control liquid mixture composed mainly of water with additives to provide lubricity, anti-foaming, anti -freeze, anti-corrosion and anti -bacterial characteristics.
API Std 16AR Repair and Remanufacture of Drill-through Equipment. - 1st edition. API Std 53:2012 Blowout Equipment Systems for Drilling Wells. - 4th edition. STAP-M-1-SS-13668:2002 BOP AND WELL CONTROL EQUIPMENT ACCEPTANCE MINIMUM REQUIREMENTS 3.1.52 original equipment manufacturer OEM, API RP 53 and in API S 53 6.5.8.1 17.11.l Installation, Operation, and Maintenance Manuals Manufacturer s installation, operation, and maintenance (IOM) manuals should be available on the rig for all the BOP equipment installed on the rig. Oil and Gas UK recommendations for critical spares page 36 section 5.4.3 Requirements for spares. API S 53 6.5.10.4 Equipment Data Book and Certification API RP 53 17.13.2 Equipment Data Book and Certification API S53, para 4.12.4. Any elastomer seals found to be outside the manufacturer's recommended expiration date shall be discarded and prohibited from use in BOP equipment systems. API S53 para 7.1.4.2 and para 4.12.5, the OEM manual, The Energy Institute recommends in the Guidelines for the Management for the Integrity of Bolted Joints for Pressurized Systems, para 2.3.3 that there must be sufficient provision for full thread engagement. The relief valves (Safety Valves) do not comply with API RP 576, para 6.3 where there is no identification tag present and the seals are broken. 4.12 Equipment Marking and Storage 4.12.1 Marking and storage of sealing components of BOP systems shall be in accordance with API 6A. API 16A, or API 17D, as applicable, including identification marking of ring gaskets, bolts, nuts, clamps, and elastomeric seals. 4.12.2 Elastomeric seals shall be marked or tagged using the equipment manufacturer defined coding system. 4.12.3 At a minimum the markings shall include information regarding the Durometer hardness, generic type of compound, dates of manufacture and of expiration (month/year), Lot / serial number, manufacturer's part number, and the operating temperature range of the component. 4.12.4 Any elastomer seals found to be outside the manufacturer's recommended expiration date shall be discarded and prohibited from use in BOP equipment systems.
BLOWOUT PREVENTION EQUIPMENT SYSTEMS FOR DRI LLI NG WELLS 4.12.5 Specialized components, including proprietary design BOP seals and packing units, shall be stored in accordance with the OEM's recommendations. API 6A June 2006 ERRATA 3 G. 2 Elevated temperature ratings The temperature ratings given in Table G. 1 may be used for equipment for service temperatures in excess of those covered by Clause 4. Table G.1 Temperature ratings Classification Operating temperature range X 18 to 180 C 0 to 350 F Y 18 to 345 C 0 to 650 F Spec 12 J: Oil Gas Separators Separators are equipped with gauge glasses or sight glasses to indicate one or two levels. A pressure gauge and thermometer well are usually installed on separators. API 16 D Specification. 9.10.3.6 2. Using the choke control system in a normal operating procedure, close the choke. The choke shall be completely closed in 30 seconds or less. 5. The choke shall operate from fully closed to fully open in 30 seconds or less. API 16 D Specification. 3.10.1 DESIGN REVIEW. Design documentation shall be reviewed and verified by qualified personnel other than those who created the original design. 3.10.2 DESIGN VERIFICATION. Manufacturers shall document their verification procedures and the results of performance verification of designs. Design verification is not required on APT flanges, hubs and ring gaskets. API 16 D Specification. 6.12.2 RANGE. Pressure measurements shall be made at not less than 25% nor more than 75% of the full pressure range of the pressure gauge. API 16 C Specification. Surface Manifold
IP 17 (a) More than one flow path through the choke manifold in case of blockage. The minimum nominal diameter of all components should be 3 inches. IP 17 Remotely controlled, power operated adjustable chokes for primary flow paths. Where the kill and choke lines are integrated through the choke manifold, e.g. subsea BOP systems and many surface BOP arrangements, the manifold should be configured so that these lines are interchangeable. The arrangement should permit high pressure pumping down the kill line while taking returns through the choke line. IP 17 In the event that the gas handling capacity of the MGS is exceeded a mud seal should be provided as a final barrier between the MGS and the downstream mud processing system. The system by-pass capacity is determined from the hydrostatic head of the mud seal and the size of the vent line. The mud seal may become contaminated with produced hydrocarbon liquids reducing its effective hydrostatic head. Circulating clean fresh mud from the pits through the mud seal can help prevent compromising the gas handling capacity. This is often referred to as a 'hot' mud injection system. IP 17 All chokes should discharge directly into an erosion nipple/spool. IP 17 5.3.2 MGS instrumentation The MGS should be instrumented and controlled so that the gas handling capacity is not exceeded i.e. the liquid seal is not disturbed. Instrumentation by means of pressure gauges fitted in the MGS to give continuous monitoring should be coupled with visual/audio warning alarms once the pre-set by-pass overboard pressure is reached.
API Specification 16F for MARINE DRILLING RISER EQUIPMENT 13.4 Marking The riser spider will be marked using permanent low-stress, metal-impression stamping specifying a serial number that corresponds to a data sheet for the spider. The data sheet shall include as a minimum the manufacturer's name and part number and the maximum load rating. API Specification 16F for MARINE DRILLING RISER EQUIPMENT 13.1 Design, rating and testing Riser handling tools and spiders shall be designed considering the following loads: Maximum static load capacity Bending loads (during handling) API Spec 8C, PSL 2. 14 Riser Running Equipment 14.1 DESIGN, RATING AND TESTING Riser handling tools and spiders shall be designed considering the following loads: a. Maximum static load capacity. b. Bending loads (during handling). Handling tools for the riser and for the diverter, if used to support the riser and the BOP Stack, shall be designed, rated, and tested in accordance with API Spec 8C, PSL 2. The spider (and gimbal and shock absorber, if applicable) shall also be designed, rated, and tested in accordance with API Spec 8C. Handling tools for the riser and for the diverter, if used to support the riser and the BOP Stack, shall be designed for hoisting and lowering the riser system through the riser spider and rotary table. Riser hang-off spiders shall be rated to support the riser system and BOP Stack at the drill floor level. The riser joint shall be permanently marked using a low stress method. Marking shall include a serial number that corresponds to a data sheet for the joint and API Spec 16F (or API Monogram). The data sheet shall include as a minimum the manufacturer s name and part number, the maximum load ratings, and the asbuilt assembled weight excluding buoyancy and protectors. Syntactic foam buoyancy modules shall be pigmented or painted a highly visible colour with require markings printed indelibly on its surface. Serial numbers shall be located in a minimum of three places on each module: the outer surface, the inner surface, and the end of the module.
Each module shall be identified with a colour code for each depth rating as agreed by manufacturer and purchaser. The riser spider shall be marked using permanent low-stress, metal-impression stamping specifying a serial number that corresponds to a data sheet for the spider. The data sheet shall include as a minimum the manufacturer s name and part number, the maximum load rating, and indication of conformance to API Spec 16F (or API Monogram). Marking shall be in accordance with manufacturer s written specifications. API 17 H. 12.10.4 Design requirements The hot stab receptacle should be designed such that it does not fill with debris whilst not in use, for example, a passive blank may be provided, which is temporarily pushed out of the way by the insertion of the hot stab. Hot stab females can also be filled with blanking plugs to avoid debris ingress; where this is the case, a parking slot should be provided for the blank during use of the hot stab facility. API 16 D. 1.5 EMERGENCY BACKUP BOP CONTROL SYSTEMS. When the subsea control system is inaccessible or non-functional, an independent control system may be used to operate critical well control and/or disconnect functions. These systems have their own supply of power fluid. They include acoustic control systems, ROV (Remotely Operated Vehicle) operated control systems and LMRP recovery systems. API 6A. 8.1.4 Hidden marking Marking required on a connector OD that would be covered by clamps or other parts of the connector assembly shall be stamped in a visible location near the connector. API RP 53. 12.3.3 Accumulator Response Time. Response time between activation and complete operation of a function is based on BOP or valve closure and seal off. For surface installations, the BOP control system should be capable of closing each ram BOP within 30 seconds. Closing time should not exceed 30 seconds for annular BOPs smaller than 183/4 inches (47.63 cm) nominal bore and 45 seconds for annular preventers of 183/4 inches (47.63 cm) nominal bore and larger. Response time for choke and kill valves (either open or close) should not exceed the minimum observed ram close response time. API Specification 16 D. EFFECTIVE DATE, JANUARY 2005 5.1.1 Response Time Response time between activation and complete operation of a function is based on BOP or valve closure and seal off. For surface installations, the BOP control system shall be capable of closing each ram BOP within 30 sec. Closing time shall not exceed 30 sec. for annular BOPs smaller than 18 3/4 in. nominal bore and 45 sec. for annular preventers of 18 3/4 in. and larger. Response time for choke and kill valves (either open or close) shall not exceed the minimum observed ram close response time. Measurement of closing response time begins when the close function is activated at any control panel and ends when the BOP or valve is closed affecting a seal. A BOP may be considered closed when the regulated operating pressure has recovered to its nominal setting. 5.2.1 Response Time The control system for a subsea BOP stack shall be designed to deliver power fluid at sufficient volume and pressure to operate selected functions within allowable response times. The control system shall have a closing response time not exceeding 45 sec. for each ram BOP. Closing response time for each annular BOP shall not exceed 60 sec. Operating response time for each
choke and kill valve (either open or close) shall not exceed the minimum observed ram close response time. The response time to unlatch the riser (LMRP) connector shall not exceed 45 sec. API Specification 16 D. EFFECTIVE DATE, JANUARY 2005 5.2.10.2 Hose Reel Drum The hose reel drum radius shall be equal to or greater than the minimum bend radius recommended by the manufacturer of the subsea umbilical, for the type of service intended. The hose reel drum shall be equipped with a brake capable of overriding and stalling the motor. The brake should be capable of supporting the weight of the fully deployed subsea umbilical when it is suspended in water. The hose reel drum shall have a mechanical locking device that permits operation of the hose reel manifold (if equipped) and ability to connect the junction box when parked. API RECOMMENDED PRACTICE 64 (RP 64) SECOND EDITION, NOVEMBER 2001 REAFFIRMED, JANUARY 2012 8.4.2 Installation Test 5. A pressure integrity test (200 psig minimum) should be made on the diverter system after each installation. The tests may be made on parts of the system or on individual components of the system should certain components of the casing string or riser components not support a complete system test. The test should be stable for at least five minutes. Stainless Steel Basic Properties Galvanic Corrosion Takes Place When Two Dissimilar Metals Are Electrically Coupled In The Presence Of An Electrolyte: The electrolyte assisting in the transfer of the charged atoms / molecules necessary for the corrosion to take place, the more reactive of the two metals (the anode) will corrode in preference to the less reactive metal (the cathode), steel structures in the maritime environment are often protected by zinc anodes. The (more reactive) zinc corrodes and dissolves in the presence of the salt water (the electrolyte), thereby offering some anti-corrosion protection to the steel (cathode). The serviceable life of the steel is thus extended. The rate at which galvanic corrosion can proceed is governed by two key factors. Availability of electrolytic liquid (such as salt water) to facilitate ion transfer The relative exposed area of the two dissimilar metals that are exposed and electrically coupled in the electrolyte Stainless steel is less reactive than ordinary mild steel or cast iron, therefore the iron/steel will corrode via galvanic reaction (if the above conditions are met) protecting the stainless steel. - Remote control panels for operating the hydraulic control manifold from remote locations. REMOTE CONTROL PANELS GENERAL API RP 16 E. 2.6 A minimum of one remote control panel should be furnished. This is to ensure that there are at least two locations from which all of the system functions can be operated. The remote panel should be accessible to the driller to operate functions during drilling operations. The driller's remote control panel display should be physically arranged as a graphic representation of the BOP stack. Its capability should include the following: 1. Control all the hydraulic functions which operate the BOP's and choke and kill valves. ANSI/API Specification 16A Third Edition, June 2004 8.5.8.4.2 Acceptance of Drift Test.
The drift mandrel shall pass through the bore within 30 min without being forced. API STANDARD 53 6.2.3.2.1 Choke lines shall be secured to withstand the dynamic effect of fluid flow and the impact of drilling solids. Supports and fasteners located at points where piping changes direction shall be capable of restraining pipe deflection. Special attention should be paid to the end sections of the line to prevent line whip and vibration. diverter 7.3.10.4 The following response times shall be met by at least one of the surface/subsea power supplies: a) Close each ram BOP in 45 seconds or less; b) Close each annular BOP in 60 seconds or less; c) Unlatch the riser (LMRP) connector in 45 seconds or less; d) Response time for choke and kill valves (either open or close) shall not exceed the minimum observed ram close response time. API S 53. 7.6.6.3 For the pre-deployment BOP test (stump test), the annular(s) and VBR(s) shall be pressure tested on the largest and smallest OD drill pipe to be used in well drilling program. API S 53 7.3.20.1 ROV Intervention 7.3.20.1.1 The BOP stack shall be equipped with ROV intervention equipment that at a minimum allows the operation of the critical functions (each shear ram, one pipe ram, ram locks, and unlatching of the LMRP connector). 7.3.20.1.2 Hydraulic fluid can be supplied by the ROV, stack mounted accumulators (which may be a shared system), or an external hydraulic power source that shall be maintained at the well site. The source of hydraulic fluid shall have necessary pressure and flow rate to operate these functions. 7.3.20.1.3 All critical functions shall be fitted with single-port docking receptacles designed in accordance with API 17H. 7.3.20.1.4 If multiple receptacle types are used, a means of positive identification of the receptacle type and function shall be required. 7.3.20.1.5 Frequency of testing and acceptance criteria shall be in accordance with Table 6 and Table 7. 7.3.20.1.6 All critical functions shall meet the closing time requirements in 7.3.10.4. 7.3.10.4 The following response times shall be met by at least one of the surface/subsea power supplies: a) Close each ram BOP in 45 seconds or less; b) Close each annular BOP in 60 seconds or less; c) Unlatch the riser (LMRP) connector in 45 seconds or less; d) Response time for choke and kill valves (either open or close) shall not exceed the minimum observed ram close response time.