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W e l l
c o m p l e t i o n
a n d
i n t e r v e n t i o n
Well Completion Functions & Applications
Eng. El Sayed Amer
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Schedule Time frame managing
Well completion introduction Completion string equipment Surface wellhead equipment Well intervention applications and techniques Wireline & coiled tubing Workover and well problems troubleshooting
Eng. El Sayed Amer
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About well completion
Welcome Introductions completion involves all of the operations designed to make the well produce, in particular connecting the borehole and the pay zone, treating the pay zone, equipping the well, putting it on stream and assessing it. By pay zone we mean a zone consisting of reservoir rocks which contain oil and/or gas that can be recovered.
Eng. El Sayed Amer
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Introduction Well Completion The objective of a completion is to convey fluids from the reservoir to the surface, in a safe and efficient manner. Process: The design, selection and installation of tubular, tools and equipment, located in the wellbore, for the purpose of conveying, pumping or controlling production (or injection) fluids.
Eng. El Sayed Amer
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Introduction
Completion History/Evolution 1814 First naturally flowing oil well – 475 ft 1822 Rudimentary art of drilling established 1905 Casing cemented 1911 First gas lift device 1913 First dual completion 1926 First electric submersible pump 1933 First gun perforation job 1969 Commercial coiled tubing services introduced
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Petroleum system
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Typical flowing well.
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Typical Casing Program
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Completion cost completion costs generally fall in the range of $2.9 MM to $5.6 MM per well
wellhead equipment
completion liner and tubing
source water, water additives,
€ £ € £ £ € £ €
completion and perforating crews
pumping equipment rentals
completion Eng. El Sayed Amer
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Purpose of a Completion
7
•
To produce hydrocarbons in a
Injection well
•
the well
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To inject fluids in a safe and cost effective manner throughout the 2
safe and cost effective manner throughout the life of
9
6
Production Well:
life of the well •
For
disposal
maintenance
or
pressure
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IDEAL COMPLETION
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LOWEST COST
02
MEETS DEMANDS PLACED ON IT DURING PRODUCTION LIFE.
03
GENERALLY THE SIMPLER THE COMPLETION THE GREATER IT’S RELIABILITY.
04
WELL WORKOVER MAY ALSO BE CONSIDERED PART OF COMPLETION DESIGN.
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Well control and barriers barrier systems through the life of the well
Drilling a well
Primary barrier Overbalanced mud capable of building a filter cake
Primary barrier Running completion
Pulling the BOP
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Isolated and tested reservoir completion, for example inflow-tested cemented liner or pressure-tested isolation valve
Primary barrier
Secondry barrier Casing/wellhead and BOP
Secondry barrier Casing/wellhead and BOP
Secondry barrier
Packer and tubing
Casing, wellhead and tubing Hanger.
Isolated reservoir completion, for example deep-set plug
Tubing hanger plug. Possible additional barrier of downhole safety valve
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Well control and barriers barrier systems through the life of the well
Naturally flowing well
Operating a pumped well not capable of flowing naturally
Primary barrier
Secondry barrier
Christmas Packer and tubing
Downhole safety valve. Casing, wellhead and tubing hanger
Primary barrier
Secondry barrier
Christmas tree or surface valve Casing and wellhead
Primary barrier Pulling a completion
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Pump shut-down
Isolated and tested reservoir completion, for example deep-set plug and packer or overbalanced mud
Secondry barrier Casing/wellhead and BOP
Completion Functions
• The Starting Point
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Completion Functions
functions
Protect the Casing
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Section of corroded tubing from well in Oman
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Completion Functions
Contain the Reservoir
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functions
Protect the Casing
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Completion Functions
Contain the Reservoir
Allow Well Killing
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functions
Protect the Casing
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Completion Functions
Contain the Reservoir
Allow Well Killing
functions
Protect the Casing
Install the Tubing String
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Completion Functions
functions
Limit Production Problems
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Completion Functions
Enable Chemical Injection
functions
Enable Tubing to Casing Circulation
< 2,000 ft
Circa 9,740 ft Circa 9,770 ft
SPM With Chemical Injection Valve
Circa 9,800 ft
Circa 10,000 ft Eng. El Sayed Amer
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Completion Functions
Enable Chemical Injection
Enable Well Kill Can be Annulus to Tubing Or Tubing to Annulus
functions
Enable Tubing to Casing Circulation
Sliding Side Door (SSD)
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Factor affecting completion Design 02
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Factor affecting completion Design
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Artificial Lift Psurf = surface pressure psurf
Ph = hydrostatic pressure
Uses alternate sources to lift or lighten fluid column ph Artificial lift is required when reservoir pressure is not sufficient to lift fluids to surface.
Pwf = flowing well pressure pwf Eng. El Sayed Amer
MAIN FACTORS INFLUENCING COMPLETION DESIGN well’s purpose The purpose of drilling can vary depending on the well type.
environment well is located, whether on land (plain or mountain, desert, agricultural or inhabited area, etc.) or offshore (floating platform, development from a fixed platform or by subsea wellhead)
reservoir initial reservoir pressure, natural or artificial flow pattern.
production Flowing well or artificial lift, In addition to the separation pressure Anticipated measurement, maintenance or work over operations
Completion techniques the pay zone to borehole connection, •treatment of the formation if required
60 % Eng. El Sayed Amer
Completion cost around 60% of the well total cost and the Success or failure of well is related to success in well completion design and techniques
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Well Completion Down hole Environment Factors over which the operator has no control:
1
2
3
4
5
Formation Temperature
Formation Pressure
Corrosion due to H2S, CO2, or microbes
Scale buildup
Production type (Oil, Gas, Water
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6 Sand, paraffin, and asphaltines
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Well Completion Operator Variables
Factors which the operator can control:
1
2
3
4
5
Material Selection - Metallurgy, Elastomers
Reservoir Interface
Completion, disposal, and stimulation fluids
Applied and hydrostatic pressures
Injection temperature
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6 Tubular design, forces and stresses, dimensional contraints, etc.
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Well Completion Logging Data Known at time of drilling Angle of Dip (Dipmeter) Reservoir Pressure (P)
Porosity (Acoustic) Fluid Contacts Hole Size
(Calliper) Formation Boundaries (Gamma Ray)
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(Resistivity)
Reservoir Temperature (T)
Completion design criteria A. B. C. D.
Open Hole/Barefoot Cased Hole Horizontal Multilateral
Wellbore/Reservoir/Interface
01 Eng. El Sayed Amer
02 Producing Zones
A. B.
Single Zone Multiple Zone
A. B.
04
Natural Flow Artificially Induced
Production Method
03
Number of Tubing Strings
A. B.
I. Single String J. Multiple Strings
The Starting Point B OP S tac k Wellhead
C as ing
Inhibited Brine (KCl)
10,000 ft Eng. El Sayed Amer
Formation
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Types of Completions Well completion types
Interface between Wellbore and Reservoir
• Open hole • Cased hole Production Method
• Artificial lifting • Flowing
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Number of Zones Completed
• Single • Multiple zones
Completion design criteria 01
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Wellbore, Reservoir Interface Completion
A
Open Hole/Barefoot
B
Cased Hole
C
Horizontal
D
Multilateral
1st well completion introduction
Completion techniques and functions
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Completion design criteria Classification Criteria
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Wellbore/Reservoir/Interface
A. B. C. D.
Open Hole/Barefoot Cased Hole Horizontal Multilateral
Producing Zones
E. F.
Single Zone Multiple Zone
Production Method
G. Natural Flow H. Artificially Induced
Number of Tubing Strings
I. Single String J. Multiple Strings
Open hole completion Applications
Deep wells, consolidated with depletion drive
horizontal and multi lateral wells
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Naturally fractured reservoirs
Low cost completion budget
Open hole Completion summary
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Open hole Completion summary
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Advantages of Open Hole Completions The entire pay zone is open
Maximum wellbore diameter is
to the wellbore
opposite the pay zone
1
Perforation expense is
Expensive log analysis not
eliminated
required
1 2
Reduce casing cost
3 Eng. El Sayed Amer
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5
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Disadvantages of Open Hole Completions 1 2
Excessive gas or water production difficult to control because the- .entire interval is open to flow
3 4
The casing may need to be set before the pay zone(s) are drilled and logged
Separate zones within the completion cannot be selectively fractured or acidized
Requires frequent cleanout if producing formations are not completely firm Eng. El Sayed Amer
Open Hole Completion
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Open Hole Completion
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Surface Casing Production Casing
Tubing Packer
RESERVOIR
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Open Hole Completion
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a. Slotted Liner Completion
SURFACE CASING
TUBING
PACKER PRODUCTION CASING
RESERVOIR
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LINER HANGER SLOTTED,PERFORATED OR SCREEN LINER
Open Hole Completion a. Slotted Liner Completion Cement Casing
Hanger (usually with a packer) Casing Shoe
Slotted Liner (shown diagrammatically) Oil Sand
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Liner Shoe
Open Hole Completion a. Slotted Liner Completion
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Cased hole Completion summary
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Cased Hole Completion
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a. Cemented & Perforated casing
Perforations
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Cement Production Casing
Cased Hole Completion
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b. Cemented & Perforated Liner
Liner Hanger Cement
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Cement Production Casing Liner Perforations
Cased Hole Completion
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b. Cemented & Perforated Liner
Cement
Casing
Hanger (usually with a packer) Casing Shoe Cemented Liner
Oil Sand
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Liner Shoe
Cased Hole Completion
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Gravel Pack Completion • What is a ‘Gravel Pack’?
• Placement of prepared gravel of a specific size against the reservoir interface to control the movement of formation solids into the well stream
• What is a ‘Frac Pack’?
• Placement of a slurry of efficient fluid and a properly sized proppant into a formation at pressures exceeding the frac gradient of the formation stone for the purpose of increasing the productivity of the completion and reducing the production related stresses on the formation
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Gravel Pack Open Hole Completion SURFACE CASING
TUBING
PACKER PRODUCTION CASING GRAVEL PACK
RESERVOIR
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LINER HANGER SLOTTED,PERFORATED OR SCREEN LINER
Gravel Pack Cased Hole Completion
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Tubing
Liner Hanger Slotted, Perforated or Screen Liner RESERVOIR
Gravel Eng. El Sayed Amer
Packer Production Casing Perforations
Gravel Pack FRAC AND PACK COMPLETION
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Tubing
Liner Hanger Slotted, Perforated or Screen Liner
Packer Production Casing Perforations
RESERVOIR
Gravel Eng. El Sayed Amer
Hydraulic Fracture
Gravel Pack
GP Packer
Blank Pipe Screens Sump Packer
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Crossover Wash pipe
Gravel (sand) Fracture created and propped in some cases
WWW.BOX.COM
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Actual sand screen completion
Sand control and gravel pack INSIDE CASING GRAVEL PACK
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UNDERREAMED CASING GRAVEL PACK
SCREEN LINER IN OPEN HOLE
OPEN HOLE GRAVEL PACK
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UNDERREAMED OPEN HOLE GRAVEL PACK
Sand Screens
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Sand control completions
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Comparison of Completions Completion Type Cased Hole
Liner
-
Open Hole
-
Advantages Pressure control Isolation of zones Control of stimulation Wellbore Stability Less expensive than casing entire hole Pressure and stimulation control (when cemented) Wellbore stability Maximum flow area Minimize damage
-
Slimhole
- Lower Cost
-
Eng. El Sayed Amer
Disadvantages More expensive Limited communication to reservoir Possible cement damage Cementing more difficult No control of flow if not cemented Slots plugged w/formation Limited control of stimulation No control of flow Limited or no control of stimulation Hole collapse in weak formations Limited workover capability due to small hole Limited stimulation rate No zone isolation
Multi Lateral Completion
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Multi Lateral Completion
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Horizontal Completion
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Surface Readout Conductor line
SCSSV
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Bull Nose
7” Slotted Liner (0.040”)
Seal Bore Receptacle
7” Pre-Packed Screens (Baker ‘Slim Pack’, 0.012”)
Gravel Pack Extension
SC-1LR Packer
Permanent Pressure Gauges
Horizontal Completion 65
41/2” Hanger
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Horizontal Completion OPEN HOLE
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SLOTTED LINER
PRE-PACK SCREEN
Production Casing Cement Sheath Open Hole Section
Slotted Liner
Pre-Pack Screen
◦◦ ◦◦◦ ◦◦ ◦◦◦ ◦◦ ◦◦◦ ◦◦
GRAVEL PACK
CMT & PERF LINER
Graded Gravel Gravel Pack Screen
• ••••••••••••••••••• • ••• •••••• •••• •••• Eng. El Sayed Amer
Perforations
Horizontal Completion
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Completion design criteria 02
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Producing Zones Completion
A
Single Zone
B
Multiple Zone
Single Zone / Single String Tubing
Packer
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Interval Co-Mingling
70
Tubing
Packer
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Selective Completion
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Producing a Zone between Packers 72
Top Packer OPEN
CLOSED
Sliding Sleeve
Perforated Interval Eng. El Sayed Amer
Bottom Packer
Dual Zone / Single String
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Dual Zone / Dual String
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Dual Zone / Dual String
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Dual Zone / Dual String
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Multi Zone / Multi String
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Triple Packer Flow Couplings Dual Packer Single Packer
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DUAL STRING SELECTIVE COMPLETION
This completion design increases the well’s functionality by using sliding sleeves to independently produce, stimulate, test or isolate one or more zones, using slickline or other methods to manipulate the sleeves. The example at the right highlights a quad zone completion.
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CONCENTRIC STRING Tubing Strings Packers
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INTERVAL SEGREGATION
SSDs
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Packers
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MULTIPLE ZONE COMPLETION
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Completion design criteria 03
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Mode Of Production
A
Natural Flow
B
Artificially Induced
Natural flow completion Tubing-less
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Small OD Casing or Large Tubing Cement Perforations
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Natural flow completion Retrievable Completion / Temporary Tubing Retrievable Packer Wireline Nipple
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Natural flow completion Permanent / High Pressure Completion Sliding Sleeve
No-Go Wireline Nipple
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Permanent Packer Millout Extension Perforated Joint
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Natural flow completion High Rate Liner (Monobore) Polished Bore Receptacle Liner Hanger Liner
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Large Tubing Sliding Side Door Cement
Artificial Lift Methods
Commonly used artificial lift methods include: Rod pump Gas lift Electric submersible pump Piston pump Jet pump
Plunger lift Other specialist or adapted systems
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Artificial Lift Methods
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Artificial Lift Completion a. Rod Pump
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Artificial Lift Completion a. Rod Pump Walking beam
90
Horsehead
Stuffing box and polished rod Prime mover Production valve
Gearbox and counterbalance
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Artificial Lift Completion a. Rod Pump
• Rod pumps account for approximately 60% of onshore artificial lift completions • Industry accepted • Economic in ideal field • Not gas dependent • Limited efficiency • Maintenance intensive • Vertical wellbores
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Artificial Lift Completion a. Rod Pump
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Artificial Lift Completion b. Hydraulic Pump
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Tubing
Pump Housing Standing Valve
Pump Seating Nipple
Piston Pump Eng. El Sayed Amer
Artificial Lift Completion c. Jet Pump
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Tubing
Pump Pump Seating Nipple
Jet Pump Eng. El Sayed Amer
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Artificial Lift Completion d. Gas lift
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Artificial Lift Completion e. Plunger Lift
Piston pump system
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Jet pump system
101
Plunger Lift System Downhole Equipment
Plunger (with liquid load Intermitter or controller
Plunger catcher
Tubing stop Injection gas Production
Standing valve Tubing stop
Surface Equipment
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Artificial Lift Completion
f. Electrical Submersible Pump (ESP)
Armored cable Cable guard Sliding sleeve Dual string retrievable packer (modified)
Sliding sleeve No-go seating nipple
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Pump assembly (various) Pump Intake Protector Motor
102
103
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Surface power
enters through wellhead Power Cable
Electric Submersible Pump (ESP)
Run with tubing string Banded to tubing Pump
Hung below fluid level by discharge head Pump intake
Fluid Level
Fluids enter system Protector
Equalizes pressures Isolates motor from fluids Perforations
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Motor
Mounted above perforations for cooling
Artificial Lift Completion F. Electrical Submersible Pump (ESP)
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Artificial Lift Completion G. Progressive cavity Pump (PCP)
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Artificial Lift Completion
107
Electronic Controller Drive Head
Lubricator
Armored Cable
Plunger Pump
Rod Pump Hydraulic Pump
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Catcher w/ Arrival Sensor
Gas-Lift Valve
Pump
Rod Pump Tubing Anchor
Control Equipment
Electric Motor
Submersible Electric Pump
Gas Lift
Packer Standing Valve (Optional)
Bumper Spring Tubing Stop
Plunger Lift
Sucker Rod
Floater/ Stator
ProgressiveCavity Pump
Completion design criteria 04
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PRODUCING ZONES
A
Single Zone
B
Multi Zone
Single String Completion Single Completion
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Single Selective Interval
109
Single Selective Interval
Single Commingle
MULTIPLE Completion string Multiple Completion
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Concentric Completion
Multiple Commingle Completion
110
Multiple Selective Completion
Major COMPLETION TYPES OPEN ENDED (SUSPENDED) TUBING PRODUCTION
BASIC PACKER PRODUCTION
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PACKER WITH NIPPLES, SLIDING SLEEVE AND SAFETY VALVE
PACKER WITH PERFORATED TAIL PIPE
Production safety valve
Downhole Isolation (plug) Downhole Instrumentatio n (gauges)
Well kill capability but no control of annular fluid level and possible exposure to corrosion Eng. El Sayed Amer
Well kill capability when packer is released
Downhole Isolation (plugs) above and below packer through sliding Circulate sleeve without packer release
Casing string protected from corrosion and production stresses by inhibited packer
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