intro art lift final
DESCRIPTION
Intro Art Lift FinalTRANSCRIPT
Introduction Introduction to to
Artificial LiftArtificial Liftbyby
V S Chimmalgi
Introduction ……Introduction ……
• Multiphase Flow, Multiphase Flow,
• IPR and out flow performanceIPR and out flow performance
• Introduction to Artificial Lift, Introduction to Artificial Lift,
• Selection criteria for different modes of Lift,Selection criteria for different modes of Lift,
• SINGLE PHASE FLOWSINGLE PHASE FLOW
Refers to one fluid medium onlyRefers to one fluid medium only
• MULTIPHASE FLOWMULTIPHASE FLOW
Refers to more than one fluid medium , for example Refers to more than one fluid medium , for example
Oil , Water and Gas.Oil , Water and Gas.
SINGLE & MULTIPHASE FLOW
MULTIPHASE FLOW
VERT ICAL
FLOWFLOW
ChokeHORIZONTAL FLOW
STOCKTANK
SEPARATOR
GAS
Flow through Porous Medium Inflow Performance
INCLINED FLOW
LIQUIDLIQUID
MULTIPHASE FLOW
MULTIPHASE FLOWMULTIPHASE FLOW
HORIZONTAL FLOWHORIZONTAL FLOWVERTICAL / VERTICAL / INCLINED FLOWINCLINED FLOW
STRATIFIEDSTRATIFIED INTERMITTENTINTERMITTENT ANNULARANNULAR DISPERSED BUBBLEDISPERSED BUBBLE
SMOOTHSMOOTH WAVYWAVY SLUGSLUG ELONGATED BUBBLEELONGATED BUBBLE
BUBBLEBUBBLE SLUGSLUG CHURNCHURN ANNULARANNULAR
STRATIFIED SMOOTH FLOWSTRATIFIED SMOOTH FLOW(LOW GAS & LIQUID RATES - PHASES SEPARATED BY GRAVITY)
STRATIFIED WAVY FLOWSTRATIFIED WAVY FLOW(SAME AS ABOVE WITH RELATIVELY HIGH GAS FLOW RATE)
MULTIPHASE FLOWHORIZONTAL FLOWHORIZONTAL FLOW
Gas
Gas
ELONGATED BUBBLE FLOWELONGATED BUBBLE FLOW ( EARLIER THAN SLUG FLOW, WHEN GAS RATES ARE LOWER)
INTERMITTENT SLUG FLOWINTERMITTENT SLUG FLOW(INTERMITTENT FLOW OF LIQUID AND GAS - GAS POCKETS DEVELOPES)
MULTIPHASE FLOW
HORIZONTAL FLOWHORIZONTAL FLOW
Gas
ANNULAR FLOWANNULAR FLOW
GAS OCCUPIES CENTRAL PORTION LIKE A CYLINDER AND LIQUID REMAINS NEAR
THE PIPEWALL; CENTRAL PORTION ENTRAINS LIQUID DROPLETS. OCCURS AT VERY HIGH GAS FLOW RATE.
MULTIPHASE FLOWHORIZONTAL FLOWHORIZONTAL FLOW
DISPERSED BUBBLE FLOWDISPERSED BUBBLE FLOW
AT VERY HIGH LIQUID FLOW RATE, LIQUID PHASE IS CONTINUOUS & GAS PHASE IS
DISPERSED ALL AROUND LIQUID IN THE FORM OF DISCRETE BUBBLES.
MULTIPHASE FLOWHORIZONTAL FLOWHORIZONTAL FLOW
BUBBLE BUBBLE
FLOWFLOW
MULTIPHASE FLOWVERTICAL / INCLINED FLOWVERTICAL / INCLINED FLOW
OCCURS AT RELATIVELYLOW LIQUID RATES. Gas bubbles
SLUG FLOWSLUG FLOW
MULTIPHASE FLOWVERTICAL / INCLINED FLOWVERTICAL / INCLINED FLOW
Symmetric about the pipe axis.
Gas phase -like a large bullet shaped gas pocket with a diameter almost equal to pipe diameter.
Gas pocket is termed as “Taylor Bubble”.
Gas
CHURN FLOWCHURN FLOW
MULTIPHASE FLOWVERTICAL / INCLINED FLOWVERTICAL / INCLINED FLOW
Similar to slug flow, though it is chaotic with no clear boundaries between the two phases.
Flow pattern is characterised by oscillatory motion.
Occurs at high flow rates; liquid slugs become frothy.
ANNULAR FLOWANNULAR FLOW
MULTIPHASE FLOWVERTICAL / INCLINED FLOWVERTICAL / INCLINED FLOW
Liquid film thickness is almost uniform around pipe wall.
Characterised by a fast moving gas core. Occurs at very high GLR
Liquid film is highly wavy due to high interfacial shress.
HORIZONTAL MULTIPHASE FLOW
Effect of variablesEffect of variables• Line SizeLine Size• Flow RateFlow Rate• Gas-Liquid RatiosGas-Liquid Ratios• WaterCutWaterCut• ViscosityViscosity• SlippageSlippage• Kinetic energy termKinetic energy term
Effect of Variables - IEffect of Variables - I
Pipe Diameter – Pressure loss (dP) decreases
rapidly with increase in Pipe Diameter.
Flow Rate – Higher flow rate increases dP
GLR – Increased GLR increases friction,
hence more dP, unlike to vertical flow.
HORIZONTAL MULTIPHASE FLOW
Effect of Variables - IIEffect of Variables - II Viscosity – Viscous crude offers more
problem in horizontal flow mode. Water Cut – Its effect is not pronounced. Slippage – Its effect is not pronounced. Kinetic Energy – For High flow rates & low
density it is considered for computation.
HORIZONTAL MULTIPHASE FLOW
VERTICAL / INCLINED MULTIPHASE FLOW
Effect of variablesEffect of variables• Tubing SizeTubing Size• Flow Rate, DensityFlow Rate, Density• Gas-Liquid RatioGas-Liquid Ratio• Water CutWater Cut• ViscosityViscosity• Slippage ,Kinetic Energy termSlippage ,Kinetic Energy term• Inclination Angle Inclination Angle
Effect of Variables - IEffect of Variables - I Tubing Size – It has pronounced effect in
deciding FBHP requirement.. Flow Rate – It establishes the required FBHP,
which influences tubing size selection. GLR – Increase GLR reduces FBHP requi-
rement, after a point reversal takes place.
VERTICAL / INCLINED MULTIPHASE FLOW
Effect of Variables - IIEffect of Variables - II Density – Higher density increases dP. Viscosity – Higher viscosity increases dP. Water Cut – Higher watercut increases dP. Slippage – It is observed during unstable flow region. Kinetic Energy – For High velocity & low density it is
considered for computation.
VERTICAL / INCLINED MULTIPHASE FLOW
MULTIPHASE FLOW
FLOW CORRELATIONS
HORIZONTAL FLOW
VERTICAL FLOW
INCLINED FLOW
VARIOUS ASSUMPSIONS TAKEN FOR VARIOUS ASSUMPSIONS TAKEN FOR DIFFERENT CORRELATIONS DIFFERENT CORRELATIONS : :
Fluid must be free from emulsion.
Fluid must be free from scale / paraffin build up.
Mashed or kinked joints should not exist.
Flow patterns should be relatively stable.
No severe slugging should occur.
Oil should not be very viscous.
MULTIPHASE FLOW
HORIZONTAL MULTIPHASE FLOW
CORRELATIONS FOR
HORIZONTAL MULTIPHASE FLOW
Lockhart and Martinelli Baker
Andrews et al. Dukler et al.
Eaton et al. Beggs and Brill
MULTIPHASE FLOW
VERTICAL FLOWVERTICAL FLOWCORRELATIONSCORRELATIONS
Duns & RosDuns & Ros
OrkiszewskiOrkiszewski
Hagedorn BrownHagedorn Brown
Winkler Winkler &&SmithSmith
Beggs &Beggs &BrillBrill
Govier &Govier &AzizAziz
MULTIPHASE FLOW
INCLINED FLOWINCLINED FLOW CORRELATIONSCORRELATIONS
FLANIGANFLANIGAN CORRELATIONCORRELATION
BEGGS & BRILLBEGGS & BRILLCORRELATIONCORRELATION
INFLOW & OUTFLOW
INFLOW PERFORMANCE..
CONCEPT OF PRODUCTIVITY INDEXP.I = Q / ( Pr - Pwf )
Where ,
P.I = Productivity index.
Q = Total quantity of fluid.
Pr = Reservoir Pressure.
Pwf = Flowing bottom hole pressure.
Q Pr - Pwf
Q = K (Pr - Pwf) K = Q / (Pr - Pwf)Where K is a constant, known as PI
PwfPwf PrPr
Pwf = PrPwf = Pr
PwfPwf
Pwf = 0Pwf = 0QQ QmaxQmax
INFLOW PERFORMANCE
INFLOW PERFORMANCE RELATIONSHIP
FIG.1 : Actual Case For P I
Pwf
q
It is basically a straight line or curve drawn in the two dimentional plane,where X axis is q ( Flow Rate ) and Y axis is Pwf ( Flowing Bottom Hole Pressure ).
INFLOW PERFORMANCE INFLOW PERFORMANCE RELATIONSHIP :
Q max for Straight P.I. >> Q max for IPR
Pwf
q
It is basically a straight line or curve drawn in the two dimentional plane,where X axis is q ( Flow Rate ) and Y axis is Pwf ( Flowing Bottom Hole Pressure ).
STRAIGHT P.I. AND IPR
STRAIGHT P.I..
Q maxQ max
IPR
Pwf = Pr
Absolute open hole potential ( AOFP)Absolute open hole potential ( AOFP)
INFLOW PERFORMANCE IPR IN DIFFERENT CASES:
PRESS.
PI
GOR
CUMM. PROD.
P I
Typical Performance For A Water Drive Field
GOR
PRESSURE
* Active Water Drive : 1. Strongest drive ( Helps to exploit more than 35% of Initial oil in place ) . 2. However intensity differs in different water drive reservoirs. For e.g. Edge water drive is weaker than Bottom water drive.
INFLOW PERFORMANCE * Solution Gas Drive :
CUMM. PROD.Typical Performance For A Solution Gas Drive Field.
RESV.PRESS
GOR
PI
PI
GOR
RESV.PRESS.
1. Called as ‘Internal Gas Drive’ or ‘Depletion Drive’. 2. Least Effective Drive Mechanism (Exploits about 15% of Initial oil in place). 3. Reservoir Pressure influences the pattern of IPR. PI declines sharply.
INFLOW PERFORMANCE * Gas Cap Expansion drive :
1. Also called as Segregation Drive.2. IPR curve is somewhere in between the Solution Gas Drive & Water Drive. It is more effective than solution gas drive reservoir. (Exploits about 20-25% of Initial oil in place.
Typical Performance For A Gas cap Expansion Drive Reservoir.
CUMM. PROD.
RESV.PRESS.
GOR
PIGOR
P.I
RESV.PRESS.
INFLOW PERFORMANCE * IPR-When Pr > Bubble Point Pressure :
Combination Constant PI and Vogel Behaviour
RATE.
PRESS .
0000
PPwfwf
PPbb
qqQQmaxmaxqqbb
VOGELBEHAVIOR
CONSTANT PI
PPrr
qqvv
INFLOW PERFORMANCE * Change Of PI With Cumm. Recovery ( % Of Oil
In Place ) With Time :
IPRs for a Solution Gas Drive Reservoir with declining Reservoir pressure
PRODUCING RATE , M3/D
BOTTOM HOLE PRESS -Kg/Cm2
Np/N = 0.1%2 %
4 %6 %8 %
10 %12 %
14 %
CUMM. REC., % OF ORIGINAL OIL IN PLACE
INFLOW PERFORMANCE Damaged / stimulated well bore….
F.E = Ideal drawdown / Actual drawdown
=(Pr - P'wf) / (Pr - Pwf) ---(1) Where,
P'wf = Pwf + (DP)skin
(DP)skin defined by Van Everdingen is as below :
(DP)skin = S q / 2 kh
Contd.-----
PrPwf
(DP) Skin
So, P’wf = Pwf + (DP) Skin
INFLOW PERFORMANCE STANDING’S EXTENSION OF VOGEL’S IPR
FOR DAMAGED OR IMPROVED WELL :Where ,
h = Pay thickness q = Flow rate = Viscosity k = Permeability S = Skin factor S = ( + ) indicates damage
S = ( 0 ) indicates no damage/ no improvement S = ( -) indicates improvement Contd.---------
Outflow or Tubing Intake Curve (TIC).Outflow or Tubing Intake Curve (TIC).
Outflow or Outflow or
Tubing Intake Tubing Intake
Curve (TIC).Curve (TIC).
Liquid RateLiquid Rate
PP
Operating PointOperating Point
IPRIPR
TICTIC
PwfPwf
QLQL
PrPr
QL maxQL max00
Outflow or Tubing Intake Curve (TIC) Outflow or Tubing Intake Curve (TIC)
Vs. IPR, or Inflow.Vs. IPR, or Inflow.
Keeping GLR & THP constantKeeping GLR & THP constant
Liquid RateLiquid Rate
PPDecreasing GLRDecreasing GLR
Inflow Vs Outflow CurvesInflow Vs Outflow Curves
IPRIPR
00
Keeping THP ConstantKeeping THP Constant
INTRODUCTION ON ARTIFICIAL LIFT
DEFINITION OF ARTIFICIAL LIFT
When a self flowing oil well ceases to
flow or is not able to deliver the required
quantity to the surface , the additional
energy is supplemented from surface either
by mechanical means or by injecting
compressed gas or high pressure oil/water .
INTRODUCTION ON ARTIFICIAL LIFT
PURPOSE OF ARTIFICIAL LIFT :
PfPf PsPs
To create a steady low pressure or reduced pressure in the well bore against the formation to allow the well fluid to flow into the wellbore by lifting the well fluids from well bottom to the surface
MODES OF ARTIFICIAL LIFTMODES OF ARTIFICIAL LIFT
BY COMPRESSED GAS
BY MECHANICAL
MEANS
Use of High Pressure GasUse of High Pressure Gas Lightens the Liquid Column and helps in lifting the fluid to the surface
Formation Pressure pushes fluid into the well bore
Regular And Single Point Gas liftREFULAR GAS LIFT SINGLE POINT GAS LIFT
PERFORATIONS
PACKER
OPERATING GLVSINGLE POINTPERFORATION
UNLOADING GASLIFT VALVES
PRODN CASING
TUBINGLift Gas Lift Gas
Components of Gas Lift Components of Gas Lift SystemSystem
• High Pressure gas Source (Compressor/HP Gas Well)
•Lift gas Injection line
•Lift gas Metering and Control units
•Gas lift valves
•Gas lift Mandrels
•LP gas compressors
TYPICAL GAS LIFT NETWORK
DistributionHeader
Well Well Well Well
HP Comp GLC
Group Header
Sepa
rato
r
Booster Comp.
Oil + water
COMPRESSED GASCOMPRESSED GAS(Different Modes)(Different Modes)
1) CONTINUOUS GAS LIFT
2) INTERMITTENT GAS LIFT
3) PLUNGER ASSISTED GAS LIFT
4) CHAMBER LIFT
5) MACARONI CARRIED GAS LIFT
COMPRESSED COMPRESSED GASGAS
CONTINUOUS GAS LIFT..
HP gas
COMPRESSED COMPRESSED GASGAS
Intermittent Gas Lift…
Plunger Assisted gas lift
An improvement over intermittent lift.A injection gas lifts the plunger inside the tubing which
moves up the tubing lifting the fluid voer the plungerThis is also used for in gas well unloading
COMPRESSED GASCOMPRESSED GAS
COMPRESSED GASCOMPRESSED GAS(Different Completions)(Different Completions)
1) CLOSED
Packer completion and NRV (Standing valve ) at Tubing shoe
2) SEMI CLOSDOnly Packer Completion
3) OPENNone of the above
4) WIRE LINE RETRIEVABLE ( Side Pocket Mandrel)
5) TUBING RETRIEVABLE ( Conventional Mandrel)
COMPRESSED COMPRESSED GASGAS
Different Different Completions….Completions….
COMPRESSED GASCOMPRESSED GAS(Different Types of Valves)(Different Types of Valves)
1) CASING PRESSURE OPERATED
2) TUBING PRESSURE OPERATED
Produced HydrocarbonsOut
InjectionGas In
Side PocketMandrel withGas Lift Valve
CompletionFluid
Side PocketMandrel withGas Lift Valve
Single ProductionPacker
Side PocketMandrel withGas Lift Valve
GAS LIFT WELL WITH WIRE LINE RETRIEVABLE VALVE
Gas-lift valve in operationWIRELINE RETRIEVABLE TYPE
Macaroni Dip String Chamber Lift
Regular Lift Chamber lift
Tubing7”dia casing
Gas lift valves Working, intermittently
Chamber gas lift valve
Landing nipple
Dip tube macaroni
MACARONI DIP STRING CHAMBER LIFT
Suitable for wells with poor influx and very low bottom hole pressure.
In this a chamber in the casing is created by using packer and the tubing is completed with a macaroni inside the last tubing which dips into the chamber. The tubing provided with conventional GLV’s for unloading and the operating valve is provided below the tubing packer holding the Macaroni.
MACARONI DIP STRING CHAMBER LIFT (Contd.)
Lift gas enters into the chamber through operating valve and the oil collected in the chamber is lifted through the macaroni into the tubing.
This arrangement gives optimum production than simple intermittent lift.
Macaroni with GLV’sGas injection
Lifted oil
2 7/8” tubingMacaroni
GLVGas
Mandrel
Check valve
Casing
Macaroni gas lift.with GLV’s inside Macaroni.
This is an ingenious improvement over the macaroni method of Gas lifting. In this mandrels for fitting Gas lift valves are designed so as to install GLV’s inside the Macaroni . Thus the Macaroni acts as annulus for carrying gas to GLVs. This is the first time ever tried in ONGC and elsewhere.
With this design we can lift liquid from deeper depths compared to the normal Macaroni design and we can get optimized flow from wells with damaged casing.
This can also be used for completion of dual wells.
GASLIFTADVANTAGES
1. EXCELLENT APPLICATION FOR OFFSHORE
2. VERY GOOD FOR WATER DRIVE, HIGH PI & HIGH GLR FIELDS /WELLS
3. HIGH VOLUME LIFT & FLEXIBLE IN CAPACITY
4. EASILY HANDLES SANDS AND SOLIDS
5. MINOR PROBLEM IN DEVIATED WELLS
GASLIFTADVANTAGES (contd..)
6. EASY TO RECORD D/H PRESSURE & TEMP.
7. CENTRALLY GL SYSTEM CAN BE ADOPTED
8. SUB-SURFACE EQUIPMENT ARE RELATIVELY INEXPENSIVE.
9. IT HAS LOW PROFILE, HENCE IT HAS ADVANTAGE IN URBAN AND OFFSHORE AREAS
GASLIFTADVANTAGES (contd..)
10.SUB-SURFACE EQUIPMENT CAN BE ECONOMICALLY SERVICABLE WITH
WIRELINE UNIT.
GASLIFTDISADVANTAGES
1. SENSITIVE TO BACK PRESSURE, WHICH RESTRICT PRODUCTION
2. HIGH ENERGY OPERATING COST
3. LARGE CAPEX & OPEX – COMPRESSOR & HIGH PRESSURE GAS INJECTION LINES
4. INSTALLATION OF COMPRESSOR PRESENTS SPACE & WEIGHT PROBLEMS IN OFFSHORE
GASLIFTDISADVANTAGES (contd..)
5. ADEQUATE GAS SUPPLY IS NEEDED
6. DIFFICULT TO LIFT EMULSIONS &VISCOUS CRUDES
7. GAS FREEZING & HYDRATE PROBLEMS MAY OCCUR ON SURFACE INJECTION LINES
8. CASING MUST WITHSTAND HIGH GAS INJECTION PRESSURE
GASLIFTDISADVANTAGES (contd..)
9. SAFETY PROBLEMS WITH HIGH PRESSURE INJECTION GAS
10. INTERMITTENT G/L IS INEFFICIENT
11. DEPTH LIMITATIONS
MECHANICAL MEANSMECHANICAL MEANS(Different Types)(Different Types)
1) SUCKER ROD PUMP (SRP)
2) ELECTRICAL SUBMERSIBLEPUMP (ESP)
3) PROGRESSIVE CAVITY PUMP (PCP)
4) JET PUMP
SUCKER ROD PUMPING SYSTEM
20
SUCKER ROD PUMPINGADVANTAGES
1. RELATIVELY SIMPLE SYSTEM TO DESIGN
2. EASY FOR FIELD PEOPLE TO UNDERSTAND & OPERATE
3. IT CAN PUMP OFF A WELL TO ALMOST ZERO FLOWING BOTTOM HOLE PRESSURE
4. CAN LIFT VISCOUS CRUDE OILS
5. GOOD FOR LOW TO MEDIUM RATE WELLS
SUCKER ROD PUMPINGDISADVANTAGES
1. CROOKED HOLES LEADS TO EXCESSIVE ROD AND TUBING FRICTIONAL WEAR PROBLEM
2. SAND & SOLID CAN DAMAGE PUMP
3. GASSY WELLS IS USUALLY HAVING LOW VOLUMETRIC EFFICIENCY
4. DEPTH LIMITATION MAINLY DUE TO LIMITED ROD STRENGTH & EXCESSIVE STRETCH
SUCKER ROD PUMPINGDISADVANTAGES (contd..)
5. NOT SUITABLE IN DENSELY POPULATED CITY OR PLATFORM WITH LIMITED DECK AREA
6. PARAFFIN PRESENTS PROBLEM
ELECTRICAL SUBMERSIBLE PUMPING (ESP) SYSTEM
ESP
ADVANTAGES
1. VERY GOOD FOR EXTREMELY HIGH VOLUME LIFT
2. CAN BE EASILY ACCOMODATED IN URBAN AREA
3. SIMPLE TO OPERATE
4. APPLICATION IN BOTH ONSHORE & OFFSHORE
ESPDISADVANTAGES
1. CABLE CAUSES PROBLEM – CABLE DETERIORATE IN HIGH TEMPERATURE
2. DEPTH LIMITATION DUE TO CABLE COST AND OTHER PROBLEMS
3. GAS AND SOLID PRODUCTIONS ARE TROUBLE SOME
4. RELATIVELY LOW MTBR
ESPDISADVANTAGES (contd..)
5. PRODUCTION RATE FLEXIBILITY IS LIMITED
PROGRESSING CAVITY PUMP (PCP)
oRotorPitch
PROGRESSIVE CAVITY PUMPADVANTAGES
1. SUITABLE FOR HANDLING SOLID & VISCOUS FLUID
2. NO VALVE AT SUCTION OR DELIVERY END TO STICK, CLOG OR WEAR OUT
3. GOOD FOR LOW TO MODERATE PRODUCTION
4. PCP COUPLED WITH ELECTRIC SUBMERCIBLE MOTOR IS BETTER THAN SUCKER ROD DRIVEN PCP
PROGRESSIVE CAVITY PUMPDISADVANTAGES
1. IT DOES NOT TOLERATE HEAT – IT SOFTENS STATOR ELASTOMER
2. THOUGH GAS PRESENTS NO GAS LOCK PROBLEM BUT GAS MUST BE SEPARATED TO INCREASE EFFICIENCY OTHERWISE PUMP WILL GET OVERHEATED
3. DEPTH LIMITATIONS
HYDRAULIC JET PUMPADVANTAGES
1. CROOKED HOLE POSES NO PROBLEM
2. SAND & SOLID PRODUCTION PRESENT MINIMUM PROBLEM USING HARDENED NOZZLE AND THROAT
3. VISCOUS CRUDE CAN BE HANDLED EASILY
4. PISTON TYPE JET PUMP IS GOOD FOR VERY DEEP WELLS UP TO 17000 FT, JETPUMP UPTO 7000 FT
HYDRAULIC PUMPADVANTAGES (CONTD..)
5. PRODUCTION CAN BE VARIED TO A GREAT EXTENT BY CHANGING POWER FLUID RATE
6. FREE PUMP DESIGN IS AN ATTRACTIVE PROPOSITION
7. IT CAN BE ACCOMODATED IN URBAN LOCATIONS
8. IT CAN PUMP A WELL DOWN TO FAIRLY LOW BOTTOM HOLE PRESSURE
HYDRAULIC PUMPDISADVANTAGES
1. POWER FLUID CLEANING IS A PROBLEM
2. POSITIVE DISPLACEMENT TYPE HAS SHORTER LIFE THAN SRP & ESP
3. JETPUMP REQUIRES MINIMUM 500 PSI PRESSURE AT 5000 FT & 1000 PSI AT 10000 FT
4. USUALLY SUSEPTIBLE TO GAS INTERFERENCE
HYDRAULIC PUMPDISADVANTAGES (contd..)
5. NOT EASY FOR FIELD PERSONNEL TO TROUBLE SHOOT
6. SAFETY PROBLEM FOR HIGH PRESSURE POWER FLUID
7. JETPUMP IS VERY LOW ENERGY EFFICIENT PUMP
MOST COMMON METHODS OF ARTIFICIAL LIFT
1. GAS LIFT (GL)
2. SUCKER ROD PUMP (SRP)
3. ELECTRICAL SUBMERSSIBLE PUMP (ESP)
4. HYDRAULIC PUMP
MOST IMPORTANT FACTORS FOR CHOICE OF LIFT MODES
FOR VERY HIGH VOLUME OF PRODUCTION GL, ESP or HP
FOR VERY LOW VOLUME OF PRODUCTION SRP or IGL
FOR MODERATE VOLUME OF PRODUCTION GL, ESP, HP or SRP
FOR VERY DEEP WELL HP
TYPE OF LIFT REQUIRED IS INFLUENCED BY1. WHETHER CONVENTIONAL OR MULTIPLE COMPLETIONS2. PRODUCING LOCATION - ONSHORE, OFFSHORE, REMOTE LOCATIONS (IN ONSHORE / OFFSHORE)3. WEATHER CONDITIONS4. CORROSION5. FLUID PARAMETERS6. WELL DEPTH7. WELL CONDITIONS & PARAMETERS8. TOTAL RESERVOIR ASPECT9. DESIRED PRODUCTION RATE10. SERVICES AVAILABLE11. ECONOMIC CONSIDERATIONS
Oil FieldsOil Fields
OffshoreOffshore(Cont. G/L, ESP, Hyd. (Cont. G/L, ESP, Hyd. Jetpump, Hyd. Piston Jetpump, Hyd. Piston Pump)Pump)
OnshoreOnshore(G/L, ESP, SRP, Hyd. (G/L, ESP, SRP, Hyd. Jetpump, Hyd. Piston Jetpump, Hyd. Piston Pump)Pump)
Cont. G/LCont. G/L G/L, SRPG/L, SRP
ARTIFICAL LIFT SCENARIOARTIFICAL LIFT SCENARIO
WORLD ONGC*
Total oil wells - 846765 4476
Self flow wells - 55981 793
Art. Lift wells - 790784 3683
% of Art. Lift wells- 93.7% 82.2%
*01-04-2005
BREAK-UP AMONG ARTIFICIAL BREAK-UP AMONG ARTIFICIAL LIFT WELLSLIFT WELLS
WORLD ONGC(Aprl-2005) Wells % of total Wells % of Total
A/L Wells A/L Wells
SRP - 652706 82.5% 1708 46%
G/L - 67047 8.5% 1932 53%
ESP - 39195 4.96% 21 0.5 %
Hydraulic - 4472 0.05% 4 -
PCP - 27223 3.44% 18 0.5%