IWCF Level 3 DWC study plan

Define primary well control barrier and secondary well control barrier, and list which physical equipment serves each role on a typical rig

Explain how formation pressure, hydrostatic pressure, and bottom hole pressure relate, and calculate BHP from mud weight and true vertical depth in both SI and field units

Derive mud weight required to balance a stated pore pressure gradient, and state why overbalance margin is applied

Convert between pressure gradient, mud weight, and equivalent mud weight (EMW) for at least five worked examples

Identify the causes of kicks grouped as swabbing, lost circulation, insufficient mud weight, and abnormal pressure, and give a rig-floor trigger for each

Describe the sequence of events that produces a swab kick during a trip, including tripping speed, gel strength, and bottom hole pressure reduction

Explain kick tolerance and annular capacity concepts and why they limit how far a well can be drilled ahead

Distinguish shallow gas hazards from deeper kick scenarios and state the operational differences in response

List positive kick indicators and interpret them against pit gain, flow rate, and pump pressure changes

Explain the difference between a positive indicator and a negative indicator of a kick and give three examples of each

Describe the correct first actions on detecting a kick while drilling, while tripping, and while static, and state why shutting in fast preserves influx size

Analyze how pit gain and shut-in drill pipe pressure behave in a gas influx versus a saltwater influx

Explain the purpose of the soft shut-in and hard shut-in procedures and compare their advantages and risks

Describe how to record shut-in drill pipe pressure (SIDPP) and shut-in casing pressure (SCP) and what each reading tells you about influx and formation pressure

Calculate formation pressure from SIDPP and current mud weight, and calculate kill mud weight

Explain what a stabilized SIDPP confirms and what pressure behaviour suggests an influx is still migrating

Describe the driller's method sequence and state which pressure is held constant on each circulation

Describe the wait and weight method and compare its pressure schedule with the driller's method

Explain initial circulating pressure, final circulating pressure, and the slow circulating rate pressure used to build the kill sheet

Calculate kill mud weight, initial circulating pressure, and final circulating pressure for a worked example

Explain the behaviour of SIDPP and SCP when gas is allowed to migrate with the well shut in, and state the correct action

Describe the volumetric method for allowing gas to expand while holding casing pressure within limits

Explain why casing shoe pressure is the limiting constraint and how to check it against formation fracture pressure

Identify what happens to bottom hole pressure if gas is circulated out without allowing expansion

Describe well control equipment functions: BOP stack arrangement, choke manifold, accumulator, and choke line, and state the purpose of each in a kill operation

Explain the function of the annular preventer versus the pipe rams and when each is used

Describe choke adjustments needed to hold casing pressure on the gauge while bringing the pump to kill rate

Explain the risks of a kick while tripping, including the use of a trip tank, and the actions to take

Re-derive every key formula from memory: hydrostatic pressure, EMW, kill mud weight, ICP, FCP, and casing shoe pressure

Work through five timed mixed scenarios covering kick detection, shut-in, kill method selection, and migration control

Identify personal weak areas from the timed scenarios and close each gap with targeted re-study

State the standard well control actions and reporting sequence expected of a Level 3 candidate in a kick situation