lesson 14 ub completions and cementing

8/12/2019 Lesson 14 UB Completions and Cementing

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Harold Vance Department of Petroleum Engineering

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.


WellControl

Valve


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The float valveis opened by thebit.



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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.



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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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lesson 14 ub completions and cementing

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