artificial lift
TRANSCRIPT
PETE 410 L11-1 1
Methods of artificial lift
presented to:
Prof Dr : El ayouty . Elsaid
PETE 410 L11-1 2
Prepared by :
Sabry kasem galal .
Amir wagdy .
Mena ebrahim.
Beshoi ghaly.
Hany saeed .
PETE 410 L11-1 3
Artificial Lift- Overview
Sucker Rod or Beam Pump
Hydraulic Pumping, Submersible
Electric Pump, Progressive Cavity
Pump
Continuous Flow Gas Lift
Plunger Lift
PETE 410 L11-1 4
Major Forms of Artificial Lift
Rod Pump
Tubing Anchor
Rod PumpHydraulic
Pump
SubmersibleElectricPump
Progressive-Cavity Pump
Pump
Armored Cable
Pump
ElectricMotor
Lubricator
ElectronicController
Control Equipment
Gas-LiftValve
Packer
StandingValve(Optional)
Plunger
BumperSpring
TubingStop
Floater/Stator
SuckerRod
Catcher w/ Arrival Sensor
DriveHead
Plunger LiftGas Lift
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
PETE 410 L11-1 6
Relative Advantages of Artificial-Lift Systems (1 of 2)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 Pumping
Relatively 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 minimal cost.
Efficient, simpleand easy for field people to operate.
Applicable to slim holes and multiplecompletions.
Can pump a well down to very lowpressure (depth andrate dependent).
System usually isnaturally vented forgas separation and fluid level soundings.
Flexible-can matchdisplacement rateto well capability aswell declines.
Analyzable.
500 bbl/d (79.49 m3/d)from 15,000 ft (4572 m) have been installed to 18,000 ft (5,486.4 m).
Crooked holes presentminimal problems
Unobtrusive in urban locations.
Power source can be remotely located.
Analyzable.
Flexible-can usually match displacement to well's capability aswell declines.
Can use gas or electricity as powersource.
Downhole pumps can be circulated out infree systems.
Currently lifting +120,000 bbl/d(19,068m3/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 installdownhole pressuresensor fortelemetering pressure to surface by cable.
Crooked holespresent no problem.
Applicable offshore.
Handles largevolume in high-PIwells (continouslift). 50,000 bbl/d(7949.37 m3/d)
Fairly flexible-convertible fromcontinuous tointermittent to chamber or plungerlift as well declines.
Unobtrusive inurban locations.
Power source canbe remotely located.
Easy to obtaindownhole pressuresand gradients.
Lifting gassy wellsis no problem.
Sometimesserviceable with wireline unit.
No moving parts.
No problems in deviated orcrooked holes.
Unobtrusive in urban locations.
Applicable offshore.
Can use water as a power source.
Power fluid doesnot have to be as clean as for hydraulic pistonpumping.
Corrosion scaleemulsiontreatment easy toperform.
Veryinexpensiveinstallation.
Automaticallykeeps tubing clean ofparaffin,scale.
Applicable for high gas-oilratio wells.
Can be used in conjunctionwith intermittentgas lift.
Can be usedto unload liquidfrom gas wells.
Moderate cost.
Low profile.
Can usedownholeelectric motors that can withstand sand and viscousfluid.
High electricalefficiency.
PETE 410 L11-1 7
Relative Advantages of Artificial-Lift Systems (2 of 2)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 Pumping
Can lift high-temperatureand viscous oils
Can use gas orelectricity as powersource.
Corrosion and scaletreatments easy toperform.
Applicable to pump-off controlif electrified.
Availability ofdifferent sizes.
Hollow sucker rods are available for slimholecompletions and ease of inhibitortreatment.
Have pumps with double valving that pump 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 box for triplex offers more flexibility.
Mixing power fluidwith waxy or viscouscrudes can reduceviscosity.
Corrosion and scale treatment easy toperform.
Availability indifferent size.
Lifting cost forhigh volumes generallyvery low.
Crooked holes present noproblem.
Corrosion is not usually as adverse.
Applicable offshore.
Power sourcecan be remotelylocated and can pump highvolumes to 30,000 bbl/d(4769.623 m3/d).
PETE 410 L11-1 8
Relative Disadvantages of Artificial-Lift Systems 1 of 2Relative Disadvantages of Artificial-Lift Systems 1 of 2
Rod Pumping Hydraulic Electric Gas Lift Hydraulic Plunger Progressive Piston Submersible Jet Pump Lift Cavity Pumps Pumping Pumping
Crooked holes present a frictionproblem.
High solidsproduction istroublesome.
Gassy wellsusually lowervolumetricefficiency.
Depth is limited,primarily based on 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 installationsare more expensivebecause of extra tubing required.
Treating for scale below packer isdifficult.
Not easy for field personnel totroubleshoot.
Not applicable tomultiple completions.
Only applicable with electric power.
High voltages (1000 V) are necessary.
Impractical in shallow,low-volume wells.
Expensive to changeequipment to match declining well capability.
Cable causes problemswith tubular handling.
Cables deteriorate inhigh temperatures.
System is depth limitedto 10,000 ft (3048.0 m)because of cable costand inability to installenough powerdownhole (dependson casing size).
Lift gas is not always available.
Not efficient inlifting small fields or one-wellleases.
Difficult to liftemulsions andviscous crudes.
Not efficient for small fields or one-well leasesif compressionequipment is required.
Gas freezingand hydrationproblems.
Problems withdirty surface lines.
Some difficultyin analyzing properly withoutengineeringsupervision.
May not takewell to depletion;hence, eventually requiring anotherlift method.
Good for low-rate wells onlynormally less than 299 bbl/d(31.8 m/d).
Requires moreengineering supervision to adjust properly.
Plunger may reach too high a velocity and cause surfacedamage.
Communicationbetween tubingand casing surfacerequired for good operation unlessused inconjunction withgas lift.
Elastomers instator swell insome well fluids.
POC is difficult.
Lose efficiencywith depth.
Rotating rods wear tubing; windup andafterspin of rods increase withdepth.
Relativelyinefficient liftmethod.
Requires at least 20%submergence toapproach bestlift efficiency.
Design ofsystem ismore complex.
Pump maycavitate under certain conditions.
Very sensitiveto any change inbackpressure.
The producingof free gas through the pump causes reduction in ability to pump liquids.
Power oil systems are a fire hazard.
PETE 410 L11-1 9
Relative Disadvantages of Artificial-Lift Systems 2 of 2
Rod Pumping Hydraulic Electric Gas Lift Hydraulic Plunger Progressive Piston Submersible Jet Pump Lift Cavity Pumps Pumping Pumping
H2S limits depthat which a large-volume pump can be set.
Limitation ofdownhole pump design in small-diameter casing.
Difficult to obtainvalid well tests in low-volume wells
Requires two strings of tubing for some installations.
Problems in treating powerwater where used.
Safety problem forhigh surfacepressure power oil.
Loss of power oil insurface equipmentfailure.
Gas and solidsproduction aretroublesome.
Not easily analyzableunless goodengineering experience is available.
Lack of production rate flexibility.
Casing size limitation.
Cannot be set below fluid entry without ashroud to route fluid by the motor. Shroud also allows corrosion inhibitor to protect outside of motor.
More down-time when problems are encountered becauseentire unit is downhole.
Cannoteffectivelyproduce deepwells toabandonment.
Requires makeupgas in rotative systems.
Casing must withstand liftpressure.
Safety is a problem withhigh-pressuregas.
High surfacepower fluidpressures arerequired.
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?
PETE 410 L11-1 11
Relative Ranges of AL Methods (After Nind TEW)
Gross Productivity Index
Sta
tic
bott
om
hole
pre
ssure
Cont
inuo
us g
as li
ft
Inte
rmit
tent
gas
lift
Pumping: Sucker Rod, Subm EP, Hydraulic, Prog CP
Flowing