Download - Intro Art Lift Final

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.


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.


BUBBLE BUBBLE

FLOWFLOW

MULTIPHASE FLOWVERTICAL / INCLINED FLOWVERTICAL / INCLINED FLOW

OCCURS AT RELATIVELYLOW LIQUID RATES. Gas bubbles

SLUG FLOWSLUG 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


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


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.


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.


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.


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.


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


CORRELATIONS FOR


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


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)


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


Single ProductionPacker


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%

Download - Intro Art Lift Final

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