nodal 06 artificial lift 11-1 g

8/11/2019 Nodal 06 Artificial Lift 11-1 G

1/13


2/13

PETE 410 L11-1 2

VLP and System Stability

VLP1

q qstable unstable

VLP2

VLP3 VLP4


3/13


4/13

PETE 410 L11-1 4

Major Forms of Artificial Lift

Rod Pump

TubingAnchor

Rod PumpHydraulic

Pump

SubmersibleElectricPump

Progressive-Cavity Pump

Pump

ArmoredCable

Pump

ElectricMotor

Lubricator

ElectronicController

Control

Equipment

Gas-LiftValve

Packer

StandingValve

(Optional)

Plunger

BumperSpringTubingStop

Floater/Stator

SuckerRod

Catcher

w/ ArrivalSensor

DriveHead

Plunger LiftGas Lift


5/13

PETE 410 L11-1 5

Artificial Lift Methods,US (from PWC, 1998)

Beam or rod pump 85 %

Continuous gas lift 10 %

Electric submersile pump 4 %

Hydraulic (piston & jet) 2 %Progressive cavity pump 1 %

% No of wells


6/13

PETE 410 L11-1 6

Relative Advantages of Artificial-Lift Systems (1 of 2)

Rod Pumping Hydraulic Electric Gas Lift Hydraulic Plunger Progressive-Piston Submersible Jet Pump Lift Cavity Pumps

Pumping PumpingRelatively simple Not so depth limited- Can lift extremely Can withstand Retrievable Retrievable Some types aresystem design. can lift large volumes high volumes. large volume of without pulling without pulling retrievable with

from great depths. 20,000 bbl/d solids with minor tubing. tubing. rods.Units easilychanged to otherwells with minimalcost.

Efficient, simple

and easy for fieldpeople to operate.

Applicable toslim holesand multiplecompletions.

Can pump a welldown to very lowpressure (depth andrate dependent).

System usually isnaturally vented forgas separation andfluid level soundings.

Flexible-can matchdisplacement rateto well capability aswell declines.

Analyzable.

500 bbl/d (79.49 m 3/d)from 15,000 ft (4572 m)have been installedto 18,000 ft (5,486.4 m).

Crooked holes present

minimal problems

Unobtrusive in urbanlocations.

Power source can beremotely located.

Analyzable.

Flexible-can usuallymatch displacementto well's capability aswell declines.

Can use gas orelectricity as powersource.

Downhole pumps canbe circulated out infree systems.

Currently lifting +120,000 bbl/d(19,068m 3/d) fromwater supply wellsin Middle East with600-hp (448-kW)units; 720-hp(537-kW). Available;1000-hp (746-kW)under development.

Unobtrusive inurban locations.

Simple to operate.

Easy to install

downhole pressuresensor fortelemeteringpressure to surfaceby cable.

Crooked holespresent no problem.

Applicable offshore.

Handles largevolume in high-PIwells (continouslift). 50,000 bbl/d(7949.37 m 3/d)

Fairly flexible-convertible fromcontinuous tointermittent tochamber or plungerlift as well declines.


Power source can

be remotely located.Easy to obtaindownhole pressuresand gradients.

Lifting gassy wellsis no problem.

Sometimesserviceable withwireline unit.

No moving parts.

No problems indeviated orcrooked holes.


Applicableoffshore.

Can use water asa power source.

Power fluid doesnot have to be as

clean as forhydraulic pistonpumping.

Corrosion scaleemulsiontreatment easy toperform.

Veryinexpensiveinstallation.

Automaticallykeeps tubingclean ofparaffin,scale.

Applicable forhigh gas-oilratio wells.

Can be usedin conjunctionwith intermittent

gas lift.

Can be usedto unload liquidfrom gas wells.

Moderate cost.

Low profile.

Can use

downholeelectric motorsthat can withstandsand and viscousfluid.

High electricalefficiency.


7/13

PETE 410 L11-1 7

Relative Advantages of Artificial-Lift Systems (2 of 2)

Rod Pumping Hydraulic Electric Gas Lift Hydraulic Plunger Progressive-Piston Submersible Jet Pump Lift Cavity Pumps

Pumping PumpingCan lift high-temperatureand viscous oils

Can use gas orelectricity as powersource.

Corrosion and scaletreatments easy toperform.

Applicable topump-off controlif electrified.

Availability ofdifferent sizes.

Hollow sucker rodsare available forslimholecompletions andease of inhibitortreatment.

Have pumps withdouble valving thatpump on bothupstroke anddownstroke.

Can pump a welldown to fairly lowpressure.

Applicable to multiplecompletions.

Applicable offshore.

Closed system willcombat corrosion.

Easy to pump incycles by time clock.

Adjustable gear boxfor triplex offers moreflexibility.

Mixing power fluidwith waxy or viscouscrudes can reduceviscosity.

Corrosion andscale treatmenteasy toperform.

Availability indifferent size.

Lifting cost forhigh volumesgenerallyvery low.

Crooked holespresent noproblem.

Corrosion is notusually asadverse.

Applicableoffshore.

Power sourcecan be remotelylocated and canpump highvolumes to30,000 bbl/d(4769.623 m 3 /d).


8/13

PETE 410 L11-1 8

Relative Disadvantages of Artificial-Lift Systems 1 of 2

Rod Pumping Hydraulic Electric Gas Lift Hydraulic Plunger ProgressivePiston Submersible Jet Pump Lift Cavity Pumps

Pumping PumpingCrooked holespresent a frictionproblem.

High solidsproduction istroublesome.

Gassy wellsusually lower

volumetricefficiency.

Depth is limited,primarily basedon rod capability.

Obtrusive inurban locations.

Heavy and bulkyin offshore

operations.

Susceptible toparaffinproblems.

Tubing cannotbe internallycoated forcorrosion.

Power oil systemsare a fire hazard.

Large oil inventoryrequired in poweroil system, whichdetracts fromprofitability.

High solidsproduction istroublesome.

Operating costs aresometimes higher.

Usually susceptibleto gas interference-usually not vented.

Vented installations

are more expensivebecause of extratubing required.

Treating for scalebelow packer isdifficult.

Not easy for fieldpersonnel totroubleshoot.

Not applicable tomultiple completions.

Only applicable withelectric power.

High voltages(1000 V) arenecessary.

Impractical in shallow,low-volume wells.

Expensive to changeequipment to matchdeclining wellcapability.

Cable causes problemswith tubular handling.

Cables deteriorate in

high temperatures.

System is depth limitedto 10,000 ft (3048.0 m)because of cable costand inability to installenough powerdownhole (dependson casing size).

Lift gas isnot alwaysavailable.

Not efficient inlifting smallfields or one-wellleases.

Difficult to lift

emulsions andviscous crudes.

Not efficient forsmall fields orone-well leasesif compressionequipment isrequired.

Gas freezingand hydration

problems.

Problems withdirty surfacelines.

Some difficultyin analyzingproperly withoutengineeringsupervision.

May not takewell to depletion;hence, eventuallyrequiring anotherlift method.

Good for low-ratewells onlynormally lessthan 299 bbl/d

(31.8 m/d).

Requires moreengineeringsupervision toadjust properly.

Plunger mayreach too higha velocity andcause surfacedamage.

Communicationbetween tubingand casing surfacerequired for goodoperation unlessused inconjunction withgas lift.

Elastomers instator swell insome well fluids.

POC is difficult.

Lose efficiencywith depth.

Rotating rods wear

tubing; windup andafterspin of rodsincrease withdepth.

Relativelyinefficient liftmethod.

Requires atleast 20%submergence toapproach bestlift efficiency.

Design ofsystem ismore complex.

Pump maycavitateunder certainconditions.

Very sensitiveto any change inbackpressure.

The producingof free gasthrough thepump causesreduction inability to pumpliquids.

Power oilsystems are afire hazard.


9/13

PETE 410 L11-1 9

Relative Disadvantages of Artificial-Lift Systems 2 of 2

Rod Pumping Hydraulic Electric Gas Lift Hydraulic Plunger ProgressivePiston Submersible Jet Pump Lift Cavity Pumps

Pumping PumpingH2S limits depthat which a large-volume pumpcan be set.

Limitation ofdownhole pumpdesign in small-diameter casing.

Difficult to obtainvalid well tests inlow-volume wells

Requires two stringsof tubing for someinstallations.

Problems intreating power

water where used.

Safety problem forhigh surfacepressure power oil.

Loss of power oil insurface equipmentfailure.

Gas and solidsproduction aretroublesome.

Not easily analyzableunless goodengineeringexperience is available.

Lack of production

rate flexibility.

Casing size limitation.

Cannot be set belowfluid entry without ashroud to route fluidby the motor. Shroudalso allows corrosioninhibitor to protectoutside of motor.

More down-timewhen problems areencountered becauseentire unit is downhole.

Cannoteffectivelyproduce deepwells toabandonment.

Requires makeupgas in rotativesystems.

Casing mustwithstand liftpressure.

Safety is aproblem withhigh-pressuregas.

High surfacepower fluidpressures arerequired.


10/13

PETE 410 L11-1 10

Questions to Ask

Is a source of gas available?

Is power available?

How deep?Is the well deviated?

What are the target production rates?

Is water a problem?Is scale present?


11/13

PETE 410 L11-1 11

RelativeRanges of ALMethods(After Nind TEW)

Gross Productivity Index

S t a t i c b o

t t o m

h o l e

p r e s s u r e

Pumping: Sucker Rod, Subm EP, Hydraulic, Prog CP

Flowing


12/13

Artificial-Lift Methods Chart (PWC)

(1 of 2)Plunger

Gas Lift

Beam

ESP

1 10 100 1000 10,000 100,000

2000

4000

6000

8000

10,000

12,000

14,000

16,000

18,000

0

Rate, STB/d

D e p

t h , f t


13/13

Artificial-Lift Methods Chart (PWC)(2 of 2)

Hyd. Jet

Hyd.Recip.

1 10 100 1000 10,000 100,000

2000

4000

6000

8000

10,000

12,000

14,000

16,000

18,000

0

Rate, STB/d

D e p

t h ,

f t

nodal 06 artificial lift 11-1 g

Documents