multilateral installation

Vermilion Oil & Gas Australia

2010 Wandoo Drilling Project OverviewMarch, 2011

Rod Gibbons, Vermilion Senior Production Engineer

Mike Zimmerman, Halliburton Sperry Operations Manager

Surface Facilities

Wandoo A

Wandoo B

CALM Buoy

• 18 wells on production (gas lift)

• 1 gas injection well

• Produced water limit 24,600m3/day

• Gas compression 890e3m3/day

• Processing on Wandoo B with flowlines between A and B;

• 8” Production Line

• 3” Gas Lift Line

– Export Line to CALM Buoy

Reservoir Parameters

Shallow, unconsolidated reservoir at ~600m

TVDss (AHD)

Thin oil column (22m) with overlying gas cap

Original FWL 601.7 m TVDss (AHD)

Original GOC 579.6 m TVDss (AHD)

Oil Properties

19o API, in-situ viscosity 14cp, low GOR 17m3/m3

STOIIP ~200 mmbbl

Gas Cap ~9 Bcf

Associated Gas ~18 Bcf

Current production is ~9,000bbls/day

Initial reservoir pressure 898 psi (6194 kPa)

Current reservoir pressure 783 psi (5400 kPa)

A Platform

B Platform

Production History

Wandoo Production History

0

5,000

10,000

15,000

20,000

25,000

30,000

35,000

40,000

45,000

50,000

1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010

Oil

Ra

te (

bb

ls/d

ay

) 1997 Gravity Based Structure

Installed

Vermilion

gets

operatorship

2006 –

2007

Facility

Debottle-

necking

2008

Drilling

Campaign

Reservoir

Unit

Av. Perm

(mD)

A1 shaly sandstone 84

A2 sideritic sandstone 403

A3 glauconitic sandstone 1903

B1 7242

B2 mostly clean sandstones 5399

C 7117

Total Field -

Reservoir – Initial Conditions

7,772,000 7,773,000 7,774,000 7,775,000

7,772,000 7,773,000 7,774,000 7,775,000

550

560

570

580

590

600

610

540

550

560

570

580

590

600

610 0.00 0.25 0.50 0.75 1.00 mile

0.00 0.25 0.50 0.75 1.00 km

File: Pred_2010_Base_NFA.irf

User: rjefferies

Date: 20/05/2010

Scale: 1:26939

Z/Y: 50.00:1

Axis Units: m

1.00

Sw

1.00

So

Sg

1.00

Min Values:

Sw = 0.000

So = 0.000

Sg = 0.000

Base_NFA 2010

Ternary 1993-09-30 I layer: 3

A1 Sand

A2 Sand

A3 Sand

B & C Sands

7,772,000 7,773,000 7,774,000 7,775,000

7,772,000 7,773,000 7,774,000 7,775,000

550

560

570

580

590

600

610

540

550

560

570

580

590

600

610 0.00 0.25 0.50 0.75 1.00 mile

0.00 0.25 0.50 0.75 1.00 km


User: rjefferies

Date: 20/05/2010

Scale: 1:26939

Z/Y: 50.00:1

Axis Units: m

1.00

Sw

1.00

So

Sg

1.00

Min Values:

Sw = 0.000

So = 0.000

Sg = 0.000

Base_NFA 2010


A1 Sand

A2 Sand

A3 Sand

B & C Sands

A1 Sand

A2 Sand

A3 Sand

B & C Sands

GOC 601.7 mTVD

OWC 579.6mTVD

Reservoir – End of Field Life

WA5 WB12ST2WB13H WB1AWB5 WB6

7,772,000 7,773,000 7,774,000 7,775,000

7,772,000 7,773,000 7,774,000 7,775,000

550

560

570

580

590

600

610

540

550

560

570

580

590

600

610 0.00 0.25 0.50 0.75 1.00 mile

0.00 0.25 0.50 0.75 1.00 km


User: rjefferies

Date: 20/05/2010

Scale: 1:26939

Z/Y: 50.00:1

Axis Units: m

1.00

Sw

1.00

So

Sg

1.00

Min Values:

Sw = 0.000

So = 0.000

Sg = 0.000

Base_NFA 2010


A1 Sand

A2 Sand

A3 Sand

B & C Sands

WA5 WB12ST2WB13H WB1AWB5 WB6

7,772,000 7,773,000 7,774,000 7,775,000

7,772,000 7,773,000 7,774,000 7,775,000

550

560

570

580

590

600

610

540

550

560

570

580

590

600

610 0.00 0.25 0.50 0.75 1.00 mile

0.00 0.25 0.50 0.75 1.00 km


User: rjefferies

Date: 20/05/2010

Scale: 1:26939

Z/Y: 50.00:1

Axis Units: m

1.00

Sw

1.00

So

Sg

1.00

Min Values:

Sw = 0.000

So = 0.000

Sg = 0.000

Base_NFA 2010


A1 Sand

A2 Sand

A3 Sand

B & C Sands

With current well stock oil still remaining to be recovered in A3 and

B1 Sand

2008 Well Campaign

A Deck Extension on Wandoo

B was constructed to

accommodate additional wells

in the Wandoo Field

Impact of 2010 Drilling Campaign

Remaining Oil at 2029 Comparison

WA1

WA2

WA3

WA4

WA5

WA6

WA6H1

WA7WA8ST1

WA9

WB10ig

WB11

WB12ST2

WB13H

WB14H

WB14Pilot

WB1A

WB2A

WB3

WB4A WB5

WB6

WB7

WB8A

WB9

438,000 439,000 440,000 441,000 442,000 443,000

438,000 439,000 440,000 441,000 442,000 443,000

7,7

72

,00

07

,77

3,0

00

7,7

74

,00

07

,77

5,0

00

7,7

72

,00

07

,77

3,0

00

7,7

74

,00

07

,77

5,0

00

0.00 0.25 0.50 0.75 1.00 km


User: rjefferies

Date: 14/05/2010

Scale: 1:29738

Y/X: 1.00:1

Axis Units: m

0.0

0.7

1.3

2.0

2.7

3.4

4.0

4.7

5.4

6.0

6.7

Base_NFA 2010Oil Per Unit Area - Total (m) 2028-12-31 K layer: 46

WA1

WA2

WA3

WA4

WA5

WA6

WA6H1

WA7WA8ST1

WA9

WB10ig

WB11

WB12ST2

WB13H

WB14H

WB14Pilot

WB1A

WB2A

WB3

WB4A WB5

WB6

WB7

WB8A

WB9

439,000 440,000 441,000 442,000 443,000

439,000 440,000 441,000 442,000 443,000

7,7

72

,00

07

,77

3,0

00

7,7

74

,00

07

,77

5,0

00

7,7

72

,00

07

,77

3,0

00

7,7

74

,00

07

,77

5,0

00

0.00 0.25 0.50 0.75 1.00 km

File: Pred_A6B8B12Combined.irf

User: rjefferies

Date: 14/05/2010

Scale: 1:29870

Y/X: 1.00:1

Axis Units: m

0.0

0.7

1.3

2.0

2.7

3.4

4.0

4.7

5.4

6.0

6.7

A6B8B12Oil Per Unit Area - Total (m) 2029-12-31 K layer: 46

Base Case 2010 Flank Upside WellsB12

Lateral

A6

Lateral

B8

Lateral

Multi-Lateral Junctions

• Alternative methods of accessing reserves were

evaluated in 2009, including;

– Conventional horizontals from new conductors in a deck

extension,

– Abandoning wells and recovering well slots,

– Multilaterals,

– Through tubing drilling,

– Drilling iron - Jack-up, Platform based rig, Hydraulic

workover unit, coiled tubing drilling.

• The optimum balance of innovation and proven

technology was to use a conventional Jack-up drilling rig

and use multilateral technology.

Development Alternatives 2010 – Coiled Tubing

on Platform

• Removing the Mechanical Plug from well B12 with a coiled tubing unit removed this task off the drilling program critical path and allowed production testing before the well was sidetracked.

WA1

WA2

WA3

WA4

WA5

WA6

WA6H1

WA7WA8ST1

WA9

WB10ig

WB11

WB12ST2

WB13H

WB14H

WB14Pilot

WB1A

WB2A

WB3

WB4A WB5

WB6

WB7

WB8A

WB9

438,000 439,000 440,000 441,000 442,000 443,000

438,000 439,000 440,000 441,000 442,000 443,000

7,7

72

,00

07

,77

3,0

00

7,7

74

,00

07

,77

5,0

00

7,7

72

,00

07

,77

3,0

00

7,7

74

,00

07

,77

5,0

00

0.00 0.25 0.50 0.75 1.00 km


User: rjefferies

Date: 14/05/2010

Scale: 1:29738

Y/X: 1.00:1

Axis Units: m

0.0

0.7

1.3

2.0

2.7

3.4

4.0

4.7

5.4

6.0

6.7


Development Alternatives 2010

Adding laterals onto existing

wellbores eliminated the need

for additional well slots and

space on the surface facilities

Development Alternatives 2010

Adding laterals onto existing

wellbores eliminated the need

for recompletions in existing

wells

WA1

WA2

WA3

WA4

WA5

WA6

WA6H1

WA7WA8ST1

WA9

WB10ig

WB11

WB12ST2

WB13H

WB14H

WB14Pilot

WB1A

WB2A

WB3

WB4A WB5

WB6

WB7

WB8A

WB9

438,000 439,000 440,000 441,000 442,000 443,000

438,000 439,000 440,000 441,000 442,000 443,000

7,7

72

,00

07

,77

3,0

00

7,7

74

,00

07

,77

5,0

00

7,7

72

,00

07

,77

3,0

00

7,7

74

,00

07

,77

5,0

00

0.00 0.25 0.50 0.75 1.00 km


User: rjefferies

Date: 14/05/2010

Scale: 1:29738

Y/X: 1.00:1

Axis Units: m

0.0

0.7

1.3

2.0

2.7

3.4

4.0

4.7

5.4

6.0

6.7


Proposed 2010 Program

A3/B Sand Oil Thickness End 2009

A6 Lateral

B8 Lateral

B12 Lateral

A3/B Sand Oil Thickness End 2009

A6 Lateral

B8 Lateral

B12 Lateral

Drilling & Completion Installation

ERD Well Designs

Wandoo Sidetracks

Conventional

Extended Reach ( >2 : 1 stepout down to 2000-2500m TVD)

Extended Reach = very ER (>3 : 1 stepout)

Extended Reach = extreme ER

16 16161616

Drag Risk - Sandscreens

A6 with 5.5” & 6.875” Screens 9” OH

from 960mContingency w/400m CH Rollers on top

5.5” Screens

9 5/8” x 7” VCH

Screen Hanger

Lateral Flow Path

Mainbore Flow Path

9 5/8” x 5-1/2” Production

Packer & Upper Completion

Multilateral Installation

Lateral Flow

Mainbore Flow

TRFC “Intelligent” Completion

Multilateral “Evolution”

ReFlexRite Generation 3 - Halliburton ReFlexRite components are from existing ML designs.

1. FlexRite for junction

Subsea TAML level 5: Quick Installation, Reliable, Simple Operations

Used extensively – over 120 installed and 9 junctions installed prior to Wandoo.

2. MillRite for milling window

Milling machine cuts straight window, whipstock installed to open window and allow drilling assemblies to exit and re-enter.

Versatile – Can create level 2 through level 5 junctions.

Used extensively – over 60 installations – including 1 in Australia – to date.

3. Packers from existing product lines

4500 system - Large Bore Anchor packer is for re-entering existing wells,anchor point for whipstock and completion.

Proven ratch-latch design for anchor mechanism on all subsequent tool runs.

Redesigned running tool, enables orientation via MWD.

Multilateral Type

ReFlexRite Generation 3 – Halliburton

Level 5 Junction

• Non cemented, mechanical sealed junction – 1,200psi

Sealing Mechanism

Completion Deflector

• Completion Defector stinger seals into Anchor Packer tail pipe PBR

FlexRite Junction

• Junction stinger OD seals into the inside of Completion Deflector which has a stack of

several concentric polymer “T-seals” on the ID

• “T-seals” are protected when running the Completion Deflector by the HMRT (running tool)

Minimal Steps for Installation

• Mechanical seal - non cemented

• No open hole sting-in

• Two trip window opening system

• One trip milling casing – precision milling machine

• One trip window opening with whipstock milling assembly

Multilateral Junction Components

Anchor

Packer*

Ratch

Latch

Casing Milling

Machine*Whipstock*

Completion

Deflector*

ICI

Junction*

ICI Stinger

w/ Shearable

Shroud

*Includes

MWD in

BHA

Lower Screen

Mainbore Completion

9 5/8” Shoe

13 3/8”

Shoe

Production packer milled and Upper completion retrieved.

2 runs on B-12, 1 run on B-8 and A-6

Well is clean and drifted.

Casing evaluation tool runs have been performed in the 9 5/8”casing,

preferably to the expected junction location area.

Casing tallies were all accurate.

Suitable packer setting area has been identified.

Suitable casing exit joint has been identified, to enable drilling of lateral

branch.

Well Prep for Casing Exit Option - Above 9 5/8” Shoe


KOP Depth Considerations

Well Bore Inclination: > 65 Deg

• Halliburton has Empirically Tested to as low as 65o inclination

Dog Leg Severity: < 4 Deg/30m

• Difficulty of Milling Window with DLS > 4°/30m

• Difficulty of retrieving ML Whipstock with DLS > 6°/30m

No Casing Coupling adjacent section to be Milled

Satisfactory Cement Sheath for 9-5/8”csg / 12-1/4” hole

High Side Kick Off: 0 to 20deg – ML junction mainbore stinger needs gravity to separate

BOD for Junction Setting Depth

B8 B12 A6

KOP MD 775 m 720 m 684 m

KOP ss TVD 579 m 580 m 570 m

Inclination deg 84o 77o 68o

DLS o/30m 1o 2.56o 2.1o

Top Muderong Shale (m MD) 616 m 600 m 587 m

Top A1 Sand (m MD) 770 m 750 m 671 m

TMD / TVD ss 1,880m / 587m 1,965m / 584m 2,124m / 583m

23Optional 8 ½” Stabilizer

9 5/8” ML Anchor Packer & Tailpipe Assy

Ratch Latch Profile ML Packer Running Tool & MWD

Install ML Anchor Packer Assembly

RIH with 9 5/8” ML Anchor Packer consisting of tailpipe and upside down flapper valve.

• Running tool BHA consists of UDFV shifting tool, MWD, anchor setting tool and an

8-1/2” Stabilizer.

Tag liner PBR, pull back, space-out and orient ML packer using real time MWD signals.

• Critical that packer is set on depth relative to existing 9 5/8” casing couplings

(casing exit must be milled in a full joint)

Drop ball, pressure up to shift isolation sleeve, expose hydraulic setting ports. Pressure

up to set packer.

With 3,500 psi on the workstring, apply up to 40 tons down weight on the packer. Work

string between neutral and up to 40 tons down weight.

Pressure up further to shear out ball seat and re-establish circulation and verify

orientation.

Apply up to 10,000 ft-lbs of RH torque to verify packer is set.

Apply overpull of ~40 tons to release running tool.

Circulating Fluid By-Pass

Note : Flow path not past packer element

MWD

Flapper Valve


• Run Summary

– Set MLP Packer

• B-12: MWD too long

– Losses enabled faster MWD flow rate and trip speed

– Installation All OK

• B-8: Spun Packer at 120 RPM

– Installation All OK

• A-6: Installation All OK


Install 9 5/8” Milling Machine

M/U milling machine and BHA.

RIH with ReFlexRite milling machine and land in Ratch Latch profile in MLP anchor

packer.

Confirm orientation using MWD signals, perform overpull test.

Circulate to release Hydraulic Locking Tool (HLT).

Mill 1st pass window.

• Cuttings captured in integral junk basket

• Optional magnet sub can be run below assembly for additional steel capture

Pull back and lock HLT into MillRite throat.

Release MillRite by straight overpull. POOH.

Note: Effective debris management to ensure removal of steel debris generated during milled

operations is of paramount importance to ensure junction construction is successful in ML

installations.

Mill Ramp Ratch Latch & Integral Junk Basket

Mill

(end position)

MillRite Guide & Throat


Flapper

Valve

• Run Summary

– Mill 1st Pass

• B-12: Did not set enough weight to correctly latch in

– Increased RL shear pins and set down weight

• B-8: Less Cuttings Returned during Milling

– Increased Flow Rate and Pressure limit, adjusted for varied

mud weight

• A-6: Mill Deconstructed due to junk in hole


Contingent: Perform Clean Up Run

Perform clean up run with magnets, brush and junk baskets.

Brush inside packer head to remove milling debris from latch

Dependent on cuttings recovery with Milling Machine.

Not Conducted on B-12 – Sufficient cuttings return

Brush

1st pass milled window


Install ReFlexRite Drilling Whipstock

Ratch Latch

ReFlexRite Drilling Whipstock

8 ½” Lead & Watermelon Milling Assembly

M/up whipstock BHA

• Include magnet assembly

M/up whipstock assembly to lead mill with shear bolt, RIH.

• Whipstock can also be installed on a Hydraulic Running Tool.

Orient whipstock packer muleshoe and engage ratch latch.

Perform overpull test to verify whipstock is latched.

Confirm whipstock orientation using MWD signals.

Record circulating pressure at known flow rate.

Prepare to shear milling assembly free.

Magnet

Filter


Ratch Latch

Open Up First Pass Milled Window To Full Gauge

Apply torque and set down weight to shear running bolt.

• 20 ton shear bolt

Pull mill free from window.

Open up 1st pass window to 8 1/2” full gauge, for lateral drilling

operations.

Mill 5.5-7m from first observation of milling torque (=1.5-3m formation).

Ream & drift window with mills.

Circulate clean and POOH.

MWD

ReFlexRite Drilling Whipstock

Filter

Magnet


• Run Summary – Second Pass

– B-12: Run #1

• Whipstock set as planned

• Shear bolt sheared as planned

• Milled window, 1.5 m centered on taper face, 3.5 m on RHS

– B-12: Run #2

• Stiffer Milling BHA

• Bolt sheared premature

• Opened window *slightly* to the left


• Run Summary – Second Pass

– B-8:

• Whipstock set as planned

• Bolt sheared as planned

• Milled window, dressed window repeatedly, good returns (14.2

kg)

– A-6:

• Set whipstock as planned

• Bolt sheared as planned

• Run Stiff Milling BHA


Drill the Lateral Branch To TD

2 Stage Drillout:

• Drill with PDM to ensure high build and correct landing

depths

• Aiming for 10-12°/30m for 1st section.

• i.e. “follow” whipstock angle of 2.9°/3m

• Drill with 8 ½” bit , 9” Underreamer and RSS assembly.

Displace or condition mud prior to coming out of hole.

POOH with drilling BHA.

Ratch LatchReFlexRite Drilling Whipstock Magnet


Drilling Assembly Run #1

8.5”

PDM

Drilling

BHA

8.500

8.5in Motor BHA

Description Vendor Serial # OD/ID Max OD

Connection

(Bottom/Top)

Gender

(Bot/Top)

(in) (in) (in)

5.750 0

2.250 4 1/2 REG Pin

7.000 4 1/2 REG Box

5.500 4 1/2 REG Box

6.750 4 1/2 REG Pin

2.810 5 1/2 FH Box

6.750 5 1/2 FH Pin

5.109 4 1/2 NC50 (4 1/2 IF) Box

6.750 4 1/2 NC50 (4 1/2 IF) Pin

2.813 4 1/2 NC50 (4 1/2 IF) Box

5.000 4 1/2 NC50 (4 1/2 IF) Pin

3.000 4 1/2 NC50 (4 1/2 IF) Box

6.500 4 1/2 NC50 (4 1/2 IF) Pin

2.750 4 1/2 NC50 (4 1/2 IF) Box

5.000 4 1/2 NC50 (4 1/2 IF) Pin

3.000 4 1/2 NC50 (4 1/2 IF) Box

4.855 4 1/2 NC50 (4 1/2 IF) Pin

4.276 4 1/2 NC50 (4 1/2 IF) Box

BHA Comments

Blade Length (m) Blade Mid-Pt to Bit (m)

0.357 0.838

Gamma Ray

Resistivity

Gamma Ray

D+I

Bend Angle (deg) Bend to Bit (m)

1.500 2.143

Mud Weight (g/cm3) 1.58Funnel Viscosity (s)

18.861

Mud Properties

B12*

PV (cP)

Type

YP (lbf/100ft2)

Distance to Bit (m)

Rig5" 19.50 DPS, Premium

Vermillion/14-L/Wandoo Hole Size (in)

3

4

12.402

Sensor

2

18.215

BHA Name

Stabilizer Summary

Bend Summary

6.500Hydra-Jar

6.625

Heavy Weight Drill Pipe

8 1/2 " Bit

10.677

Generic

Field Name

Well Name

1

6.500

5

6

7

8

6.750

HE

Rig

6.890

Schlumberger

6.500

9

8.375

Schlumberger

Rig

7.500

A700M7866GT (1.5 deg Bend) Schlumberger

SchlumbergerPeriscope 675

Telescope 675 NF

NMDC

Heavy Weight Drill Pipe

8.500

8.5” x 9”

RSS

Drilling

BHA

9.000

Description Vendor Serial # OD/ID Max OD

Connection

(Bottom/Top)

Gender

(Bot/Top)

(in) (in) (in)

5.750 0

2.250 4 1/2 REG Pin

6.750 4 1/2 REG Box

5.160 5 1/2 FH Box

6.750 5 1/2 FH Pin

2.810 5 1/2 FH Box

6.750 5 1/2 FH Pin

5.109 5 1/2 FH Box

6.750 5 1/2 FH Pin

2.250 4 1/2 NC50 (4 1/2 IF) Box

6.750 4 1/2 NC50 (4 1/2 IF) Pin

3.000 4 1/2 NC50 (4 1/2 IF) Box

6.750 4 1/2 NC50 (4 1/2 IF) Pin

2.875 4 1/2 NC50 (4 1/2 IF) Box

6.750 4 1/2 NC50 (4 1/2 IF) Pin

1.500 4 1/2 NC50 (4 1/2 IF) Box

5.000 4 1/2 NC50 (4 1/2 IF) Pin

3.000 4 1/2 NC50 (4 1/2 IF) Box

6.500 4 1/2 NC50 (4 1/2 IF) Pin

2.750 4 1/2 NC50 (4 1/2 IF) Box

5.000 4 1/2 NC50 (4 1/2 IF) Pin

3.000 4 1/2 NC50 (4 1/2 IF) Box

4.855 4 1/2 NC50 (4 1/2 IF) Pin

4.276 4 1/2 NC50 (4 1/2 IF) Box

BHA Comments

Blade Length (m) Blade Mid-Pt to Bit (m)

0.506 0.64

0.506 3.688 D+I

0.762 23.131 Gamma Ray

0.610 30.185 Resistivity

1.280 32.852 Gamma Ray

D+I

Density

Bend Angle (deg) Bend to Bit (m) Neutron

0.600 0.71

Mud Weight (g/cm3) 1.58Funnel Viscosity (s)

Mud Properties

PV (cP)

Type

YP (lbf/100ft2)

Distance to Bit (m)

A06, B12, B28.5in Xceed +

Anderreamer BHABHA Name

24.296

Hole Size (in)

17.166

8.250

6.500

16.520

2

10.708

Bend Summary

25.274

8.5 x 9 Anderreamer

8-1/2 x 9" Xceed BHA

1.097

8.982

SensorStabilizer Summary

3

4

Rig

Rig

8.250

5" 19.50 DPS, Premium

8-1/4" Stab

8

9

10

11

5

6

7

Generic

Field Name

Well Name

1

Vermillion/14-L/Wandoo

9.000

Heavy Weight Drill Pipe 6.500

HE

Schlumberger

Andergauge

6.500RigHeavy Weight Drill Pipe

Schlumberger

Schlumberger

Schlumberger

6.890

Schlumberger

6.750

12

8.375

6.625

Periscope 675

Telescope 675 NF

ADN-6 w/ 8 1/4" Stabilizer

Pony NMDC

7.500

Hydra-Jar

Schlumberger

8 1/2 " Bit 8.500

Xceed 675 8 3/8" Stabilizers

Drilling Assembly Run #2

Directional Drilling Assemblies

Kick Off Drilling Assembly

DLS: 6° - 7° /30m in the hole section from KOP to End of Build (EOB) (target depth)

Near upper range of the Rotary Steerable System (8° /30m), PDM used to drill the initial

section of lateral.

Review of Wandoo drilling history could not confirm RSS performance where DLS’s were

> 4° /30m

Measurement / Logging While Drilling

The initial hole section from KO to EOC drilled with PDM assembly including MWD/GR

and PWD

From EOC to TD a RSS assembly with MWD/GR, Resistivity, Neutron Density, PWD and

Caliper.

This hole section also included an under reamer to open hole to 9” OD in the Production

Interval

Geo-steered at ~0.5m below the A3 sand utilising the LWD readings

Retrieve ReFlexRite Drilling Whipstock

RIH with Whipstock Hydraulic Retrieval Tool (HRT)

• ID Contingency retrieval method: spear assembly

• OD Contingency retrieval method: washover assy & die collar

Wash down with HRT into whipstock bore, tag stop ring and

engage whipstock ID retrieval profile.

Pull whipstock free with ~18 – 30 tons, POOH.

Whipstock HRT BHA

Ratch LatchReFlexRite Drilling Whipstock Magnet

Filter


• Run Summary – Whipstock Recovery - HRT

– B-12 #1

• HRT worked as planned

• Ran with Jars and Bumper Sub

– B-12 #2


• Stabbed Whipstock back into MLP, damaged Whipstock

– B-8:


• Ran with Jars and Intensifier

– A-6:


• Ran with Jars


Install Completion Deflector & Tailpipe Assy

Assembly includes 6” seal unit with required spaceout tubing for landing

in MLP Anchor Packer intermediate completion assembly.

RIH, and enter ML anchor packer bore.

Orient and land completion deflector in Ratch Latch profile in MLP

anchor packer.

Set down weight to confirm landed, and circulate through MWD to

confirm correct orientation with weight set down on deflector.

Perform overpull test.

Release deflector running tool with flow rate (ΔP over nozzle). POOH.

MWD

Deflector Running Tool

ReFlexRite Completion Deflector

Deflector Seal Stack

Circulating Fluid By-Pass


• Run Summary – Completion Deflector

– B-12 Run #1:

• HMRT performed as planned

• HMRT release flow rate: 580 GPM/2330 PSI

• Likely Sheared USDFV

– B-12 Run #2:

• Recovered Deflector as planned

• Damage to HMRT dogs from pull free weight

– B-12 Run #3:

• Oriented Deflector to 21°R of MLP Orientation

• HMRT performed as planned.

• POOH


• Run Summary – Completion Deflector

– B-12 Run #4:

• Deflector oriented to 34°R of MLP

• HMRT performed as planned.

– B-8:


• Likely Sheared USDFV

– A-6:

• Oriented Deflector to 11°R of MLP.



Hanger Packer

(Liner) Hanger Packer – Hanger for ML Junction and lower completion screens

The Hanger Packer design parameters for the ML hanger were reviewed and an

alternative hanger substituted, all the BOD requirements were met

VCH Hanger Packer basic design features:

• 352,000lb tensile strength running in hole

• 150,000lbs compression rating

• 10,000 ft-lbs torque rating

• 7,500psi differential sealing pressure

MLT Components

HAL23370

ReFlexRite ICI Junction

4.75” PBR w/ Scoophead – Accepts upper completion seal stinger for

tieback of mainbore stinger to upper completion tailpipe

Y-Block Assembly – Solid machined item that maintains flow

separation of both laterals while crossing over from D-tubes to tubular

connections

Lateral D-Section – Provides flow conduit for lateral wellbore.

Mainbore Stinger – Consists of D-section welded to a round stinger.

Stinger seals within the Completion Deflector. ID 2” for intervention.

D-to Round Adapter – To connect onto the base pipe of the lower

completion string

MLT Components

ICI

Junction

Aim Of Swell Packers

Water Swelling Packers – Bonded to Base Pipe

• Located in lateral close to Junction

• Assist with providing isolation of “9-5/8” annulus” from annular well fluids from the drilled lateral

• Located in 8.5” OD hole

• Low Temperature element

• Bonded onto 6-5/8” base pipe located in non production interval adjacent MLJ

• Swellable element 8.25” OD x 1.5meters in length

Water Swelling Packers – Bonded to Base Pipe

• Located in 8.5” hole section on A6 in just before 9” hole section

• To isolate screens from potential water coning from “heel dip section ” in lateral that is close to Oil / Water contact

• Specs as above

Water & Oil Swelling Packers – Slip-On Type

• To isolate 9” hole section annulus in production zone to manage both water and oil production

• Straddle geological interfaces

• Balance drawdowns from different perm sands

• Located in 9” hole section and run together in tandem

• For use with 5-1/2” base pipe

• Element 8.25” OD x 300mm in Length

B8 & B12 Wells – Swell Packer Locations

Top Muderong Shale

Top M. Australis

Lo Temp Water & Oil Swellable

Bonded Packers & Slip-On

Elements

Oil & Water Swellable Packers

Run in Tandem – Bonded Packers &

Slip-On Type

Screens Screens Screens

Well Bore Annular Isolation

Water Restriction

9”

Open Hole

8.5”

Open Hole

9”

Open Hole

5-1/2”

Tubing


A6 Well – Swell Packer Locations

Screens Screens Screens Screens

Lo Temp Water Swellable

Bonded Packers & Slip-On

& Oil Swellable Packers

Oil & Water Swellable Packers

Run in Tandem

Bonded & Slip-On Type

Top M. Australis

6m to O/W Contact

Water Salinity ~20,000Cl-

Annular Isolation

Well Bore Integrity

Bromide Completion Fluid

(minimal Chlorides)

Annular Barriers:

1) Assist in Balancing Production from

diff Perm Sands

2) Annular Water Flow Restriction

3) Isolation across fault

6-5/8”

Tubing

5-1/2”

Tubing

9” Open Hole


FlexRite ICI Junction Assy

Installation of Lateral Screens & FlexRite Junction M/U & RIH with 5-1/2” screens and 6-5/8” blank pipe with FlexRite

bullnose.

M/U ReFlexRite junction and associated equipment (safety joint & swivel).

M/U inner string with 4 ¾” MWD

M/U screen hanger assembly, record MWD offsets, continue to RIH.

Orient ReFlexRite junction (lateral leg to HS) prior to landing using MWD

Sting into deflector, and set down weight to shear tag ring in deflector to

confirm on depth and landed.

Drop ball/dart to set screen hanger, pressure up and set screen hanger.

Swivel Safety Joint 6 5/8” XO & 5 ½” Lateral Screens

Mainbore Stinger Sealing in Deflector

9 5/8” x 7”

VCH Screen Hanger

Screen Hanger

RT, 4 ¾” MWD


• Run Summary – Lower Completion

– B-12 Run #1:

• 7” Bullnose hung up on Deflector/Window

– B-12 Run #2:

• Modified Bullnose to 6.5” on Wandoo B Platform

• Dummy Run, no success

– B-12 Run #3:

• Modified Bullnose run through window at 70 ft/min, no drag

• Junction Run with Dual MWD and MFSM, added extra assembly

time: 6 hours on surface.

• Landed OK, saw pressure increase on depth. 1:40 to land.


• Run Summary – Lower Completion

– B-8 Run:

• 7” Bullnose run through window at 45 - 70 ft/min, no drag

• Junction Run with Single MWD – 5 hours to handle all

assemblies*

• *Trouble with VCH and laid out V-Door.

• Landed OK, saw pressure increase on depth. 0:50 to land

– A-6 Run:

• Modified 7” Bullnose run through window, stood up once.

Rotated 180°, passed through with minimal drag.

• Junction Run with Single MWD – 3:10 to handle all assemblies.

• Landed OK, saw pressure increase and Ring Shear on depth.

0:30 to land


9 5/8” x 7” VCH

Screen Hanger

Installation of Upper Completion

Run and install upper completion as per standard procedures.

Lateral Flow Path

Mainbore Flow Path

9 5/8” x 5-1/2” Production

Packer & Upper Completion


Lateral Flow

Mainbore Flow

TRFC “Intelligent” Completion

Upper Completion Schematic “B” Well

TR-SSSV5½" Halliburton 'SP' w/ 4.75" RPT Nipple

GLV Side-Pocket Mandrel5½" SLB MMRG w/ 1 1/2" Orifice Valve

Tubing Hanger Cameron 5½" x 13 5/8" w/ 4.875" QXT profile

Comp

letion

Fluid =

Inhibit

ed ???

ppg K

Cl Brine

Open

MLT liner hanger

Packer9⅝"HES SFT 47-53.5# x 5½" , ID 4.872" Landing Nipple,

4½", Halliburton 4.562 XN, 4.455" No GoCrossover

5½" 15.5# JFE Bear to 4 1/2" 13.5# JFE Bear

Tubing5½" Range 3 JFE Bear

Sliding Sleeve4½", Halliburton XD w/ 3.688" 'R' profile

Landing Nipple4½” x 2.875" "X" profile

Interval Control Valve4½" SLB TRFC-HNB-AP

Landing Nipple4½” x "X", 2.812" Bore

Interval Control Valve4½" SLB TRFC HN-LP w/2.812 plug

Flush joint tubing4 1/2" 12.6# TD FJ

Seal Unit MLT Y PBRHalliburton ML 12.6# TD FJ (run with shroud)

Bell Guide4½" Halliburton MLT

Lower Completion

ML Hanger Packer

B12ST3:

Well Results

Formation Top Depth

mTVDAHD(mMDRT)

1. Top Muderong 530.7(600.5)

2. Top Unit A1 584.1(744.5)

3. Top Unit A2 587.9(776.4)

4. Top Unit A3 590.1(810.1)

S N

Distance along well (m)

23 4

OGOC

1

Formation Top Depth

mTVDAHD(mMDRT)

1. Top Muderong 530.7(600.5)

2. Top Unit A1 584.1(744.5)

3. Top Unit A2 587.9(776.4)

4. Top Unit A3 590.1(810.1)

S N


23 4

OGOC

1

Original OWC

Prognosis Actual

Prognosis

Actual

Prognosis

Actual

Original OWC

Prognosis Actual

Prognosis

Actual

Prognosis

Actual

Original OWC

Prognosis Actual

Prognosis

Actual

Prognosis

Actual

Original OWC

Prognosis Actual

Prognosis

Actual

Prognosis

Actual

Pre Drill Simulation

Saturations

Post Drill Structural

Interpretation

Periscope image

B12ST3 Oil Rates

0

100

200

300

400

500

600

700

800

0 50 100 150 200 250 300 350

Days

Oil

Rate

(m

3/d

)

P50 Rate P90 Rate P10 Rate Actual

A1A2

A3B1

B2

C1

N S


Dept

h (m

TVDA

HD)

A1

A2

A3

B1

B2

C1

6H/HST1

Expect water cone

200 m wide based on

reservoir simulation

3

45 B7

Expected GOC based

on reservoir

simulation

Depth

mTVDAHD(mMDRT)

1. Top Muderong 530.1(615.9)

2. Top Unit A1 579.6(763.0)

3. Top Unit A2 583.2(832 )

4. Top Unit A3 585.1(873)

5. Top B sand (Unit B1) (1) 588.1(1025)

6. Top B sand (Unit B1) (2) 589.5(1169)

Formation Top

2

6A1

A2

A3B1

B2

C1

N S


Dept

h (m

TVDA

HD)

A1

A2

A3

B1

B2

C1

6H/HST1

Expect water cone

200 m wide based on

reservoir simulation

3

45 B7

Expected GOC based

on reservoir

simulation

Depth

mTVDAHD(mMDRT)

1. Top Muderong 530.1(615.9)

2. Top Unit A1 579.6(763.0)

3. Top Unit A2 583.2(832 )

4. Top Unit A3 585.1(873)

5. Top B sand (Unit B1) (1) 588.1(1025)

6. Top B sand (Unit B1) (2) 589.5(1169)

Formation Top

2

6

B8ST1:

Well Results

Original OWC

B7

Prognosis

Actual

Water in B sand

(swept)

~250m water along well bore

Water cone due to B7

estimated to be ~70m wide

Water in B sand

Prognosis

Actual

A3 unit

A3 unitA2 unit

A2 unit

A3 unitB1 unit

Original OWC

B7

Prognosis

Actual

Water in B sand

(swept)

~250m water along well bore

Water cone due to B7

estimated to be ~70m wide

Water in B sand

Prognosis

Actual

A3 unit

A3 unitA2 unit

A2 unit

A3 unitB1 unit


Saturations


Interpretation

Periscope image

B8ST1 Oil rates

0

100

200

300

400

0 30 60 90 120 150 180 210 240 270 300 330 360

Days

Oil

Rate

(m

3/d

)


South

Fault

A1

A2

A3B1

B2

C1

N S


Dept

h (m

TVDA

HD)

A1A2

A3

B1

B2

C1

Expected GOC based

on reservoir

simulation

A6H3:

Well Results

Water in B

sand

Prognosis

Actual

East – West Fault

Original OWC

Original OWC

Water in B

sand

Prognosis

Actual

East – West Fault

Original OWC

Original OWC


Interpretation

Periscope image


Saturations

A6H3 Oil Rates

0

100

200

300

400

500

600

0 30 60 90 120 150 180 210 240 270 300 330 360

Days

Oil

Rate

(m

3/d

)


Remaining Oil at 2029 suggests

more prospects

WA1

WA2

WA3

WA4

WA5

WA6

WA6H1

WA7WA8ST1

WA9

WB10ig

WB11

WB12ST2

WB13H

WB14H

WB14Pilot

WB1A

WB2A

WB3

WB4A WB5

WB6

WB7

WB8A

WB9

439,000 440,000 441,000 442,000 443,000

439,000 440,000 441,000 442,000 443,000

7,7

72

,00

07

,77

3,0

00

7,7

74

,00

07

,77

5,0

00

7,7

72

,00

07

,77

3,0

00

7,7

74

,00

07

,77

5,0

00

0.00 0.25 0.50 0.75 1.00 km

File: Pred_A6B8B12Combined.irf

User: rjefferies

Date: 14/05/2010

Scale: 1:29870

Y/X: 1.00:1

Axis Units: m

0.0

0.7

1.3

2.0

2.7

3.4

4.0

4.7

5.4

6.0

6.7

A6B8B12Oil Per Unit Area - Total (m) 2029-12-31 K layer: 46

Drills, 29

Injection Conversions, 1

Recompletions, 13

Water Shutoffs, 12

Debottlenecking, 1

The Future for Wandoo

• Significant oil volumes will not be drained by current

completions.

• This trapped oil is in „small‟ reserve targets (Marginal

economics with conventional drilling).

• The team is focused on refining and testing alternative

methods to access „small‟ reserves targets incorporating

the lessons learned from the latest program.

Using Proven Methods to Develop Future Prospects

multilateral installation

Documents