Formation Stresses and Strength I The term “formation strength.” Explain the term “formation strength.” Why formation strength is important. Explain why we need to know formation strength (for example, to determine the maximum pressure that can be safely applied to the open hole shoe formation). How formation strength can be determined on the rig. Explain the differences between FIT and LOT; explain how to conduct FIT and LOT Key tasks to ensure an accurate FIT/LOT. Explain the key tasks to carry out to to ensure accurate FIT/LOT measurements (for example, clean the hole, ensure consistent mud weight around the well, calibrate the pressure gauges, and test the surface equipment for leaks). Maximum Anticipated Surface Pressure A Define the term “Maximum Anticipated Surface Pressure” (MASP). Define the term “maximum anticipated surface pressure.” How MASP is used in well design. Explain why MASP is important for well control/integrity (for example, the consequences of exceeding maximum pressure limitations; BOP selection; casing burst selection; wellhead rating; surface manifolds pressure ratings). Maximum Allowable Annular Surface Pressure and Maximum Allowable Mud Weight I The terms “Maximum Allowable Annular Surface Pressure” (MAASP) and “Maximum Allowable (leak- off) Mud Weight.” Explain the terms “MAASP” (Note: also known as Maximum Allowable Casing Pressure (MACP)) and “maximum allowable (leak-off) mud weight.” Why MAASP and maximum allowable mud weight are important to the Driller. State the consequences of exceeding MAASP or leak-off mud weight on well control/integrity (for example, lost circulation; a drop in mud level; potential kicks; downtime). Calculating MAASP. Calculate MAASP using given data on formation strength. When MAASP must be re-calculated. Give examples of when MAASP needs to be re-calculated. Ballooning I The term “wellbore ballooning.” Explain the term “wellbore ballooning.” How to recognize ballooning. Recognize drilling trends that help the Driller to identify potential ballooning (for example, losses while circulating; gains when the pumps are off).
Conditions on surface that can make it difficult to get accurate pit level readings. Analyze surface conditions that can make it difficult to accurately measure pit level (for example, inoperable pit level sensors; rig movement; incorrect line-up of the circulation system; mixing mud; dumping or transferring fluid/by-pass shakers; tides; the riser not being connected; use of the riser boost line). Action(s) to take in the event of an abnormal pit level. Explain and demonstrate action(s) to take if there is a pit level increase/decrease (for example, flow check, shut-in, and investigate other options such as the pit line-up [only after shut-in]). Abnormal trip tank returns when tripping pipe or during wireline operations. Identify abnormal trip tank readings from a trip sheet. Flow Return Rate Increase M Why flow rates are closely monitored at all times. Explain why it is important to monitor flow rates at all times when the rig is connected to the well (for example, open hole always has a potential to flow; tested barriers may fail). How to monitor the well to detect flow rate increases. Demonstrate the set-up of the flow rate monitoring system (for example, the correct line-up). Acceptable alarm limits for flow rates. Demonstrate the set-up of the flow rate alarm system (for example, the acceptable values for high and low level alarms set on the flow rate indicator). What operations can increase or decrease flow rate that are not related to increased flow or losses in the well. Assess surface operations for false flow rate indications of a kick or losses (for example, increased SPM; a dumping trip tank; leaks in the surface system). Accurate flow rate readings. Analyze surface conditions that can make it difficult to accurately measure flow rate (for example, an inoperable flow sensor; rig movement; tides; a leaking slip joint; the use of the riser boost line). Action(s) to take if there is an abnormal flow reading. Explain and demonstrate action(s) to take if there is a flow rate increase/decrease (for example, flow check, shut-in, and investigate other options [only after shut-in]).
Sub-Modules AIM Learning Topics Learning Objectives and Assessment Guidelines The instructor will impart knowledge on: The attendee will be able to: Kick Log I Reason for recording data following a kick. Explain why shut-in data is recorded (for example, to show the buildup of pressures over time; to calculate kill data). Main data to record following a kick. Identify main data to record following shut-in (for example, pressures, volumes, and time). Gauges used when recording drillpipe and casing pressures. Record data from chosen gauges (for example, the choke panel gauges; compare with other gauges for variation/calibration). Evaluate the action to take if gauge readings show a discrepancy. Gas Migration I Identify gas migration based on shut-in pressures. Analyze shut-in data to determine if gas migration is taking place, and communicate with supervisor (for example, shut in drillpipe pressure, shut-in casing pressure). Action(s) the Driller must take if gas is migrating. Explain the action(s) to take if gas is migrating (for example, inform the Supervisor, monitor the pressure buildup and time). Trapped Pressure I Cause(s) of trapped pressure. Give examples of the possible causes of trapped pressure (for example, improper pump shutdown or startup). Effects of trapped pressure on wellbore pressures. Explain the effect that trapped pressure has on wellbore pressures (for example, an increased pressure in all parts of the wellbore). Procedure to reduce trapped pressure. Explain the procedure to reduce trapped pressure. Handling Ballooning I Bleeding fluid back from the well. List the potential dangers when bleeding back drilling fluid from a ballooning formation. Opening (Bumping) the Float Valve I Procedure to open the float to obtain Drillpipe Pressure (SIDPP). Demonstrate the procedure to open the float to read the SIDPP. Line-Up I Line-up in preparation for a kill. Demonstrate the line-up of pits, pumps, and manifolds in preparation for a kill. Line-up to monitor riser and potential annular/ram leaks. Demonstrate the line-up of the trip tank, valves, and manifolds to allow detection of a leaking BOP.
Procedure for displacing the riser and associated lines. Describe the procedure to use for displacement. 2.14 Casing & Cementing Considerations Module Name: 2.14 Casing & Cementing Considerations Sub-Modules AIM Learning Topics Learning Objectives and Assessment Guidelines The instructor will impart knowledge on: The attendee will be able to: Procedures when Running or Pulling Casing M Why the running speed is controlled. Explain why casing-running speed is controlled (for example, keep from surging and swabbing the well). Filling casing when running in the hole. Explain why casing is filled when running in the hole (for example, to maintain the integrity of the float valve due to differential pressure; to minimize the risk of casing collapse; to quickly recognize a kick inside the casing; to prevent underbalance if the float fails). Precautions when using a self-filling float. Explain problems of a self-filling float (for example, it allows formation fluids to flow directly up inside the casing; it allows cement to backflow up inside the casing). Cement Waiting Time A Effect of cement hardening on cement hydrostatic pressure and resulting BHP. Describe the effect of cement hardening on cement hydrostatic pressure and how that affects well control (for example, it reduces hydrostatic pressure; there is potential for a kick). Monitor the Well During and After Cementing Operations I Importance of maintaining pump-rate and monitoring pit levels during cementing and displacement. Identify reasons for monitoring flow changes during cementing and displacement operations (for example, to monitor for well flow or lost circulation). How a well is monitored during cement waiting time. Describe the procedure for monitoring the well during the cement waiting time (for example, monitoring flow returns in the trip tank). Cement Testing Procedure - Positive and Negative I Importance of testing after the cement job. Explain the importance of testing after a cement job (for example, to measure the integrity of the cement in place; the difference between testing cement behind casing strings and testing cement plugs).
How the unit and control panel work. Explain how key equipment in this system works (for example; fluid storage and accumulators; the importance of pre-charged, pressure systems, valves and piping to the BOP; regulators; feedback instrumentation such as gauges, flow meters, lights, block position, and bypass valve). General operating parameters. Explain general operating parameters (for example, pressures to operate; how wellbore pressure can affect operating pressures). Potential failure and remedial actions during shut-in and on-going kill operation. Monitor the operation of gauges, flow meter, and lights to check the status of the BOP during and after closing and opening operations (for example, demonstrate an understanding of panel lights and gauges to decide if the BOP has functioned correctly). Function Tests and Pressure Tests I Difference between function and pressure tests. Describe a function test and a pressure test; explain the differences between the two tests. Difference between high- and low-pressure tests. Describe a high-pressure test and a low-pressure test, and explain the differences between the two tests (for example, typical test values; holding time; test fluid type; test sequence). How often tests must be carried out. Explain how often these tests are to be carried out, what equipment must be tested. Monitoring Equipment Failures/Erroneous Readings M Common failures. Detect errors in gauge readings based on the discrepancy between gauges (for example, the drillpipe and casing gauges on the standpipe manifold, the choke manifold, and the choke panel; analog versus digital). Deadman, Autoshear, and Emergency Disconnect System I Purpose of this equipment. Explain the purpose of this equipment in the well control process and its basic working (for example, the basic difference between the systems, reasons for the differences, and the basic sequence of events). Action to take in case of an Explain the action the Driller must take if an emergency-disconnect is required. Mud-Gas Separator I Purpose of this equipment. Explain the purpose and location of the mud-gas separator in the circulating system.