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Causes of Well Kick, Secondary Well Control, Primary Well Control
relies…
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Secondary Well Control
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Regain Primary WC by:
Removing any influx of gas,
oil or water from the well
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Regaining
Control
Shutting In
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Effects
Allows pressure to build up in the well which
– combined with the hydrostatic head
of the fluids in the pipe and annulus
– will eventually balance BHP.
This equilibrium situation
thus prevents further
flow into the Well
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Removal
of Influx
3 Methods
3) Bullhead
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When a gas kick is taken
in a deep high pressure
well which would result in
excessively high surface
pressures.
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1) Circulation
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Which Method to Use?
Driller's Method
The limited and largely theoretical
benefits of the W&W method
are generally seen to be outweighed by
the practical application of the Drillers method.
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Shallow Gas
Characteristics
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Gas leaks, followed by ignition and fire
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Procedures
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Hydrostatic Control
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Avoidance of losses
(controlled ROP, solids control,
deeper conductor pipe shoe, etc.)
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Sources
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Petrogenic Gas
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Methane, Ethane and Propane
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"gas effect"
can cause the top of the reservoir to be abnormally pressured with respect to the local hydrostatic gradient
Well Control Equpment
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Annular Preventer
Life span
Testing the annular preventer under high test pressures significantly shortens the life of the packing element.
Closing the annular preventer without pipe in the hole will shorten the life of the packing element, especially when high closing pressures are required to achieve this.
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Motion reversal is hard on the packing element, so pipe should be moved as far as possible in one direction before reversing the direction (i.e. long strokes).
Barriers
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Groups
Fluid barriers
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Dynamic Fluid Column –
Continual fill, restricted to
total loss conditions.
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Mechanical barriers
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Examples
Cement plugs, tagged and tested.
Cemented liners, pressure tested and the liner lap (& liner top packer) inflow tested.
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BOPs –pressure tested drilling, wireline and Coiled Tubing stacks.
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SSSV: Safety valves are generally considered a barrier if inflow tested with a zero leak rate. (NB: API definition of a sub-surface safety valve includes an acceptable leak rate)
Tubing hanger seals pressure tested via the hanger test ports in the wellhead or against the casing.
Plugs with bi-directional seals (O-rings or solid seal elements) are considered to be a barrier if inflow tested, or under some circumstances pressure tested from above.
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