BOP Equipment eOJT Assessors Guide Training ProceduresSection 1Training ProceduresBOP Equipment OJT ModulePage: 1.1 Rev. 02: January 2005Training Procedures SheetObjectivesUpon completion of this module, the participant should be able to:1. demonstrate a clear understanding of the role and responsibilities of Transocean BOP equipment operators, and2. perform basic BOP maintenance tasks safely and competently.Training ProcedureCompleting the BOP module should take about sixteen working weeks, depending on the effort put in.The mandatory task list is the basic tool for recording progress, and each item on the list shall be completed before participantscan receive a module certificate. The task list evaluation guide in this assessors guide is to help you assess the competenceof the participants. Some flexibility is permitted, but you must be thoroughly satisfied that the level of skill and knowledgedemonstrated by each participant is consistent with the objectives of this OJ T module. Only when you believe that a participanthas truly achieved the required skill level and knowledge required by each task, should you sign off on it.The suppporting self-study DVD-ROMs, CD-ROMs, books and workbook questions helps participants understand the tasks.The use of these tools is voluntary. Many training participants will find the tools very helpful in providing fundamental knowledge.You can customize the task list according to the requirements of your particular rig.A blank section is provided foryou to addadditional tasks you feel are important and want participants to perform. You cannot, however, delete tasks, except where theydo not apply to your rig.When the participant completes the task list requirements to your satisfaction, and has successfully completed the computer-generated final test, complete and sign a completion notification form (CNF).Also, ensure that the participant fills in theemployee comments section. Then, forward the completed and signed CNF to the regional training center. After receiving theCNF, the training center will complete the participant in the Training Management System. The RSTC will then be able to printamodule certificate from the Training Management System. Keep the completed task list on file at each participants assignedlocation. The training file shall be transferred when the participant is transferred.Task List Evaluation GuideSection 2Task List Evaluation GuideBOP Equipment Task List Evaluation GuidePage: 2.1 Rev. 02: January 20041.2.3.Show how to perform a task-risk assessment for a major BOP related job.Observe participants performing a task-risk assessment for a major BOP related job. This assessment should includeidentifying risks and initialing risk reduction measures. The risk assessment should involve everyone concerned with thejob and should be documented. The assessment should also include: daily THINK drill, permit to work and task specificTHINK procedures. ALARP on reduction measures.Show how to conduct a THINK drill prior to an operation involving the BOP equipment.Observe participants assembling the crew and conducting a THINK drill prior to an operation involving the BOP equipment.The task should follow rig-specific procedures and use START observations.Reference HS&E Manual 9.30000.Show how to use personal protective equipment when working on the BOP equipment.Observe participants using PPE while performing BOP tasks. Ensure that they use proper safety harness and fallarrestor equipment when working at heights and that they don work vests and antifall devices when working over water(standby boat in attendance if applicable). When working over water a permit to work must be issued.Reference HS&E Manual 9.30000.Explain and show the safety precautions to take when working in the cellar or spider deck area, if applicable.Observe participants using safety precautions, such as conducting a task-risk analysis, START process, zoning off thework area, ensuring the presence of a standby boat when working over water, and procuring work permits. No trippingand slipping hazards should be present, such as oily or muddy grating or out-of-place tools in the cellar or spider deckarea.Explain and show the safety precautions to take when performing high-pressure testing on the BOP equipment.Observe participants using safety precautions, such as procuring a work permit, zoning off a work area, placing warningsigns and barriers, snubbing high-pressure lines, making an announcement on the PA system, and establishing telephoneor radio communication with a third-party operator when using a cement pump or a test pump. Inspect the condition ofall high-pressure BOP hoses and safety lines. Follow safe working practices such as never tightening a leaking fittingunder pressure or never standing directly in front of the bleed-off line when bleeding off pressure.Explain and show the safety precautions to take when working on the accumulator unit.Observe participants working on the accumulator unit while following fundamental safety precautions, such as procuringa work permit, using START process, using RSP, locking out and tagging out, ensuring pressure is bled from thehydraulic lines before disconnecting, and ensuring that persons assigned to the task are qualified for the job.Check the participants work area. It should be clean and orderly. No tripping and slipping hazards should exist, such asan oily or muddy deck area. Make sure that access to the accumulator unit is unhindered in case of an emergency.Report any damaged or bent grating, steps, or handrails around the accumulator unit and deck area.Reference CD-ROM 61.10010.Show how to determine H2S certification of the BOPs and related well-control equipment.Participants should confirm whether the BOPs and well-control related equipment is H2S certified. If it is, ensure that theBOPs and related equipment certificates state that all surfaces exposed to wellbore fluids are H2S rated and meetNACE-MR-0175 (National Association of Corrosion Engineers) requirements.4.5.6.7.BOP Equipment Task List Evaluation GuidePage: 2.2 Rev. 02: January 2005Explain why BOP components should never be field welded unless performed under controlled conditions.Ask participants why BOP components should never be field welded unless performed under strictly controlledconditions.Any heating of the BOP material without the proper specifications for that material will alter the metal properties thatcould lead to catastrophic failure of the component.Ask participants to explain the controlled conditions for welding on BOP equipment.Certified welder, manufacturers approved welding procedure, availability of heat-treating and stress-relieving equipment.Never allow welding of pads on the annular to enable hydraulic jacking open of cap.Reference IADC Drilling Manual 10.10010 and CD-ROM 61.20070.Explain and show the safety precautions when using BOP lifting gear.Ask participants to explain the safety precautions when using BOP lifting gear.All lifting gear used for BOP maintenance, such as the removal of ram blocks or bonnets, should be properly maintainedand the certification and color-coding kept up-to-date. This maintenance includes items such as pad eyes, eyebolts,slings, shackles, chain hoists, turnbuckles, and air winches. Visual inspection should be performed before use. Liftinggear should be used within its rated capacity. Beware of the change in loading when lifting equipment at an angle. Knowthe full load of all the components to be lifted. Company policies on lifting should be followed.Explain and show the safety precautions to take when using BOP power tools that are designed specifically forthe BOPs.Observe participants practicing safety precautions when using BOP-specific power tools such as the hydraulic torquewrench or pneumatic impact wrench. Ensure that these power tools are properly maintained and that they are function-tested before use. The tools should also be properly lubricated before use. Participants should be aware of pinch pointswhen using the hydraulic torque wrench. Ask them to set the hydraulic pressure for a specific torque (the gauge shouldbe certified). They should explain how the torque wrench works.Ensure that securing devices are used on impact wrench air connections. Tie off the tool(s) when working at heights orover water. Ensure that socket and extensions are secured to the tool, and use the correct size socket for the size of bolt.Ensure that the power tool components are working within their rated limits and the regulators are properly set. Observeparticipants cleaning, maintaining, and storing BOP-specific power tools. This should include running lubricant throughthe air wrench and emptying the water trap in the air line. Tools should be stored at designated locations. Damaged toolssuch as worn impact sockets should be replaced immediately.Show how make up a flexible hose assembly.Participants should select compatible hoses and fittings and assemble using of the rigs crimping machine. Hose andfitting must match (diameter & pressure rating) and crimping dies must be the correct type for the hose assembly.Participants should explain the difference between skive and no-skive hose.Show how to clean, maintain, and store BOP hand tools that are used only on the BOPs.Observe participants cleaning, maintaining, and storing BOP-specific hand tools. Tools should be clean and stored atdesignated locations. Damaged tools such as worn pipe wrench jaws, splayed spanners, worn impact sockets, roundedhammer wrenches, and broken sledgehammer handles should be replaced immediately. Always use the correct tool forthe job. Clean and function-test the wellhead grease packing tool.Show how to clean, maintain, and store wellhead tools.Observe participants cleaning, maintaining, and storing wellhead tools. All wellhead tools should be cleaned and inspectedafter use. Any tool with minor damage shall be reported so that it can be properly repaired. Any tool with major damagemust be reported and replaced. Tools such as wear bushing and running tools, casing, packer, seal assembly runningtools, and plug- and cup-type testers must be lubricated, fitted with required protectors, and stored in their designatedplace. Use lubrication bath for storage where possible.10.9.8.11.12.13.BOP Equipment Task List Evaluation GuidePage: 2.3 Rev. 02: January 2004Show how to clean, maintain, and store BOP rams and elastomers.Observe participants cleaning, maintaining, and storing BOP rams and elastomers. Go to the storeroom with participantsand inspect rams and elastomers. Rams should be greased and stacked in sets according to their size. Elastomersmust be stored in a temperature- and humidity-controlled environment, fully wrapped, and sealed. They should makesure that all new elastomers are marked with shelf life (use by date).Reference Hydril Blowout Preventers 9.00601 and DVD-ROM 20.0406.Describe your rigs current BOP stack including its pressure rating, connection type, and size.Participants should define the blowout preventer stack specifications. Ask them to verify its size, either by physicallymeasuring it or reading installation specifications.Ask a question such as: What is the size of BOP, its pressure ratings, and the connections in use?Reference IADC Drilling Manual 10.10010, Drilling Data Handbook 10.12010, and CD-ROM 61.10160.Describe your rigs current BOP stack configuration and its operational advantages and disadvantages.Ask participants to describe the rigs BOP stack configuration. They should explain operational advantages and dis-advantages during functions such as bleed-off between rams, circulating procedures for specific well-control events,spaceout for hang off, and clearances for tool joints during shearing, stripping, and BOP ram replacement or repairs.Reference IADC Drilling Manual 10.10010 and Drilling Data Handbook 10.12010.Explain how to run and retrieve the BOP stack on your rig.Ask participants to describe the BOP run & retrieve procedures on the rig. This explanation should include a full descriptionof a stack, as well as the installation of wellheads. The description should also include rig-specific lifting equipment andhoists, tools, ring gaskets, lubricants, scaffoldings, all safety procedures required including job-risk analysis, and permits.Explain and show how to install the diverter and flow line, if applicable.Ask participants to describe how to install the diverter and flow line. Observe them carrying out these operations. Ensurethat all safety precautions are followed such as job risk analysis and permits, clear verbal and visual communications,slinging and hoisting procedures, and use of safety belts and inertia reels.Explain and show how to install BOPs on the test stump.Ask participants to describe how to install a BOP on the test stump. They should describe the use of rig-specific liftingequipment and hoists, tools, ring gaskets, lubricants, scaffoldings. Ensure that all safety precautions are followed suchas job risk analysis, and permits. Observe participants installing the BOP on the test stump.Explain the operating sequence of a ram-type BOP hydraulic circuit.Ask participants to explain the sequence of events when a ram BOP function is activated from the remote panel. Theyshould trace functions on a schematic and at the unit.Ask participants to describe the normal and maximum ram operating pressures and closing ratio. They shoulddescribe the closing ratio and what effect it has on maximum operating pressure relative to wellbore pressure.If the wellbore pressure exceeds a certain value, the operator may need to increase the closing pressure to close therams.Reference Blowout Prevention book 2.30330, Cameron Type U Blowout Preventer book 9.22001, DVD-ROM20.0418, and CD-ROM 61.10130.16.15.14.17.18.19.20.BOP Equipment Task List Evaluation GuidePage: 2.4 Rev. 02: January 2005Identify and explain the use of different ram types.Ask participants to describe the different ram types and their application. This description should include variable borerams, blind rams, shear blind rams, fixed pipe rams, and dual-string fixed pipe rams.Ask questions such as: Which grades of pipe can be sheared using the shear rams at normal operating pressure andmaximum operating pressure? How do you apply maximum operating pressure to the shear rams?Using the bypass valve. What bonnet types are used on your rigs BOP shear rams?They are either standard or large bore. What is the difference between standard and large bore bonnets?Standard bonnets have a cylinder liner. Large bore bonnets do not have a cylinder liner, which gives a larger operatingarea. What is the effect of wellbore pressure on the sealing element once the rams are closed?The rams are wellbore-pressure energized. Wellbore pressure assists in sealing and keeping the rams closed. Note thatthe rams seal pressure from the bottom only. Because pressure is sealed from the bottom only, it is vitally important thatrams be installed correctly.Reference Blowout Prevention book 2.30330, DVD-ROM 20.0418, and CD-ROMs 61.10130 and 61.20130.Explain the purpose of the weephole in the ram shaft packing area of the bonnet, where applicable.Ask participants to explain the purpose of the weephole in the ram shaft packing area of the bonnet.In the event of ram shaft seal failure, the weephole prevents wellbore fluid from entering the operating cylinder, openingthe rams, and possibly causing major damage to the bonnet.On rigs with surface stacks so equipped, participants should explain and show how to energize the ram shaft emergencypacking mechanism in the event of main ram shaft failure and resulting visible leakage from the weephole.Reference Cameron Type U Blowout Preventer book 9.22001 and CD-ROMs 61.10130 and 61.20130.Identify different types of ram elastomers available and describe their application.Ask participants to describe some different types of common ram elastomers available and their application.Naturalrubber,neoprene,nitrile.Naturalrubberisusedwithwater-basedrillingfluids,Neoprenerubberisforlowtemperature operating service and oil-base drilling fluids, Nitrile rubber is for use with oil-base or oil-additive drillingfluids.Participants should show data book/catalogue identifying all the different types of elastomers available for specialapplications. They should describe the shelf life for elastomers in use on the rig.Ask a question such as: What type of elastomers are installed on the ram-type BOPs on your rig?Reference Blowout Prevention book 2.30330, DVD-ROM 20.0418, and CD-ROMs 61.10130 and 61.20130.Explain and show the operating sequence of a ram-type BOP locking system.Ask participants to describe and show the operating sequence of the ram-type BOP locking system on their rig.Reference Blowout Prevention book 2.30330, Cameron Type U Blowout Preventer book 9.22001, DVD-ROM 20.0418,and CD-ROMs 61.10130 and 61.20130.23.22.21.24.BOP Equipment Task List Evaluation GuidePage: 2.5 Rev. 02: January 2004Explain and show how to perform PMS tasks on a ram-type BOP.Observe participants performing PMS tasks on the ram-type BOPs. These tasks should include opening bonnets, changingrams, inspecting bonnet seal grooves, replacing bonnet seals, replacing ram packers and top seals, inspecting bonnets,measuring ram cavities and ram blocks, and ensuring that measurements are within specifications. Lubricate the ramcavity and ram block. Close the bonnets. Apply correct lubricant to bonnet bolts and torque bolts to the correct value.Ask participants to explain how to strip down, inspect, and rebuild the bonnet. These procedures include removing thebonnet from the BOP body, inspecting all internal parts, replacing the seals, rebuilding the bonnet and testing it, andrefitting the bonnet to the BOP body.Participant to explain all safety procedures to be followed when performing the PMS tasks.Participant to show the rig specific procedure (RSP) if applicable.Reference Blowout Prevention book 2.30330, Cameron Type U Blowout Preventer book 9.22001, DVD-ROMs 20.0405and 20.0418, and CD-ROMs 61.10130 and 61.20130.Explain and show how to perform PMS tasks on the ram-type BOP locking system.Observe participants performing PMS tasks on the ram-type BOP locking system. In case of a screw-thread lock, theyshould clean the threads using a wire brush, inspect the thread condition, lubricate the threads, and function test thelocking system. On internal systems such as Wedgelock, MPL, Ultralock, or Poslock, participants should give a fullexplanation of system operation and carry out related PMS tasks. The rams should be tested by closing on a test joint,venting the closing pressure to zero, and applying full wellbore pressure to confirm the correct operation of the locks.Participant should explain all safety procedures to be followed when performing the PMS tasks. Participant should showthe rig specific procedure (RSP) if applicable.Reference CameronTypeUBlowoutPreventer book 9.22001, DVD-ROMs 20.0405 and 20.0418, and CD-ROMs61.10130 and 61.20130.Explain and show the operating sequence of an annular BOP hydraulic circuit.Ask participants to explain the sequence of events when an annular BOP function is activated from the remote panel.They should trace the function on a schematic and at the unit.Ask participants to describe normal and maximum annular operating pressures and closing and opening times. Askthem what precautions to take prior to running the casing.Ask questions such as: What is the recommended closing pressure to avoid collapsing the casing in use?What is the recommended closing pressure during stripping operations to avoid excessive wear on the packer element? How does the annular packing element work?The response should include whether it is wellbore energized, slightly wellbore energized, or not energized. They shouldalso explain the use of surge bottles and the effects on the element when it is closed on open hole.Reference Blowout Prevention book 2.30330, Hydril Blowout Preventers book 9.00601, DVD-ROMs 20.0414 and 20.0416,and CD-ROM 61.10030.25.26.27.BOP Equipment Task List Evaluation GuidePage: 2.6 Rev. 02: January 2005Explain and show how to perform PMS tasks on an annular BOP.Observe participants performing PMS tasks on the annular BOP. These tasks may include opening the cap, inspectingthe element and changing it if necessary, removing and inspecting the piston, replacing seals, and inspecting cylinderbores. Rebuild, function test, and pressure test the annular BOP after it is maintained. Participants should explain allsafety procedures to be followed when performing the PMS tasks and show the rig specific procedure (RSP) if applicable.Reference Hydril Blowout Preventers book 9.00601, DVD-ROMs 20.0414 and 20.0416, and CD-ROM 61.10030.Describe different types of annular packing elements and their application.Ask participants to describe the different types of packing element material available and their application.Packing elements are designed for oil-base muds (OBMs), water-based muds (WBMs), and for low and high temperatures.Askquestionssuchas: Whattypeofpackingelementwouldbeusedinanoil-basemudsystematlowtemperatures?Nitrile rubber can be used in an OBM but at standard operating temperature. Nitrile becomes brittle at temperaturesbelow -7 degrees Celsius or 20 degrees Fahrenheit. Neoprene becomes brittle below -35 degrees Celsius or -30 degreesFahrenheit. How would you identify the different types of packing elements?Neoprene has a green colored band and serial number with the suffix N or CR. Nitrile rubber has a red colored band andthe suffix S or NBR. Natural rubber is an all black unit with the suffix R or NR.Reference Hydril Blowout Preventers book 9.00601, DVD-ROMs 20.0414 and 20.0416, and CD-ROM 61.10030.Explain and show how a manual BOP choke line gate valve operates.Ask participants to explain how a manual BOP choke line gate valve operates.It is a floating gate with a back-seating stem.Ask participants to explain the principle of the floating gate. As pressure is applied, pressure pushes the gate across thebody (the gate floats) to seal against the seat and seal ring. Therefore, the stem must be backed off a quarter turn afterfully closing.Ask participants to explain the principle of the back-seating stem. A device within the valve provides sealing of the stempacking area; this sealing allows the stem packing to be changed while the valve is under pressure. To energize theback-seating stem, the valve must be fully closed rather than backed off a quarter turn.On rigs with subsea stacks, explain failsafe valve operation.Reference DVD-ROM 20.0419 and CD-ROM 61.20080.Explain and show how to perform PMS tasks on a manual BOP choke line gate valve.Observe participants stripping down the valve, inspecting gate and seats, checking the bodys internal sealing surfaces,replacing seals and worn parts, reassembling the valve, and testing it. Participants should demonstrate the rig specificprocedure and all safety precautions when performing the PMS tasks.On rigs with subsea stacks, show how to perform PMS tasks on failsafe valves.Reference DVD-ROMs 20.0405 and 20.0419 and CD-ROMs 61.20080 and 61.20090.28.29.30.31.BOP Equipment Task List Evaluation GuidePage: 2.7 Rev. 02: January 2004Explain and show how a hydraulic (HCR) BOP choke line gate valve operates.Ask participants to explain the sequence of events when a BOP choke line gate valve operating function is activatedfrom the remote panel. They should trace the function on a schematic and at the unit.Ask participants how to identify an internal hydraulic leak in the valve actuator. Remove the inspection plugs on theaccumulator tank and check for fluid leaking from the return line through the 3-position 4-way valve.Reference Blowout Prevention book 2.30330 and DVD-ROM 20.0419.Explain and show how to perform PMS tasks on a hydraulically operated BOP choke line gate valve.Observe participants stripping down the valve, inspecting the gate and seats, inspecting the bodys internal sealingsurfaces, stripping down and inspecting the hydraulic actuator, replacing seals and worn parts, reassembling the valve,and testing it. Participant should explain all safety procedures when performing the PMS tasks.Reference DVD-ROM 20.0419 and CD-ROM 61.20040.Explain and show how a choke & kill line non-return valve operates.Participants should explain and show how a choke & kill line non-return valve operates and why it is used. The valve iseither a spring-actuated gate-and-seat valve or a ball-and-seat one-way check valve. The purpose of either type is toprevent over pressurizing such surface equipment as the standpipe, mud pumps, and surface lines.Ask participants to explain when a check valve should be removed from the line and why it should be removed. Thevalve is removed only during BOP testing and it is removed to maintain it and check that it is operating properly. It is vitalto always have this valve in place and functioning properly; otherwise, well pressure could be applied to such surfaceequipment as the standpipe, pumps, and surface lines, which could be catastrophic. It is also important to note the flowdirection of the valve to ensure that it is reinstalled properly after it is maintained or repaired.Explain and show how to perform preventive maintenance on a choke & kill line non-return valve.Observe participants stripping down the valve, inspecting the gate and seats, inspecting the bodys internal sealingsurfaces, replacing seals and worn parts, and reassembling and testing it. Participants should explain all safety precautionswhen performing the PMS tasks and show the rig specific procedure (RSP) if applicable.Explain and show the connections of the high-pressure flexible lines from the BOP to the choke manifold andkill line.Observe participants tracing the high-pressure flexible lines from the BOP to the choke manifold and kill line. Theyshould explain how the system works. Any leaks or possible wear points should be noted and corrected. Check toensure that the hoses are supported adequately. Verify the pressure ratings of all components including each union andhose. Ask participants to show the certification of the hose.Reference CD-ROM 61.20040.Explain and show the choke manifold valve alignment options.Observe participants aligning the choke manifold for specific operations such as: drilling, well-kill operations through oneor two chokes, using a degasser, flaring gas through the flare line, and using a stripping tank. Ask participants why it maybe necessary to circulate through two chokes simultaneously. If well pressure becomes high enough, it may be necessaryto remove kick fluids through two chokes to maintain proper bottomhole pressure. Ask participants what modificationsare required for high-temperature operation on the rig. Install a glycol injection system, install temperature recorders,change valve stem packing to high-temperature material. Note that it is important to control the temperature of the mudto keep the hydrates stable.Reference CD-ROM 61.20040.32.33.34.35.36.37.BOP Equipment Task List Evaluation GuidePage: 2.8 Rev. 02: January 2005Explain and show how to perform PMS tasks on choke manifold valves.Observe participants stripping a gate valve, inspecting the gate and seats, checking the bodys internal sealing surfaces,replacing seals and worn parts, and reassembling and testing the valve. They should take care to properly reinstallTeflon seals. Identify lead target flanges on the manifold and observe participants inspecting and removing the targetflange. Ask participants why a hole should be drilled through the center of the lead target. A hole should be drilled throughthe center of the lead plug to allow venting off any pressure trapped behind the plug. Participants should explain allsafety precautions when performing the PMS tasks and show the rig specific procedure (RSP) if applicable.Reference CD-ROM 61.20040.Explain and show how to perform PMS tasks on choke manifold sensors and gauges.Participants should describe how each sensor works. They should disassemble the diaphragm. They should be able toidentify whether the valve is trimmed for H2S service and explain why it is important. They should show current calibrationcertification of all gauges. Participants should also be aware of any variations in the readouts of the choke manifoldsystem gauges. Participants should explain all safety precautions when performing the PMS tasks and show the rigspecific procedure (RSP) if applicableReference CD-ROM 61.20040.Explain and show the operating sequence of a remote choke hydraulic circuit.Ask participants to explain the sequence of events when a remote choke valve is activated from the remote panel. Theyshould trace functions as follows: the hydraulic valve is actuated, which allows regulated hydraulic fluid to flow to theremote choke actuator. Note the time it takes to operate the valve from the fully open to fully closed positions. Observeparticipants adjusting the operating speed of the choke. Ask participants to explain how the choke-position indicatorworks. Participants should show and explain how to activate the choke in the event of a power failure. Participantsshould demonstrate how to use the hand-operated hydraulic pump to operate the choke.Reference Drilling Data Handbook 10.12010, DVD-ROM 20.0409, and CD-ROM 61.20040.Identify the different types of BOP flange-and-hub connections and explain the use of each.Ask participants to identify the flange-and-hub connections on the rigs BOPs. They should identify which connectionsarestudded,bolted,clampedhub,face-to-face,nonface-to-face,ring-groovetype,andring-gaskettype. Torquerequirements for each connection and the lubricant used on the fastening mechanism should be described.Ask questions such as: What is the correct torque for the through-bore connections on your BOP? What is actually happening when you torque up (tighten) a connection?The bolts stretch, gaskets compress, and the hub faces are preloaded. How often should a ring gasket be used?Use it only once. What effect does the wrong lubricant have on the preload applied to the connection?It causes incorrect preload that could lead to separation of the components under pressure, which, in turn, could washout the ring groove and ring gasket. Why is it important to periodically check the torque on flange connections?Vibration and/or improper line support may cause the connection to work loose, which causes a leak. What lubricant should be used on the ring groove and gasket?Never use any type of lubricant.Reference Drilling Data Handbook 10.12010, DVD-ROM 20.0409, and CD-ROM 61.20040.38.39.40.41.BOP Equipment Task List Evaluation GuidePage: 2.9 Rev. 02: January 2004Identify the different types of ring gaskets and explain their use.Ask participants to identify and show where the following gasket types are used on the rig:- R type gasket. Nonpressure-energized with nonface-to-face hubs, octagonal or oval.- RX type gasket. Pressure-energized face-to-face or nonface-to-face hubs.- BX type gasket. Pressure-energized, face-to-face hubs.Ask participants to identify the pressure rating for each gasket.Reference Drilling Data Handbook 10.12010.Explain and show how to perform BOP stack and choke manifold pressure and function tests.Observe participants performing BOP and choke manifold pressure and function tests. Ask them to explain the use ofeach component in the test assembly. Plug-type tester, cup-type tester, and test pump and chart recorder. Observeparticipants completing the BOP and choke manifold test forms. Confirm that the test follows the rig-specific procedures.Participant to explain all safety procedures to be followed when performing the tests.Ask a question such as: What is the purpose of the low-pressure test?To identify equipment problems such as worn ram cavities that may seal under high-pressure situations only. A low-pressure test should always precede a high-pressure test.Explain and show how to perform PMS tasks on BOP test equipment.Observe participants performing PMS tasks on equipment such as plug-type tester, cup-type tester, and test pump andchart recorder. They should show how to replace seals on plug and cup testers, ensure that the port is open on plugtesters, and calibrate the chart recorder if required. Participants should explain all safety precautions when performingthe PMS tasks and show the rig specific procedure (RSP) if applicable.Show how to rig up Chiksans for high-pressure operations and perform PMS tasks on them.Observe participants rigging up Chiksans for high-pressure operations. They should be properly secured. All rig-specificsafety procedures should be followed. Observe strip down, inspection, and rebuild of a Chiksan swivel joint. High-pressure Chiksan lines shall be snubbed at each joint. Participants should explain all safety precautions when performingthe PMS tasks and show the rig specific procedure (RSP) if applicable.Explain the operation and show how to perform PMS tasks on a plug-type (Lo-Torq) valve, if applicable.Ask participants to explain how the plug-type (Lo-Torq) valve works. Observe disassembly, inspection, seal change, re-assembly, and function and pressure testing. Ensure that only correct high-pressure grease is used in the valve. Participantsshould explain all safety precautions when performing the PMS tasks and show the rig specific procedure (RSP) ifapplicable.Explain the operation and show how to perform PMS tasks on a Gray-type non-return valve, if applicable.Ask participants to explain how the Gray-type nonreturn valve works. Observe disassembly, inspection, seal change,reassembly, and pressure testing. Participants should explain all safety precautions when performing the PMS tasksand show the rig specific procedure if applicable.Ask participants to give an example of when this valve should be used. Only used in conjunction with full-opening safetyvalve during stripping operation.Reference CD-ROM 61.10010.43.42.44.45.46.47.BOP Equipment Task List Evaluation GuidePage: 2.10 Rev. 02: January 2005Explain the operation and show how to perform PMS tasks on IBOPs.AskparticipantstoexplainhowtheupperandlowerIBOPswork.Observedisassembly,inspection,sealchange,reassembly, function, and pressure testing. Participants should explain all safety precautions when performing the PMStasks and show the rig specific procedure if applicable.Ask a question such as: When should this valve be used?It is used anytime a backflow is expected or encountered up the drill string. It is not designed to be used as a mud savervalve.Reference CD-ROM 61.10010.Explain the operation and show how to perform PMS tasks on a drop-in valve (DIV) and landing sub.Ask participants to explain how the drop-in valve (DIV) works. A special landing sub is installed in the drill string near thebottom of the string. The valve is dropped into the drill string and pumped down to the sub. There, it seats in the sub andprevents flow up the drill string. Observe disassembly, inspection, seal change, reassembly, function, and pressuretesting. Participants should explain all safety precautions when performing the PMS tasks and show the rig specificprocedure (RSP) if applicable.Ask a question such as: When should this valve be used?It is used anytime a backflow is encountered up the drill string and there is a landing sub installed in the drill string.Ensure there are no ID restrictions in the drill string above the landing sub.Reference CD-ROM 61.10010.Explain the operation and show how to perform PMS tasks on a drill string float valve.Ask participants to explain how the drill string float valve works. It is installed in the drill string, usually just above the bit.Normally, it is open so that drilling fluid can flow down the string, through the valve and bit and up the annulus. Should akick occur, this back-pressure in the drill string causes the valve to close and thus prevent flow up the string. Observedisassembly, inspection, seal change, and reassembly. Participants should explain all safety precautions when performingthe PMS tasks and show the rig specific procedure (RSP) if applicable.Ask questions such as: When should this valve be used?It is often used when drilling top hole prior to setting surface casing or anytime the posted well-control plan is to divert. Itcan also be used in deeper, small diameter sections of the hole. The float valve prevents sudden influx entry in the drillstring and prevents back flow of cuttings plugging bit nozzles. Explain the purpose of a ported float.It allows reading SIDPP.Reference CD-ROM 61.10010.Identify different types of hammer unions and show how to perform PMS tasks on them.Ask participants to identify the hammer unions used on the rig. They should describe the union type, its size, and itsmanufacturer. They should also describe the pressure rating and sealing mechanism. Observe participants inspectingthe hammer union locks, threads, and sealing surfaces; also, observe them replacing seals.Ask the participants why it is imperative not to mis-match similar union halves.48.49.51.50.BOP Equipment Task List Evaluation GuidePage: 2.11 Rev. 02: January 2004Explain and show how to operate the surface control (accumulator) unit.Ask participants to explain operation of the entire unit.Using a schematic, they should trace all hydraulic and pneumaticcircuits. Ask them to identify the system components such as the fluid reservoir, 3-position 4-way valves, reservoirinspection ports and sight glass, suction shutoff valves, pump suction strainers, the interface between different systempressures, and the remote panel, pumps, intake check valves, outlet check valves, manifold regulator, annular regulator,bypass valve, pressure transducers, pressure switches, accumulator shutoff and bleed-off valves, and pressure manifolds.Reference DVD-ROM 20.0409 and CD-ROM 61.10110.Explain and show how to perform PMS tasks on the surface control (accumulator) unit.Ask participants to explain the procedure for isolating an accumulator bank to change a bladder. Observe participantschecking nitrogen precharge and charging an accumulator bottle as required. Participants should show how to adjustgland packings on pumps, adjust triplex and air pump pressure switches, reset the regulators, calibrate the gauges, andadjust transducers. Participants should explain all safety precautions when performing the PMS tasks and show the rigspecific procedure (RSP) if applicable.Reference DVD-ROMs 20.040820.0413 and 20.0417.Explain the pressure ratings, connection types, and applications of BOP hydraulic hose assemblies.Ask participants to identify the BOP hydraulic hoses by pressure rating, construction, crimp fitting style (skived ornonskived), and crimping procedure. Participants should show crimping chart for use with the rigs crimping machine.They should also describe hose inspection procedure and identify any faults that they may find.Reference Vickers Industrial Hydraulics Manual 10.05010.Show how to read and interpret accumulator unit hydraulic and pneumatic schematic symbols.Ask participants to read and interpret accumulator unit hydraulic and pneumatic schematic symbols such as pumps,check valves, motor, 3-position 4-way manipulator valve, regulators, flowmeter, pneumatic and hydraulic lines, andpressure switches.Reference CD-ROM 61.20050.Explain and show how to troubleshoot surface BOP control unit and remote panel problems.Ask participants to troubleshoot hypothetical surface BOP control unit and remote panel malfunctions involving itemssuch as the transducers, pressure switches, and battery banks.Ask questions such as: You press a function on the drillers remote BOP control panel and nothing happens. Whatcould be wrong?You press a function on the drillers remote BOP control panel and the function light turns on but nothing happens to thepressure gauges. What could be wrong?You press a function on the drillers remote BOP control panel and the function light doesnt turn on but pressure gaugesregister a drop. What could be wrong?Reference DVD-ROM 20.0410.52.53.54.55.56.BOP Equipment Task List Evaluation GuidePage: 2.12 Rev. 02: January 2005Show how to calculate the volume of usable fluid in the accumulator bottles.Observe participants calculating the usable fluid in the accumulator bottles using Boyles law. Confirm sufficient capacityon your rig to meet Transocean well-control manual requirements. Reference the Transocean workbook titled AccumulatorUnit Bladder Replacement and Precharge and/or the Well Control Manual.Reference Accumulator Unit Bladder Replacement and Precharge book 9.20001 and DVD-ROM 20.0404.Explain the importance of maintaining the quality of BOP fluid correctly.Ask questions such as: What maintenance should be carried out on the BOP control system fluid?Keep it clean and free of contaminants and change strainers and filters on a regular basis. Follow fluid analysis proceduresand replace when required. Why is it important to maintain the BOP fluid correctly?The fluid comes into contact with all internal surfaces of all components of the BOP system. A poorly maintained systemcan cause damage to seals and sealing surfaces leading to malfunction of equipment.Explain how to set the accumulator unit pump pressure switches.Ask participants to explain the required settings of the triplex and air-operated pumps. For example, triplex pumpsshould kick in at 90 percent of maximum working pressure (2,700 psi) and kick out at 3,000 psi. Air pumps should kickin at 2,650 psi and kick out at 2,950 psi.Reference CD-ROM 61.20050.Explain the diverter system operation on your rig.Ask participants to explain the sequencing of the diverter and associated valves.Ask questions such as: What is the purpose of the diverter system?To divert the flow of wellbore fluids away from the rig. When should a diverter system be used?When shallow gas is encountered.Reference Blowout Prevention book 2.30330, DVD-ROM 20.0407, and CD-ROM 61.10160.Explain how to perform PMS tasks on the diverter assembly, piping, valves, and controls.Observe participants performing PMS tasks on the diverter assembly, piping, valves, and controls. Ask them to explainhow to change the diverter packer and carry out wall thickness checks on piping. Also, they should service and functiontest the diverter valves. Participants should explain all safety precautions when performing the PMS tasks and show rigspecific procedures.Reference DVD-ROM 20.0407.Explain how a rotating head operates, if applicable.Ask participants to explain the basic principles of the rotating head and when it is used.A rotating head is an annular preventer which, through a bearing and seal arrangement, allows the head to rotate whiledrilling underbalanced.Explain and identify the wellhead system and components on your rig.Ask participants to identify the components of the wellhead system in use on the rig and explain their function. Theyshould identify the high-pressure wellhead, casing hangers, seal assemblies, and wear bushings.Reference CD-ROM 61.20060.57.58.59.60.61.62.63.BOP Equipment Task List Evaluation GuidePage: 2.13 Rev. 02: January 2004Explain how the BOP handling system and work platforms operate and show how to rig them up.Ask participants to explain how the BOP handling system works. Their explanation should include the load capacity, thetype of system, and the operation of the system. Observe participants performing PMS tasks on the BOP handlingsystem. Tasks should include servicing the load cell and lubricating the hoist mechanism and the track. Observe participantsperforming PMS tasks on the work platform. These tasks should include checking the grating for damage or corrosion,checking guard chains, and checking handrails. Participants should explain all safety precautions when performing thePMS tasks and show rig specific procedures.Show how to verify BOP equipment certification.Ask participants to show you the file certification sheets for BOP components such as rams, choke and kill hoses, andthe annular preventer. Certification documents are contained in the PMS central filing system.Explain basic coiled tubing BOP operations.Ask participants to explain basic coiled tubing BOP operations. They should explain when and how to shut in the well incase of an emergency. Participants should explain all safety precautions when performing the PMS tasks and show rigspecific procedures.Explain basic wireline BOP operations.Ask participants to explain the basic wireline BOP operations. They should explain how to install the shooting nipple, theBOPs, and test the assembly. Ask when and how to shut in the well in case of an emergency. Participants should explainall safety precautions when performing the PMS tasks and show rig specific procedures.Explain how to use the annular BOP for stripping operations.AskparticipantstostatetheprecautionstotaketopreventtheannularBOPfromexcessivewearduringastripping operation.Reduce closing pressure to the minimum required to maintain the seal. There should be a slight leakage of wellbore fluidto aid in lubrication. It may be worthwhile to manually lubricate the pipe as it passes through the rotary. File smooth anymajor burrs on the tool joints and pipe body that may damage the annular packing element as it passes through. Monitordisplacement during stripping.Participants should explain all safety precautions when performing the PMS tasks and show rig specific procedures.Explain how to use the BOP rams for stripping operations.Ask participants to state the precautions to take to prevent the BOP pipe ram packers from excessive wearduring a stripping operation.Reduce closing pressure to the minimum required to maintain the seal. Manually lubricate the pipe as it passes throughthe rotary. File smooth any major tong die burrs on the pipe body that may damage the ram packers as it passes through.Monitor displacement during stripping.Ask participants to state the procedure for ram-to-ram stripping in the hole.Reduce ram operating pressure. Close upper rams. Strip tool joint to the top of upper rams. Close lower rams. Bleed offthe pressure between the upper and lower rams. Open the upper rams. Strip the tool joint down to the top of the lowerrams. Close the upper rams. Open the lower rams. Repeat the process. Monitor displacement during stripping.Participants should explain all safety precautions when performing the PMS tasks and show rig specific procedures.64.65.66.67.68.69.Workbook Questions and AnswersSection 3Workbook Question & AnswersBOP Equipment OJT ModulePage: 3.1 Rev. 02: January 2005Workbook Questions and AnswersBOP Equipment OJ T Module workbook questions are provided to enhance learning on subjects covered by the task list.Workbook questions should be completed as fully as practical, with local translation if necessary.Completing the workbooks does not exempt a participant from the mandatory task list.Participants should achieve a score of 70% or more on each workbook. Where scores fall below 70%, the participant shouldreview the corresponding books, DVD-ROMS, and/or CD-ROMs. The supervisor should coach the participant on any weakpoints to ensure that material is understood.The following workbooks are provided in this section:Workbook Page Numbers1. Vickers Industrial Hydraulics Manual 02052. Rotary Drilling Blowout Prevention 06073. Cameron Ram-Type U Blowout Preventer 08094. Rucker Ram-Type Blowout Preventer 10115. Hydril Ram BOP 12136. Hydril GL Annular Preventer 14157. Accumulator BottlesBladder Replacement and Precharge 1617BOP Equipment OJT ModulePage: 3.2 Rev. 02: January 20051. A fundamental law of physics states that energy can neither be created nor destroyed.A. TrueB. False2. What determines the speed of an actuator?A. Its sizeB. Rate of oil flow into itC. both A and B aboveD. none of the above3. Hydraulic fluid in a working system contains energy in two forms: kinetic and potential.A. TrueB. False4. Viscosity is the measure of a fluids ______A. density.B. water content.C. weight.D. resistance to flow.5. Demulsibility is the ability of a fluid to be anticorrosive.A. TrueB. False6. Nitrile seals can be used in the temperature range of ______A. -10 degrees F to 120 degrees F.B. -40 degrees F to 250 degrees F.C. -20 degrees F to 60 degrees F.D. -0 degrees F to 200 degrees F.7. A breather assembly on a reservoir should be ______A. large enough to allow draining of the reservoir.B. threaded to allow plugging.C. large enough to handle air flow required.D. large enough to allow filling of the reservoir.8. Hydraulic systems are 100% efficient in controlling temperature.A. TrueB. False9. There are ______ types of particulate induced failures.A. oneB. twoC. threeD. four10. A filter rated at ten (10) microns would trap particles ______A. 10 microns in size or smaller.B. 10 micron size only.C. 10 microns in size or larger.D. none of the aboveVickers Industrial Hydraulics Manual - Workbook AnswersBOP Equipment OJT ModulePage: 3.3 Rev. 02: January 200511. Filter bypass valves ______A. will eliminate the possibility of element collapse if the element becomes clogged.B. will eliminate the need to change a filter.C. are found in all filters.D. will allow continuous flow if the element collapses due to clogging.12. Double-acting cylinders are really found in industrial hydraulics.A. TrueB. False13. Compared to a straight check valve, the design of a right angle check valve allows ______A. higher flows with less pressure drop.B. lower flows with less pressure drop.C. higher flow with large pressure drop.D. higher flow with no pressure drop.14. Rotary valves cannot be used to control a pilot flow in a pilot-operated system.A. TrueB. False15. A pressure compensated flow control valve _______ compensates for pressure changes.A. hydraulicallyB. pneumaticallyC. automaticallyD. electrically16. What electronic components are required in all equipment using proportional control valves?A. Operational amplifiers and floating gate transistorsB. Electrical power supply and electronic controlsC. Bidirectional and Zener diodesD. all of the above17. The voltage drop across a 7-ohm resistance is 70 volts. The power dissipated through the resistance is ______A. 10 watts.B. 70 watts.C. 100 watts.D. 700 watts.18. AC solenoid failure due to heating may occur because of _______A. blocked plunger or armature.B. excessive ambient temperature.C. low line voltage.D. all of the above19. The relief valve______A. is found in virtually every hydraulic system.B. is a normally-closed valve connected between the pressure line (pump outlet) and the reservoir.C. limits pressure in the system to a preset maximum.D. all of the above20. Pressure reducing valves are normally open-pressure controls used to maintain reduced pressures in certainportions of the hydraulic system.A. TrueB. FalseVickers Industrial Hydraulics Manual - Workbook AnswersBOP Equipment OJT ModulePage: 3.4 Rev. 02: January 200521. An unloading relief valve is used in accumulator charging circuits to _______A. limit maximum pressure.B. unload the pump when the desired accumulator pressure is reached.C. both of the aboveD. none of the above22. The four-way directional control valve ______A. is a poppet valve.B. is a shuttle valve.C. provides four flow paths, two at a time.D. is a pilot-operated check valve.23. Cartridge valves must be sized for the highest flow at any one port.A. TrueB. False24. The device that forms the basic element of most amplifier circuits is a ______A. capacitor.B. resistor.C. transistor.D. diode.25. The input impedance of the op-amp is ______A. very high.B. very low.C. equal to the output impedance.D. none of the above26. A current input signal is preferred over a voltage input signal in many process control applications.A. TrueB. False27. Deadband compensation is primarily caused by ______A. malfunction of the op-amp.B. spool overlapping the valve ports.C. overheating of the pressure transducers.D. none of the above28. In normal operation, a proportional valve has ______A. one flow path.B. two flow paths.C. three flow paths.D. none of the above29. In a pilot-operated proportional directional valve, the pilot spool has ______ possible controlling positions.A. oneB. twoC. threeD. four30. In a mechanical servo valve, the part that is connected with the load is the ______A. valve body.B. control handle.C. valve spool.D. all of the aboveVickers Industrial Hydraulics Manual - Workbook AnswersBOP Equipment OJT ModulePage: 3.5 Rev. 02: January 200531. Linearity is the relationship between the valves control flow and its ______A. output flow.B. input signal.C. output signal.D. none of the above32. PLCs are generally programmed in ______A. serial logic.B. parallel logic.C. ladder logic.D. symbolic logic.33. When using an AND logic gate, to get 1 as an output ______A. both inputs should be 0.B. one input should be 0 and another input 1.C. both inputs should be 1.D. any of the above34. The flow capacity of a pump can be expressed as ______A. maximum operating pressure.B. displacement per revolution.C. hydraulic horsepower.D. none of the above35. The volumetric efficiency of a 10-gpm pump delivering 8.5 gpm at 850 psi is ______A. 75%B. 80%C. 85%D. 90%36. In axial piston pumps, the pistons reciprocate perpendicular to the axis of rotation of the cylinder block.A. TrueB. False37. The type of accumulator that works at constant pressure is a ______A. spring-loaded type.B. gas-charged type.C. weight-loaded type.D. all of the above38. The Bourdon tube gauge and Schradder gauge are examples of ______A. flow meters.B. pressure gauges.C. temperature gauges.D. none of the above39. Conventional reciprocating circuits provide reversal through the use of a ______A. unidirectional valve.B. two-way directional valve.C. three-way directional valve.D. none of the above40. An accumulator can be used to ______A. maintain the pressure during a holding operation.B. augment pump delivery during short periods of large volume demand.C. absorb hydraulic shock.D. all of the aboveVickers Industrial Hydraulics Manual - Workbook AnswersBOP Equipment OJT ModulePage: 3.6 Rev. 02: January 20051. In the equation P =0.052 x W x TVD, the units P, W, and TVD are expressed in ______A. pascals, kilograms, and metres.B. psi, ppg, and metres.C. psi, ppg, and feet.D. lbs, gallons, and feet.2. The ______ the relative movement of mud past the pipe, the ______ the pressure required to overcome thefriction.A. slower, greaterB. faster, greaterC. faster, smallerD. none of the above3. Measurement of actual number of barrels used to fill the hole is generally made by ______A. trip tank.B. pump stroke counter.C. pit level change.D. all of the above4. A fracture pressure of 1,248 psi at 2,000 feet corresponds to an equivalent mud weight of ______A. 12 ppg.B. 13 ppg.C. 14.1 ppg.D. 15 ppg.5. Abnormally pressured shales are found to have a lower porosity than would normally be found at the samedepth.A. TrueB. False6. Gas may enter the mud as a result of ______A. trip gas that follows round trips of the drill string.B. connection gas that is associated with each drill pipe connection.C. gas from drilled gas-bearing sands.D. all of the above7. High permeability formation underbalanced by mud pressure is the most dangerous type of kick.A. TrueB. False8. The first step when controlling a well kick if on bottom is to ______A. check for well flow.B. shut down the pump.C. raise the kelly to clear the tool joint above the rotary, or pick the bit up off bottom.D. read and record the stabilized SIDPP.9. For stripping operations, the methods that can be used are ______A. stripping through the annular.B. stripping from annular to ram.C. stripping from ram to ram.D. all of the above10. Large-size mechanical snubbers are capable of exerting 350,000 pounds of force.A. TrueB. FalseRotary Drilling Blowout Prevention - Workbook AnswersBOP Equipment OJT ModulePage: 3.7 Rev. 02: January 200511. One should always open or close the valve next to the well before flow commences or after flow has beenstopped by the downstream valve.A. TrueB. False12. The working pressure of the BOP assembly should exceed the least of the following:1. The burst rating of the casing to which it is attached.2. The formation breakdown pressure at the last casing shoe.3. The maximum bottomhole pressure.4. The maximum anticipated surface pressure.A. 1 and 2B. 1, 2, and 3C. 1, 3, and 4D. 1, 2, and 413. The casinghead usually provides ______ opening(s) that can be used for bleeding off the pressure or for pumpinginto the well.A. oneB. twoC. threeD. none of the above14. Pipe rams in the BOPs are designed to center the pipe in the hole when the rams are closed.A. TrueB. False15. Rotating heads have a body that rotates with the kelly while the packing element is stationary.A. TrueB. False16. The choke line and lines downstream of the choke should be ______A. as straight as practicable.B. firmly anchored to prevent vibrations.C. having a bore of sufficient size to prevent excessive erosion.D. all of the above17. Valves on a kill line ______A. should be kept closed at all times when not in use.B. should be kept open at all times when not in use.C. should have a minimum internal diameter of 4 inches.D. none of the above18. One type of wireline preventer can close off the top of the drill string without a lubricator.A. TrueB. False19. All preventers and valves should be tested with pressure from ______A. the downstream side.B. the upstream side.C. both of the aboveD. none of the above20. It is possible to test the blind rams when using a hanger plug for BOP testing.A. TrueB. FalseRotary Drilling Blowout Prevention - Workbook AnswersBOP Equipment OJT ModulePage: 3.8 Rev. 02: January 20051. What is the first step that should be taken before working on the type U BOP?A. Connect the hydraulic line to the close port.B. Familiarize yourself with the BOP parts and their location and also with the inspection andmaintenance procedures.C. Loosen the bonnet bolts.D. Open the ram locks.2. How are the rams removed?A. Using a nylon strapB. Using a lifting-eye and a steel bar or air hoistC. Using a standard pry-barD. Using a sledge hammer3. Upon inspection of the ram core and all connecting surfaces of the preventer body and intermediate flange, whichof the following would be a major problem?A. Small nicks and scratchesB. Deep gouges and/or large nicks and scratchesC. Water and dirtD. Fine abrasions and normal wear4. Can scratches and gouges be field-repaired?A. Yes, normally a file may be used to smooth down the problem area.B. Yes, only if the nick is very minor.C. No, never attempt to remove any nicks or scratches in the field.D. No, scratches can only be removed by Cameron repair shop service.5. A bad bonnet seal is ______A. misshaped.B. unnaturally flattened on the sides.C. cracked and slightly cut.D. all of the above6. Wellbore pressure aids in closing and in holding rams closed.A. TrueB. False7. Two primary and one emergency seal with a vent hole in between prevent well pressure from bleeding into theoperating cylinder.A. TrueB. False8. Rams may be locked in the closed position by using mechanical screw locks. There is no optional hydraulic ramlock function available.A. TrueB. False9. Each operating piston rod has a triple seal system which includes a Hycar lip seal, a plastic energizedsecondary seal, and large O-ring seals in the hydraulic operation system. Therefore, well pressure cannot reachthe operating cylinders.A. TrueB. FalseCameron Ram-Type U Blowout Preventer - Workbook AnswersBOP Equipment OJT ModulePage: 3.9 Rev. 02: January 200510. How many foot-pounds should the bonnet bolts for a 5,000 psi rated 13 5/8-inch bore ram type BOP be torquedto?A. 3,000 ft/lbsB. 5,000 ft/lbsC. 7,000 ft/lbsD. 10,000 ft/lbs11. Ram preventers are designed to hold bidirectional pressure (from above and/or below).A. TrueB. False12. In an emergency, ordinary water can be used as an operating pressure fluid.A. TrueB. False13. On the surface BOP rams, the emergency plastic compression seal is used in the event of a leaking main seal.A. TrueB. False14. Never cut an old seal or O-ring in half.A. TrueB. False15. Bonnet bolts dont require O-ring seals.A. TrueB. False16. Always coat O-ring seals with light oil when installing.A. TrueB. False17. Check for gaps between the intermediate flange and preventer body using a ______ feeler gauge along thesurfaces of these two areas.A. .005-inchB. .010-inchC. .020-inchD. .030-inch18. In cold weather operations, the preventer should be kept as warm as possible as the rams are susceptible tofreezing in place since water-base drilling fluids freeze quickly and solidly when they come to rest at suchtemperatures.A. TrueB. False19. In cold weather operations, water is a satisfactory operating fluid provided a soluble oil is used for corrosionprotection and sufficient antifreeze is added to prevent freezing.A. TrueB. FalseCameron Ram-Type U Blowout Preventer - Workbook AnswersBOP Equipment OJT ModulePage: 3.10 Rev. 02: January 20051. The first step in the 3-month test series is ______A. the closing hydraulic pressure test.B. visual inspection.C. locking hydraulic pressure test.D. field wellbore pressure test.2. A leak past the piston is indicated in the opening hydraulic pressure test by the opening gauge ______ and theclosing gauge rising.A. risingB. remaining stationaryC. fallingD. none of the above3. The closing hydraulic pressure test may be performed with the doors open or closed.A. TrueB. False4. The fluid used in the field wellbore pressure test is cold water.A. TrueB. False5. During the closing hydraulic pressure test, if the valve in the opening hydraulic line is closed and the pressureincreases, hydraulic fluid is leaking past the piston.A. TrueB. False6. Excessive wear in the BOP bore is normally indicated by ______A. 1/8 inch of wear.B. leaks at the hinge pin.C. 1/32 inch of wear.D. none of the above7. Only one door at a time should be opened unless the BOP is well supported because the weight from two opendoors could cause it to tip over.A. TrueB. False8. The normal locking pressure for pipe and blind rams should be ______ to ______ psi.A. 5 to 10B. 25 to 50C. 100 to 200D. 500 to 1,4009. A clearly visible mark on the torque tool and clamp will permit accurate counting of turns on the torque toolduring adjustment.A. TrueB. False10. The 10-inch piston should be disassembled exactly the same way the 14-inch piston is disassembled.A. TrueB. False11. Before the piston can be removed, the ______ must be removed.A. ram rubbersB. opening hydraulic gaugeC. locking plateD. all of the aboveRucker Ram-Type Blowout Preventer - Workbook AnswersBOP Equipment OJT ModulePage: 3.11 Rev. 02: January 200512. To prevent the ram shaft from turning during disassembly, ram blocks or ram holders are installed.A. TrueB. False13. To help push the cylinder head off, ______ is blown into the closing hydraulic line.A. waterB. oilC. airD. none of the above14. The ramshaft is removed after the ramshaft packing is removed.A. TrueB. False15. During the adjustment sequence, the rams should be in the fully closed and locked position.A. TrueB. False16. The brass locking segments must be installed before the cylinder is installed over the piston.A. TrueB. FalseRucker Ram-Type Blowout Preventer - Workbook AnswersBOP Equipment OJT ModulePage: 3.12 Rev. 02: January 20051. The five main components of a Hydril ram BOP are the cylinder assemblage, fluid hinge assemblage, bonnetassemblage, upper latch assemblage, and the ram assemblage.A. TrueB. False2. The first step in the initial disassembly of the Hydril ram BOP is to ______A. close the rams completely.B. disconnect the hoses.C. open the rams completely.D. remove the fluid hinges.3. If a deep scar is noticed on the upper seal seat during inspection, it is important to send the BOP back to anapproved workshop for repair.A. TrueB. False4. When replacing the piston seals it is important to ______A. ensure the seal on the piston rod side opens towards the shaft and the seal on the piston rod opens towardsthe mechanical lock.B. check that the mechanical lock is not in place as the seal is of a smaller diameter than the mechanicallock.C. ensure that the seals are completely dry and free of any silicon compound or oil.D. ensure the seal on the piston rod side opens towards the shaft and the seal on the mechanical lockside opens towards the mechanical lock.5. The removal of the cylinder-to-bonnet O-ring is the last seal on the cylinder, and ______A. requires a special tool supplied by Hydril.B. can simply be pryed off.C. should never be removed as it is an integral part of the cylinder.D. none of the above6. The mechanical lock shaft must be screwed into the piston with a counterclockwise rotation.A. TrueB. False7. When aligning the bonnet of a Hydril ram BOP, the bonnet is raised by ______A. building up the hinges with shims supplied by Hydril.B. loosening the upper hinge pin and then tightening the lower hinge pin.C. loosening the lower hinge pin and then tightening the upper hinge pin.D. all of the above8. The emergency or secondary seal is normally used only on surface BOPs and its function is to ______A. retain hydraulic operating fluid within the BOP if the mud seal fails and can be energized manually onsurface stacks.B. act as a backup to the mud seal and can be energized manually on surface stacks.C. act as a backup to the mud seal and can be energized by removing the pipe plug and attaching a hot line toits threaded port.D. none of the above9. It is important to never use screwdrivers during the removal of the upper seal from a ram block.A. TrueB. FalseHydril Ram BOP - Workbook AnswersBOP Equipment OJT ModulePage: 3.13 Rev. 02: January 200510. When tightening the bonnet bolts, it is important to ______A. check the operators manual for the correct torque values.B. check that the bolts are dry and free of grease.C. take the weight of the bonnet with a chain hoist to help the alignment of the bonnet.D. all of the above11. A continual flow from the opening chamber port while pressure testing the closed chamber may mean a ______leak, or a cylinder liner to bonnet seal leak.A. hinge pinB. upper seal seatC. piston sealD. none of the above12. A leak from the weephole means that there is a bad bonnet seal or piston rod seal.A. TrueB. FalseHydril Ram BOP - Workbook AnswersBOP Equipment OJT ModulePage: 3.14 Rev. 02: January 20051. What is the purpose of the GL annular BOP?A. It is to allow returns during a kick situation.B. It is to seal off the wellbore during a kick situation.C. It is to allow kill mud to enter the wellbore during a kick situation.D. none of the above2. The main parts of the GL annular BOP are ______A. the BOP head, packing unit, opening chamber head, piston, outer body sleeve, slotted body sleeve,BOP body, group of parts forming the head latch system.B. the BOP head, packing unit, opening chamber head, piston, outer body sleeve, group of parts forming thehead latch system.C. the BOP head, opening head unit, closing chamber head, piston, outer body sleeve, slotted body sleeve,BOP body, group of parts forming the head latch system.D. the BOP head, packing unit, opening chamber lower body, piston, outer body sleeve, lower body sleeve,BOP body, group of parts forming the head latch system.3. The three different hydraulic hookups that can be used with a GL annular BOP are to connect the secondarychamber to the ______A. opening chamber on a surface BOP, closing chamber to reduce the closing pressure by one third,and the marine riser to neutralize the effect of the drilling fluid.B. opening chamber on a surface BOP, closing chamber to reduce the closing pressure by one third, and theshear rams to allow faster closing time of the shear rams.C. closing chamber on a surface BOP, opening chamber to reduce the closing pressure by one third, and themarine riser to neutralize the effect of the drilling fluid.D. none of the above4. What methods can be used to limit wear on the packing unit of the GL annular BOP during stripping operationswith the BOP in the closed position?A. Adjust the closing pressure so there is a slight leakage of drilling fluid.B. Keep to a slow stripping speed to reduce surge pressures.C. It is not possible to strip pipe through a GL annular BOP.D. both A and B above5. What are acceptable fluids for use in the GL annular BOP hydraulic system?A. Light petroleum hydraulic oil and diesel oilB. Water with water-soluble oil and diesel oilC. Light petroleum hydraulic oil onlyD. Light petroleum hydraulic oil and water with water-soluble oil6. What can be used in the hydraulic system to ease a particular disassembly procedure?A. Air, gas, and hydraulic fluidB. Air, gas, and water with water-soluble oilC. Any fluid can be used to ease a particular disassembly procedure.D. Light petroleum hydraulic oil and water with water-soluble oil7. How should you install a double U seal?A. The upper seal in each set of single Useals is installed with the groove opening UP. The lower sealin each set is installed with the groove opening DOWN.B. The upper seal in each set of single U seals is installed with the groove opening DOWN. The lower seal ineach set is installed with the groove opening UP.C. The upper seal in each set of single U seals is installed with the groove opening UP. The lower seal in eachset is installed with the groove opening UP.D. none of the aboveHydril GL Annular Preventer - Workbook AnswersBOP Equipment OJT ModulePage: 3.15 Rev. 02: January 20058. Explain the relationship between the length of the piston stroke needed for seal-off and the condition of thepacking unit in the GL annular BOP.A. Measure the distance between the piston and the slotted body sleeve. After closing the annular with the newpacking unit installed, remeasure the distance and record the difference. By taking subsequentmeasurements each time you test the BOP, you can determine the relative wear on the packing unitB. There is no relationship between the length of the piston stroke needed for seal-off and the condition of thepacking unit.C. Measure the distance between the piston and the annular head. After closing the annular with thenew packing unit installed, remeasure the distance and record the difference. By taking subsequentmeasurements each time you test the BOP, you can determine the relative wear on the packing unit.D. none of the above9. Why should you check the operators manual before pressure testing?A. For closing pressureB. For wellbore pressureC. For test pipe diameterD. for all of the above10. When you have closed the GL annular BOP around the test pipe, but have not yet pressurized the wellbore, howdo you check for leaks?A. It is not possible to check for leaks until the wellbore is pressurized.B. Cover the top of the packing unit with water and watch for the water level rising.C. Use air to close the GL annular BOP, as it is possible to listen for the leak.D. none of the above11. We do not need to vent off any hydraulic chambers before disassembly of the GL annular BOP as they are allself-venting.A. TrueB. False12. To release the GL annular BOP head latching mechanism, we need to turn the jaw operating screws ______turns counterclockwise.A. oneB. twoC. threeD. four13. The GL 16 3/4" and the GL 18 3/4" use cap screws and head clamps to secure the BOP head to the body.A. TrueB. False14. If a major scar is found on the internal body of the GL annular BOP, ______A. you can get the rig welder to build up over the scar and smooth down with emery cloth.B. you can fill the scar with a suitable hard-setting compound and file it smooth.C. you must send the body into an approved machine shop for repair.D. all of the above15. It is important to check the vertical bore of the head of a GL annular BOP for wear or damage as drill stringtubulars and tools can cause damage here.A. TrueB. FalseHydril GL Annular Preventer - Workbook AnswersBOP Equipment OJT ModulePage: 3.16 Rev. 02: January 20051. Subsea accumulators with no temperature difference between surface and subsea ______A. are charged to a set surface precharge pressure.B. are charged to hydrostatic pressure at seabed.C. are charged to surface precharge plus hydrostatic pressure.D. are charged to surface precharge plus hydrostatic pressure plus atmospheric pressure.2. Atmospheric pressure at sea level is ______A. 0 psi.B. 14.7 pounds.C. 14.7 psi.D. 0.445 psi per foot.3. A lower temperature at seabed compared to the surface would cause ______A. the nitrogen to contract.B. a decrease in pressure in the accumulator bottles.C. the last drop of fluid to come out of the bottle at a reduced pressure.D. all of the above4. Hydrostatic pressure exerted by a column of seawater is ______A. .445 psi.B. .445 psi per foot.C. 14.7 psi per foot.D. none of the above5. Specific volume is ______A. pounds of gas per cubic feet of gas.B. pounds of gas per 100 cubic feet of gas.C. cubic feet of gas per pound of gas.D. cubic feet of gas per gram of gas.6. Specific volume of nitrogen at 50 degrees Fahrenheit and 3,750 psia is ______A. 0.06032 cubic ft/lbB. 0.05540 lb/cubic ftC. 0.05673 lb/cubic ftD. 0.05673 cubic ft/lb7. Specific volume of nitrogen at 55 degrees Fahrenheit and 3,750 psia is ______A. 0.05673 cubic ft/lbB. 0.05804 cubic ft/lbC. 0.05737 cubic ft/lbD. 0.05739 cubic ft/lb8. Specific volume of nitrogen at 55 degrees Fahrenheit and 3,875 psia is ______A. 0.05739 cubic ft/lbB. 0.05611 cubic ft/lbC. 0.05466 cubic ft/lbD. 0.05673 cubic ft/lb9. For a surface precharge of 1,500 psi, 300-feet water depth and no difference between surface and subseatemperatures, the subsea precharge would be ______A. 1,649.2 psi.B. 1,633.5 psi.C. 1,633.2 psi.D. 1,648.2 psi.Accumulator Bottles - Bladder Replacement and Precharge - Workbook AnswersBOP Equipment OJT ModulePage: 3.17 Rev. 02: January 200510. For question 9 above, if the surface temperature is 80 degrees Fahrenheit, and subsea temperature is 40degrees Fahrenheit, the subsea precharge would be approximately ______A. 1,650 psi.B. 1,830 psi.C. 1,740 psi.D. 1,870 psi.11. MMS states the minimum requirements for accumulator volumes to be ______A. usable fluid volume should be 11/2 times the volume necessary to close all functions.B. after closing all functions, there should be a minimum pressure of 203 psi above precharge pressure.C. both A and B aboveD. none of the above12. Boyles gas law states that ______A. pressure is directly proportional to the temperature.B. volume is directly proportional to pressure.C. pressure is inversely proportional to the volume.D. none of the above13. Following MMS guidelines, the total usable fluid in an 11-gallon accumulator bottle with 1,000 psi precharge and3,000 psi final pressure is ______ A. 10 gallons.B. 4.97 gallons.C. 6.67 gallons.D. 3.33 gallons.14. Following MMS guidelines, the total usable fluid in an 11-gallon accumulator bottle with 1,203 psi precharge and3,000 psi final pressure is ______A. 6 gallons.B. 4 gallons.C. 8.5 gallons.D. 4.5 gallons.15. In an 11-gallon accumulator bottle, the available volume for nitrogen and fluid is ______A. 1 gallon.B. 10 gallons.C. 5 gallons.D. 11 gallons.Accumulator Bottles - Bladder Replacement and Precharge - Workbook Answers Transocean 2005 Issue Date: 01 J anuary 2005