Well Control Program (WCP): An Ultimate Guide
Introduction
Well control program: A program designed to prevent blowout and
kingdom hydrocarbon release based on geological and engineering requirements.
About a better understanding of what is involved from the key aspects of a well
control regulatory program covering killing fluid needs to well control
equipment and specify pressure and safety requirements.
1.1 Well Control Program
1.1.1 Endorsement of
Completion/Workover Programs for Key Well Control Requirements
Well Control strategy, after
geological design and engineering design, is independently developed to meet
well control design demand to meet completion and workover. Here's a list of
the core elements of the program:
1) Killing Fluid Requirements
While designing killing in the well-bores,
the type and density of killing fluid should be calculated based on the
formation pressure and fluid properties.
The minimum amount of kill fluid
needed must be clearly stated because it will be needed in the event of an
emergency.
2) Preparation for well killing
materials
Pre-mixing of well-killing agents
(such as clear water, additives, and weighting agents) must be prepared in
advance.
Ensure the availability of required
chemicals (e.g., barite to increase fluid density, and polymers to enhance
fluid rheology).
3) Well Control Equipment
Specification and Configuration
They include definite BOP (Blowout
Preventer) specifications in size, pressure rating, and type (annular, ram, etc.).
Choke and kill manifold
specifications, including pressure ratings and configuration, shall be logged.
The program shall include a
schematic diagram of the well control system.
4) Requirements for installation,
commissioning and pressure tests
Well control equipment is required
to be installed on site according to industry practices.
All BOPs, choke manifolds, and kill
lines, which require verification at predetermined intervals, require pressure
testing.
Functional tests and operational
checks should be included as part of the commissioning rule set.
5) Blowout Preventive Devices in
Pipe String
The well control program shall
specify type and number of blowout preventive devices in the pipe string,
including float valves and safety joints and shear rams.
6) Safety Procedures for Certain
Operations
Tripping pipe strings, rotary
operations (drilling, RIH casing, etc.) and handling of large-diameter tools
such as drill collars and packers should have safety protocols.
Additional precautions need to be
taken with wireline logging operations and versus air holes.
7) Closure (Choke) Method Selection
Define appropriate shut-in for
different operating scenarios (soft shut-in, hard shut-in)
Such method must be based in
pressure of formation, conditions in wellbore and type of influx.
8) Protect and Safeguard environmental
There should be equipment and
procedures in place to protect the environment, prevent fires, and mitigate
hydrogen sulfide (H2S) related hazards.
Installation of gas detection devices
for toxic gases like H2S, CO2, SO2, etc.
1.1.2 Maximum Shut-in Pressure Predictive Model
And the well head shut in pressure
is based on geological data formation pressure.
This should be adapted to the
density, type and performance of kill fluid, with a sufficient safety margin.
Kill fluid volume and reserve is
maintained as per well kill requirement.
1.1.3 Properties of Formation Fluid
Reservoir fluid description, and
whether the well contains oil, gas, or water; the well control program
Gas to oil ratio (GOR), and liquid
to gas ratio → keep track of these for fluid behavior
Please also specify what is the type
of the reservoir (sandstone, carbonate, fractured).
1.1.4 Considerations with Pressure Data
Formation Pressure or Formation
Pressure Coefficient should be noted.
Formation pressure and wellhead
pressure are updated on a regular basis.
In order to detect early kicks and
achieve control, real-time pressure monitoring is required.
1.1.5 Requirements on Production Data
Production data – oil, gas and water
production rates (test yield and absolute open flow) should be included in the
program.
Analysis for performance evaluation
of wells to track production time and variations in production.
Designed to Monitor Water Injection,
Gas Injection (Steam) Rates and Dynamic Liquid Levels.
All this analysis assumes and
implies a wellbore which, while it may be filling / fluctuating, is not
otherwise changing.
Documentation must be made of cement
plug status, such as plug thickness and bridge plug position.
The casing strings specifications
must be provided (steel grade, wall thickness, outer diameter, and depth).
Ultimately, downhole tool
specifications, casing corrosion, deformation, and the presence of downhole
fish should be documented.
1.1.6 Well Killing and Choke Manifold Requirements
A well kill and choke manifold is
not always required for downhole operations.
But a simple well-killing and
bleed-off line not less than 50 mm in diameter must be fitted.
1.1.7 Blowout Preventer Tool Requirements
The specification, model and number
of blowout prevention tools in the pipe string must be determined accurately.
The program should necessitate the
availability of shear rams, annular preventers, and other key BOP components.
1.1.8 Gas indıcations
Monitoring of the presence and concentration
of hydrogen sulfide (H2S), sulfur dioxide (SO2), carbon monoxide (CO), and
carbon dioxide (CO2).
Plans for detection of and
mitigation of natural gas should be included as part of the well control strategy.
Conclusion
Proper safety, environmental
safeguard, and optimized well operations are hence to be provided at such a
level that they do not come into conflict with each other and hence a sound
well control program is an integral part in efficient well operations. This
includes development of killing fluid preparation, well control equipment
specification, pressure monitoring, and safety procedures to limit risk and
maintain operational integrity. Following these guidelines assists in reducing
blow outs, controlling formation pressures and improving production from wells.
With access to data in general up to October 2023, developing a solid well control strategy can optimize hydrocarbon recovery, enhance wellbore stability and meet regulatory requirements. In order to prepare personnel for well control challenges, regular updates, training and safety drills should be carried out.
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