lesson 14 ub completions and cementing
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Lesson 14
General Considerations,
Completion Tools
PETE 689Underbalanced Drilling (UBD)
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The Reason for UB Drilling
Determines the Completion Type
Faster Rate of Penetration.
Lost Circulation.Differential Pressure Sticking.
Formation Evaluation.
Prevention of Formation Damage.
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UB Completion Types
Open HoleLiners
Cased Hole
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Advantages of UB Open
Hole Completion
SimpleLow Cost
Low Maintenance
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Disadvantagesof UB Open
Hole Completion
Difficult Well Control
Borehole Stability
Formation Specific
Entire Formation ExposedNo Zonal Isolation
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Open Hole Completion
General Considerations
Intermediate Casing Point
Stripping or snubbing head
Tripping In and Out
Drill StringTubing
Well Head Installation
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Isolating BHP From Surfacein Open-Hole Completions
While tripping.Running completion tools.
Installing tubing head and tree.
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Isolation Valve
Temporary Plug
Floating Mud Cap
Strip and SnubKill the well with mud
Isolating BHP
From Surface
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Isolation Valve for
Completion / Drilling
HalliburtonPetrolane/Weatherford
Techcorp (Canada)
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Well Control ValveHALLIBURTON
Valve goes at about3,000
Deeper is not necessary.
Runs on a liner that ties
into intermediate casing.
Hanger Backoffth
reads
WellControl
Valve
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Valve closes against
upward pressure
Trip without stripping
Balance pressure toopen valve.
Well Control ValveHALLIBURTON
WellControl
Valve
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The float valveis opened by thebit.
Well Control ValveHALLIBURTON
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The floatvalve is closedwhen the bit pulls thesleeve the bit.
The sleeve rides the drillpipe up and out of the
hole.
Well Control ValveHALLIBURTON
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Completion Isolation Valve(Petroline)
Safe underbalancedcompletion running.
Bi-directional suspensionbarrier.
Interventionless completioninstallation.
Tool deployment barrier. Remote opening from surface.
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Run outer and innerstring to depth and
set liner hanger
Liner Top Operational SequenceRelease liner hanger
running tools andpull back to inflate
ECP
Pull back into largerID section to
activate shifting tool
no-go mechanism
Run in to land andlock, shifting tool in
TB-CIV.
Pull ball closed
Shear shifting tooland pull back.
Pressure test and
circulate tocompletion fluid
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Run guns and spotunderbalance
cushion if required
Tool Deployment Operational Sequence
Fire guns Pull back to closeCIV & pressure tests
Retrieve guns &re-deploy as
required shiftingCIV open
Pressure cycleCIV open
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Temporary Completion Plug
Activate/Release
with Tubing. Restriction at TD.
Through-Tubing
Bridge Plug.
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Completion Types
Open Hole
Various liners
Cased Hole
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Slotted Liner in UB
Completion - Considerations
Stripping and snubbing
Downhole lubricatorTemporary plug
Standard overshot on liner
Drill-in liner
Expandable liner
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Expandable Liners
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Petroline AlternativeBorehole Liner (ABL)
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ABL Advantages
Reduced well costs, low cost contingency. Larger bore production casing allows easier
access/larger completion accessories.
Can allow larger production conduits. Can eliminate sidetracks, therefore well on
line earlier.
In prolific reservoirs, large productionincreases possible due to larger payzonediameter.
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ABL Key Uses Isolation of problem zones:
Swelling Clay
Sloughing shales
Fluid loss zones
Under/over pressured zonesDifferential sticking
Additional contingency casing stringswithout loss of hole size.
Incomplete casing run - can be set belowshoe to isolate exposed formations.
An integral element of Slim hole welldesign.
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Reduces well 'telescoping'
Not limited by length/diameter.
Relatively simple, robust tools.
Permits fundamental changes in welldesign.
ABL Key Uses
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Running Tool
Accommodates theexpansion cone andtwo drift cones.
Bottom part containsshearing device towhich the expandabletop connector is
made-up.
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Expandable Top Connector
Interface between the
running tool and theABL string andcontains the locationsfor the shear pins.
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ABL Joints
Supplied in 40 ft lengths.
Also available in pup
joints of differentlengths.
All joints internallycoated with apolyurethane sealant
which allows circulation.
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Expandable Bottom
Connector
Interface betweenAnchor Shoe and ABLstring.
The Anchor Shoe ismade of aluminum and
is drillable in approx. 30minutes.
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ABL Deployment
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Set ConventionalCasing
Drill New Zone Overgauge(Under-Ream if Necessary)
Run in HoleEST ABL
Cement ABL
Deployment Procedure
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Expanded ABLWhile Cement Soft
Expanded ABLLet Cement Harden
Drill Out HardCement
Continue New SectionWithout Loss of Hole Size
Deployment Procedure
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ABL as a Completion Liner
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Expandable Completion Liner
Isolates annulus from pay zone.
Allows slimming down of wellby one casing size.
Improves mud cake removal.
Improved PLT interpretation.
Maximizes inflow area.
Stabilizes the formation.
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Expandable Sand Screen
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Conventional vs. ESS
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Completion Types
Open HoleVarious liners
Cased Hole
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Cased Hole-UB Completion
Liner
Use same technique
Full String
Strip/SnubSurge/Swab Potential
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Two-Stage Techniquein UB Completion
Conventional or UBD Intermediate
Drill out With CTU
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Inflate ECP and cement liner intomain bore casing.
Clean out liner.
Perform any remedial treatments ifnecessary.
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Coiled-Tubing Unit
UB Completion
Open HoleSlotted Liner
Conventional Liner or Full String
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End
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(Chapter 8.4)
Cementing
C ti UB
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Cementing UBis it Possible?
UB Cementing
Incompetent Cement
OB Cementing
Formation Damage
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Annular Flow Through Cement
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Formation DamageMechanism in Cementing
Slurry Damage
Filtrate Damage
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Formation DamageFrom Cement
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Minimize Damage
Before cementing, rememberwhy the well was drilled
underbalanced.
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Loading the Hole
Casing Run Dry
Straight
Deviation requires lubrication.
Stable Formation
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Advantages of Loadingthe Hole
Clean the Hole
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Pack-Off Due to
Sloughing
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Advantages of Loading
the Hole
Clean the HolePrevent Pack-off
Ensure Float Equipment is Open
Remember: gas compresses
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Temperature Effects
Cool Steel Contracts
Liners
Minimum Two Circulations
Set Down Weight
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Preventing FormationDamage in Cementing
Low API FL
Know the Slurry Rheology
Know Frac and Pore Pressures
Model HydraulicsNon-damaging Pre-flush
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Snubbing and Stripping
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SNUBBING - Pipe Light
Where an external force isneeded to push pipe into thehole.
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STRIPPING - Pipe Heavy
Condition. Where weightof pipe exceeds well borepressure.
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STRIPPING OPERATIONS Normal Stack Configurations can
be used.
Recommended not to exceed 50%of the rated working pressure.
Pay attention to Volumetrics
Stripping - maintain constant BHP
Bleed Mud volume equal to Steelvolume going in.
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Maintaining SealElement Life
Pass tool joints slowly.
Lubricate Element.
Reduce closing pressure to
minimum.
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SNUBBING
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Rig up for Phase II
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Calculations
The Depth of the Neutral Point.
The Critical Buckling Load of
the Work String for Supportconditions of the Snubbing Unit.
The jack system settings.
Maximum Jack Speed.
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Forces on Snubbing String
The Pressure Area Force ActingUpward.
Gravity working downward.
Frictional Forces.
The Snubbing Unit Forces.
Force of any Obstructions in well.
Downward Forces = Upward Forces
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Snub Force + String Weight
=
(Pressure x Area) + Friction
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Upward force resulting from thewellhead pressure against the pipe:
Remember tool joints!
Fp-a= (* OD2
* WHP) / 4
Where Fp-a pressure area force, lbs
OD diameter in which seal is made, inches.
WHP wellhead pressure, psi.
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Max Snub Force = Pressure Area Force+ Friction
Fmax snub= Fp-a+ Ffriction
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Transition from pipelight to pipe heavy.
Balance Point
Bouyed String Weigh = Pressure Area Force
WT = Fp-a
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Bouyed Pipe Weight
WT = L*{w - [(OD2* MWwell)/24.5]}
Where
WT effective (bouyed) string weight, lbs
w pipe weight per foot in air, lbs/foot
L pipe length in the well, feetMWwell fluid density in the well, ppg
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Pressure Area Force = Bouyed Weight
Balance Point
LB-P= {[(*OD2*WHP)/4] / [w(OD2*MWwell)/ 24.5]}
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Calculate increased
weight due to filling pipe:
WT = [(L*ID2
* MWstring)/24.5]Where
WT change in string weight, lbs
ID pipe inside diameter, inchesMWstring fluid density inside the work string, ppg
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Watch out for density variations
inside and outside the pipe:
WT = L {w + [(ID2* MWstring)/24.5].
..[(OD2*MWwell)/ 24.5)]}
Where
WT total weight of the string considering bouyancy and
fill inside the pipe, lbs (all other variables are the
same as above)
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Next Step
Snubbing force known.
NOW determine whether or notthe string to be used will
buckle or not.
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Cross-Section of the
Snubbing String
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Column Stability and
Local Buckling
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1. Column Slenderness Ratio
2. Radius of Gyration
3. Effective Slenderness Ratio
Buckling Determination
Cc = * (2*E) / y
r = I / Asc
SR = (K*L) / ror
SR = QRT(R/t)*[4.8 +(R/225)*t]
End Conditions
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End ConditionsDetermine K Values
Buckling Load
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Buckling Load(SR
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In This Situation, The BucklingLoad Can be Increased By:
Increasing the work string size(OD).
Increasing work string wallthickness.
Increasing work string yield stress.
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In This Situation, The BucklingLoad Can be Increased By:
Reducing the unsupported length. Increasing the work string size.
Increasing the work string wall
thickness.
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