General requirements:
Paragraph 2 (1):
PM program shall include all WCE listed in appendix B.
All PM program activities shall be verified, approved and countersigned by tool pusher or
Rig manager.
BOP control unit PM shall be as per OEM recommendations.
A visual inspection of the Annular BOP Packing Element shall be conducted prior to the commencement of operations that may be impacted by rubber down hole if elastomer rubber shedding or chunking from the Packing Element were to occur. Visual inspection documents shall be signed by the Tool pusher and Rig Foreman and shall be available at the rig site for audit verification.
Rig and warehouse personnel shall follow OEM Operation and Storage Procedures for annular BOP s and packers. Rigs Shall create a tracking sheet to track the following: BOP closure date and timed operating pressure, pipe size, wellbore pressure, wellbore temperature, reason for closure, type of fluid in the hole, closure duration and was stripping taking place, YES or NO.
A copy of the drilling contractor PM Manual shall be available at the rig-site either in hardcopy or softcopy. The rig shall also maintain on-site a PM logbook with list by serial number of all current on-location WCE confirming all inspections, PM dates and PM completed or pending actions. Both the PM Manual and Logbook will be a Saudi Aramco rig audit item.
1.1.2 TRACEABILITY…(2): instead of “repair numbers are not acceptable for
This requirement” / “repair job numbers marked on WCE are not acceptable for traceability requirement, however complete repair/recertification documentation history is required”. Instead of “diameter” / “inside diameter”.
1.1.3 only OEM parts are acceptable when repairing or redressing BOPs….
(1) control unit spare parts will be as recommended by the OEM.
1.1.9 (2)instead of “emergency lines” / “emergency kill lines”.
1.1.13 (1) The Toolpusher/OIM is responsible for maintaining the logbook.
The logbook shall be verified and signed by Toolpusher/OIM and Saudi
Aramco Representative.
1.1.15 (3)“all WCE must meet ISO 15156 was”, (4) “ New manufacture and
repair/remanufacture: New manufactured WCE, shall meet latest editions of NACE MR-0175, in addition to API specifications 6A, 16A, 16C or 16D, latest editions, depending on equipment type. Nonmetallic elastomers in contact with well fluids shall meet all requirements of API 6A appendix F ‘modified’ test requirements (Test parameters will be defined on separate document). Diverters shall meet API standard 64 latest edition. Repaired/remanufactured WCE shall meet the requirements of API standard 6AR, 16AR, 16C or 64. For WCE and BOP’s manufactured prior to API-16A Fourth Edition, first-class recertifications per OEM specifications for WCE and BOP’s is an acceptable substitute for 16AR RSL-2 and RSL-3. In-field recertification is not acceptable
1.1.16 full OEM certification or recertification …
(1)NOTE: Rigs under an existing contract that exercise an extension (maintaining the same contract number) will retain the current WCE COC’s in effect at the time of contract extension. The rig will be audited against the WCM edition in effect at the time of the initial contract. If an existing rig’s contract ends, then rig is re-contracted under a new contract number (different from the previous number), the WCE would require valid OEM COC’s and the latest edition WCM will take effect for future audits.
1.1.20 “WCE for recertification includes but not limited to” (3) in WCM 7”
(1) The recertification interval period will begin from the date of the OEM Repair, Remanufacture or New Manufactured COC, not the date of shipping, installation, or commissioning. OEMs shall not issue postdated COC’s for WCE. The repair remanufacture or new manufactured document package shall correspond with the COC date.
1.1.21 (2) instead of “Recertification can only be performed by OEM or their licensee
facility” / “Recertification or COC can only be performed by OEM (except for API 6A dumb iron) or their licensee facility. Recertification intervals will be determined based on the date reflected on individual component COC”.
(4)The OEM or OEM licensee shall have the appropriate API License for the equipment under recertification repair/remanufacture. The recertification document package shall include a copy of the API license. If the recertification was completed by a non-OEM shop, the document package shall include a current license issued from the OEM to the licensee.
1.1.23 (1)Recertification shall include visual inspection, NDE inspection and
pressure testing. Blind flanges are exempt from the pressure test requirement.
1.1.24 (2) instead of “BOPE” / “WCE”
1.1.25 (1) Fabrication of WCE detailed in this manual is prohibited.
1.1.28 (2) instead of “Drilling contractors are strongly discouraged from sharing BOP
equipment between rigs without equipment owner documented basic
maintenance and inspection after the previous installation” / (2/4)“Drilling
contractors may not share BOP equipment between rigs without equipment owner documented, singed basic maintenance and inspection from the previous installation. If sharing equipment, it is the responsibility of the Toolpusher/OIM of the sending and receiving rigs to ensure proper documentation indicating the transfer. Documentation shall contain details for both rigs (including Toolpusher/OIM name), date, type of BOP, size, pressure rating, part number, and serial number.”
1.1.29 (2) instead of “Gate valves” / “manual/hydraulic gate valves”
1.1.30 (1)At time of new manufacture and subsequent repair/remanufacture, (2)instead of
“BOP forgings must meet minimum yield requirement <= 5000 psi: 60 K or higher yield and >= 10,000 psi : 75K yield” / “BOP forgings shall also meet minimum yield requirement <= 10,000 psi: 60 K or higher yield and >= 15,000 psi : 75K yield”.
1.1.31 (2) instead of “All non-metallic elastomers in contact with well fluids, shall
be tested in accordance with, and shall meet all the requirements of NACE TM0187, latest version, for Elastomeric Materials in Sour Gas Environments” / “ All non-metallic elastomers in contact with well fluids, shall meet all the requirements of API 6A Appendix F ‘modified’ test requirements (Test parameters will be defined on a separate document) latest version.
1.1.32 (3) “WCE which has been installed on Gas or Offshore Oil service at any time
from the previous recertification, and is then moved to Onshore Oil Service, the re-certification will remain at 3-years”.
1.1.33 (4)“Climate to air conditioned climate” , “in accordance with the equipment owner’s and manufacturer’s requirements to in accordance with equipment owner’s requirements and OEM procedures, BOPs to RAM BOPs.
(1)“Annular BOPs shall have the cap removed, packer removed, all components cleaned and coated with an OEM recommended lubricant prior to reassembly. If practical, the used annular packer shall be stored in climate-controlled storage until needed”.
Annular units and Diverters:
1.2.2 (2)The minimum acceptable H2S and temperature ratings for annular BOP’s and packers are
WCM 6
WCM 7
1.2.4(1)Rotary diverter systems shall be stamped on the product with “API S64”. Equipment to be marked include diverter housing, diverter assembly, diverter spool, diverter packers, diverter running tool and flow selector…. The API 6A gate valves on the divereter assembly will require 3 or 5 year recertification, (dependent on pressure rating).
1.2.5 (2): instead of “functionality” / “sequencing per API 16D”
1.2.7(2): instead of “30 inch 1,000 psi annulars are non-monogrammed” / “30 inch 1,000 psi annulars purchased after the release of WCM 7th Edition, shall be monogrammed under API specification 16A, and shall be recertified every 5 years”
Ram BOP’s / Ram Blocks / Wetted Elastomers:
1.3.3 The minimum acceptable ratings for H2S and temperature for BOP’s and Ram assemblies are:
WCM 6
WCM 7
1.3.4 (2): instead of “GE-Hydril” / “HMH-Hydril (including Sentry Model) are acceptable manufacturers for ram preventers, …. instead of “All ram assemblies shall meet NACE Standards MR-01-75 and TM0187 (latest editions) for sour service”. “..Shall meet latest editions of NACE standards MR-01-75 (for metallic components) and (for wetted elastomers)”.
1.3.5 (3) for locking devices “Automatic devices (e.g.: Shaffer Posilocks) are also acceptable”.
1.3.5 Variable Bore Ram Preventer Blocks and Elastomers:
(3) for VBR compliance “with 1.3 (Ram BOPs/Ram Blocks/Wetted elastomers)”.
1.4.2 (1)… VBR’s may be used in 10,000 psi BOP stack configurations only if drilling in 5,000 psi oil service.
1.4.3 (2)The minimum acceptable ratings for H2S and temperature for VBR’s are:
WCM 6
WCM 7
1.4.4 (2)instead of “Cameron ER-HT VBR-II Successfully tested to 250 Deg F” / “..Successfully tested to 300 Deg F”.
Shear Blind Ram (SBR) Blocks and Elastomers:
1.5.2 The minimum acceptable ratings for H2S and temperature for SBR’s are:
WCM 6
WCM 7
1.5.3 (1)Approved SBR: … Cameron (Dual string inerlocking shear rams {DSI}), Shaffer Type 6000, HMH (Hydril) Sentry Model, Cameron DSI, NOV shaffer LFS and HMH Hydril Sentry SBR shear rams have completed shear and seal of dual 3-1/2” 9.3 lb/ft tubing strings.
1.5.7 (4)…Shear rams shall meet SAWCM, API 16 A, API 16TR latest editions for PR2.
WCM 6
WCM 7
Side Outlets, Valve Removal Plugs and Blind Flanges:
Drilling Spools:
1.5.8 (2)instead of “PSL-2 with PSL-3 Gas Test (≥10,000 psi working pressure)” “PR-1 (or better) “/ “PSL-3 (≥10,000 psi working pressure)” ” PR-1 (or better), <= 5000 psi working pressure”.
CHAPTER B REQUIREMENTS FOR KILL, EMERGENCY KILL, CHOKE LINES AND
CHOKES
The Minimum Bore Size for Kill, Emergency Choke & Kill Lines Shall Be As Follows:
2.1 (2)instead of “choke lines minimum nominal size/bore 3-1/8” in 3k and 5k “/ “3-1/16” in 3k and 5k”. (2)instead of “Rigs utilizing ≤5,000 psi BOP equipment shall have 3-1/8” dual choke lines and 2-1/16” and dual kill line access, (one above the lower rams and one above the lower rams). There shall be primary and emergency kill lines, with primary tie-in from the mud pumps and the emergency tie-in allowing high-pressure access by a cement unit. All configurations are as specified in Chapter B. / “Rigs utilizing <= 5.000 psi BOP equipment shall have a 3-1 8″ choke line and dual 2-1/16″ kill lines. In the case that a 10K or 15K psi BOP is nippled up on a 5K or 3K psi wellhead (thereby de-rating all equipment to 5K or 3K psi). and only for operations on an oil or water injection well, then the choke manifold may be held to the requirements for a 5K psi choke manifold as defined in Section 15.3 of the Well Control Manual and the minimum choke line size may be 3-1/16″. The primary kill line shall be connected to the drilling spool with the emergency kill line connected to the lower ram BOP body side outlet. Primary and emergency kill lines provide well access from either the mud Pumps or high-pressure access by a cement unit. All configurations are as specified in Chapter B, Figure B-5.”
2.1.2 (2)instead of “Rigs utilizing ≥10,000 psi BOP equipment shall have 4-1/16” dual choke lines and 2-1/16” dual kill line access, (one above the lower rams and one above the lower rams). There shall be primary and emergency kill lines, with primary tie-in from the mud pumps and the emergency tie-in allowing high-pressure access by a cement unit. All configurations are as specified in Chapter B” / Rigs utilizing 10.000 and 15,000 psi BOP equipment shall have 4-1/16″ dual choke lines. Primary and emergency kill lines are required with 10K kill lines sized as 2-1/16″ minimum and 15K kill lines sized as 3- 1/16” minimum. The primary kill line shall be connected to the drilling spool with the emergency kill line connected to the lower ram BOP body side Outlet. Primary and emergency kill lines provide well access from either the mud pumps or high-pressure access by a cement unit. All configurations are as specified in Chapter B, Figures B-3 and B-4.
Materials and Fabrication:
2.2.2 (2)instead of “Choke/kill lines for 3M and 5M applications” / “Choke/kill lines for 3k through 15k applications”.
2.2.2 (2)instead of “Technip” / “Technip and Conti Tech”. (1) Temperature & H2S Requirements: Oil Service 3K & 5K, 300 2500, 10% H2S, Gas Service 10K & 15K 30º – 300º, 20% H2S
2.2.7 (2) instead of “ Flexible choke and kill lines shall be monogrammed to API Specification 16C. If flange connections are installed on the flexible line, the flange will be monogrammed to API-6A. The only approved flexible choke and kill lines are: Technip/Coflexip (coflon lined) ≥10,000,
Continental ContiTech-Thermo plastic lined (allowed only for ≤5,000 psi) ContiTech/Phoenix (allowed only for ≤5,000 psi) (see product compatibility table)
Gates Black Gold Xtreme (allowed only for ≤5,000 psi) (see product compatibility table)”. /
Flexible choke and kill line assemblies shall be monogrammed to API Specification 16C. Integral (API 6A monogrammed), swivel flange (API 17D monogrammed) connections are acceptable on the flexible line. The connections may be included as a component in the API 16C flexible line assembly monogram. The only approved flexible choke and kill lines are:
Technip/Coflexip, Coflon lined approved for > = 3000 psi.
ContiTech/TauroFlon lined approved for > = 3000 psi.
ContiTech/Phoenix HNBR lined approved for < = 5 000 psi (see product compatibility table)
Gates Black Gold Xtreme approved for < = 5,000 psi. (see product compatibility table).
2.2.8 (4) “ … shall at a minimum pass NDE including hardness tests (HRC 22 or less) , MPI/LPI (depending on ferrous or non-ferrous material), and radiography or UT of welds”.
2.2.10 (2)instead of “ integral or hubbed” / “ integral, studded or hubbed”.
Requirements for drilling chokes:
2.3.1 (2)instead of “ Cortec CX3” / “ Cortec CX series drilling choke”.
2.3.2 (2)..All chokes instead of “ PSL-2 (manual ≤5000 psi)” / “ PSL-3 (manual >= 3000 psi)”. (1)Manual choke trims shall be tungsten carbide per the manufacturers API 6A qualification specifications.
Requirements for Manual Gate Valves, Hydraulic Gate Valves and Check Valves:
2.4.1 (2)instead of “ hard faced using Praxair LW-45 or Bodycote CW-15” “ shall be qualified to API 6A Annex F”/ “ Gates and seats (unless stellite overlaid) are to be hard-faced using Praxair : LW-45, GV-50H, GV70D or Bodycote CW-15” ” 10000 and 15000 psi valves shall be qualified to API 6A Annex F”.
2.4.2 (2) Gate valves.. instead of “ PSL-2 or higher (≤5,000 psi) PR-2 (≥10,000 psi) PR-1 or higher (≤5000 psi)” / “ PSL-3 or higher (≤5,000 psi) PR-2 (≥3,000 psi)”.
2.4.3 (2)Check valves.. instead of “ PSL-2 or higher (≤5,000 psi) PR-2 (≥10,000 psi) PR-1 or higher (≤5000 psi)” / “ PSL-3 or higher (≤5,000 psi) PR-2 (≥3,000 psi)”.
2.4.4 Gate and check valves re certification
(3)“The test shall be acceptable if there are no visible leaks” (1)“ printed charts dated, signed and included in the data package”.
CHAPTER C: ACCESSORY WCE EQUIPMENT REQUIREMENTS:
Mud/Gas Separator (MGS) – Gas Busters:
3.3.8 MGS shall be built in compliance with API 12J
i.e pressure gauge should be installed at the top and properly working, (2)instead of “ NOTE: Pressure Relief Valves (PRV’s) are not required on the MGS” / “NOTE: Pressure Relief Valves (PRV’s) on the MGS are a requirement of API 12J and ASME BPVC.VIII.1”.
3.3.12 (1) Annual Drilling Contractor Maintenance of MGS Per API 53:
The equipment owner’s maintenance system shall include annual wall thickness measurements for the MGS. The equipment owner’s maintenance system shall include clearing of debris. The vent lines shall be inspected in accordance with the equipment owner’s maintenance system to ensure they are adequately braced. Water or drilling fluid shall be pumped into the MGS inlet to verify unobstructed flow and proper operation in accordance with the equipment owner’s maintenance system. i.e this requirement is also applicable in WCM 6 as it states clearly in 1.1.1 “Maintenance, repair and PM Schedules shall be as required in API 16AR and API 53 latest editions and Saudi Aramco WCM”.
WCM 6
WCM 7
Full Opening Safety Valves:
3.4.4Full Opening safety valves (2) instead of “ … it is recommended / “ Safety valves shall undergo OEM inspection every two years”.
3.6Trip tanks:
3.6.3 There shall be two (2) independent measuring devices
(1) “ Both devices will be always maintained by the drilling contractor and in good working order”.
3.8 BOP Test Plugs & Cup Testers:
3.8.2 Cup testers
(3) “Cameron Type ‘F’ cup testers are the only approved model”.
3.10 Drill Pipe Float Valves:
3.10 Drill pipe float valve…except when planned operations preclude running a float (1) “include but not limited to” Testing, treating, fishing or squeezing.
3.14 Accumulator Control units:
3.14 Accumulator Control Units
(3/2) “There is no re-certification requirement for Accumulator Control Systems or control hoses. However, the. An OEM or OEM Qualified Designee, inspection and function test diagnostics (offsite or onsite) along with NDE and hydrostatic testing of the individual accumulator bottles is required every five years.
All documentation including individual Accumulator Bottle test charts must reside on the rig.” / “Accumulator Control Units, suitcases, and flexible hydraulic lines shall undergo 5-year inspection and testing (unless being replaced with new) by the OEM or OEM licensed designee. All recertification documentation including individual Accumulator Bottle test charts shall reside on the rig.”
3.14.2 Accumulator units design requirements
(2)instead of “All Accumulators and Lines must be manufactured by an API16D Licensed Facility… “ All piping and connections used from the Accumulator Unit to the BOP must be ASME/ANSI SCH 160 or equivalent.”. …” There is no recertification requirement for 16D hoses “ / “ ..The control lines shall meet API 16D requirements for hydraulic and fire testing”. “For 3000 psi control unit, piping and connections used in the control unit and suitcases to the BOP shall be ASME/ANSI SCH 160 or equivalent with derated working pressure of 4275 psi. For 5000 psi control unit, piping and connections used in the control unit and suitcases to the BOP shall be ASME/ANSI SCH XXS or equivalent with derated working pressure of 7125 psi.” “There are no monogram or recertification requirement for 16D hydraulic control hoses therefore, hydraulic flexible and hard lines from the control unit to the BOP shall undergo inspection and pressure testing every 5-years.”
3.14.2 Accumulator PRVS
(2)instead of “These will not fail open causing loss of operating pressure.” / “Fail open regulator valves that allow loss of operating pressure are prohibited.”
3.14.3 Accumulator bottles
(2)instead of “The minimum required pre-charge pressure for a 3000 psi(20.7 MPa) working pressure accumulator unit is 1,200 psi (6.9 MPa) ”The minimum required pre-charge pressure for a 3000 psi(20.7MPa) working pressure accumulator unit is 1,000 psi (6.9 MPa)”.
3.14.5 Accumulator controls …
(3)“During normal drilling operations the HCR valve next to the wellhead will be closed”.
3.14.7 (2)Accumulator Pump System …
(3)“ON SHORE / OFF SHORE i.e requirements changed to be both the same the new paragraph is more clear and better rephrased” Also (1) If using pneumatic pumps as a secondary system the pumps shall be powered by an independent dedicated air system separate from the rig air system, so if rig air is lost. the control unit pneumatic pumps remain operational. On rigs utilizing compressed air, the compressor shall be powered by a different prime mover, or the electric motors for compressors are powered by a system which is independent from the rig primary electrical supply for the pumps. a separate bus. Air pumps. if used, shall be capable of charging the accumulators to 98 % to 100 % of the system RWP with 75 psi (0.52 MPa) air pressure supply. (2)“the air and hydraulic pumps must maintain control system available working pressure between 2,800 psi and 3,000 psi (3K System) and 4,800 psi to 5,000 psi (5KSystem)”.”The air and hydraulic pump on-off pressure and run time settings will be as per OEM specifications”. / “…The cumulative output capacity of the pump system shall be sufficient to charge the main accumulator system from precharge pressure 98% to 100% of the system RWP within 15 minutes between 2,940 psi and 3000 psi (3K System) and 4,900 psi and 5000 psi (5K System). ”The air and hydraulic pump on-off pressure and run time settings will be as per OEM specifications/API 53 specifications”.
3.14.8 Accumulator Pressure Regulator Settings
(2)“All BOP Annular and Shear Blind Ram controls shall have a bypass to route maximum system working pressure to the annular packer and SBR’s.
(1) The driller remote panel shall have a pressure gauge reflecting annular BOP regulator pressure. (this requirement is mandatory for new contract rigs from the release date of this manual.)
3.19 Studs and Nuts
(2) instead of “Bolt sizes 1-7/8” diameter and larger require make-up using hydraulic torque wrenches” / ”Bolt sizes 1-1/2” diameter and larger require make-up using hydraulic torque wrenches”.
CONNECTION BOLTING SIZE & REQUIRED TORQUE VALUES
(1)30”
3.20 (1):API 6A Ring joint Gaskets:
Types R or RX gaskets shall be used on 6B flanges with type R grooves. Only BX gaskets shall be used with 6BX flanges with type BX grooves. NOTE: RX and BX gaskets provide a pressure-energized seal but are not interchangeable. RX gaskets provide additional clearance between the flanges. Ring gaskets have a limited amount of positive interference, which ensures that the gaskets are coined into a sealing relationship in the grooves and therefore RING GASKETS SHALL NOT BE REUSED. Ring gaskets shall be API Monogrammed in accordance with the requirements of API 6A latest edition and marked per Table A-16.
General language modification in WCM 7th edition all the “must” word was replaced with “shall”
Formatting required you can restyle the info in a better way instead o for example writing in each line 7th edition added in page Axx added/modifed/rephrased make it more professional and better technical writing
