ozgamma-1 basic well completion report · 2017-08-28 · basic well completion report ozgamma-1...

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Basic Well Completion Report

OzGamma-1

South Georgina Basin Northern Territory, Australia

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Table of contents

1.1 Well Objective ................................................................................................................................................. 8

1.2 Well Outcome ................................................................................................................................................. 8

1.3 Well Summary Table ....................................................................................................................................... 9

2 Drilling .......................................................................................................................................................... 12

2.1 Drilling Summary ........................................................................................................................................... 12

2.1.1 Non-productive time summary ...................................................................................................................... 13

2.1.2 Time versus Depth Curve ............................................................................................................................. 14

2.2 Casings ......................................................................................................................................................... 15

2.3 Well Path - Directional Data .......................................................................................................................... 15

2.4 BHA Records ................................................................................................................................................ 15

2.5 Cementing Summary .................................................................................................................................... 17

2.6 Bit Records ................................................................................................................................................... 18

2.7 Drilling Fluids ................................................................................................................................................ 19

3 Well Evaluation Logs .................................................................................................................................. 19

4 Cores, Cuttings and samples .................................................................................................................... 20

4.1 Coring, cores and samples ........................................................................................................................... 20

4.2 Cuttings ......................................................................................................................................................... 21

5 Pore Pressures and Temperature ............................................................................................................. 21

5.1 Pore pressure and stress .............................................................................................................................. 21

5.2 Formation temperature ................................................................................................................................. 21

App A Directional Data – surveys ......................................................................................................................... 21

App B Well Schematics.......................................................................................................................................... 22

App C Wellhead ...................................................................................................................................................... 23

App D Well Barriers ................................................................................................................................................ 24

App E Pore Pressure and Fracture Gradient Plot ............................................................................................... 25

App F End of Well Report Drilling fluids .............................................................................................................. 26

App G End of Well Report Cementing .................................................................................................................. 42

App H Core Intervals and Preserved Samples .................................................................................................... 62

App I Cuttings and Core Descriptions ............................................................................................................... 63

Enclosures to OzGamma-1 Basic Well Completion Report (DVD) OzAlpha-1 Core images, white and UV light

Mudlog and gas recordings (pdf and LAS)

Openhole Wireline logs (pdf and LAS)

Core and Cuttings Sample Manifests


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1.1 Well Objective

The OzGamma-1 exploration well was one of five 2014 Statoil wells drilled to de-risk the unconventional play in the

Middle Cambrian carbonate deposits; the Arthur Creek Hot Shale and the Thorntonia Limestone (dolomitized) in the

south-eastern part of EP 103 in the central South Georgina Basin. Permeabilities in these formations are expected to be

too low for conventional production methods, and the most prospective wells are planned to be stimulated through

hydraulic fracturing. Oz-Gamma-1 was drilled and prepared to be one of the candidates for this stimulation. No

commercial production rates can be expected from such a short vertical well, and the aim being to prove and sample any

movable hydrocarbons. The results of testing will form the basis for future project planning, and the aquired data will be

vital imput for future well designs and completion strategies.

It was aimed to locate the well at a tectonically undisturbed location to best assess presence of hydrocarbons. Extensive

coring and wireline logging was perfomed to form basis for rock property asessment and hydrocarbon potential

evaluation.

The overall design for the OzGamma-1 well includes two casing strings. The upper section (12 ¼” hole and 9 5/8” surface

casing) was designed to be cased and cemented to surface to

- isolate the aquifers,

- achieve kick tolerance

- ensure well integrity towards underlying potential hydrocarbon bearing zones

The lower 7 7/8” drilling section included continuous coring through the basal Arthur Creek Hot Shale and the underlying

Thorntonia Limestone.

The Final objective of the drilling phase was to run 4½” production casing to TD and cement to surface tol provide

isolation for possible hydraulic stimulation and testing in the next operational phase if this well is selected for this.

1.2 Well Outcome

12 ¼” hole was drilled to 504 m MD RKB and 9 5/8” surface casing run to 502 m MD RKB and cemented to surface,

isolating the aquifers. Kick tolerance and well integrity were confirmed with a formation integrity test at 12.3 ppg EMW

77/8” production hole was then drilled to the coring point at 926 m MD RKB. 31/2” wireline retrieved coring was conducted

using 18m core barrels in the Arthur Creek Fms and 9m barrels in the Thorntonia. 100% recovery was achieved through

the lower Arthur Creek Formation and the Arthur Creek Hot Shale. As in the other wells, coring of the Thorntonia

Limestone was demanding, with broken core packing off the core barrels, resulting in 0.5 m to 3 m of low quality core

recovered per run.

The coring was terminated at 1024.8 m int the Thorntonia Formation. Conventional drilling was resumed, and it was

drilled to TD in metavolcanic basement.

Tormation tops were encountered within the uncertainties of the prognosed depths. Red Heart Dolomite was penetrated

instead of the prognosed Sun Hill Arkose.

Wireline logging was conducted before production casing was run. Cores were later slabbed and photographed in both

white and ultraviolet light, and numerous analyses performed

OzGamma-1 was temporarily suspended awaiting evaluation of the wells suitability for stimulation and testing.


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1.3 Well Summary Table

WELL SUMMARY

WELL NAME OzGamma-1 OFFSET WELLS Ross 1, Lucy Creek, Baldwin WELL CLASS Exploration

LOCATION DETAILS BASIN Southern Georgina Basin NORTHING 7554542.05 mN LICENCE EP 103 EASTING 663605.35 mE LOCATION Northern Territory ZONE 53 S SEISMIC SURVEY TEX-09-0212-107 LATITUDE 22° 06’23.0923 S SEISMIC REF. Trace 2693 / CDP 2791 / SP 184938 LONGITUDE 136° 35’9.7546 E

ELEVATIONS 263 mAHD (GL), 267.2 mAHD (KB), 4.2 m (KB)

GRID GDA’94

OPERATION DETAILS OPERATOR Statoil Australia Theta B. V. DRILLING RIG / EDA Rig # 2

PRIMARY OBJECTIVE Arthur Creek Formation ‘Hot Shale’ and Thorntonia Limestone

SPUD DATE 26/05/2014

STRUCTURE Unconventional Stratigraphic RIG RELEASE 12/06/2014 WELL TYPE Vertical TD DATE OzAlpha-1 09/05/2014 DRILLER TD 1069 m MD OPERATION DAYS 20 HOLE SUMMARY OzGamma-1 HOLE SIZE HOLE DEPTH CASING SIZE SHOE DEPTH CASING TYPE 17 ½” (445mm) 14 mMD 13 3/8” 12 mMD Conductor

12 ¼” (316mm) 504. mMD 9 5/8” (244mm) 502 mMD 36 ppf J-55 BTC

7 7/8” (200mm) 1069 mMD 4 ½” 1067 mMD 13.5 ppf L-80 Tenaris Blue

MWD-LWD & LOGGING SUMMARY OzGamma-1

RUN IN (mMD)

OUT (mMD)

TOOLS STRING REMARKS

1

1068.5 502.0

502.0 Surface

MCG-SGS-MDN-MPD-MLE-MMR MCG only

SuperCombo: spontaneous potential, gamma (to surface), spectral gamma, neutron, density, laterolog, microres Max. BHT 50°C at TD.

2a 1250 919 MCG-CMI (image log)-CXD (sonic) Image log (CMI) run separately 2b 1250 480 MCG-CMI (image log)-CXD (sonic) Sonic log (CXD) to csg shoe

CORING: OzGamma-1 RUN INTERVAL (mMDKB) RECOVERY m (%) COMMENT1-17 926 – 1024.8 98% Wireline retrieved coring

The OzGamma-1 well is located in the central part of the Southern Georgina Basin; see Figure 1 and Figure 2.


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Figure 1 Map of the Statoil licences area and position of the OzGamma-1 well location in EP103


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Figure 2 Survey certificate


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2 Drilling

All depths in this report are measured depths related to Kelly bushing height (4.2 m MD KB), if not otherwise stated.

2.1 Drilling Summary

OzGamma-1 was spudded May 26th 2014 and took a total of 20 days to complete drilling, logging and cementing. The

well was temporarily suspended awaiting potential stimulation and testing operations.

17 ½” tophole was drilled to 14 m and the 13 3/8” conductor set at 12m below ground level.

12 ¼” surface hole (14 m to 504 m)

Surface hole drilled to 46m when loss circulation was first experienced, LCM pills of various concentrations (30 – 50 ppb)

per mud engineer as referenced in the drilling fluids end of well report were pumped to treat the losses, and drilling

continued to 99m while monitoring and treating losses varying from 20 to 50 bbl/hr. At this depth, additional LCM pills

were spotted (100 bbl of 50 ppb pill) and drilling stopped to let the formation heal. Drilling resumed and complete losses

were still present, after attempt to cure. Operations continued drilling blind maintaining the hole full while pumping also

fluid from the back side, a bit trip was performed after high torque was observed and the bit got temporary stuck to 113m

.

At 113m an additional 100 bbl. LCM pill was pumped from surface and losses decreased to partial returns. One more

meter was drilled and no returns to surface were encountered again at 345 bbl. /hr. At this point, three cement plugs (20

bbl. each) were pumped from 47m and partial returns were established enabling drilling operations to be resumed with

moderate fluid loss of 20 bbl/hr to the planned section TD at 504m. The well was observed as static stable before pulling

out, and an LCM pill was spotted above the loss zone prior to pull out of the hole to run casing.

9 5/8” J55 BTC casing was run to 502 m and cementing operations took place with full returns, cement returns were

observed at surface.

7 7/8” production hole (504m – 1069m):

After drilling 4m of new formation below surface casing shoe to 508m, a FIT was successfully performed to 12.3 ppg

EMW.

Drilling resumed to the planned coring depth at 926m with no issues. A CorePro 7 7/8” coring assembly with 18m barrel

was run in hole and four successful coring runs were performed in Arthur Creek and Arthur Creek Hot Shale with full

100% recovery.

At 992m Thorntonia Formation was intersected, and based on previous experiences of coring conditions this formation a

planned trip was performed to reduce barrel length to 9m, and a more durable corehead. The same problems as in

previous wells were experienced with the core barrel frequently being unseated due to pack-offs. This is assumed to be

caused by interconnected vugs or weak zones leading to a succession of short trips with retrieved core material of

typically poor quality. After the core sample #17 was cut at 1024.8m, coring section was completed; the rat hole was

drilled with conventional drilling assembly. TD was determined to be reached 22m into the metavolcanic basement at

1069m.This allowed log coverage over the full potential reservoir interval, and also gave sufficient extra hole for potential

later stress testing and fracturing operations.


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Wireline logging was successfully performed in 2 runs per program.

4 ½” L80 Tenaris Blue production casing was run to 1067 m MD KB and cemented to surface without any issues. A

casing mandrel hanger / pack-off tool was installed and tested successfully, the BPV installed, and the BOP was nippled

down. The well head adapter was installed and nippled up and the seals were pressure tested.

The well was temporarily suspended and the rig was released June12st 2014.

A time overview for the OzGamma-1 activities can be seen in Table 2-1.

Table 2-1 Summary of operations for OzGamma-1

Section Start time End time Rig nameAU OZGAMMA-1 Move-In, Rig Up 22.May.2014 09:00 26.May.2014 11:00 EDA 2 AU OZGAMMA-1 Drilling, Surface 26.May.2014 11:00 01.Jun.2014 06:30 EDA 2 AU OZGAMMA-1 Casing, Surface 01.Jun.2014 06:30 03.Jun.2014 06:00 EDA 2 AU OZGAMMA-1 Drilling, Production 03.Jun.2014 06:00 10.Jun.2014 07:00 EDA 2 AU OZGAMMA-1 Formation evaluation, Production 10.Jun.2014 07:00 10.Jun.2014 21:45 EDA 2 AU OZGAMMA-1 Casing, Production 10.Jun.2014 21:45 11.Jun.2014 22:30 EDA 2 AU OZGAMMA-1 Rig Down 11.Jun.2014 22:30 12.Jun.2014 03:45 EDA 2

2.1.1 Non-productive time summary

A summary of the non-productive time for OzGamma-1 drilling operation can be seen in the table below.

COMPANY DESCRIPTION HOURSEDA Equipment repairs 7.5

Halliburton Pressure tested Surface lines - failed, air in cement head, 2nd failure, tighten low torques, 3rd failure, install low torque on bottom of cement head manifold

0.25

Operator Losses Encountered in surface section 75

Cement plugs pumped to re-establish circulation 13

FMC Landing joint, mandrel landing issues 3.50

Weatherford RIH with logging tools run # 2 - software failure. 0.75

Grand Total 100

Table 2-2 Summary of the non-productive time for OzGamma-1


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2.1.2 Time versus Depth Curve

The time versus depth illustration with explanatory remarks can be seen in Figure 3 below.

Figure 3 Time versus depth curve for OzGamma-1


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2.2 Casings

The overview of the run casings in OzGamma-1 is presented in the table below.

Table 2-3 Casing summary for OzGamma-1

Hole Size

Depth m MD KB

Casing Diameter

Casing Depth m MD KB Type

Test FIT/LOT Test Date

Test Result (ppg)

Test Depth m MD KB

17 1/2" 14 13 3/8” 14 Conductor

12 1/4" 504 9 5/8" 502 36 ppf J-55 BTC FIT 04.06.2014 12.3 504

7 7/8" 1069 4 1/2" 1067 13.5 ppf L-80 Tenaris Blue

2.3 Well Path - Directional Data

The well inclination was monitored with single shot surveys. See App A for the inclination measured from the single shot

surveys. The verticality analysis from the dipole sonic run shows that the well was turning towards an azimuth of 149 deg

towards TD.

2.4 BHA Records

All the bottom hole assemblies utilized in the OzGamma-1 can be viewed on the next pages.

BHA NO: 1 RUN TYPE: Drilling run DESCRIPTION: Surface, PDC bit RUN NAME: 1

String component OD in ID in Length

m Acc length m

BIT 12.250 2.750 0.41 0.41 BIT SUB 8.000 2.000 0.92 1.33 SHOCK SUB 8.125 2.500 2.92 4.25 DRILL COLLAR 8.000 3.000 9.05 13.30 STABILIZER 12.250 2.870 2.46 15.76 DRILL COLLAR 8.000 3.000 9.04 24.80 X-OVER 8.000 2.120 0.25 25.05 X-OVER 7.000 2.120 0.38 25.43 DRILL COLLAR 6.250 2.120 92.33 117.76 X-OVER 7.500 2.500 0.21 117.97


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BHA NO: 2 RUN TYPE: Drilling run DESCRIPTION: Surface, PDC bit RUN NAME: 2


m Acc length m

BIT 12.250 2.750 0.38 0.38 BIT SUB 8.000 2.000 0.92 1.30 SHOCK SUB 8.125 2.500 2.92 4.22 DRILL COLLAR 8.000 3.000 9.05 13.27 STABILIZER 12.250 2.870 2.46 15.73 DRILL COLLAR 8.000 3.000 9.04 24.77 X-OVER 8.000 2.120 0.25 25.02 X-OVER 7.000 2.120 0.38 25.40 DRILL COLLAR 6.250 2.120 92.40 117.80 X-OVER 7.500 2.500 0.30 118.10

BHA NO: 3 RUN TYPE: Drilling run DESCRIPTION: Production, PDC bit RUN NAME: 3


m Acc length m

BIT 7.875 2.250 0.26 0.26 MUD MOTOR 6.750 1.500 8.15 8.41 X-OVER 6.620 2.250 0.81 9.22 STABILIZER 7.750 2.870 1.86 11.08 X-OVER 6.500 2.250 0.88 11.96 DRILL COLLAR 6.250 2.250 101.67 113.63 JAR 6.250 2.250 9.08 122.71 X-OVER 6.250 2.500 0.30 123.01

BHA NO: 4 RUN TYPE: Coring run DESCRIPTION: Core Assy 18m barrel RUN NAME: 4


m Acc length m

BIT 3.500 0.47 0.47 CORE BARREL 4.600 8.23 8.70 STABILIZER 4.600 0.91 9.61 CORE BARREL 4.600 8.24 17.85 STABILIZER 4.600 0.91 18.76 COREBARREL 4.600 0.73 19.49 COREBARREL 4.600 0.72 20.21 DRILL COLLAR 4.600 94.08 114.29


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BHA NO: 5 RUN TYPE: Coring run DESCRIPTION: Core Assy, 9m barrels RUN NAME: 5


m Acc length

m BIT 3.500 0.46 0.46 CORE BARREL 4.600 8.24 8.70 STABILIZER 4.600 0.91 9.61 COREBARREL 4.600 0.43 10.04 COREBARREL 4.600 0.72 10.76 DRILL COLLAR 4.600 94.08 104.84

BHA NO: 6 RUN TYPE: Drilling run DESCRIPTION: Tri-cone to TD RUN NAME: 6

String component OD in ID in Length m

Acc length m

BIT 7.875 0.24 0.24 MUD MOTOR 6.750 1.500 8.16 8.40 DRILL COLLAR 6.250 2.250 9.28 17.68 DRILL COLLAR 6.250 2.250 9.29 26.97 X-OVER 0.60 27.57 STABILIZER 7.750 2.870 1.86 29.43 X-OVER 6.500 2.250 0.37 29.80 DRILL COLLAR 6.250 2.250 83.06 112.86 JAR 6.250 2.250 9.36 122.22 DRILL COLLAR 6.250 2.250 9.27 131.49 X-OVER 1.08 132.57 X-OVER 6.250 2.500 1.23 133.80 HW DRILL PIPE 55.77 189.57 X-OVER 1.21 190.78 X-OVER 0.60 191.38

2.5 Cementing Summary

Cementing of the 9 5/8” surface casing:

Pressure tested surface lines to 248PSI/5min and 2437PSI/5min - OK. Pumped 10bbls flo-check spacer at

5bbls/min/170PSI. Pumped 8bbls water at 5-2bbls/min/140PSI. Dropped bottom plug and pumped 2bbls water spacer.

Mixed and pumped 142.7bbls of 13.5ppg slurry at 4bbls/min / 125-84PSI. Dropped top plug and displaced with 124.7bbls

of water at 6-2.1bbls/min / 80- 530PSI. Bumped plug at 530PSI and P/T to 1000PSI.

Achieved cement returns to surface 97bbls into displacement, 27.7bbls cement to surface. Bleed back 0.75bbls, floats

held.

Table 2-4 Cementing summary for Oz-Gamma-1 surface casing

Fluids pumped

Type Density

ppg Volume bbl

Pump rate bbl/min

Pump pressure psi

Return Preflush Econolite 8,33 10 5,00 170,0 Full

Spacer before Fresh Water 8,33 10 5,00 150,0 Full

Lead Cement Slurry 13,50 143 4,00 84,0 Full

Spacer after Fresh Water 8,33 10 5,21 140,0 Full

Displacement Fresh Water 8,33 125 5,00 530,0 Full


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Cementing of the 4 ½” production casing:

Operation summary: Cemented 4.5" production casing. Pumped 10 bbl water spacer. Pressure tested surface lines to

250/5000psi for 5/10min. Pumped 8 bbl water spacer and dropped bottom plug. Pumped 2 bbl water spacer. Mixed and

pumped 155.6 bbl 12.5ppg lead cement slurry (346.7sx) and 39.4 bbl 14.8ppg tail cement slurry (164sx).

Dropped top plug and displaced with 51 bbl biocide water to bump plug at 820psi (15:45). Increased pressure to 1505psi

for 10 min. Bled off 1/4 bbl floats held. Good returns through out the cement job with 7bbl cement to surface, 44bbls into

displacement.

Table 2-5 Cementing summary for OzGamma-1 production casing

Fluids pumped

Type

Density ppg

Volume bbl

Pump rate bbl/min

Pump pressure psi

Return

Lead Blended Cement 12,50 156 6,00 Full

Tail Blended Cement 14,80 39 6,00 Full

2.6 Bit Records

OzGamma-1 bit records can be seen in the tables below.

Tables 2-6 Bit records for OzGamma-1 bit runs

Run no

Bit size Bit no BHA

no Bit type

IADC code

Bit manufacturer

1 12 1/4" 1 1 DSH519M NOV 2 12 1/4" 2 2 DSH616M NOV 3 7 7/8" RR 3 DSH616M NOV 4 7 7/8” Core head 1 4 DC613QL Corpro 5 7 7/8” Core head 2 5 RS910Q3S Corpro6 7 7/8" 1 6 EQH47 Halliburton

Nozzles (n/32”)

Run no

Bit size Bit no

BHA no

Serial no no x n no x n Flow area in2

1 12 1/4" 1 1 A190383 5 x 26 3 x 14 3.0440 2 12 1/4" 2 2 A192989 6 x 28 x 3.6080 3 7 7/8" RR 3 A154444 6 x 18 x 1.4920

4 7 7/8” Core head

1 4 1518 6 x 12 x 0.6630

5 7 7/8” Core head

2 5 1525 9 x 10 x 0.6910

6 7 7/8" 1 6 11744887/07 3 x 32 x 2.3570

Run no

Bit size

Pump rate

gal/min

Pump press psi

Depth in

mMD

Depth out

mMD

Form drld m

Total drld m

Drld hrs

Circ hrs

ROP m/hr

1 12 1/4" 306.0 171.0 14 114 100 100 8.5 11.8 2 12 1/4" 643.3 798.5 114 504 390 390 28.0 34.0 13.9 3 7 7/8" 452.5 1140.0 504 926 422 422 12.2 34.64 Core head 236.0 432.5 926 992.20 66.20 66.20 12.9 5.1 5 Core head 242.0 340.0 992.20 1024.80 32.60 32.60 19.3 48.0 1.7 6 7 7/8" 510.0 1100.0 1024.80 1069 44.20 44.20 6.7 10.0 6.6


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Run no

Bit size I O DC L B G OC RP

1 12 1/4" 2 2 BT S X In CT HP 2 12 1/4" 4 2 BT N X I HC TD 3 7 7/8" 1 2 WT G X I NO CP 4 Core head 1 2 LT N X I NO BHA 5 Core head 1 1 CT C X I NO TD 6 7 7/8" 1 1 CR M E I NO TD

2.7 Drilling Fluids

The OzGamma-1 well was drilled with water based mud. The water was supplied from the OzGamma water bore, and

from No. 3 station bore to fill the turkeys nest on OzGamma-1 well site. The end of well report from the drilling fluids

company can be seen in App F. A short summary is given in the table below:

Table 2-7 Drilling fluids summary

Hole Section Fluid Type Mud Weight

(ppg)

Viscosity

(sec/qt)

PV

(cp)

YP

(lb/100 ft2)

Fluid Loss

(ml/30 min) pH

Surface Spud Mud 8.7-10.2 27-68 2-13 3-28 20 8.0 – 9.0

Production LSND 8.5-9.0 35-36 10-12 15 - 20 15 9.0 – 9.5

3 Well Evaluation Logs

Openhole logging was carried out to provide information on lithology, rock properties (por/perm), fluid content,

parameters to develop stress models, selection of stress test depths and perforation intervals, and imaging of stress

directions (breakouts, drilling induced fractures) and natural fracturing.

Lithology and fluid identification tools:

Spectral-GR

High Resolution Resistivity

Density

Neutron

These logs will provide measurements for clay volume estimation, porosity and saturation calculation and identifying the

TOC level (SGR).

The following logs will provide input for stress modelling, stress direction and for the seismic tie/calibration:

Multiple P&S (waveforms) sonic tool

Image Scanning Tool combined with Multi-arm caliper for bore hole ovality to estimate the direction of the

minimum horizontal stress (σmin)


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Table 3-1 Logging runs with Weatherford’s open hole wireline tools

Run no

Logging Company

Logged Interval (m MD)

Tools Temp tool

(m MD) Remarks

1 Weatherford 1069 - 0 MCG-SGS-MDN-MPD-MLE-MMR

50 SuperCombo: spontaneous potential, gamma, spectral gamma, neutron, density, laterolog, microres

2a Weatherford 1069 - 926 MCG-CMI-CXD 50 Image (CMI) and sonic (CXD) on same tool string. CMI run first

2b Weatherford 1069 – 502.5 MCG-CMI-CXD 50 Sonic (CXD) from TD to casing shoe

4 Cores, Cuttings and samples

4.1 Coring, cores and samples

A continous coring interval of up to 120 m was planned, and thus a wireline retrieved coring system was found beneficial.

Coring commenced at the planned depth at 926 m corresponding to 50m above prognosed Arthur Creek Hot Shale. Full

core coverage of lower part of the Arthur Creek Formation, including the Hot Shale, and into Thorntonia Fm was

programmed.

High recovery and good progress was achieved throughout the lower Arthur Creek Formation and the Arthur Creek Hot

Shale. 18m core barrels were utilized, and full recovery was obtained. As planned 9m barrels were installed when the

Thorntonia Formation was reached. This was to improve handling efficiency if mostly short cores were recovered as

experienced in previous wells. The same problems appeared with numerous pack offs resulting in very short cores

brought to surface. The quality of the cores was typically poor, and for a large part mostly gravel and hockey puck shaped

slices were recovered. The core competency in this section was generally low, and only few intervals from the recovered

material were applicable for physical and chemical analysis. After 12 short core runs in theThorntonian, coring was

terminated at 1024.8m.

19 core plugs of typically 20-30cm were selected at site. These were sealed in bags immediately after cores were

brought to surface.

The whole core has been slabbed and photographed in both normal- and fluorescence light.

Core details and preserved samples are listed in App H

A rig site description of the cores is included at the end of App I


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4.2 Cuttings

Cuttings samples were collected at 10m intervals from surface to the 9-5/8” casing shoe and at 5m and 10m intervals

depending on ROP from the surface casing shoe to core point and from cessation of coring to TD. The list of cuttings

sampled and described can be seen in App I.

5 Pore Pressures and Temperature

See the update pore pressure and stress plot in parts per gallon (ppg) in App E.

5.1 Pore pressure and stress

No indications on pore pressure were given during the drilling as the well was drilled in overbalance.

The formation integrity test at the surface casing shoe was done to 12.3 ppg, equivalent 0.639 psi/ft or 1.54 g/cm3.

5.2 Formation temperature

Formation temperature was obtained whilst openhole wireline logging, and the temperature measured 50 oC at 1069 m

MD, which equals a temperature gradient of 47 oC/km.

App A Directional Data – surveys

Depth m MD RKB Inclination (deg) Survey Instrument

197 1.00 Single Shot







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App B Well Schematics

Well Name: Azm: TVD(m):Field Name: Op Area: TMD(m):County/Block: BHL: X = Y= Profile:API #: SHL: X = Y= WBS No

MD TVD SSPreset

Conductor 14 14 253 - - - 14

8.4

114 114 8.4

Logging:

Arrinthrunga 178 178 89 8.4

Fluid-

Surface Casing 504 504 -237 91 8.1 8.6

12.3 FIT/LOT: 12.3 ppg EMW

Profile:

Bit Type:

Arthur Creek 645 645 -378 98 8.5

Steamboat Sds

Surveys:

Casing/Liner:

Lwr Arthur Creek 840 840 -573 106 8.8

Begin Coring 926 926 -659 109 8.9

AC hot shale 957 957 -690 111 8.9

Thorntonia 990 990 -722 112 8.8End Coring 1 024 1 024 -757 114 8.8

Basement 1 039 1 039 -772 114 - 8.7

Production Casing 1 067 1 067 -800 115 - 8.7

- - - -

Note: Depths are referenced to RKB Cement Outside CasingNote: Not Drawn to Scale External Casing Packer

Notes / Comments:

Centralizers:1 centralizer on float shoe + float collar1 every 4 joints until surface casing point1 centralizer every 5 joints to cellar

BHAs:

- 616 PDC + Straight PDM + IBS + 6-1/4" DC- Coring Assy- Insert bit + Straight PDM + IBS + 6-1/4" DC

Logging:Mud Logging the whole intervalCoring: started 31 m above target and near Base of ThorntoniaOH Logs: Lithology + Fluid + Sonic + Image Logs

4-1/2 in 13.5# L-80 Prm CNX set at 1067 m MD/1067 m TVD.

Liner Hanger:

South Georgina Basin - Drilling Well SchematicOzGamma-1 GLE (m): 263 1 069South Georgina Basin RKB (m): 4.2 1 069

Vertical

Formations & Csg Points

Depth, mForm Temp

(F)

Pore Press (EMW)

Frac Grad

(EMW)

Planned MW

Measure DepthProgram Details

(m)13-3/8" Conductor

12-1/4" Surface

9-5/8 in 36# J-55 BTC set @ ~ 504 MD/504 TVD

Profile: Vertical

Bit Type: 12-1/4" PDC

BHA:

Rotary Assembly:- 616 PDC + Shock sub + 2 8" DC + 2 IBS + 10 6-1/4" DC

- Loss circulation starting ~ 690m. Pumped LCM- Hard rock abrasive formation

Water Zone: Surface to 50 - 100 m (1500 PPM Salinity)

none

Surveys: 197m: 1.0° - 386m: 0.75° - 498m: 1.5°

Mud:

FW: 8.4 - 9.0 ppg

Centralizers:

504

Casing:

1 every 4 joints + 3 cement baskets above losses

Cement: Class: GTOC : SurfacePumped 50% excess. 27.7bbls cement to surface

1 069

Drilling Problems:

- Losses from 46 - 57m.

7-7/8" ProductionVertical

7-7/8" PDC

1 069

674m: 1.0° - 867m: 1.0° - 1040m: 0.5°

N/A

MD:TVD

Cement: Class: GTOC: SurfaceExcess: Caliper + 15%

Potential Drilling Problems:

Notes / Comments:

Wireline retrievable coring operations from 926 m to 1024 m

FC @ 1043.3

Inhibited

Last Revision Date: 26/08/14Revised by: LDT

Mud:

Spud Mud, 8.6 ppg


OzGamma-1

Valid from Rev. no.

of 74

App C Wellhead


OzGamma-1

Valid from Rev. no.

of 74

App D Well Barriers


OzGamma-1

Valid from Rev. no.

of 74

App E Pore Pressure and Fracture Gradient Plot


OzGamma-1

Valid from Rev. no.

of 74

App F End of Well Report Drilling fluids

Operator : Statoil

Well : OzGamma 1

Spud Date : 15th June 2014

DRILLING FLUID SUMMARY

Operator:

Statoil

Well Name: OzGamma 1

Basin: Northern Territory

OPERATIONAL SUMMARY SERVICE DETAILS

Well Description: OzGamma 1

Drilling Fluid Engineers

Names:

Wojciech Czarny

Country: Australia

State: Northern Territory

Contractor: EDA Project Manager: Dr. H.F. Potgieter

Rig: 2

Well Spud Date: 26th May 2014

Well TD Date: 9th June 2014 Well Engineering Cost: TBA

Rig Release: 12th June 2014 Well Materials Cost: $48,098.12

Well Days: 18 days Well Minus Weighting Costs: $ 1,273.06

Well TD depth: 1069 metres Reconciliation Cost: $ 84,375.51

Total Meterage Drilled: 1069 metres Other services:

RT to Ground Level: 6 m Total Well Cost: TBA

Well Status Case and suspend

Operator : Statoil

Well : OzGamma 1


CONTENTS

1. Summary of Operations

2. Interval Discussions

3. Cost Analysis

4. Recommendations and lessons learnt

5. Interval Summaries

6. Mud Materials Reconciliation

7. Fluid Properties Summary

8. Fluid Volume Summary

9. Daily Mud Reports

10. Drilling Fluids Program

Operator : Statoil

Well : OzGamma 1


1. Summary Of Operations

OzGamma 1 was spud at 1230 hrs on the 26th May 2014 and drilled as a Vertical Shale Gas Exploration well within the South Georgina Basin, Northern Territory, Australia. The drilling fluids engineer was called to the location on 28th May 2014. The objectives of drilling the proposed OzGamma-1 well were to core through the basal Arthur Creek Hot Shale and the Thorntonia Limestone to assess presence of hydrocarbons, then hydraulically stimulate and test selected intervals to determine the productivity of matrix hydrocarbons. The well was located within 22°05'51.314"S Longitude / 136°35'9.494"E Latitude, respectively and in a distance of 115 km from Plenty Highway to OzGamma-1 Lease. A field analysis of water source from turkey’s nest showed pH: 8.0, Cl: 600 mg/L, TH: 400mg/L, Pf/Mf:0.1/0.3. Density: 8.4ppg. After pre-setting the 14” conductor at 4.3 m, the 12 ½” hole section was drilled to 504 m MD with 9 5/8” casing set at 502 metres. The 7 7/8” hole drilled from 502 to 926 metres followed by cutting 17th core barrels to 1024,8 metres and keep on drilling to TD at 1069 metres. The 4 ½” Casing was set at 1067 metres on 11th June 2014.

Operator : Statoil

Well : OzGamma 1


2. Interval Discussions

12 ¼” Surface Hole Section

HOLE SIZE : 12 ¼” Surface Hole

MUD TYPE : Recycled Sump Water / Gel mud

INTERVAL : 4 – 504 metres MD

CASING : 9 5/8” Surface Casing set @ 502 metres MD

The drilling fluids engineer was called to the rig site two days after the well was spudded in on 26th of May 2014. At that time 114 m of 12.1/4” interval was drilled with water and pre-hydrated Hi Vis sweeps. Total down hole losses were experienced and unsuccessful attempts were made to resume the circulation with the returns. All LCM pills were mixed by Statoil recipes at that time. Then a decision was made by the operator to pump cement plugs to cure the losses. It appeared that 3 cement plugs were set, but the results were not good. After running in hole to drill out cement at 108 m, again the circulation was lost and a 50 bbl LCM pill was mixed up with 25 ppb QuickSeal M and 25ppb Sandseal Fine. This time full circulation was achieved with seepage losses at 20 to 24 bph. Drilling of the 12 1/4” hole with PDC bit equipped with 5 x 26 and 3 x 15 jet nozzles resumed from 114 to 494 m using sump water mixed up with Maxigel on the fly and dumping returns to the sump as per Statoil request. The mud weight was maintained at 8.4 ppg and was at 8.6 ppg at TD. The expected rheology was however not achieved with Maxigel as it did not have a chance to prehydrate when a large amount of sump water was recirculated back to active system and the mud mixing pump was out of commission most of the time to prevent mixing the gel. Occasionally a Hi Vis pill made up of LCM pill were pumped to assist in hole cleaning. Nevertheless the flow rate of 750 gpm was applied to clean the hole of predominately limestone, dolomite, hard cemented sandstone and chert. At the TD of 504 m, the hole was circulated clean with a 80 bbls Hi Vis LCM pill indicating 10% over gauge. The last survey before POOH for casing was run at 498 m and showed 0.2 deg deviation. Tripping out for casing was incident free. Also running the 9 5/8” casing to 502 m was without any problems. No down hole losses were observed during cementing. The cement job was carried out as per the Halliburton/Statoil program. Good cement returns were observed at surface. The returns were diverted to the sump after dropping the top plug. Both the water spacer and cement returned to surface. The plug was bumped. A total of 124.7 bbl of drilling fluid was pumped for displacement. The shoe was set at 502 metres

Drilling Fluid

The drilling fluid used to spud the top section was just water treated on the run with Maxigel from 114 m onwards. This was as authorised by the OCR to use such a mud system after total losses were cured.

Operator : Statoil

Well : OzGamma 1


The average mud properties in the surface hole were as follows: Mud weight (ppg) 8.4 – 8.6 Funnel Viscosity (sec/qt.) 26 – 28 Plastic viscosity (cPs) 1 – 2 Yield point (lbs/100ft2) 1 – 2 pH 9.0-10.5 Mud Properties

Mud Weight

The mud weight established at 8.4 ppg for most of the drilling time and reached 8.6 ppg just before TD at 504 m.

Rheology

Funnel Viscosity represented water results at 26 sec for most of the time despite addition of Maxigel on the fly to the recircle sump water. Sufficient hole cleaning was achieved by running a flow rate of 750 gpm as no fill was recorded on trips. Downhole Losses

Total losses were experienced by the time the DFE was called to the location. A total of 520 bbls of LCM mixed up to Statoil recipes followed by setting 3 unsuccessful cement plugs and a last successful LCM pill made up by DFE. The last pill included: 70 bbl of water; 25 ppb Quickseal M and 25 ppb Sandseal Fine. Moreover, 80 bbls of LCM made up to the same recipe was pumped as a sweep before POOH for casing. It help to indicate the 10% over gauge hole. No more losses were observed during the cementing job. Total downhole losses were recorded as follows:

26 May = 4400 bbls 27 May = 1086 bbls 28 May = 140 bbls 30 May = 300 bbls 31 May = 480 bbls 1 June = 10 bbls

Total LCM pills mixed: 760 bbls

520 bbl (to the time mud engineer arrived) 240 bbl (thereafter)

Solids Control

Solids control consisted of two single bed DFE shakers. The shakers were dressed with the API 200 and API 230 and carried out water mud with success.

Operator : Statoil

Well : OzGamma 1


7 7/8” Production Hole Section

HOLE SIZE : 7 7/8” Production Hole

MUD TYPE : Water, and 5ppb Bentonite +Xanthan polymer

INTERVAL : 504– 1069 metres MD

CASING : 4 ½” Casing Set @ 1067 metres MD

A 7 7/8" PDC DSH616M (6 x 18 nozzles) bit and BHA with mud motor was RIH to tag cement at 489.8 metres MD. The cement was drilled out on a short system with sump fluid on the premix tank. Prior to performing the FIT/LOT the casing volume was displaced to clean fluid in the active tanks. Circulated even MW in and out of 8.4 ppg, and the FIT resulted in a LOT, which had an EMW of 11.4 ppg. Drilling continued through the Arrinthrunga formation. Once into the Steamboat sandstone formation (approximately at 743 metres) experienced noticeable down hole dynamic seepage of up to 40 bbl/hr. The OCR advised to hold-off on any LCM additions as they ceased from 60 to 40 then to 25 bph by the time the core point at 926 m was reached. Once the coring point was reached at 926 m, a 20 bbl high viscosity unweighted sweep was pumped, confirming the hole was clean, followed by tripping out of the hole without problems. There were 17 cores cut at the following inervals: #1 – 926 TO 944.5 m

#2 – 944.5 – 963 m

#3 – 963.0 – 981 m

#4 – 981.0 – 991.5 m

#5 – 991.5 – 992.2 m

#6 – 992.2 – 993.2 m

#7 – 993.2 – 995.4 m

#8 – 995.4 – 997.9 m

#9 – retrieve to surface

#10-998.9 – 1001.4 m

#11-1001.4 – 1002.5 m

#12-1002.5 – 1007.7 m

#13-1007.7 – 1010.2 m

#14-1010.2 – 1019.2 m

#15-1019.2 – 1020.6 m

#16-1020.6 – 1021.8 m

#17-1021.8 – 1024.8 m

After coring was completed, the core barrel was retrieved to the surface and the tri-cone

insert bit was made up to run into the hole and drill from 1024.8 m to TD of at 1069 m. Then

the hole was circulated clean and 10 bbl HiVis unweighted pill was swept followed by taking

surveys and pulling back to 690 m when a 5 bbl LCM pill mixed up with QuickSeal M was

spotted. Thereafter the BHA was pulled and the logging company called to the location.

Operator : Statoil

Well : OzGamma 1


Drilling Fluid

The fluid from the previous section was discharged, and all tanks cleaned. The tanks were refilled with recycled sump fluid weighing 8.4ppg. The sump fluid had pH of 12.5 from cement contamination, therefore Citric Acid was added to maintain the pH at 9. Before reaching the coring point the OCR requested to add 5 ppb Bentonite, therefore the premix of higher Bentonite concentration was prepared and bled to active while drilling ahead from 570 to CP of 926 m. As discussed with the OCR: no fluid loss control was implemented, but rheology increased by addition of premixed XCD polymer. PV/YP of 5/8 respectively was achieved at that time. On the last circulation before POOH for coring the whole mud system was treated with biocide, sodium sulphite and pH control additives. Also, high viscosity (YP = 20 -24 lb /100ft2) pills based on Xanthan Gum polymer were spotted across the BHA prior to retrieving the 9 m core interval. The MW was kept at 8.8 ppg as requested by Sataoil, using dumping and dilution actions using the turkey’s nest water as the sump fluid. The rheology was kept at a YP of 10 to 11 lb/100ft2 as per Statoil request, by adding Xanthan Gum polymer to each premix of water. On the last circulation before logging the whole system was treated with 0.13 ppb Idcide 20 and Sodium Sulphite to maintain SO3 at 150-180 mg/l Mud Properties

Mud Weight

The density of the drilling fluid at the start of this section was 8.7 ppg reaching a maximum of 8.9 ppg. MW was maintained at 8.7-8.8 ppg for the entire coring section and until TD.

Rheology

Funnel viscosity ranged from 31- 34 sec/qt for the majority of this section. Yield Point was maintained between 8 – 11 lb/100ft², with adequate hole cleaning observed throughout. Down hole Losses

Once the coring was completed, the tricone bit was run into the hole and while drilling to TD the down hole losses were experienced in the following intervals:

1024.8 to 1045 m @ 15 bbl per hr 1045 to 1057 m @ 12 bbl per hr 1057 to 1069 m @ 5 bbl per hr

Operator : Statoil

Well : OzGamma 1


After discussion with the Statoil Rep. both Sandseal Fine at 1.4 ppb and Quickseal M at 2 ppb were added directly to the suction pit while drilling. Once TD was reached and on tripping out of the hole, 5 bbl of LCM mixed on Quickseal M were spotted as per Statoil order.

Solids Control

Solids control consisted of two single bed DFE shakers. Drilled out with API 2x 230 1xAPI 170 maintained until TD at 1069 metres.

Post TD Section

DEPTH : 1069 metres MD

CASING : 4 ½” Casing set at 1067 metres

Weatherford Wireline rigged up for wireline logging and performed the following runs as per Statoil program: Run # 1: MDL-MMR-MSS-MPD & MDN-SGG-MEC-SP-CALI Run # 2: CMI-CXD Wireline logs were completed without any problems with seepage losses at1.3 bbl/hr. A decision was made to run casing without a wiper trip. The 4 ½” production liner was run into the hole to 1067 m. The well was circulated and the tubing hanger was landed. The Halliburton cement job was performed as programmed and displaced with 51 bbl of inhibited water (1.0 ppb Ancor 1+0.5ppb Idcide-20+ 0.5 Sodium Sulphite) mixed on Halliburton Unit as per Statoil request. Because it was mixed on Halliburton unit no NaOH was added. After the successful cement job all mud was discharged to the sump. The rig commenced rig down. The DFE was released on 12th June 2014.

Operator : Statoil

Well : OzGamma 1


3. Cost Analysis

The following table breaks down the difference in mud cost into intervals:

Surface

Hole

( 504m)

Main

Production

Hole

1389

Cost to TD Post TD

Treatment Total Well

Programmed $4,622.41 $4,436.26 $9,058.67 $965.61 $12,534.56

Actual $37,925.18 $ 9,512.06 $47437.24 $ 660.88 $48,098.12

% Difference + 720.5% + 114.4% + 423.7% -31.5% +283.7%

OzGamma 1 was drilled to TD of 1069 m for a cost of $ 47,437.24. A further $660.88

was spent on post TD. The completed well mud costs was 283,7% over the programmed

well budget.

12.1/4” Surface Hole

The surface hole was drilled for a total cost of $ 37,925.18 which was 720,5 % over budget

due to experience severe total down hole losses of 6416 bbls and 760 bbls of LCM mixed

to cure the problem.

7.7/8”Main Production Hole

The 565 meters of main production interval drilled in 7 days finished with a total cost of

$9,512.06 which was 114.4% over budget. Keeping the MW at 8.7 ppg as per Statoil Rep.

request with fresh water viscosified by Xanthan gum polymer and LCM addition contributed

to the over budget cost. Nevertheless, the rheology kept at YP 10 lbs/100 ft2 as per Statoil

with Xanthan Gum polymer provided no problems during coring and drilling.

7.7/8” Post TD Treatment

Post TD cost reached $660,88 which is 31,5% under the budget.

Operator : Statoil

Well : OzGamma 1


4. Recommendations & Lessons Learnt

1. To provide a better filter cake across the fractured formations it is advised to add 5

ppb of Prehydrated Gel to all premixes while drilling.

2. While coring it is good to keep YP at 10 lbs/100 ft2 to maintain the rheology for

hole cleaning.

3. It is highly recommended to add the sump recycled water via premix tank to

monitor more closely the amount of fluid added while drilling the top hole with

dumping at the shakers at the same time to avoid getting misleading values for

down hole losses.

4. Having the centrifuge and close system rather than dumping and dilution technique

will help to reduce the cost of drilling fluids and the amount water used for whole

drilling operation.

Statoil

Interval Summary

OzGamma 1 {Rev 2} Main Production Hole

Key Interval Data

Initial Depth (m) 504

Final Depth (m) 1069

Interval Depth (m) 565

Received Volume 0

BackLoad Volume 0

Recd From Prev Section 0

Centrifuge 0

Other SCE 0

Seepage/Lost Circulation 629

Down Hole/Behind Casing 0

Losses

Volume Reconcile

Cost Analysis

Section Materials Cost $9,512.06

Programmed Cost $4,436.26

Mud Cost Per (m) Drilled $16.84

Mud Cost Per bbl $9.25

AUDCurrency

Surface Loss (bbls) 365

Sub-Surface Loss (bbls) 629

Total Loss 994

Dilution Factor (bbl / m) 1.76

Prog Dil' Factor (bbl / m) 0

Total Built/Added 1028

Shakers 15

Other 0

Volume Accounting

Nett Volume 1028

Discharged 350

Total Volume Lost 994

Final Volume 34

Formations Drilled Through

Products

- Section SBM Cost

Total Section Cost $9,512.06

Products Utilised Unit

Size

Unit Cost Initial

Units

Units

Receive

Units

Damaged

Units

Used

Units

Remaining

Total CostReturned

To Stores

1Xanthan Gum (P) 25 Kg $190.58 60 0 0 26 34 $4,955.080

2Sand Seal (fine) 25 Kg $137.16 10 0 0 10 0 $1,371.600

3Maxigel 25 Kg $14.94 817 0 0 86 731 $1,284.840

4Quickseal (M) 18 Kg $40.50 74 0 0 17 57 $688.500

5Citric Acid 25 Kg $50.60 10 0 0 6 4 $303.600

6Idcide-20 20 Ltr $98.41 23 0 0 3 20 $295.230

7Caustic Soda 25 Kg $50.16 12 0 0 5 7 $250.800

8Sodium Sulphite 25 Kg $32.91 43 0 0 5 38 $164.550

9Defoam A 25 Kg $140.86 27 0 0 1 26 $140.860

10Soda Ash 25 Kg $19.00 35 0 0 3 32 $57.000

$9,512.06

CUMULATIVE FLUID BUILT

Whole Mud Backloaded

Premix drill water

Chemical Volume added

Sump recycled water

Seawater

Other Received on Rig

Whole Mud Received

Other Built

17

261

750

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

Statoil

Interval Summary

OzGamma 1 {Rev 2} Surface Hole

Key Interval Data

Initial Depth (m) 0

Final Depth (m) 504


Received Volume 0

BackLoad Volume 0


Centrifuge 0

Other SCE 0



Losses

Volume Reconcile

Cost Analysis

Section Materials Cost $37,925.18

Programmed Cost $4,622.41



AUDCurrency



Total Loss 6421




Shakers 5

Other 0

Volume Accounting

Nett Volume 7662

Discharged 0


Final Volume 1241


Products

- Section SBM Cost

Total Section Cost $37,925.18


Size

Unit Cost Initial

Units

Units

Receive

Units

Damaged

Units

Used

Units

Remaining

Total CostReturned

To Stores

1Sand Seal (fine) 25 Kg $137.16 60 0 0 50 10 $6,858.000

2Maxigel 25 Kg $14.94 77 1134 0 394 817 $5,886.360

3Quickseal (M) 18 Kg $40.50 30 180 0 136 74 $5,508.000

4Cellplug (Coarse) 25 lb $44.36 32 160 0 110 82 $4,879.600

5Fracseal (fine) 25 lb $39.59 60 35 0 95 0 $3,761.050

6Quickseal ( C) 18 Kg $40.50 0 210 0 90 120 $3,645.000

7Fracseal (Medium) 11.3 Kg $39.59 8 40 0 48 0 $1,900.320

8Rheoplug Ultra 8 Kg $115.50 24 0 0 13 11 $1,501.500

9Rheoplug 8 Kg $105.50 24 0 0 13 11 $1,371.500

10Barite 25 Kg $12.01 327 82 0 102 307 $1,225.020

11Defoam A 25 Kg $140.86 30 0 0 3 27 $422.580

12Citric Acid 25 Kg $50.60 16 0 0 6 10 $303.600

13Caustic Soda 25 Kg $50.16 18 0 0 6 12 $300.960


15Idcide-20 20 Ltr $98.41 24 0 0 1 23 $98.410

$37,925.18



Premix drill water


Sump recycled water

Seawater


Whole Mud Received

Other Built

70

1917

5675

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

Statoil

Interval Summary

OzGamma 1 {Rev 2} Post TD Treatment

Key Interval Data

Initial Depth (m) 1069

Final Depth (m) 1069


Received Volume 0

BackLoad Volume 0


Centrifuge 0

Other SCE 0



Losses

Volume Reconcile

Cost Analysis

Section Materials Cost $660.88

Programmed Cost $965.61



AUDCurrency



Total Loss 27




Shakers 0

Other 0

Volume Accounting

Nett Volume 60

Discharged 0


Final Volume 33


Products

- Section SBM Cost

Total Section Cost $660.88


Size

Unit Cost Initial

Units

Units

Receive

Units

Damaged

Units

Used

Units

Remaining

Total CostReturned

To Stores

1Ancor 1 (20Lt) 20 Ltr $161.64 16 0 0 2 14 $323.280

2Rheopac LV 25 Kg $107.64 28 0 0 1 27 $107.640

3Idcide-20 20 Ltr $98.41 20 0 0 1 19 $98.410

4Citric Acid 25 Kg $50.60 4 0 0 1 3 $50.600

5Barite 25 Kg $12.01 307 0 0 4 303 $48.040


$660.88



Premix drill water


Sump recycled water

Seawater


Whole Mud Received

Other Built

60

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

Mud Materials ReconciliationWell OzGamma 1 {Rev 2}

Total Weight : 41.11 Tonnes

Product Size TransferredFrom

PreviousWell

Returned To

Stores

Received from

Stores

Value

Received

from Stores

Nett

Quantity

Issued

Dam-

aged

Damaged

Value

Total

Used

Total Used

ValueTransferQuantity

Unit Price Transfer

Value

Unit Value Nett

Quantity

Issued

Starting Amount

Transferred from

another Rig

Ancor 1 (20Lt) 20 Ltr 16 $2,586.24 16 2 $323.28 14 $161.64 $2,262.96$2,586.24

Barite 25 Kg 409 $4,912.09 409 106 $1,273.06 303 $12.01 $3,639.03Sack $4,912.09

Caustic Soda 25 Kg 18 $902.88 18 11 $551.76 7 $50.16 $351.12Drum $902.88

Cellplug (Coarse) 25 lb 192 $8,517.12 192 110 $4,879.60 82 $44.36 $3,637.52$8,517.12

Citric Acid 25 Kg 16 $809.60 16 13 $657.80 3 $50.60 $151.80Sack $809.60

Defoam A 25 Kg 30 $4,225.80 30 4 $563.44 26 $140.86 $3,662.36$4,225.80

Frac Attack 18.1 Kg 80 $14,880.00 80 80 $186.00 $14,880.00$14,880.00

Fracseal (fine) 25 lb 95 $3,761.05 95 95 $3,761.05 0 $39.59 $0.00Sack $3,761.05

Fracseal (Medium) 11.3 Kg 48 $1,900.32 48 48 $1,900.32 0 $39.59 $0.00$1,900.32

Idcide-20 20 Ltr 24 $2,361.84 24 5 $492.05 19 $98.41 $1,869.79Drum $2,361.84

JK-161 LV 25 Kg 40 $4,034.40 40 40 $100.86 $4,034.40$4,034.40

KCl (fine) 25 Kg 48 $1,324.80 48 48 $27.60 $1,324.80Sack $1,324.80

Maxigel 25 Kg 1211 $18,092.34 1211 480 $7,171.20 731 $14.94 $10,921.14Sack $18,092.34

Poly Drill Sticks 1 Ea 33 $2,186.58 33 33 $66.26 $2,186.58$2,186.58

Quickseal ( C) 18 Kg 210 $8,505.00 210 90 $3,645.00 120 $40.50 $4,860.00$8,505.00

Quickseal (M) 18 Kg 210 $8,505.00 210 153 $6,196.50 57 $40.50 $2,308.50Sack $8,505.00

Rheopac LV 25 Kg 28 $3,013.92 28 1 $107.64 27 $107.64 $2,906.28$3,013.92

Rheoplug 8 Kg 24 $2,532.00 24 13 $1,371.50 11 $105.50 $1,160.50$2,532.00

Rheoplug Ultra 8 Kg 24 $2,772.00 24 13 $1,501.50 11 $115.50 $1,270.50$2,772.00

Sand Seal (fine) 25 Kg 60 $8,229.60 60 60 $8,229.60 0 $137.16 $0.00Sack $8,229.60

Soda Ash 25 Kg 35 $665.00 35 3 $57.00 32 $19.00 $608.00Sack $665.00

Sodium Sulphite 25 Kg 51 $1,678.41 51 14 $460.74 37 $32.91 $1,217.67$1,678.41

TopSpot 208 Ltr 8 $9,274.24 8 8 $1,159.28 $9,274.24$9,274.24

Xanthan Gum (P) 25 Kg 60 $11,434.80 60 26 $4,955.08 34 $190.58 $6,479.72Sack $11,434.80

Zinc Oxide 25 Kg 20 $5,368.60 20 20 $268.43 $5,368.60$5,368.60

$132,473.63 $48,098.12 $84,375.51$132,473.63

Wednesday, June 11, 2014 Page 1 of 1

Date Day Mud Type Temp. Depth Weight Vis PV YP 10Sec

10Min Cake HPHT Bent Water Oil Sand MBT pH Pm Pf Mf Cl- CA++ SO3 K+ KCl PHPA

Rheology Fluid Loss Data

API

Solids Water Phase Chemistry

K2SO46 RPM Drilled Solids

WBM Fluid Properties SummaryOzGamma 1 {Rev 2}Statoil

LSRV Salt HGS LGS

ppb % % % ppb%% % %

Glycol

%

K2CO3

28-May-14 1 Water 114 8.7 32 4 7 2 4 0.1 97.2 0.1 3 8.6 0.1 0.1 0.4 2100 80 0 0 02.63 10.0 1.5

29-May-14 2 Water 114 8.4 26 0.1 99.5 8 0.1 0.2 2000 420 00.4 0.4

Water 114 8.4 26 0.1 99.5 8.5 0.2 2000 400 00.4 0.4

Water 114 8.4 26 0.1 99.5 8.5 0.1 0.2 2000 400 00.4 0.4

30-May-14 3 Water 114 8.4 26 1 0 0.1 99.5 11 0.25 0.3 2000 440 00.4 0.4

Water 160 8.4 27 1 1 0.1 99.5 10 0.2 0.3 2100 440 00.42 0.4

Water 253 8.4 28 1 1 0.1 99.5 3 9.5 0.15 0.22 2100 420 00.42 4.5 -0.1

31-May-14 4 Water 320 8.4 28 1 1 0.1 99.5 9.2 0.24 0.3 1100 440 00.42 0.4

Water 389 8.4 26 1 1 0.1 99.5 9 0.22 0.3 1000 400 00.42 0.4

Water 494 8.6 27 1 2 0.1 98.0 5 9 0.24 0.3 1000 400 01.92 5.8 1.3

01-Jun-14 5 Water 504 8.7 26 1 1 0.1 97.2 9 0.24 0.3 1000 400 02.72 2.7

Water 504 8.6 26 1 1 0.1 98.0 9 0.24 0.28 1000 400 01.92 1.9

Water 504 8.6 26 1 1 0.1 98.0 9 0.24 0.28 1000 440 01.92 1.9

02-Jun-14 6 Water 504 8.4 27 1 2 0.0 99.5 9 0.24 0.28 700 480 00.51 0.5

Water 504 8.4 27 1 2 0.0 99.5 9 0.24 0.28 700 480 00.51 0.5

03-Jun-14 7 Water 535 8.4 27 1 2 18 0.1 0.0 99.5 13 0.4 0.5 700 400 00.51 0.5

Water 620 8.5 27 1 2 15 0.1 0.0 98.8 9 0.25 0.3 700 360 80 01.21 1.2

Water 857 8.8 30 4 7 3 5 15 0.1 0.0 96.5 5 9 0.25 0.5 700 360 180 03.53 3.5

04-Jun-14 8 Polymer mud 926 8.9 34 5 8 3 5 15 0.1 0.0 95.8 5 9 0.2 0.6 700 360 180 04.24 4.2

Polymer mud 926 8.9 35 5 8 3 5 18 0.1 0.0 95.8 5 9 0.2 6 700 360 180 04.24 4.2

Polymer mud 926 8.9 34 5 8 3 5 18 0.1 0.0 95.8 5 9 0.2 0.6 700 360 180 04.24 4.2

05-Jun-14 9 Polymer mud 937 8.9 31 5 7 2 4 20 0.1 0.0 95.8 5 9 0.2 0.6 700 360 180 04.22 4.2

Polymer mud 963 8.9 33 5 9 4 6 20 0.1 0.0 95.8 5 9 0.2 0.55 700 360 180 04.25 4.2

Polymer mud 992 8.9 33 5 9 4 6 20 0.1 0.0 95.8 5 9 0.22 0.6 700 360 180 04.25 4.2

06-Jun-14 10 Polymer mud 962 9.8 33 5 9 4 6 20 0.1 0.0 89.0 5 9 0.22 0.6 700 360 180 011.04 11.0

Polymer mud 962 8.9 33 4 10 4 6 20 0.1 0.0 95.8 5 9 0.22 0.6 700 360 180 04.25 4.2

07-Jun-14 11 Polymer mud 995 8.8 33 5 10 6 7 18 0.1 0.0 96.5 4 9 0.22 0.7 700 320 100 03.56 3.5

Polymer mud 1001 8.8 33 5 10 5 7 16 0.1 0.0 96.5 3 9 0.22 0.6 700 320 100 03.56 3.5

Polymer mud 1008 8.8 33 5 10 5 7 18 0.1 0.0 96.5 3 9 0.22 0.6 700 320 180 03.56 3.5

08-Jun-14 12 Polymer mud 1015 8.8 32 5 11 5 7 18 0.1 0.0 96.5 3 9 0.24 0.6 700 320 180 03.56 3.5

Polymer mud 1021 8.8 33 6 10 5 6 18 0.1 0.0 96.5 3 9 0.23 0.6 700 320 180 03.54 3.5

Polymer mud 1025 8.8 33 5 11 5 6 18 0.1 0.0 96.5 3 9 0.22 0.6 700 320 180 03.56 3.5

09-Jun-14 13 Polymer mud 1015 8.7 31 3 10 3 5 18 0.1 0.0 97.2 3 8.5 0.18 0.58 700 280 100 02.74 2.7

Polymer mud 1026 8.7 30 3 10 3 5 17 0.1 0.0 97.2 3 8.6 0.22 0.58 700 280 150 02.74 2.7

Polymer mud 1069 8.7 32 3 11 3 5 17 0.1 0.0 97.2 3 9 0.24 0.6 700 280 180 02.74 2.7

10-Jun-14 14 Polymer mud 1069 8.75 32 3 11 3 5 15 0.1 0.0 96.9 3 9 0.22 0.58 700 280 150 03.14 3.1

Polymer mud 1069 8.75 32 3 10 3 5 15 0.1 0.0 96.9 3 9 0.2 0.6 700 280 100 03.14 3.1

11-Jun-14 15 Polymer mud 1069 8.75 32 3 11 3 5 18 0.1 0.0 96.9 3 9 0.2 0.58 700 280 100 03.14 3.1

Displacement volumes 1069 8.4 0.1 99.5 8 900 320 180 00.5 0.5

Page 1 of 1

StatoilOPERATOR:

WELL NAME: OzGamma 1 {Rev 2}

FLUID VOLUME SUMMARY

Date Midnight

Depth

Depth Drilled

Previous

Final

Volume Received Bklded Chem Drill & Sea

Water

Sump &

Other

Daily Added

Mud in

Hole

Pits ResV Store Total Mud

VolumeShakers Disch Trip Other Lost

CircLeft in

Hole/CsgOther

Total Daily

Losses

Daily Loss/m

Cumm Losses

Cumm Loss/m

Final Volume

SUB-SURFACE

MUD LOSSES

SURFACE

Whole Mud Transfers

ADDITIONS MUD VOLUME

SeepageDsander/Desilter

Cfuge Cleaner /Dryer

Cuml Depth Drilled

Hole Volume

Total Surface Volume

Oth Vol

(Hole)

28/05/2014 114 114 0 0 0 26 220 5626 5872 55 246 0 0 301 0 0 0 0 5626 0 0 5626 49.35 5626 49.4 24600 0 0114 55 24655

29/05/2014 114 0 246 0 0 0 34 0 34 41 239 0 0 280 0 0 0 0 0 0 0 0 0 5626 49.4 28000 0 0114 55 2390

30/05/2014 253 139 280 0 0 34 1000 0 1034 104 908 0 0 1012 2 0 0 0 0 0 0 302 2.17 5928 23.4 10123000 0 0253 121 9080

31/05/2014 494 241 1012 0 0 7 600 0 607 214 922 0 0 1136 3 0 0 0 0 0 0 483 2.00 6411 13.0 11364800 0 0494 236 9220

1/06/2014 504 10 1136 0 0 3 36 0 39 241 929 0 0 1170 0 0 0 0 0 0 0 10 1.00 6421 12.7 1165100 0 0504 241 9290

2/06/2014 504 0 1165 0 0 0 27 49 76 241 300 0 700 1241 0 0 0 0 0 0 0 0 0 6421 12.7 124100 0 0504 241 10000

3/06/2014 857 353 1241 0 0 7 40 677 724 165 274 111 700 1250 10 225 0 0 0 0 0 715 2.03 7136 8.3 12504800 0 0857 196 10850

4/06/2014 926 69 1250 0 0 0 0 63 63 187 248 105 700 1240 1 0 0 0 0 0 0 73 1.06 7209 7.8 1240720 0 0926 211 10530

5/06/2014 992 66 1240 0 0 1 180 10 191 191 292 100 800 1383 1 47 0 0 0 0 0 48 0.73 7257 7.3 138300 0 0992 224 11920

6/06/2014 992 0 1383 0 0 0 0 0 0 189 229 107 800 1325 0 58 0 0 0 0 0 58 0 7315 7.4 132500 0 0992 222 11360

7/06/2014 1008 16 1325 0 0 1 20 0 21 192 227 107 800 1326 1 20 0 0 0 0 0 21 1.31 7336 7.3 132500 0 01008 225 11340

8/06/2014 1025 0 1325 0 0 1 10 0 11 228 210 98 800 1336 0 0 0 0 0 0 0 0 0 7336 7.3 133600 0 01008 228 11080

9/06/2014 1069 44 1336 0 0 7 11 0 18 202 252 21 800 1275 2 0 0 0 0 0 0 79 1.80 7415 7.0 1275770 0 01052 239 10730

10/06/2014 1069 0 1275 0 0 0 0 60 60 239 230 39 800 1308 0 0 0 0 0 0 0 27 0 7442 7.1 1308270 0 01052 239 10690

11/06/2014 1069 0 1308 0 0 0 0 0 0 36 0 0 1272 1308 0 0 0 0 0 0 0 0 0 7442 7.1 130800 0 01052 53 12720

0 0 87 2178 6485 8750 2525 20 350 0 0 5626 0 0 7442 7.07SECTION:

Figures In Red Not Able To Be Calculated Correctly Due To Division By Zero

1052 14460 0 02786 55


OzGamma-1

Valid from Rev. no.

Page 42 of 74

App G End of Well Report Cementing

OzGamma 1 Post Job Report

1. Summary of Operations

The OzGamma 1 well was cemented with a 9 5/8in surface casing and a 4 1/2in production casing.

The 9 5/8in surface casing was cemented on 02 June 2014, with 10bbls of freshwater spacer, followed by

and 10bbls of 9.3ppg Flochek spacer, 10bbls of freshwater and 143bbls of 13.5ppg primary slurry. Please

see Section 2.0 & 4.0 for more details.

The 4 1/2in production casing was cemented on 12 June 2014, with 20bbls of freshwater followed by

157bbls of 11.9ppg lead slurry and 41bbls of 14.8ppg tail slurry. Please see Section 3.0 & 5.0 for more

details.

1.1. Lessons Learnt

Jobs were performed as per planed with no HSE incidents.

1.2. Blending & Bond log Details

All jobs where pre-hydrated at rig location during the job.

Well Logging details Comments

Good / Bad Bond

Cementing Page i 13 June 2014

4. Summary, EJCS & Job Logs Surface Casing

OzGamma 1

Post Job Report

Prepared for Mark Van Diesen

SURFACE CASING 7521

Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the use of the

information given in this report

02-June-2014

Prepared by Craig Hutchens

The Future is Working Together.

Statoil

POST JOB REPORTCEMENTING/PUMPING

Well : OzGamma 1Rig: EDA 2

RIG Name & Number

EDA 2

WELL COMPONENT

FLUID SUMMARY (Refer to Lab Reports for full details)

EXCESS

%50%

%

J-55

PREVIOUS CSGOPEN HOLENEW CASING

54.5

9 5/8

(in)

SIZE

Mark Van Diesen

COUNTRY

AustraliaWELL TYPE BASE OF OPS

HES REP

Craig HutchensCUSTOMER REP

OzGamma 1WELL Name & Number

SURFACE CASING 7521JOB PURPOSE CODE CUSTOMER PO No.SALES ORDER No.

9 5/8Casing Size

BDA

Perth01 None01 Development 01 OIL

SAP#1210 BULKER

EQUIPMENTSAP# HOURSPUMPING / MIXING BULK/COMPRESSORS HOURS VEHICLES/OTHER

HOURSHOURS PERSONNEL

PERSONNEL

SAP#11261210

QTY

SAP#

ELITE #4 - FLASH

FLOAT AND CASING EQUIPMENT

11224093 KW BUNK - SB31CP

HOURS11667685

QTY

1

(ft)

1

5

QTY

12

OTHER

WELL PROFILE THREAD TOP (MD) END (MD) END (TVD)

650 1653 1653

36

GRADE

13 3/812.25

Buttress 0 1646 1646

3

9.625in Stop Collar

LENGTH

1

9.625in Basket

9.625in Centralizer

0 65(ft) (ft) (ft)

WEIGHT(ppf)

SAP# PERSONNEL HOURS SAP# PERSONNEL 561349 Michael Couch

Start Date mm/dd/yy

01-Jun-14

TECHNOLOGYWELL CATEGORY

CUSTOMER End Date mm/dd/yy

Statoil 02-Jun-14

Moomba

Craig Hutchens417716

Cementing Services Post Job Report Summary

D-Air 3000

WG-17

Econolite

Volume

Density

Yield

Water Requirement

Total Fluid Req

ABC Class 'G'

Cal Seal 60

PRO

PER

TIES

CM

TH

2OC

HEM

ICA

L

bbls

ppg

cuft/sk

gal/sk

gal/sk

sk

sk

bbls

bbls

lbs

lbs

gals

lbs

HTB

Bore

10.00

8.33

11 121 2FLUID

9

Spac

er

Flow

chec

k

Spac

er

Slur

ry

Dis

plac

eme

3 4 5 6 7 8 10

1.73

9.24

10.0

295.8

9.31 8.33 13.50 8.33 NA

10.00 10.00 141.50 124.30

NA

9.23 NA

NA

458.0 458.0

0.0

6.6 10.0 103.0 124.3 253.9

0.0

575.0 575.0

840.0

1.5 1.5

840.0

21.0

0.0

21.0

DETAIL UOM

TOTA

L

PLUGSFLOAT EQUIPMENT

9.625in Float Collar

9.625in Float Shoe 9.625in TOP Plug

9.625in BOTTOM Plug

1

12043886 LANDCRUISER - S970ASH

SUMMARY Page 2 of 8

RATE

21:15 10 5 Flowcheck Spacer

Pressure Test LowPressure Test High2483-2436

400-344

WELL Name & Number RIG Name & Number HES REP CUSTOMER REP

OzGamma 1 EDA 2 Craig Hutchens

Op-HRS-Stby

31-May-14

Called to Rig

PRESSURE

REMARKS/DETAILS

VOLUME

14:30

19:30

DATE TIME

CUSTOMER PO No.

SURFACE CASING 7521

01-Jun-14 12:30

14:00

JOB DESCRIPTION

Spot Equipment

20:00

DD-MM-YYYY HRS:MIN (bbls)

Test Kickouts

(psi)

Slurry

Bleed Off

13:20 Mix Chemicals

Bump Plug

Spacer21:18 8

124.7

20:40

22:05

21:08

Drop Top Plug

21:20

23:05

22:34

22:05

22:36

21:26

22:46

22:46

Wash Up23:55

Displace

Pressure Casing 500>Bump

Rig Down

5 Spacer142.7

6

Monitor Returns

27.7

02-Jun-14

Cementing Services Post Job Report - JOB LOGS

Mark Van DiesenJOB PURPOSE CODE SALES ORDER No.

CUSTOMER Start Date mm/dd/yy End Date mm/dd/yy

Statoil 01-Jun-14

JOB LOGS

0 0 (bpm)

4

5

0.75

1000

Rig Up & Run up Equipment

2Drop Bottom Plug21:19

Safety MeetingHead up Plugs Loaded

Standby for job14:50

Load PlugsRig Up Floor

20:20

21:05

19:50

Cement returns to surface

JOBLOGS Page 3 of 8

TYPE OF JOB (Cementing or Non-Cementing):Select the job type (Cementing or Non-Cementing)

TOTAL OPERATING TIME (hrs)Rig up/ Pumping/ Rig Down

This should be recordable incidents only

WAS THE JOB PURPOSE ACHIEVED?This will be dictated by the customer

TOTAL TIME PUMPING (hrs)Total number of hours pumping fluid on this job

NON -PRODUCTIVE RIG TIME:As a result of Halliburton cementing PSL

NUMBER OF JSA'S PERFORMED:

NUMBER OF UNPLANNED SHUTDOWNS (After starting to pump)

TYPE OF RIG (CLASSIFICATION) JOB WAS PERFORMED ON:

WAS THIS A PRIMARY CEMENT JOB (YES / NO)Primary cement job = Casing job, Liner Job, tie back

DID WE RUN WIPER PLUGS?

WAS THIS A PLUG OR SQUEEZE JOB?

WAS THIS A PRIMARY OR REMEDIAL JOB?Remedial = Repeated attempts or corrections of initial cement job

MIXING DENSITY OF JOB STAYED IN DESIGNED RANGE percentage

Density defined as +/- 0.2ppg. Calculation: Total bbls cement

mixed at designed density divided by total bbls of cement multiplied by 100

WAS AUTOMATED DENSITY CONTROL USED

JOB WAS PUMPED AT DESIGNED PUMP RATE percentage

Pump rate ranged defined as +/- bpm. Calculation : total bbls

of fluid pumped at the designed rate divided by total bbls of fluid pumped multiplied by 100

NUMBER OF REMEDIAL SQUEEZE JOBS REQUIRED - HESNumber of remedial squeeze jobs required after primary job performed by HES

NUMBER OF REMEDIAL AQUEEZE JOBS REQUIRED - COMPETITIONNumber of remedial squeeze jobs required after primary job performed by competition

NUMBER OF REMEDIAL PLUG JOBS REQUIRED - HESNumber of remedial plug jobs required after primary plug pumped by HES

ANY REASON FOR UNPLANNED SHUTDOWNS (After starting to pump)Add details in job logs

ANY REASON FOR NON-PRODUCTIVE RIG TIME (Cementing PSL responsibility):Add details in job logs

OzGamma 1 EDA 2 Craig Hutchens Mark Van Diesen


Statoil 1-Jun-14 2-Jun-14

Cementing Services Post Job Report - KPIWELL Name & Number RIG Name & Number HES REP CUSTOMER REP

YES

JOB PURPOSE CODE

SURFACE CASING 7521

KEY PERFORMANCE INDICATORS

20.0 hrs

HSE INCIDENT, ACCIDENT, INJURY: NO

SALES ORDER No. CUSTOMER PO No.

Primary

2.5 hrs

0.0 hrs

1

0

YES

0

0

0

LAND

Top & Bottom

Neither

Primary

90%

YES

90%

KPI Page 4 of 8

OzGamma 1 EDA 2 Craig Hutchens Mark Van Diesen



HSE checksheetWELL Name & Number RIG Name & Number HES REP CUSTOMER REP

SURFACE CASING 7521

SALES ORDER No. CUSTOMER PO No.JOB PURPOSE CODE

TOTAL EVACUATION AREA!! CONTACT DETAILS

Ambulance / EMS: First Aid Responders on this site (names):

Doctor:

Supervisor: Halliburton Hospital:

Fire Department Police:

Information Centre: National Poisons and Hazardous Chemicals

PERSONELL RESPONSIBILITES

Discuss individual roles and responsibilities for all of the above. Determine the level of understanding by asking questions, performing skill checks or other forms of evaluation, depending upon the hazards of the process (eg. Opening and closing of valves, the correct use of communication devices, the correct use of specific PPE such as fall

protection, and an understanding of equipment and procedures.

EMERGENCY PROCEDURES

Dion Clapp 0886756611

HSE CHECKSHEET Page 7 of 8

JSA's reviewed

Correct PPE onsite

Spacers bbls bpm

Lead slurry bbls bpm

Tail Slurry bbls bpm

Displacement bbls bpm Fluid

Top Up Job bbls

Max Rate Allowed bpm

Mix Water pH Chlorides

Surface Lines test psi

The surface line test should be at least the max allowable pressure for the job

Casing Pressure test psi

Max pressure allowed psi CHECK CASING GRADE!

Kickouts/PRV set to max pressure allowed *CRITICAL*

Expected Bump Pressure psi

Unipro / Chart recorder Functional & ON

Is the Rig Displacing? Can we monitor Pressure?

Previous Jobs Downloaded

Are lost returns expected?

Note Thickening Times (hrs) for slurries if unexpected situation arises.

Adequate mix water & displacement fluid?

Personnel injury contingency plan discussed?

Unusual pressures, collapsed casing pressure discussed?

HSE Rep: Company Rep:

SURFACE CASING 7521

HSE

Yes

OzGamma 1 EDA 2 Craig Hutchens Mark Van DiesenJOB PURPOSE CODE SALES ORDER No. CUSTOMER PO No.



PREJOB CHECKSHEETWELL Name & Number RIG Name & Number HES REP CUSTOMER REP

WELL CONDITIONS - CONTINGENCY PLAN

No

2hr43min

Yes

Yes

No

Yes

124.3

N/A

141.5

30.0

VOLUMES

6.0

4.0

8.0

TARGET RATE

N/A

Mix Water

No

No

Yes *CRITICAL*

441.0

DATA RECORDING

Yes

3520.0

500 > Bump

2500.0

8.0

PRESSURE

Bore

PREJOB CHECKSHEET Page 8 of 8

5. Summary, EJCS & Job Logs Production Casing

OzGamma 1

Post Job Report

STATOIL

POST JOB REPORTSCEMENTING/PUMPING

Well : OzGamma #1Rig: EDA #2

Prepared for Graham Blue

PRODUCTION CASING 7523

Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the use of the information

given in this report

12-June-2014

Prepared by Craig Hutchens

The Future is Working Together.

Cementing Farpack Page 1 of 10 12/06/2014

WELL COMPONENT


Start Date mm/dd/yy

11-Jun-14

0CUSTOMER PO#

PRODUCTION CASING 7523TECHNOLOGYWELL CATEGORY


STATOIL 12-Jun-14

EDA #2

Moomba01 None01 Development 01 OIL

HOURSHOURS PERSONNEL 554351Craig Hutchens

(ft) (ft) (ft)

GRADEWEIGHT(ppf)

WELL PROFILE THREAD TOP (MD) END (MD) END (TVD) LENGTH

9 5/87 7/8"

tenarus 0 3499 3499

BTC 0 1646 1646 3507 3507

13.5

1

cement basket 1

Weld A

2

4.5" float collar 1 4.5" hwe top plug 1 centralisers

4.5" hwe bottom plug stop collar1

26

PN# OTHER QTY

EQUIPMENT

11224093 KW BUNK - SB31CP

FLOAT EQUIPMENT QTY

4.5" float shoe 1

11174232

SAP# HOURSPUMPING / MIXINGElite 4 - Rasputin

FLOAT EQUIPMENT AND CASING EQUIPMENTPN# PLUGS

SAP#11261210

PN# QTY

BDA

Perth

SAP#

SAP#

BULK/COMPRESSORS HOURS

Leigh Morris

WELL Name & Number

OzGamma #1RIG Name & Number

Graham Blue

COUNTRY

Australia

SALES ORDER No.

0WELL TYPE

JOB PURPOSE CODE

BASE OF OPS

HES REP


417716

PERSONELL

VEHICLES/OTHER HOURS1210 - SY41BB

SAP# PERSONNEL HOURS SAP# PERSONNEL

EXCESS

0%25%0%

%K55

THS

PREVIOUS CSGOPEN HOLENEW CASING

36

4 1/2"

(in)

SIZE

1646(ft)

3499



Start Date mm/dd/yy

11-Jun-14

0CUSTOMER PO#

PRODUCTION CASING 7523TECHNOLOGYWELL CATEGORY


STATOIL 12-Jun-14

EDA #2

Moomba01 None01 Development 01 OILBDA

Perth

WELL Name & Number

OzGamma #1RIG Name & Number

Graham Blue

COUNTRY

Australia

SALES ORDER No.

0WELL TYPE

JOB PURPOSE CODE

BASE OF OPS

HES REP


DETAIL UOM

TOTA

L

0

255

30 10 40

178 77

26

3 1.5 5

18 8

555

110 55 165

555

0

900 900

0

122.5 24.2 147

NA

346.7 164 511

NA

14.84 6.2 NA

276

11.9 14.8 8.33 NA

155.6 39.4 51

2.52 1.34

15.14 6.5

FLUID9

Spac

er

scav

enge

r

lead tail

disp

lace

3 4 5 6 7 8 11 121 2 10

30

8.33

PRO

PER

TIES

CM

TH

2OC

HEM

ICA

L

bbls

ppg

cuft/sk

gal/sk

gal/sk

sk

sk

bbls

bbls

lb

lb

gal

lb

gallon

HTB

Drillwater

calseal

Volume

Density

Yield

Water Requirement

Total Fluid Req

ABC Class 'G'

econolite

Halad-413L

WG-17

D-Air 3000l

Calcium Chloride

Pheno Seal

lb

lb

FLUID SUMMARY (Refer to Lab Reports for full details)


RATE

13:30

5

pump spacer

rig up floor

7:00 mix tail chems

Standby for job

pump spacer14:33 2

mix lead chems

51.1

14:14

safety meeting

spot equipment

drop top plug6

pressure test surface lines 5000psi14:23 5177

5 mix pump lead cement

290

0 0 (bpm)


STATOIL 11-Jun-14

JOB LOGS

12-Jun-14

Cementing Services Post Job Report - JOB LOGS

Graham BlueJOB PURPOSE CODE SALES ORDER No.

pressure test surface lines 250psi

14:38

pump spacer14:28 8

cement returns to surface

5

15:35

rig down head

drop bottom plug

7.1

156.6

PRESSURE

(psi) REMARKS/DETAILS

DATE TIME VOLUME

DD-MM-YYYY HRS:MIN (bbls)

bleed off check floats

displace

mix pump tail cement

15:39 0.25

15:35

rig down wash up

44 bbls into displacement

4

15:47 820

13:50

14:17

14:32

10 5

16:35

15:11 40.4

16:30

rig up cmt head

pressure casing 500psi ^ bump15:47 1505

bump plug

9:30

6:30 Test Kickouts

5:30

11-Jun-14 5:15 call to rig

13:20 load plugs

14:00

WELL Name & Number RIG Name & Number HES REP CUSTOMER REP

OzGamma #1 EDA #2 Craig Hutchens

Op-HRS-Stby

0 0

Rig Up & Run up Equiptment

CUSTOMER PO#


6:00

JOB DESCRIPTION


TYPE OF JOB (Cementing or Non-Cementing):

Select the job type (Cementing or Non-Cementing)

TOTAL OPERATING TIME (hrs)

Rig up/ Pumping/ Rig Down

This should be recordable incidents only

WAS THE JOB PURPOSE ACHIEVED?

This will be dictated by the customer

TOTAL TIME PUMPING (hrs)

Total number of hours pumping fluid on this job

NON -PRODUCTIVE RIG TIME:

As a result of Halliburton cementing PSL

NUMBER OF JSA'S PERFORMED:

NUMBER OF UNPLANNED SHUTDOWNS (After starting to pump)

TYPE OF RIG(CLASSIFICATION) JOB WAS PERFORMED ON:

WAS THIS A PRIMARY CEMENT JOB (YES / NO)

Primary cement job = Casing job, Liner Job, tie back

DID WE RUN WIPER PLUGS?

WAS THIS A PLUG OR SQUEEZE JOB?

WAS THIS A PRIMARY OR REMEDIAL JOB?

Remedial = Repeated attempts or corrections of initial cement job

MIXING DENSITY OF JOB STAYED IN DESIGNED RANGE percentage

Density defined as +/- 0.2ppg. Calculation: Total bbls cement mixed at designed

density divided by total bbls of cement multiplied by 100

WAS AUTOMATED DENSITY CONTROL USED

JOB WAS PUMPED AT DESIGNED PUMP RATE percentage

Pump rate ranged defined as +/- bpm. Calculation : total bbls of fluid pumped at

LAND

Top & Bottom Plugs

Neither

Primary

98%

YES

Y

1hr 45min

0.0 hrs

1

0

YES

YES

JOB PURPOSE CODE SALES ORDER No. CUSTOMER PO#

PRODUCTION CASING 7523 0 0

KEY PERFORMANCE INDICATORS

Cementing

12.0 hrs

HSE INCIDENT, ACCIDENT, INJURY: NO

OzGamma #1 EDA #2 Craig Hutchens Graham Blue


STATOIL 11-Jun-14 12-Jun-14









the designed rate divided by total bbls of fluid pumped multiplied by 100

NUMBER OF REMEDIAL SQUEEZE JOBS REQUIRED - HES

Number of remedial squeeze jobs required after primary job performed by HES

NUMBER OF REMEDIAL AQUEEZE JOBS REQUIRED - COMPETITION

Number of remedial squeeze jobs required after primary job performed by competition

NUMBER OF REMEDIAL PLUG JOBS REQUIRED - HES

Number of remedial plug jobs required after primary plug pumped by HES

ANY REASON FOR UNPLANNED SHUTDOWNS (After starting to pump)

Add details in job logs

Add details in job logs

0

0

0

ANY REASON FOR NON-PRODUCTIVE RIG TIME (Cementing PS







HSE checksheetWELL Name & Number RIG Name & Number HES REP CUSTOMER REP

TOTAL EVACUATION AREA!! CONTACT DETAILSAmbulance / EMS: First Aid Responders on this site (names):Doctor:

Supervisor: Halliburton Hospital:

Fire Department Police:

Information Centre: National Poisons and Hazardous Chemicals

Emily Collis 0886756611

Discuss individual roles and responsibilities for all of the above. Determine the level of understanding by asking questions, performing skill checks or other forms of evaluation, depending upon the hazards of the process (eg. Opening and closing of valves, the correct use of communication devices, the correct use of specific PPE such as

fall protection, and an understanding of equipment and procedures.

EMERGENCY PROCEDURES


WELL NAME DATEJOB DETAILHES REPCOMP REP

JSA's reviewed yes

Unit checklist signed no

Correct PPE onsite yes

MSDS for chemicals available yes

VOLUMES TARGET RATESpacers 30 bbls 8 bpm

Lead slurry 155.6 bbls 5 bpm

Tail Slurry 39.4 bbls 4 bpm

Displacement 51 bbls 6 bpm

Top Up Job 0 bbls

Max Rate Allowed 8 bpm

PRESSURESurface Lines test 5000 psi

The surface line test should be at least the max allowable pressure for the job

Casing Pressure test 500^bump psi

Max pressure allowed 6832 psi

Kickouts/PRV set to max pressure allowed yes

Expected Bump Pressure 818 psi

DATA RECORDINGUnipro / Chart recorder Functional & ON yes

Displacement pressures monitorable? yes

Previous Jobs Downloaded yes

WELL CONDITIONSAny Abnormal conditions expected,any instructions?

REMEMBER - AT ANY TIME THE JOB PARAMETERS CHANGE ORTHERE IS AN UNPLANNED EVENT, STOP THE JOB ,STEP BACK AND COMMUNICATE WITH YOUR WORK PARTY THE NEW PLAN

PRE JOB OPERATIONAL CHECKLIST

OzGamma #1

11/06/2014


Craig Hutchens

Graham Blue

CHECK CASING GRADE!

*CRITICAL*

*CRITICAL*

If the rig is displacing can we monitor the pressure?



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App H Core Intervals and Preserved Samples

Core nr

Bit no

FormationInterval

from MD(m)

Interval to

MD(m)

Recovery (m)

Recovery %

Barrel length (m)

Barrel utilisation

%Barrel type

Core company

Preserv. Method

Preserved samples *

1 1Lwr Arthur Crk 926.0 944.5 18.45 100 18 102.5 Aluminium Corepro Mylar

931.46 - 931.73 943.71 - 943.98

2 1Lwr Arthur Crk / Arthur Crk Hot Shale

944.5 963.0 18.50 100 18 102.8 Aluminium Corepro Mylar953.11 - 953.50 962.30 - 962.69

3 1

Arthur Crk Hot Shale 963.0 981.0 18.00 100 18 100.0 Aluminium Corepro Mylar

967.28 - 967.51 971.48 - 971.70 975.37 - 975.69 979.21 - 979.53

4 1

Arthur Crk Hot Shale / Thorntonia

981.0 991.5 9.50 90 18 52.8 Aluminium Corepro Mylar984.18 - 984.51 988.32 - 988.52 989.22 - 989.45

5 1 Thorntonia 991.5 992.2 0.45 64 18 2.5 Aluminium Corepro6 2 Thorntonia 992.2 993.2 1.00 100 9 11.1 Aluminium Corepro Mylar 992.36 - 992.507 2 Thorntonia 993.2 995.4 2.20 100 9 24.4 Aluminium Corepro 8 2 Thorntonia 995.4 997.9 2.42 97 9 26.9 Aluminium Corepro Mylar 996.70 - 996.949 2 Thorntonia 997.9 998.9 0.93 93 9 10.3 Aluminium Corepro 10 2 Thorntonia 998.9 1001.4 2.06 82 9 22.9 Aluminium Corepro Mylar 999.91 - 1000.2011 2 Thorntonia 1001.4 1002.5 0.90 82 9 10.0 Aluminium Corepro 12 2 Thorntonia 1002.5 1004.0 1.50 100 9 16.7 Aluminium Corepro

13 2Thorntonia 1004.0 1010.2 6.06 98 9 67.3 Aluminium Corepro Mylar

1004.37 - 1004.61 1009.03 - 1009.36

14 2Thorntonia 1010.2 1019.2 9.09 101 9 101.0 Aluminium Corepro Mylar

1013.69 - 1013.99 1018.88 - 1019.20

15 2 Thorntonia 1019.2 1020.8 1.60 100 9 17.8 Aluminium Corepro 16 2 Thorntonia 1020.8 1021.8 0.95 95 9 10.6 Aluminium Corepro 17 2 Thorntonia 1021.8 1024.8 3.00 100 9 33.3 Aluminium Corepro Mylar 1024.41 - 1024.68

* Some preserved samples may be shifted 1-10 cm compared to slabbed core photographs as the cores were re-stacked in core trays after slabbing


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App I Cuttings and Core Descriptions

CUTTINGS DESCRIPTIONS:

From To % OzGamma-1 Cuttings descriptions

0 20 100 Sst: clr - wh, qtz, m - f, vit - trnsl, sb ang, mod srtd, no vis cmt, fri, gd vis por

20 30 100 Sst: clr - wh, qtz, m - f, vit - trnsl, sb ang, mod srtd, no vis cmt, fri, gd vis por

30 40 70 Sst: clr - wh, qtz, m - f, vit - trnsl, sb ang, mod srtd, clr mtrx, sil - dol cmt, fri - frm, mod - pr vis por

30 Dol: yel brn, microxln, hd, nil vis por, r bit stn, no fluor.

40 114 NO RETURNS

114 120 80 Sst: clr - wh, qtz, m - f, vit - trnsl, sb ang, mod srtd, clr mtrx, sil - dol cmt, fri - frm, tr cal, mod - pr vis por

20 Dol: wh, microxln, hd, nil vis por

120 150 90 Sst: clr - wh, qtz, vf - c, vit - trnsl, rd - sb ang, pr srtd, clr mtrx, dol cmt, rexlzd ip, fri - frm, tr cal, rr pyrmod - pr vis por

10 Dol: bl gry, microxln, hd, nil vis por

150 160 50 Sst: clr - wh - med gry, qtz, vf - c, vit - trnsl, rd - sb ang, pr srtd, clr mtrx, dol cmt, rexlzd ip, fri - frm, tr cal, rr pyrmod - pr vis por, rr bit stn, no fluor.

40 Dol: bl gry - lt yel gry, microxln, hd, nil vis por 20 Clyst: gry gn, arg, hd, dol, nil vis por 10 Slst: med gry, aren - arg, hd, dol ip, nil vis por

160 170 30 Sst: clr - wh - med gry, qtz, vf - c, vit - trnsl, rd - sb ang, pr srtd, clr mtrx, dol cmt, rexlzd ip, fri - frm, tr cal, rr pyrmod - pr vis por, rr bit stn, no fluor.

40 Dol: bl gry - lt yel gry, microxln, hd, nil vis por 20 Clyst: gry gn, arg, hd, dol, nil vis por 10 Slst: med gry, aren - arg, hd, dol ip, nil vis por

170 178 80 Dol Grst: lt yel gry - wh, microxln - fxln, hd, nil vis por

20 Slst: med gry, arg, hd, dol, nil vis por

178 190 100 Dol Grst: lt yel gry - wh, microxln - fxln, hd, nil vis por


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From To % OzGamma-1 Cuttings descriptions 190 200 60 Dol: dol grst ip, lt yel gry - wh, microxln - fxln, hd, nil vis por

30 Clyst: gry gn, arg, hd, dol, nil vis por 10 Slst: med gry-brn rd, aren - arg, hd, dol, nil vis por

200 210 70 Dol: dol grst ip, lt yel gry - wh, microxln - fxln, hd, nil vis por 20 Clyst: gry gn, arg, hd, dol, nil vis por 10 Slst: med gry-brn rd, aren - arg, hd, dol, nil vis por

210 220 70 Dol: dol grst ip, lt yel gry - wh, microxln - fxln, hd, nil vis por 20 Clyst: gry gn, arg, hd, dol, nil vis por 10 Slst: med gry-brn rd, aren - arg, hd, dol, nil vis por

220 230 50 Clyst: gry gn, arg, hd, dol, nil vis por 20 Slst: med gry-brn rd, aren - arg, hd, dol, nil vis por 30 Dol: dol grst ip, lt yel gry - wh, microxln - fxln, hd, nil vis por

230 240 40 Clyst: gry gn, arg, hd, dol, nil vis por 30 Slst: med gry-brn rd, aren - arg, hd, dol, nil vis por 30 Dol: dol grst ip, lt yel gry - wh, microxln - fxln, hd, nil vis por

240 250 50 Dol: dol grst ip, lt yel gry - wh, microxln - fxln, hd, nil vis por 30 Slst: med gry-brn rd, aren - arg, hd, dol, nil vis por 20 Clyst: gry gn, arg, hd, dol, nil vis por



280 290 80 Dol: wh-lt olv gry, microxln, hd, nil vis por 20 Slst: med gry-brn rd, aren, mic, hd, dol, nil vis por





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From To % OzGamma-1 Cuttings descriptions 320 330 70 Dol: wh-lt olv gry, microxln, hd, nil vis por

30 Slst: med gry-brn rd, aren, mic, hd, dol, nil vis por

330 340 60 Dol: dol grst ip, med gry-lt olv gry-wh, microxln, hd, nil vis por

30 Slst: med gry-brn rd, aren , mic ip, hd, dol, nil vis por 10 Clyst: gry gn, arg, hd, dol, nil vis por


20 Clyst: gry gn, arg, hd, dol, nil vis por


10 Clyst: gry gn, arg, hd, dol, nil vis por

360 370 40 Slst: med gry-brn rd, aren, mic ip, hd, dol, nil vis por 40 Clyst: gry gn, arg, hd, dol, nil vis por

20 Dol: dol grst ip, med gry-lt olv gry-wh, microxln, hd, nil vis por


30 Slst: med gry-brn rd, aren, mic ip, hd, dol, nil vis por 10 Clyst: gry gn, arg, hd, dol, nil vis por


30 Slst: med gry-brn rd, aren, mic ip, hd, dol, nil vis por 20 Clyst: gry gn, arg, hd, dol, nil vis por


40 Slst: med gry-brn rd, aren, mic ip, hd, dol, nil vis por


40 Clyst: gry gn, arg, hd, dol, nil vis por 10 Slst: med gry-brn rd, aren, mic ip, hd, dol, nil vis por


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From To % OzGamma-1 Cuttings descriptions 410 420 40 Ls: lt gry-wh, microxln-fxln, hd, nil vis por

40 Dol: med-lt gry, microxln, hd, nil vis por 20 Slst: med gry, arg, mic, hd, dol, nil vis por

420 430 30 Ls: lt gry-wh, microxln-fxln, hd, nil vis por 30 Dol: med-lt gry, microxln, hd, nil vis por 20 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por 20 Clyst: gry gn, arg, hd, dol, nil vis por

430 440 40 Ls: lt gry-wh, microxln-fxln, hd, nil vis por 30 Dol: med-lt gry, microxln, hd, nil vis por 30 Clyst: gry gn, arg, hd, dol, nil vis por

440 450 40 Ls: lt gry-wh, fxln, hd, nil vis por 30 Dol: med-lt gry, microxln, hd, nil vis por 30 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por

450 460 aa

460 470 30 Ls: lt gry-wh-or yel, microxln-fxln, hd, nil vis por 30 Dol: med-lt gry, microxln, hd, nil vis por 30 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por 10 Clyst: gry gn, arg, hd, dol, nil vis por

470 480 40 Ls: lt gry-wh-or yel, microxln-fxln, hd, nil vis por 30 Dol: med-lt gry, microxln, hd, nil vis por 20 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por 10 Clyst: gry gn, arg, hd, dol, nil vis por

480 490 50 Dol: med-lt gry-or yel, microxln, hd, nil vis por 30 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por 20 Ls: lt gry-wh-or yel, microxln-fxln, hd, nil vis por

490 500 50 Dol: med-lt gry-or yel, microxln, hd, nil vis por 30 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por 20 Ls: lt gry-wh-or yel, microxln-fxln, hd, nil vis por

500 504 40 Dol: med-lt gry-or yel, microxln, hd, nil vis por 30 Ls: lt gry-wh-or yel, microxln-fxln, hd, nil vis por. 30 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por


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From To % OzGamma-1 Cuttings descriptions 504 510 50 Dol: med-lt gry-or yel, microxln, hd, nil vis por

30 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por 20 Clyst: gry gn, arg, hd, dol

510 515 40 Dol: med-lt gry-or yel, microxln, hd, nil vis por 30 Ls: wh-lt yel brn, fxln,hd, nil vis por 30 Slst: brn rd, arg-aren, mic, hd, dol, nil vis por

515 520 50 Ls: wh-lt yel brn, fxln,hd, nil vis por 30 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por 20 Dol med-lt gry-or yel, microxln, hd, nil vis por

520 530 70 Dol: lt gry-wh, microxln, hd, nil vis por 30 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por



550 560 50 Dol: dol grst ip, lt gry-wh, fxln, hd, nil vis por 50 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por

560 570 40 Ls: grst ip, wh-lt gry, micro-fxln, hd, nil vis por 30 Dol: lt gry-olv gry, microxln, v hd, nil vis por 20 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por 10 Cht: olv brn-yel brn, crpxln, v hd

570 580 40 Ls: grst ip, wh-lt gry, micro-fxln, hd, nil vis por 40 Dol: lt gry-olv gry, microxln, v hd, nil vis por 20 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por

580 590 50 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por 30 Ls: grst ip, wh-lt gry, micro-fxln, hd, nil vis por 20 Dol: lt gry-olv gry, microxln, v hd, nil vis por

590 600 40 Ls: wh-lt gry, micro-fxln, hd, nil vis por 40 Dol: lt gry-olv gry, microxln, v hd, nil vis por 20 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por


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From To % OzGamma-1 Cuttings descriptions 600 610 60 Ls:

30 Dol: lt gry-olv gry, microxln, v hd, nil vis por 10 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por

610 620 50 Ls: wh-lt gry, micro-fxln, hd, nil vis por 40 Dol: lt gry-olv gry, microxln, v hd, nil vis por 10 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por

620 630 50 Dol: lt gry-olv gry, microxln, v hd, nil vis por 40 Ls: wh-lt gry, fxln, hd, v pr vis intxln por 10 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por

630 640 40 Dol: lt gry-olv gry, microxln, v hd, nil vis por 40 Ls: wh-lt gry, fxln, hd, nil vis por 20 Slst: med gry-brn rd, arg-aren, mic, hd, dol, nil vis por

640 650 40 Dol Sst: wh-lt gry, vf-ftrnsl, rd, wl srt, dol cmt, hd, rr glauc grnil vis por

30 Dol: lt gry-olv gry-yel olv gry, microxln, v hd, nil vis por 20 Ls: wh-lt olv gry, fxln, hd, nil vis por 10 Cht: yel brn, crpxln, v hd

650 660 40 Dol Sst: wh-lt gry, vf-ftrnsl, rd, wl srt, dol cmt, hd, rr glauc grnil vis por

30 Ls: wh-lt gry, fxln, hd, rr calc xl, nil vis por 30 Dol: lt gry-olv gry-yel olv gry, microxln, v hd, nil vis por

660 670 60 Dol: lt gry-olv gry-yel olv gry, microxln, v hd, nil vis por

40 Dol Sst: lt gry-dk yel brn, vf-mtrnsl, sbang, mod srt, dol cmt, hd, nil vis por, rr bit stn, no fluor

670 680 80 Dol: wh-lt gry, microxln, v hd, nil vis por

20 Dol Sst: lt gry-dk yel brn, vf-m, trnsl, sbang, mod srt, dol cmt, hd, nil vis por, rr bit stn, no fluor

680 690 80 Dol: wh, microxln, v hd, nil vis por

20 Dol Sst: lt gry-wh, vf-f, op, rd, wl srt, dol cmt, hd, nil vis por, rr bit stn, no fluor

690 700 80 Dol: wh, microxln, v hd, nil vis por

20 Dol Sst: lt gry-wh, vf-f, op, rd, wl srt, dol cmt, hd, nil vis por


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From To % OzGamma-1 Cuttings descriptions 700 710 60 Dol: wh, microxln, v hd, nil vis por

40 Dol Sst: lt gry-wh, vf-f, op, rd, wl srt, dol cmt, hd, nil vis por

710 720 100 Dol Sst: lt gry-wh, vf-f, op, rd, wl srt, dol cmt, hd, nil vis por

720 730 80 Dol Sst: med gry, f, op, rd, wl srt, dol cmt, hd, nil vis por 20 Dol: yel brn, fxln, rexlzd suc gr str vis,v hd, nil vis por

730 740 60 Dol Sst: med gry, f, op, rd, wl srt, dol cmt, hd, nil vis por 30 Dol: lt gry, microxln, v hd, nil vis por 10 Dol: yel brn, fxln, rexlzd suc gr str vis,v hd, nil vis por

740 750 60 Ls: med gry, vf-fxln,v hd, nil vis por 30 Dol: lt olv gry, microxln, v hd, nil vis por 10 Dol Sst: med gry-or yel, f, op, rd, wl srt, dol cmt, hd, nil vis por

750 760 70 Ls: med gry, vf-fxln,v hd, nil vis por 30 Dol: lt olv gry, microxln, v hd, nil vis por

760 770 40 Ls: med gry, vfxln,v hd, nil vis por 30 Dol Sst: med gry-or yel, f, op, rd, wl srt, dol cmt, hd, nil vis por 30 Dol: lt olv gry, microxln, v hd, nil vis por

770 780 100 Calc Sst:

lt gry, vf-fxln, op, ang-sbang, mod srt, calc cmt, hd, v pr intrxln por

780 790 90 Calc Sst: lt gry, vf-fxln, calc cmt, hd, v pr intrxln por

10 Dol: lt olv gry, microxln, v hd, nil vis por

790 800 60 Calc Sst: lt gry, vf-fxln, calc cmt, hd, nil vis por

40 Dol: med olv gry, microxln, v hd, nil vis por

800 810 40 Dol: med olv gry, microxln, v hd, nil vis por 30 Ls: med yel brn, fxln,hd, nil vis por

20 Calc Sst: lt gry, vf-fxln, calc cmt, hd, nil vis por

10 Cht: yel brn, crpxln, v hd

810 815 40 Dol: med olv gry, microxln, v hd, nil vis por 30 Ls: med yel brn, fxln, hd, nil vis por




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From To % OzGamma-1 Cuttings descriptions 815 820 40 Dol: med olv gry, microxln, v hd, nil vis por

40 Ls: med yel brn, fxln, hd, nil vis por



820 825 60 Dol: med olv gry, microxln, r rexlzd gr st vis, v hd, nil vis por 40 Ls: med yel brn, fxln, hd, nil vis por

825 830 50 Dol: med olv gry, microxln, r rexlzd gr st vis, v hd, nil vis por 50 Ls: med yel brn, fxln, hd, nil vis por

830 835 70 Calc Sst:

30 Dol: med olv gry, microxln, r rexlzd gr st vis, v hd, nil vis por

835 840 80 Dol: med olv gry, microxln, r rexlzd gr st vis, v hd, nil vis por


840 850 100 Ls: med gry-lt brn gry, micro-fxln, hd, nil vis por

840 860 70 Ls: med gry-lt brn gry, micro-fxln, hd, nil vis por

30 Dol: med bl gry, microxln, v hd, nil vis por

860 870 60 Ls: med gry-lt brn gry, micro-fxln, hd, nil vis por 40 Dol: med bl gry, microxln, v hd, nil vis por

870 880 60 Dol: med bl gry, microxln, r dk lam vis, v hd, nil vis por 40 Ls: med gry-lt brn gry, micro-fxln, hd, nil vis por

889 890 50 Dol: med bl gry, microxln, r dk lam vis, v hd, nil vis por 30 Ls: med gry-lt brn gry, micro-fxln, hd, nil vis por 20 Slst: dk gry, arg, hd, nil vis por

890 900 50 Dol: med bl gry, microxln, r dk lam vis, v hd, nil vis por 30 Ls: med gry-lt brn gry, micro-fxln, hd, nil vis por 20 Slst: dk gry, arg, hd, nil vis por

900 910 40 Ls: med gry-lt brn gry, micro-fxln, hd, nil vis por 30 Dol: med bl gry, microxln, r dk lam vis, v hd, nil vis por 30 Slst: dk gry, arg, hd, nil vis por

910 920 60 Ls: med gry-lt brn gry, micro-fxln, hd, nil vis por 30 Dol: med bl gry, microxln, r dk lam vis, v hd, nil vis por 10 Slst: dk gry, arg, hd, nil vis por


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From To % OzGamma-1 Cuttings descriptions 920 926 60 Ls: med gry-lt brn gry, micro-fxln, hd, nil vis por

30 Dol: med bl gry, microxln, r dk lam vis, v hd, nil vis por 10 Slst: dk gry, arg, hd, nil vis por

CORED INTERVAL 926m - 1024.8m SEE BELOW

1030 1040 60 Dol: dk gry-dk olv brn, micro-vfxln, v hd, nil vis por 30 Ls: lt-med gry, microxlnv hd, nil vis por 10 Clyst: bl gry, arg,hd

1040 1050 100 Meta Volc:

blk-dk gry, wh-gry, f-mxln, v hd, cmn biot, cmn pyr, cmn hrnblnd, r fspr, r epidote, r musc, r qtz, rr calc

1050 1060 100 Meta Volc:


1060 1069 100 Meta Volc:


CORE DESCRIPTIONS:

From To Lith. OzGamma-1 Corechips descriptions 926 926.91 Ls: dk olv gry, micro-fxln, v hd, ab sb mm lam, nil vis por, n/s.

926.91 927.71 Ls: lt olv gry, microxln, hd, sps sb mm styl, rr slty lam, nil vis por, n/s.

927.71 931.49 Ls:

med bl gry, fxln, v hd, ab sb mm lam, rr cm dol slt lam, nil vis por, sps pch yel gn bl fluor, v slw wk wh bld cut, v slw wk wh blmg crsh cut.

931.49 934.11 Ls: dk olv gry, micro-fxln, v hd, ab sb mm lam, nil vis por, n/s.

934.11 935.58 Ls: dk gry, micro-vfxln, v hd, ab sb mm lam, nil vis por, n/s.

935.58 937.55 Ls: med brn gry, vfxln, hd, rr sft sed def , nil vis por, n/s.

937.55 938.46 Ls:

lt olv gry, mxln, v hd, rr sb mm lam, rr cm cht nod, nil vis por, sps pch yel gn bl fluor, mod wh bld cut, v thn wh res rng, fst mod wh blmg crsh cut, wk wh res rng.

938.46 941.31 Ls: drk olv gry, vf-mxln, v hd, ab sb mm lam, com sb cm calc lam, r cm dk ls lam, n/s.


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From To Lith. OzGamma-1 Corechips descriptions 941.31 945.89 Ls: med brn gry, vfxln, hd, rr sft sed def , nil vis por, n/s.

945.89 947.47 Ls: drk olv gry, vf-mxln, v hd, ab sb mm lam, cmn sb cm calc lam, r cm dk ls lam, nil vis por, n/s.

947.47 948.71 Ls: med olv gry, fxln, v hd, r mm pbl, r sft sed def, nil vis por, n/s.

948.71 951.81 Ls: med gry brn, micro-vfxln, v hd, ab sb mm lam, rr sft sed def, nil vis por, n/s.

951.81 957.79 Ls: Lime mdst, med olv gry gn, micro-mxln, v hd, sps mm-cm d-ang pbl, r sft sed def, nil vis por, n/s.



965.85 971.2 calc Slst,

med olv brn- dk gry, v calc. micromicahd-v hdab sb mm lam, rr sft sed def, nil vis por, com sps pchy dl yel fluor, wk slo blm dl grn yel cut, tr thn dl bl film res.

971.2 974.5 ls dk gry, olv gry, vf-f xln, tr micromic, v hd, ab sb mm lam,n/s.

974.5 975 calc Slst,

med olv brn- dk gry, r 1cm dk gry chrt bands, v hd, ab sb mm lam,n/s.

975 976.65 calc Slst,

med gry-olv gry, com micromic, tr-com calc,v hd, ab sb mm lam,com sps pchy dl yel fluor, wk slo blm dl grn yel cut, tr thn bl film res.

976.65 979.2 Slst,

med-dk gry, dk brn gry, com micromic, tr-com calc,v hd, ab sb mm lam,com sps pchy dl yel fluor, wk slo blm dl grn yel cut, tr thn bl film res.

979.2 980.95 Slst,

med-dk gry, dk brn gry, com micromic, tr-com calc,v hd, ab sb mm lam,com sps pchy dl yel fluor, wk slo blm dl grn yel cut, tr thn bl film res.


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From To Lith. OzGamma-1 Corechips descriptions

980.95 984.5 dol

Sltst,

med-dk gry, dk brn gry, com micromic, tr-com calc,v hdab sb mm lam,com sps pchy dl yel fluor, wk slo blm dl grn yel cut, tr thn bl film res.

984.5 988.5 dol

Sltst,

dk gry brn - olv blk, com micromic, tr-com calc,hd, ab sb mm lam,com sps pchy dl yel fluor, wk slo blm dl grn yel cut, tr thn bl film res.

988.5 989.6 Sltst,

olv blk, com micromic, tr-com calc,hd-v hd, ab sb mm lam,com sps pchy dl yel fluor, wk slo blm dl grn yel cut, tr thn bl film res.

989.6 992.2 Dol

lt gry, med gry, c - microxln, tr calc, tr sft bit fil vugs, hd-v hd, rr sb mm styl, mnr - cmn mm - cm vugs, nil to v vug por, strg pet od, pchy dul yel-gold fluor, v slo cut.

991.5 992.2 Dol

lt gry brn, lt gry, f - microxln, rexld, tr calc, tr sft bit fil vugs, hd-v hd, rr sb mm styl, mnr - com mm vugs, nil to v vug por, wk pet od, pchy dul yel-gold fluor, v slo cut.

992.2 993.55 Dol,

lt gry, lt brn gry, med gry, m -microxln, r calc, r bit fil vugs, hd, mnr - com mm vugs anhy fld, rr sb mm styl,nil to v vug por, pchy dul yel-gold fluor, no cut.

993.55 995.63 Dol,

lt gry, lt brn gry, med gry, m -microxln, cmn glauc, hd, com mm vugs anhy fld, rr cm sltst lam, mnr glauc, rr shl frag, rr styl,nil to v vug por, pchy dul yel-gold fluor, no cut.

995.63 997.51 Dol, med-dk gry, f-microxln, hd, ab mm-cm styl, cmn cm vugs anhy fld, mod vug por, n/s.

997.51 997.82 Dol, lt gry, lt brn gry, micro-vfxln, hd, com mm vugs anhy fld, rr styl,rr pchy dul yel-gold fluor, no cut.



998.9 1003.5 Dol, wh-lt brn gry, microxln, v hd, rr styl, rr mm-vug anhy fld, v pr vis por, n/s.


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From To Lith. OzGamma-1 Corechips descriptions

1000.96 1003.48 Dol, wh-lt brn gry, microxln,v hd, rr styl, rr mm-vug anhy fld, v pr vis por,tr v dul yel ring/film res.

1003.48 1003.5 Dol, wh-lt brn gry, microxln,v hd, rr styl, rr mm-vug anhy fld, pr iis por, n/s.

1003.5 1003.65 Dol, dk gry - blk brn -blk, f-microxln, hd-vh, mm-sb mm lam, n/s.

1003.65 1003.69 Sltst, med gry, blk, mod hd, com micromic, tr euhed cryst pyr, tr embdd c-med dol grns, lam, nil vis por, n/s.

1003.69 1003.9 Dol, wh gry -lt gry, f-microxln, hd-v hd, rr styl, rr mm-vug anhy/calc fld, nil vis por, n/s.

1003.9 1003.91 Sltst, blk, mod hd, micromic, n/s.

1003.91 1010.06 Dol, wh gry -lt gry, f-mcoxln, v hd, nil vis por, n/s.

1007.7 1010.2 Dol, wh gry -lt gry, f-mcoxln, v hd, nil vis por, n/s.

1013.4 1017.28 Dol: dk olv gry, micro-mxln, v hd, cmn styl, r stylo nod bd, r cm vugs anhy fld, pr vug por, n/s.

1017.28 1020.13 Dol: med olv gry, mxln, hd, cmn styl, r stylo nod bd, ab cm vugs anhy fld, n/s.

1020.13 1024.2 Dol: dk-med olv gry, micro-mxln, v hd, ab stylo nod bd, cmn cm vugs anhy fld, r styl, mod vug por, n/s.

1024.2 1024.8 Ls: dk gry, micro-vfxln, v hd, cmn sb vrt cm fracs calc fld, nil vis por, n/s.

1024.8 1030 Ls: dk gry-dk olv brn, micro-vfxln, v hd, nil vis por, n/s.

v hd, nil vis por, n/s.

ozgamma-1 basic well completion report · 2017-08-28 · basic well completion report ozgamma-1...

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