Transcript No Slide Title

Introduction to Artificial Lift
Methods
• This section introduces the main
methods of artificial lift with a
brief description, advantages,
disadvantages, operational
windows considering depth vs.
rate.
• All methods are covered in detail
in following sections.
ARTIFICIAL LIFT SYSTEMS
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Overview of Artificial Lift
Systems:
Features
Advantages
Disadvantages
ARTIFICIAL LIFT SYSTEMS
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Inflow to node
Predicted node
pressure
P at node
Outflow from note
Predicted flow
Q
ARTIFICIAL LIFT SYSTEMS
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ARTIFICIAL LIFT SYSTEMS
© Weatherford. All rights reserved.
Reciprocating Rod Lift
System Advantages
Sucker Rod
Tubing Anchor/
Catcher
 High System Efficiency
 Optimization Controls Available
Sucker Rod
Pump
Assembly
 Economical to Repair and Service
 Positive Displacement/Strong Drawdown
 Upgraded Materials Reduce
Corrosion Concerns
 Flexibility - Adjust Production
Through Stroke Length and Speed
 High Salvage Value for Surface &
Downhole Equipment
ARTIFICIAL LIFT SYSTEMS
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Reciprocating Rod Lift
System Limitations
Sucker Rod
Tubing Anchor/
Catcher
 Potential for Tubing and Rod Wear
Sucker Rod
Pump
Assembly
 Gas-Oil Ratios
 Most Systems Limited to Ability of
Rods to Handle Loads - Volume
Decreases As Depth Increases
 Environmental and Aesthetic
Concerns
ARTIFICIAL LIFT SYSTEMS
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Rod Lift System
Application Considerations
Typical Range
Sucker Rod
Operating
Depth
100 - 11,000’ TVD
16,000’ TVD
Operating
Volume
5 - 1500 BPD
5000 BPD
Operating
Temperature
100° - 350° F
550° F
0 - 20° Landed
Pump
0 - 90° Landed
Pump <15°/100’
Build Angle
Wellbore
Deviation
Tubing Anchor/
Catcher
Corrosion Handling
Sucker Rod
Pump
Assembly
Good to Excellent
w/ Upgraded Materials
Gas Handling
Fair to Good
Solids Handling
Fair to Good
Fluid Gravity
>8° API
Servicing
Workover or Pulling Rig
Prime Mover Type
*Special
Analysis
Required
Maximum*
Offshore Application
System Efficiency
Gas or Electric
Limited
45%-60%
ARTIFICIAL LIFT SYSTEMS
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Vertical
Electric Wellhead
Drive
Progressing Cavity Pumping
System Advantages

Low Capital Cost
Casing
 Low Surface Profile for Visual
and Height Sensitive Areas
Production Tubing
Sucker Rod
 High System Efficiency
 Simple Installation, Quiet Operation
Sucker Rod Coupling
Tubing Collar
Stator
Rotor
 Pumps Oils and Waters with Solids
 Low Power Consumption
 Portable Surface Equipment
 Low Maintenance Costs
Tubing Collar

Use In Horizontal/Directional Wells
ARTIFICIAL LIFT SYSTEMS
Tag Bar Sub
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Vertical
Electric Wellhead
Drive
Progressing Cavity Pumping
System Limitations
Casing
 Limited Depth Capability
 Temperature
Production Tubing
 Sensitivity to Produced Fluids
Sucker Rod
 Low Volumetric Efficiencies in
Sucker Rod Coupling
High-Gas Environments
Tubing Collar
Stator
Rotor
 Potential for Tubing and Rod
Coupling Wear
 Requires Constant Fluid Level
above Pump
Tubing Collar
ARTIFICIAL LIFT SYSTEMS
Tag Bar Sub
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Progressing Cavity System
Application Considerations
Typical Range
Operating
Depth
2,000 --4,500’ TVD
Operating
Volume
Vertical
Electric Wellhead
Drive
4,500 BPD
75 -150° F
250° F
N/A
0 - 90° Landed
Pump <15°/100’
Build Angle
Casing
Wellbore
Deviation
Production Tubing
Corrosion Handling
Gas Handling
Sucker Rod Coupling
Tubing Collar
*Special
Analysis
Required
Tubing Collar
Fair
Good
Solids Handling
Excellent
Fluid Gravity
<35° API
Servicing
Stator
Rotor
6,000’ TVD
5 - 2,200 BPD
Operating
Temperature
Sucker Rod
Maximum*
Workover or Pulling Rig
Prime Mover Type
Gas or Electric
Offshore Application
Good (ES/PCP)
System Efficiency
40%-70%
ARTIFICIAL LIFT SYSTEMS
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Tag Bar Sub
Injection
Gas In
Produced
Hydrocarbons
Out
Side Pocket
Mandrel with
Gas Lift Valve
Gas Lift
System Advantages
 High Degree of Flexibility and
Design Rates
 Wireline Retrievable
Side Pocket
Mandrel with
Gas Lift Valve
 Handles Sandy Conditions Well
 Allows For Full Bore Tubing Drift
Side Pocket
Mandrel with
Gas Lift Valve
Completion
Fluid
Single Production
Packer
 Surface Wellhead Equipment
Requires Minimal Space
 Multi-Well Production From
Single Compressor
 Multiple or Slimhole Completion
ARTIFICIAL LIFT SYSTEMS
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Injection
Gas In
Produced
Hydrocarbons
Out
Side Pocket
Mandrel with
Gas Lift Valve
Gas Lift
System Limitations
 Needs High-Pressure Gas Well or
Compressor
Side Pocket
Mandrel with
Gas Lift Valve
 One Well Leases May Be
Uneconomical
Side Pocket
Mandrel with
Gas Lift Valve
Completion
Fluid
Single Production
Packer
 Fluid Viscosity
 Bottomhole Pressure
 High Back-Pressure
ARTIFICIAL LIFT SYSTEMS
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Gas Lift System
Application Considerations
Injection
Gas In
Produced
Hydrocarbons
Out
Typical Range
Maximum*
Operating
Depth
5,000 -10,000’ TVD
15,000’ TVD
Operating
Volume
100 - 10,000 BPD
30,000 BPD
100 - 250° F
400° F
0- 50°
70°
Short to
Medium
Radius
Operating
Temperature
Wellbore
Deviation
Side Pocket
Mandrel with
Gas Lift Valve
Corrosion Handling
Side Pocket
Mandrel with
Gas Lift Valve
Gas Handling
Excellent
Solids Handling
Side Pocket
Mandrel with
Gas Lift Valve
Good
Fluid Gravity
Best in >15° API
Servicing
Single
Production
Packer
Completion
Fluid
Wireline or Workover Rig
Prime Mover Type
*Special
Analysis
Required
Good to Excellent with
Upgraded Materials
Compressor
Offshore Application
Excellent
System Efficiency
10% - 30%
ARTIFICIAL LIFT SYSTEMS
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Lubricator
Catcher
Solar Panel
Controller
Motor Valve
Dual “T” Pad
Plunger
Orifice Control
Valves
Plunger Lift
System Advantages
 Requires No Outside Energy Source -
Uses Well’s Energy to Lift
 Dewatering Gas Wells
 Rig Not Required for Installation
Bumper
Spring
 Easy Maintenance
 Keeps Well Cleaned of Paraffin Deposits
 Low Cost Artificial Lift Method
 Handles Gassy Wells
 Good in Deviated Wells
 Can Produce Well to Depletion
ARTIFICIAL LIFT SYSTEMS
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Lubricator
Catcher
Solar Panel
Controller
Motor Valve
Orifice Control
Valves
Plunger Lift
System Limitations
Dual “T” Pad
Plunger
 Specific GLR’s to Drive System
 Low Volume Potential (200 BPD)
Bumper
Spring
 Solids
 Requires Surveillance to Optimize
ARTIFICIAL LIFT SYSTEMS
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Plunger Lift System
Application Considerations
Solar Panel
Controller
Typical Range
Maximum*
Lubricator
Catcher
Operating
Depth
8,000’ TVD
19,000’ TVD
Orifice Control
Valves
Operating
Volume
1-5 BPD
200 BPD
120° F
500° F
N/A
80°
Operating
Temperature
Motor Valve
Wellbore
Deviation
Dual “T” Pad
Plunger
Corrosion Handling
Excellent
Gas Handling
Excellent
Solids Handling
Bumper
Spring
Poor to Fair
GLR Required
300 SCF/BBL/1000’ Depth
Servicing
Wellhead Catcher or Wireline
Prime Mover Type
*Special
Analysis
Required
Offshore Application
System Efficiency
Well’s Natural Energy
N/A at this time
N/A
ARTIFICIAL LIFT SYSTEMS
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Surface Power
Fluid Package
Hydraulic Piston Lift
System Advantages
Production
Casing
 Often “Free” or Wireline Retrievable
 Positive Displacement - Strong
Packer Nose
High Pressure
Power Fluid
Bottom Hole
Assembly
Drawdown
 Double-Acting High-Volumetric
Efficiency
 Good Depth/Volume Capability Piston or Jet
“Free Pump”
+15,000 ft.
 Deviated Wells
 Multi-Well Production From
Standing Valve
Single Surface Package
 Horsepower Efficiency
ARTIFICIAL LIFT SYSTEMS
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Surface Power
Fluid Package
Hydraulic Piston Lift
System Limitations
Production
Casing
 Solids
Packer Nose
High Pressure
Power Fluid
Bottom Hole
Assembly
 Requires Specific Bottom Hole
Assemblies
 Medium Volume Potential
(50 - 1000 BPD)
Piston or Jet
“Free Pump”
 Require Service Facilities
 Free Gas
Standing Valve
 Requires High-Pressure
Surface Line
ARTIFICIAL LIFT SYSTEMS
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Hydraulic Piston Lift
Application Considerations
Typical Range
Surface Power
Fluid Package
Packer Nose
Operating
Depth
7,500 - 10,000’ TVD
17,000’ TVD
Operating
Volume
50 - 500 BPD
4,000 BPD
Operating
Temperature
100° - 250° F
500° F
0 - 20°
Landed Pump
0 - 90° Pump
Placement <15°/100’
Build Angle
Wellbore
Deviation
Production
Casing
High Pressure
Power Fluid
Corrosion Handling
Bottom Hole
Assembly
Fair
Solids Handling
Poor
>8° API
Servicing
Hydraulic or Wireline
Prime Mover Type
Standing Valve
*Special
Analysis
Required
Good
Gas Handling
Fluid Gravity
Piston or Jet
“Free Pump”
Maximum*
Offshore Application
System Efficiency
Multi-Cylinder or Electric
Good
40%-50%
ARTIFICIAL LIFT SYSTEMS
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Surface Power
Fluid Package
Hydraulic Jet Lift
System Advantages
Production
Casing
 No Moving Parts
Packer Nose
High Pressure
Power Fluid
 High Volume Capability
 “Free” Pump
Bottom Hole
Assembly
 Deviated Wells
Piston or Jet
“Free Pump”
 Multi-Well Production from
Single Surface Package
Standing Valve
 Low Pump Maintenance
ARTIFICIAL LIFT SYSTEMS
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Surface Power
Fluid Package
Hydraulic Jet Lift
System Limitations
Production
Casing
 Producing Rate Relative to
Packer Nose
High Pressure
Power Fluid
Bottomhole Pressure
 Some Require Specific Bottomhole
Bottom Hole
Assembly
Assemblies
Piston or Jet
“Free Pump”
 Lower Horsepower Efficiency
 High-Pressure Surface Line
Standing Valve
Requirements
ARTIFICIAL LIFT SYSTEMS
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Hydraulic Jet Lift
Application Considerations
Typical Range
Surface Power
Fluid Package
Production
Casing
Packer Nose
High Pressure
Power Fluid
Operating
Depth
5,000 - 10,000’ TVD
15,000’ TVD
Operating
Volume
300 - 1,000 BPD
>15,000 BPD
Operating
Temperature
100° - 250° F
500° F
Wellbore
Deviation
0 - 20°
Hole Angle
0 - 90° Pump
Placement <24°/100’
Build Angle
Corrosion Handling
Bottom Hole
Assembly
Good
Solids Handling
Good
>8° API
Servicing
Hydraulic or Wireline
Prime Mover Type
Standing Valve
*Special
Analysis
Required
Excellent
Gas Handling
Fluid Gravity
Piston or Jet
“Free Pump”
Maximum*
Multi-Cylinder or Electric
Offshore Application
Excellent
System Efficiency
10%-30%
ARTIFICIAL LIFT SYSTEMS
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Motor Control
Vent Box
Produced
Hydrocarbons Out
Production
Tubing
Pump
Electric Submersible
Pumping System
Advantages
 High Volume and Depth Capability
 High Efficiency Over 1,000 BPD
Flat Cable
Extension
Seal Section
 Low Maintenance
 Minor Surface Equipment Needs
 Good in Deviated Wells
Motor
 Adaptable to All Wells With 4-1/2”
Casing and Larger
 Use for Well Testing
ARTIFICIAL LIFT SYSTEMS
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Motor Control
Vent Box
Produced
Hydrocarbons Out
Production
Tubing
Electric Submersible
Pumping System
Limitations
Pump
 Available Electric Power
 Limited Adaptability to Major
Flat Cable
Extension
Seal Section
Changes in Reservoir
 Difficult to Repair In the Field
 Free Gas and/or Abrasives
 High Viscosity
Motor
 Higher Pulling Costs
ARTIFICIAL LIFT SYSTEMS
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Electric Submersible Systems
Application Considerations
Typical Range
Motor Control
Vent Box
Produced
Hydrocarbons Out
Operating
Depth
1,000’ - 10,000’ TVD
Operating
Volume
200 - 20,000 BPD
30,000 BPD
100° - 275° F
400° F
Operating
Temperature
Production
Tubing
10°
Wellbore
Deviation
Pump
Corrosion Handling
Flat Cable
Extension
Seal Section
0 - 90° Pump
Placement <10° Build
Angle
Good
Poor to Fair
Solids Handling
Poor to Fair
>10° API
Servicing
Workover or Pulling Rig
Prime Mover Type
*Special
Analysis
Required
15,000’ TVD
Gas Handling
Fluid Gravity
Motor
Maximum*
Electric Motor
Offshore Application
Excellent
System Efficiency
35%-60%
ARTIFICIAL LIFT SYSTEMS
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ARTIFICIAL LIFT SYSTEMS
© Weatherford. All rights reserved.
2.
Elimination Process
Rod Lift
Progressing
Cavity
Gas Lift
Plunger
Lift
Hydraulic
Piston
Hydraulic
Jet
Electric
Submersible
100’ 16,000’ TVD
2,000’ 6,000’ TVD
5,000’ 15,000’ TVD
8,000’ 19,000’ TVD
7,500’ 17,000’ TVD
5,000’ 15,000’ TVD
1,000’15,000’ TVD
5 - 5000
BPD
5 - 4,500
BPD
200 - 30,000
BPD
1 - 5 BPD
50 - 4,000
BPD
300 - >15,000
BPD
200 - 30,000
BPD
100° 550° F
75°-250° F
100° 400° F
120° 500º F
100° 500° F
100° 500° F
100° 400° F
Corrosion
Handling
Good to
Excellent
Fair
Good to
Excellent
Excellent
Good
Excellent
Good
Gas
Handling
Fair to
Good
Good
Excellent
Excellent
Fair
Good
Poor to
Fair
Solids
Handling
Fair to
Good
Excellent
Good
Poor to
Fair
Poor
Good
Poor
to Fair
Fluid
Gravity
>8° API
<35° API
>15° API
GLR Required 300 SCF/BBL/
1000’ Depth
>8° API
>8° API
>10° API
Workover or
Pulling Rig
Gas or
Electric
Workover or
Pulling Rig
Gas or
Electric
Hydraulic or
Wireline
Multicylinder
or Electric
Hydraulic or
Wireline
Multicylinder
or Electric
Workover or
Pulling Rig
Electric
Motor
Limited
Good
Excellent
N/A
Good
Excellent
Excellent
45% - 60%
40% - 70%
10% - 30%
N/A
45% - 55%
10% - 30%
35% - 60%
Operating
Depth
Operating
Volume (Typical)
Operating
Temperature
Servicing
Prime Mover
Offshore
Application
Overall System
Efficiency
Wellhead
Wireline or
Workover Rig Catcher or Wireline
Wells’ Natural
Compressor
Energy
ARTIFICIAL LIFT SYSTEMS
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2.
Elimination Process
Gas Lift
ESP
25,000
20,000
15,000
Hydraulic
Jet Pump
10,000
16,000
15,000
14,000
13,000
12,000
11,000
10,000
9,000
8,000
7,000
6,000
5,000
4,000
3,000
5,000
2,000
Hydraulic
Jet Pumps,
Electric
Submersible
Pumping
and Gas Lift
30,000
1,000
High
Volume
Barrels per Day
35,000
Lift Depth
ARTIFICIAL LIFT SYSTEMS
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Elimination Process
4,000
3,500
3,000
2,500
2,000
Recip. Hydraulic
1,500
Recip. Rod Pump
1,000
PC Pumps
500
16,000
15,000
14,000
13,000
12,000
11,000
10,000
9,000
8,000
7,000
6,000
5,000
4,000
3,000
Plunger Lift
2,000
Reciprocating
Hydraulic
Pumps,
PC Pumps,
Rod Pumps &
Plunger Lift
4,500
1,000
Lower
Volume
Barrels per Day
2.
Lift Depth
ARTIFICIAL LIFT SYSTEMS
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Lower Rate Applications
700.0
Recip. Hydraulic
650.0
600.0
550.0
PCPumps
500.0
450.0
3
m /D
400.0
Recip Rod Pumps
350.0
300.0
250.0
200.0
Plunger Lift
150.0
100.0
50.0
0.0
0
500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500
Depth, m
ARTIFICIAL LIFT SYSTEMS
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m3/D
Hi-Volume Selection of Lift
6000.0
5500.0
5000.0
4500.0
4000.0
3500.0
3000.0
2500.0
2000.0
1500.0
1000.0
500.0
0.0
Gas Lift
ESP
Jet Pump
0
500 1000 1500 2000 2500 3000 3500 4000 4500 5000
Depth, m
ARTIFICIAL LIFT SYSTEMS
© Weatherford. All rights reserved.
Summary
• Information has been presented on the
major methods of AL.
• Already enough information has been
presented that would allow you to rule out
certain methods of lift for particular
applications.
• Later sections describe the various
systems in detail, discuss operational
considerations, discuss design and
analysis and other details of each system.
ARTIFICIAL LIFT SYSTEMS
© Weatherford. All rights reserved.