completions equipment

© 1999 Shell International Exploration and Production B.V. 19/04/2006 Completion Design.ppt, page 1

SShheell ll EP LEP LeeaarrnniinnggCopyright 2001 SIEP B.V

Completion Equipment

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SShheell ll EP LEP Leeaarrnniinngg

Well life cycle roles and responsibilities

Production technology (basis for well design)Selection of suitable well typeReservoir well bore interfaceTubing and casing size and quality

Drilling Engineer (well bore and structure detail design and constructionConstruction of well bore and structureInstallation of completion

Production Operations (well conduit detail design and maintenance of well)Selection of componentsAcceptance of constructed assetOperate wellMaintain availability of well


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Completion categories based on the reservoir -wellbore interface

UNCEMENTEDLINER COMPLETION

OPENHOLECOMPLETION

PERFORATEDCOMPLETION

Sump

Casing

Cement

Caprock

Casingshoe

Openholeinterval

Rubble orgravel

Damagedzone

Perforations

Productiveformation

Slottedliner

Linerhanger

Cement

Productioncasing

Dr No TCM 6198

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Completion functional requirements

Provide optimum flowing conditions

Protect casing

Downhole emergency isolation

Permit downhole chemical injection

Permit downhole measurement

Isolate producing zones


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Bowl type tubing head

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Permanent Packer

Simple slip and packer design

Capable of withstanding high tensile forces and differential pressures

Relatively large through bore

Indicated when:Differential pressure across packer exceeds

5000 psi

Temperature exceeds 225 deg F

H2S is present

Infrequent workovers are expected


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Permanent Packer Characteristics

Top and bottom slips

Packer element (solid / complex)

Anti-extrusion rings for element

Ratch-latch mechanism to hold set

Milling required to recover

Designed for milling – lock rings etc

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Packer Setting OptionsMechanical

Rotation

Compression

Tension

HydraulicPressure 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

ElectricalMechanical setting mechanism using wireline setting tool


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Hydraulically Set Packers

Packer set using internal pressure (against tubing plug)

Pressure acts through port (A) on setting piston (B)

Shear pin (C) breaks

Setting sleeve drives bottom slips (D) up against cone (E)

Element (F) and upper slips energised then slips break and bite into casing

A

B

C

D

E

F

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Anchor 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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Polished Bore Receptacle (PBR)


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Advantage of having Seal Area above Packer

d

D D

Tubing

Max. Dia.

Seal Area

Casing

Packer

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Monobore Completion

9 5/8 ” Casing, 8.54” IDTRSCSSV Landing Nipple, 5.750” ID

7” Tubing, 5.963” ID

Flow CouplingSeal Stem, 6.023” ID

Liner PBR, 7.50” ID

Back Packer/Liner Hanger

7” Liner


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BlowoutKuwait


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Wireline retrievable safety valve

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Where in the string do we put the SCSSV?

Limitation of valve

Hydrate depth

Cratering depth

Collapse limitation of tubing

Scaling, wax, asphaltenes

KO point

Risk assessment

Subsidence

Earthquake


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SShheell ll EP LEP LeeaarrnniinnggCopyright 2001 SIEP B.V

Safety Valve Landing Nipple

Honed bore

Non welded shoulderto protect C/L while RIH

Honed bore

Control line

Lock profile

Dr. No. TCM7803


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Integral annulus safety valve

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Ways of providing a circulation route

Sliding side door

Side pocket mandrel

Coiled tubing

Tubing punch

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Reverse v forward circulation

Potentially corrosive well fluids kept off casing

Less pressure on surface equipment

Natural direction for the flow of the lighter hydrocarbons

Better sweep of hydrocarbons out of tubing

No damage to the casing due to jetting at the SSD

Hydrocarbons disposed of through normal flowline


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Permanent downhole gauge


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Xmas Trees

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Xmas Trees


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completions equipment