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OIL COMPANY OF AUSTRALIA LIMITED

Talinga #2WELL COMPLETION

REPORTATP 692P - QUEENSLAND

by

S F SIMEONE & B J CORBETT

Oil Company of Australia Limited A.B.N. 68 001 646 331Ground Floor, South Tower John Oxley Centre339 Coronation DriveMILTON QLD 4064

October 2003

TABLE OF CONTENTS

Page No.WELL DATA CARD

GENERAL DATA WIRELINE LOGS FORMATION TESTS FULL HOLE CORES PERFORATIONSLOG INTERPRETATION SIDEWALL CORES SUMMARY

1. SUMMARY 12. WELL HISTORY 2

2.1. General Data 22.1.1. Well Name and Number 22.1.2. Location 22.1.3. Elevations 22.1.4. Petroleum Tenement 22.1.5. Permit Operator 22.1.6. Other Participants 22.1.7. Date Drilling Commenced 22.1.8. Date Drilling Completed 22.1.9. Date Final Rig Released 22.1.10. Total Depth 22.1.11. Status 3

2.2. Drilling Contractor(s) and Rigs 3Surface Hole 3Production Hole 3Casing Rig 3

2.3. Drilling Data 42.3.1. Drilling Data Summary 42.3.2. Hole Sizes and Depths 42.3.3. Casing and Cementing 52.3.4. Deviation Surveys 52.3.5. Drilling Fluid 52.3.6. Physical Mud Properties 52.3.7. Perforation Record 52.3.8. Plugging and Cementing 5

2.4. Logging and Testing 52.4.1. Wellsite Geologist 52.4.2. Mudlogging 62.4.3. Ditch Cutting Samples 62.4.4. Coring 62.4.5. Sidewall Cores 62.4.6. Testing 62.4.7. Wireline Logging 62.4.8. Temperature Surveys 62.4.9. Velocity Survey 6

3. GEOLOGY 73.1. Reasons for Drilling 73.2. Stratigraphy 73.3. Hydrocarbon Shows 7

4. DISCUSSION AND CONCLUSIONS 85. COMPLETION 96. REFERENCES 9

TABLES

Table 1: Net Coal Prognosis 7

LIST OF FIGURES

Figure 1 – Location MapFigure 2 – Drilling Time/Depth Curve Figure 3 – Time AnalysisFigure 4 – Surat/Bowen Stratigraphic Figure 5 – Downhole Installation Diagram

APPENDICES

APPENDIX 1 – DAILY DRILLING REPORTS APPENDIX 2 – WELL LOCATION SURVEY PLAN APPENDIX 3 - WIRELINE LOG (1:200, 1;500)

Date spudded(Mitchell 101):Date TD reached(Mitchell 101):

Date rig release(OD&E 9):

WELL DATA CARD OCA Talinga #2

PAGE 1 of 3

G E N E R A L D A T A Location: (AGD 84) Latitude:

Longitude:2652'35.82"S

15024'12.60"EStatus: Cased and Completed with

PCP

(AMG Zone 56) Easting: 242 053.92 Total Depth:

Driller: 573.00 m

Northing: 7 024 576.68 Logger: 569.96

Elevation: GL: RT :

292.78 metres

293.78 metres

Plugs: None.

WIRELI NE LOG SLog Run Interval (from / to)

mBHT / Time

GR 1 569.96 m - surface Not RecordedCAL 1 569.96 m – surfaceDENSITY 1 569.96 m – 17m

F O R M A T I O N T E S T SNo Interv

al (m)

Periods (mins)

EMP IP/FP(psi)

EMP FSIP(psi)

Fluid to

surface

(mins)

Surface Press. (max)(psi)

TCmm

BCmm

Rev Out

Result

None

FULL H O LE CO RES No. Interval Formation Cut (m) Rec.(m)

None

(Mitchell 101)

2/10/2001 7:00 hours Casing: Size: Shoe:

5/10/2001 13:30 hours (a) Surface 219 mm 17.0 m

8/10/2001 11:30 hours (b) Production

140 mm 569.4 m

Depth (m)

LithologyDepth (m)

Lithology

None

Interval (mGL)

Formation SHOTS255.20-255.61 Macalister 8249.20-249.50 Macalister 6246.40-247.11 Macalister 14244.00-244.46 Macalister 9232.20-232.76 Macalister 11229.40-229.91 Macalister 10

Interval (mGL)

Formation Shots

524.30-525.16 Taroom 17505.50-506.87 Taroom 27489.00-489.76 Taroom 15477.50-478.21 Taroom 14468.50-469.36 Taroom 17386.20-387.11 Iona 18376.70-377.77 Iona 21

WELL DATA CARD OCA Talinga #2 PAGE 2 of 3

P E R F O R A T I O N S

L O G I N T E R P R E T A T I O N Formation Interval *Cat. San

d(m)

**Pay

(m)

AveØ

(%)

AveSw (%)

None

S I D E W A L L C O R E S

WELL DATA CARD OCA TALINGA #2 PAGE 3 of 3

S U M M A R Y

Talinga #2 was drilled as part of a four well appraisal program in October 2001. Talinga #2 is located in ATP 692P near Chinchilla in South Eastern Queensland. These four wells were drilled to further evaluate the productivity potential of the Walloon coal measures.

The primary target of Talinga #2 was the Macalister coal seam in the Juandah Coal Measures. A secondary target was the additional coal seams in the Taroom Coal Measures. A total of 16 seams (>0.5 m) were intersected during drilling, with a cumulative net thickness of 15.10 m.

Talinga #2 was spudded at 7:00 hours, 2nd October 2001 using Mitchell Rig 101. The 254 mm surface hole was drilled to 17.0 m before 219 mm surface casing was run in and set at 17.0 m. The 200 mm production hole was drilled to a total depth of 573.0 m, which was reached at 13:30 hours, 5th October 2001. The well was logged with Mitchell Rig 101 standing onsite. Operations were suspended and Mitchell Rig 101 was released at 19:30 hours on the 5 th of October 2001.

Operations resumed again on the 7th of October with OD&E Rig 9 arriving on site to run 140mm production casing with baffles on the 7th of October 2001. The casing was set at 569.4m and OD&E Rig 9 was released from site on the 8th of October at 11:30 hours.

Wellsite Geologists: NA Card Prepared by: B Corbett Date: 01/03

1. SUMMARY

Talinga #2 was drilled in October 2001, as part of a four well appraisal program. Talinga #2 is located in ATP 692P near Chinchilla in South Eastern Queensland. These four wells were drilled to further evaluate the productivity potential of the Walloon coal measures.

The primary target of Talinga #2 was the Macalister Coal Seam in the Juandah Coal Measures. Additional seams in the Taroom Coal Measures were a secondary target. A total of 16 seams (>0.5 m) were intersected during drilling with a cumulative net thickness of 15.10 m.

Talinga #2 was spudded at 7:00 hours, 2nd October 2001 using Mitchell Rig 101. The 254 mm surface hole was drilled to 17.0 m before 219 mm surface casing was run in and set at 17.0 m. The 200 mm production hole was drilled to a total depth of 573.0 m, which was reached at 13:30 hours, 5th October 2001. The well was logged with Mitchell Rig 101 standing onsite. Operations were suspended and Mitchell Rig 101 was released at 19:30 hours on the 5th of October 2001.

Operations resumed again on the 7th of October with OD&E Rig 9 arriving on site to run 140mm production casing with baffles on the 7th of October 2001. The casing was set at 569.4m and OD&E Rig 9 was released from site on the 8th of October at 11:30 hours.

OIL COMPANY OF AUSTRALIA LIMITED - DRILLING Page: 1 of 9Talinga #2 WELL COMPLETION REPORT Issued: October 2003I:\Talinga\Talinga 02\Well Completion Report\WCR Talinga #2.doc Date Printed: 6-Oct-03

A

A

PL72

P

P

A

A

A

27 0

7 ATP721PATP606P ATP525PPL 101

ATP465PPL 171

ATP525P

ATP695P

ATP692PWoleebee East-1ATP692P

SURAT BASINATP687P

ATP574P ATP610P

ATP676P ATP676P

ATP651PATP632P

ATP676PS1 ATP676P

ATP631PDalwogan-1

ATP610PATP676PS2

ATP647PTalinga-5ATP632P

ATP 692PTalinATPg692P a-2

PL185

ATP702PPL 72 ATP676PS1

PL73PL180PL 73

ATP620PTalinga-1

PL179 ATP676PS2PL194

ATP648P

Guluguba-1

149 48 34 E 150 00 00 E 150 30 00 E 150 51 04 E

Figure 1

26 3

0 26

07

27 0

0

2. WELL HISTORY2.1. General Data

2.1.1.Well Name and NumberTalinga #2

2.1.2.Location(AGD-84) Latitude: 2652'35.82"S

Longitude: 15024'12.60"E

(AMG Zone56) Easting: 242 053.92Northing: 7 024 576.68

2.1.3.ElevationsGround Level: 292.786 m ASLRotary Table: 293.786 m ASL (Mitchell Rig 101)

2.1.4.Petroleum TenementATP 692 P

2.1.5.Permit OperatorOIL COMPANY OF AUSTRALIA LIMITED ABN 68 001 646 331Ground Floor, South Tower John Oxley Centre339 Coronation DriveMILTON QLD4064

2.1.6.Other ParticipantsSONOCO INC OF AUSTRALIAC/O Suncor Energy Developments Inc 112-4th Avenue S.W.Calgary, Alberta Canada T2P 2V5

2.1.7.Date Drilling Commenced7:00 hours 2nd of October, 2001 (Mitchell Rig 101)

2.1.8.Date Drilling Completed13:30 hours 5th of October, 2001 (Mitchell Rig 101)

2.1.9.Date Final Rig Released11:30 hours 8th of October, 2001 (OD&E Rig 9)

2.1.10. Total DepthDriller: 573.00 metresLogger: 569.96 meters

OIL COMPANY OF AUSTRALIA LIMITED - DRILLING Page: 2 of 9

Talinga #2 WELL COMPLETION REPORT Issued: October 2003I:\Talinga\Talinga 02\Well Completion Report\WCR Talinga #2.doc Date Printed: 6-Oct-03

2.1.11. Status

Cased and completed as a gas producer with a PC pump.

2.2. Drilling Contractor(s) and Rigs Surface Hole

Drilling Contractor: MITCHELL DRILLING23 Limestone StreetDARRA QLD 4076

Drilling Rig: Mitchell Drilling Rig 101 - Reichdrill T – 100

Production HoleDrilling Contractor: MITCHELL DRILLING

23 Limestone StreetDARRA QLD 4076

Drilling Rig: Mitchell Drilling Rig 101 - Reichdrill T – 100

Casing RigService Rig Contractor: OIL DRILLING & EXPLORATION LIMITED

461 Greenwattle StreetTOOWOOMBA QLD 4350

Service Rig: OD&E Rig 9


Dep

th

5a.0

2. 3. 4.

100

200

5b.

5c.

300

400

5005d.

6. 7. 8.

6000

Predicted

Actual

Shut Down For Night

1 2 Days from Spud 3 4 Figure 2 5

This well is drilled By Mitchell Drilling on a 12 hours a day basis. Production casing will be run by a separate service rig.1. Spud well at 16:00 hours, 2ND oCT. 20012. Drill 251mm conductor hole to 17 metres. Hole

unstable and had to be completed via mud drilling.3. Cemented 218mm conductor casing. SDFN.4. Nipple up diverter and drill out cement.5a. Drill 200mm hole to 45m - chamge to Salt Pac R mud system. 5b. Drill 200mm hole to 214m. SDFN.5c. Drill 200mm hole to 433m. SDFN. 5d. Drill 200mm hole to TD (573mRT).

TD reached at 13:30 hrs 5 October 20016. POOH7. Run logs.8. RDMO Mitchell Drilling Rig, 19:30 hours, 5th Oct 2001 Anticipated Activities

Talinga 02 Time-Depth

1

Talinga 2 Time

Analysis

Cementing 2.1

Casing 2.6

Wireline 3.1

Tripping 3.1

Safety 3.1

Circ & Condition 9.9

Drilling 24.5

Other 51.6

0.0 10.0 20.0 30.0 40.0 50.0 60.0

Percentage of Time on Location

Figure 3

2.3. Drilling Data2.3.1.Drilling Data SummaryBelow is the operations summary for Talinga #2. It has been compiled from the tour sheets and daily drilling reports. G Jameson provided onsite drilling supervision for Oil Company of Australia Limited. Further details are provided in the time / depth curve (Figure 2) and the time analysis chart (Figure 3).

Surface HoleSize: 254 mmInterval: 0.0 m – 17.0 mCasing: 219 mmDepth: 17.0 m

Talinga #2 was spudded at 7:00 hours on the 2nd of October 2001. A 1 m conductor had previously been set. The 254 mm surface hole was drilled to 17.0 m using Mitchell Drilling Rig 101. The hole was circulated clean prior to pulling out and running surface casing. A total of 6 joints of 219 mm conductor casing were run and set at 17.0 m. The casing was cemented to surface with 15.6ppg Class A cement.

Production Hole Size: 200 mmInterval: 17.0 m – 573.0 m (T.D.) Casing: 140 mmDepth: 569.4 m

Mitchell Drilling Rig 101 drilled the 200 mm production hole. After drilling out the cement the production hole was drilled to 573.0 m using a 7.875’ PDC bit. This total depth was reached at 13:30 hours on the 5th of October 2001.

The hole was circulated clean and a 50bbl sweep was pumped to the bottom prior to pulling out of the hole. A calliper, gamma and density logging run was performed to TD (569.96 m logger).

Operations were suspended and Mitchell Rig 101 was released at 19:30 hours on the 5th of October 2001.

Operations resumed and OD&E Rig 9 arrived on site to run production casing on the 7th of October 2001. 46 joints of 140mm production casing including baffles were run with a shoe depth of 569.4 m GL. The casing was cemented with a 37 sack 65/35 Pozblend + 6% gel + 0.5% HR7 lead and a 290 sack Class A + 1% Halad 322 tail. The BOPs were nippled down and OD&E Rig 9 moved off site at 11:30 hrs on the 8th of October 2001.

2.3.2.Hole Sizes and Depths10.0” / 254 mm to 17.0 m7.875” / 200 mm to 573.0 m (TD)

Interval(mGL)

Formation Shots

255.20-255.61

Macalister 8

249.20-249.50

Macalister 6

246.40-247.11

Macalister 14

244.00-244.46

Macalister 9

Interval(mGL)

Formation Shots

524.30-525.16

Taroom 17

505.50-506.87

Taroom 27

489.00-489.76

Taroom 15

477.50-478.21

Taroom 14

2.3.3.Casing and CementingSurfaceSize - 8.625” / 219 mmWeight - 28.9 ppfGrade - Ultra PipeShoe Setting Depth - 17.0 mQuantity of Cement - 15.6ppg Class A redi-mix cement. Interval Cemented - 17m to surface

ProductionSize - 5.5” / 140mmWeight - 17 ppfGrade - N-80Shoe Setting Depth - 569.4 mQuantity of Cement - 37 sacks 65/35 Pozblend + 6% gel +

0.5% HR7 lead and 290 sacks Class A + 1% Halad tail

Interval Cemented - 569.4m to surface

2.3.4.Deviation SurveysNil

2.3.5.Drilling FluidA freshwater Gel Mud was used during the drilling of Talinga #2.

2.3.6.Physical Mud Properties

No Mud Engineer was onsite during the drilling of Talinga #2 and as such a complete record of mud properties was not recorded. Mud density was kept as low as possible during drilling; never exceeding 9.0ppg.

2.3.7.Perforation Record

2.3.8.Plugging and CementingNone.

2.4. Logging and Testing

2.4.1.Wellsite GeologistNo wellsite geologist was present for the drilling of Talinga #2


2.4.2.MudloggingNo mudlogging services were utilised during the drilling of Talinga #2. Consequently, gas levels and rates of penetration were not recorded.

2.4.3.Ditch Cutting SamplesA complete set of ditch cuttings samples was not collected during drilling.

2.4.4.CoringNone

2.4.5.Sidewall CoresNone

2.4.6.TestingNone

2.4.7.Wireline LoggingOne suite of logs was run at TD by Geoscience Associates Australia.

Suite/Run Type Log Interval1 GR 569.96 m –

surface1 DENSITY 569.96 m –

surface1 CAL 569.96 m -

surface

2.4.8.Temperature SurveysNo bottom hole temperature was recorded during wireline logging.

2.4.9.Velocity SurveyNo velocity survey was shot at Talinga #2.

OIL COMPANY OF AUSTRALIA LIMITED - DRILLING Page: 6 of 9Talinga #2 WELL COMPLETION REPORT Issued: October 2003

I:\Talinga\Talinga 02\Well Completion Report\WCR Talinga #2.doc Date Printed: 6-Oct-03

3. GEOLOGY3.1. Reasons for Drilling

Talinga #2 was drilled as part of a four well appraisal program in October 2001. The wells further evaluate the productivity potential of the Walloon coal measures.

It was anticipated that Talinga #2 would intersect a number of coal seams within the Taroom and Juandah coal measures. Of these, the Macalister Coal Seam was the primary target. A total of 16 seams (>0.5 m) were intersected during drilling. The total net coal intersected was 15.10 m.

Table 1: Net Coal Occurrence

Coal

Top (RT)

Base (RT)

Net (m)

Kogan 2 157.64

158.44

0.80

Macalister 6

229.38

230.06

0.68

Macalister 5

232.02

232.78

0.76

Macalister 4

243.98

244.62

0.64

Macalister 3

246.28

247.44

1.16

Iona 3 376.68

377.68

1.00

Iona 2 378.60

379.34

0.74

Iona 1 386.14

387.00

0.86

Condamine 5

468.42

469.52

1.10

Condamine 4

470.20

470.80

0.60

Condamine 2

477.86

478.84

0.98

Condamine 1

488.82

490.26

1.44

Taroom 4 505.28

506.56

1.28

Taroom 3 507.52

508.58

1.06

Taroom 2 523.84

525.32

1.48

Taroom 1 546.70

547.30

0.54

Total 15.10

3.2. StratigraphyNo ditch cutting samples were collected during the drilling of Talinga #2, consequently a complete stratigraphic section cannot be compiled. The general

sedimentary section of the area is displayed graphically in Figure 4.

3.3. Hydrocarbon ShowsNo mudlogging services were utilised during the drilling of Talinga #2, consequently total gas and chromatograph levels were not recorded. Ditch cutting samples were not collected at Talinga #2.


Figure 4

STRATIGRAPHY OF THE WESTERN SURAT/BOWEN BASINS

PROVINCE PERIOD PALYNOLOGY ZONES STRATIGRAPHY LITHOLOGY SHOWS

TERT. TERTIARY UNDIFF. MAJOR UNCONFORMITY

PK 5

PK 4

PK 3

PK 2

PK 1

WALLUMBILLA FORMATION

BUNGIL FORMATION

MOOGA SANDSTONE

ORALLO FORMATION

GUBBERAMUNDA SANDSTONE

PJ 6

PJ 5

PJ 4

WESTBOURNE FORMATION

SPRINGBOK SANDSTONE

WALLOON COAL MEASURES

HUTTON SANDSTONE Oil shows

PJ 3

PJ 2 PJ 1

EVERGREEN FORMATION

UPPER EVERGREEN MEMBER

BOXVALE SANDSTONE MEMBER

LOWER EVERGREEN SHALE BASAL EVERGREEN SANDSTONE

Oil & Gas

Oil & Gas

PT 5 PT 4

PT 3

MAJOR UNCONFORMITYMOOLAYEMBER FORMATION Gas

BASAL MOOLAYEMBER SST MOOLAYEMBER SHALE MBR

Oil & Gas

PT 2

PT 1 PP 6

SNAKE CREEK MUDSTONE SHOWGROUNDS SANDSTONE

REWAN FORMATIONBASAL REWAN SANDSTONE

BANDANNA FORMATION

Gas

Oil & Gas

Oil Shows

LATE MID EARLY

PP 5

PP 2-4 PP 1 PC 4

BLACK ALLEY SHALE

TINOWON FORMATION MUGGLETON FM

WONOLGA VOLCANICS

TIMBURY HILLS

WINNATHOOLA COAL MBR

MANTUAN BEDSWALLABELLA COAL MBR

LORELLE SANDSTONE MBR

PALAEOZOIC

Gas

Gas

Gas

SUR-BOW STRAT.CDR VER: 1.0 OCT 1997

GRANIT

BLACK

THO

MPS

ON

FO

LD

BOW

EN

SUR

AT

TRIA

SSI

DJU

RAS

SIC

CR

ETAC

EOC

PER

MIA

EAR

LAEA

RL

LE

LAEA

RM

IDD

ROLL

ING

DO

W

UPP

ER

REW AN

BU

NDAM

BA

INJU

NE C

REEK

BL

YTH

ESD

ALE

4. DISCUSSION AND CONCLUSIONS

Talinga #2 was drilled as part of a four well appraisal program to further evaluate the productivity potential of the Walloon Coal Measures. This program was conducted in October of 2001. The well was anticipated to intersect a number of coal seams in the Taroom and Juandah coal measures.

A typical Bowen Basin sedimentary section was encountered at Talinga #2. A total of 16 coal seams (>0.5 m) were encountered during drilling with a net thickness of 15.10 m.

Talinga #2 was spudded at 7:00 hours, 2nd of October 2001 using Mitchell Drilling Rig 101. The 254 mm surface hole was drilled to 17.0 m before 219 mm surface casing was run in and set at17.0 m. Mitchell Rig 101 proceeded to drill the 200 mm production hole to a total depth of573.0m, which was reached at 13:30 hours on the 5th of October 2001. The well was logged using high resolution calliper, gamma and density tools provided by Geoscience Associates Australia with Mitchell drilling Rig 101 standing onsite.

Operations were suspended and Mitchell Drilling Rig 101 was released at 19:30 hours on the 5th of October 2001. Operations resumed again when OD&E Rig 9 moved onsite to run casing and baffles on the 7th of October 2001. 140mm production casing was set at 569.4 m and OD&E Rig 9 was released from site at 11:30 hours on the 8 th of October 2001.

5. COMPLETION

Talinga #2 was cased and cemented on the 8th of October 2001 using OD&E Rig 9; 140mm casing was run in and set at a depth of 569.4 mGL.

Talinga #2 was completed as a gas producer. A progressive cavity pump was installed on 2-3/8” tubing. The downhole diagram for Talinga #2 is displayed in figure 5.

6. REFERENCESG Ottaviano ATP 692P 2001 Talinga Appraisal Campaign, Talinga

02 &05 (Fracc Wells) Drilling Programme, unpublished report prepared for Oil Company of Australia Limited, July 2001.


Downhole Installation DiagramWell: Talinga 02

ItemD 1 No.

2 1C 2

3 3456

78910

Description

GL to top of tubinghead spool Tubing hanger21 joints x 2-7/8" EUE tubing Swage, 2-7/8" EUE x 3-1/2" EUE12' x 3-1/2" EUE pup jointSTATOR: Weatherford BMW PCP, 350-1600 c/w Buna Stator.Swage, 2-7/8" EUE x 3-1/2" EUEGas Anchor, 3-1/2" OD, 2-7/8" EUE BxP 10 joints x 2-7/8" EUE J55 R2 tubing2-7/8" EUE bull plug

End of tail pipe

Length (m)

-0.450.10

197.640.233.724.230.000.234.74

96.740.20

Depth (m GL)

-0.45-0.35

197.29197.52201.24205.47205.47205.70210.44307.18307.38

Min ID (in)

Rod String (from bottom up):A BMW 350-1600 rotor (+ crossover coupling. 1.0" x 7/8")B 25 x 7/8" Grade D Sucker Rod (only one guide on first rod) C 2 x 6' x 7/8" Grade D pony rods to space outD 26' x 1-1/4" SS polished rod

2 x Huber poly rod guides installed on each 7/8" rod.4 1 x rod guide on 1st rod above rotor, I on each pony rod

A 5 Rotor Serial - 56-500 / E373086 Stator Serial - 56-500-3440 / E37308 - HS

PERFORATIONS Gun Charges7 Formation

8

Interval (mGL) Size Type SPF Type Ph gm

Surface Casing9 Production Casing

Cementing Details Remarks:

10String Weight

Calculated

8-5/8", 28.6ppf, API 5LB ultrapipe @ 17mGL 5-1/2", 17ppf N80 LTC @ 569mGLLead: 40sx Class A Pozmix. Tail: 290sx Class A Weatherford H60 Hydraulic d/head c/w PVH 74 Hydraulic Power Skid and 4.3L GM Gas Engine

Actual

PBTD: ~ 568mGL

Wellsite Supervisor Date of Installation Drafted by

S. Gore 14th Jan 2002

EJT Date:

Not to Scale Proposed

14-Jan-02 Re-Completion

Checked by Date: 15/02/02 Completion X

Figure 5

B

Macalister 229.40 - 229.91 3-3/8" HSD 6 34B HJII 60 21.7Macalister 232.20 - 232.76 3-3/8" HSD 6 34B HJII 60 21.7Macalister 244.00 - 244.46 3-3/8" HSD 6 34B HJII 60 21.7Macalister 246.40 - 247.11 3-3/8" HSD 6 34B HJII 60 21.7Macalister 249.20 - 249.50 3-3/8" HSD 6 34B HJII 60 21.7Macalister 255.20 - 255.61 3-3/8" HSD 6 34B HJII 60 21.7

LJCM 376.70 - 377.77 3-3/8" HSD 6 34B HJII 60 21.7LJCM 386.20 - 387.11 3-3/8" HSD 6 34B HJII 60 21.7

Taroom 468.50 - 469.36 3-3/8" HSD 6 34B HJII 60 21.7Taroom 477.50 - 478.21 3-3/8" HSD 6 34B HJII 60 21.7Taroom 489.00 - 489.76 3-3/8" HSD 6 34B HJII 60 21.7Taroom 505.50 - 506.87 2-1/2" HSD 6 35B UP 60 10.5

Taroom 524.30 - 525.16 2-1/2" HSD 6 35B UP 60 10.5

OIL COMPANY OF AUSTRALIABIT RECORD

Well : Talinga # 2 Basin / Area : Chinchilla Permit : ATP 692 Field : TalingaLocation : Latitude : 26° 52' 36.00'' S G.L. 295.00 metres Spud Date: 2-Oct-01

Longitude : 150° 24' 12.50'' N Well Site Supervisor: G jameson K.B. 296.30 metres T.D. Date: 2-Oct-01Contractor : Mitchell Drilling Rig #: 101 Proposed TD: 570 metres Rig Released Date: 5-Oct-01

PUMPS MUD TYPENo. Type Stroke (in) Liner (in) Output (gps) Section Dev Interval Type Wt1 Rostel Duplex 14.00 6.50 7.80 Surface 0.00° 0m to 17m Polymer 8.452 Triplex 0.00 0.00 0.00 Main 0.00° 17m to 573m Polymer 8.60

BitNo.

RunNo.

Size(in) Make Type IADC

CodeSerialNo. Nozzles Motor

Y / NShock-SubSerial No.

DepthOut Metres Hours ROP

(m/hr)AccumHours

Bit Grading WOB RPM Press(psi)

Pump(gpm)I O D L B G O R Mn Mx Mn Mx

1 1 9.875 Hughes Tricone 17 17 ####### ###### #######2 1 7.875 Hughes PCD 1402581 556 4000 6000 60 85 250 420

Comments : Bit #2 has 4 x 11 jets. 2 x12 & 1 x 14 jets on bit record have the equivalent T.F.A.

APPENDIX 1 – DAILY DRILLING REPORTS

REPORT # 1WELL RIGOP's TO 06:00 REMARKS:LAST CASING

24:00 DEPTHFORMATION

24 HR PROGPTD

CUM. COSTSDAILY COSTS

TEST DUE

fine2. MSDSfineWEATHER AM

PM1. Welding flashesSAFETYAFD's: 238

NILBOP TESTMAASPLOTSET AT8 5/8''

Nippling up Diverter line. Preparing to drill 7 7/8" surface casing hole

$16,555.76$16,55617m17mTalinga # 2

17.0m

570mMitchell Drilling # 101

DAILY DRILLING REPORT 02/10/01BIT INFORMATION BHA # 1 MUD PROPERTIES OPERATION HRS CUM

WOB(kLb) JET V(fps) TOOL LENGTH Time 1800 1. Air Rig upRPM H S I /tricone 0.27 Depth (m) 17 2. Casing 2.5 2.5

BIT NUMBER 1 Bit Sub 0.71 Temp (° C) 29 3. Cementing 2.0 2.0Size (in) 9.875 Collars 18.00 Mud Type Polymer 4. Circ & Condition 3.0 3.0Make Hughes Density (ppg) 8.45 5. CoringType Tricone ECD (ppg) 6. Drill OutIADC Code Viscosity (sec) 28 7. Drilling 2.5 2.5Serial Number PV / YP (cp/lb) 8. Handle BHANozzles OPEN Gells (s/m) 9. LOT / FITDepth In (m) API Filt. (cc) 10. Nipple up BOP'sDepth Out (m) 17 Cake (/32") 11. P & ATotal Metres 17 Solids (% Vol) 12. RepairsHours 2.5 Sand (% Vol) 13. Rig ServiceROP 6.8 MBT 14. Safety 1.0 1.0Condition Out BHA LENGTH (m) 18.98 pH (strip) 15. Survey

FLOW DATA BHA WEIGHT(kLb) 2.0 Chlorides (mg/l) 16. Test BOPCIRC. RATE (gpm) STRING WT (kLb) 2.0 KCL (% ) 17. Tight hole / FishingAV - DP (fpm) HOOK LOAD (kLb) PHPA (ppb) 18. Tripping 1.0 1.0AV - DC (fpm) WT BELOW JARS (kLb) ALC - 50 (K) 19. Wait on CementSPP (psi) DRAG UP (kLb) Circ. Vol. (Bbl) 100 20. Wash / ReamSPP (calculated) DRAG DOWN (kLb) CHEMICAL USAGE 21. Well Control

PUMP #1 PUMP #2 TORQUE ON (Amps/Rel.) Flossy Salt 60 22. Well TestRstel TORQUE OFF (Amps/Rel.) PAC-R 2 23. Wiper Trip

RATE RATE ENVIRONMENTAL DATA 24. WirelineLINER 6.5'' LINER FUEL ON SITE 400 Litres 25. Other 12.0 12.0STROKE 14.0'' STROKE DAILY USAGE 200 Litres TOTALS 24.0 24.0

CUM. FUEL USED 200 Litres DAILY MUD COSTS $809.76SURVEYS CUM. MUD MIXED 100 Bbls CUM. MUD COSTS $809.76

CUM. MUD LOSSES AFE COST - C&SCUM. GEL AFE COST - P&ACUM. BARITES AFE COST - C&C

HOURLY OPERATIONS SUMMARY 0000 to 2400From To Description

6:30 SDFN6:30 7:00 Safety meeting .Service rig7:00 9:30 Drill 10" conductor hole to 17m GL9:30 10:30 Trip out . Nipple down diverter

10:30 12:30 Weld on lifting lugs and run and weld 18m 8 5/8" conductor casing12:30 14:30 Mix and pump cement for conductor casing .Top up cement. Clean gear14:30 15:00 Weld on diverter flange Wait on Cement15:00 15:30 Tool Box safety meeting Read MSDS sheets on mixing salt and Pac R15:30 18:30 Mix salt and Pac R in mud tank and pump to mud pits18:30 0:00 SDFN

SUPERVISOR: G jameson

GEOLOGIST: MUD CO: BAROID AUSTRALIA

Talinga # 2 REPORT #1

Talinga02DDR01 Printed on 10/10/2003



24 HR PROGPTD


TEST DUE

2.fineWEATHER AM

PM1. PPESAFETYAFD's: 239


Drilling ahead with 7 7/8" PCD bit production hole from 214m

$19,651.60$36,207197m214mTalinga # 2

17.0m

570mWalloons SubgroupMitchell Drilling # 101


WOB(kLb) 6000 JET V(fps) #DIV/0! TOOL LENGTH Time 1800 1. Air Rig upRPM 85 H S I #DIV/0! PCD 0.30 Depth (m) 214 2. Casing 2.5

BIT NUMBER 1 Bit Sub 0.54 Temp (° C) 25 3. Cementing 2.0Size (in) 7.875 Collarsx10 63.14 Mud Type Polymer 4. Circ & Condition 2.5 5.5Make Hughes Xover 0.24 Density (ppg) 8.60 5. CoringType PCD ECD (ppg) 6. Drill OutIADC Code Viscosity (sec) 34 7. Drilling 7.0 9.5Serial Number 1402581 PV / YP (cp/lb) 8. Handle BHANozzles OPEN Gells (s/m) 9. LOT / FITDepth In (m) 17 API Filt. (cc) 10. Nipple up BOP'sDepth Out (m) IN Cake (/32") 11. P & ATotal Metres 197 Solids (% Vol) 12. RepairsHours 7 Sand (% Vol) 13. Rig ServiceROP 28.1 MBT 14. Safety 0.5 1.5Condition Out BHA LENGTH (m) 64.22 pH (strip) 15. Survey

FLOW DATA BHA WEIGHT(kLb) 5.5 Chlorides (mg/l) 16. Test BOPCIRC. RATE (gpm) 468 STRING WT (kLb) 4.8 KCL (% ) 17. Tight hole / FishingAV - DP (fpm) 185 HOOK LOAD (kLb) PHPA (ppb) 18. Tripping 1.0AV - DC (fpm) 185 WT BELOW JARS (kLb) ALC - 50 (K) 19. Wait on CementSPP (psi) DRAG UP (kLb) Circ. Vol. (Bbl) 175 20. Wash / ReamSPP (calculated) DRAG DOWN (kLb) CHEMICAL USAGE 21. Well Control


RATE 60 RATE ENVIRONMENTAL DATA 24. WirelineLINER 6.5'' LINER FUEL ON SITE 300 Litres 25. Other 14.0 26.0STROKE 14.0'' STROKE DAILY USAGE 400 Litres TOTALS 24.0 48.0

SCR: 250 @ CUM. FUEL USED 600 Litres DAILY MUD COSTS $1,536.60SURVEYS CUM. MUD MIXED 300 Bbls CUM. MUD COSTS $2,346.36


HOURLY OPERATIONS SUMMARY 0000 to 2400From To Description0:00 6:30 SDFN6:30 7:00 Safety meeting .Service rig7:00 8:30 Nipple up diverter line and stake down .Fence off mud pits8:30 9:30 Drill 7 7/8" PCD bit production hole from 17m to 45m9:30 11:30 Mix 100 bbls flossy salt and Pac R mud and pump to mud pits

11:30 17:30 Drill 7 7/8" PCD bit production hole from 45m to 214m17:30 18:00 Pump 25bbl sweep. Pull back 5jts drill pipe .Secure well for night18:00 0:00 SDFN

SUPERVISOR: GEOLOGIST: MUD CO: BAROID AUSTRALIA





24 HR PROGPTD


Fluid trickle from well on arrival 500m / minute. Drilling breaks at 156m,160m,243m,254m,289m,301m,307m,334m,356TEST DUE

2. ffineWEATHER AM

PM1.SAFETYAFD's: 240


Drilling ahead with production hole from 443m to TD at 570m

$17,761.26$49,429229m443mTalinga # 2

17.0m

570mWalloonsMitchell Drilling # 101


WOB(kLb) 6000 JET V(fps) TOOL LENGTH Time 1800 1. Air Rig upRPM 80 H S I PCD 0.30 Depth (m) 443 2. Casing 2.5

BIT NUMBER 1 Bit Sub 0.54 Temp (° C) 28 3. Cementing 2.0Size (in) 7.875 Collarsx10 63.14 Mud Type Polymer 4. Circ & Condition 2.0 7.5Make Hughes Xover 0.24 Density (ppg) 8.60 5. CoringType PCD ECD (ppg) 6. Drill OutIADC Code Viscosity (sec) 30 7. Drilling 8.5 18.0Serial Number 1402581 PV / YP (cp/lb) 8. Handle BHANozzles OPEN Gells (s/m) 9. LOT / FITDepth In (m) 17 API Filt. (cc) 10. Nipple up BOP'sDepth Out (m) IN Cake (/32") 11. P & ATotal Metres 426 Solids (% Vol) 12. RepairsHours 15.5 Sand (% Vol) 13. Rig ServiceROP 27.5 MBT 14. Safety 1.0 2.5Condition Out BHA LENGTH (m) 64.22 pH (strip) 15. Survey

FLOW DATA BHA WEIGHT(kLb) 5.5 Chlorides (mg/l) 16. Test BOPCIRC. RATE (gpm) 468 STRING WT (kLb) 3.7 KCL (% ) 17. Tight hole / FishingAV - DP (fpm) 185 HOOK LOAD (kLb) PHPA (ppb) 18. Tripping 1.0AV - DC (fpm) 185 WT BELOW JARS (kLb) ALC - 50 (K) 19. Wait on CementSPP (psi) DRAG UP (kLb) Circ. Vol. (Bbl) 75 20. Wash / ReamSPP (calculated) DRAG DOWN (kLb) CHEMICAL USAGE 21. Well Control


RATE 60 RATE ENVIRONMENTAL DATA 24. WirelineLINER 6.5'' LINER FUEL ON SITE 300 Litres 25. Other 12.5 38.5STROKE 14.0'' STROKE DAILY USAGE 300 Litres TOTALS 24.0 72.0

SCR: 750 @ CUM. FUEL USED 900 Litres DAILY MUD COSTS $403.26SURVEYS CUM. MUD MIXED 400 Bbls CUM. MUD COSTS $2,749.62


HOURLY OPERATIONS SUMMARY 0000 to 2400From To Description0:00 6:30 SDFN6:30 7:00 Safety meeting .Service rig7:00 7:30 Tool Box safety meeting Kick detection and procedures.7:30 8:00 Circulate back to bottom8:00 10:00 Drill7 7/8" PCD bit production hole from 214m to 244m

10:00 10:30 Mix 50bbls flossy salt and Pac R mud and circulate10:30 17:00 Drill 7 7/8" PCD bit production hole from 244m to 443m17:00 18:00 Circulate hole mix and pump 25bbl sweep. Pull back 5jts and secure well18:00 0:00 SDFN

SUPERVISOR: G Jameson GEOLOGIST: MUD CO: BAROID AUSTRALIA





24 HR PROGPTD


TEST DUE

2.fineWEATHER AM

PM1.TrippingSAFETYAFD's: 241


Drillling breaks at469m,476m,488m,506m,522m,

RDMO to Talinga #3

$17,824.76$67,253130m573mTalinga # 2

17.0m

570mWalloonsMitchell Drilling # 101


WOB(kLb) 6000 JET V(fps) #DIV/0! TOOL LENGTH Time 1200 1. Air Rig upRPM 80 H S I #DIV/0! PCD 0.30 Depth (m) 573 2. Casing 2.5

BIT NUMBER 1 Bit Sub 0.54 Temp (° C) 29 3. Cementing 2.0Size (in) 7.875 Collarsx10 63.14 Mud Type Polymer 4. Circ & Condition 2.0 9.5Make Hughes Xover 0.24 Density (ppg) 8.60 5. CoringType PCD ECD (ppg) 6. Drill OutIADC Code Viscosity (sec) 32 7. Drilling 5.5 23.5Serial Number 1402581 PV / YP (cp/lb) 8. Handle BHANozzles OPEN Gells (s/m) 9. LOT / FITDepth In (m) 17 API Filt. (cc) 10. Nipple up BOP'sDepth Out (m) IN Cake (/32") 11. P & ATotal Metres 556 Solids (% Vol) 12. RepairsHours 21 Sand (% Vol) 13. Rig ServiceROP 26.5 MBT 14. Safety 0.5 3.0Condition Out BHA LENGTH (m) 64.22 pH (strip) 15. Survey

FLOW DATA BHA WEIGHT(kLb) 5.5 Chlorides (mg/l) 16. Test BOPCIRC. RATE (gpm) 406 STRING WT (kLb) 3.1 KCL (% ) 17. Tight hole / FishingAV - DP (fpm) 160 HOOK LOAD (kLb) PHPA (ppb) 18. Tripping 2.0 3.0AV - DC (fpm) 160 WT BELOW JARS (kLb) ALC - 50 (K) 19. Wait on CementSPP (psi) DRAG UP (kLb) Circ. Vol. (Bbl) 50 20. Wash / ReamSPP (calculated) DRAG DOWN (kLb) CHEMICAL USAGE 21. Well Control

PUMP #1 PUMP #2 TORQUE ON (Amps/Rel.) Flossy Salt 6 22. Well TestRostel TORQUE OFF (Amps/Rel.) PAC-R 1 23. Wiper Trip

RATE 52 RATE ENVIRONMENTAL DATA 24. Wireline 3.0 3.0LINER 6.5'' LINER FUEL ON SITE 200 Litres 25. Other 11.0 49.5STROKE 14.0'' STROKE DAILY USAGE 400 Litres TOTALS 24.0 96.0

CUM. FUEL USED 1300 Litres DAILY MUD COSTS $209.76SURVEYS CUM. MUD MIXED 425 Bbls CUM. MUD COSTS $2,959.38


HOURLY OPERATIONS SUMMARY 0000 to 2400From To Description0:00 6:30 SDFN6:30 7:00 Safety meeting .Service rig7:00 7:30 Well trickling 1l/m. Monitor well for flow increase. OK7:30 8:00 Circulate back to bottom8:00 13:30 Drill 7 7/8" PCD production hole from 443m to TD at 573m

13:30 14:30 Circulate and clean hole. Pump 50bbl sweep.14:30 16:30 POOH with Drill String16:30 19:30 RIH with wireline logger and log hole19:30 0:00 SDFN

SUPERVISOR: G.Jameson GEOLOGIST: MUD CO: BAROID AUSTRALIA



OIL COMPANY OF AUSTRALIA

LIMITED PETROLEUM

ENGINEERING

DAILY REPORT: TALINGA CASING

WELL: Talinga 02 REPORT No.: 01 DATE: 07 October 2001 CONTRACTOR: OD&E #09 OBJECTIVE: Run 5-1/2” Production Casing 0700 STATUS: Circulating mud in casing

TIME

OPERATIONS PERFORMED PAST 24 HOURS

FROM TO06:00 06:30 Travel to rig06:30 08:00 MIRU at Talinga 0208:00 09:00 Raise mast & secure.09:00 10:00 Take on 80bbls of water, spot cat walk and pipe racks.10:00 10:30 Load casing onto racks, remove protectors and clean.10:30 11:30 Take on 90bbls of mud, R/U pump lines.11:30 12:00 R/U work floor.12:00 13:00 Strap and tally casing. Adjust order of casing on rack for appropriate

bafflespace out.

13:00 16:00 RIH casing (c/w centralisers & baskets) as follows: Mill shoe Float collar 6 x jts 5-1/2” 17ppf, N80 casing Baffle #1 (3.25” ID) 5 x jts 5-1/2” 17ppf, N80 casing Baffle #1 (3.75” ID) 13 x jts 5-1/2” 17ppf, N80 casing Baffle #3 (4.00” ID) 21 x jts 5-1/2” 17ppf, N80 casing 1 x 3m pup 5-1/2” 17ppf, N80 casing 1 x jt 5-1/2” 17ppf, N80 casing

Fill casing with gel/polymer mud from sump. Last jt tagged fill 1m from casing TD

16:00 16:30 Land casing on slips, R/D pipe racks and catwalk. Mix up KCl brine.16:30 17:00 Travel to camp.

DAILY COST $A : 58 328 CUM. COST $A : 58 328

SUPERVISOR: Greg Ottaviano BUDGET $A :

OIL COMPANY OF AUSTRALIA

LIMITED PETROLEUM

ENGINEERING

DAILY REPORT: TALINGA CASING

WELL: Talinga 02 REPORT No.: 02 DATE: 08 October 2001 CONTRACTOR: OD&E #09 OBJECTIVE: Run 5-1/2” Production Casing 0700 STATUS: Rig Released

TIME


FROM TO06:00 06:30 Travel to rig06:30 07:00 P/U on casing, remove slip spider and cut off conductor.07:00 07:30 M/U ground clamp, R/D floor.07:30 08:30 R/U circ. head, wash to bottom & circ. 1.5 x casing volume.08:30 09:00 Land casing, R/U floor and Halliburton to cement.09:00 09:30 Hold safety meeting & pressure test cementing lines to 4000psi.09:30 10:30 Pump lead 40 sx Class A c/w 35% fly ash, 9% gel mix.

Pump tail 290 sx Class A c/w 1% Halad 322.10:30 11:00 Displace with 46 bbls 2% KCl. Excellent cement returns. Bump plug.

Plug onlyheld 570psi. Held for 10 mins. Bleed pressure. Floats held.

11:00 11:30 R/D Halliburton. Release Rig.

DAILY COST $A : 22 461

CUM. COST $A : 80 789SUPERVISOR: Greg Ottaviano BUDGET $A :

PETROLEUM ENGINEERING

DAILY COMPLETION / WORKOVER REPORT

WELL: Talinga # 2 REPORT No.: 1 DATE: 11-1-02 CONTRACTOR: EWS #05 OBJECTIVE: Completion 0700 STATUS:

TIME


FROM

TO

06.00 06.30 Travel to Talinga # 2 and inspect the lease. Compressors were already dropped off at # 4, so will have to move over to # 2 when rig is set up. Mitchell drilling repwill arrive at approx 12.00 with the booster.

10.30 17.30 ODE rig # 9 arrived, hold meeting and drive to Talinga # 2 and decide the best way to rig up on the lease and also point out the wet areas, then proceed to move equipment to lease. Will pick up all equipment needed on T2 from T4. Mitchell Drilling Rep (Allen) arrived at 12.30 w/- booster unit, spot and work on getting Compressor unit over and spotted. Remove Hydrill from BOP’s and M /U to Flow “T”/ Blooie valve assy and N/U ready to put onto tubing spool onceHowco valve removed.

17.30 18.00 REMOVE Frac valve and pup joint, well gave a kick while installing BOP’s and dieddown after 3 min, unloaded roughly 30 bbls, finish N/U BOP’s and secure well.

18.00 18.30 Travel to Chinchilla.

DAILY COST $A: 14404.00CUM. COST $A: 15257.00

SUPERVISOR: Simon Gore BUDGET $A: 0




TIME


FROM

TO

06.00 06.30 Travel to Talinga # 206.30 07.00 Hold TBM and discussed Landowner issues, “G” forms signed and then

discussed program for this well, also discussed the small kick yesterday, got the Mitchell drilling hand to discuss the air operations of compressors and make sure clearsignals are issued and only the driller to give those signals.

07.00 11.00 Continue to R/U floor, Blooie line, catwalk and pipe rack, put pipe on racks andstrap. R/U compressors and associated manifold and pump lines.

11.00 11.30 Hold JSA on RIH tubing. M/U Hammer assembly and install air line and testhammer, OK.

11.30 11.45 Commence RIH w/- 2 7/8” EUE tubing and 4” Dominator hammer assembly.

11.45 15.00 Tag at 245 m, (joint 26), hit hard bridge, hammer and work till break through,then continue to RIH till we tag baffle #3 @ 274.40.

15.00 15.30 Commence milling out the baffle.15.30 17.15 Through baffle, circ clean and then RIH without circ or rotating. Tag 2nd

Baffle @433.74 m.

17.15 17.30 Break circulation and confirm hammering on baffle then stop circ and layout joint 47 w/- swivel attached and install TIW valve on joint #46 and P/U into derrick overnight. All we have to do in the morning is RIH # 46 and P/U swivel w/- # 47and commence milling baffle.

17.30 18.00 Well secure, SDFN and drive to Chinchilla.

DAILY COST $A: 8549CUM. COST $A: 24586

SUPERVISOR:

Simon Gore BUDGET $A: 70,508



WELL: Talinga # 2 REPORT No.: 3 DATE: 13-1-02 CONTRACTOR: EWS #05 OBJECTIVE: Completion 0700 STATUS: Work down joints #60 and 4m on # 61 which is TD of 567.97m

TIME


FROM

TO

06.00 06.30 Travel to Talinga # 206.30 07.00 Hold TBM and R/U Transfer pump as pit is nearly full and start to transfer

fluid tothe frac pond.

07.00 08.45 Start circulate w/- air and unload well and commence hammer operations. Bitmust be partially blocked as the pressure at pump is running at 800psi.

08.45 09.30 2nd Baffle gone, circulate clean and then RIH and tag Baffle # 1, no fillencountered on the way in. Tag Baffle at 495.7 m.

09.30 14.00 3rd Baffle finally gone, circulate clean.14.00 15.15 RIH to TD, but hit fill at 510m. Start circulate w/- air and work down joint

# 5515.15 16.15 M/U joint # 57 and work down slow going.16.15 17.00 M/U joint # 58 and work down. Need to get to joint # 61, 4m into get to

567.97m.17.00 17.30 M/U joint # 59 and work down w/- out rotating till we work the joint up.

Circulate clean and lift up power swivel and joint to crown and secure the well.

17.30 18.00 Well secure, SDFN and drive to Chinchilla.


SUPERVISOR:





TIME


FROM

TO

06.00 06.30 Travel to Talinga # 206.30 Hold TBM ,JSA # 46 and commence circ w/- air and wash down jt # 59 in

derrick.P/U jt #60 and work down.

09.30 P/U # 61 and wash down 3.8m before we tag bottom, 1.2m above recorded depth– 567 m, circ the well clean. Hold Safety meeting while circ the well clean. Total of 4 lt Envirolube used on hammer drilling operation.

09.30 11.00 Stop circ, bleed off pressure and B/O Power swivel and jt #61 then start to POOHL/O sideways.

11.00 11.30 POOH w/- Hammer assy, B/O and M/U 2nd hammer drill and test the hammer action, OK, B/O and load both hammer drills onto Pat’s truck + 1 drum of Lube togo to Moura.

11.30 12.30 M/U 2 7/8” EUE bull plug to single and RIH 10 joints 2 7/8” EUE, then M/U Gas anchor,Stator and 12’ x 3 ½” EUE pup joint, then 21 jts 2 7/8” EUE tubing. Thisputs the plug at 307.38 m . M/U hanger and land.

12.30 14.30 R/D floor and catwalk, Inspect pole and lights for loose bolts after all thehammering, N/D Mud Cross, B/O Blooie line.

14.30 15.15 Rig to run rods, (floor, piperacks and stripper assy)15.15 16.00 P/U and M/U Rotor and start to RIH w/- 7/8” ‘D’ grade rods.16.00 17.30 Tag and space out, 25 x 7/8” rods, 2x 6’ pony rods and 1 ¼”polish rod,

left 18”stickup above clamp. R/D floor and install drive head.

17.30 18.00 Rig release ,Well secure ,SDFN and drive to Chinchilla.


SUPERVISOR:


APPENDIX 2 – WELL LOCATION SURVEY PLAN

APPENDIX 3 – WIRELINE LOGS

WELL COMPLETION REPORT FOR

TALINGA 2

WIRE LINE LOG DA

TA

ADDITIONAL DATA CAN

BE OBTAINED

BY CONTACTIN

G

Geoscience Information Services Department of Natural Resources and Mines (DNRM)

[email protected] (07) 3035 5256

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