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Copyright 2001 SIEP B.VCompletion Equipment
IE P B .VWell life cycle roles and responsibilities
z
Production technology (basis for well design)
Selection of suitable well type
Reservoir well bore interface
Tubing and casing size and quality
z
Drilling Engineer (well bore and structure detail design and construction
Construction of well bore and structure
Installation of completion
z
Production Operations (well conduit detail design and maintenance of well)
Selection of components
Acceptance of constructed asset
Operate well
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Completion categories based on the reservoir
-wellbore interface
UNCEMENTED LINER COMPLETION OPENHOLE COMPLETION PERFORATED COMPLETION Sump Casing Cement Cap rock Casing shoe Openhole interval Rubble or gravel Damaged zone Perforations Productive formation Slotted liner Liner hanger Cement Production casing Dr No TCM 6198 .VCompletion functional requirements
z
Provide optimum flowing conditions
z
Protect casing
z
Downhole emergency isolation
z
Permit downhole chemical injection
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IE P B .VC opy ri ght 2001 S IE P B .V
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Bowl type tubing head
IE
P
B
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.V PermanentPacker
z
Simple slip and packer design
z
Capable of withstanding high tensile
forces and differential pressures
z
Relatively large through bore
z
Indicated when:
Differential pressure across packer exceeds
5000 psi
Temperature exceeds 225 deg F
H2S is present
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Permanent Packer Characteristics
z
Top and bottom slips
z
Packer element (solid / complex)
z
Anti-extrusion rings for element
z
Ratch-latch mechanism to hold
set
z
Milling required to recover
z
Designed for milling – lock rings
etc
IE
P
B
.V
Packer Setting Options
z
Mechanical
Rotation
Compression
Tension
z
Hydraulic
Pressure applied to tubing or annulus
Differential pressure acts on setting tool (permanent packer) or internal
setting sleeve (retrievable packer)
Preferred method for deep / deviated wells
z
Electrical
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Hydraulically Set Packers
z
Packer set using internal
pressure (against tubing plug)
z
Pressure acts through port (A) on
setting piston (B)
z
Shear pin (C) breaks
z
Setting sleeve drives bottom slips
(D) up against cone (E)
z
Element (F) and upper slips
energised then slips break and bite
into casing
A
B
C
D
E
F
.VAnchor Latch
•Anchors the completion tubing to
the packer
•Creates a static seal between the
tubing and the packer
•Allows the packer to be run with
the completion (one run)
•Can be rotated out of the packer
•Can be re-installed with a straight
push into the packer
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IE P B .VC opy ri ght 2001 S IE P B .V
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Advantage of having Seal Area above
Packer
d D D Tubing Max. Dia. Seal Area Casing Packer IE P B .VMonobore Completion
9 5/ 8” Casing, 8.54” ID TRSCSSV Landing Nipple, 5.750” ID 7” Tubing, 5.963” ID Flow Coupling Seal Stem, 6.023” ID Liner PBR, 7.50” ID Back Packer/Liner HangerC opy ri ght 2001 S IE P B .V
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.VBlowout
Kuwait
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Wireline retrievable safety valve
IE
P
B
.V
Where in the string do we put the SCSSV?
z Limitation of valve
z Hydrate depth
z Cratering depth
z Collapse limitation of tubing
z Scaling, wax, asphaltenes
z KO point
z Risk assessment
z Subsidence
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Safety Valve Landing Nipple
Honed bore
Non welded shoulder
to protect C/L while RIH
Honed bore
Control line
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Integral annulus safety valve
IE
P
B
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Ways of providing a circulation route
z
Sliding side door
z
Side pocket mandrel
z
Coiled tubing
z
Tubing punch
.V
Reverse v forward circulation
z
Potentially corrosive well fluids kept off casing
z
Less pressure on surface equipment
z
Natural direction for the flow of the lighter hydrocarbons
z
Better sweep of hydrocarbons out of tubing
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IE P B .VC opy ri ght 2001 S IE P B .V
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IE P B .VC opy ri ght 2001 S IE P B .V
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IE P B .VC opy ri ght 2001 S IE P B .V
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Xmas Trees
IE P B .VXmas Trees
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.VC opy ri ght 2001 S IE P B .V