Gas Lift Course

(1)

FORTIES GAS LIFT SUPPORT TEAM

BASICS IN GAS LIFT

OPERATIONS

FORTIES GAS LIFT SUPPORT TEAM

VIJAY POTHAPRAGADA

SURVEILLANCE ENGINEERS

OWEs

(2)

OBJECTIVES



_{DESCRIBE MAIN RESERVOIR DRIVES}



_{EXPLAIN WHY/WHEN DO WE NEED ARTIFICIAL/GAS LIFT}



_{EXPLAIN BASICS IN GAS LIFT OPERATION}



_UNLOADING



_OPERATIONS



_OPTIMIZATION



_{FAMILIARIZE WITH GAS LIFT}

_{FAMILIARIZE WITH GAS LIFT EQUIPMEN}

_EQUIPMENT

_T



(3)



_{WELL AND RESERVOIR INFLOW PERFORMANCE}



_{OUTFLOW PERFORMANCE AND MULTIPHASE FLOW}



_{TYPES OF ARTIFICIAL LIFT}



_{GAS LIFT}



_{CONTINUOUS FLOW UNLOADING SEQUENCE}



_{GAS LIFT VALVE MECHANICS}



_{GAS LIFT WELL OPERATION}



_{GAS LIFT WELL}

_{GAS LIFT WELL OPTIMIZATION}

_{GAS LIFT WELL}

_OPTIMIZATION



_{GAS LIFT WELL TROUBLESHOOTING}



(4)

WELL AND RESERVOIR

INFLOW PERFORMANCE

(5)

WELL & RESERVOIR INFLOW

WELL &

RESERVOIR INFLOW

PERFORMANCE

TYPES OF RESERVOIR DRIVES



_{DISSOLVED / SOLUTION GAS DRIVE}



_{GAS CAP DRIVE}



(6)

DISSOLVED GAS DRIVE

(7)

WELL & RESERVOIR INFLOW

PERFORMANCE



_{DISSOLVED / SOLUTION GAS DRIVE}



_{CONSTANT VOLUME}



_{NO WATER ENCROACHMENT}



_{TWO PHASE FLOWING RESERVOIR BELOW}

BUBBLE POINT



_{NO GAS CAP}



_PI

_{PI NOT}

_NOT

_{NOT LINEAR}

_LINEAR



_PI

_{PI DECLINES}

_DECLINES

_{DECLINES WITH}

_WITH

_{WITH DEPLETION}

_DEPLETION



_FORMATION

_{FORMATION GOR}

_FORMATION

_GOR

_{GOR INCREASES}

_INCREASES

_{INCREASES WITH}

_WITH

_{WITH DEPLETION}

_DEPLETION



(8)

GAS CAP DRIVE

(9)

WELL & RESERVOIR INFLOW

PERFORMANCE



_{GAS CAP DRIVE}



_{GAS FROM SOLUTION WILL FORM GAS CAP}



_{WITH PRODUCTION GAS CAP INCREASES}

PROVIDING DRIVE



_{EXCESSIVE DRAWDOWN CAN CAUSE CONING}



_PI

_{PI USUALLY}

_USUALLY

_{USUALLY NOT}

_NOT

_{NOT LINEAR}

_LINEAR



_{GOR CONSTANT EXCEPT NEAR DEPLETION}



(10)

WATER DRIVE

(11)

WELL & RESERVOIR INFLOW

PERFORMANCE



_{WATER DRIVE}



_{NOT CONSTANT VOLUME}



_{RESERVOIR PRESSURE MORE CONSTANT -}

_{RESERVOIR PRESSURE MORE CONSTANT}

-EXPANSION

EXPANSION OF

OF WATER

WATER 1

1 IN

IN 2500

2500 PER

PER 100

100 PSI

PSI

EXPANSION

OF

WATER

1

1 IN

IN

2500

PER

100

100 PSI

PSI



_PI

_{PI MORE}

_MORE

_{MORE CONSTANT}

_CONSTANT



_GOR

_{GOR MORE}

_MORE

_{MORE CONSTANT}

_CONSTANT



_{COMBINATION OF WATER DRIVE & GAS CAP}

EXPANSION



_{OFTEN SUPPLEMENTED BY WATER INJECTION}



(12)

WELL & RESERVOIR INFLOW

PERFORMANCE

PRODUCTIVITY INDEX

The relationship between well inflow rate and

pressure drawdown can be expressed in the form of

a Productivity Index, denoted ‘PI’ or ‘J’, where:

a Productivity Index, denoted ‘PI’ or ‘J’,

where:

q

q = J(Pws - Pwf)

or

J = ---

J =

---Pws - Pwf

Pws - Pwf

(13)

WELL & RESERVOIR INFLOW

PERFORMANCE

INFLOW PERFORMANCE CURVE

0

0 1000

1000

2000

3000

0

1

0

2

0

3

0

0 Production Rate [stbo/d]

Production Rate [stbo/d]

P

r

e

s

u

r

e

[

p

s

i

]

V

o

g

e

l

S

t

r

a

i

g

h

t

L

i

n

e

(14)

WELL & RESERVOIR INFLOW

PERFORMANCE

SUMMARY OF FACTORS AFFECTING PREDICTION

OF WELL PRODUCTION



_{PRESENCE OF THREE PHASE FLOW}



_{NATURE OF DRIVE MECHANISMS}



_{PHYSICAL NATURE OF RESERVOIR (NON HOMOGENEOUS)}



_{AVAILABILITY OF STABILIZED FLOW}



_{CHANGES OVER TIME & DRAWDOWN}



_{INCREASED GAS SOLUTION NEAR WELLBORE}



_{STABILISED FLOW NEAR WELLBORE}



_{FLOW REGIME NEAR WELLBORE}



(15)

OUTFLOW PERFORMANCE

AND MULTIPHASE FLOW

(16)

OUTFLOW PERFORMANCE AND

MULTIPHASE FLOW

MOVEMENT OF A MIXTURE OF FREE GASES AND LIQUIDS

VERTICAL FLOWING GRADIENTS

HORIZONTAL FLOWING GRADIENTS

(17)

INJECTION GAS INJECTION GAS PRODUCED FLUID PRODUCED FLUID

WELL

INFLOW (IPR

)

WELL OUTFLOW

RELATIONSHIP

(VLP) or (TPC)

SURFACE PRESSURE

SANDFACE

PRESSURE

BHFP

RESERVOIR

PRESSURE

(18)

OUTFLOW PERFORMANCE AND

MULTIPHASE FLOW



_{VERTICAL FLOWING GRADIENTS}



_{HORIZONTAL FLOWING GRADIENTS}



_{SELECT CORRECT TUBING SIZE}



_{PREDICT WHEN ARTIFICIAL LIFT WILL BE}

_{PREDICT WHEN ARTIFICIAL LIFT WILL BE REQUIRED}

_REQUIRED



_{DESIGN ARTIFICIAL LIFT SYSTEMS}



_{DETERMINE BHFP}



_{DETERMINE PI}



_PREDICT

_{PREDICT MAXIMUM}

_MAXIMUM

_{MAXIMUM AND/OR}

_AND/OR

_{AND/OR OPTIMUM}

_OPTIMUM

_{OPTIMUM FLOW RA}

_{FLOW RATE}

_TE



(19)

(20)

(21)

(22)

ARTIFICIAL LIFT

(23)

TYPES OF ARTIFICIAL LIFT



_{ROD PUMPS}



_{HYDRAULIC PUMPS}



_{ELECTRIC SUBMERSIBLE PUMPS}



(24)

(25)

GAS LIFT

(26)

TYPES OF GAS LIFT



_CONTINUOU

_{CONTINUOUS FLOW GAS LIFT}

_{S FLOW GAS}

_LIFT

TUBING

TUBING FLOW

FLOW /

/ ANNULAR

ANNULAR FLOW

FLOW

TUBING

FLOW

/

ANNULAR

FLOW



_INTERMITTEN

_{INTERMITTENT GAS LIFT}

_{T GAS}

_LIFT



_{PLUNGER LIFT}



_{CONVENTIONAL & WIRELINE RETRIEVABLE}



(27)

APPLICATIONS OF CONTINUOUS FLOW

GAS LIFT



_{TO ENABLE WELLS THAT WILL NOT FLOW}

NATURALLY TO PRODUCE



_{TO INCREASE PRODUCTION RATES IN FLOWING}

WELLS



_{TO UNLOAD A WELL THAT WILL LATER FLOW}

NATURALLY



_{TO REMOVE OR UNLOAD FLUID IN GAS WELLS}



_{TO BACK FLOW SALT WATER DISPOSAL WELLS}



(28)

ADVANTAGES OF GAS LIFT



_{INITIAL DOWNHOLE EQUIPMENT COSTS LOWER}



_{LOW OPERATIONAL AND MAINTENANCE COST}



_{SIMPLIFIED WELL COMPLETIONS}



_{FLEXIBILITY - CAN HANDLE RATES FROM}

10 TO 80000 BPD



(29)

DISADVANTAGES OF GAS LIFT



_{MUST HAVE A SOURCE OF GAS}

IMPORTED FROM OTHER FIELDS



_{PRODUCED GAS - MAY RESULT IN}

START UP PROBLEMS



_{POSSIBLE HIGH INSTALLATION COST}



_{TOP SIDES MODIFICATIONS TO EXISTING PLATFORMS}



_{COMPRESSOR INSTALLATION}



_{LIMITED BY AVAILABLE RESERVOIR PRESSURE}

AND BOTTOM HOLE FLOWING PRESSURE

(30)

INJ

INJECTION GECTION GASAS

PRODUCED FLUID PRODUCED FLUID PRESSURE (PSI) PRESSURE (PSI) D D E E P P T T H H ( ( F F T T T T V V D D ) ) 1000 1000 2000 2000 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 0 0 1 1000000 22000000 0 0

OPERATING GAS LIFT VALVE OPERATING GAS LIFT VALVE CASING PRESSURE WHEN CASING PRESSURE WHEN WELL IS BEING GAS LIFTED WELL IS BEING GAS LIFTED

FBHP FBHP S S I I B B H H P P F F L L O O W W I I _N_N G G T T U U B B I I _N_N G G P P R R E E S S S S U U R R E E G G R R A A D D I I _E_E

N N T T

CONSTANT FLOW GAS LIFT

(31)

INJ

INJECTION ECTION GASGAS

PRODUCED FLUID PRODUCED FLUID PRESSURE (PSI) PRESSURE (PSI) D D E E P P T T H H ( ( F F T T T T V V D D ) ) 1000 1000 2000 2000 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 0 0 1 1000000 22000000 0 0

OPERATING GAS LIFT OPERATING GAS LIFT VALVE

VALVE CASING PRE

CASING PRESSURE WHSSURE WHENEN WELL IS BEING GAS LIFTED WELL IS BEING GAS LIFTED

FBHP FBHP S S I I B B H H P P F F L L O O W W I I _N_N G G T T U U B B I I _N_N G G P P R R E E S S S S U U R R E E G G R R A A D D I I _E_E

N N T T

CONSTANT FLOW GAS LIFT WELL

(32)

PRODUCED FLUID PRODUCED FLUID

INJECTION GAS INJECTION GAS

TUBING FLOW

ANNULAR FLOW

PRODUCED FLUID PRODUCED FLUID

INJECTION GAS INJECTION GAS

(33)

GAS LIFT SYSTEM CONSIDERATIONS



_{SAND PRODUCTION}



_{PRODUCED WATER}



_{WATER CONING}



_{ANNULAR SAFETY}

SYSTEM



_{CORROSION EFFECTS}



_HYDRATES



_ASPHALTINES



_{BUBBLE POINT}



_{CHEMICAL INJECTION}



_SCALE



_{GAS CAPACITY AND}

_{GAS CAPACITY AND AVAILABILITY}

_AVAILABI

_LITY



_{CASING INTEGRITY}



_{RESERVOIR PERFORMANCE}



_{SYSTEM OPTIMISATION}



_{WELL STABILITY}



_{WELL START UP}



_{PLANT CONSIDERATIONS}



_{GAS QUALITY}



(34)

CONTINUOUS FLOW

UNLOADING SEQUENCE

(35)

FIGURE 3-1

The fluid level in the casing and the tubing is at surface. No gas is being injected into the casing and no fluid is being produced. All the gas lift valves are open. The The fluid level in the casing and the tubing is at surface. No gas is being injected into the casing and no fluid is being produced. All the gas lift valves are open. The pressure to open the valves is provided by the weight of the fluid in the casing and tubing.

pressure to open the valves is provided by the weight of the fluid in the casing and tubing.

Note that the fluid level in the tubing and casing will be determined by the shut in bottom hole pressure (SIBHP) and the hydrostatic head or weight of the column of Note that the fluid level in the tubing and casing will be determined by the shut in bottom hole pressure (SIBHP) and the hydrostatic head or weight of the column of

fluid which is in turn determined by the density. Water has a

fluid which is in turn determined by the density. Water has a greater density than oil and thus the fluid level of a column of water will be lower than that of greater density than oil and thus the fluid level of a column of water will be lower than that of oil.oil.

INJ

INJ ECTION ECTION GASGAS CHOKE CLOSED CHOKE CLOSED

TO SEPARATOR/STOCK TANK TO SEPARATOR/STOCK TANK

TOP VALVE OPEN TOP VALVE OPEN

SECOND VALVE SECOND VALVE OPEN OPEN THIRD VALVE THIRD VALVE OPEN OPEN FOURTH VALVE FOURTH VALVE OPEN OPEN 0 0 2000 2000 6000 6000 8000 8000 10000 10000 12000 12000 14000 14000 4000 4000 2 2000000 44000000 PRESSURE PSI PRESSURE PSI D D E E P P T T H H F F T T T T V V D D SIBHP SIBHP TUBING PRESSURE TUBING PRESSURE CASING PRESSURE CASING PRESSURE 3000 3000 1000 1000 50005000 C C _A_A S S _I_I N N _G_G P P _R_R E E _S_S S S _U_U R R _E_E T T _U_U B B I I _N_N G G P P _R_R E E _S_S S S _U_U R R _E_E 6000 6000 70007000

(36)

FIGURE 3-2

Gas injection into the casing has begun. Fluid is

Gas injection into the casing has begun. Fluid is U-tubed through all the open gas lift valves. No U-tubed through all the open gas lift valves. No formation fluids are being produced because the pressure in theformation fluids are being produced because the pressure in the wellbore at perforation depth is greater than the rese

wellbore at perforation depth is greater than the reservoir pressure i.e. no rvoir pressure i.e. no drawdown. All fluid produced is from the casing drawdown. All fluid produced is from the casing and the tubing. All fluid unloaded fromand the tubing. All fluid unloaded from the casing

the casing passes through the open gas lift valves. Because of this, it is important that the well be unloaded at a reasonable rate to prevent damage to the gas liftpasses through the open gas lift valves. Because of this, it is important that the well be unloaded at a reasonable rate to prevent damage to the gas lift valves.

valves.

INJ

INJ ECTION ECTION GASGAS CHOKE OPEN CHOKE OPEN

SECOND VALVE SECOND VALVE OPEN OPEN THIRD VALVE THIRD VALVE OPEN OPEN FOURTH VALVE FOURTH VALVE OPEN OPEN 0 0 2000 2000 6000 6000 8000 8000 10000 10000 12000 12000 14000 14000 4000 4000 2 2000000 44000000 PRESSURE PSI PRESSURE PSI D D E E P P T T H H F F T T T T V V D D SIBHP SIBHP TUBING PRESSURE TUBING PRESSURE CASING PRESSURE CASING PRESSURE 3000 3000 1000 1000 55000000 66000000 70007000

(37)

FIGURE 3-3

The fluid level has been unloaded to the top gas lift valve. This aerates the fluid above the top gas lift valve, decreasing the fluid density. This reduces the pressure in The fluid level has been unloaded to the top gas lift valve. This aerates the fluid above the top gas lift valve, decreasing the fluid density. This reduces the pressure in the tubing at the top gas lift valve, and also reduces pressure in the tubing at all valves below the top valve. This pressure reduction allows casing fluid below the top the tubing at the top gas lift valve, and also reduces pressure in the tubing at all valves below the top valve. This pressure reduction allows casing fluid below the top gas lift valve to be U-tubed further down the well and unloaded through valves 2, 3 and 4.

gas lift valve to be U-tubed further down the well and unloaded through valves 2, 3 and 4.

If this reduction in pressure is sufficient to give some drawdown at the perforations then the well will start to produce formation fluid. If this reduction in pressure is sufficient to give some drawdown at the perforations then the well will start to produce formation fluid.

INJ

INJ ECTIOECTION GASN GAS CHOKE OPEN CHOKE OPEN

SECOND VALVE SECOND VALVE OPEN OPEN THIRD VALVE THIRD VALVE OPEN OPEN FOURTH VALVE FOURTH VALVE OPEN OPEN 0 0 2000 2000 6000 6000 8000 8000 10000 10000 12000 12000 14000 14000 4000 4000 2 2000000 44000000 PRESSURE PSI PRESSURE PSI D D E E P P T T H H F F T T T T V V D D SIBHP SIBHP TUBING PRESSURE TUBING PRESSURE CASING PRESSURE CASING PRESSURE 3000 3000 1000 1000 55000000 66000000 70007000

(38)

FIGURE 3-4

The fluid level in the annulus has now been unloaded to just above valve number two. This has been posssible due to the increasing volume of gas passing through The fluid level in the annulus has now been unloaded to just above valve number two. This has been posssible due to the increasing volume of gas passing through number one reducing the pressure in the tubing at valve two thus enabling the U-tubing process to continue.

number one reducing the pressure in the tubing at valve two thus enabling the U-tubing process to continue.

INJ

SECOND VALVE SECOND VALVE OPEN OPEN THIRD VALVE THIRD VALVE OPEN OPEN FOURTH VALVE FOURTH VALVE OPEN OPEN 0 0 2000 2000 6000 6000 8000 8000 10000 10000 12000 12000 14000 14000 4000 4000 2 2000000 44000000 PRESSURE PSI PRESSURE PSI D D E E P P T T H H F F T T T T V V D D SIBHP SIBHP TUBING PRESSURE TUBING PRESSURE CASING PRESSURE CASING PRESSURE 3000 3000 1000 1000 50005000 DRAWDOWN DRAWDOWN 6000 6000 70007000 FBHP FBHP

(39)

FIGURE 3-5

The fluid level in the casing has been lowered to a point below the second gas lift valve. The top two gas lift valves are open and gas being injected through both The fluid level in the casing has been lowered to a point below the second gas lift valve. The top two gas lift valves are open and gas being injected through both valves. All valves below also remain open and continue to pass casing fluid.

valves. All valves below also remain open and continue to pass casing fluid.

The tubing has now been unloaded sufficiently to reduce the flowing bottom hole pressure (FBHP) below that of the shut in bottom hole pressure (SIBHP). This gives The tubing has now been unloaded sufficiently to reduce the flowing bottom hole pressure (FBHP) below that of the shut in bottom hole pressure (SIBHP). This gives a differential pressure from the reservoir to the wellbore producing a flow of formation fluid. This pressure differential is called the drawdown

a differential pressure from the reservoir to the wellbore producing a flow of formation fluid. This pressure differential is called the drawdown

INJ

SECOND VALVE SECOND VALVE OPEN OPEN THIRD VALVE THIRD VALVE OPEN OPEN FOURTH VALVE FOURTH VALVE OPEN OPEN 0 0 2000 2000 6000 6000 8000 8000 10000 10000 12000 12000 14000 14000 4000 4000 2 2000000 44000000 PRESSURE PSI PRESSURE PSI D D E E P P T T H H F F T T T T V V D D TUBING PRESSURE TUBING PRESSURE CASING PRESSURE CASING PRESSURE 3000 3000 1000 1000 50005000 DRAWDOWN DRAWDOWN 6000 6000 70007000 FBHP FBHP SIBHPSIBHP

(40)

FIGURE 3-6

The top gas lift valve is now closed, and all the gas is being injected through the second valve. When casing pressure operated valves are used a slight reduction in the The top gas lift valve is now closed, and all the gas is being injected through the second valve. When casing pressure operated valves are used a slight reduction in the casing pressure causes the top valve to close. With fluid operated and proportional response valves, a reduction in the tubing pressure at valve depth causes the top casing pressure causes the top valve to close. With fluid operated and proportional response valves, a reduction in the tubing pressure at valve depth causes the top valve to close. Unloading the well continues with valves 2, 3 and 4 open and casing fluid being removed through valves 3 and 4.

valve to close. Unloading the well continues with valves 2, 3 and 4 open and casing fluid being removed through valves 3 and 4.

INJ

TOP VALVE CLOSED TOP VALVE CLOSED

(41)

FIGURE 3-7

The No. 3 valve has now been uncovered. Valves 2 and 3 are both open and passing gas. The bottom valve below the fluid level is also open. The No. 3 valve has now been uncovered. Valves 2 and 3 are both open and passing gas. The bottom valve below the fluid level is also open.

Note that the deeper the point of injection the lower the FBHP and thus the greater the drawdown on the well. As well productivity is directly related to the drawdown Note that the deeper the point of injection the lower the FBHP and thus the greater the drawdown on the well. As well productivity is directly related to the drawdown

then the deeper the injection the greater the production rate. then the deeper the injection the greater the production rate.

INJ

(42)

FIGURE 3-8

The No. 2 valve is now closed. All gas is being injected through valve No 3. Valve No 2 is closed by a reduction in casing pressure for casing operated valves or a The No. 2 valve is now closed. All gas is being injected through valve No 3. Valve No 2 is closed by a reduction in casing pressure for casing operated valves or a reduction in tubing pressure for fluid operated and proportional response valves. Valve No 3 is the operating valve in this example. This is because the ability of the reduction in tubing pressure for fluid operated and proportional response valves. Valve No 3 is the operating valve in this example. This is because the ability of the reservoir to produce fluid matches the ability of the tubing to remove fluids (Inflow/Outflow Performance). The operating valve can either be an orifice valve or can be a reservoir to produce fluid matches the ability of the tubing to remove fluids (Inflow/Outflow Performance). The operating valve can either be an orifice valve or can be a gas lift valve. The valve in mandrel No 4 will remain submerged unless operating conditions or reservoir conditions change.

gas lift valve. The valve in mandrel No 4 will remain submerged unless operating conditions or reservoir conditions change.

INJ

SECOND VALVE SECOND VALVE CLOSED CLOSED THIRD VALVE THIRD VALVE OPEN OPEN FOURTH VALVE FOURTH VALVE OPEN OPEN 0 0 2000 2000 6000 6000 8000 8000 10000 10000 12000 12000 14000 14000 4000 4000 2 2000000 44000000 PRESSURE PSI PRESSURE PSI D D E E P P T T H H F F T T T T V V D D TUBING PRESSURE TUBING PRESSURE CASING PRESSURE CASING PRESSURE 3000 3000 1000 1000 50005000 DRAWDOWN DRAWDOWN 6000 6000 70007000 FBHP FBHP SIBHPSIBHP

(43)

FIGURE 3-8: Example of the Unloading Sequence

Casing Operated Valves and Ch

Casing Operated Valves and Ch oke Con

oke Con trol of

trol of Injecti

Injection Ga

on Ga

0 0 200 200 400 400 600 600 800 800 1000 1000 1200 1200 1400 1400 1600 1600 1800 1800 2000 2000 1 122::000 0 AAMM 0033::000 0 AMAM 0066::000 0 AAMM 0099::000 0 AAMM 1122::000 0 PPMM 0033::000 0 PPMM 0066::000 0 PPMM

Time

P P r r e e s s s s u u r r e e p p s s i i P

(44)

GAS LIFT VALVE

MECHANICS

(45)

GAS LIFT VALVE

GAS LIFT VALVE MECHANICS

MECHANICS

GAS LIFT VALVE

MECHANICS

INJECTION PRESSURE (CASING) OPERATED VALVES

PRODUCTION PRESSURE (FLUID) OPERATED

PRODUCTION PRESSURE (FLUID) OPERATED VALVE

VALVE

PRODUCTION PRESSURE (FLUID) OPERATED

VALVE

THROTTLING/PROPOR

THROTTLING/PROPORTIONAL RESPONSE

TIONAL RESPONSE VALVES

VALVES

THROTTLING/PROPORT

IONAL RESPONSE

VALVES

ORIFICE VALVES

NOVA ORIFICE VALVE

(46)

Spring Operated Gas Lift Valve

Pressure Regulator

Diaphragm/

Atmospheric Bellows

Spring

Stem

Stem Tip

Port

Downstream

Upstream

Upstream/

Casing

Downstream/Tubing

(47)

CLOSING FORCE (IPO VALVE)

Fc = PbAb

OPENING FORCES (IPO VALVE)

Fo

₁₁₁₁

= Pc (Ab- Ap)

Fo

₂₂₂₂

= Pt Ap

TOTAL OPENING FORCE

Fo = Pc (Ab - Ap) + Pt Ap

JUST BEFORE THE VALVE OPENS THE FORCES ARE EQUAL

Pc (Ab - Ap) + Pt Ap = Pb Ab

Pb - Pt (Ap/Ab)

SOLVING FOR Pc

Pc = ---

Pc =

---1 - (Ap/Ab)

1 - (Ap/Ab)

WHERE:

Pb

= Pressure in bellows

Pt

= Tubing pressure

Pc

= Casing pressure

Ab

= Area of bellows

GAS LIFT VALVE

GAS LIFT VALVE MECHANICS

MECHANICS

GAS LIFT VALVE

(48)

Pt Pt Pc Pc Pb Pb Dome Dome Bellows Bellows Square Edged Square Edged Seat Seat Check Valve Check Valve Chevron Chevron Packing Packing Stack Stack

N i t

N i tr o g e n C

r o g e n C h a r g e d B e l l o w s T y p e

h a r g e d B e l l o w s T y p e

I n j

I n je c t i o n P r e s

e c t i o n P r e s s u r e ( C a

s u r e ( C a s i n g )

s i n g ) O p

O p e r a t e d G a s L

e r a t e d G a s L i f

i ft

t V a l v e

V a l v e

Chevron Chevron Packing Packing Stack Stack

Stem Tip (Ball) Stem Tip (Ball)

Pt Pt Pc Pc Pb Pb Dome Dome Bellows Bellows Check Valve Check Valve Chevron Chevron Packing Packing Stack Stack

Nitrogen Charged Bellows Type

Production Pressure (Fluid) Operated Gas Lift Valve

Stem Tip (Ball) Stem Tip (Ball)

Square Edg Square Edgeded

Seat Seat

(49)

Pt Pt Pc Pc Pb Pb Dome Dome Bellows Bellows Tapered Tapered T.C. Seat T.C. Seat Check Check ValvValvee Chevron Chevron Packing Packing Stack Stack

Nitrogen Charged Bellows T Nitrogen Charged Bellows T ypeype Pr

Pr oportional Response Gas Lift Valveoportional Response Gas Lift Valve

Chevron Chevron Packing Packing Stack Stack Spring Spring Large T.C. Ball Large T.C. Ball Pt Pt Pc Pc Atmospheric Atmospheric Bellows Bellows Square Edged Square Edged Seat Seat Check Valve Check Valve Chevron Chevron Packing Packing Stack Stack Spring Operated Spring Operated Injectio

Injection Pn P ressure (Casing) Operated Gas Lressure (Casing) Operated Gas L ift Valift Valveve

Stem Tip (Ball) Stem Tip (Ball) Spring Spring Adjustment Adjustment Nut & Lock Nut & Lock NutsNuts

(50)

(51)

(52)

(53)

(54)

PRESSURE (PSI)

SUB-CRITICAL

FLOW

P

CASCASIINGCASCASIINGNGNG

P

_TUBING_TUBING_TUBING_TUBING

= 55%

T

H

R

O

T

L

I

N

G

R

E

G

I

O

N

T

T H

H R

R O

O

T

T L

L I

I N

N G

G

R

R E

E G

G I

I O

O N

N

ORIFICE FLOW

G

A

S

I

N

J

E

C

T

I

O

N

R

A

T

E

(

M

S

C

F

/

D

)

GG

AA

SS

IINN

JJ

EE

CC

TT

IIOO

NN

RR

AA

TT

EE

((MM

MM

SS

CC

FF

//DD

))

(55)

RDO-5 Orifice Valve, 32/64" Port, Cd = 0.76 RDO-5 Orifice Valve, 32/64" Port, Cd = 0.76

0.00 0.00 1.00 1.00 2.00 2.00 3.00 3.00 4.00 4.00 5.00 5.00 6.00 6.00 7.00 7.00 8.00 8.00 0 0 22000 0 44000 0 66000 0 88000 0 1100000 0 1212000 0 1144000 0 1166000 0 1188000 0 22000000

Downstream Pressure (psig) Downstream Pressure (psig) G G a a s s F F l l o o w w r r a a t t e e ( ( m m m m s s c c f f / / d d Ca

Calculculalateted d FlFlowowratrate e MeMeasuasurered d FloFlowrawratete

Ca

(56)

(57)

(58)

5 1/2” MMRG-4, 1 1/2” POCKET

ROUND MANDREL DESIGN

ENGINEERING DATA

PART NUMBER

05712-000-00001

SIZE

5 1/2”

MAX O.D.

7.982”

MIN I.D.

4.756”

D

DR

RIIF

FT

T

II..D

D..

4 4..6

65

53 3”

”

THREAD

17 LB/FT

17 LB/FT MANN BDS

MANN BDS B x P

B x P

T

TE

ES

ST P

T PR

RE

ES

SS

SU

UR

RE I

E IN

NT

TE

ER

RN

NA

AL

L

7

77

740 40 P

PS

SII

TE

TEST

ST PR

PRES

ESS

SUR

URE E

E EXT

XTER

ERNA

NAL

L

62 6280

80 PS

PSII

L

LA

AT

TC

CH

H T

TY

YP

PE

E

R

RK

K,

, R

RK

K--1

1,

, R

RK

KP

P,

, R

RK

K--S

SP

P

K

KIIC

CK

KO

OV

VE

ER

R T

TO

OO

OL

L

OM

O

M--1

1,

, O

OM

M--1

1M

M,

, O

OM

M--1

1S

S

R

RU

UN

NN

NIIN

NG

G T

TO

OO

OL

L

R

RK

K--1

1 1

15

50

07

79

9 PULLING TOOL

PULLING TOOL

1 5/8” JDS 15155

MATERIAL

410 S.S., 13

410 S.S., 13 CR

CR 22 HRC

22 HRC MAX

MAX

TENSILE STRENGTH (EOEC)

490,000 LBS

Orienting Orienting Sleeve Sleeve Tool Tool Discriminator Discriminator ‘G’ Latch ‘G’ Latch Lug Lug Polished Polished Seal Bore Seal Bore