Presentación Metodos Mecánicos Control Arena Junio 2-06

8/11/2019 Presentacin Metodos Mecnicos Control Arena Junio 2-06

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Sand ControlFluid System and Down Hole Tools

June 2 nd , 2006Bogot, Colombia

Presenter: Sandra Garcia- Luis Velandia


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What are the consequences ofsand production?

Wellbore fill Equipment problems due to

sand fill Sand erosion of downhole

equipment Sand accumulation on surface Erosion of surface equipment Production Loss

Casing / Liner Collapse Sand Disposal

Environmental Concerns

Facility downtime


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3

What causes sand production?

Totally or weakly unconsolidated formations Argillaceous (containing clay) cementing materials Interaction of inter-granular friction and in situ

stresses Capillary forces Viscosity of the fluids in place

Improper well completionAcid stimulation / Completion fluids / Cement

Changing stresses in the near wellbore area High Production Rates Depletion of the Reservoir Pressure Production of High Viscosity Fluids


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What causes sand production?

Water Production Dissolves the cementing materials holding the sand

grains togetherinjection waterwater not from the immediate vicinity

Increased drag forces due to increasing total fluidrates

Increased drag forces due to two phase fluid flow Disturb the cohesive forces holding the grains

together Disturb the capillary forces holding the grains

together


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What can be done aboutsand production?

Production Restriction or Lower FlowVelocity

Choke back productionRe-perforate, etc.

Mechanical Methods Downhole Filter Gravel Pack Screen in Open hole - Expandable

Horizontal Gravel Pack FracPack

Chemical consolidation of the formation


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10 September 2014

Design


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Information required for designing asand control completion

Mineralogy and Water-Sensitivity of theFormation

Formation Sizing Sieve Analysis Particle Size Analysis

Gravel Sizing Gravel Pack vs. FracPac

Slot Sizing Gravel Pack vs. FracPac Slotted Liners Screen only Prepack Screens

etc.


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Completion method based on the formationinformation Clay Instability Rating (CIR) Acid Soluble Clays Formation Heterogeneity Formation Height Deviation

Reservoir Drive Type (water, gas, compac t ion ,etc.)

BHT BHP


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Swelling or migrating clay content Completion fluid selection and compatibility Sieve Analysis Particle Size Analysis


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Sizing the Gravel

Formation Sand Sample is run through a series of

sieves Amount remaining on each sieve

is plotted as a function ofcumulative weight % versusgrain diameter


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Sieve Analysis Plot

Various pointsare determined

D50 , D 10 , D 40 ,D90

These points canthen be used todetermine thegravel sized

needed to retaina formationsand .

100

90

80

70

60

50

40

30

20

10

0

VeryCoarse Coarse Medium Fine

VeryFine

Silt andFiner

U.S. Sieve No.

Sieve Opening mm

3250040000000000

.03040608.1.2.4.6.8.0.0

muav

P

c

a


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Gravel Sizing

Gravel Sizing - Gravel Pack Coberly Tausch & Corley Saucier 5-6 x D 50

Screen Only Completions Coberly Sparlin - D 10

FracPack 7-10 x D 50 One size larger than Sauciers Criteria


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Sizing the Screen Opening Gravel Pack

The screen opening is typically between 50-70% of the smallest gravel diameter

For 20/40 mesh sand the smallest gravel is the 40mesh which has a D 50 of 0.0165 0.0165 x 70% = 0.01155 or 0.012 opening (12

gauge) Screen Only

Screen Opening is approximately equal to theD10

Slotted Liner Slotted Liner Opening is approximately equal

to the D 10

Prepack Screen


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10 September 2014

Recent Gravel Pack Techniques

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Slurry Pack - (1970s - 1990s) Can be used for cased and perforated or openhole completions

Typically used for vertical wells with shorter

intervals The carrier fluid is viscosifed

Originally viscous oilViscosified Water (80 lb m /1000 gallons HEC, 36-48lb m /1000 Xanthan, etc.)

Sand concentrations can range from 3 to 15ppg

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Staged Acid - Prepack followed byAnnular Water Pack (1980s - ) Typically used on cased and perforated

completions

Staged Acid Prepack used to packperforationsCarrier Fluid is viscosified (typically 60 lb m /1000gal HEC)Sand Concentration is typically 3-4 ppg

Annular Pack (typically water pack) used tofill screen-casing annulus

Carrier Fluid is water or slightly viscosifed waterSand concentration is typically 0.5 - 2 ppg

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Water Pack Only - typically used for openhole completions Water or slightly viscosified water Higher rates required

Lower sand concentrations required Very good annular packing technique

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High Rate Water Pack Water or slightly viscosified water Higher rates required to fill perforations and

create numerous mini-fracs into the formation inhigh permeability wells

Typically 5-10 bpm or 1 bpm per 10 ft of perforations Sand concentrations

3-4 ppg Additional Surface Equipment is required

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Ex-tension PacSM

Service Liquid Sand SM SC 2OOP TM SandWedge TM

Xtra_nalysis.xls SoftwareTip screenouttechniqueSand placement to

200-250-lbs/ft ofperforationsSkin values betweenHRWP and FracPac

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Ex-tension Pac SM Design

Candidates: Typical HRWP Area where fines are problematic

Pump at rates up to 15 bpm Use slick water (10 - 20 lb m gel /1000 gallons) Proppant concentrations up to 4 ppg Use Step-Rate test, Mini-frac, and Pad

equation to determine pad size.

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Recent Gravel Pack Techniques Horizontal Gravel Packing

Pump Rate and Fluid Velocity2-4 BPM(1-3 ft/sec)

Alpha and Beta Wave Progression Through Pack

Sand Concentration0.5 - 2 ppg

Placement Procedure and Tool Configurations Liner / Tailpipe Ratio

> 0.80 ratio Screen / Casing Clearance Screen / Open Hole Clearance Perforation Phasing


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10 September 2014

Ex-tension Pac

Gravel Pack Job, SqueezePosition

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Design:Correlation Well A:

* Sand Placement Increasing to at least 200-250 lb/ft.Placing as much sand bas possible behind pipe is critical togood well production. Actual packing factor in well A(sand in place) was 5600 lb/ft.

* System fluid - Using SandWedge allowed the sand size to beincreased from 20/40 to 16/20 for further conductivityenhancement.

* Down hole tools Using MPA and gravel pack assy. testedaccording to pressure requirements (7000 psi) permit performpickling, injection and reverse operations required.

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Design:

Well B:* Sand Placement Increasing to at least 200-250 lb/ft.

Placing not too much sand as possible behind pipe in order toprevent an early high water production (6224, 6230, 6240).

* System fluid - Using SandWedge allowed the sand size to beincreased from 20/40 to 16/20 for further conductivityenhancement.

* Down hole tools Using MPA and gravel pack assy. testedaccording to pressure requirements (7000 psi) permit performpickling, injection and reverse operations required.

* Proppant Size - 16-20 Using SandWedge / Slot GaugeScreen Size 0.012

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Log Well B.

Design:Log Well A.

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Design:Sieve Analysis

D50 = .0174

0

10

20

30

40

50

60

70

80

90

100

0.0010.010.1Size (inches)

P e r c e n t

U. S. MESH10 10060403020 325140 200

SIZE

2500 305010015025050075010001500

AveragesMedian: .0174Mean: 0.022Mode: 0.0199

Proj. No. Careto-1Sample No.

Uniformity Coefficient. D40/D90 = 2.7667

D10 = 0.0460D40 = 0.0209 D50 = 0.0174 D90 = 0.0076

%Fines = 0.0

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Running Sump Packer & BHA Assy

Permanent Packer RIH BHA:

- Seal Assy for permanent packer.- Screen 0.012 slot gauge AWWW, 4NU - Blank pipe 4NU - Shear Joint- Ex-tension Pack Assy

Landing nipple and Test Tool. Running tubing (test pressure 7000 psi). Spacing out tubing.

Final Test. Pulling Test Tool w/ slickline. Rig-up surface lines and set PRVs.

AWD @ 6222 top

VTA @ 6147 top

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Setting VTA Packer / Expend ball

Set Packer and Expelling the Ball

4/14/200617:40 17:50 18:00 18:10 18:20

4/14/200618:30

Time

0

500

1000

1500

2000

2500

3000

3500

4000 Backside Pressure (psi) Treating Pressure (psi)321

Local Event Log

1

2

3

IntersectionSet Packer

Annulus Test

Expelling the ball

BP-28.83

1034

-25.75

TP2076

-20.04

3609

Customer: MONTECZ S.A. Job Date: 14-Apr-2006 Sales Order #: 43215001Well Description: CARETO 1 UWI:

H A L L IB U R T O NINSITE for Stimulation v2.4.0p1

16-Apr-06 13:08

VTA @ 6147 top

AWD @ 6222 top

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VTA @ 6147 top

AWD @ 6222 top

Assuring MPA PositionsMulti Positional Test

4/14/200618:35 18:40 18:45 18:50 18:55 19:00 4/14/200619:05Time

0

250

500

750

1000

1250A

0

1

2

3

4

5BBackside Pressure (psi) Treating Pressure (psi) Slurry Rate (bpm)A A B

76543

Local Event Log3

4

5

6

7

Squeeze Position

Circulation Position

Reverse Position Pump by Tubing

Reverse Position Pump by Annulus

Reverse Position Pump by Annulus

18:36:04

18:40:08

18:46:55

18:56:54

19:05:12



16-Apr-06 13:58

67200

4.33700 7

2500Reverse pump by

annulus

72090Reverse pu mp by tubing

220600Circulation

1.00.201000

1.00.50800Squeeze

Volume (bbl)Rate (bpm)Annulus Press (psi)Tubing Press (psi)MPA position

67200

4.33700 7

2500Reverse pump by

annulus

72090Reverse pu mp by tubing

220600Circulation

1.00.201000

1.00.50800Squeeze

Volume (bbl)Rate (bpm)Annulus Press (psi)Tubing Press (psi)MPA position

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VTA @ 6147 top

AWD @ 6222 top

Pickline

4/14/200619:10 19:20 19:30 19:40 19:50 20:00 20:10 20:20

4/14/200620:30

Time

0

20

40

60

80

100

A

0

3

6

9

12

15

B

0

10

20

30

40

50

60

70

CBackside Pressure (psi) Treating Pressure (psi)Slurry Rate (bpm) Stage Slurry Vol (bbl)

A AB C

987

Local Event Log

7

8

9

IntersectionAcid

Displacement

Reverse

SSV14.02

37.25

61.11



16-Apr-06 14:04

Pickling Acid

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Step Rate Test

Step Rate Test

4/14/200621:50 22:00 22:10

4/14/200622:20

Time

0

1000

2000

3000

4000

5000

A

0

5

10

15

20

25

30B

0

2000

4000

6000

8000

10000E

0

20

40

60

80

100

120

140G

Treating Pressure (psi) Slurry Rate (bpm)Backside Pressure (psi) Stage Slurry Vol (bbl)

A BE G

321

Local Event Log1

2

3

Load Well (Brine + Clasta FS)

Fluid Efficiency Test

Shut-In for FET Analysis



16-Apr-06 18:46

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Ex-Tension Pac TreatmentJob Summary

4/15/200602:46 02:48 02:50 02:52 02:54 02:56

4/15/200602:58

Time

0

2000

4000

6000

8000A

0

2

4

6

8

10

12

14

16

18B

0

2

4

6C

0

2000

4000

6000

8000

10000

12000

14000

16000

18000

20000E

Treating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)Bottomhole Proppant Conc (lb/gal)Backside Pressure (psi)

ABCCE



16-Apr-06 20:56

MaxTreatingPressure

AvgTreatingPressure

MaxSlurryRate

AvgSlurryRate

SlurryVolume

ProppantMass

Pumped

AvgProppant

Conc

Stage Number

psi psi bp m bpm bbl 100*lb lb/galPad 3952 3227 15.5 14.9 83 0 0

Proppant Laden Fluid 3143 3118 15 14.7 37 8.5 0.55

Proppant Laden Fluid 3096 3057 15 14.9 26 13.7 1.27

Proppant Laden Fluid 3771 3428 14.9 14.8 33 27.7 2.01

Proppant Laden Fluid 3910 3850 14.6 14.6 7 7.1 2.42

Screen Out 6000 -- -- -- -- -- --

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Reversing

4/15/200603:10 03:15 03:20

4/15/200603:25

Time

0

100

200

300

400

500

600

700

800

900A

0

1

2

3

4

5

6

7B

0

20

40

60

80

100

120D

Backside Pressure (psi) Annulus Rate (bpm)Returns Total (bbl)

A BD



16-Apr-06 21:02

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Re-stress Test

Re-Stress

4/15/200603:35 03:40 03:45 03:50 03:55

4/15/200604:00

Time

0

1000

2000

3000

4000

5000A

0

1

2

3

4

5

6

7B

0

10

20

30

40

50

60D

Treating Pressure (psi) Backside Pressure (psi)Tubing Rate (bpm) Tubing Total (bbl)

A AB D

21

Local Event Log

1

2

IntersectionFilling Tubing (Brine + Surfac tant)

Re-Stress

TP603.6

4417



16-Apr-06 21:16

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Running Completion

RIH Completion:

- Seal Assy for VTA Packer (not additional packer).- No-Go Locator.- Tubing Joint 3 (spacing)- Landing Nipp le XN 2.635No -Go (in order to test the

string and set memories gauges).- Tubing Joint 3 (spacing) - Sliding Side Door X 2.750 (inside will set a Jet

pump).- Tubing to surface.

RIH jet pump and start the well test.

VTA @ 6147 top

AWD @ 6222 top

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Conclusions:

The objective of sand control was achieved, by putting Carbolite 16/20into formation (effective Sand Control technique).

C7 formation receives a total sand in formation of 262.5* lb/ft inaccording to the target.

C7 formation in Careto 01 has a ISIP gradient of 0.662psi/ft and Formation Stress Gradient of 0.568 psi / ft.

Using linear gel during PAD in most of the sand control operation willminimize the fluid friction in the tubing, the turbulence effect and theproppant transport into the formation in the sand laden stages.

According to pumped schedule, returned sand and re-stress test, thequantity of proppant into formation is good for this Sand Pack service.

According to pressure behavior and bottom hole proppantconcentration the small fracture generated in formation reached a tipscreen out condition.

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Historical Cases Colombia

Halliburton 2002

Production Rate Trend Sand Controled Wells 2003-2004-2005

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

20-Mar-03 28-Jun-03 6-Oct-03 14-Jan-04 23-Apr-04 1-Aug-04 9-Nov-04 17-Feb-05 28-May-05 5-Sep-05

B F P D

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Historical Cases Colombia

Halliburton 2002

Production Tendency Well A

0

1000

2000

3000

4000

5000

6000

7000

8000

9000

18-Jan-06 23-Jan-06 28-Jan-06 2-Feb-06 7-Feb-06 12-Feb-06 17-Feb-06Date

B B L

0

150

300

450

600

750

900

1050

1200

1350

B P D

Vt (BBL) Vw (BBL) Vo (BBL) Qt (BPD) Qw (BPD) Qo (BPD)


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10 September 2014

PoroFlex

Exp and ab le ScreenCom plet ion Sys tems

Tech no log y Overview

Halliburton 2002

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Why Expandable Screens? Borehole collapse damages completions

Eliminate or reduce borehole/screen annulus

Minimize plugging of non-uniform sands

Minimize pressure drops in horizontal intervals

Eliminate gravel pack failures

Installation of intelligent sand control equipment

Well Completions

PoroFlex

Halliburton 2002

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Why Expandable Screens?Borehole collapse during production

PluggedScreen

Erosion Sites

Solution: Stabilize borehole by expanding screen OD to or near

borehole ID .

Creates hot-spots on both sides of non-producingarea that plug sooner or erode, causing screen

failure.

PoroFlex

Halliburton 2002

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Eliminate AnnulusMinimize Plugging Effects of Non-Uniform Sand

Solution: Eliminate annulus by expanding screen OD to or near

borehole ID .

Fines move down the borehole annulus to findthe nearest unplugged section and plug it;increasing velocity in the unplugged sectionsuntil erosion occurs.

PoroFlex

Halliburton 2002

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Why Expandable Screens?Minimize pressure drop along horizontal section Caused by undesirable well screen OD/ID ratios. Can lead to early water coning, breakthrough or

blocking of oil production, and early start of sandproduction.

Solution: Install sand screens with larger ID for same OD.

Larger ID facilitates workovers and/or zonalisolation techniques

Allows installation of intelligent well completion

PoroFlex

Halliburton 2002

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Why Expandable Screens?

Gravel pack failures can be eliminated Caused by undesirable borehole geometries

in combination with carrier fluids and nature

Solution: Where possible, eliminate gravel packing

from well completion operations

Well Completions

PoroFlex

Halliburton 2002

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Additional Benefits Formation support lowers skin values

Large ID for easier well intervention access

Isolation of trouble zones with expandable solids(cladding)

High resistance to erosion and plugging

Well Completions

PoroFlex

Halliburton 2002

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Key Features Perforated solid base pipe

Stronger Remedial options

Premium one-piece sintered laminate screen Filtration integrity under a variety of load conditions Integral joint expandable threaded connection

Allows rotation during run-in

Makes up faster on the rig floor Mechanical or hydraulic expansion options

Hydraulic expansion more reliable in extended reachhorizontal wellbores

PoroFlex

Halliburton 2002

49


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System Components

S imple con f igura tion Uncom pl ica ted equipm ent Reliable ins tal lat io n

Open hole

Spacer

Standardconnection

ExpansionConeLauncher

ExpandableSandScreen

Down-JetFloat Shoewith SealBore

Production casing

or liner

Expandableconnections

ScreenSuspensionTool

PoroFlex

Halliburton 2002

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Installation Issues Hole geometry

Sperry- Sun Slickbore service to maintain hole size

Getting screen to bottom and wellbore clean-up Baroid for fluids selection and filter cake treatment

Completion placement Acoustic or caliper logging for hole size verification

Restriction effects Formation deformability Expansion tool stress

PoroFlex

Halliburton 2002

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Premium Screen

316L screen material One-piece construction

Plain Dutch weave Each layer sintered 360 coverage

Micron rating unchanged post-expansion Dual drainage layers Perforated outer shroud for stiffness and reliable

installation

PoroFlex

Halliburton 2002

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Screen Construction

Base pipe

Lower drainagemesh layer

Filter mesh layer

Upper drainagemesh layer

Outer shroud

Top fo ur layers s in teredto fo rm a one-piece f i l ter

PoroFlex

Halliburton 2002

53


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Screen Construction

Well Completions

Top View

Oblique View

Warp wire

Weave wire

Micron ra t ing d eterm ined by diam eter of warp w ire

Expansionalong radial axis

(no pores seen) Plain Dutchweave

Warp w ires no t expanded Weave w ires no t y ie lded

MICRON RATING UNCHA NGED

PoroFlex

Halliburton 2002

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Screen Joint ConstructionReceive mill-rolled blank base pipePerforate

Apply ID coatingThread box x pinInstall screen jacketsWeld screen jackets to base pipeInsert desiccant and install thread protectors

PoroFlex

Halliburton 2002

55


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Operating StepsHanger

ExpandedRun

ExpanderExpanding

ScreenExpansionCompleteRun Liner

PoroFlex

Halliburton 2002

56


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Expansion Process Mechanical

Set weight down Hydraulic

Expansion cone deployed to upper mandrelsection Slips set to anchor expansion tool Mandrel hydraulically extended to expand screen

Slips released and pipe run in hole to meetexpansion cone

At end of expansion, nose lands in seal bore,cone sheared, and expansion tool retrieved

(Click to run animation)

PoroFlex

Halliburton 2002

58
http://localhost/var/www/apps/h021041.HALAMERICA/Local%20Settings/My%20Documents/PD&C%20Stuff/PoroFlex/Animations/100101exsRoughCutdivx.avihttp://localhost/var/www/apps/h021041.HALAMERICA/Local%20Settings/My%20Documents/PD&C%20Stuff/PoroFlex/Animations/100101exsRoughCutdivx.avi


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SpecificationsPoroFlex Screen 6.125 8.500

Run-in OD (125/250) 5.375/5.460 7.370/TBD Run-in ID 4.500 6.390 Expanded OD 6.125 8.500 Expanded ID 5.440 7.730 Screen rating 125 & 250 125Screen material 316L 316LService rating Std. & H 2S Std. & H 2S

Expansion Tool

Run-in & retrieval OD 5.000 7.000 Expanded OD 5.440 7.730 Operating pressure (approx.) 3,500 psi TBDExpansion method Mechanical or HydraulicStroke length 10 15

PoroFlex

Halliburton 2002

59


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Job Histories

Amerada Hess GoM March, 2002 7 29# cased hole

Max hole angle 53

Dual zone completion (top of zones 8,558 and11,440 MD)

Upper zone 1 jt screen + 1 ea 10 annular barrier

Lower zone 1 jt screen + seal bore/float shoe Expansion to maximum OD (6.125) System performed per plan and procedure No production data available at this time

PoroFlex

Halliburton 2002

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Job Histories Repsol Indonesia March, 2002

6.125 open hole side track completion Maximum hole angle 57

Dual zone (top of screen at 3,312 MD) out of 7 casing

Upper zone 1 jt screen + 1 ea 10 annular barriers Lower zone 1 jt screen + seal bore/float shoe

Repsol Indonesia April, 2002 6.125 open hole side track completion

Maximum hole angle 90 Top of zone at 6,200 MD 288 feet of screen expanded

PoroFlex

Halliburton 2002

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Future Work

Petrobras 6.125 open hole completion

S shaped well Maximum hole angle 90

Dual zone completion out of 9- 5/8 casing Possible deployment below expandable liner hanger

Upper zone 750 screen + 225 blank (annularbarriers at either end) Lower zone 750 screen + seal bore/float shoe

PoroFlex