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Transcript of Introduction
1
Introduction
Artificial Lift Methods
2
Artificial Lift - Uses
• In Oil Wells, Gas Wells and Coal Bed Methanewells:– To “boost” or increase production of naturally flowing
wells– To put dead wells back into production– To stabilize the unsteady production of some naturally
flowing wells– To “kick-off” wells that can produce naturally but may
die when closed and can not achieve the naturalequilibrium flowrate without help
• In water injection wells– To “backflow” and clean the injection zone
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Artificial Lift Methods
• There are several artificial lift methods. The most common ones are:–––––––––
Beam PumpingElectrical Submersible PumpContinuous Gas LiftProgressive (Progressing) Cavity PumpHydraulic Jet PumpIntermittent Gas LiftPlunger LiftHydraulic Reciprocating PumpEtc…
• Some methods are used exclusively to dewater gas wells– Foam and soap bars
• For deep water conditions it may be more convenient to install theartificial lift device outside the production well at some point of theseabed. Those methods are called Boosting Methods. The mostcommon ones are:––––
Sub-sea multiphase pumpingRiser gas liftSub-sea separation and pumpingEtc…
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Beam Pump
Pumping Unit
Prime Mover
Polished RodSuffing Box
Tubing
Sucker Rods
Pump
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Electrical Submersible Pumping
Primary Transformer
Switchboard
Wellhead andelectricmandrel
Tubing
Round Cable
Packer
Pump
Separator
Protector
Flat Cable
Motor
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Continuous Gas Lift
Injection Choke
Christmas Tree
Unloading Valve
Gas Lift Mandrel
Tubing
Operating Valve
Packer
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Christmas Tree
Progressing Cavity Pump
Transformer
Polished Rod
Control
Panel Electric Motor
Tubing
Rods
Downhole PCP
Gas Anchor
Anchor
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Hydraulic Jet Pumping
Transformer
Control PanelMotor Power Fluid Treatment
Valve
Christmas Tree
Tubing
Downhole Pump
Standing Valve
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Tubing
Unloading Valve
Valve Mandrel
Operating Valve
Packer
Check Valve
Intermittent Gas Lift
IntermitorChristimas Tree
Pressure Gas
Open
Closed
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ComputerOpenClosed
Nipple
Plunger Lift
Catcher
Control Valve
Tubing
Plunger
Plunger stop
Seating nipple
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Distribution of Artificial Lift Methods
• 90% of the wells in the world produce by some form ofartificial lift method
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Main Important Methods
• Sucker Rod Pump– Most commonly used method worldwide– Used massively in US and in significant number of wells in
Russia, China and South America– Simple to operate and inexpensive compared to other methods,
but usually lower pumping capacity– Problems with high GLR, with small tubing, with deep wells and
with crooked or deviated wells– Can achieve very low bottom hole flowing pressure making it
ideal for very depleted reservoirs• Electrical Submersible Pump
– Second most commonly used method worldwide (+100,000wells)
– Used massively in Russia and in significant number of wells inUS
– Responsible for the highest amount of total fluids produced (oiland water) by any artificial lift method and an ideal method forhigh water cut wells
– Problems with sand production, high gas liquid ratio and highbottom hole temperatures
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Main Important Methods
• Continuous Gas Lift– Very flexible and service through wireline is
inexpensive. Tolerant to sand and solids production,tolerant to high GLR, tolerant with deviated wells
– Requires a stable source of high pressure gas andlooses efficiency as bottom hole flowing pressuredeclines and may require the use of another artificiallift method as reservoir ages
– The high reliability of the method makes it the firstchoice for offshore production instead of ESP
• Progressing Cavity Pump– Less expensive than other methods and tolerant to
solids and sand production– Selection of materials (elastomer for the stator) very
dependent on temperature and fluids composition
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Main Important Methods
• Hydraulic Jet Pump, Intermittent Gas Lift andPlunger Lift– Special circunstances makes those methods very
effective in some applications– Hydraulic Jet Pump
• Very beneficial for high-viscosity crudes where blending witha light power fluid can help in the processing of heavy crudes
– Intermittent Gas Lift• Very beneficial for wells with a reasonably high reservoir
pressure but low productivity where stimulation is not anoption and high gas liquid ratio makes the use of beam pumpdifficult
– Plunger Lift• Used in combination with intermittent gas lift to reduce liquid
fall back or by itself in wells that present casing heading as aform of enhanced natural flow. Very used in dewateringapplications
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Beam Pump
Pumping Unit
Prime Mover
Polished RodSuffing Box
Tubing
Sucker Rods
Pump
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Beam Pump
•••••••••
•
The oldest and most commonly used form of artificial liftFamiliar to most engineers and operatorsAllow very low fluid levels (low bottom hole flowing pressure)Low capital investment for low production at shallow to medium depthsHigh investment for high flow rates in deep wellsAdaptable to scale and corrosion problemsLimitation with casing sizeNot suitable for crooked holesMay have problems with sand production, high viscosity fluids and high GLRwellsEasily installed in remote locations with an internal combustion engine
Pumping Unit
Prime Mover
Polished RodSuffing Box
Tubing
Sucker Rods
Pump
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Electrical Submersible Pumping
Primary Transformer
Switchboard
Wellhead andelectricmandrel
Tubing
Round Cable
Packer
Pump
Separator
Protector
Flat Cable
Motor
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Electrical Submersible Pumping
••
••
••
••••
Very complex system. MTBF average around 2 ½ year worl wideCan be applicable to a wide range of flowrates from 100 bpd up to 100,000 bpd but efficiencyreduces with a decrease in flowrateInvestment cost directly related to the depth due to cable cost and motor horsepowerEfficiency increases with reduction in produced GLR either by reduction of GOR or increase inWC. Efficiency decreases with decrease in flowrateCasing size is not critical for high flowratesRequires work-over to remove a conventional unit although cable and coil deployed options areavailableElectrical systems is the weak link and requires a stable source of electricityElectrical system (cable, motor and protector) very sensitive to operating temperatureCan be flexible with the use of a VSD. Very delicate installation and a high rate of “infant mortality”May have problems with scale, sand and wax
Primary Transformer
Switchboard
Wellhead andelectricmandrel
Tubing
Round Cable
Packer
Pump
Separator
Protector
Flat Cable
Motor
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Continuous Gas Lift
Injection Choke
Christmas Tree
Unloading Valve
Gas Lift Mandrel
Tubing
Operating Valve
Packer
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Continuous Gas Lift
••••
•
•
•
•
Very simple method seen as an extension of natural flowRequires a source of high pressure gas and casing and lines must withstand injection pressureLow investment for deep wells if high pressure gas is availableEfficiency decreases with decrease in production GLR either due to a reduction in GOR orincrease in WCNo problem with sand and crooked wells. Can be used in deviated wells but highly deviated wellsmay have problems retrieving valves with wire lineVery flexible and simple design, applicable in a wide range of flowrates from 50 bpd (macaronitubing) to 40,000 bpd (casing flow)There is a relation between the minimum possible bottom hole flowing pressure, the depth and thefluid propertiesMost design modification and repairs can be done through wire line intervention without the needof a workover
Injection Choke
Christmas Tree
Unloading Valve
Gas Lift Mandrel
Tubing
Operating Valve
Packer
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Christmas Tree
Progressing Cavity Pump
Transformer
Polished Rod
Control
Panel Electric Motor
Tubing
Rods
Downhole PCP
Gas Anchor
Anchor
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Progressing Cavity Pump
••
•
••
Christmas Tree
Is a positive displacement pump that does not rely on valves to pump fluidsUsually has a stator made of an elastomer. Stator material is sensitive to oilcomposition (aromatics) and temperatureHas higher tolerance to free gas than beam pumping, but excess gas can also causelack of lubrication and cooling as well as chemical problems with the elastomerMay have problems with deviated and crooked wellsApplicable for low to medium flowrates
Transformer
Polished Rod
Control
Panel Electric Motor
Tubing
Rods
Downhole PCP
Gas Anchor
Anchor
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Hydraulic Jet Pumping
Transformer
Control PanelMotor Power Fluid Treatment
Valve
Christmas Tree
Tubing
Downhole Pump
Standing Valve
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Hydraulic Jet Pumping
••
•
•••
Very simple methodFrom all artificial lift methods this is the one that has the biggest depth applicationrangeThe use of a light oil as the power fluid makes this a very interesting method for highviscosity fluidsRequires an injection of 5 to 7 times the volume of liquid producedNo moving parts, applicable to deviated and crooked wellsPump can be back-circulated to the surface
Transformer
Control Panel
Motor Power Fluid TreatmentValve
Christmas Tree
Tubing
Downhole Pump
Standing Valve
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Tubing
Unloading Valve
Valve Mandrel
Operating Valve
Packer
Check Valve
Intermittent Gas Lift
IntermitorChristimas Tree
Pressure Gas
Open
Closed
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Intermittent Gas Lift
•
•••
•
Tubing
Unloading Valve
Valve Mandrel
Operating Valve
Packer
Check Valve
Despite the name this is a “pumping” method. The pump is a “gas piston” thatexpands and accelerates to the surface propelling a liquid slug on topSame general characteristics of continuous gas liftUsually used for low flowrate rangeIntermittent gas injection and liquid production can disrupt the separation system aswell as can interfere with other wellsHigh instantaneous consumption of injected gas
IntermitorChristimas Tree
Pressure Gas
Open
Closed
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ComputerOpenClosed
Nipple
Plunger Lift
Catcher
Control Valve
Tubing
Plunger
Plunger stop
Seating nipple
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Plunger Lift
•
•
••
ComputerOpen
Closed
Nipple
A mechanical interface (plunger) used to reduce the liquid fall back inintermittent gas lift wellsCan be used without external gas injection using the production gasaccumulated in the casingPlunger descend velocity will affect production cycle and production flowrateCan be used with and without an external injection of gas
Catcher
Control Valve
Tubing
Plunger
Plunger stop
Seating nipple
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Hydraulic Reciprocating Pumps
• This method is a combination of a positive displacement pump(similar to a sucker rod pump) actuated by a hydraulic system(similar to the power fluid injection system of hydraulic jet pump)
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Auto Gas Lift
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Auto Gas Lift
• Curious application where a gas zone is isolated with 2 packers andused as the high pressure gas source for a gas well
• The gas injection can only be controlled by the injection gas lift valve
32
Well Multiphase Pumping
••
Can-K Multiphase PumpsAdvantages
––––
Very Low shear rate and hence, least emulsion compared to ESPPositive displacement pumpCan be installed in vertical, slanted or horizontal wellsHigh temperature capability of up to 287DegreesC (550DegreesF) withCAN-K top drive
• Volume:– 24 m3/day to 8898 m3/day (150 to 56,000 bbl/day)
• Casing Sizes:– From 139.7mm to 339.9mm(5 1/2" to 13 3/8") casing suitability.
• Drive:– Electric Submersible Motor or CAN-K top drive.
• Speed:– Up to 6000 rpm
• Power:– Up to 850 HP
• Installation:– Installed exactly like an ESP system and suitable for all available
Standard electric submersible motors. Alternatively installed with suckerrod
• Prime Movers:– Downhole Electric Motors -
• Will bolt to any existing Downhole electric motor with no modification required– Top Drive
••
Electric or HydraulicRod String
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Hydraulic Driven Centrifugal Pump
•
••
The Weir hydraulic drive downhole pumping system is a newconcept designed specifically to provide reliability andflexibility in downhole pumping applications.Today this technology is offered by Clyde Pumps in GlasgowSpecifications––––
up to 100,000 barrels/dayup to 1,000 hp5000 to 15,000 rpmup to 400°F
•
•
•
•
In a typical application a proportion of the produced fluid isbled off from the well output line and passed through acyclone separator (or equivalent filter) to achieve therequired filtration level of not more than 100 micron/100ppm.The fluid is then boosted in pressure by a suitable surfacecharge pump and passes through a control valve (whichenables the well output to be varied) down the power supplytubing on which the downhole pump set is suspended, andinto the turbine to provide the power required to drive thepump.The pump takes its suction from the reservoir and increasesthe fluid pressure to overcome static and friction heads anddeliver the required quantity to the wellhead at the designedpressure.Outlet from the pump mixes with the turbine exhaust and thecombined fluids flow up the annulus between the powersupply tubing and the production tubing and out of thewellhead into the production line
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Diaphragm Pumps
• There are several Diaphragm pumps available• Smith Lift developed a Hydraulic Diaphragm Electric
Submersible pump• The pump is driven by a 3 phase electric motor that
actuates two diaphragms to positively displace fluids• It was developed for low liquid production (less than 200
bpd) and for wells shallow than 2,500 ft
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Balance Pump
•
•
•
The Balance pump is a hydraulically actuated reciprocating, low-volume pump that can be used to remove liquid from onshore andoffshore gas wellsThe pump, which can be retrofitted, is operated by two hydrauliclines—one filled with oil, the other with waterThe differential hydrostatic pressure between water and oil movesthe pump’s internal piston downward. The application of pressureto the oil line drives the piston upward, lifting the water trappedabove the travelling check and drawing water into the lowerchamber. Removing the pressure from the hydraulic line allowsthe water line to return the piston, after which pressure isreapplied to the hydraulic line
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Curiosities
37
Swab