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7/26/2019 Well Control PRESENTATION Modified
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Types & methods & equipment
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Primary well control
Secondary well control
Tertiary well control
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By maintaining hydrostatic pressure (Ph) in thewellbore greater than formation pressure (Pf ) but
NEVER exceed the fracture pressure
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Using blow out preventors (BOPS)
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We use the BOPs at the blowout well and begin our
plan which is drilling “ RELIEF WELLS “ at specific
distance from the blowout well
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kick : Kick is the Undesired Flow of Formation Fluids Into
the Wellbore
Blowout: is the Undesired Flow of Formation Fluids Into
the surface
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Improper monitor of pipe movements(drilling assembly and Casing )
Trip out and trip in
Swabbing during pipe movements
Lost of circulation
Insufficient mud weight ( abnormal pressureformation )
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Field history & drilling experience
primary : it mean that the well has already got a
kick (the formation fluid is in the wellbore)
secondary : means that the well may or may not
be under balance (check for flow )
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1. mud pit gain or loss
2. Increase in mud return rate
3. Change in flow line temperature
4. Variation in pump speed & standpipe pressure5. Swabbing
6. Hole fill volumes
7. Mud density reduction
8. Increase in rate of penetration ( ROP)9. Increase cutting size and shape
10. Increase torque & drag
11. Drilling exponent
Temperature Increase
Cuttings size & sDrille
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1. chloride change in mud ( delta chloride log )
2. Gas show
3. changing mud salinity & viscosity
4. Shale density
Normal
Pressure
Increasing
Formation Fluid
Pressure
Increasing Shale Density
9500’
9700’
9900’
10100’
9600’
9800’
10000’
10200’
Normal Trend Line
Shale
Shale
Shale
Sand
Sand
Sand
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The objective of various kill methods is to circulate
any invading fluid and circulate a satisfactory weight
of kill mud into the well
1. Driller’s method
2. Wait & weight method “ engineer’s method “
3. Concurrent method
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Having all the information at hand, following parameters are
determined before attempting to circulate the kick :
The influx has to be removed from the annulus
kill Mud weight
pump strokes
Quantity of weighting material
initial circulation drillpipe pressure
final circulation drillpipe pressure
Drillpipe pressure reduction schedule (for wait-and-weight method).
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The well is kept closed in while the pressures
stabilize.
When ready, the well is circulated with originalweight mud to remove the influx. Meanwhile kill
mud is prepared.
After completing the first circulation, kill mud iscirculated around to kill the well.
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Gas2.swf
Gas3.swf
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This method try to kill the well in one circulation
Mud is circulated out at the time the heavy mud is
pumped down the hole
As heavy mud pumped down to the bit ph increase till
it balances formation pressure
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Gas4.swf
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It kills the well in more than one Circulation may twoor three or more.
First circulation is not by the original mud weight
It depends on gradual increase in mud weight.
Every Circulation has its own initial & final circulation
pressure & its own step- by – step pressure dropschedule.
The well is Completely killed after last circulation
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BOP stack comprise various types of preventer
elements as :
1. Anuular preventer (bag type or spherical preventer)
1. Ram preventer
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Designed to stop flow from the well using a steel-
ribbed packing element that contracts around the drill
pipe
Packer will conform to the shape of the pipe in the bore
hole
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Have two opposing rubber packing elements that are
closed by moving them together
The main difference between it and annular one is thatdesigned for a certain type of pipe will work only on
that type of pipe
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Have semi-circular openings that match the diameter of
the pipe being used
The number of pipe rams in the hole depend on thedifferent sizes of pipes in the hole
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Designed to close off the hole when no pipe in the hole
If they are shut on drill pipe, they will flatten the pipe
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Form of blind rams that are designed to cut drill pipe
when closed
last choice
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Bop stack contain some mud access line and a drilling
spool for connection of choke and kill lines
Diverter system : which is low pressure system ,used below annular preventer to allow the flow to be
directed a way from the rig and where casing pressure
can’t contain shut-in pressure
Valves installed at the drill string to stop flow Kelly
cock valve
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Used to control of the kick and kill fluids
during kill operations
Capable of controlling the well using one ofseveral chokes and to divert flow to (reserve
pits , burn pits , degasser)