Historical Review of Dual and Multiple Completions

2004 Gas-Lift Workshop

Joe Dunn Clegg 1

Historical Review of Dual and Multiple Completions

By

Joe Dunn Clegg

2004 Gas-Lift Workshop

Joe Dunn Clegg 2

History Early Days (1859 to 1900) Spindletop & East Texas: RRC & Proration After WW II: Commingling & Dual Approval The 1950’s & 60’s: Hard times : Duals + The 1960’s: Computers and Offshore The Good Years: 1970 to 1984 Reality and Profitability Using the Best Technology

2004 Gas-Lift Workshop

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Multiple Zones

One zone: Only single possible Two or more zones: Development Plan

Needed--How best to produce reserves. Aggie approach: Singles & Plug-Back Well for each zone (expensive) Mix of singles, duals, multiples and

…..recompletions.

2004 Gas-Lift Workshop

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Multiple Zones Objective: to make more production with less initial

costs & less operating expenditures .…make more money

Applicable for only limited rates in certain environments….. 2”x 2” for < 1000 bpd x 1000 bpd

Avoid large mismatches in depth and pressure ….… depths < 10%; gradients < 10%

Review potential operating problems/costs Key often a long flowing life Dual artificial lift & workovers usually a problem

$

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Annulus-TubingDualforflowing wells

PackerLeakageTests?

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Flow CouplingCross-over

Packer

Tubing

Flow CouplingLanding Nipple

Blast JointPolished Nipple

Packer

No-Go Nipple

Perforations

Annulus-TubingDual withCross-Over

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Fad in the 1960’s

Work-Overs?

Secondary Recovery?

Unitization?

Little OperatingCost Data Available

CourtesyOtis

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Multiple“Tubingless”Completion

Exxon Special

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ConcentricDualCompletionTubing

UpperZone

LowerZones

OK forFlowingZonesi.e. Gas Wells

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DualParallelGas-Lift

Survivedthe testof time

11

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DualParallelGas-Liftw/concentrictbg. string

x Lift Gas

Lower ZoneProduction

o

Upper Zone ProductionNormal gas injection

12

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W/GasInjection

String&

SpecialCrossover

9 5/8”Csg

3 1/2” OD Tbg w/

1.9” OD Tbg

(Hydraulic)

(Permanent)

x

X XProposed DualParallelGas-Lift

13

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ThreeTubing StringDual Gas-Lift

Rigid<90’

(Hydraulic)

(Hydraulic)

(Permanent)

Outz & Osmus

Casing Size?

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Circulating SleeveUpper PumpSealLower Pump

Sucker-rod string

Upper Zone ProductionUpper Zone GasLower Zone Production

Liquid & Gas

Upper Zone

Lower Zone

Dual Rod Pumping: One Beam Unit

o

Schematic

2004 Gas-Lift Workshop

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Head to HeadDual BeamRod Pumps

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Triple Beam Rod Pumps

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Head to Head Dual For Triple Units Single Dual Head

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9 5/8” Csg

Lower Zone Power Fluid

All Production +Power Fluid

Upper ZonePower Fluid

Dual Hydraulic

Lower Zone

Upper Zone

CommingledProduction

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Dual Hydraulic Pumping: No vents

Production lower pump +all power fluid

Production upper zone

Power fluid for upper pump

Power fluid for lower pump

LP

UP

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oo

Upper ZonePump

Perforations

Packer

Lower Zone PumpLower Zone

HypotheticalDual ESPInstallation

UpperZone

Feasible but notPractical

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Multilateral Dual

Upper Zone Lateral

Lower Zone OpposedMultilateral

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MultipleCompletion:

CommingledZones OneTubing String

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My Conclusions Singles or Commingling Preferred Duals are profitable for selected cases Multiples (>2) are seldom justified over well life

except for flowing wells Most successful high rate (> 200 BPD) artificial

lift: ...Gas Lift Savings on drilling costs are often lost due to

higher operating costs, higher workover costs and lost reserves

Multiple completions increase stress

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Duals Singles Multiples

The Winner

Special Cases Flowing Wells