Well Control Procedures & Basics

Procedures & well control basics
“A good understanding of basic mathematics is required for every well control
operation”

Shut-in Procedures & Well Control Basics
SHUTTING THE WELL IN - PROCEDURE
❑ Once a kick has been detected, the well should be controlled according to correct procedures. Shut-in procedures require common sense.
❑ At times of excitement or emergency, there must be strong control and discipline on the rig floor. Drills, planned procedures and strong
supervision are the keys to successfully controlling the well.
❑ Once a kick has been detected, the well should be shut in as quickly as possible. The reasons for shut-in procedures include:
❑ To protect the crew and rig.
❑ To stop the influx of formation fluid into the wellbore.
❑ To allow shut-in pressures to be determined
❑ To provide an opportunity to organize the kill procedure.
PROCEDURES

SHUTTING THE WELL IN - PROCEDURE
❑ There is no such thing as a small kick or a small flow. Either can rapidly develop into a blowout.
❑ All flows must be recognized as potential blowouts. When in doubt as to whether the well is flowing or not – shut it in.
❑ Shut-in procedures may vary considerably, depending on company policy, the type of rig and the size of the crew.
❑ However, the basics of shutting a well in do not change.
❑ A preventer must be closed to stop the flow. There are debates as to which method is the proper one to use, a hard or soft shut in, or a
modification of either.
❑ All wells are different, and procedures should be decided upon, posted, known and practiced on an individual well or activity basis.
PROCEDURES

SHUTTING THE WELL IN – PROCEDURE
PROCEDURES

FLOW CHECK PROCEDURES
❑ A flow check consists of observing a well with pumps shut off to determine whether it is flowing.
GENERAL FLOW CHECK PROCEDURES
FLOW CHECK WHILE DRILLING
1. Alert the crew
2. Pick up off the bottom and clear uppermost tool joint above the rig floor
3. Stop the rotary
4. Shut off pump
5. Observe the well for flow
FLOW CHECK WHILE TRIPPING
1. Alert the crew
2. Set slips so the last tool joint is at normal working level above rig floor
3. Install full open safety valve in open position
4. Observe the well for flow
Note: Make flow check prior to pulling BHA through BOPs. If the well is flowing, shut-in procedures should begin immediately.
PROCEDURES

Objectives
❑ To know the importance of kill sheet preparation
❑ To Design a kill mud weight to kill the kicked well
❑ To understand the commonly used well killing methods for bringing well to the primary
control from secondary control.
Kill Sheet Preparation & Killing Methods

Why do we prepare kill sheet?
To Design the following parameters
• Maximum Allowable Mud Weight
• Initial MAASP
• Final MAASP
• Total Wellbore Volume (Capacity of DP+DC+HWDP+Annulus)
• Total Circulation Time
• Kill mud Weight
• Initial Circulating Pressure (ICP)
• Final Circulating Pressure (FCP)
• Fracture Pressure

Kill Sheet Preparation
Data Collection for Kill Sheet Preparation
Hole Dimensions
• Casing Size
• Casing Shoe Depth
• Open Hole Diameter
• Hole Depth
• Drill Pipe
• Heavy Weight DP
• Drill Collars
Capacities
• Drill Pipe Capacity
• Heavy Weight DP Capacity
• Drill Collars capacity
• CSG to Pipe Annulus
• OH to Pipe / HW Annulus
• OH to Collar Annulus
Pumping Data
• Pump Output
• Slow Circulating Rate Pressure up to 40 SPM
Fracture Data
• Leak Off Test Pressure
• Mud Weight In Hole At Test
Kick Data
• Mud Weight In Hole
• SIDPP
• SICP
• Pit Gain

Pipe Capacities
• Drill Pipe Capacity
ID of DP should be known
• Heavy Weight DP Capacity
ID of HWDP should be Known
• Drill Collars capacity
ID of DC should be Known
Annular Capacities
• CSG to Pipe Annulus
ID of CSG & OD of DP Should be Known
• OH to Pipe / HW Annulus
Hole Diameter & OD of DP and HWDP Should be Known
• OH to Collar Annulus
Hole Diameter & OD of DC Should be Known
𝑷𝒊𝒑𝒆 𝑪𝒂𝒑𝒂𝒄𝒊𝒕𝒚 =
𝑰𝑫 𝟐
𝟏𝟎𝟐𝟗. 𝟒
−−−−−−−−− −(
𝒃𝒃𝒍𝒔
𝒇𝒕
)
𝑨𝒏𝒏. 𝑪𝒂𝒑𝒂𝒄𝒊𝒕𝒚 =
𝑫𝒉
𝟐
− 𝑫𝒑
𝟐
𝟏𝟎𝟐𝟗. 𝟒
−−−−−− −(
𝒃𝒃𝒍𝒔
𝒇𝒕
)

KICK DATA
• Mud Weight in Hole
Density of the mud at the time of kick
• SIDPP
Recorded at the pressure gauge attached to the
choke manifold
• SICP
Recorded at the pressure gauge at the stand pipe
• Pit Gain
How much barrel increased in the pit mud tank at
the surface
Fracture Data
• Leak Off Test Pressure
By Conducting LOT Test after setting &
Cementing the casing
• Mud Weight in Hole at test
Mud weight used for LOT Test

Important Parameters Required from Kill Sheet
• Maximum Allowable Mud Weight
Maximum limit of the mud of the formation to withstand
• Initial MAASP
Maximum Allowable Annulus Surface Pressure is the maximum limit of the pressure in the annulus
before kill the well
• Final MAASP
Maximum Allowable Annulus Surface Pressure is the maximum limit of the pressure in the annulus after
kill the well
• Total Wellbore Volume (Capacity of DP+DC+HWDP+Annulus)
Volume of Drilling mud occupied in the wellbore.

Important Parameters Required from Kill Sheet
• Total Circulation Time
Time required for the fluid to return to the surface
• Kill mud Weight
Weight of the Drilling Mud to kill the kicked well to get it stable
• Initial Circulating Pressure (ICP)
Initial Pressure Required for the mud through the DP to start circulation for killing the well
• Final Circulating Pressure (FCP)
The Pressure at the bit when kill mud reach to the bit
• Fracture Pressure
The Drilling mud Pressure at which the formation at the shoe brakes
Fracture Pressure = LOT Pressure + HSP (at the mud weight used in LOT Test)

Capacities
Drill Pipe Capacity = 0.01776 bbls/ft
Heavy Weight DP Capacity = 0.0088 bbls/ft
Drill Collars capacity = 0.00768 bbls/ft
CSG to Pipe Annulus = 0.0505 bbls/ft
OH to Pipe / HW Annulus = 0.0459 bbls/ft
OH to Collar Annulus = 0.0292 bbls/ft
Hole Dimensions
Casing Size = 9-5/8 “
Casing Shoe Depth = 7950 “ ft (TVD = 7950 ft)
Open Hole Diameter = 8-1/2”
Hole Depth = 9800 ft (TVD = 9800 ft)
Drill Pipe = 5” OD ; Length = 8700 ft
Heavy Weight DP = 5” OD ; Length = 500 ft
Drill Collars = 8” OD; Length = 600 ft

Pumping Data
Pump Output = 0.119 bbls / stroke
Slow Circulating Rate Pressure at 40 SPM = 500 Psi
Fracture Data
Leak Off Test Pressure = 1970 psi
Mud Weight in Hole at test = 10.5ppg
Kick Data
Mud Weight in Hole = 11.3 ppg
SIDPP = 450 psi
SICP = 500 psi
Pit Gain = 14 bbls
Putting Data in the kill sheet and calculate as per instructions in the kill sheet

Well Killing Methods
Objectives of the killing operations
• To Restore Primary well control
In order to do this, It is necessary to do the following:
• Remove the influx
• Replace the current mud with the Havier Mud
Killing Methods
• Driller’s Method
• Wait & Weight Method

Driller’s Method
• Two Circulations Method
• More Time Consuming
• High Chance of Secondary Kick
Wait & Weight Method
• Single Circulation Killing Method
• Less Time Consuming
• less Chance of Secondary Kick

Important Points:
The original mud weight is used to circulate the influx
Important Steps:
- Reset the stroke counter.
- Bring the pump up to kill speed while holding the casing pressure constant.
- Maintain DP pressure constant until the influx is circulated out from the well
BHP
Bottom
Hole
Pressure,
Psi
Pumping Volume, bbl
Driller’s Method : 1st Circulation

The maximum shoe pressure is when the top of the influx reaches the shoe
Casing
Shoe
Pressure,
Psi
Pumping Volume, bbl
Surface
Casing
Pressure,
Psi
Pumping Volume, bbl

When the influx is passing the casing shoe, the shoe pressure will decrease.
Casing
Shoe
Pressure,
Psi
Surface
Casing
Pressure,
Psi
Pumping Volume, bbl
Pumping Volume, bbl

When the influx is above the casing shoe, the shoe pressure will remain constant.
Casing
Shoe
Pressure,
Psi
Pumping Volume, bbl
Surface
Casing
Pressure,
Psi
Pumping Volume, bbl
SICP
Driller’s Method : 1st Circulation Well Killing Methods

- Surface casing pressure is increasing as the influx is circulated up the well.
- Pit volume is raising.
Surface
Casing
Pressure,
Psi
Pumping Volume, bbl
SICP
Driller’s Method : 1st Circulation Well Killing Methods

SICP
- The maximum surface casing pressure is reached when the top of the influx is at
surface.
- It will be the maximum increase in pit level.
Surface
Casing
Pressure,
Psi
Pumping Volume, bbl

- As the influx is passing through the choke, the surface casing pressure will decrease.
- The pit volume will decrease.
Surface
Casing
Pressure,
Psi
Pumping Volume, bbl
SICP

If all the influx is successfully circulated from the well and the pump is stopped,
SIDPP = SICP

• Line up the kill mud.
• Reset the stroke counter.
• Bring the pump up to kill speed while holding the casing pressure
constant.
• Reset the stroke counter after pumping the surface line volume.
• Keep the casing pressure constant until KMW reach the bit.
• ( Or follow the calculated DP pressure drop schedule from ICP to FCP.)
• Pit volume has increased due to the weighting material added in the
system.
• When kill mud enters the annulus, maintain FCP constant until kill mud is
at surface.
Driller’s Method : 2nd Circulation

Driller’s
Method
Driller’s
Method
Drill Pipe
Casing

Driller’s
Method
Driller’s
Method
Drill Pipe
Casing
Driller’s Method : 2nd Circulation

Advantages:
• Can start circulating right away
• Able to remove influx even if not enough barite on board
• Less chance of gas migration
• Less calculation
Disadvantages:
• Higher surface pressure
• In certain situation, higher shoe pressure
• Two circulation, more time through the choke
Driller’s Method :

Driller’s Method (Review)
1) The well is shut in.
2) Record Shut in Drill pipe/Casing pressures.
3) Circulation is started by holding casing pressure constant until pump is at kill rate.
4) When pump speed is at kill rate, drill pipe pressure is recorded and kept constant with choke adjustments as
necessary. Drill pipe pressure should be the sum of SIDPP and kill rate pump pressure.
5) The drill pipe pressure and pump rate are kept constant until the kick is circulated out of the hole.
6) Then the well is shut in (or circulated) and the fluid weight increased.
7) A heavier fluid is prepared and circulation is started again. Either a pressure chart is followed or the casing
pressure is kept constant (assuming no additional influx) until the drill pipe is full of new heavy fluid.
8) When the drill pipe is full of heavy fluid FCP should be maintained until the annulus has been displaced with kill
fluid.

• The kill mud weight is used to circulate the influx
• Reset the stroke counter
• Bring the pump up to kill speed while Holding the
casing pressure constant.
• Reset the stroke counter after pumping the surface line
volume.
• Pump kill mud from surface to bit while following a
calculated DP pressure drop schedule.
• When kill mud enters the annulus, maintain FCP
constant until kill mud is at surface.
BHP
Bottom
Hole
Pressure,
Psi
Pumping Volume, bbl

Drill Pipe
Casing

Advantages:
• Can generate lower pressure on formation near the casing shoe
• In most situation generate less pressure on surface equipment
• With a long open hole, less chance to induce losses
• One circulation, less time spent circulating through the choke
Disadvantages:
• Longer waiting time prior to circulate the influx
• Cutting could settle down and plug the annulus
• Gas migration might become a problem
• Need to have enough barite to increase the mud weight
• More Calculations

Wait & Weight Method (Review)
1) The well is shut in after a kick and stabilized SIDPP, SICP and kick size information recorded.
2) The first calculation should be kill fluid density.
3) The rest of the worksheet is filled out while the fluid density in the pits is increased.
4) When ready to circulate, the pump is brought to kill rate speed while maintaining proper casing (backpressure) with
the adjustable choke.
5) Maintain drill pipe (or tubing) pressure according to the pressure chart. All pressure adjustments begin with
adjustment of casing (backpressure) from the choke. Every pressure adjustment should be recorded.
6) When heavy fluid reaches the bit, maintain drillpipe (or tubing) pressure at the Final Circulating Pressure until kill
weight fluid returns to surface.
7) When gas, or liquid following the gas, starts to go through the choke, casing pressure must be stabilized at the last
recorded value. Once pressures stabilize, then drillpipe (or tubing) pressure must be adjusted and kept at its
proper value until the well has been killed.

WELL # ABC
FIELD - XYZ
Hole Size 8.5 inch O-H/DC Capacity 0.03221 bbl/ft
Hole Depth TVD/MD 11536 ft O-H/DP-HWDP Capacity 0.0447 bbl/ft
Casing 9-5/8” TVD/MD 9875 ft C-H/Drill Pipe Capacity 0.04891 bbl/ft
DP Capacity. 0.01741 bbl/ft Fracture EMW 16.9 ppg
HWDP Length 600 ft SIDPP 530 psi
HWDP Capacity 0.00874 bbl/ft SICP 700 psi
DC 6-1/4” Length 880 ft Pump Displacement 0.1019
bbl/str
k
DC Capacity 0.00492 bbl/ft RRCP 30 SPM 650 psi
Mud Weight 14 ppg Pit Gain 10 bbl
CASE STUDY
OBSERVE NORMAL WELL BEHAVIOR
FOR:
1. Driller’s Method
2. Wait & Weight Method

37
DRILLERS METHOD
1st CIRCULATION
DP
Pf= 8928 psi
SHUTT IN WELL
1489
MAASP
CSG
0
O C
530 700
0
BHP= 8928 psi
7889
psi
7189
psi

DRILLERS METHOD
1st CIRCULATION
Pf= 8928 psi
BHP= 8928 psi
O C
700
30
22
1180
DP
REACHING: ICP
• CP: Keep constant while bringing
pumps up
• Pumps up and pressure stabilized
• DPP: Keep constant
1489
MAASP
CSG
7889
psi

DRILLERS METHOD
1st CIRCULATION
Pf= 8928 psi
BHP= 8928 psi
GAS IN OPEN HOLE
• DPP: Constant
• Gas Influx: Expands
• CP: Increases
• Shoe Pressure: Increases
• MAASP: Constant
O C
30
1180
310
740
DP
1489
MAASP
CSG
7929
psi

DRILLERS METHOD
1st CIRCULATION
Pf= 8928 psi
BHP= 8928 psi
GAS REACH SHOE
• DPP: Constant
• CP: Increases
• Shoe Pressure: Increases to Max
• MAASP: Constant
O C
1180
30
470
775
DP
MAASP
1489
CSG
7964
psi

DRILLERS METHOD
1st CIRCULATION
Pf= 8928 psi
BHP= 8928 psi
GAS MOVES INSIDE
CASING
• DPP: Constant
• SICP: Increases
• Shoe Pressure: Decreases
• MAASP: Increases
O C
1180
30
620
785
DP
MAASP
1685
CSG
7718
psi

DRILLERS METHOD
1st CIRCULATION
Pf= 8928 psi
BHP= 8928 psi
GAS MOVING INSIDE
CASING
• DPP: Constant
• CP: Increases
• Shoe Pressure: Constant
7718
psi
O C
1180
30
2300
1120
DP
2020
MAASP
CSG

DRILLERS METHOD
1st CIRCULATION
Pf= 8928 psi
GAS REACH CHOKE
• DPP: Constant
• CP: Increases to Max
• MAASP: Increase To Max
7718
psi
BHP= 8928 psi
O C
1180
30
4800
1580
DP
MAASP
2480
CSG

DRILLERS METHOD
1st CIRCULATION
Pf= 8928 psi
GAS OUT OF WELL
• DPP: Constant
• CSG Pressure: Decreasing to SIDPP
• CP: Constant
• MAASP: Decreases to Original Value
7718
psi
BHP= 8928 psi
O C
1180
30
5400
530
DP
1489
MAASP
CSG

DRILLERS METHOD
2nd CIRCULATION
Pf= 8928 psi
START PUMPING
KILL MUD 14 PPG
• CP: Constant
• MAASP: Constant
7718
psi
BHP= 8928 psi
O C
30
1180
5400
530
DP
1489
MAASP
CSG

DRILLERS METHOD
2nd CIRCULATION
Pf= 8928 psi
KILL FLUID INSIDE
DRILL PIPE
• CP: Constant
• DPP: Decreases
• MAASP: Constant
7718
psi
BHP= 8928 psi
O C
530
30
6306
936
DP
1489
MAASP
CSG

DRILLERS METHOD
2nd CIRCULATION
Pf= 8928 psi
KILL MUD REACH
BIT
• CP: Constant
• DPP: Decreases to FCP
• MAASP: Constant
7718
psi
BHP= 8928 psi
O C
530
30
7212
692
DP
1489
MAASP
CSG

DRILLERS METHOD
2nd CIRCULATION
Pf= 8928 psi
KILL MUD REACH
SHOE
• DPP: Constant
• CP: Decreases
• MAASP: Constant
7657
psi
BHP= 8928 psi
DP
1489
MAASP
CSG
O C
692
30
7832
469

DRILLERS METHOD
2nd CIRCULATION
Pf= 8928 psi
KILL MUD INSIDE
CASING
• DPP: Constant
• CP: Decreases
• MAASP: Decreasess
7657
psi
BHP= 8928 psi
O C
692
30
10202
233
DP
MAASP
CSG
1253

DRILLERS METHOD
2nd CIRCULATION
Pf= 8928 psi
KILL MUD AT
SURFACE
• DPP: Constant
• CP: Decreases to Zero
• MAASP: Decreases to New MAASP
with KMW
7657
psi
BHP= 8928 psi
O C
692
30
12600
0
DP
MAASP
CSG
1020

Pf= 8928 psi
SHUTT IN WELL
Mixing Kill Mud 14.9
BHP= 8398 psi
7889
psi
7189
psi
WAIT & WEIGHT METHOD
0
O C
530 700
0
DP
1489
MAASP
CSG

Pf= 8928 psi
BHP= 8928 psi
7889
psi
O C
700
30
22
1180
DP
1489
MAASP
CSG
REACHING
ICP
• CP: Keep Constant While Bringing
Pumps Up
• Pumps Up And Pressure Stabilized
• DPP: Keep On Schedule

Pf= 8928 psi
BHP= 8928 psi
7929
psi
GAS IN OPEN HOLE
• DPP: Decreases
• CP: Increases
• Shoe Pressure: Increases
• MAASP: Constant
O C
30
310
1097 740
DP
MAASP
CSG
1489

Pf= 8928 psi
BHP= 8928 psi
7964
psi
GAS REACH SHOE
• DPP: Decreasing
• CP: Increases
• Shoe Pressure: Increase To Max
• MAASP: Constant
O C
30
470
1053 775
DP
MAASP
CSG
1489

Pf= 8928 psi
BHP= 8928 psi
7718
psi
GAS MOVES INSIDE
CASING
• DPP: Decreases
• CP: Increases
O C
30
620
1013 785
DP
MAASP
CSG
1685

Pf= 8928 psi
7718
psi
KILL MUD AT BIT
GAS INSIDE CASING
• DPP: Decreases to FCP
• CP: Increases
O C
30
1812
692 1050
DP
MAASP
CSG
1950
BHP= 8928 psi

Pf= 8928 psi
7641
psi
KILL MUD AT SHOE
GAS INSIDE CASING
• DPP: Constant
• CP: Increasing
• Shoe Pressure: Decreasing
O C
30
2432
692 1080
DP
MAASP
CSG
1980
BHP= 8928 psi

Pf= 8928 psi
7641
psi
KILL MUD INSIDE
CASING
GAS REACH CHOKE
• DPP: Constant
• CP: Increases
BHP= 8928 psi
O C
30
4800
692 1278
DP
MAASP
CSG
2178

Pf= 8928 psi
7641
psi
KILL MUD INSIDE
CASING
GAS OUT OF WELL
• DPP: Constant
• CP: Decreasing
• MAASP: Decreases
BHP= 8928 psi
O C
30
5360
692 180
DP
MAASP
CSG
1204

Pf= 8928 psi
7641
psi
KILL MUD AT
SURFACE
• DPP: Constant
• CP: Decreases to Zero
• MAASP: Decreases to New MAASP
with KMW
BHP= 8928 psi
O C
30
7200
692 0
DP
MAASP
CSG
1027

Well Control Procedures & Basics

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