Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes: Supervisory Level
Revision 4B May 14, 2014
Prepared by Black & Veatch Corp.
DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Contents 4. Supervisor Level Overview ...... 2 4.1. Drilling, Workover, Completion Plan ...... 3 4.2. Technical Principles ...... 4 4.3. Mud & Pit Management ...... 9 4.4. Pre-Kick Data ...... 11 4.5. Pore Pressure Prediction ...... 12 4.6. Kick Awareness during Drilling, Workover, & Completion Operations ...... 14 4.7. Barriers ...... 17 4.8. Kick Detection & Drills ...... 18 4.9. Shallow Gas/Water Flows & Top Hole Drilling ...... 21 4.10. Shut-In Procedures & Verification ...... 22 4.11. Well Control/Risk Management ...... 25 4.12. Well Control Methods ...... 27 4.13. Equipment Readiness/Assurance ...... 31 4.14. Extract of Subsea Elements ...... 35
Page 1 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
4. Supervisor Level Overview The purpose of the core curriculum is to identify a body of knowledge and a set of job skills that can be used to provide well control skills for drilling operations.
This curriculum incorporates both surface and subsea topics. The majority of the topics are relevant to both surface and subsea operations. Those topics specific to subsea are in a BLUE font. To assist the user, all Subsea topics have been extracted into Section 4.14.
Recommended Attendees:
WCI recommend the following Job Positions attend the Supervisor Level course:
• Wellsite Supervisors, Company men and assistants • MPD/UBD Wellsite supervisors • Office-based drilling supervisors/superintendent (not involved with well design approval) • Office-based rig, drilling manager • OIM for mobile offshore drilling units • Rig Manager (shore-based/superintendent (land)) • Rig Superintendent offshore (most senior offshore leader for drill crew, may be the OIM) • Toolpushers
Note:
• Blue Text = Subsea • Black Text = Common to Surface and Subsea
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
4.1. Drilling, Workover, Completion Plan *A = Awareness of learning topics at this job level Module Name: Drilling, Workover, Completion Plan I = Implements learning topics at this job level M = Mastery of learning topics at this job level Learning Topics AIM* Learning Objectives Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Key elements of the drilling, work over, completion program that are important to Identify key elements of the well program that the Supervisor Well Work Objectives A ensure control and containment of formation applies to kick prevention. fluids at all times during rig operations. Identify the importance of knowing Fracture Pressures and Fracture Gradients The importance of knowing the Fracture A Formation Fluid Pressures (Pore Pressures) when drilling, and Pore Pressures gradients and pore pressures in the well. completing and workovers. The role of casing and cementing in the Casing & Cementing A drilling of a well and for containing formation Identify the role/s of casing and cementing in a well. Program fluids. Why wells have to be worked over. Identify reasons for a workover. Reasons for A Major well control differences between Differentiate between well control operations normally Workover drilling a well and a 'workover'. related to drilling operations and those related to workover. Differentiate between well control operations normally Major well control differences between Completion Program A related to drilling operations and those related to drilling a well and completing a well. completions. Why a well-designed drilling and completions Fluids Program A fluid program is important to containment of Identify key functions of a fluids program formation fluids. Barrier Management A The term Barrier Management. Select definition of Barrier Management Well Control Why BOP selection is essential to Select reason why a BOP has to be selected to meet the A Equipment Selection containment of formation fluids requirements of the formations drilled.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
4.2. Technical Principles Module Name: Technical Principles Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Select correct definition of a U-Tube. The principle of a U-tube. Calculate pressures on each side of a u-tube. State what would happen if a certain weight of fluid was pumped into the u-tube and how this might affect hydrostatic How the model of a u-tube works during a pressure and pump pressure: e.g. effect on mud level in the well kill. two legs of the u-tube; effect of surface pressures if end of u- tube is sealed by BOP or Valve. Principle of U-Tube M Calculate SIDPP if kill is shut down with kill mud being The effect of the u-tube when pumping kill circulated to Bit. weight mud during a kill operations tripping. Calculate mud returns following displacement of a heavy weight slug into the drill string prior to tripping: e.g. how much mud should return back at surface from a given weight and volume of slug. How the u-tube can assist in calculating Calculate top of cement position once displaced into position displacement position of cement. Select correct statement when defining friction in the well or Friction and pump pressure. pump pressure Describe how frictional losses around the circulating system How friction in the different sections of the result in pump pressure: e.g. sum of losses in surface lines, Pump Pressure well contribute to final pump pressure. drill string, bit and annulus. Effects & Circulating M Recognize how mud properties, hole geometry and flow rate Friction Pressures How mud weight, viscosity, flow rate and affect the pump pressure and the effect of pumping a hole geometry affects pump pressure. different weight fluid around the well (u-tube effect). Calculate changes in pump pressure due to Using standard industry formula calculate effect of SPM and changes in pump speed and mud weight. Mud Weight changes on pump pressure.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Technical Principles Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Define the term Kick Tolerance: e.g. general definition, Kick Tolerance and how it is expressed. explain the limitation of maximum pressure and volume of a kick to safely shut-in and circulate kick to surface The assumptions used in the kick tolerance State common assumptions used when calculating kick calculation. tolerance: e.g. increase in pore pressure, maximum kick size. Planning & Use a kick tolerance graph showing kick intensity versus kick Operational Kick I volume to obtain kick tolerance: e.g. identify initial shut-in Methods to obtain Kick Tolerance Tolerance kick tolerance and circulating kick tolerance, aware of alternative ways to calculate the value. State options available if a low kick tolerance is established: Options available if Kick Tolerance is low. e.g. set casing, shut-in immediately, enhanced well monitoring for warning signs. Options if well kicks with zero kick tolerance. State options available with zero kick tolerance The term formation strength. Select the correct definition of formation strength Why we need to determine Formation State why knowledge of formation strength is important in Strength. the drilling process. How formation strength can be determined Select reason why we need to know formation strength: e.g. on the rig using Formation Integrity Test or to determine maximum pressure than can be safely applied Leak Off Test (FIT/LOT). to the open hole shoe formation Formation Stresses & List key tasks to carry out to ensure an accurate LOT/FIT I Strength The key preparation tasks to ensure an result: e.g. clean hole, consistent mud weight around well, accurate FIT/LOT calibrated pressure gauges, surface equipment tested for leaks, The term Maximum Allowable Mud Weight Select correct definition for Maximum Allowable Mud (MAMW). Weight. How to calculate Fracture Pressure and Calculate Formation Fracture pressure and MAMW from FIT Maximum Allowable Mud Weight (MAMW). or LOT data.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Technical Principles Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: State actions that can be taken if formation strength is lower Possible action/s to take if MAMW is too low than expected: e.g. carry out cement squeeze, repair casing if for expected formation fluid pressures in next damaged, adjust drilling program to accommodate lower hole section. fracture strength. The term Maximum Predicted Surface Select the correct definition of MASP Pressure. Describe why MASP is important to Well Control/Integrity: How Maximum Predicted Surface Pressure is e.g. consequences of exceeding maximum pressure used in well design and the consequences of limitations, BOP selection, casing burst selection, wellhead exceeding maximum pressure limitations. rating, surface manifolds pressure rating. Maximum Predicted The term Maximum Allowable Annular Surface Pressure & Select the correct definition of MAASP Surface Pressure (MAASP). Maximum Allowable I Why a knowledge of maximum allowable and Describe the potential consequences of exceeding MAASP or Annular Surface maximum predicted pressures important in MAMW on well control/integrity: e.g. lost circulation, mud Pressure (MAASP) drilling operations. level drop, potential kick, downtime. Using Formation Strength data calculate MAASP using How to calculate MAASP. formula or kill sheet. When MAASP must be recalculated. State when MAASP needs to be re-calculated. Difference between Static and Dynamic State the difference between the terms Static MAASP and MAASP Dynamic MAASP The term bottom hole pressure (BHP). Select the correct definition of bottom hole pressure Distinguish between hydrostatic pressure and bottom hole Equivalent How BHP can be different from hydrostatic pressure: e.g. Static versus circulating bottom hole pressure, Circulating Density pressure. I cuttings loading, shut-in pressure, pipe movement. (ECD) & Bottomhole The importance of having the correct bottom Describe why correct bottom hole pressure is so important to Pressure (BHP) hole pressure (BHP). well control/integrity The term ECD. Select the correct definition of ECD
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Technical Principles Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: State how ECD is derived (formula not required): e.g. from How ECD is derived (formula not required). calculated annular friction losses. Describe how different operations can impact ECD and the resulting effect on bottom hole pressure: e.g. reduction when pumps are stopped at connections or flow checks, circulation How ECD affects bottomhole pressure. across flowline versus circulating through subsea choke or kill line, pumping out of the hole, circulating cement, high viscosity pills, pumping lost circulation material Describe the process of ECD drilling state the potential well control problems that can arise from this process: e.g. The principle of ECD drilling and associated underbalance on connections, connection gas, gas issues in well control problems. long marine Risers, narrow drilling window, mud weight displacement for tripping. Select the effects of gas on wellbore mud hydrostatic and How the relatively low density of gas affects bottom hole pressure: e.g. reduces pressure as gas expands, the hydrostatic pressure. may cause underbalance, gas-cut mud at surface effect, re- circulating gas-cut mud. Describe the correct relationship between gas pressure and The relationship between pressure and gas volume: e.g. Boyles Law concept to explain volume of a gas in the wellbore. pressure/volume relationship, most expansion close to Gas Behavior in I surface. Carry out basic calculation using Boyles Law Fluids State why the pressure of gas in the mud must be reduced in a controlled manner as it is brought to surface (circulated up Why a gas kick must expand as it is circulated hole): e.g. if not allowed to expand gas will increase wellbore up the wellbore. pressures, danger of allowing it to expand uncontrolled (reduced hydrostatic, well kick, Riser unloading), circulating through choke to maintain bottom hole pressure. The term gas migration Select correct definition of gas migration Page 7 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Technical Principles Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Predict the consequences of gas migration in the wellbore The consequences of gas migration. and on associated pressure gauges. e.g. In a shut-in well, in an open well, migration rates, effect of hole angle How gas normally behaves in a water-based Describe how gas generally behaves when circulated in a mud. water-based mud and how this impacts detection. How gas normally behaves in an oil-based Describe how gas generally behaves when circulated in a non- mud aqueous mud. Select reasons why it can be difficult to detect kicks when gas Describe the difficulty of detecting kicks with is in solution in the mud: e.g. gas in solution, smaller volume soluble gases while drilling and/or tripping. increase seen on surface, flow rate and PVT accuracy for small influxes, effect of rapid expansion at bubble point. Select correct statements on gas behavior as it is circulated Describe what happens to a gas as it is across the choke. e.g. rapid expansion overloading mud-gas circulated through the choke from a high- separator, cooling effect on equipment, increase velocity and pressure environment to a low-pressure potential erosion, possible hydrate formation causing environment. plugging. How downhole pressure can affect fluid State how pressure affects fluid weight weight. State how temperature affect mud properties: e.g. weight, Compressibility and How mud temperature can affect mud viscosity and gel strength, potential for hydrate formation, Temperature Effects properties. effect on mud in subsea choke and kill lines, heat expansion, on Oil Based Fluids I crystallization of brines (Non Aqueous Fluids Describe how pressure and temperature effects on the mud (NAF)) and Brines can impact well control: e.g. actual mud weight downhole, How downhole pressure and temperature mud weight to mix on surface to get correct value downhole, can impact well control. potential ECD effects, potential change in downhole condition when circulating and not circulating; monitoring for flow.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Technical Principles Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Describe how the values of wellbore pressure and string How well pressure effects whether pipe can weight and annular preventer limitations impact the decision Snubbing/Stripping be stripped or snubbed into the well. I to strip or snub into the well. Forces Describe the effect of buoyancy on forces required for Effect of buoyancy on calculations. stripping or snubbing. How to interpret Shut-In Pressures for a Interpret shut-in values for high angle wells and how they directional well. impact a well kill operation. State the effect of hole angle on potential for gas expansion Directional Well How gas expansion and migration is affected and migration: e.g. minimal effect in horizontal section, Effects on Well I in a highly deviated well significant change as it enters the build section. Control The potential problems if standard vertical Describe the effect on bottom hole pressure id vertical well- well-kill calculations are applied to killing of a kill calculations are use on a highly deviated well. highly deviated well. Describe how a tapered string will impact trip monitoring How tapered strings affect Trip Monitoring Tapered Drill String values I Effects Describe how a tapered string will impact well control How tapered strings affect Kill procedure calculations: e.g. ICP to FCP values
4.3. Mud & Pit Management Module Name: Mud & Pit Management Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Describe how mud density is measured using atmospheric or Maintaining Correct Two different methods to measure fluid I pressurized mud-balances: e.g. reason for difference, Mud Weight density and the reason for the difference. importance of calibration
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Mud & Pit Management Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Select reasons why key mud properties are checked at the Importance of regular mud property suction pit and shakers at regular time intervals: e.g. close measurements in kick prevention. monitoring of mud weight in and out, early recognition of problems, time between measurements, who should be told. Give instructions to crew on mud pit monitoring when drilling Role and responsibilities of drill crew and during a well kill: e.g. pit measuring devices, mud weight personnel who are working with the pit readings, communication with rig floor, record keeping, system. contamination by light fluids. Possible pit line-ups that can be used during a Demonstrate effective management of pit line-up for a kill well kill operation operation. How to handle volume increases due to influx State actions to take to manage pit gains during a well kill: expansion. e.g. pre-planning, pit size, transfers. Dangers of circulating formation fluids into State dangers involved in circulating formation fluids into the surface pit system. surface pit system Managing Pits during I Describe how formation fluids are handled at surface during a a Kill Operation Actions to take to reduce risks associated kill operation: e.g. handling gas, handling oil/condensate, with formation fluids at surface. handling formation water. Give instructions to crew on roles and responsibilities during a How drill crew should responsibilities when well kill. e.g. weighting up mud, monitoring pit levels, circulating out and killing a kick. switching suction when required, monitoring shakers, manifold line-ups, recording data, pump control. Select well control problems that can occur when displacing The dangers of adding/transferring fluids to a wellbore to a different weight of fluid: e.g. correct procedure Managing Pits during pit system during active drilling/circulating to use when adding/transferring mud and potential to miss Wholesale Wellbore I operation. gains or losses. Displacements Actions to take in the event of a pit volume Select action to take in event of a pit level discrepancy: e.g. discrepancy. stop drilling, flow check, analyze pit level records
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Mud & Pit Management Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: State importance of correct pit level sensor calibration and Importance of correct calibration of different agreement in volumes between different sensors and pit measuring systems. recording devices.
4.4. Pre-Kick Data Module Name: Pre-Kick Data Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Give reasons for taking a SCR: e.g. calculate ICP/FCP, detect Reason for taking slow circulating rates (SCRs). potential leaks in system, required for wait & weight method Select times that an SCR can be taken: e.g. at selected depth Time/s an SCR should be taken. interval, mud property changes, hole geometry changes, every shift, pump output changes. Typical flow rate/SPM for an SCR. Choose acceptable flow rate/SPM for a SCR Slow Circulating Which gauges are commonly used to read the I Select gauges to use to record a SCR Rates (SCR) SCR value. Give reasons why a SCR may not be accurate and could impact a well kill: e.g. if taken immediately after a trip or What can affect SCR readings and why SCRs extended non-circulating time, different mud weights in hole may not be 100% accurate for well kill at time of test, inaccurate result can lead to incorrect kick operations. circulating pressure, using it only as a guide to 'actual' pressure generated by 'start-up' procedure. Give reasons for taking a CLF: e.g. used in well kill start-up Choke Line Friction procedure, potential increase in bottom hole pressure if used I Reason for taking choke line frictions (CLFs). (CLF) incorrectly or during latter stages of well kill, detect potential leaks in system.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Pre-Kick Data Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Select times a CLF can be taken: e.g. mud property changes, Time/s a CLF should be taken. pump output changes Typical flow rate/SPM for a CLF. Choose acceptable flow rate/SPM for a CLF Which gauges are commonly used to read the Select gauges to use to record a CLF CLF value. The effect of taking the CLF on bottom hole Given various techniques for recording CLF state the effect on pressure. bottom hole pressure. What effect choke and kill line fluid densities, Choke & Kill Line Describe the effect on SICP of a choke or kill line having a I that are different from the fluid density in the different fluid density than that in the well and possible Fluid Densities wellbore, have on preparations to kill a well. action to take prior to killing the well.
4.5. Pore Pressure Prediction Module Name: Pore Pressure Prediction Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: How data from downhole tools such as LWD Give basic description of downhole tools that can enhance PWD/LWD Data I and Resistivity can help detect changes in detection of increasing formation pressure or reduction in formation fluid pressure. overbalance margin.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Pore Pressure Prediction Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Interpret observations and trends at Shakers that may help crew members identify potential well control problems: e.g. How the returns at the shale shaker can Shaker Evidence I visual condition of mud, cuttings load, cuttings shape, identify potential kick conditions. sloughing shales (cavings), gas-cut mud, mud weight and viscosity. Interpret observations and trends in mud data that may help How mud properties that can be affected by Changes in Mud crew members identify potential well control problems: e.g. I potential kick conditions, e.g. (gas cutting, Properties weight, viscosity, gas cutting, background gas increases, trip chlorides, temperature) gas, connection gas, mud chlorides, mud temperature Interpret observations and trends in drilling parameters that How drilling parameters are affected by Changes in Drilling may help you identify potential well control problems: e.g. I potential kick conditions (e.g., ROP, torque, Data/Parameters ROP changes (drilling break), torque, drag, pump pressure drag) decrease Define the term transition zone in relation to Abnormal Transition Zones. pressure State actions that may need to be taken during transition zone drilling: e.g. regular flow checks, enhanced mud weight monitoring in pits and shakers, enhanced logging of drilling Mud Weight Actions that may need to be taken during and gas parameters by Driller and Mud Logger, enhanced Management in drilling of a transition zone. I 'fingerprinting' of flowback at connections, increased Transition Zone awareness of essential crew to warning signs, use of Drilling PWD/LWD. Give reason why good mud weight management is required Reason why mud weight management is during transition zone drilling: e.g. formation pressure are important in a transition zone. rising and mud weight must be adjusted to prevent losing overbalance margin. Abnormal pressure and how it affects primary State how Abnormal pressure affects primary control in the Trend Analysis I control. wellbore Page 13 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Pore Pressure Prediction Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Common trends in the warning signs that can Identify trends in mud, shaker and drilling data that indicate indicate increasing formation fluid pressure potential abnormal pressure development (transition zone) (or a reduction in Overbalance). State appropriate actions a Supervisor must take when Actions the Supervisor must take when warning signs are noted: e.g. analyze, compare different warning signs are recognized. trends. List responsibilities of key team members in the monitoring of Role and responsibilities of various rig floor trends: e.g. Driller, Mud Logger, Mud Engineer, Company crewmembers in monitoring for warning signs. representative, geologist, drilling engineer.
4.6. Kick Awareness during Drilling, Workover, & Completion Operations Module Name: Kick Awareness during Drilling, Workover, & Completion
Operations Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Use of trip sheet to determine if hole fill is Analyze a trip sheet for signs of abnormal hole fill: e.g. normal or abnormal. swabbing, surging. M State action to take if trip tank readings show swabbing or Action/s to take if hole fill readings are Tripping Operations surging: e.g. flow checks, returning to bottom, lost abnormal. circulation remediation. Considerations for trip tank capacity in large State how to monitor large volume operations on a trip tank. volume operations. State standard procedures to follow before running non- Running non-shearables. shearables. Non-Shearables I Well flows with a non-shearable across the State action to take if well flows with a non-shearable across BOP. the BOP.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Kick Awareness during Drilling, Workover, & Completion
Operations Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Classification of loss Classify loss rates: e.g. seepage, minor, major State first actions to take for each of the loss types: e.g. Handling Losses M Actions to take for each of these loss types. monitor, maintain hole full, add base fluid, monitor volumes pumped, shut-in. The term wellbore ballooning. Define the term ballooning Select surface data that can help the Supervisor determine if Recognition of Ballooning. it is ballooning. First action to take if a Supervisor suspects Select correct action to take if ballooning is suspected. Ballooning. Analyze fingerprinting, shut-in and bleed back data to decide Ballooning Issues M How Ballooning can be distinguished from a if well is ballooning or kicking: e.g. compare flow rate with Kick at shut-in. flow back fingerprint, shut-in pressures versus ECD effect, pressures after bleed back, bleed back rate. Describe procedure to bleed down ballooning and dangers associated with the bleed back process: e.g. bleed back Procedure for bleeding down ballooning. amount, circulate bottoms-up, route through choke, danger of gas bled into well, gas expansion, gas in Riser. State what can increase risk of swabbing and surging during Factors that increase risk of swabbing and casing operations: e.g. narrow clearance, mud condition, surging during casing running/pulling running or pulling speed, heave at connections, casing operations. jewelry. Casing & Cementing M Casing displacements and how often casing Calculate casing displacements required for monitoring the Operations should be filled when running in hole . hole and casing fill-up. State precautions when running self-fill/automatic floats: Precautions to take when running self- e.g. what can cause mechanism to fail, manually fill to check fill/automatic casing shoe floats. system is functioning, monitor weight of string. Page 15 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Kick Awareness during Drilling, Workover, & Completion
Operations Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Select statements regarding problems of a self-filling float Well control risks if a self-fill float fails to that does not convert: e.g. allows formation fluids to flow convert. directly up inside the casing, allow cement to backflow up inside casing. Equipment required to shut-in on a kick when State equipment used to shut-in on a kick while casing or running casing or during and after cementing. cementing: e.g. circulating head State effect of cement hardening on cement hydrostatic and Effects of a cementing operation on BHP. how that affects well control: e.g. reduction in hydrostatic Importance of following recommendations Select reason/s why cement waiting time is critical to well based on cement pilot testing before beginning control. follow up operations. State how to monitor flow rate during cement operations: e.g. expected increases while pumping cement, expected pit Monitoring wellbore flow rates/pit levels during levels during displacement by mud, stabilized flow rate, the cementing and displacement. monitoring correct pits, handling contaminated return volumes. State how to monitor the while waiting on cement: e.g. How well is monitored during cement waiting annulus flow, flow inside casing, detecting small amounts of time. flow over time. Calculate height of cement in annulus based on pump How final pumping pressure can be used to pressure at final displacement or final expected pump calculate cement height in the annulus. pressure at planned displacement. Select kick prevention monitoring practices to employ during Wellbore Fluid Common practices when displacing wellbore displacements to lighter fluid: e.g. maintain accurate volume M Displacements fluid to a lower density fluid. control at all times, monitor flow rates, expected pumping pressures.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Kick Awareness during Drilling, Workover, & Completion
Operations Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Using data provided calculate when hydrostatic pressure Point at which a low-density displacement above a barrier exerts a negative pressure across that causes a negative pressure across a barrier. barrier. Select possible causes of a kick during wireline operations: Potential causes of a kick during wireline e.g. swabbing, free gas migrating and expanding, barite operations. settling. Wireline Operations M State kick prevention practices while wirelining: e.g. monitor Common kick prevention practices during fluid displacement on trip tank, stable mud condition, wireline operations. effects of temperature changes on mud expansion/contraction. Negative testing Define the term negative test. Negative Testing M Common procedure for carrying out a negative Describe common procedure for carrying out a negative test. test. Riser Margin. Define the term Riser Margin Riser Margin M Calculate Riser Margin. Using given data calculate Riser Margin
4.7. Barriers Module Name: Barriers Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Barriers and Barrier Systems. Define the terms barrier and barrier system Philosophy and For typical drilling operations state how barriers maintain well Operations M How barriers are used to maintain well integrity: e.g. role of mud, cement, casing, BOP, String Valves, Requiring Barriers integrity in drilling and casing operations. Packers.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Barriers Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: For typical casing & cementing operations state how barriers maintain well integrity: e.g. role of mud, cement, previous casing, BOP, inside casing non return valves State location of barriers at sea-floor and effect if breached: e.g. gas in Riser with only Diverter as a barrier, effect of Effect of subsea BOP on barrier location formation breakdown around wellhead, impact of blowout at sea bed, option to unlatch or ESD The minimum number of barriers required for Number of Barriers Select the minimum number of barriers for normal operations M safe operations and why. for Safe Operation Number of barriers for given well designs. Identify the number of barriers present in a given well design How common mechanical barriers are tested Select definition of positive and negative testing for barriers to ensure well integrity. Testing Barriers M Describe how a failed barrier can be detected: e.g. flow from How to recognize a failed barrier. the well, losses to the well, increase in surface pressure when shut-in.
4.8. Kick Detection & Drills Module Name: Kick Detection & Drills Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Define a Flow Check. Select the correct definition of a flow check Recognize the need to carry out a flow check and take Well Flow with How to carry out a flow check. required action: e.g. difference between tripping and drilling M Pumps Off flow check State action if flow check is positive: e.g. difference between Action to take if flow check is positive. tripping and drilling operation.
Page 18 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Kick Detection & Drills Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: How the trip tank can be used for a flow State how to carry out a flow check using the Trip Tank: e.g. check. line up on trip tank and monitor flow Select surface and subsurface conditions that may make it Surface and subsurface conditions that can difficult to identify if the well is flowing: e.g. inoperable flow make it difficult to decide if well is flowing meter, rig movement, dumping trip tank, low permeability formation, small underbalance, ECD effects, gas solubility. Select correct reaction to well flow that may be due to How to react to flow if ballooning is suspected. ballooning: e.g. initially assume an influx and shut-in, make assessment for ballooning criteria. Select reasons why it is important to monitor pit levels at all Why pit levels are closely monitored at all times the rig is connected to the well: e.g. open hole always times. has a potential to flow, tested barriers may fail. Choose acceptable values for high and low level alarms set on Acceptable alarm limits for pit levels. PVT. Select surface operations that can give false pit level What operations can increase or decrease pit indications of a kick or losses: e.g. surface additions of fluid, level that are not related to flow or losses in fluid transfers, ballooning, gas solubility, losses through mud the well. cleaning equipment, leaks Pit Gain M Select surface conditions that may make it difficult to accurately measure pit level: e.g. inoperable pit level sensors, Conditions on surface that can make it difficult rig movement, incorrect line up of circulation system, mixing to get accurate pit level readings. mud, dumping or transferring fluid/by-pass shakers, tides, riser not connected, use of riser boost line Select correct action to take for a pit level increase/decrease: State action to take in event of abnormal pit e.g. flow check, shut-in, investigate other options such as pit level line-up only after shut-in. Abnormal Trip Tank returns when tripping Identify abnormal trip tank readings from a trip sheet: pipe or wirelining. e.g. identify abnormal readings on a trip sheet. Page 19 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Kick Detection & Drills Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Select reasons why it is important to monitor flow rates at all Why flow rates are closely monitored at all times the rig is connected to the well: e.g. open hole always times. has a potential to flow, tested barriers may fail. Choose acceptable values for high and low level alarms for Acceptable alarm limits for flow rates. Flow Rate. State what operations can increase or Select surface operations that can give false flow rate Flow Returns Rate decrease flow rate that are not related to indications of a kick or losses: e.g. increased SPM, dumping M Increase increased flow or losses in the well. trip tank, leaks in surface system. Select surface conditions that may make it difficult to Conditions on surface that can make it difficult accurately measure flow rate: e.g. inoperable flow sensor, rig to get accurate flow rate readings. movement, tides, riser not connected, use of riser boost line Select correct action to take for a flow rate Action to take in event of an abnormal flow increase/decrease: e.g. flow checks, shut-in, investigate other reading options only after shut-in. Reason for regular Pit Drills. Select reason for carrying out Pit Drills. Pit Drills M Roles and responsibilities of rig crew Select common crew roles for a Pit Drill: e.g. what crew personnel for a Pit Drill. members normally do during this drill. Reason for regular Trip Drills. Select reason for carrying out Trip Drills. Trip Drills M Roles and responsibilities of rig crew Select common crew roles for a Trip Drill: e.g. what crew personnel for a Trip Drill. members normally do during this drill. State reason for Stripping Drills. Select reason for carrying out Stripping Drills. Stripping Drills M Roles and responsibilities of rig crew Select common crew roles for a Stripping Drill: e.g. what crew personnel for a Stripping Drill. members normally do during this drill. State reason for Choke Drills. Select reason for carrying out Choke Drills. Choke Drills M Roles and responsibilities of rig crew Select common crew roles for a Choke Drill: e.g. what crew personnel for a Choke Drill. members normally do during this drill.
Page 20 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Kick Detection & Drills Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: State reason for regular Emergency Evacuation Select reason for carrying out Emergency Evacuation & Emergency & Abandonment Drills. Abandonment Drills. Evacuation and M Roles and responsibilities of rig crew Select common crew roles for an Emergency Evacuation & Abandonment personnel for an Emergency Evacuation & Abandonment Drill: e.g. what crew members normally do Drills Abandonment Drill. during this drill. State reason for Diverter Drills. Select reason for carrying out Trip Drills. Diverter Drills M Roles and responsibilities of rig crew Select common crew roles for a Trip Drill: e.g. what crew personnel for a Diverter Drill. members normally do during this drill. Explain why early detection of a kick is important: e.g. Importance of early detection and the minimize kick size and surface annular pressure, minimize consequences of not responding to a kick in a chance of formation breakdown, blowout, personnel safety, Importance of Early timely manner. broaching around casing, gas releases, fire, pollution, loss. Response, Stop Give reasons why all crewmembers must inform their Work Authority & M supervisor if they see any potential well control issues: e.g. Empowerment to Why each crewmember has the authority to minimizing chance of a kick and associated consequences, Act stop work and communicate any possible early increased communication, the more eyes on the problem the indications of well control problems. better, consequence of stopping work is insignificant compared to a kick or blowout.
4.9. Shallow Gas/Water Flows & Top Hole Drilling Module Name: Shallow Gas/Water Flows & Top Hole Drilling Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Top Hole Drilling Causes of abnormal pressure in top-hole State causes of abnormal pressure in top-hole sediments: e.g. I Practices and formations. trapped fluids, weight of overburden, charged formation.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Shallow Gas/Water Flows & Top Hole Drilling Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Causes of Kicks in Select common causes of going underbalance in top hole: Top Hole Main causes of underbalance in top hole e.g. mud weight too low, gas cutting, swabbing, overloaded drilling annulus, lost circulation, abnormal pressure, artesian flow, reduced hydrostatic while waiting on cement to set. Select common good drilling and tripping practice in top hole Top hole drilling practices that can reduce risk to prevent kicks: e.g. control of mud weight, logging tool data, of a well flow regular hole sweeps, drill pilot hole, controlled ROP, pump out of hole, seismic data. State possible options available with a shallow flow: e.g. Kill Options in Top Well control procedural options available (i.e., I Divert and desert, pump kill mud, pump at fast rate for ECD- Hole Divert, Increase SPM, Pump Kill Mud). dynamic kill. State how water depth affects the formation fracture Shallow Subsea How water depth affects formation fracture I pressure: e.g. distance from sea floor to rig floor (water depth Fracture Gradients pressures in shallow formations. and Air Gap), less compaction, narrower drilling window.
4.10. Shut-In Procedures & Verification Module Name: Shut-In Procedures & Verification Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: State advantage of shutting in early: e.g. minimize influx size, minimize SICP, reduce pressures on wellbore, importance of Why an immediate shut-in is an advantage. crew shut-in training, ensure crew know that if in doubt, shut Drilling & Tripping M it in. Steps to take to verify the well is secure and Carry out checks following shut-in to ensure well is secure: potential problem/s if not secure. e.g. no leaks at BOP, string, pumps, manifolds.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Shut-In Procedures & Verification Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Choose reasons for using blind and blind/shear rams: e.g. no Reasons for use of Blind/Shear Rams pipe in hole, blowout through drill string, emergency disconnect. State why knowledge of shear ram capability versus tubular Importance of knowing what the Shear Rams shear strengths is critical to development of shut-in can shear. procedures and the management of risk. Procedure for shut-in with all tubulars out of Out of Hole M State shut-in procedure when out of hole. the hole. Select actions that can be taken if well kicks with non- Running Casing Action to take if non-shearables are across M shearable tubulars across the BOP: e.g. use of Annular, casing and Cementing BOPs. rams, drop pipe, emergency disconnect issues. Wireline M Procedure for shut-in with wireline in the hole. Select correct shut-in procedure: e.g. including cutting wire Select reason/s for recording shut-in data; e.g. show buildup Reason for recording data following a kick. of pressures over time, calculating kill data. Main data to record following a kick and how Record data following shut-in e.g. pressures, volumes, time. often. Recording of Shut- Which gauges should be used to record Record data on correct gauges: e.g. normally on Choke In Pressures, M Drillpipe and Casing pressures. control panel, need for calibration checks. Differences, and The procedure to open the float to obtain Float in String Demonstrate how to measure SIDPP with a float in the string. shut-in drill pipe pressure. State how shut-in pressure accuracy may be affected by Complications to reading accurate shut-in water depth: e.g. cool mud in choke and kill lines, potentially pressures in deepwater wells. high gel strengths that can mask real pressure. Monitoring for Describe the procedure for identifying gas State how gas migration in a shut-in well can be recognized: Gas Migration, migration based on shut-in pressures. e.g. increasing shut-in pressures after initial stabilization. M Handling Action the Supervisor must initiate if gas is Demonstrate how to manage migrating gas in a shut-in well: Technique, and migrating. e.g. in a well without a float.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Shut-In Procedures & Verification Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Problems with State how to manage gas migration in a well where there is Excessive float in the drillstring: e.g. volumetric technique. Pressures Relationship between Formation Fluid Define SIDPP and SICP. pressure, Mud Hydrostatic pressure and Shut- Given data, calculate either formation fluid pressure or shut- In Pressure (SIDPP and SICP). in pressure. Give reason why SIDPP and SICP are different: e.g. fluid hydrostatics in the u-tube Effect of formation fluids on shut-in pressures Select well conditions than cause SIDPP to exceed SICP: e.g. values. formation fluids in string, cuttings effect on annulus hydrostatic, lighter mud in string. Analysis of Shut-In M Conditions State consequences of trapped pressure on kill calculations How incorrect reading of shut-in pressures can and how incorrect pressure can affect success of kill process: affect the kill operation. e.g. higher shut-in pressures, incorrect kill mud weight, higher pressure for start-up, potential losses. Analyze shut-in pressure at selected points in a kill and Shut-in pressures readings at any time during determine if correct bottom hole pressure is being a kill operation to determine if kill is going maintained e.g. analysis of shut-in pressure with kill mud at according to plan. different points in the string, kill mud at certain positions in the annulus, reaction on gauges following a shut down. How to identify trapped pressure from true Demonstrate how to identify if the current surface pressure Trapped Pressure shut-in pressure. reflect trapped pressure. and How to M Demonstrate how to reduce trapped pressure in a controlled Handle Procedure to reduce trapped pressure. manner. Riser Flow after Reasons for mud flow from the Riser following State what can cause Riser flow following well shut-in: e.g. M Shut-In well shut-in. leaking BOP, gas migration in Riser.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Shut-In Procedures & Verification Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: State the action to take if Riser is flowing following shut-in: Action to be taken if the Riser is flowing e.g. Check for BOP operation, close another preventer, Divert following shut-in. overboard.
4.11. Well Control/Risk Management Module Name: Well Control/Risk Management Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Give reason for supervisors and crew to develop and communicate a well kill plan: e.g. to have a procedure to Reason for developing a kill plan follow, to communicate that procedure to relevant personnel, to get feedback from the team to ensure they understand and can carry out their role, action to take if plan goes wrong. State role that the supervisor plays in planning: e.g. key role Assessing Risks and in development of technical aspects of plan, consults with Key role of Supervisor in well kill planning. Planning the Kill I wide range of subject matter experts, communicates the plan, Operations motivates personnel to do the right thing. Develop a kill plan including pit management Using a set of data identify key elements that would be for a well kill. needed in a kill plan. Identify main risk areas during a kill plan and For a set of pre-determined risks within a kill plan select actions to take to mitigate the risk. actions that could be taken to mitigate those risks. How to carry out a handover during a well kill Demonstrate a handover to another supervisor during a well exercise. kill exercise.
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Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Well Control/Risk Management Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Interpret data on a kill log and select possible kill problems/s: What to record on a kill log and how to not maintaining correct pressure, abnormal changes to casing analyze kill log during well kill to identify pressure and/or choke opening size and pit levels, SPM possible problems. variations State reason for having a safety margin during a kill Reason for using safety margins. operation: e.g. to reduce risk of going underbalance during a well kill. Safety Margin M State dangers of using safety margins during a well kill: e.g. Selection Dangers of using safety margins. margin too high that may cause losses, adding a choke safety margin and a mud weight safety margin adds extra pressure. What is an acceptable safety margin. Select an acceptable safety margin from a set of kill data. Using specific well data determine an action to take: e.g. Action that should be taken due to a problem incorrect mud pumped, run out of weighting material; with the kill. weather problem (onshore and offshore), Ram or Annular failure, plugged string, rig power failure. Managing Change For a specific kill plan identify key feedback from the well that I during a Well Kill would indicate the plan is not successful and state action to Identify 'stopping points' that would indicate take at that point: e.g. problem maintaining correct surface the kill plan was not working. pressure, casing pressure and pit volume changes not according to plan, possible points to stop the kill to check pressures. Recognize selected well control problems that can occur Typical well kill problems. during a well control operation: e.g. plugging, washouts, Handling Kill equipment issues. M Problems Demonstrate correct action to a specific problem that Responses to kill problems. maintains well integrity, minimizes further influx and restores bottom hole pressure in a timely manner.
Page 26 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Well Control/Risk Management Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: State options available if surface casing pressure is likely to Action/s to take if Casing Pressure may exceed exceed MAASP: e.g. continue and accept losses, reduce MAASP. circulating friction in annulus and choke lines yet maintain correct bottom hole pressure State why Bit to Shoe strokes are calculated as part of the kill plan: e.g. establish when influx is at the shoe, realize that Reason for calculating Bit to Shoe Strokes. shoe pressure will not increase once influx is above shoe even though surface pressure continues to rise (assuming constant bottom hole pressure procedure is maintained). State the purpose of a well control bridging document: e.g. assure all parties have the same information, well control Bridging I Purpose of a Well Control bridging document. issues between different parties have been resolved, handle Documents specific issues in relation to a particular well/environment or legislative regime. Decision to State potential situations during a well kill that would require Circumstances during a well kill operation that Implement rig emergency procedures to be activated and the actions to would require emergency procedures to be Emergency M take to secure the well (if applicable): e.g. uncontrolled BOP initiated and possible actions to take to secure Procedures (e.g., leak, 'broaching' at surface, potential vessel collision, bad the well. during a Well Kill) weather, drive-off, toxic gas, fire.
4.12. Well Control Methods Module Name: Well Control Methods Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Explain basic principles and steps involved in the Drillers Drillers Method M Basic principles of the Driller's method. Method.
Page 27 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Well Control Methods Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: How to kill a well using the Driller's Method. Demonstrate how to kill a well with the Drillers method. Action/s to take if shut-in pressures are not Select possible courses of action if the shut-in pressures are the same following the first circulation. not the same following the first circulation. How to maintain constant BHP when influx is Demonstrate how to maintain constant BHP when influx is being circulated through the choke/choke being circulated through the choke lines and choke. lines. Demonstrate how to start up and shut down a well while How to handle choke line friction effects compensating for Choke Line friction. during the well kill. State effect of choke line friction on surface pressures during the later stages of the kill process. State key differences with W&W method Select key differences with Wait & Weight Method Method. Explain basic principles and steps involved in the Wait & Basic principles of the Wait & Weight method. Weight Method. How to kill a well using the Wait & Weight Demonstrate how to kill a well with the Wait & Weight Method. method. Select possible courses of action if the shut-in drill pipe Shut-in pressure if well is shut-in with kill mud pressure is not zero following shut-in once kill mud is pumped at bit. to the Bit. Wait & Weight M How to maintain constant BHP when influx is Method Demonstrate how to maintain constant BHP when influx is being circulated through the choke/choke being circulated through the choke lines and choke. lines. Demonstrate how to start up and shut down a well while How to handle choke line friction effects compensating for Choke Line friction. during the well kill. State effect of choke line friction on surface pressures during the later stages of the kill process. Key differences with Drillers method Select key differences with Drillers Method Kill Sheets M Kill sheets Complete a kill sheet using given data (surface or subsea)
Page 28 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Well Control Methods Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: The importance of the start-up/shut down Explain the importance of using the correct start up and shut procedures in maintaining constant down procedure in a well kill: e.g. maintain BHP bottomhole pressure. The Supervisor's role in the start-up/shut Demonstrate a start up and shut down procedure down procedures. State action to take if start up procedure does not give ICP on Reasons why start-up pump pressure may not the drillpipe gauge: e.g. shut down and discuss, continue with equal ICP. updated ICP, monitor pressures as gels are broken down. State reasons why a shutdown may not return shut-in Reasons why pump pressure at shut down pressure to expected value: e.g. safety factors, trapped may not equal expected pressure. Pump Startup and pressure. Shut Down M Demonstrate how to compensate for lag time between a Lag time Procedure choke adjustment and pump pressure change. How a Choke Line Friction greater than Shut-In State how a CLF greater than SICP affects start-up: e.g. Casing Pressure affects start-up. increased ICP, zero casing pressure. State appropriate actions to take to ensure well is dead Method used at the end of a kill to verify well before opening up the BOP: e.g. shut down procedure, check is dead for trapped pressure, monitor through choke, circulating practice once well is open. State appropriate actions to minimize CLF effect on well when Method used to shut down at the end of a kill shutting down: e.g. shut down procedure, check for trapped and verify well is dead pressure, monitor through choke, circulating practice once well is open. Select situations when the volumetric method would be used: Volumetric Situations when the Volumetric method is I e.g. unable to circulate, no SIDPP to monitor, off bottom, out Method used. of hole.
Page 29 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Well Control Methods Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Explain the basic principles of the Volumetric Describe basic principles of volumetric method e.g. pressure method. increase and controlled bleed off cycles. Action/s to take once influx reaches the BOP. Describe principle of lube and bleed method. Select situations when the stripping would be used: e.g. bit Situations when Stripping is used. off bottom State key steps in stripping process whether compensating for gas migration or not: e.g. strip in pipe, bleed off closed end Outline key steps in Stripping and Stripping displacement (barrel in barrel out), incorporating volumetric with Gas Migration. method to handle potential gas migration, reasons for these Stripping I two techniques, action to take when Bit is stripped back into Technique the influx State how to ensure well integrity during stripping operations: e.g. monitor surface pressures, do not exceed State key considerations to ensure well formation breakdown, ensure minimum leakage through integrity during stripping operations. stripping BOP, maintain overbalance, bleed off correct volumes. Trapped gas at the BOP. Define trapped gas at the BOP Explain how trapped gas can be a problem: e.g. gas trapped Problems associated with trapped gas at the beneath BOP can migrate when BOP opened, large-scale gas Trapped Gas at subsea BOP I expansion; water depth, divert, danger of gas at rig floor. BOP List basic steps to remove trapped gas: e.g. secure well below Procedure for safely removing trapped gas. choke line, flush choke line to light fluid, u-tube riser back up choke line, fill riser and monitor for residual flow. Displacing Riser I Reason for displacing Riser following a kill. Give reason for displacing Riser to kill mud. Post-Kill
Page 30 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Well Control Methods Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Select reasons why bullheading may be preferred to circulation: e.g. toxic gas, unable to handle influx at surface, Circumstances when Bullheading may be used. potential to exceed equipment limitations if circulated to Bullheading I surface. Explain the basic principles of Bullheading. Describe key elements of bullheading. Explain how gas migration affects bullhead State effect gas migration would have on chosen bullhead rate. rate. Select reasons why reverse circulation may be preferred to Circumstances when Reverse Circulation may normal circulation: e.g. better containment of formation Reverse Circulation I be used. fluids, less circulation to remove formation fluids, reduced casing pressure. Basic principles of Reverse Circulation. Describe key elements of reverse circulation State dangers of uncontrolled gas expansion in the Riser: e.g. Dangers of Riser Gas. danger of unloading riser, danger to personnel, danger of fire, reduction in BHP. State basic principles for preventing riser gas and handling Handling Gas in the technique: e.g. circulate proportion of bottoms up through I Riser choke line, effect of mud type of gas expansion, water depth Procedures for preventing and handling Riser effect, monitor riser on trip tank to see small gains due to Gas expansion, employ diverter to protect rig floor, possible use of flowline mud gas separators (include dangers associated with their use).
4.13. Equipment Readiness/Assurance Module Name: Equipment Readiness/Assurance Learning Topics AIM* Learning Topics Assessments and Learning Outcomes
Page 31 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
The attendee will gain an understanding of: The attendee will be able to: Purpose of Diverter State the purpose of the Diverter in well control operations. Describe how the Diverter functions: e.g. valve/s open when How it functions Diverter is closed. Select general operating parameters e.g. pressure to operate, Diverters I General operating parameters maximum wellbore pressures. State areas where failure may occur during a well control Potential failure and remedial actions during operation: e.g. packer element, flowline seals, valves, action if shut-in and ongoing kill operation. packer fails. Well Control Equipment Inspect and approve line-up BOP stack and manifolds for How to line up equipment for chosen Alignment and I certain operations: e.g. drilling ahead for chosen shut-in operation. Stack procedure and well kill operations. Configuration State the purpose of key items of equipment on the BOP Stack: e.g. Annular, Pipe Rams, VBR's Blind/Shear Rams, Casing Rams, Test Rams, Rubber goods, Locking devices, Purpose of key equipment. Failsafe or HCR valves, drilling spool, Choke and kill line connections, wellhead connector/casing head and riser BOP Stack, Stack connector, booster line and bleed line. Valves, and How each item functions. Describe how each of the key items of equipment function. I Wellhead Select general operating parameters: e.g. pressures to Components General operating parameters. operate, temperature rating, maximum wellbore pressures, flow measurement devices, lights. State areas where failure may occur during a well control Potential failure and remedial actions during operation and how to recognize them: shut-in and ongoing kill operation. e.g. stuck in open position, primary packers and seals, secondary seals, locking devices, flange seal rings. Manifolds, Piping, Describe the function of this equipment in the well control I Function of this equipment. and Valves process.
Page 32 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Equipment Readiness/Assurance Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: State how pressure rating can impact line ups during the well kill process: e.g. standpipe manifold, choke manifold, cement Typical operating pressure manifold, various pressure ratings, temperature rating, valves upstream and downstream of Chokes, flexible hoses, mud pump valves and pressure-relief valve, targeted ‘tees’. State the purpose of key items of this equipment: e.g. Inside BOPs, full opening safety valves (including Top-Drive/Kelly Purpose of key equipment valves), non-return valves, 'dart' valves, float valves in drill string and casing, crossovers How each item functions Describe how each of the key items of equipment function. Drillstring Valves I Select general operating parameters: e.g. maximum wellbore General operating parameters pressures, temperature rating, State areas where failure may occur during a well control Potential failure and remedial actions during operation and how to recognize them: shut-in and ongoing kill operation. e.g. stuck in the open position, seals and sealing faces, operator seals, leak paths to surface. Well Control Explain purpose and location of key well control Related instrumentation equipment: e.g. Pit Level indicators, flowline Instrumentation I Purpose of key equipment indicators, pressure measuring devices, mud pump stroke and Auxiliary Well counter, pressure gauges, ROP indicator/recorder, maintain Control Equipment calibration, daily maintenance. Explain purpose and location of gas detection equipment in Gas Detection A Purpose of this equipment the circulating system; e.g. measure gas levels in mud and air, Equipment flowline, pits, cellar, shakers. Explain the purpose of this equipment in the well control BOP Closing Unit & process: e.g. to operate the BOP, give feedback on whether I Purpose of this equipment Control Panels BOP closed, feedback on operating pressure on BOP, secondary stations to operate the BOP. Page 33 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Equipment Readiness/Assurance Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Describe how key equipment in this system functions: e.g. Surface v Subsea, fluid storage and accumulators, How the unit and control panel function pressure systems, valving and piping to the BOP, regulators, feedback instrumentation such as gauges, flow meter and lights, Block position Select general operating parameters: e.g. pressures to General operating parameters operate, maximum wellbore pressures Interpret (at the level of a Supervisor) operation of gauges, flow meter and lights to check status of BOP during and after Potential failure and remedial actions during closing and opening operations: e.g. demonstrate shut-in and ongoing kill operation. understanding panel lights, gauges and flow to decide if BOP has functioned correctly. Difference between Function and Pressure Describe the difference between a function test and a tests pressure test. Describe the difference between a high-pressure test and a Function Tests and Difference between high and low pressure I low-pressure test: e.g. typical test values, holding time, period Pressure Tests tests between tests, test fluid type. State how often these test are to be carried out, what How often tests are to be carried out equipment is tested and direction to test equipment Monitoring Recognize an error in gauge readings based on discrepancy Equipment Common failures and how they can impact between gauges: e.g. drill pipe and casing gauges on Failures/ I well control operations. standpipe, choke manifold and choke panel, analog versus Erroneous Sensor digital. Reading Deadman, State the purpose of this equipment in the well control Autoshear and I Purpose of this equipment process and its basic functionality: e.g. reasons why, basic Emergency sequence of events.
Page 34 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Equipment Readiness/Assurance Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Disconnect System Action to take in case of emergency State what action the Supervisor should take if an emergency- disconnect disconnect is required. Explain purpose and location of the mud gas separator in the Purpose of this equipment circulating system. Mud-Gas Select general operating parameters: e.g. pressure to I Separator operate, calculate maximum operating pressure, vent line General operating parameters diameter, u-tube height, potential dangers if overloaded and immediate action to take if overloaded. Explain purpose and location of the control choke/s in the Purpose of this equipment Control Chokes well control system: e.g. manual, hydraulic, fixed. (Manual and/or I Select general operating parameters: e.g. how they operate, Hydraulic) General operating parameters maximum operating pressure, positive seal or leak potential, control of operating speed. ROV Hotstab e.g. how they operate, maximum operating pressure, positive A Purpose of this equipment Capability seal or leak potential, control of operating speed. Riser Gas Handling State the purpose of this equipment in the well control I Purpose of this equipment Equipment process and potential dangers with its use. Stripping and State the purpose of this equipment in the well control I Purpose of this equipment Tripping Tanks process: e.g. monitoring for leaks, for stripping process Role of Rules and Common industry regulation bodies for well State major regulating bodies for the student’s area of A Regulations control operation.
4.14. Extract of Subsea Elements Module Name: Extract of Subsea Elements Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to:
Page 35 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Extract of Subsea Elements Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Technical Principles Compressibility and Temperature State how temperature affect fluid properties: e.g. weight, Effects on Oil How mud temperature can affect fluid viscosity and gel strength, potential for hydrate formation, I Based Fluids (Non properties. effect on mud in subsea choke and kill lines, heat expansion, Aqueous Fluids crystallization of brines. (NAF)) and Brines. Describe how different operations can impact ECD and the resulting effect on bottom hole pressure: e.g. reduction when pumps are stopped at connections or flow checks, circulation How ECD affects bottomhole pressure. Equivalent across flowline versus circulating through subsea choke or kill Circulating line, pumping out of the hole, circulating cement, high Density (ECD) & I viscosity pills, pumping lost circulation material. Bottom hole Describe the process of ECD drilling state the potential well Pressure (BHP) control problems that can arise from this process: e.g. The principle of ECD drilling and associated underbalance on connections, connection gas, gas issues in well control problems. long marine Risers, narrow drilling window, mud weight displacement for tripping. State why the pressure of gas in the mud must be reduced in a controlled manner as it is brought to surface (circulated up Why a gas kick must expand as it is circulated hole): e.g. if not allowed to expand gas will increase wellbore Gas Behavior I up the wellbore. pressures, danger of allowing it to expand uncontrolled (reduced hydrostatic, well kick, Riser unloading), circulating through choke to maintain bottom hole pressure. Pre-Recorded Information Page 36 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Extract of Subsea Elements Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Give reasons for taking a CLF: e.g. used in well kill start-up procedure, potential increase in bottom hole pressure if used Reason for taking choke line frictions (CLFs). incorrectly or during latter stages of well kill, detect potential leaks in system. Select times a CLF can be taken: e.g. mud property changes, Choke Line Time/s a CLF should be taken. I pump output changes. Friction (CLF) Typical flow rate/SPM for a CLF. Choose acceptable flow rate/SPM for a CLF. Which gauges are commonly used to read the Select gauges to use to record a CLF. CLF value. The effect of taking the CLF on bottom hole Given various techniques for recording CLF state the effect on pressure. bottom hole pressure.
What effect choke and kill line fluid densities, Describe the effect on SICP of a choke or kill line having a Choke & Kill Line I that are different from the fluid density in the different fluid density than that in the well and possible Fluid Densities wellbore, have on preparations to kill a well. action to take prior to killing the well.
Kick Awareness during Drilling, Workover, & Completion Operations Describe procedure to bleed down ballooning and dangers associated with the bleed back process: e.g. bleed back Ballooning Issues M Procedure for bleeding down ballooning. amount, circulate bottoms-up, route through choke, danger of gas bled into well, gas expansion, gas in Riser. State what can increase risk of swabbing and surging during Casing & Factors that increase risk of swabbing and casing operations: e.g. narrow clearance, mud condition, Cementing M surging during casing running/pulling running or pulling speed, heave at connections, casing Operations operations. jewelry. Riser Margin. Define the term Riser Margin. Riser Margin M Calculate Riser Margin. Using given data calculate Riser Margin.
Page 37 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Extract of Subsea Elements Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Barriers State location of barriers at sea-floor and effect if breached: Philosophy and e.g. gas in Riser with only Diverter as a barrier, effect of Operations M Effect of subsea BOP on barrier location formation breakdown around wellhead, impact of blowout at Requiring Barriers sea bed, option to unlatch or ESD Kick Detection & Drills Select surface conditions that may make it difficult to accurately measure pit level: e.g. inoperable pit level sensors, Well Flow with Conditions on surface that can make it difficult M rig movement, incorrect line up of circulation system, mixing Pumps Off to get accurate pit level readings. mud, dumping or transferring fluid/by-pass shakers, tides, riser not connected, use of riser boost line Select surface conditions that may make it difficult to accurately measure pit level: e.g. inoperable pit level sensors, Conditions on surface that can make it difficult Pit Gain M rig movement, incorrect line up of circulation system, mixing to get accurate pit level readings. mud, dumping or transferring fluid/by-pass shakers, tides, riser not connected, use of riser boost line Select surface conditions that may make it difficult to Flow Returns Rate Conditions on surface that can make it difficult M accurately measure flow rate: e.g. inoperable flow sensor, rig Increase to get accurate flow rate readings. movement, tides, riser not connected, use of riser boost line Shallow Gas/Water Flows & Top Hole Drilling Shallow Subsea State how water depth affects the formation fracture How water depth affects formation fracture Fracture I pressure: e.g. distance from sea floor to rig floor (water depth pressures in shallow formations. Gradients and air gap), less compaction, narrower drilling window. Choose reasons for using blind and blind/shear rams: e.g. no Drilling & Tripping M Reasons for use of Blind/Shear Rams pipe in hole, blowout through drill string, emergency disconnect
Page 38 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Extract of Subsea Elements Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Shut-In Procedures & Verification Select actions that can be taken if well kicks with non- Running Casing Action to take if non-shearables are across M shearable tubulars across the BOP: e.g. use of Annular, casing and Cementing BOPs. rams, drop pipe, emergency disconnect issues Recording of Shut- State how shut-in pressure accuracy may be affected by In Pressures, Complications to reading accurate shut-in M water depth: e.g. cool mud in choke and kill lines, potentially Differences, and pressures in deepwater wells. high gel strengths that can mask real pressure. Float in String Reasons for mud flow from the Riser following State what can cause Riser flow following well shut-in: e.g. well shut-in. leaking BOP, gas migration in Riser. Riser Flow after M State the action to take if Riser is flowing following shut-in: Shut-In Action to be taken if the Riser is flowing e.g. Check for BOP operation, close another preventer, Divert following shut-in. overboard. Well Control/Risk Management Decision to State potential situations during a well kill that would require Circumstances during a well kill operation that Implement rig emergency procedures to be activated and the actions to would require emergency procedures to be Emergency M take to secure the well (if applicable): e.g. uncontrolled BOP initiated and possible actions to take to secure Procedures (e.g., leak, 'broaching' at surface, potential vessel collision, bad the well. during a Well Kill) weather, drive-off, toxic gas, fire. Well Kill Methods Demonstrate how to start up and shut down a well while How to handle choke line friction effects compensating for Choke Line friction. Drillers Method M during the well kill. State effect of choke line friction on surface pressures during the later stages of the kill process. Wait & Weight How to handle choke line friction effects Demonstrate how to start up and shut down a well while M Method during the well kill. compensating for Choke Line friction.
Page 39 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Extract of Subsea Elements Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: State effect of choke line friction on surface pressures during the later stages of the kill process. Kill Sheets M Kill sheets. Complete a kill sheet using given data (surface or subsea) How a Choke Line Friction greater than Shut-In State how a CLF greater than SICP affects start-up: e.g. Casing Pressure affects start-up. increased ICP, zero casing pressure. Pump Start Up State appropriate actions to minimize CLF effect on well when and Shut Down M Method used to shut down at the end of a kill shutting down: e.g. shut down procedure, check for trapped Procedure and verify well is dead pressure, monitor through choke, circulating practice once well is open. Trapped gas at the BOP. Define trapped gas at the BOP Explain how trapped gas can be a problem: e.g. gas trapped Problems associated with trapped gas at the beneath BOP can migrate when BOP opened, large-scale gas Trapped Gas at subsea BOP expansion; water depth, divert, danger of gas at rig floor. BOP I List basic steps to remove trapped gas: e.g. secure well below Procedure for safely removing trapped gas. choke line, flush choke line to light fluid, u-tube riser back up choke line, fill riser and monitor for residual flow. Displacing Riser I Reason for displacing Riser following a kill. Give reason for displacing Riser to kill mud. Post-Kill State dangers of uncontrolled gas expansion in the Riser: e.g. Handling Gas in I Dangers of Riser Gas. danger of unloading riser, danger to personnel, danger of fire, the Riser reduction in BHP.
Page 40 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Extract of Subsea Elements Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: State basic principles for preventing riser gas and handling technique: e.g. circulate proportion of bottoms up through choke line, effect of mud type of gas expansion, water depth Procedures for preventing and handling Riser effect, monitor riser on trip tank to see small gains due to Gas expansion, employ diverter to protect rig floor, possible use of flowline mud gas separators (include dangers associated with their use) Equipment Readiness/Assurance State the purpose of the Diverter in well control operations: Diverter I Purpose of Diverter e.g. for protection against gas in the Riser State the purpose of key items of equipment: e.g. LMRP, Riser Riser Equipment Connector, Slip Joint, Ball Joint, Flex Joint, Choke & Kill lines, BOP Stack, Stack Riser Dump valve, Booster Line, Bleed line Valves, and I State the purpose of key items of equipment on the subsea Wellhead BOP Stack: e.g. Annular, Pipe Rams, VBR's Blind/Shear Rams, Components Purpose of key equipment Casing Rams, Test Rams, Locking devices, Failsafe valves, wellhead connector Explain the purpose of this equipment in the well control process: e.g. to operate the BOP, give feedback on whether BOP Closing Unit I Purpose of this equipment BOP closed, feedback on operating pressure on BOP, & Control Panels secondary stations to operate the BOP. control valves in correct position, pump start-up facility set correctly.
Page 41 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT
Well Control Institute (WCI) Core Curriculum and Related Learning Outcomes for Drilling Operations: Supervisory
Module Name: Extract of Subsea Elements Learning Topics AIM* Learning Topics Assessments and Learning Outcomes The attendee will gain an understanding of: The attendee will be able to: Describe how key equipment in this system functions: e.g. Pods, fluid storage and accumulators, importance of pre- charge, pressure systems (main/pilot), valves and How the unit and control panel function piping/signals to the BOP, regulators, feedback instrumentation such as gauges, flow meter and lights, Block position. Select general operating parameters e.g. pressures to General operating parameters operate, maximum wellbore pressures. Interpret (at the level of a Supervisor) operation of gauges, flow meter and lights to check status of BOP during and after Potential failure and remedial actions during closing and opening operations: e.g. did BOP close, shut-in and on-going kill operation. demonstrate understanding panel lights, gauges and flow count to decide if BOP has functioned correctly. Deadman, State the purpose of this equipment in the well control Autoshear and Purpose of this equipment process and its basic functionality: e.g. basic difference Emergency I between the systems, reasons why, basic sequence of events. Disconnect Action to take in case of emergency State what action the Supervisor should take if an emergency- System disconnect disconnect is required. ROV Hot stab State the purpose of this equipment in the well control A Purpose of this equipment Capability process. Riser Gas State the purpose of this equipment in the well control Handling I Purpose of this equipment process. Equipment
Page 42 of 43 Prepared by Black & Veatch Corp. Revision 4B: May 14, 2014 DRAFT WORK PRODUCT – FOR INDUSTRY COMMENT