P&P Hand Out

7/21/2019 P&P Hand Out

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1

WELL CONTROL

It Is An Influx Of Formation Fluid Into The Well.

What Is A Kick?

2

WELL CONTROL

An Uncontrolled Exit Of The Formation Fluids At The Surface

What Is A Blowout?



3

WELL CONTROL

Pore Spaces

Grains

What Is Formation Pressure?

All Formations We Drilled Consists of Rock

Grains and Pore Space.

Formation Fluid Pressure Is the Pressure of

the Fluids That Exist in Pore Space

4

WELL CONTROL

Preventing A Kick

PRIMARY MUD HYDROSTATIC

What Is Well Control?

Shutting In The Well After A Kick Has Been Taken

OR

SECONDARY BLOW OUT PREVENTERS



5

WELL CONTROL

PRIMARYPREVENTION

TAKE KICK

SHUT IN WELL

SECONDARY

KILL WELL

Well Control?

6

WELL CONTROL

How Can You Prevent A Kick?

KNOW WHAT CAUSES A KICK

USE CORRECT RIG PRACTICES



7

WELL CONTROL

MUD HYDROSTATIC FALLS

FORMATION

PRESSURE

OR

MUD

HYDROSTATIC

FORMATION PRESSURE RISES

8

WELL CONTROL

Causes Of Kicks

Kicks Occur When

“ Under Balance ”

Under Balance Is Caused by :

2. Increase in Formation Pressure.

1. Mud Hydrostatic Reduction.



9

WELL CONTROL

What Causes Mud Hydrostatic To Drop?

Pressure = Mud Wt X Constant X TVD

Reduce Mud Weight Reduce Length

Of Mud Column

?

?

?

?

?

?

10

WELL CONTROL

Running Into Bubbles

Mud Hydrostatic Reduction.



11

WELL CONTROL

Hole TVD 10,000ft (81/2”)Hole cap. 0.0772 bbl/ft

Dc / hole cap. 0.03 bbl/ft

Mud wt. 11 ppg

Formation gradient. 0.56 psi/ft

Influx size 10 bbls while POOH (Swabbing)

Gas gradient 0.1 psi/ft

What is effect on BHP when run back to the bottom

Example

12

WELL CONTROL

Circulating Hole Clean




13

WELL CONTROL

Drilled Gas

Gas in the Well Bore


14

WELL CONTROL

Effect of Gas Expansion

Example:-

well depth 7000’

mud wt. 11 ppg

influx (gas) volume 1 cu. Ft

Calculate vol. Of gas @ 6000’, 5000’, 4000’, 3000’,

2000’, 1000’, 500’, 250’ and @ surface

gas Pressure @7000’ = 11 X .052 X 7000=4000 psi

Vol. Of gas @6000’ =1.16 cu.ft

@5000’ = 1.39 cu.ft @4000’ = 1.75 cu.ft

@3000’ = 2.33 cu.ft @2000’ = 3.5 cu.ft

@1000’ = 7.00 cu.ft @500’ = 14.0 cu.ft

@250’ = 28.0 cu.ft @125’ = 56.0 cu.ft

@surface = 272 cu.ft



15

WELL CONTROL

Swabbing


16

WELL CONTROL

Main Causes:

Momentary reduction in BHP due to reduction in

hydrostatic force cased by the upward suction action

of the drill string, which can allow a small invasion

into well bore.

Swabbing

1. Pulling Pipe Too Fast2. High Viscosity Mud

3. Small Collar to Hole Wall Clearance

4. Balled-Up' Bit



17

WELL CONTROL

Pumping Light Mud


Bottom Hole Pressures

psi

18

WELL CONTROL

Loss of Barite

Centrifuge

Shakers

Desilters

Poor Mud/Settling

PitHole

What Can Reduce Mud Weight ?



19

WELL CONTROL

Losses

20

WELL CONTROL

Losses



21

WELL CONTROL

Rig Floor

Flowline

Pull Out Without Filling The Hole


22

WELL CONTROL

Casing Cap = Annular Cap + Pipe Cap + Metal Disp.

** All Capacities In bbls/ ft.

Pressure or Level Drop Per Foot Pulled

Mud Grad X Metal Displacement

( Casing Cap - Metal Displacement)Dry Pipe =

Mud Grad X Metal Disp. + pipe Cap

Casing Cap - Metal Disp. + Pipe Cap

Wet Pipe =



23

WELL CONTROL

Mud Weight = 12 ppg

Metal Disp = .0075 bbls / ft.

Pipe Cap = .0177 bbls / ft.

Casing Cap = .076 bbls / ft.

Stand Length = 93 ft.

Calculate Pressure Drop When

A) Pulling One Stand Dry.

B) Pulling One Stand Wet.

Example

24

WELL CONTROL

Mud Grad X Metal Displacement

( Casing Cap - Metal Displacement)Dry Pipe =

Answer

Mud Grad X Metal Disp. + pipe Cap

Casing Cap - Metal Disp. + Pipe CapWet Pipe =

12 X 0.052 X 0.0075

(0.076 - 0.0075)

= 6.8 psi

=

12 X 0.052 X (0.075 + 0.0177)

0.076 - (0.075 + 0.0177)

= 28.78 psi

=



25

WELL CONTROL

720 Ft Of 8” Drill Collars.

D.C. Capacity = .0077 bbls / ft.

D.C. Displacement = .0546 bbls / ft.

Mud Weight = 15 ppg.

Casing Capacity = .1497 bbls / ft.

Calculate.

A. Drop in Mud Level when all collars are pulled

from the hole without filling the annulus.

B. Drop in Bottom Hole Pressure.

Example

26

WELL CONTROL

Rig Floor

Flowline

Failure of Float collar



27

WELL CONTROL

Example

A13 3/8 String Casing Is Run Into The Hole With Conventional Float. The

Driller Did Not Fill The Casing For Fourteen 40 ft Joints. If Float Were To

Fail At This Point, And Mud U-tubes Up Inside The Casing, Calculate The

Effect On Bottom Hole Pressure.

Data:-

Casing Capacity = 0.152 bbls/ft

Annular Capacity = 0.1238 bbls/ft

Mud Weight = 12.6 ppg

Answer

Hydrostatic Pressure Loss If Casing Float Fail =

Mud Gradient X Casing Capacity X Differential Height

(Casing Capacity + Annular Capacity)

0.665 X 0.152 X 14 X40

( 0.152 + 0.1238)= 205 psi

28

WELL CONTROL

Key Prevention Practices.

Do Not R.I.H. Too Fast.

Monitor Trip Tank.

Always Fill Hole With Correct Mud.

Monitor ECD.

Keep Viscosity Down To Acceptable Level.Keep Casing Full.

Know What Mud Is In Hole.



29

WELL CONTROL

Causes Of Abnormal Pressure

Under Compaction

Faulting

Sand Lens

Salt Dome

Artesian

Gas Cap

Leaks Around Casing

30

WELL CONTROL

Under Compaction (Trapped Water)

Permeable Layers Trap Water.

Fluid Pressure Rises Steeply



31

WELL CONTROL

+ +

+ +

++ ++

+

+++

Sand Lens

32

WELL CONTROL

Sand A00

Sand A0

Faulting



33

WELL CONTROL

Salt Domes

34

WELL CONTROL

0’

500’

Spring

Underground

water level

Rain

1000’

Artesian Effects

Calculate Mud Weight To Balance?

Formation Water = .433 psi/ft



35

WELL CONTROL

7000’

8000’

.465 psi/ft

Normal Pressure

Gas Cap Effect

36

WELL CONTROL

Calculate the pressure at top of the reservoir

Pressure at 8000’ = 8000 X .465 = 3720 psi

Height of reservoir = 8000 – 7000 = 1000’

Ph of the reservoir = 1000 X 0.1 = 100 psi

Pr at 7000’ = 3720 – 100 = 3620 psi

E.M.W. at 8000’ = 3720 / .052 / 8000/ = 8.94 ppg

E.M.W. at 7000’ = 3620 / .052 / 7000 = 9.94 ppg

In trapped gas reservoir, the highest point of the reservoir

usually has the highest pressure. Due to gas less dense

than formation water.

Example



37

WELL CONTROL

Leaks Around Casing

38

WELL CONTROL

Revision:

KICKS OCCUR WHEN

“ UNDERBALANCE ”

Causes Of Kicks

UNDERBALANCE IS CAUSED BY :

MUD WEIGHT REDUCTION.

DROP IN MUD LEVEL.

INCREASE IN FORMATION PRESSURE.



39

WELL CONTROL

Monitor Trips - In And Out

Circulate Bottoms Up If In Doubt Of Hole Condition

Monitor Well At All Times

Trip Carefully In And Out

Pump Out If Tight Hole

Circulate Through Choke If A Lot Of Gas Is Expected

Keep Mud In Good Shape

Always Keep Hole Full

Double Check Effect Of Lightweight Mud/Pills

Pump Good Cement

Kick Prevention

40

WELL CONTROL

What Is Warning Signs

Information From the Well That

Tells You That the Well May Be Getting

Close to Being “Under Balanced”

Your Safety Margin Is Getting Less.



41

WELL CONTROL

1. ROP ChangesOverbalance Less

Softer Rock

2. Hole condition

Squeezing Rock

Torque / Drag / Fill

3. Data from Mud

Gas

Cuttings

Temperature

Kick Warning Signs

Chlorides

Shale Property

Trip Monitor

42

WELL CONTROL

Improper Fill up or Displacement During Trips

Connection Gas

Increased Background Gas

Increased Drilling Rate

Flowline Mud Temperature Increase

Increased Chloride Content of Mud

Increased Drill String Torque

Increased Drill String Drag

Increased Number and Size of Cuttings

Decreasing Shale Density

Major Warning Signs



43

WELL CONTROL

Sometimes Called ‘Fast Break’

A Sudden Increase in R.O.P

How Much

How Far to Drill ?

What About a Decrease in R.O.P ?

What Is a Drilling Break

What Affects ROP

WOB

RPM

Bit Type

Hydraulics

Rock Type

Overbalance

44

WELL CONTROL

Geolograph Chart

Increasing

Drill Rate

(ROP)

9850’

9855’9860’

9.00

9.15

9.30

Increased Drilling Rate



45

WELL CONTROL

Increased Drill String Torque

46

WELL CONTROL

Drilled cuttings

‘Knocked Off’,

Heaving Shale Cuttings

Cuttings Size and Shape



47

WELL CONTROL

Cause of Connection Gas

BHP=

6864 psi

BHP=

7114 psi

7000 psi 7000 psi

11 ppg

mud

12000’

Annular

Pressure Loss

= 250 psi

Mud Static

Kick Can Occur Mud Circulating Formation Under ControlConnection Gas being Circulated to Surface

Formation Pressure

0

psi3000

psi

48

WELL CONTROL

Normal

Pressure

Abnormal

Pressure

Temperature Increase

9500’

9700’

9900’

10100’

9600’

9800’

10000’

10200’

Flow Line Temperature Graph



49

WELL CONTROL

Shale Density Graph

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

Abnormal Pressure Zones Exhibited a DECREASINGShale Density with DEPTH

50

WELL CONTROL

Surface Kick Indicators

Excess Flow From the Well When Tripping

Return Flow Rate Increase When Pumping

Pit Gain

Drilling Break

Decreased Pump Pressure/increased SPMFlow From Well With Pumps Off



51

WELL CONTROL

First : Shut the Well In

Second : Choose and Use a Kill Method to

Restore the Mud Hydrostatic

Pressure to Level That Re-Establishes

Primary Control

What Action to Take?

52

WELL CONTROL

Shut In MethodsHard

Soft

Reason for Shut In

To Prevent Blowout

To Allow Pressure Reading to Be Taken for

Kill Mud



53

WELL CONTROL

Flow / Pit Alarms Not Set (Properly)

Drill Too Far After Drilling Break

Lack of ‘Shut In’ Training

Lack of Maintenance & Testing

Waiting for Instructions

Accumulator Unit Not Working

Not Monitoring Trips

Low Level of Crew Awareness

Shut In Practices

Things That Delay Shut In.

54

WELL CONTROL

Soft Method

Raise Kelly/Top Drive Until Tool Joint Is Above Rotary

Table

Shut Down Mud Pumps

Open Choke Line Valve (HCR) at Stack

Check That Adjustable Choke Is Open

Close Annular Preventer *

Close Adjustable Choke

Record Shut in Pressure and Pit Gain

* API Soft Shut in States BOP

(It Does Not Specify an Annular)

Line up With Remote Choke Opened.

Drilling



55

WELL CONTROL

Soft Method

Install and make up the fully opened SAFETY VALVE in

the Drill String.

Close the Safety Valve


Check That Adjustable Choke Is Open

Close Annular Preventer *

Close Adjustable Choke

Pick up and make up Kelly?Top Drive

Open Safety ValveRecord Shut in Pressures and Pit Gain


(It Does Not Specify an Annular)

Tripping

Line up With Remote Choke Opened.

56

WELL CONTROL

Hard Method

Line up With Remote Choke Closed.

Drilling

Raise Kelly/Top Drive Until Tool Joint Is Above Rotary

Table

Shut Down Mud Pumps

Close Ram Preventer *


Record Shut in Pressure and Pit Gain


(It Does Not Specify a Ram)



57

WELL CONTROL

Hard Method Tripping

Install and make up the fully opened SAFETY VALVE in

the Drill String.

Close the Safety Valve

Close Ram Preventer *


Pick up and make up Kelly?Top Drive

Open Safety Valve

Record Shut in Pressures and Pit Gain* API Soft Shut in States BOP

(It Does Not Specify a Ram)

Line up With Remote Choke Closed.

58

WELL CONTROL

Hard

Quicker

Less to Remember

Smaller Influx

Soft

Slower

Checks if choke line is Clean

Larger Influx

Reduces Water Hammer Effect

Hard V’s Soft



59

WELL CONTROL

Problems

1. Shallow Gas

Many Rigs That Are Burned up Suffered

Shallow Gas Kicks

2. Losing the Hole and a Re-drill

Top Hole Drilling

60

WELL CONTROL

Shallow Gas

200 ft

Wind Direction



61

WELL CONTROL

SIDPP Shut In Drill pipe PressureSICP Shut In Casing Pressure

Pit Gain

SIDPP

Tells You Under Balance Inside Drill String

SICP

Tells You Under Balance Inside Annulus

Pit GainTells You Size of Influx at Shut in

Shut in Data

62

WELL CONTROL

Why Are They Different?

Mud in Annulus Is Contaminated

Therefore Less Hydrostatic

SIDPP V’s SICP SIDPP

Influx Height

Pump

SICP

Choke

Manifold

psi0

0psi



63

WELL CONTROL

Increase SPM = Increase PSI

Approximate Effect Is :

= Old Pump Pressure X

Pressure V’s Strokes

New SPM

Old SPM

2

64

WELL CONTROL

Pressure V’s Drilling Fluid Density

New M.Wt

Old M.Wt

Increase M. Wt = Increase PSI

Approximate Effect Is:

= Old Pump Pressure X



65

WELL CONTROL

Kill Mud

Kill Mud Weight

SIDPP

TVD X 0.052

+ Present Mud Wt.

66

WELL CONTROL

Initial and Final Circulating Pressure

I.C.P. = Slow Circulating Pressure + SIDPP

F.C.P. = Slow Circulating Pressure X

Kill M.Wt

Old M.Wt



67

WELL CONTROL

Pressure Exerted on the Bottom of the Hole.

B.H.P = Mud Hydrostatic

+

Back Pressure Held at Remote Choke

+

Annular Pressure Loss (APL)

Bottom Hole Pressure

68

WELL CONTROL

Slow Pump Rate

Normally 1/2 - 1/4 Drilling SPM

Why Kill Well at Slow Rate?

How Are They Taken?

When Are They Taken?

How Are They Used in Kill Process?



69

WELL CONTROL

1. Size Of Choke And Choke Lines.

2. Minimize Excess Pressure Exerted On

Formations During The Kill.

3. To Allow Kick Fluid To Be Handled At Surface.

4. To Reduce The Chance Of Overloading The

M.G.S.

5. Allow Choke Operator Time To Make

Necessary Choke Adjustments.

6. Ability To Mix Kill Mud.

7. To Reduce Damage To The Pump

Causes Effect the Choice of SCR

70

WELL CONTROL

When Should Be Taking SCR ?

1. At Beginning of Each Shift.

2. After Mud Properties Changed .

3. When Long Sections of Hole Are Drilled

Rapidly (500 Ft).

4. When Returning to Drilling After Kill.

5. When Changed B.H.A (Nozzles, D.C, Motor….)



71

WELL CONTROL

SCR’ s Should Be Read On The Drill Pipe

Pressure at The Remote Chock Panel.

SCR’ s Should Be Taken With The Bit Near The

Bottom.

Where To Read Standpipe Pressure.

When Recording SCR

72

WELL CONTROL

High

PermeabilityLow

Permeability

Time For Build How Long For Shut In Pressure To Stabilize?

psi

600

psi

600

Time

P r e s s u r e

Fast

P r e s s u r e

Time

Slow

Casing Pressure Casing Pressure



73

WELL CONTROL

Why?Gas Is Light And Will Migrate (Percolate) Up Hole

Speed Of Migration?

Depends On Mud Wt + Mud Viscosity

How Can I See Migration?

Steady Rise In Surface Pressure After Initial Stabilization

Gas Migration

74

WELL CONTROL

Time

SIDPP or SICP

Migra tion

Shut In Pressure

Gas Migration



75

WELL CONTROL

psi

600

psi

600

0

0

Float in Drill String

Pump Slowly Down Drill

Pipe And Watch Build Up

Time

500

SIDPP

Time

600

SICP

How To Find SIDPP?

76

WELL CONTROL

psi0

0

Clean Annular

psi psi

psi0

0

Annular Loaded

With Cutting



77

WELL CONTROL

Bit off Bottom

psi0

0psi

78

WELL CONTROL

Packed Off

psi0

0psi



79

WELL CONTROL

1. Drill 10 - 15 Feet Rat Hole

2. Test Surface Equipment

3. Circulate To Condition Mud

4. Pull Inside Casing

5. Shut In Well

6. Pump 1/4 - 1/2 Bbl/Min Into Well*

7. Plot Pressure Rise

8. When Pressure Rise Slows Down Or Stops; Shut Down

Pump

9. Measure Pressure Where Pressure Rise Slows Down

10.Monitor Stable Pressure Then Bleed Back Pressure

* Varies With Company Policy

Leak Off Procedure

80

WELL CONTROL

Volume Pumped

P u m p P

r e s s u r e

Trend LineLeak Off Pressure Point Of Leak Off

Leak Off Test (L.O.T.)

How Is Formation Strength Measured?

Fracture Pressure = Mud Hydrostatic psi + LOT psi

Formation Integrity Test

Pressure Up To Agreed Pressure Without Any Leak-off



81

WELL CONTROL

Fracture Pressure

Can Be Called “ Breakdown” Or “ Max. Allowable ”

= (L.O.T ÷ Shoe TVD ÷ .052) + Mud Wt. ppg

= (Mud Wt. ppg X .052 X Shoe TVD) + L.O.T.

Fracture Mud Weight

MAASP

Difference Between Pressure That Will Fracture The

Rock And The Mud Hydrostatic Pressure

= (Fracture Mud Wt - Current Mud Wt) X .052 X Shoe TVD

82

WELL CONTROL

MAASP = Leak Off At Time Of Leak Off Test

If Mud Weight Is Increased The Hydrostatic On

Shoe Increases

Therefore

Margin Between Mud Hydrostatic And Fracture

Gets Less.

This Margin Is Called M.A.A.S.P.

MAASP V’s Leak Off



83

WELL CONTROL

Well Condition Required For Accurate Leak Off Test.

Drill Out The Casing Shoe And Approximately

5 – 15 Ft Into New Formation.

Circulate The Mud To Get Same Weight All

Way Around.

Good Pressure Test Of Surface Equipment.

Calibrated Pressure Gauges.

Accurate T.V.D Of Casing Shoe.

Accurate Volume Of Mud Pumped.

84

WELL CONTROL

Mud Hydrostatic

Friction Losses In Annulus

Bridging/Packing Off In Annulus

Shutting In Well With Pumps Running

Kicks And The Kill ProcessChoke Line Friction

What Exerts Pressure On The Formation?



85

WELL CONTROL

What Can Increase The Risk Of ExceedingMAASP

Incorrect Casing Shoe Setting Depth

Unexpected High Pressure

Large Kick Size

Low Fracture Pressure

Long Open Hole Sections

Gas Migration

Bad Kill Practices

Too Much Safety Margin

Choke Line Friction Loss

86

WELL CONTROL

Principle Of Kill Method

One That Maintains Correct AndConstant Bottom Hole Pressure

Restore Primary Control

How ?

Clean Out Influx

Replace Old Mud With Kill Mud

At All Times

Maintain Correct Bottom Hole Pressure.

How ?

Use Approved Kill Method



87

WELL CONTROL

Pressure Exerted on the Bottom of the Hole.

B.H.P = Mud Hydrostatic

+

Back Pressure Held at Remote Choke

+

Annular Pressure Loss (APL)

Bottom Hole Pressure

Most Times APL Is Small And Can Be Ignored.

88

WELL CONTROL

Pressure Balance

BHP = Hydrostatic + Back Pressure

To Maintain Constant BHP!

Fluid Hydrostatic

Then

Choke Back Pressure

If



89

WELL CONTROL

The Choke (Remote Or Manual) Is A DeviceFor Adjusting Back Pressure.

A Kick Is Due To Lack Of Mud Hydrostatic.

The Choke Provides A Back Pressure To

Compensate For Lack Of Mud Hydrostatic.

When Heavy Mud Is Pumped The Operator

Reduces Back Pressure.

Role Of Choke

90

WELL CONTROL

This Procedure Starts the Kill Correctly.

It Ensures That B.H.P Is Correct for the Kill.

It Can Be Stated That the Start up Procedure

“Calibrates” the Well Kill to Correct B.H.P.

How?

Bring Pump Up to Speed Holding Casing

Pressure Constant.

Start up Procedure



91

WELL CONTROL

1st Clean Out Influx

2nd Circulate Kill Mud

After 1st Circulation

SIDPP = SICP

Driller’s Method

Two Circulation's

92

WELL CONTROL

1st Circulation

Start up - Bring Pumps up to Kill Rate Holding

Casing Pressure Constant

When up to Speed Look at Drill Pipe Pressure.

Hold It Constant at This Value For Complete Circulation

On Completion of Circulation Shut DownThe Reverse of Start up Procedure

If Annulus Is Clean S.I.C.P Will Now Read S.I.D.P.P

If Annulus Is Not Clean Then S.I.C.P Will Be Greater

Than S.I.D.P.P



93

WELL CONTROL

Start up - Bring Pumps up to Kill RateHolding Casing Pressure Constant

When up to Speed Maintain Casing Pressure

Constant Until Kill Mud Is at the Bit

With Kill Mud at Bit Switch to Drill Pipe Pressure and

Hold Constant Until Clean Mud Returns at Surface

It May Be Preferred to Use the Wait and Weight

Procedure for the 2nd Circulation.This Is in Case of Any Influx That Was Not Cleaned Out

in the1st Circulation

2nd Circulation

94

WELL CONTROL

One Circulation

Pump Kill Mud From the Start

Procedure

Start up - Bring Pumps up to Kill Rate

Holding Casing Pressure Constant

Once up to Speed the Drill Pipe Pressure Should

Equal I.C.P

Allow Drill Pipe Pressure to Fall From I.C.P to F.C.P

As Kill Mud Is Pumped to the Bit With Kill Mud at the

Bit Hold Drill Pipe Pressure Constant at F.C.P Until Kill

Mud Returns at Surface

Wait and Weight



95

WELL CONTROL

ICP = SIDPP + SCR Pressure

FCP = SCR X

Step Down From Icp To Fcp

Using Either Graph Or Chart

Kill Mud

Old Mud

PSI

ICP FCP

Strokes From Surface To Bit

SIDPP

0Strokes From Bit To Surface

STKS PSI

0 1400

100 1350

200 1300300 1250

400 1200

500 1150

600 1100

700 1050

750 1025

ICP

Strokes To Bit FCP

96

WELL CONTROL

Following A Choke Adjustment The Drillpipe Gauge

Takes Longer To React Due To Length Of System

Kill Mud Only Does Good When Going Downhole.

Therefore Re-zero Stroke Counter

Calculated ICP Is Only A Guideline. Actual (True) ICP Is

Seen At Start Up

If Actual ICP Is Different Then Recalculate Graph Or

StepDown

Things To Watch



97

WELL CONTROL

Comparison of Killing Methods

Ease of Calculation ( Driller Method )

Lower Annulus Pressure ( Wait & Weight)

Shortest Circulating Time (Wait & Weight )

98

WELL CONTROL

Drillers And Wait & Weight Only Work With Bit Below

The Influx.

Problems May Be:-

Unable To Use Pump

Hole Plugged

Bit Above Influx

In These Situations It May Be Necessary To Use

Other Well Control Techniques

Volumetric

Stripping

Combined Volumetric/Stripping

Non-Routine Techniques



99

WELL CONTROL

Volumetric Method

Circulation Not Possible

Plugged string.

Pipe out of hole.

Pump is shut-down or unavailable

and there is a float in the string.

Circulation Not Recommended

Not at TVD off bottom).

Pipe stuck

Not possible to strip.

Applications

100

WELL CONTROL

To keep BHP constant

Bleed mud through choke maintaining SIDPP constant

BHP =Ph d/p (no change) + SIDPP (constant)

= Constant

Bad practice

Due Hold casing Pressure Constant

BHP = Ph Ann. + SICP

= Ph Ann (decrease to bleed mud) + SICP (constant)

= Decrease

Volumetric Method



101

WELL CONTROL

Well Control ProblemsIndicators of Mechanical Failures

Changes In Drillpipe And Casing Pressures During

Well Control Variations Can Indicate Potential

Mechanical Problems

Blockages

String

Annulus

Choke

Washouts

String

Choke

Surface Equipment Failure

Losses

Hydrates

Common Kick Problems

102

WELL CONTROL

Loss of Circulation

Plugged Choke

Choke Washout

Plugged Nozzle

Nozzle Washout

String Washout

Problem DP psi Csg psi BHP



103

WELL CONTROL

Bad Practices

Incorrect Start Up

Changing SPM

Holding Wrong Pressure

Not Using Graph/Step Down

Not Pumping Correct Mud

104

WELL CONTROL

A. Use Correct “Start Up”

B. 1. Maintain Correct SPM

2. Correct Pressure V Strokes

3. Correct Mud Wt

How Do You Know That The B.H.P Is:

A. Correct ?

B. Constant ?



105

WELL CONTROL

Procedure

Correct Action

wrong Action

Effective on BHP

Brining up pump to kill speed

106

WELL CONTROL

Procedure

Correct Action

wrong Action

Effective on BHP

Driller Method (1st Circulation)



107

WELL CONTROL

Procedure

Correct Action

wrong Action

Effective on BHP

(2nd

Circulation) While Pumping Kill Mud To Bit

108

WELL CONTROL

Procedure

Correct Action

wrong Action

Effective on BHP

(2nd Circulation) While Pumping Kill Mud From

Bit to Surface



109

WELL CONTROL

Procedure

Correct Action

wrong Action

Effective on BHP

W&W Method (While Pumping Kill Mud To Bit)

110

WELL CONTROL

Procedure

Correct Action

wrong Action

Effective on BHP

Increase Pump Speed



111

WELL CONTROL

Procedure

Correct Action

wrong Action

Effective on BHP

Decrease Pump Speed

WELL CONTROL

Procedure

Correct Action

wrong Action

Effective on BHP

W&W Method (While Pumping Kill Mud From Bit

To Surface)

Date post:	05-Mar-2016
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