Historical Review of Dual and Multiple Completions
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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
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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.
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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
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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
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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
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