Well Control PRESENTATION Modified

7/26/2019 Well Control PRESENTATION Modified

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Types & methods & equipment



Primary well control

Secondary well control

Tertiary well control



By maintaining hydrostatic pressure (Ph) in thewellbore greater than formation pressure (Pf ) but

NEVER exceed the fracture pressure



Using blow out preventors (BOPS)



We use the BOPs at the blowout well and begin our

plan which is drilling “ RELIEF WELLS “ at specific

distance from the blowout well



kick : Kick is the Undesired Flow of Formation Fluids Into

the Wellbore

Blowout: is the Undesired Flow of Formation Fluids Into

the surface



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 )



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 )



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



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



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



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).



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.



Gas2.swf

Gas3.swf



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



Gas4.swf



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



BOP stack comprise various types of preventer

elements as :

1. Anuular preventer (bag type or spherical preventer)

1. Ram preventer



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



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



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



Designed to close off the hole when no pipe in the hole

If they are shut on drill pipe, they will flatten the pipe



Form of blind rams that are designed to cut drill pipe

when closed

last choice



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



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)

Well Control PRESENTATION Modified

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