annual report of south australian cooper basin joint venture...

Santos Ltd ABN 80 007 550 923 SACBJV Operations

2012 Annual Report of

South Australian Cooper Basin Joint Venture Operations

This report has been prepared in accordance with the requirements of the Petroleum and Geothermal Energy Act 2000 and the Petroleum and Geothermal Energy Regulations 2000 and covers all of the operations conducted for the SA Cooper Basin Joint Venture by Santos Ltd during the period January 1 – December 31 2012.

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ANNUAL REPORT - 2012

INDEX 1. INTRODUCTION..................................................................................................................................................... 5

2. EXECUTIVE SUMMARY ....................................................................................................................................... 5

3. SUMMARY OF REGULATED ACTIVITIES ........................................................................................................ 6

4. PERFORMANCE ..................................................................................................................................................... 6 4.1 PROVISION OF DATA .......................................................................................................................................... 6

4.2 PIPELINE MANAGEMENT................................................................................................................................... 6

4.3 QUARTERLY PERFORMANCE MEETINGS ...................................................................................................... 7

5. INCIDENTS .............................................................................................................................................................. 7

5.1 REPORTABLE INCIDENTS ............................................................................................................................... 8

5.2 REPORTABLE ENVIRONMENTAL INCIDENTS ........................................................................................... 9

5.2.1 SUMMARY OF ACTIONS TO PREVENT RECURRENCE ...................................................................... 10

5.3 NOTIFIABLE WORK RELATED INJURY OR DANGEROUS OCCURRENCE ...................................... 10 6. MONITORING/STUDIES...................................................................................................................................... 10

6.1 MONITORING ..................................................................................................................................................... 10

6.1.1 SEO Compliance ....................................................................................................................................... 10 6.1.2 SEO Review ............................................................................................................................................... 11 6.1.3 Buried Piping Risk Assessment ........................................................................................................... 11 6.1.4 Satellite Upgrades .................................................................................................................................... 11

6.2 STUDIES.............................................................................................................................................................. 12

6.2.1 Produced Formation Water Management Strategy ......................................................................... 12 6.2.2 Sludge Management ................................................................................................................................ 12 6.2.3 Waste Management.................................................................................................................................. 12 6.2.4 Fauna Refuge and Release System (FRRS) ...................................................................................... 12

7. MANAGEMENT SYSTEM ................................................................................................................................... 13

7.1 ENVIRONMENT, HEALTH & SAFETY MANAGEMENT SYSTEM (EHSMS) ......................................... 13

7.1.1 Management Standards .......................................................................................................................... 13 7.1.2 Hazard Standards ..................................................................................................................................... 14 7.1.3 Training and Awareness ......................................................................................................................... 15

7.2 AUDITS, ASSESSMENTS AND REVIEW PROCESSES ........................................................................... 15

7.2.1 Performance Based Audits .................................................................................................................... 16 7.2.3 Pipelines ......................................................................................................................................................... 16 7.2.4 Training .......................................................................................................................................................... 17 7.2.5 Sustainability Report ...................................................................................................................................... 17

8. REASONABLY FORESEEABLE THREATS ...................................................................................................... 17

8.1 RISK ASSESSMENT ........................................................................................................................................... 18

8.1.1 WHOLE OF PLANT RISK ASSESSMENT (WOPRA) AND FORMAL SAFETY ASSESSMENT (FSA) ........................................................................................................................................................................... 18

8.1.2 PIPELINES ....................................................................................................................................................... 18

8.1.3 SIGNIFICANT HAZARD RISK REGISTERS .............................................................................................. 19

8.1.4 NEW PIPELINES ............................................................................................................................................ 19 8.1.6 HAZOP ............................................................................................................................................................... 20

9. EMERGENCY RESPONSE ................................................................................................................................... 20

9.1 EMERGENCY RESPONSE CAPABILITY .......................................................................................................... 20

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9.2 EMERGENCY RESPONSE PROCEDURES ................................................................................................. 20

9.3 EMERGENCY RESPONSE DRILLS ............................................................................................................... 20

9.3.1 Overview of Significant Response Drills ............................................................................................ 21 Moomba Plant Major Exercise ........................................................................................................................ 21 9.4.1 Emergency Response Equipment........................................................................................................ 25

10. GENERAL .............................................................................................................................................................. 25

10.1 LOCAL COMMUNITY INVOLVEMENT ........................................................................................................ 25

11. SEISMIC EXPLORATION .................................................................................................................................... 25

11.1 Summary of Activities ................................................................................................................................... 25

11.2 Restoration ...................................................................................................................................................... 26

11.3 Significant Operations Proposed for 2013 .............................................................................................. 26

11.4 Environmental Monitoring ........................................................................................................................... 26

11.4.1 Standards ................................................................................................................................................. 26 11.4.2 Environmental Monitoring Points Set Up ........................................................................................ 27 11.4.3 Environmental Monitoring Points Revisits ...................................................................................... 27 11.4.4 Environmental Report Forms .............................................................................................................. 27 Environmental Objectives and Performance – Geophysical Operations SEO ................................... 29

12. DRILLING AND WELL OPERATIONS............................................................................................................... 34 12.1 WELLSITE, CAMPSITE, BORROW PIT and ACCESS TRACK CONSTRUCTION & RESTORATION ..... 34

12.2 DRILLING OPERATIONS ................................................................................................................................. 35

12.3 DRILLING ACTIVITY – 2013 ........................................................................................................................... 35

12.4 WELL COMPLETION, WORKOVER, PRODUCTION, SUSPENSION and ABANDONMENT .................. 35

12.4.1 Monitoring of Wells ................................................................................................................................ 36

12.5 WELL TESTING, COMPLETION and WORKOVER ACTIVITY – 2013.............................................. 36

12.6 WELL/LEASE ABANDONMENT .................................................................................................................. 36

12.7 DOWNHOLE WELL ABANDONMENT – 2012 ........................................................................................... 36

12.8 DOWNHOLE WELL ABANDONMENT – 2013 ........................................................................................... 36 Environmental Objectives .,and Performance – Drilling and Well Operations SEO .............................................. 37

13. PRODUCTION & PROCESSING FACILITY OPERATIONS ............................................................................. 50 13.1 PRODUCTION FACILITY PROJECTS ............................................................................................................. 50

13.1.1 MOOMBA PLANT...................................................................................................................................... 50

13.2 PRODUCTION FORECAST – 2013 ................................................................................................................... 51

13.3 PIPELINE CONSTRUCTION, OPERATION AND MONITORING ................................................................ 52

13.4 LICENSED PIPELINES ...................................................................................................................................... 52

13.4.1 PL 5 – Ballera to Moomba Pipeline ............................................................................................................. 53 13.4.2 PL 9 – Stokes to Mettika Pipeline ................................................................................................................ 53 13.4.2 PL 15 – Moon to Kerna Pipeline .................................................................................................................. 54

13.5 ROAD AND WELLSITE LEASE AND ACCESS CONSTRUCTION AND RESTORATION ....................... 54

13.5.1 WELLSITE LEASE AND ACCESS CONSTRUCTION AND RESTORATION...................................... 54 13.5.2 ROAD CONSTRUCTION ........................................................................................................................... 55

13.6 WATER EXTRACTION FROM COOPER CREEK .......................................................................................... 55

Environmental Objectives and Performance – Production and Processing SEO .................................................... 56 14 REPORTS ISSUED DURING THE 2012 LICENCE YEAR ................................................................................. 72

15. STATEMENT OF ACTUAL AND PROPOSED EXPENDITURE 2012/2013 ..................................................... 72

Confidential ...................................................................................................................................................................... 72

16. GLOSSARY OF TERMS ....................................................................................................................................... 72

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17. APPENDICES ........................................................................................................................................................ 73

Appendix 1 DMITRE Meetings – 2012 ............................................................................................................... 74 Appendix 2 Environmental Incidents Summary - 2012 ....................................................................................... 75 Appendix 3 Emergency Drills – 2012 ................................................................................................................. 78 Appendix 4 Well Drilling Lease Scout, Construct, Backfill and Restoration Activity – 2012 ............................ 90 Appendix 5 Well Workover Summary ................................................................................................................. 96 Appendix 6 Well Summary – Producing & Suspended Wells ........................................................................... 100 Appendix 7 Flowlines Constructed – 2012 ........................................................................................................ 102 Appendix 8 Pipeline Inspection, Testing & Repair – 2012 .............................................................................. 102 Appendix 9 Details of Seismic Activity ........................................................................................................... 104 Appendix 10a 2012 Production Facility Projects ................................................................................................ 106 Appendix 10b 2013 Production Facility Projects - Proposed .............................................................................. 107 Appendix 11 Wells Drilled – 2012...................................................................................................................... 108

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ANNUAL REPORT – 2012 SA Cooper Basin Joint Venture Operations

1. INTRODUCTION This report covers the activities conducted in the South Australian section of the Cooper Basin (SACB) by Santos Ltd as Operator for the South Australian Cooper Basin Joint Venture (SACBJV). This report covers the period 1 January 2012 – 31 December 2012. This report covers: - SACBJV exploration, production and processing operations

- Pipelines operated under Pipeline Licences #5 (Ballera to Moomba), #9 (Stokes to Mettika) and #15 (Moon to Kerna)

- Emergency response exercises conducted during 2012 - The hydrocarbon liquids pumping station at the head of the Moomba – Port

Bonython liquids pipeline This report does not cover but the systems and procedures are applied equally to:

- PPLs 206, 208 & 215 which are located in the SACB and where Santos Ltd is the Operator for a joint venture other than the SACBJV

- PL 17, the SA section of the Jackson to Moomba Oil Pipeline - PEL 114 and associated PPLs 225, 226 and 227 which are located in the SACB

and are held 100% and operated by Santos Ltd This report does not cover:

- the liquids pipeline from Moomba to Port Bonython - any facilities owned or operated by other third parties

This Annual Report for all activity was prepared considering the relevant Statements of Environmental Objectives (SEO).

2. EXECUTIVE SUMMARY During 2012, there was one incident or accident reported associated with Santos activities which involved any member of the public or third parties. In 2012 there were twenty one Serious Incidents (as defined by the Act and the Regulations and relevant SEO) and which were reported to DMITRE in accordance with the requirements of the legislation applicable to SACBJV activity During 2012, there were,

- 78.4 petajoules (PJ) of sales gas produced into the Moomba - Adelaide and Moomba – Sydney gas pipelines.

- 11.2 PJs of ethane produced into the Moomba – Sydney ethane pipeline. - 255 mL of gas condensate produced to Port Bonython. - 8.781 mm Barrels (BBLS) of crude oil exported to Port Bonython.

During 2012 a CPSAN12 3D Seismic Survey (Greater Leleptian 3D) recorded in Santos PPL’s 17, 20, 35, 52, 55, 56, 68, 91, 95, 124, 140, 154, 160, 223 & 238 and AAL’s 164 & 177 (covering multiple areas outside Santos acreage)

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A total of 20 wells were drilled by the SACBJV. All were cased and suspended for later completion. There were also 4 wells drilled in PEL 114 by Santos There were 215 individual workover operations conducted during 2012. Of these 10 were for PEL 114. This involved 31 Fracture Stimulation operations. Workover activities included casing repair, down-hole pump installation/repair, well completion or re-completion, Integrity repairs, water well conversion and perforation operations. At the end of this reporting period there were a total of 402 oil (185 producing) and 926 gas or gas/oil (524 producing) Santos operated wells. 648 wells (producing, inactive or suspended) were subject to casing annulus pressure testing During this period, there were 100.292 km of flowline constructed, made up of 28 individual flowlines. Of the 100.292 km constructed, 60.443 km was Glass Reinforced Epoxy (GRE) line, 39.349 km of steel line. Close cooperation and liaison was maintained with landholders and third party exploration companies in the SACB. Santos continued to actively support local community activities across the areas where hydrocarbon exploration and production activities take place.

3. SUMMARY OF REGULATED ACTIVITIES The following Regulated Activities were conducted by the SACBJV under the various petroleum licences during 2012,

- Exploration for and appraisal of petroleum. - Road, track, borrow pit and well lease construction. - Seismic line construction. - Seismic survey. - Well drilling operations. - Water injection / water flood operations to enhance production. - Operations associated with the production of petroleum, including

construction, maintenance, repair and operation of pipelines, plant and facilities, camps, airstrips and associated infrastructure.

- Gas and oil processing operations. - Storage of natural gas in underground reservoirs. - Disposal of produced formation water. - Operation of licensed transmission pipelines.

4. PERFORMANCE The activities covered by this report are administered in accordance with the Petroleum and Geothermal Energy Act 2000, the Petroleum and Geothermal Energy Regulations 2000 and relevant SEO’s.

4.1 PROVISION OF DATA As a result of the previous increased focus on the provision of timely and accurate data to DMITRE, there were very few occasions where data was incomplete or late.

4.2 PIPELINE MANAGEMENT

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Santos field pipelines are designed in accordance with AS2885 and engineering standards. Operation and Maintenance of pipelines is managed by the Santos Pipeline Asset Management System which sets standards for integrity management and design life review to ensure EHS risks are ALARP. Individual Integrity Management Plans (IMP) are in place for each pipeline in the Santos operated network. These IMPs indicate the activities and frequencies of inspections required to manage integrity of each asset, based on estimated risk analysis

4.3 QUARTERLY PERFORMANCE MEETINGS Quarterly performance meetings between Santos and DMITRE continued during 2012. The dates of these meetings are listed in Appendix 1.

5. INCIDENTS The Petroleum and Geothermal Energy Act 2000 requires certain incidents to be reported to DMITRE within specified time frames. The Act defines two categories of incidents, namely serious and reportable. Further details are given below.

5.1 SERIOUS INCIDENTS All serious incidents are required to be reported promptly to DMITRE. A serious incident means an incident arising from activities conducted under a licence in which— (a) a person is seriously injured or killed; or (b) an imminent risk to public health or safety arises; or (c) serious environmental damage occurs or an imminent risk of serious environmental damage arises; or (d) security of natural gas supply is prejudiced or an imminent risk of prejudice to security of natural gas supply arises; or (e) some other event or circumstance occurs or arises that results in the incident falling within a classification of serious incidents under the regulations or a relevant statement of environmental objectives. During 2012, there was one incident or accident reported associated with Santos activities which involved any member of the public or third parties.

Third Party Incidents

(1) On the 23rd January 2012, it was reported that a third party had struck the Kirralee #1 gas flow line, subsequent investigation determined that the pipeline sustained no damage and there were no concerns associated with pipeline integrity.

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In 2012 there were twenty one Serious Incidents (as defined by the Act and the Regulations and relevant SEO) and which were reported to DMITRE in accordance with the requirements of the legislation applicable to SACBJV activity.

5.2 REPORTABLE INCIDENTS Reportable incidents are reported to DMITRE in accordance with legislative requirements and are provided to DMITRE at the Quarterly Performance meetings, these are listed in Appendix 1. A reportable incident is an incident (other than a serious incident) arising from activities conducted under a licence classified under the regulations as a reportable incident. In accordance with Regulation 32(1), the following are classified as reportable incidents:

• an escape of petroleum, a processed substance, a chemical or a fuel that affects an area that has not been specifically designed to contain such an escape; and

• an incident identified as a reportable incident under the relevant statement of environmental objectives.

Reportable Incidents that have been reported to DMITRE during 2012 may have also been reported to other regulatory agencies, such as the SA EPA and SafeWork SA. In the interest of sharing safety information and developing uniform safety approaches, Santos issued invitations to third party exploration and production operators to participate in the regular Santos/Contractor safety meetings.

Pipeline Integrity Incidents

(1) On the 9th January 2012, it was reported that a leak had been detected on the Carmina #1 glass reinforced epoxy (GRE) oil flowline in the Limestone Creek area.

(2) On the 22nd January 2012, it was reported that a pinhole corrosion leak had been identified on the Dilchee #4 manifold.

(3) On the 30th January 2012, it was reported that a pinhole corrosion leak had been identified on the Nephrite #1 gathering line.

(4) On the 9th February 2012, it was reported that a pinhole corrosion leak had been identified on the Coonatie #15 flowline.

(5) On the 18th February 2012, it was reported that a pinhole corrosion leak had been identified on the Coonatie #16 flowline.

(6) On the 28th February 2012, it was reported that a pinhole corrosion leak had been identified on the Moonanga #1 lease flowline to Jack Lake.

(7) On the 24th March 2012, it was reported that a pinhole corrosion leak had been identified on the Moomba #5 flowline.

(8) On the 15th April 2012, it was reported that a pinhole corrosion leak had been identified on the Strzelecki #8 flowline.

(9) On the 28th May 2012, it was reported that a pinhole corrosion leak had been identified on the Kurunda #4 flowline.

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(10) On the 16th June 2012, it was reported that a pinhole corrosion leak had been identified on the Epsilon #3 flowline.

(11) On the 29th June 2012, it was reported that a pinhole corrosion leak had been identified on the Big Lake #3 flowline.

(12) On the 28th July 2012, it was reported that a pinhole corrosion leak had been identified on a flowline in the Embarrka swamp, 5.5 km South East of Tirrawarra.

(13) On the 2nd August 2012, it was reported that a pinhole corrosion leak had been identified on the Cabernet #1 flowline.

(14) On the 6th September 2012, it was reported that a pinhole corrosion leak had been identified on the Moonanga to Jack Lake flowline.

(15) On the 16th October 2012, it was reported that a pinhole corrosion leak had been identified on the Bookabourdie Pondrinie #15 flowline.

(16) On the 26th October 2012, it was reported that a pinhole corrosion leak had been identified on the Big Lake #83 flowline.

(17) On the 26th October 2012, it was reported that a pinhole corrosion leak had been identified on the Nephrite South #8 flowline.

Facility Integrity Incidents

(18) On the 25th April 2012, it was reported that a pinhole corrosion leak had been identified on the Moomba #2 wellhead meter run

(19) On the 13th September 2012, it was reported that a pinhole corrosion leak had been identified on the Moomba Plant Crude Stabilization Plant (CSP) Vessel V2262 Offgas line.

(20) On the 21st October 2012, a pinhole corrosion leak was identified in the Tirrawarra Satellite sludge catcher.

Potential Aquifer Contamination Incidents (21) On the 7th August 2012, it was reported that Phase Separated Hydrocarbons

(PSH) had been identified in ground water monitoring bores at the Dullingari and Daralingie Satellite interceptor ponds. Results from Detailed Risk Assessments (DRA) on events which occurred in 2011 will be utilised to determine the appropriate remediation strategy, if required, for each site.

Environmental Incidents Environmental incidents are listed in Appendix 1 and Appendix 2. These incidents were risk assessed and the consequences of these ranged from Negligible (86%) to Minor (14%) with no risks assessed at greater than Minor. There was a decrease in the number of reported incidents, from 82 to 66, reported for 2012.

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The volume of uncontained hydrocarbon reported was 26.51m3, up from 25.05 m3 in 2011, from a total fluid volume of 289.4m3, down from 600m3. Of the total incidents 67% were for total volumes of less than 100 litres. Root causes included Design (9%), Monitoring and Maintenance (73%), Work Practices (14%).

5.2.1 SUMMARY OF ACTIONS TO PREVENT RECURRENCE The focus on reporting of minor events and those not involving hydrocarbon has continued.

A range of corrective actions, from investigations have been implemented including:

• The assessment of pipeline tape coating integrity and re-coating (with yellow jacket) where required.

• The development of a 5 year plan to improve performance of cathodic protection in the Cooper Basin.

• The improved management and reduction of dead legs. • The upgrading of telemetry.

5.3 NOTIFIABLE WORK RELATED INJURY OR DANGEROUS OCCURRENCE

Notifiable Work-related Injuries or Dangerous Occurrences required to be reported to SafeWork SA are also reported to DMITRE. There was no Immediately Notifiable Work-related Injury reported during 2011, there were 35 events classified as Reportable to DMITRE and 7 Notifiable Dangerous Occurrences reported Safe Work SA.

At the Quarterly performance meetings these incidents are also reported. Appendix 2 provides an analysis of those reports. Root causes included Design (3%), Monitoring and Maintenance (80%), Work Practices (14%) and Risk Management Induction/Training (3%).

6. MONITORING/STUDIES

6.1 MONITORING

6.1.1 SEO Compliance The following programs monitor compliance of Santos operations with the SEOs: • There continues an ongoing focus on the prevention of hydrocarbon spills

through the implementation of integrity management plans. In 2012 this program continued a focus on key equipment including buried piping. These plans include audit and monitoring programs to assess conformance against procedures and the effectiveness of the standards and programs in place in the field. Audits of several satellites against the requirements of the SEO was also undertaken, with outcomes and opportunities for improvement adopted by operations.

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• Of the 49 abandoned production facilities (including produced formation water ponds, flare pits, well-heads and sumps) identified in 2011, a further 7 sites underwent site contamination assessments using the SHI procedure. Individual rehabilitation plans were scoped and are being implemented where further work is required.

6.1.2 SEO Review The scheduled review of the Geophysical Operations Statement of Environmental Objectives (SEO) commenced in May 2012, with the SEO and related Environmental Impact Report (EIR) being updated to reflect current technological and environmental practices. The documents were further refined following stakeholder review and consultation, and will be submitted to DMITRE in early 2012 after final internal review by Santos.

6.1.3 Buried Piping Risk Assessment The Buried Piping Risk Assessment Program is a major activity to identify, risk assess and prioritise maintenance and replacement activities of intentional and unintentionally buried piping. The program aims to ensure risks are ALARP. The Buried Piping Risk Assessment Program was initially instigated following the premature failure of a buried pipe in the Moomba Plant in 2009. This program has been extended to include buried lines outside the Moomba Plant and within the Cooper Basin. The intent of the extended program is to manage the remaining life and integrity of buried pipeline assets across the Cooper Basin.

• To date, over 4800 buried pipe soil / air interfaces have been surveyed within the Cooper basin.

• 70% of these buried pipe soil / air interfaces have now been consequenced assessed with higher risk pipes identified for earth to ground potential checks and review of cathodic protection readings. These findings will determine which pipes will be planned for further inspection activities including but not limited to eg., direct assessment dig ups and or Advanced Non Destructive Testing.

Santos has a proactive integrity management program for buried piping that considers various factors to understand risk and remaining life which guides additional inspection, maintenance and re-lifing activities in a form of forward looking 5yr plans. Any failures outside of predictions and life assessment estimations are thoroughly investigated and reviewed to improve understanding of the factors impacting integrity risk, and models are updated to incorporate the learnings.

6.1.4 Satellite Upgrades There is an ongoing program to upgrade satellite facilities to improve environmental performance. Areas of focus include liquid separation and water disposal facilities , condition assessment of buried piping, and flare facilities. Satellites that have been upgraded (or are in the process of being upgraded) include:

• Strzelecki Satellite • Merrimelia Oil Satellite

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• Tirrawarra Gas Satellite • Bookabourdie Gas Satellite • Della Gas Satellite • Toolachee Gas Satellite • Gidgealpa Gas Satellite • Moomba South Central Gas Satellite • Merrimelia Gas Satellite.

In addition, there has been an increased focus on housekeeping, with regular inspections addressing issues such as weeds, spills and leaks, rubbish and appropriate signage.

6.2 STUDIES

6.2.1 Produced Formation Water Management Strategy In 2012, an investigative drilling program was undertaken to identify impacts to soil and groundwater from the operation of 12 interceptor ponds. These ponds were identified as posing a high risk due to potential seepage of hydrocarbon liquids, following the 2009 produced formation water management study. The program identified impacts at number of sites and appropriate action to address is being scoped, including the replacement of the traditional in-ground interceptor pond at Gidgealpa Gas, with an above ground pond. This pond is on track for commissioning in Q2 2013. In 2012 a water management study was undertaken to assess options for forecast produced formation water in the Cooper Basin. The study looked at technically feasible and economic alternatives for produced formation water management, including assisted evaporation techniques. The findings are now being considered for implementation in 2012 and beyond.

6.2.2 Sludge Management Construction of the new sludge plant began in Q3 2012. It is expected to be on line in Q2 2013.

6.2.3 Waste Management In 2011, the extension to the landfill at the Moomba Waste Management Facility (WMF) was completed. The new landfill is a fully engineered, lined landfill with leachate collection system, designed in accordance with SA EPA guidelines. The first cell was approved for operation by the SA EPA in Q1 2012, and has been operated successfully since then. An extension to that cell is currently being scoped. The Landfill Environmental Management Plan has been developed and implemented in conjunction with the landfill.

6.2.4 Fauna Refuge and Release System (FRRS) A FRRS Trial was conducted for the Charo to Tirrawarra Trunkline Project. This involved a new and innovative technology to safely reduce fauna entrapment related impacts on open trenchlines associated with pipeline construction. FRRS was utilised on this trial between March and May 2012, with extremely positive results confirmed.

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An associated paper and presentation was being delivered at the SPE/ APPEA forum at Perth in September 2012, and a promotional DVD has been developed through the Corporate SANTOS environmental team.

7. MANAGEMENT SYSTEM

7.1 ENVIRONMENT, HEALTH & SAFETY MANAGEMENT SYSTEM (EHSMS) The implementation, monitoring and review of the Santos Environment, Health and Safety Management System (EHSMS) continued as an organisational priority during 2012. The level of performance was communicated in the DMITRE Annual Health and Safety Management System Self-Assessment. Management standards performance was further validated by the use of internal auditors to monitor improvement initiatives highlighted by the EHSMS audit and assessment program.

The EHSMS contains management standards, health and safety hazard standards and environmental hazard standards. The management standards provide a framework for the sustainable achievement of acceptable EHS outcomes, whilst the hazard standards provide a clear process for control of hazards that are specific to Santos’ business.

The new Work Health Safety Act and Regulations have been reviewed and a gap analysis completed on the EHSMS in preparation of the introduction in SA.

7.1.1 Management Standards Further implementation of management standards continued throughout 2012. Process safety (the prevention of high consequence/low frequency events involving sudden loss process fluids/gasses) standards continue to be embedded into the business. Process Safety data continues to be collected and analysed. Trending information is fed back through the monthly Eastern Australia leadership committee. There were 8 management standards amended and updated in 2012– EHS Responsibility & Accountability, Incident Investigations and Response, Contractor and Supplier EHS Management, Consultation and Communication, Acquisitions and Divestments, Workplace Inspections, Training & Competency. A significant review of Contract and Supplier EHS Management was completed during 2012 with some key changes including new definitions of Contractor Categories, more descriptive information around Contractor requirements (particularly in relation to EHS Management and Improvement Plans, Auditing and Meetings); increased guidance on pre-qualification and use of sub-contractors. This review also targeted the improvement of Contractor EHS Management Training for Contract Sponsors and Representatives with pilot programs completed in readiness for a full roll out first half of 2013.

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A significant review of Hazard Identification, Risk Assessment and Control was initiated in 2012 as a pilot for the complete overhaul and redesign on the EHS Management System. It is expected the Hazard Identification, Risk Assessment and Control Standard will be completed and rolled out during Q1/2013; and that a further 18 Management and Hazard Standards will be reviewed, amended and updated as part of this project during 2013.

7.1.2 Hazard Standards Further development and implementation of hazard standards progressed in 2012. The following standards were updated: Cultural Heritage and Working at Heights. Santos have continued to take a proactive approach with the health and well-being program (supported by the hazard standard) with significant focus on workforce health awareness, education and resilience training. A specific program is in place for high risk individuals, staff who were assessed at having 5 health risks from previous health check (health checks are conducted every 2 years), this included personal health coaching (this commenced in 2010). Most of our SA sites have on site gym facilities which are manned by lifestyle coordinators and show an increased attendance for our staff over the last few years. Santos also supports our employees by way of entrance fees into community events such as, Nissan Triathlon (Santos were the winners of the 2012 highest corporate participation), City to Bay and the BUPA challenge (an event in the Santos World Tour Down Under) The health and wellbeing program also supports our employees with the ups and downs of everyday life through our Employee Assistance Program, whereby employees can seek professional and confidential counselling to help them resolve or better cope with personal or work problems that maybe affecting their work or overall wellbeing. Drug and alcohol testing (urine) continued in 2012 with employees and contractors at all field and office locations being subject to random, for cause and post incident testing. Results for testing were 0.75% for illegal Drugs and 0.27% for Alcohol, well below national data supplied. A fatigue management program was implemented in 2009, including awareness programs, self-management tools and reporting protocols. This program continued in 2012 with refresher awareness sessions in the field and specific work on reviewing Moomba process and contractor rosters.

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In 2012, sites continued to identify and focus on their ‘top 5’ hazards standards. These standards were aligned with their Significant Hazard Risk Register, to ensure a constant site-based focus on the most significant hazards. During 2012, sites continued to review and update their Significant Hazard Risk Registers and their ‘top 10’ risks and controls were reported back through the monthly Eastern Australia Leadership EHS Committee.

7.1.3 Training and Awareness A new program was launched in 2010 to raise the awareness of high risk safety activities (The Santos Lifesaver Program). This program continued in 2012 with a different approach to raising awareness. Santos developed a number of Santos DVD-s to educate the workforce on the lifesaver topic. The program also contained a toolbox talk, promotional material (displays, posters, sticker, and screen saver), quiz, workplace inspection and audit. During 2012 the program provided specific focus on fundamental aspect of EHS was rolled out under the title of EHS Fundamentals. Maintaining the 10 topic framework the program was delivered through the same mechanisms as 2011 with an excellent level of participation from all sites. The overall participation rate increased by approx. 10%. Topics for the year were: Safety Hazard Identification, Following Procedures, Chemical Management, Process Safety Hazard Identification, Environmental Hazard Identification, Noise Management, Biodiversity & Land Disturbance, Emergencies, Plant (Equipment & Machinery) and Manual Tasks. This program continues to be successful in raising the level of awareness and resulted in an increase in hazard reporting on these topics. It’s important to note that the repeatability of this program will, over time, embed a level of awareness to enhance our safety culture and ensure new team members are routinely on-boarded through the process.

7.2 AUDITS, ASSESSMENTS AND REVIEW PROCESSES The following summarises some of the Audit and Review processes used to determine system conformance, effectiveness and fitness for purpose. Santos effectively mandates a three tiered approach to Audit and Review; 1. On site workplace inspections; statutory testing of equipment; work permit and

JHA reviews as well as measuring use of operating documentation. 2. During 2012 Asset Managers were responsible for ensuring Self EHS Audits

were conducted within their area of responsibility (on site). A risk based approached is used to determine the required audits against EHS Management System Standards. These audits are conducted in accordance with AS/NZS ISO 19011:2003.

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3. The Internal Corporate Audit Program continued during 2012 and ~20 Audits and Progress Reviews completed. A balance of internal and external Lead Auditors was responsible for the delivery of the Audits and Progress Reviews.

Results of Inspections, Reviews, Audits and Progress Reviews were tabled at Eastern Australia Leadership and Site EHS Committee meetings for discussion and tracking of actions. A number of detailed presentations were also made to communicate the learnings from these activities across the business. Audit findings were also presented at the Environment, Health, Safety and Sustainability Board Meeting. In 2012, we continued to report, investigate and record any High Potential Incidents (HiPos) that occurred within the company. A HiPo is defined as any incident that had potential to result in a fatality. Tracking and reporting HiPos continues to provide the company with another avenue to learn from incidents and improve our overall safety performance. Results and presentation are reported to senior management on a regular basis.

7.2.1 Performance Based Audits In 2012, four Legislative and Regulatory Performance Audits were conducted:

No Audit Title Act/Reg #

1 Work Permit – Various sites OHS&W Act

2 Excavation – Various sites OHS&W Act

3 Electrical Safety – Various sites OHS&W Act

4 Working at heights – Various sites OHS&W Act

7.2.3 Pipelines Management of pipeline integrity occurs by targeting pipeline systems and associated equipment which are high risk or near the end of design life (Risk Based Inspection - RBI - approach). Main targets of Pipeline Integrity Management are:

- Redirection of pipeline operating risks to ALARP - Address safety risks - Maintain integrity of ageing pipeline network - Standards compliance - AIMS (Asset Integrity Management System) compliance

AIMS is the framework used within Pipeline Integrity to provide effective through-life integrity management of pipeline assets to meet operational availability, as well as achieving statutory and corporate compliance with Safety, Health and Environment

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7.2.4 Training Various training requirements identified from audits and assessments were addressed.

7.2.5 Sustainability Report Santos released its first annual sustainability publication in late 2004, making public its commitment to long- term sustainability as an energy company. At that time, Santos adopted sustainability as a core value and committed to continually improving its performance in this area. Since then, Santos has implemented a framework in which the company measures performance across a comprehensive suite of indicators in the environment, community, our people and economic domains. Santos publishes its annual verified Sustainability Report in March each year. This document reports against Santos’ sustainability targets and provides further detail on policy, procedures and performance across the four domains of sustainability.

8. REASONABLY FORESEEABLE THREATS Reasonably foreseeable threats, those that reasonably present, or may present, a hazard to the facilities or activities, continued to be reviewed and reduced by a number of initiatives. These initiatives included:

• Close liaison continues with 3rd parties exploring and producing in the Cooper Basin to manage the risk of 3rd party impact on pipelines.

• Work to expand the EHS Management System’s focus on Process Safety, targeting potential low-frequency, high-consequence events such as loss of containment. The Moomba Plant and Cooper Basin Production both underwent external audits against Santos EHSMS including the PSM standards during 2008. During 2009, 2010 and 2011, formal progress reviews were undertaken against the audit recommendations. Progress reviews may also identify new improvement opportunities as part of continuous improvement. Most non-conformances have been completed and closed. A full re-audit of the Moomba plant was carried out in 2012.

• Completion of a Formal Safety Assessment (FSA) of the Moomba Gas Plant. The FSA is a key source of process safety risk information for the Moomba Gas Plant and recommendations were commenced in 2011 with actions to be ongoing for 3-5 years. Information from the FSA will also be a significant input into the safety case which will be required for Moomba under Major Hazard Facilities regulations.

• Communications with other parties operating in the area are maintained to manage threats posed to the facilities, in particular to high pressure natural gas pipelines, to as low as reasonably practicable (ALARP). This includes pastoralists, on whose properties the operational activities are conducted. Information on infrastructure, including pipeline maps and information, is provided and regularly updated.

• Security situation has continued to be monitored and close liaison continues to be maintained with State and Federal authorities responsible for managing this issue. Appropriate relationships have been established with key response agencies.

• Participating in the development of common drilling industry standards, practices and procedures. A key component of this is the Wellsite Permit to Work System

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that Santos continues to provide leadership for, including providing the chair for the newly formed industry association structured to manage the System going forward.

The listing of Production Facility Projects for 2012 Appendix 10a, and proposed projects for 2013, Appendix 10b, provide a more comprehensive listing.

8.1 RISK ASSESSMENT Santos undertook a number of risk assessments during the period. These risk assessments are aimed at identification of risks and the development of actions designed to reduce the risk to as low as reasonably practicable (ALARP). Risk assessments are undertaken in line with EHSMS09 Hazard Identification, Risk Assessment and Control.

There were also a number of projects identified in previous risk assessments which continued to be progressed during 2012. These projects are addressed in this report

8.1.1 WHOLE OF PLANT RISK ASSESSMENT (WOPRA) AND FORMAL SAFETY ASSESSMENT (FSA) WOPRA was a systematic whole of plant risk assessment process with strong emphasis on work group participation. It’s structure was intended to be compatible with the anticipated Major Hazard Facility requirements.

Assessments were completed for the Moomba Gas Plant and the Moomba South Central Gas Satellite.

Focus of the WOPRAs was on actions associated with the top 10 Hazards for the Moomba plant and the top 5 Hazards at the Moomba South Central Satellite. Priority action items were issued and stewarded. The WOPRA processes are complete.

In 2009, a Formal Safety Assessment (FSA) of Moomba Gas Plant commenced in line with the requirements of EHSMS09 Hazard Identification, Risk Assessment and Control and to build on the WOPRA study. Following a pilot study started in 2009, the remainder of the Moomba Plant was reviewed in 2010. The potential risk reduction opportunities identified are in the process of further analysis and commencement of actions in order to maintain risk as low as reasonably practicable (ALARP). Projects and implementation plans will be instigated as part of this process over an anticipated 3-5 year period. The risk and control information will also be an important basis for the Safety Case which will be required under MHF regulations.

8.1.2 PIPELINES Detailed risk assessments are completed for new pipelines and an improved risk based design life review process has been implemented for pipelines in operation. A key risk mitigator is the effective completion of the activities required by the IMPs. Risk reviews throughout the operating life of the pipeline are determined through the pipeline risk based inspection process. Individual Integrity Management Plans are in place for each pipeline that forms part of the Santos network.

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The performance of integrity management system is reported via monthly KPIs, IMP compliance reports and is discussed with individual asset owners and management at quarterly forums such as L2 Reliability & Integrity Review and Operations Governance.

The KPIs monitor performance of the chemical pump reliability, CP reliability, the batch and slug treatment program, CP and ROW surveys, barrel treatments, inspections (ILIs and DAs), preliminary and final abandonments and pipeline threats. Compliance of IMP-related activities is also measured.

A number of risk assessments were undertaken on key pipelines, listed Appendix 8, as required under the Pipeline Management System.

8.1.3 SIGNIFICANT HAZARD RISK REGISTERS A requirement of Santos EHSMS9 Hazard Identification, Risk Assessment and Control is for operating sites to develop and maintain a Significant Hazard Risk Register (SHRR). The SHRRs record risks with an inherent risk rating of 3 or higher (from Santos’ Risk Rating tool). Information is consolidated from various EHS and process safety risk assessment processes. SHRRs are used to: • Identify the major EHS hazards to be included in EHS inductions • Prioritise resources for the auditing/ monitoring of key controls • Assist with the development of site/ function EHS inspection, monitoring

and audit programs • Assist with the development of annual EHS Improvement Plans During 2012, the SHRRs for the Moomba Gas Plant, Upstream Gas Operations and Cooper Basin Oil operations underwent further update and development to maintain currency and to improve their effectiveness for managing risks. The top items from SHRRs are reviewed in rotation by the Eastern Australia Business Unit EHS Committee meeting.

8.1.4 NEW PIPELINES A total of 28 new pipelines (oil & gas) were constructed in South Australia in 2012.

8.1.5 SECURITY

Security related activities within Cooper Basin continued effectively through 2012 with the following key activities:

• Conduct of Security risk Assessment for Port Bonython as part of

implementation of new Hazard Standard for Security Management • Emergency response arrangements occurred at multiple sites across

Cooper Basin. Port Bonython conducted an exercise involving SAPOL and Metropolitan Fire Services support.

• SAPOL Critical Infrastructure Support Group liaised with Santos regarding the presence of Protesters in the Port Bonython area (focus on BHP Billiton)

• Liaison network with the various Federal and State agencies responsible for security related issues were maintained.

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8.1.6 HAZOP There were 8 HAZOPs conducted for the Moomba Plant, production facilities and pipelines in 2012.

9. EMERGENCY RESPONSE

9.1 EMERGENCY RESPONSE CAPABILITY Santos maintains a dedicated emergency response crew at Moomba. This consists of fully trained Emergency Officers (fire crew) and medical response personnel together with a large inventory of emergency response equipment, material and vehicles.

9.2 EMERGENCY RESPONSE PROCEDURES Santos has a Crisis Management Plan in accordance with EHSMS13. The Duty Manager is notified from the site informing of an incident, and if significant, will result in the Crisis Management Team assembling. Emergency response drills are regularly held in order to continuously update plans and maintain a high degree of readiness among personnel.

In the event of the emergency response procedures being used in response to an actual event, a de-brief of all relevant parties is conducted in order to ensure learning’s are incorporated into the plans. A Business Impact Assessment (IA) has been conducted for Moomba and Adelaide-based infrastructure in accordance with new Business Continuity Planning arrangements for Santos.

9.3 EMERGENCY RESPONSE DRILLS A listing of drills held during 2012 is contained in Appendix 3 Emergency Services conducted a number of Drills, Exercises and Desktop Exercises in 2012 including Evacuation Drills, Muster Point Training, Operational Exercises, EOC Training and Exercises, SAR Exercises and CSE Training and Rescue Rehearsals etc. An agreement with DMITRE provides for a summary within this report with regard to the requirements of Reg 31 (5) of the Petroleum and Geothermal Energy Regulations 2000, the preparation and submission of a report after a drill. The drills held during 2012 have met the requirements of Reg 31-(6). They have demonstrated the adequacy of the emergency response procedures and the competency of personnel to execute the procedures. A summary of outcomes, and any identified deficiencies and the remedial action proposed or taken is provided in the listing in Appendix 3. The following provides some additional detail on the more significant response drill Santos conducted, or participated in, during 2012.

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A number of emergency response exercises were conducted during 2012 to test the adequacy of the emergency response procedures and the competency of personnel to execute the procedures. On 15 October 2012, a Moomba major plant emergency response exercise was conducted to test procedures for responding to a process emergency, and extended to a consideration of crisis management arrangements in the event of a more serious incident arising. The size and scope of the exercise was designed to ensure that all resources immediately available were utilised and/or considered, and it identified opportunities to improve emergency response training and radio communications during an emergency situation.

9.3.1 Overview of Significant Response Drills

Moomba Plant Major Exercise The 2012 Major plant exercise for the Moomba plant was an operational exercise (OPREX) designed to analyse the effectiveness of established emergency response procedures (as required by EHSMS 13 emergency preparedness) which included but not limited to Strategic decisions made by the Incident Management Team within the EOC and tactics employed by the combatants at the incident. Under review was also the effectiveness of evacuation procedures for a major hazardous facility The size and scope of the emergency response ensured that all resources immediately available were utilised and/or considered. This in turn facilitated the practice and review of crisis management arrangements in the event of a more serious incident arising. Incident Scenario A tanker has pulled into the load-in/load-out facility; the driver and the Process operator begin to hook up the tanker to the pipe work to decant the 35,000 litres of oil. Whilst in the early stages of the operation smoke and fire is seen from the rear of the prime mover, the driver and the operator see an opportunity to move the prime mover clear of the facility and attempt to suppress the fire. During this heightened level of activity a valve is not completely isolated on the tanker and is passing liquid to grade. The prime mover has only partially cleared the area and the driver is slumped over the steering wheel in an unresponsive state. There will be two casualties – 1 x Process operator injured during first response to the incident and the 1 x driver as previously stated (which will be a training manikin to mitigate any casualty handling issues).

There were eight defined objectives for the exercise to be measured against.

• To validate the effectiveness of the current Moomba Emergency Plan,

Emergency Response Procedures and the Moomba Plant Contingency Pre-Plan.

• Measure the effectiveness of call, receive and dispatch procedures and relevant notifications.

• Measure the effectiveness of first response capabilities and training. • To employ fire and rescue tactics to provide continuous improvement

opportunities for Emergency Services Officers and Process Personnel.

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• Provide the opportunity to practice casualty assessment, treatment and transportation.

• To present the Moomba Incident Management Team with a scenario that will require the implementation of the Moomba Emergency Plan, strategic management and support of the incident.

• Manage any environmental concerns from the incident • Identify any weakness in the plans, procedures and training so actions can

be assigned to rectify any potential issues. Emergency Operations Centre Exercises A number of EOC exercises were conducted throughout 2012 covering both the primary EOC and the alternate EOC. These exercises were designed to practise established emergency response procedures and individual roles and responsibilities within the Emergency Operations Centre during the time of an incident. There were a number of objectives detailed for each individual exercise which was reported directly against in the associated exercise debriefs and reports Cooper Basin Camp Evacuation Exercises Camp evacuation exercises were also conducted across Santos sites including a night exercise at the Moomba FC47 Operations Camp. This exercise was designated as an OPREX as per the 2012 Cooper Basin Emergency Exercise Schedule, which is a requirement under EHSMS13 – Emergency Preparedness. The night exercise presented a set of circumstances not able to be accomplished during day time exercises namely a full camp of approx 535 personnel and evacuation of communal areas such as the Wet Mess and recreation facilities whilst fully occupied etc. The aims of these exercises were to:

• Practise and refine emergency evacuation procedures in the event of a

generic emergency occurring in the FC47 camp. • Provide a skills maintenance training opportunity for Spotless and Santos

camp personnel.

There were four defined objectives for the Moomba FC 47 Operations Camp Night Exercise to be measured against

• Assess the effectiveness of evacuation procedures for the FC47 camp • Practise and assess the operation of the Muster Point at the FC47 camp • Practise and assess procedures for activation of the multiple manual siren

activation points. • Practise and assess procedures for clearance of the FC47 accommodation

vans within acceptable time frames (30 minutes).

Limestone Creek The aim of this exercise is to practice and refine emergency management arrangements in the event of a fire emergency occurring in the Limestone Creek

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satellite and to provide a skills maintenance training opportunity for Production Department personnel Scenario The operators will be notified of a leak that has caught fire at the inlet manifold, a contractor had been working in that area and is unaccounted for. Upon locating the dummy they will find that he is partially conscious and suffering from serious burns. Dullingari/Toolachee The aim of this exercise is to practice and refine emergency management arrangements in the event of an Operator being over due to his satellite & being located at height & requiring rescue, and to provide a skills maintenance training opportunity, Moomba Comms, Dullingari / Toolachee operators, Dullingari OFA Scenario At 1300 hrs Moomba Communications Officer attempts to contact the Toolachee operator as he is two (2) hours over due to Toolachee west Nodal compressor. Moomba Communications Officer advises the Dullingari Incident Controller that the Toolachee operator is over due to the Toolachee west nodal compressor. The Incident Controller instigates a SAR utilising local Production operators to follow the most commonly known route taken by the Toolachee operator. The out field operator arrives at Toolachee west nodal compressor & advises the Dullingari Incident Controller & Moomba Communications Officer that he has located the operators vehicle & is currently searching the surrounding area for the operator. Out Field Operator locates the Toolachee Operator on top of the Toolachee west nodal compressor dewatering and storage tank & reports that the operator is unconscious. The Incident Controller requests assistance from the Dullingari OFA to attended site. He also requests the assistance from area operators to safely retrieve the casualty from the top of this tank. Daralingie The aim of this exercise is to practice and refine emergency management arrangements in the event of a vehicle accident occurring in the Daralingie Field. And to provide skills maintenance training opportunity for Production Operators and other on site personnel Scenario A vehicle accident has occurred with one entrapment near Daralingie. Moomba Comms will be notified of the incident and will undertake the appropriate action, while referring to EHSMS 13 EMERGENCY PREPAREDNESS. One Emergency Services Officer and RFDS Nurse will respond to the incident via Ambulance and Ute. A safe removal of the casualty will be undertaken by the Emergency Services Officer and RFDS Nurse. Moomba Aerodrome Emergency Exercise The 2012 Major Aerodrome Exercise for Moomba will be an operational exercise (OPREX), designed to practice established Emergency Response Procedures and Emergency Personnel as required by:

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Civil Aviation Safety Authority (CASA) regulation 139.215 EHSMS 13 EMERGENCY PREPAREDNESS. CASA regulations require a full scale Aerodrome Emergency Exercise at intervals not exceeding 24 months Scenario Conquest Shuttle inbound to Moomba with 7 passengers + Crew (passenger numbers depends on volunteers available on the day). Captain reports an engine fire on the starboard side inside engine some on final approach just prior to landing and has no choice but to continue to execute landing in Moomba. The Captain attempts to quell the fire and shuts engine down. The aircraft makes an emergency landing from the west?(direction depends on the prevailing wind on the day) bringing the aircraft to a halt on the airstrip between the two taxiways opposite the terminal. A fire is still evident on the starboard side engine of the aircraft after landing. A full evacuation of the passengers from the aircraft is commenced. All persons are evacuated from the aircraft however, there are a small number of injuries sustained during the evacuation including a suspected heart attack, badly injured ankle and a fractured arm to be treated by on site emergency / first aid personnel and transported to Health Centre. Note: all passengers and crew are able to make their own way of the aircraft and any persons requiring assistance will be at grade external to aircraft. No emergency personnel will be required to enter the aircraft during the exercise. There will be three injured passengers all of which are serious and require immediate attention and evacuation to hospitals. There is 1,000lbs of fuel still on board. CTAF radio frequency 126.7 is Moomba normal operations. Wind Direction (as per prevailing conditions). Staging area for all resources is on the Apron in front of the Terminal. 9.4 EMERGENCY RESPONSE In addition to planned drills, the Moomba emergency response resources were activated on a number of occasions in 2012. The majority of these were in response to Alarm Calls or as a precaution following a minor incident. The more significant response events that resulted in activation of the Moomba ERP included:

• Portable Rig Building Fire (Charo) 18/01/2012 • Small grass fire in the Moomba plant flare radiation zone 24/02/2012 • Cold Box Purge Alarm in the Moomba Plant 29/02/2012 • Switch Room 7 Electrical Short and subsequent Oil Spill 04/03/2012 • Small lube oil fire under STA#5 in the Moomba plant 18/04/2012 • NAFS III release Moomba Control Room 19/04/2012 • Small grass fire in the Moomba plant flare radiation zone 25/05/2012 • Motor Vehicle Accident – Northern Fields, Moolion Area 21/11/2012 • Numerous bushfires throughout Cooper basin fields caused by lightning

(January – March and September – December)

Nineteen Moomba environs incidents included Medical Assists, Truck Break Fire, Vehicle Accidents and 3rd party Search & Rescue.

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Bushfires continued throughout 2012 in the Cooper basin. Unusually high levels of native vegetation resulting from two consecutive wet seasons 2009-2012 with above average rainfall have lead to a number of large bushfires throughout the Cooper Basin. Santos emergency resources were deployed for these fires to protect Santos assets and assist pastoralists as requested. Over 1million hectares have been burnt during the spring and summer periods. No Santos assets have been damaged during these fire emergencies.

In all cases, the response systems operated effectively.

Santos helps within the general community by assisting with vehicle accidents, Medivacs, search and rescues and response to activated Emergency Position Indicating Radio Beacons (EPIRB’s). Santos also provides emergency assistance at community events.

9.4.1 Emergency Response Equipment The equipment for a well-site incident was reviewed and evaluated. CUDD Well Control were involved in this process and recommended an increase in the standby equipment held in the Cooper Basin. This recommendation was accepted and the equipment sourced and is stored in Jackson

10. GENERAL

10.1 LOCAL COMMUNITY INVOLVEMENT During this reporting period, Santos continued to be actively involved with the local community associated with various events and issues which impact this community. This involvement ranged from facilitating and participating in local sporting and fund-raising events, to active involvement in various local Committees and groups, such as. - “Local” events - Innamincka races. - Cooper Cup - Emergency and other assistance to local community. - Cooper Creek Catchment Committees - South Australia Arid Lands Natural Resources Management Board - Active support of RFDS

11. SEISMIC EXPLORATION During 2012, the following seismic activity was carried out:

• CPSAN12 3D Seismic Survey (Greater Leleptian 3D) recorded in Santos PPL’s 17, 20, 35, 52, 55, 56, 68, 91, 95, 124, 140, 154, 160, 223 & 238 and AAL’s 164 & 177 (covering multiple areas outside Santos acreage)

11.1 Summary of Activities Only the above seismic project, CPSAN12 3D Seismic Survey (Greater Leleptian 3D), was undertaken during the reporting period.

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The programme totalled 389.28 sq km of which 176.461 sq km was acquired in the SACBJV PPLs. The breakdown of square kilometres in each Licence is provided in Appendix 9. The CPSAN12 3D survey was recorded in dune fields in an area approximately 50km northwest of Moomba and 15km west south west of Tirrawarra Oil Satellite. The area included the Andree, Bindah, Cooba, Coopers Creek, Cowralli, Double Jay, Ficus, Gooranie, Hackett, Kanowana, Leleptian, Mica, Paranta, Reglet, Tindilpie, Varanus and Yarowinnie fields.

The dune field is characterised by a series of north – south trending, sub-parallel dunes separated by swales that vary from a hundred to several thousand metres in width. Dunes are buff/orange in colour and most are asymmetrically in shape with a steep eastern slope. They range in height from 5m to 20m above the general base level. Cultural heritage clearance was conducted by a team of representatives of the Dieri people working in a pre-clearance mode, that is, the entire survey area was inspected prior to the commencement of any Santos operations.

Cultural Heritage clearance Phase1: 5th Jan. – 17th Jan. 2012 Cultural Heritage clearance Phase2: 11th May – 17th May 2012 Line preparation (dozers): 5th May – 6th Jul. 2012 Surveying/Pegging: 7th May – 7th Jul. 2012 Recording period: 17th May – 17th Jul. 2012 Restoration 7th – 8th Jul. & 22nd – 25th Jul. 2012 Please note the wet weather standby/shutdown 31st May – 16th Jun. 2012

11.2 Restoration Restoration was conducted in two parts. Fence line access and roads where restored where required, primarily to remove wheel rutting. In addition, windrows were removed from some source lines and wheel ruts repaired on some receiver lines. There was no post production restoration from the GAS audit as no significant impact was encountered. Re-seeding was inappropriate and sand dune side cuts were already showing signs of recovery.

11.3 Significant Operations Proposed for 2013 There are no seismic programs currently proposed for 2013.

11.4 Environmental Monitoring The following is a brief summary of the standards followed and Environmental Monitoring Points set up and revisited. 11.4.1 Standards SEO for Geophysical Operations South Australian Cooper Basin Operators June 2006 Environmental Impact Report: Geophysical operations June 2006 Dozer Manual - Environmental Procedures for Seismic Line Preparation Nov 1998 Goal Attainment System (GAS) – included in the SEO June 2006

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Environmental Procedures for the Management of Aboriginal Heritage Sites 1998 11.4.2 Environmental Monitoring Points Set Up Proposed Greater Leleptian environmental monitoring point (EMP) locations were located from the aerial map / programme overlay. The final location of each EMP however was determined by the Santos site representatives upon a ground inspection and accessibility. The locations are governed by the objective of monitoring terrain and vegetation impact. All six EMPs are located near roads to provide current and future access without any detrimental impact upon the landscape.

CESAN11B (Nephrite 3D VSP) Six EMPs were established and recorded within the 3D survey area.

EMP # Surveyed East

Surveyed North Location Comments

EMP #1 393400 6926950 R1064 : S5168 sand dunes EMP #2 397400 6932150 R1144 : S5064 floodplain/dune boundary / vegetation EMP #3 404600 6931750 R1288 : S5072 sand / vegetation EMP #4 397800 6925750 R1152 : S5184 floodplain/dune boundary / vegetation EMP #5 391400 6922150 R1024 : S5264 low sand dunes EMP #6 395800 6919750 R1112 : S5312 floodplain / inundation area

The EMP report for Greater Leleptian 3D was delivered to DMITRE 26/11/12.

11.4.3 Environmental Monitoring Points Revisits Santos has the practice of revisiting EMP locations at irregular intervals until the sites have recovered to a level that is not discernible from the surrounding terrain. During 2012, there were two 3D surveys re-visited within SA. CPSN08C Charo 3D 21/7/12 CPSN08D Callabonna 3D 22/7/12 The updated EMP reports have not yet been completed. 11.4.4 Environmental Report Forms

Environmental Report Forms (ERFs) are produced by the field crew members to highlight field practices, whether they are good or bad. Reports are forwarded through the Santos Environment Department. No ERFs were produced for the Greater Leleptian survey.

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Environmental Objectives and Performance – Geophysical Operations SEO Environmental

Objective Assessment Criteria Guide to How Objectives can be Achieved Performance

2012 Report Period Objective 1: Minimise the visual impact of operations.

Campsite and survey line preparation • Proposed survey lines and campsites have been

appropriately located and prepared to minimise the visual impact.

• The attainment of 0, +1 or +2 GAS criteria for ‘visual impact’ objective listed in Appendix 3.

• Pre-survey planning has been undertaken to

minimise visibility of operations and records are available for audit.

• Maximise use of vegetation or land forms to disguise operations

• Offset sand dune crest cuts along the length of the survey line to minimise visibility.

• Avoid extensive side cuts on dune flanks. • Lessen visual impact of uphole cuttings, where they

contrast with the surface, e.g. by use of appropriate colouring agents.

• Avoid cutting sand dunes facing tourist access tracks.

• All litter is to be disposed of correctly.

• Six EMPs (Objective 3 & Section 11)

were recorded and will be included in the final EMP report.

• Line preparation & survey crews camped at an existing drill rig campsite for Leleptian 3. Recording crew camped at a previously cleared area for a road works borrow pit.

• Some unavoidable side cuts were made on the eastern flanks of the dunes. No dune cuts visible from public roads. Whilst dune cuts were deeper than desired in places (GAS = -1, no -2 scores). The dune cuts were blowing in by the end of recording and no rehabilitation is expected although ongoing monitoring will be undertaken.

• No uphole drilling conducted. • All rubbish removed from lines.

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Environmental Objective

Assessment Criteria Guide to How Objectives can be Achieved Performance 2012 Report Period

Objective 2: Minimise disturbance to and contamination of soil resources.

Campsite & survey line preparation • Attainment of 0, +1 or +2 GAS criteria for

‘Minimise impacts to land surface’ objective, as listed in Appendix 3.

• Proposed survey lines and campsites have been appropriately located and prepared to minimise the disturbance to soil resources.

Fuel Storage and Handling No refuelling occurs outside designated

refuelling/servicing areas. Spills or leaks are immediately reported and clean

up actions initiated. Records of spill events and corrective actions are

maintained in accordance with company procedures.

Appropriate spill response equipment is available on site.

• Pre-survey planning has been undertaken to minimise

impacts of operations and records are available for audit.

• Survey line preparation techniques are monitored and documented to minimise soil disturbance, particularly in gibber and floodplain/wetland terrains.

• Gibber mantle has not been removed in gibber and tableland land systems.

• Gibber surface is not ripped at campsites. • Any requirement to traverse sensitive land systems and

the method of managing the impacts should be justified in accordance with company procedures. Any records should be available for audit.

• There is no evidence of off-road driving or creation of shortcuts.

• No survey line or access track preparation is carried out on salt lakes.

• Areas subject to inundation have been assessed for conduciveness to support vehicles.

• Oil spills areas have been ripped to an appropriate depth.

• No cases of soil contamination reported. • Line preparation & survey crews

camped at an existing drill rig campsite for Leleptian 3. Recording crew camped at a previously cleared area for a road works borrow pit.

• Only minimal rehab was required on completion- no drainage pits had been dug, no wheel ruts visible after restoration.

• No fuel spills reported. • Bulk fuel storage kept away from camp.

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Objective 3: Minimise disturbance to native vegetation and fauna.

Campsite and survey line preparation • The attainment of 0, +1 or +2 GAS criteria for

‘Impact on native vegetation’ objective listed in Appendix 3.

• No mature trees are removed. • Vehicle access to survey lines is to be via existing

access tracks or pre-existing survey lines, except where they have rehabilitated. Other temporary access tracks may be utilised where such use is likely to result in less environmental impact than other options.

Fuel and Chemical Storage and Management Refer to assessment criteria for objective. Fire Danger Season restrictions & education All personnel are fully informed on the fire danger season and associated restrictions.

• Terrain and vegetation is considered in planning stage when designing layout of the survey.

• Records of vegetation clearance/habitat disturbance are kept and available for auditing.

• Appropriately trained and experienced personnel have scouted proposed survey lines access tracks and campsites.

• Native vegetation clearance has been minimised and the conservation needs of particular species have been considered.

• Campsites are established in locations where the preparation of a new access track is not necessary.

Waste Management • Covered bins are provided for the collection and

storage of wastes. • All loads of rubbish are covered during transport to the

central waste facility. Fire Danger Season restrictions & education • Include Fire Season education as part of the induction.

• Line preparation & survey crews camped at an existing drillrig campsite for Leleptian 3. Recording crew camped at a previously cleared area for a road works borrow pit.

• Only minimal rehab was required on completion- no drainage pits had been dug, no wheel ruts visible on line after restoration.

• Waste stored in covered bins on camp and transported to Moomba for disposal.

• Fire risk was extreme on prospect. Fire risk addressed during planning and daily at toolbox meetings. No fire incidents occurred as a result of survey.

• Six EMPs established. Final report

delivered 26/11/12. GAS scores included within the EMP report.

Objective 4: Avoid disturbance to sites of cultural and heritage significance

The following is one possible procedure to achieve the objective. • Appropriately trained and experienced

cultural/heritage advisors have scouted proposed survey line locations and access tracks.

• The operator has a mechanism in place to appropriately report and respond to any sites discovered during survey operations.

• Any sites identified have been flagged and subsequently avoided.

Note: Where a negotiated agreement or determination for heritage is in place, compliance with the negotiated agreement or determination takes precedence over the above criteria. The EIR details this possible procedure.

The possible procedure may well be achieved by the following; • Documents and/or reports of scouting for

cultural/heritage are available for audit • Environmental Report Forms (ERF) to be completed for

any sites or artefacts identified. • The ERFs relating to Aboriginal sites are forwarded to

Department for Aboriginal Affairs and Reconciliation (DAARE).

Note: Where a negotiated agreement or determination for heritage is in place, provisions may include that appropriately trained and experienced cultural/heritage advisors will carry out a Work Area Clearance (WAC) and produce a report for sites of cultural and heritage significance before commencement of line preparation. This provision will take precedence over the above guideline. The EIR details these criteria for the possible procedure.

• Cultural Heritage clearance was completed by the Dieri people. The entire survey area was pre-cleared.

• A 50m corridor (25m either side of the programmed line) was cleared on the design access line location. Experienced dozer operators were used - all well versed in spotting sites as a backup.

• Multiple Sites were recorded and flagged off, particularly around the various waterholes. Detour routes were made around the sites.

• No non conformance occurred.



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Objective 5: Minimise disturbance to livestock, pastoral infrastructure and landholders.

• The attainment of 0, +1 or +2 GAS criteria for

‘Impact on infrastructure’ objective listed in Appendix 3.

• No reasonable concerns raised by stakeholders are left unresolved.

• The extent to which the relevant sections of the Petroleum Act and Regulations have been followed and implemented and in particular in relation to landowner liaison and notification.

• Relevant landowners and occupiers are notified prior to

survey of preparation of campsites, preparation of survey lines and undertaking of operations (pursuant to the Petroleum Regulations).

• Compliance with requirements of the Cattle Care and Organic Beef accreditation programmes.

• System is in place for logging landholder complaints to ensure that issues are addressed as appropriate.

• Seismic sources are not to operate within 20 m of any pipeline, utility, installation or building. This distance may need to be larger for explosive-sources, pending size of explosive used.

• Damage to station tracks is avoided. • Operations in wet weather are not allowed. • All gates are left in the condition in which they were

found (i.e. open/closed). • When necessary, all fences are restored to satisfaction

of landowner/managers • Induction for all employees and contractors covers

pastoral, conservation, legislation and infrastructure issues.

• Gidgealpa, Clifton Hills and

Mungerannie were officially permitted and then contacted prior to survey commencement.

• Comprehensive start up meeting / induction held on crew prior to work commencing.

• No problems for landholders. • Non operational zone around

infrastructure set at 50m. • Crew shutdown and demobilised by

helicopter following significant rain event. No road damage as a result.

• Gates / Grid left as found. • Restoration of fence lines access

required in places and has been completed to landholders satisfaction.

Objective 6: Avoid the introduction or spread of exotic species and implement control measures as necessary.

• Weeds or feral animals are not introduced into,

or spread, in operational areas

• All vehicles and equipment appropriately cleaned prior

to entering the Cooper Basin. • Vehicles and equipment are to be cleaned when

moving from areas within the Cooper Basin where weeds are present.

• Cleaning carried out in accordance with specified company procedures and accepted practices.

• Records of vehicle and equipment cleaning are kept and available for auditing.

• Records of detection, monitoring or eradication of exotic weed or other pest or noxious species introduced by industry activities are kept and are available for audit.

• Crew mobilised from Scarab Whanto 3D

project in SWQ for Greater Leleptian start up.

• No exotic weeds in previous survey

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Environmental Objective Assessment Criteria Guide to How Objectives can be Achieved

Performance 2012 Report Period

Objective 7: Minimise disturbance to drainage patterns and avoid contamination of surface waters and shallow groundwater resources.

Campsite and survey line preparation • Campsites and survey lines/traverses are located

and constructed to avoid diversion of water flows. • The attainment of 0, +1 or +2 GAS criteria for

‘disturbance to land surface’ objective listed in Appendix 3.

• No uncontrolled flows to surface from aquifers intersected in upholes/shallow boreholes.

• There is no unnecessary interference with natural drainage features.

Fuel Storage and Handling • No spills occur outside of areas designed to

contain them. • Refuelling occurs at least 1km from watercourses

or sensitive ecological environments (wetlands). • Appropriate spill response equipment is available

on site. • Spills or leaks are immediately reported and clean

up actions initiated promptly.

• All access through watercourses area carefully assessed

to determine the locations of least impact to channels and creek banks.

• Any artesian flows are to be immediately plugged and monitored to ensure effectiveness of plug(s).

• Any required remediation work carried out as soon as possible after completion of all activities

• If any contamination from spillage of oils or fuel occurs during vehicular operations, immediate effective clean-up procedures must be employed.

• Line preparation & survey crews

camped at an existing drill rig campsite for Leleptian 3. Recording crew camped at a previously cleared area for a road works borrow pit.

• Prospect was large dune field although

it did contain a couple of significant waterholes. Particular attention was paid to line preparation around watercourses. Santos conducted and environment audit during the survey and the crew were complimented on their work around the watercourses. No water courses impacted.

• No soil contamination was reported to

have occurred.

Objective 8: Optimise waste reduction and recovery.

• Wastes are segregated, burnt or transported to an

Environment Protection Authority (EPA) approved waste disposal facility for recycling or burial in accordance with approved procedures.

• 0, +1 or +2 GAS criteria are attained for ‘Negligible survey markers and rubbish in situ’ objective listed in Appendix 3.

• Production of waste is minimised by purchasing

biodegradable or recyclable materials where practical.

• • Waste transported to Moomba. • GAS audit indicated some pin flags

and pegs remained on line. These were subsequently removed.

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12. DRILLING AND WELL OPERATIONS

12.1 WELLSITE, CAMPSITE, BORROW PIT and ACCESS TRACK CONSTRUCTION & RESTORATION During this reporting period, 22 wellsite leases were either constructed or in the processes of being constructed which included 43.3 km of new tracks to provide access to these sites. A total of 51 borrow pits were necessary to provide fill for the tracks and leases.

The drilling sites scouted, constructed, backfilled and restored are listed in Appendix 4.

Partial restoration of drilling leases was carried out on 33 wells during 2012. 3.1 km of track and 10 borrow pits were restored. No borrow pits were sought by landholders.

Close consultation was maintained with pastoral lessees and National Parks rangers to ensure their interests and any issues raised remained high in consideration when conducting petroleum activities.

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Disturbance to sites of Aboriginal and European heritage was avoided. Santos trained staff is used to scout sites prior to work commencing on the construction of sites and access. Where necessary, a consultant archaeologist is engaged to ensure heritage sites are avoided.

12.2 DRILLING OPERATIONS The drilling operations conducted by Santos are undertaken in accordance with the Statement of Environmental Objectives for Drilling and Well Operations and the Santos Drilling Management System and Drilling Operations Manual. Well casing design is undertaken in accordance with Santos procedures and industry guidelines, which take account of the pressures, stresses, risks, loads and the environmental conditions which exist in each circumstance. A total of 30 wells were drilled by the SACBJV. All were cased and suspended for later completion. There were also 4 wells drilled in PEL 114 by Santos A list of wells drilled by the SACBJV and Santos in 2012 is provided in Appendix 11.

12.3 DRILLING ACTIVITY – 2013 The major activity planned for 2013 (number indicated are only approximate) includes the following,

- 48 wells to be drilled - construct flow lines to connect successful wells to the production system

- the construction of access tracks, borrow pits and campsites as necessary - completion or re-completion operations - fracture stimulations

12.4 WELL COMPLETION, WORKOVER, PRODUCTION, SUSPENSION and ABANDONMENT

There were 215 individual workover operations conducted during 2012. Of these 10 were for PEL 114. This involved 31 Fracture Stimulation operations. Workover activities included casing repair, down-hole pump installation/repair, well completion or re-completion, Integrity repairs, water well conversion and perforation operations. These activities are listed in Appendix 5. At the end of this reporting period there were a total of 402 oil (185 producing) and 926 gas or gas/oil (524 producing) Santos operated wells. 648 wells (producing, inactive or suspended) were subject to casing annulus pressure testing. Appendix 6 provides additional details.

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12.4.1 Monitoring of Wells Monitoring of well casing annuli pressure continued. Available data was reviewed and risk assessments completed to determine the best means to effectively mitigate the risk of these wells. There was one high risk well. The number of substantial and moderate risk wells is as follows: o One well was rated as a Level 4 (High risk), Moomba 26; however this risk was mediated by setting a suspension plug. o 35 wells were rated as Level 3 (Substantial risk). These wells have a remaining mild steel barrier. Workovers will repair

3 of the Level 3 risk wells in 2013. o 202 wells were rated as Level 2 (Moderate risk). These wells were able to be topped up and inhibit 1 of 2 remaining

mild steel barriers. Appendix 6 provides additional details.

12.5 WELL TESTING, COMPLETION and WORKOVER ACTIVITY – 2013 The corrosion monitoring and annulus pressure testing program will continue in 2013. 3 Workovers are planned to address and repair well integrity issues.

12.6 WELL/LEASE ABANDONMENT 10 leases were remediated during 2012.

12.7 DOWNHOLE WELL ABANDONMENT – 2012 No wells were plugged and abandoned post completion in 2012.

12.8 DOWNHOLE WELL ABANDONMENT – 2013 There are 2 well abandonments planned for in the 2013 work program.

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Environmental Objectives .,and Performance – Drilling and Well Operations SEO Environmental

Objectives Assessment Criteria Guide to How Objectives Can Be Achieved Performance

2012 Report Period

Objective 1: Minimise the risk to public and other third parties.

• Reasonable measures

implemented to ensure no injuries to the public or third parties.

All employees and contractor personnel complete a safety induction

prior to commencement of work in the field. All employees and contractor personnel undertake a refresher

induction every 2 years. Signage in place to warn third parties of access restrictions to

operational areas, with particular warnings when potentially dangerous operations are being undertaken.

Necessary measures (e.g. signage/fencing) taken to prevent the public accessing the wellhead equipment or waste relating to a given well.

Demobilisation inspections undertaken at random to ensure that backfilling and waste removal requirements are met.

Permit to work systems in place for staff and contractors in dangerous situations.

All appropriate PPE (personnel protective equipment) is issued and available as required in accordance with company operating requirements and applicable standards.

Effective Emergency Response Plan (ERP) and procedures are in place in the event of a fire or explosion; Annual exercise of ERP.

Communication of rig moves and other potential hazards to safety associated with drilling and well operations to potentially affected parties prior to commencement of operations.

Compliance with relevant speed restrictions on access roads and tracks.

Reporting systems for recording injuries and accidents in place, and annual (at minimum) review of records to determine injury trends.

Implementation of appropriate corrective actions. Ensuring safety management plans are updated and reviewed. Wastewater disposal in accordance with Objective 11.

There were no injuries to the public or any third parties arising from Drilling and Well operations in 2012. All Santos and Santos Contract employees attend a compulsory safety induction prior to commencing work. Refresher training is provided at regular intervals. Signs are installed at strategic locations in the operating area to deter the public from accessing drilling and production areas and when potentially hazardous tasks are undertaken. A specific Wellsite Permit-to-Work system is used to manage workplace / worksite safety. Personnel are provided with the relevant, approved PPE when undertaking potentially hazardous tasks. Emergency Response Plans and procedures are in place. These procedures are regularly exercised with identified improvements included into the ERPs. Relevant parties are advised of potentially hazardous operations before they are undertaken. An electronic accident and incident recording system is used to report and monitor accidents, incidents and trends. Safety Management Plans, including KPIs, have been developed and introduced by Santos and its contractors. These are regularly reviewed and updated. Emergency Response procedures for well operations were reviewed and updated during this reporting period.

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Environmental Objectives

Assessment Criteria Guide to How Objectives Can Be Achieved Performance 2012 Report Period

Objective 2: Minimise disturbance and avoid contamination to soil.

Well Site and Access Track Construction 0, +1 or +2 GAS

criteria are attained for “Minimise impacts on soil” objective as listed in Appendix 1 Table A1 and “To minimise the visual impact” as listed in Appendix 1 Table A2.

No unauthorised off-road driving or creation of shortcuts.

No construction activities are carried out on salt lakes or steep tableland slopes (as defined in EIR).

Borrow pit construction and restoration 0, +1 or +2 GAS

criteria are attained for “Minimise visual impacts’, and “Minimise impact on soil” objectives as listed in Appendix 1 Table A3.

Production Testing/Well Blowdowns No soil contamination

as a result of production testing or well blowdown operations.

Well Site and Access Track Construction Consider alternate routes during planning phase to minimise

environmental impacts. Use existing routes / disturbed ground where practicable. Gibber mantle on access tracks and well sites (excluding sumps) is

not removed where possible, only rolled, in gibber and tableland land systems. Gibber mantle reinstated where appropriate during restoration.

Topsoil stockpiled (including gibber mantle) from sump construction and respread (and gibber recompacted) on abandonment.

The need to traverse sensitive land systems and the methods of managing the impacts must be justified in accordance with company procedures, recorded and available for auditing.

Borrow pit construction and restoration Existing borrow pits to be re-used where practicable. Siting of new borrow pits to avoid sloped areas and gibber as far as

practicable. Topsoil stockpiled (including gibber mantle) and respread on

abandonment (gibber to be recompacted). Production Testing / Well Blowdowns If appropriate use:

- impermeable or clay lined flare pit to flare / contain hydrocarbons. - flare tanks.

Soil disturbance is minimised wherever possible. Rootstock is left intact and top soil is stockpiled for respreading. This is respread during site restoration. Off-road driving is actively discouraged. Alternate routes are considered in planning. Work is restricted to ROW. No construction activity is carried out on salt lakes, steep tablelands or wetland systems. Audits of construction activity are undertaken with high level of performance. Borrow pit construction is minimised by reuse of any suitable existing borrow pit/s. Borrow pits are restored on an ongoing basis to ensure the most time efficient restoration Gas well post fracture stimulation activities remained largely unchanged with dry gas wells typically only flowed 4 to 5 days to atmosphere (flaring where possible) to clean up frac fluids prior to the wells being shut in and connected. Liquids rich gas wells were flowed for similar durations, but were flowed through separators to capture the liquids with the gas going to flare. Different styles of separator are being trialled with the ultimate intention being to capture all produced water and liquids from post frac clean up.

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Environmental


2012 Report Period

Objective 2 cont: Minimise disturbance and avoid contamination to soil.

Fuel and Chemical Storage and Handling No spills/leaks outside

of areas designed to contain them.

Level of hydrocarbon continually decreasing for in situ remediation of spills.

Soils remediated to a level as determined by the SHI process.

Also refer to Objective 12.

Waste Disposal (domestic, sewage and sludges) All domestic wastes

are disposed of in accordance with EPA licensing requirements.

0, +1 or +2 GAS criteria are attained for “Site to be left in a clean and tidy condition” objective listed in Appendix 1 Table A2.

No spills or leaks from sewage treatment processing.

Refer to Assessment Criteria for Objective

Fuel and Chemical Storage and Handling All fuel, oil and chemical storages bunded in accordance with the

appropriate standards and guidelines e.g. EPA guideline 080/07 Bunding and Spill Management.

Records of spill events and corrective actions maintained in accordance with company procedures.

Spills or leaks are immediately reported and clean up actions initiated. Logged incidents are reviewed annually to determine areas that may

require corrective action in order to reduce spill volumes in subsequent years (and drive continual improvement).

Chemical and fuel storage procedures, including signage, are reviewed and monitored in audit process.

Spill Response / Contingency Planning Results of emergency response procedures carried out in accordance

with Regulation 31 show that an oil spill contingency plan in place in the event of a spill is adequate and any necessary remedial action needed to the plan is undertaken promptly.

Oil spill contingency plan (reviewed annually) is up to date with specific scenarios relating to spills to creeks and floodplain areas.

Spill response equipment is audited annually. Annual spill response training exercise / rehearsal is undertaken. Spills or leaks are immediately reported and clean up actions initiated. Waste Disposal (domestic, sewage and sludges) Covered bins are provided for the collection and storage of wastes. All loads of rubbish are covered during transport to the central waste

facility. Approved transportable Aerated Wastewater Treatment Plants (AWTPs)

used for rigs/camps (once approved AWTPs are available from a supplier suitable to Santos1). Interim controls for management of sewage effluent (developed in consultation with the Department of Health) implemented1.

Use of permanent septic systems with camps where possible Refer to Objective 11.

No spills occurred outside areas designed to contain them. SACBJV learnings from Incidents were reviewed to enable improvement strategies to be identified and are applied to other Santos operated PEL and PPLs No oil spill is likely to have impacted ground water. Records of spills are maintained. Spills are reported in accordance with legislative and company requirements. Incident registers are reviewed to determine areas requiring improvement and to ensure ongoing improvement. Domestic wastes are disposed of in accordance with EPA License Requirements. Audits identified good Performance Waste bins and containers are covered during Transport New landfill cell completed and approved by EPA Landfill cells are located only at Authorised facilities and are fenced to exclude stock and wildlife There were no incidents at installed sewage disposal Facilities

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11.



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Objective 3: Avoid the introduction or spread of pest plants and animals and implement control measures as necessary.

No weeds or feral animals

are introduced to, or spread in, operational areas as a consequence of activities.

Where appropriate a weed and feral animal management strategy is in

place (avoidance and control strategies). Rig and vehicle wash downs are initiated in accordance with the

management strategy.

Weed and feral animal strategies are in place. There is no evidence of the introduction of weeds or feral animals. Vehicles and rig equipment is washed in accordance with the management strategy.

Objective 4: Minimise disturbance to drainage patterns and avoid contamination of surface waters and shallow ground water resources.

Well Lease and Access Track Construction Well sites and access

tracks are located and constructed to maintain pre-existing water flows (i.e. channel contours are maintained on floodplains and at creek crossings).

Drilling Mud Sumps and Flare Pits No overflow of drill

cuttings, muds and other drilling fluids from mud sumps.

No waste material disposal to sumps and flare pits.

Well Heads (Oil and Gas Systems) No leaks/spills outside of

areas designed to contain them.

Well Lease and Access Track Construction Sensitive land systems (e.g. wetlands) avoided wherever possible.

Where activities are undertaken in or near these areas, appropriate review, assessment and mitigation measures are in place to ensure that surface water flows are maintained and contamination of surface water and groundwater is avoided.

Drilling Mud Sumps and Flare Pits All drill cuttings, muds and non toxic drill fluids are contained within the

designated mud sumps with adequate freeboard at the completion of operations to allow for a 1m cover of clean fill at remediation.

Well Heads (Oil and Gas Systems) Where appropriate, imperviously lined well cellars are installed on oil

wells. Bunds / containment devices are installed on gas well skids. Well heads shut in and chemicals removed prior to flood events. Jet pumps are installed within containment device with an adequately

sized containment sump.

Drainage channels and patterns are maintained or restored to minimise impeding or changing natural drainage patterns associated with well leases, access tracks and roads and at creek crossings.

Work programs are modified to avoid periods of flooding and other seasonal influences and variations.

No overflow of drilling mud sumps occurred. No waste material is disposed of in drilling mud sumps or flare pits. Investigated alternatives for impervious lining for well cellars. Automatic shutdown of wellhead pumps investigated and devices progressively fitted to all beam pumps to shutdown pump if Polished rod packer fails. Wells are shut-in and wellhead equipment is removed in areas to be impacted by flooding. Jet-pumps are installed with 9M3 sumps.

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Objective 4 cont Minimise disturbance to drainage patterns and avoid contamination of surface waters and shallow ground water resources.

Well Blowdown/Production Testing No water (surface or

groundwater) contamination as a result of production testing or well blowdown operations.

Fuel/Chemical Storage and Handling No water (surface or

groundwater) contamination as a result of fuel or chemical storage and handling.

Well Blowdown/Production Testing Activity is conducted in accordance with accepted industry standards /

good oilfield practice. If appropriate use:

- impermeable / clay lined flare pit - flare tanks - separators - supervision.

Fuel and Chemical Storage and Handling All fuel, oil and chemical storages bunded in accordance with the

appropriate standards (e.g. AS 1940 and EPA guideline 080/07 Bunding and Spill Management).

Records of spill events and corrective actions maintained in accordance with company procedures.

Spills or leaks are immediately reported and clean up actions initiated. Logged incidents are reviewed annually to determine areas that may

require corrective action in order to reduce spill volumes in subsequent years (and drive continual improvement).

Chemical and fuel storage procedures, including signage, are reviewed and monitored in audit process.

Waste Management Refer to Objective 11. Spill Response / Contingency Planning Results of emergency response procedures carried out in accord with

Regulation 31 show that oil spill contingency plan in place in the event of a spill is adequate and any necessary remedial action needed to the plan is undertaken promptly.


Spill response equipment is audited annually. Annual spill response training exercise / rehearsal is undertaken.

See Objective 2 above. Records of spills are maintained Spills which occurred outside areas designed to contain them are reported at quarterly meetings. Spills are reported in accordance with legislative and company requirements. Incident registers are reviewed to determine areas requiring improvement and to ensure ongoing improvement. Soil removed to land farm in some instances to eliminate contamination. No spill is likely to have impacted ground water. Emergency response procedures for spill response are in place and regularly exercised. Learning from exercises and actual events are included in Plans. Oil Spill Plans are up-to-date and regularly drilled. Spill response equipment and procedures are regularly audited.

Regular drills are conducted.

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Objective 5: Avoid disturbance to sites of cultural and heritage significance.

Proposed well sites and

access tracks have been surveyed and any sites of Aboriginal and non-Aboriginal heritage identified.

Any identified cultural and heritage sites have been avoided.

Consultation with stakeholders (i.e. government agencies, landholders

etc) in relation to the possible existence of heritage sites, as necessary.

Heritage report forms completed for any sites or artefacts identified, and report forms forwarded to the Aboriginal Heritage Branch, Aboriginal Affairs and Reconciliation Division (AARD).

Survey records are kept and are available for auditing. Areas requiring remediation which lie outside previously surveyed

sites should be surveyed in accordance with company heritage clearance procedures.

A procedure is in place for the appropriate response to any sites discovered during drilling activities.

Note: Where a negotiated agreement or determination for heritage clearance is in place, compliance with the negotiated agreement or determination takes precedence over the above criteria.

Construction sites are inspected for cultural heritage sites. Identified sites are avoided. Significant sites are fenced. Identified sites are avoided.

Objective 6: Minimise loss of aquifer pressures and avoid aquifer contamination.

Drilling & Completion Activities There is no uncontrolled

flow to surface (blow out). Sufficient barriers exist in

casing annulus to prevent crossflow between separate aquifers or hydrocarbon reservoirs.

Relevant government approval obtained for abandonment of any radioactive tool left downhole.

Drilling & Completion Activities

A competent cement bond between aquifer and hydrocarbon reservoirs is demonstrated.

For cases where isolation of these formations is not established, a risk assessment incorporating the use of pressure / permeability / salinity data is undertaken in consultation with DLWBC & SAALNRM Board to determine if lack of cement or poor bond will cause or has caused damaging crossflow which needs to be remediated.

There were no well bore failures reported

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Objective 6 Cont: Minimise loss of aquifer pressures and avoid aquifer contamination

Producing, Injection, Inactive and Abandoned Wells • No cross-flow behind casing

between aquifers, and between aquifers and hydrocarbon reservoirs unless approved by DFW.

Producing, Injection and Inactive Wells

Monitoring programs implemented (e.g. through well logs, pressure measurements, casing integrity measurements and corrosion monitoring programs) to assess condition of casing and cross-flow behind casing.

Casing annulus pressures are monitored every 2 years. The condition of the primary casing barrier is adequate. For cases where crossflow is detected, a risk assessment

incorporating the use of pressure / permeability / salinity data is undertaken in consultation with DFW & SAALNRM Board to determine if lack of cement or poor bond will cause or has caused damaging crossflow which needs to be remediated.

Well Abandonment Activities

Isolation barriers are set in place to ensure that crossflow, contamination or pressure reduction will not occur.

Barriers will be set to meet or exceed the requirements of applicable standards for the decommissioning and abandonment of water bores and abandonment of petroleum wells. The placement of isolation barriers will in general be to isolate the groups of formations as listed under comments. The number and placement of barriers may be varied from this standard approach on a case-by-case basis by Santos personnel using relevant available data and the SA Cooper Basin Water Pressure and Salinity Module Report (2002), and in consultation with DFW.

Corrosion monitoring, pressure measurements and casing integrity monitoring programs undertaken on a regular basis. Wells prioritised for remedial action based on condition of casing barriers. Cement bond logs conducted on new wells for baseline indication of cement bond.

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Objective 7: Minimise disturbance to native vegetation and native fauna.

Well Lease and Access Track Construction and Restoration Any sites with rare,

vulnerable and endangered flora and fauna have been identified and avoided.

0, +1 or +2 GAS criteria are attained for “Minimise impact on vegetation” objective as listed in Appendix 1 Table A1 and “The revegetation of indigenous species” objective as listed in Appendix 1 Table A2, during well lease and access track site selection and construction and restoration.

Borrow Pit Construction and Restoration 0, +1 or +2 GAS criteria

are attained for “Minimise impacts on vegetation” objectives as listed in Appendix 1 Table A3 during borrow pit site selection, construction, and restoration.

Waste Management Refer to assessment

criteria for Objective 11. Fuel and Chemical Storage and Handling • Refer to assessment criteria for Objectives 2 and 4.

Well Lease and Access Track Construction and Restoration Proposed well sites, camp sites, access tracks and borrow pit sites

have been assessed for rare, vulnerable and endangered flora and fauna species before the commencement of construction.

Consider alternate routes during planning phase to minimise environmental impacts

Sensitive land systems (e.g. wetlands) avoided wherever possible. Where activities are undertaken in these areas (i.e. no practicable alternative), appropriate review, assessment and mitigation measures are in place.

Facilities (e.g. borrow pits, well cellars) are designed and constructed as far as practicable to minimise fauna entrapment.

Sumps and mud pits are fenced as appropriate to minimise wildlife access

Assessment records are kept and are available for auditing. In recognised conservation reserves (i.e. Innamincka Regional

Reserve) excavations are left in a state as agreed with the responsible statutory body

Borrow pits are restored to minimise water holding capacity, where agreements are not in place with stakeholders.

Waste Management Covered bins are provided for the collection and storage of putrescible

wastes. All loads of rubbish are covered during transport to the central waste

facility. Refer to Objective 11. Fuel and Chemical Storage and Handling Refer to Objectives 2 & 4. Fauna Management No domestic pets allowed at camps or worksites. Feeding of wildlife (e.g. dingoes) is not permitted.

Study undertaken to determine habitats for rare, vulnerable and endangered species. Areas identified are avoided. Vegetation impacts are minimised during well lease access and construction by scouting surveys prior to the entry of construction machinery. Wherever possible, significant vegetation is avoided. Borrow pit site selection provides for the avoidance of vegetation impacts. Borrow pits are restored on an ongoing basis to allow natural vegetation regrowth to recommence. Where necessary, borrow pits are reopened to minimise vegetation impacts.

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Assessment Criteria Guide to Objectives Achievement Performance 2012 Report Period

Objective 8: Minimise air pollution and greenhouse gas emissions.

Performance to EPA

requirements.

Well Testing Conduct well testing in accordance with appropriate industry accepted

standards. Continually review and improve operations. Appropriate emergency response procedures are in place for the case

of a gas leak. Well Blowdown Blowdown carried out in accordance with industry accepted standards /

good production practice. Any well that is consistently blown down is identified for a small ID

tubing or plunger lift installation to minimise blow downs on that well.

Petroleum engineering activities are continuously reviewed for opportunities to minimise air pollution and greenhouse gas emissions. Emergency response procedures are in place, are regularly tested and improvements identified are included in the plans.

Objective 9: Maintain and enhance partnerships with the Cooper Basin community.

No unresolved reasonable

complaints from the community.

Relevant affected parties are notified and consulted on proposed

activities. Forward development plans are presented to the local community. Local community projects and events are sponsored and supported

where appropriate. Industry membership of appropriate regional land management

committees and boards

Relevant parties are notified and consulted on proposed activities. There were no complaints, concerns or issues left unresolved. Local community events and activities are actively supported. Membership and active participation is made to regional management committees and Boards.

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Objective 10: Avoid or minimise disturbance to stakeholders and/or associated infrastructure

No reasonable

stakeholder complaints left unresolved.

Induction for all employees and contractors covers pastoral,

conservation, tourism, legislation and infrastructure issues. Relevant stakeholders are notified prior to survey and construction of

well sites, camp sites and access tracks and undertaking of operations (pursuant to Regulations). Borrow pits left open (unrestored) if requested by landholder and upon receipt of letter of transfer of responsibility to landholder.

Gates or cattle grids are installed to a standard, consistent with pastoral infrastructure in fences where crossings are required for access.

All gates left in the condition in which they were found (i.e. open/closed).

Potential sources of contamination are fenced as appropriate to prevent stock access.

Excavations are located and managed so as not to pose an unacceptable hazard to stock or wildlife.

System is in place for logging landholder complaints to ensure that issues are addressed as appropriate.

Requirements of the Cattle Care and Organic Beef accreditation programs are complied with.

In recognised conservation reserves (e.g. Innamincka Regional Reserve) excavations are left in a state as agreed with the responsible statutory body (e.g. DEH).

The importance of developing and maintaining good relationships with landholders is stressed to all employees and contractors. Relevant stakeholders are notified of and consulted about projects and are provided with information, maps etc. No Borrow pits were formally transferred to landholders. Grids, fences, gates installed are to a standard acceptable to the landholder. All gates are left “as found”. In response to concerns regarding potential for contamination of cattle an extensive fencing of facilities program was completed in 2005 and continues to be installed and repaired as required Landholder complaints and requests are logged to ensure closeout. There were no complaints lodged. Cattle management systems (cattle care) are recognised and complied with.

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Objective 11: Optimise waste reduction and recovery.

All wastes to be disposed

of at an EPA licensed facility in accordance with EPA Licence conditions, with the exception of drilling fluids, drill cuttings, other fluids disposed during well clean-up and wastewater (see below).

Wastewater (sewage and grey water) disposed of in accordance with the Public and Environmental Health (Waste Control) Regulations 1995 or to the Department of Health’s satisfaction.

Attainment of GAS criteria for “Site to be left in clean, tidy and safe condition” objective during well site restoration.

Attainment of GAS criteria for “Site left in clean and tidy condition” objective during borrow pit restoration

Chemicals and oil are purchased in bulk. “Bulki bins” or other storage

tanks are in place for large volume items. Covered bins are provided for the collection and storage of putrescible

wastes. All loads of rubbish are covered during transport to a licensed waste facility.

Waste streams are segregated on site to maximise opportunities for waste recovery, reuse and recycling.

Coordinate covered waste transportation on backload. Production of waste is minimised by purchasing specifying reusable,

biodegradable or recyclable materials in procurement, where practical. Drilling fluids, drill cuttings and other fluids are disposed of to sump on

the Act licence area. Waste water (sewage) disposal is where possible in accordance with

the Public and Environmental Health (Waste Control) Regulations 1995 (which require that the waste water disposal system must either comply with the Standard for the Construction, Installation and Operation of Septic Tank Systems in SA or be operated to the satisfaction of the Department of Health) and the Environment Protection (Water Quality) Policy 2003.

Grey water is disposed of to the sewage treatment system. Secondary treated sewage wastewater is disposed of onto land well

away from any place from which it is reasonably likely to enter any waters, and to minimise spray drift and ponding, in accordance with clause 11 of the Environment Protection (Water Quality) Policy 2003.

Chemicals, cement & inhibitors are purchased in bulk containers. Waste material is disposed of at EPA Approved facilities.

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Objective 12: Remediate and rehabilitate operational areas to agreed standards.

No unresolved reasonable

stakeholder complaints. Contaminated Site Remediation Contaminated sites are

remediated in accordance with criteria developed with the principles of the National Environment Protection Measure for Contaminated sites and in consultation with the EPA.

Well Site and Access Track Restoration The attainment of 0, +1 or

+2 GAS criteria for: - “minimise visual

impact of abandoned well sites”

- “minimise visual impact of abandoned access tracks”

- “re-establish natural vegetation on abandoned well sites and access tracks”

Borrow Pit Restoration The attainment of 0, +1 or

+2 GAS criteria for: - “minimise impact on

vegetation” - “minimise impact on

soil” - “Minimise visual

impacts” Note: Well abandonment

issues addressed under objective 6.

Rehabilitation/ abandonment plans for surface activities will be

developed in consultation with relevant stakeholders Well Site and Access Track Restoration Compacted soil areas have been ripped (except on gibber and

tablelands) and soil profile and contours are reinstated following completion of operations.

No complaints raised by stakeholders.

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13. PRODUCTION & PROCESSING FACILITY OPERATIONS During 2012, there were,

- 78.4 petajoules (PJ) of sales gas produced into the Moomba - Adelaide and Moomba – Sydney gas pipelines.

- 11.2 PJs of ethane produced into the Moomba – Sydney ethane pipeline. - 255 mL of gas condensate produced to Port Bonython. - 8.781 mm Barrels (BBLS) of crude oil exported to Port Bonython.

During 2012, the pipeline, flowline and trunkline network delivered natural gas, Ethane, Condensate and Crude Oil to the Moomba Plant resulting in the export volumes listed in the Table below,

Sales Gas Ethane LPG Condensate Crude Oil

(PJ) (PJ) (Kt) (Ml) (mm BBLS)

78.4 11.2 193.0 255 8.781

The above Crude Oil includes the following :

(mm BBLS)

PEL114 (includes PPL 225, 226, 227 for 2012) 0.094

PPL 225, 226 & 227 (Stimpee, Hoek, Stimpson Jay, Teringie & Frostillicus) (does not include Cartman) 0.084

Derrilyn & Toparoa 0.056

Reg Sprigg West 0.001

13.1 PRODUCTION FACILITY PROJECTS During 2012 a number of plant and field facility projects were completed and a listing of some of these is provided in Appendix 10a. There are a number of projects that have continued to be progressed or were commenced previously, these are listed in Appendix 10b, as are those that are planned to commence in 2012.

13.1.1 MOOMBA PLANT In the Moomba Plant, the major activities included,

- Moomba Sludge Treatment Plant – New Facility - Moomba Power and Steam Efficency Improvement Project

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- Moomba Plant Buried Lines

13.2 PRODUCTION FORECAST – 2013 The estimated gas and liquids production and export volumes from the Moomba Plant for 2013 are as listed below,

Sales Gas (PJ) - export 94.79

Ethane (PJ) (Qenos Demand) 8.74

LPG (Kt) 202.9

Condensate (Kbbls) 1768

Crude Oil (Block and Unit) (mm bbls) 4.911

The above Crude Oil includes the following :

(mm BBLS)

PEL114 (includes PPL 225, 226, 227 for 2013) 0.178

PPL 225, 226 & 227 (Stimpee, Hoek, Stimpson Jay, Teringie & Frostillicus only) (does not include Affogato/Cartman/Chimmichurri/Chivito/Hoff/Moe/Wallace/Wollemi that are part of PEL114)

0.090

Derrilyn & Toparoa 0.038

Reg Sprigg West 0.001

Estimated Third Party Deliveries from Moomba 4.204

2013 Gas Storage Estimates (Moomba and Chookoo)

Opening Storage (PJ) Sales Gas + ethane 38.94

Net Storage Injection / (Withdrawal) (PJ) 11.4

Total Closing Sales Gas and Ethane Storage (PJ) 50.34

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13.3 PIPELINE CONSTRUCTION, OPERATION AND MONITORING During the reporting period the Cathodic Protection (CP) units and pipeline voltage potentials in the Cooper Basin were monitored bi-monthly for protected pipelines. Performance survey along protected pipelines is normally completed on an annual basis as per AS 2885 requirements.

Most batch treatment of gas and oil trunklines and gathering lines, normally carried out in an annual basis, were completed in accordance with Santos’ Integrity Management Plans. Pipeline right of ways, normally inspected during the annual Cathodic Protection were generally completed in line with IMP requirements, except where excessive flooding prevented access.

Corrosion inhibitor was injected into raw gas pipelines at wells and satellite stations. Inhibitor pumps were monitored and maintained at intervals ranging from monthly to three monthly as prescribed by Santos’ Integrity Management Plan. The biocide injection facilities on the major oil transmission lines, to manage microbiological corrosion, have been upgraded to pulse injection systems.

Water samples were obtained from flowlines for residual amine and dissolved iron analysis, with the results used to optimise the corrosion inhibitor injection rates on gas pipelines. In addition samples were taken to determine the source of microbiological induced corrosion (MIC).

MIC continuous improvement program continues to be implemented and improved, driven by a steering committee made up of personnel from integrity, laboratories and production. The program has identified activities which include pigging, pipeline suspension, and source of bacteria, 3rd party contamination, biocide, design, and procedures. During 2012, pipelines and flowlines were constructed to connect new wells to the production system, as listed in Appendix 7. Various inspections, repairs and testing was undertaken on pipelines as listed in Appendix 8, a program covering in line inspection of key pipelines was also continued. The Pipeline Management System was further enhanced during 2012 by improving the standard of integrity management plans, rationalising the risk distribution in all fields and completing annual Pipeline Integrity Reviews (PIR) and detailed risk reviews. This process has been supported by further development of the Pipeline Integrity Database, KPI reporting and IMP compliance tracking to support the Management System and provide the heart of the pipeline task management and records management system.

.

13.4 LICENSED PIPELINES This report also covers the Licensed Pipelines covered by Pipeline Licenses Numbers 5 (Ballera to Moomba), 9 (Stokes to Mettika) and License No. 15 (Moon to Kerna) flowline.

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The activities carried out in relation to PL 5, PL 9 and PL 15 are administered in accordance with each pipeline’s individual integrity management plan (IMP). The IMPs have been created to ensure each pipelines integrity and compliance with the Petroleum Act (2000), Petroleum Regulations (2000) and the relevant SEO’s. There were no incidents recorded on any of the Licensed Pipelines. The reporting of Environmental Objectives and Performance – Production and Processing SEO, are covered in detail in this report and are considered to also address the performance in respect to the pipeline SEOs.

Various inspections, repairs and testing were undertaken on the Licensed Pipelines, details specific to each pipeline are as follows:

13.4.1 PL 5 – Ballera to Moomba Pipeline Internal Corrosion Mitigation • Continuous inhibitor injection of 10.0ltrs per day (IRN341A target rate, the

injector system was monitored monthly) • The pipeline was operationally pigged on 13th October 2012 • The pipeline was batch treated with corrosion inhibitor on 13th October 2012 • Pig Launcher treated with corrosion inhibitor on 19th October 2012; Pig Receiver

treated on 16th December 2012

External Corrosion Mitigation • The operation of CP Units associated with the pipeline were checked bi-monthly. • A complete Cathodic Protection Test Post Potential survey was performed in

October 2012 indicating full compliance with the AS 2832 ‘Off Potential’ criteria.

Inspection • The ROW patrol was performed October 2012. ROW observed to be in good

condition • Pig Receiver was inspected in July 2012, and found to be in good condition

13.4.2 PL 9 – Stokes to Mettika Pipeline Internal Corrosion Mitigation • Continuous inhibitor injection of 5.0ltrs per day (IRN341A target rate, the injector

system was monitored monthly) • The pipeline was operationally pigged on six-weekly basis as per the pipelines

IMP (100% Compliance for 2012) • The pipeline was batch treated with corrosion inhibitor on 15th September 2012. • Pig Launcher & Pig Receiver were both treated with corrosion inhibitor on 15th

September 2012. External Corrosion Mitigation • The operation of CP Units associated with the pipeline were checked bi-monthly. • A complete Cathodic Protection Test Post Potential survey was performed in

February 2012 indicating full compliance with the AS 2832 ‘Off Potential’ criteria.

Inspection

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• An In-Line Inspection (ILI) was performed in July 2011. Detailed analysis of results has been completed and is under internal review. Any remedial actions will be completed during 2013.

• The ROW patrol was performed February 2012. ROW observed to be in good condition.

13.4.2 PL 15 – Moon to Kerna Pipeline Internal Corrosion Mitigation • Continuous inhibitor injection of 2.0ltrs per day (IRN341A target rate, the injector

system was monitored monthly)

External Corrosion Mitigation • The operation of CP Units associated with the pipeline were checked bi-monthly. • A complete Cathodic Protection Test Post Potential survey was performed in

March 2012 indicating full compliance with the AS 2832 ‘Off Potential’ criteria.

Inspection • The ROW patrol was performed March 2012. ROW observed to be in good

condition. Product transported through Licensed pipelines in 2012 was: Sales Gas (PJ) Ethane (PJ) LPG (Kt) Cond (Ml)

Ballera to Moomba 17.7 2.2 44.8 66.2 Stokes to Mettika 1.3 0.2 3.5 4.1

Moon to Kerna 0.06317 0.00886 0.07135 0.05374

13.5 ROAD AND WELLSITE LEASE AND ACCESS CONSTRUCTION AND RESTORATION

A large network of roads is maintained in order to provide access to production sites and to drilling locations. Roads are maintained to agreed standards, dependent upon application and the frequency of use. Performance against the Production and Processing SEO is described in the following table.

13.5.1 WELLSITE LEASE AND ACCESS CONSTRUCTION AND RESTORATION Access to drilling locations and the wellsite area is constructed following the scouting of individual locations to identify a route which has the least environmental impact. A total of 43.3 Km of access road was constructed during 2012 and 3.1km of road was restored. The drilling sites scouted, constructed, backfilled and restored are listed in Appendix 4.

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There were 51 borrow pits constructed during 2012, to provide fill for well lease and related road construction, and 10 borrow pits were restored. No borrow pits were transferred to the land holder.

13.5.2 ROAD CONSTRUCTION No major road construction projects were undertaken in 2012, minor roads associated with new drilling leases made up most of the new roads constructed in 2012.

13.6 WATER EXTRACTION FROM COOPER CREEK In accordance with the Production and Processing SEO water extraction from the Cooper Creek is allowed under specific criteria related to flow in the Cooper Creek, refer objective 4. During 2012 Santos took no water under this allocation.

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Santos Ltd ABN 80 007 550 923 PPL 225, 226 and 227 Santos Operations

Environmental Objectives and Performance – Production and Processing SEO Environmental


2012 Report Period

Objective 1: Minimise any safety risk to public and other third parties.

• Reasonable measures

implemented to ensure no injuries to the public or third parties.

All employees and contractor personnel complete a safety induction prior to

commencement of work in the field. All employees and contractor personnel undertake a refresher induction

every 2 years. Signage in place to warn third parties of access restrictions to operational

areas, with particular warnings when potentially dangerous operations are being undertaken.

Necessary measures (e.g. signage/fencing) taken to prevent the public accessing the wellhead equipment or waste relating to a given well.

Demobilisation inspections undertaken at random to ensure that backfilling and waste removal requirements are met.

Permit to work systems in place for staff and contractors in dangerous situations.

All appropriate PPE (personnel protective equipment) is issued and available as required in accordance with company operating requirements and applicable standards.

Effective Emergency Response Plan (ERP) and procedures are in place in the event of a fire or explosion; Annual exercise of ERP.

Communication of rig moves and other potential hazards to safety associated with drilling and well operations to potentially affected parties prior to commencement of operations.

Compliance with relevant speed restrictions on access roads and tracks. Reporting systems for recording injuries and accidents in place, and annual

(at minimum) review of records to determine injury trends. Implementation of appropriate corrective actions. Ensuring safety management plans are updated and reviewed. Wastewater disposal in accordance with Objective 11.

There were no injuries to the public or any third parties Induction training is provided to all Santos and contractor Employees Refresher training is provided. Signs are placed to warn the public about the hazards associated with accessing production areas. A Work Permit System, which is regularly audited, is in place. Santos and Contractor personnel are provided the appropriate PPE. Effective emergency response plans exist, which are regularly exercised. Regular emergency exercises are conducted. Communication of potentially hazardous or unusual tasks is made to affected parties prior to being undertaken. Injury and incident recording and reporting systems are maintained.

Safety management plans are reviewed and updated regularly.

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Objective 2: Minimise disturbance and avoid contamination to soil.

Construction Activities (e.g. pipelines and roads) No evidence of

significant subsoil on surface (colour) on the pipeline ROW following construction.

No subsidence is evident over pipeline trench.

At pipeline dune crossings, dune profiles have been restored consistent with surrounding dune profiles.

No visual evidence of soil compaction following remediation of the pipeline easement (e.g. hard soil, local water pooling).

The extent of erosion on the ROW is consistent with surrounding land.

No unauthorised off-road driving or creation of shortcuts.

No construction activities are carried out on salt lakes or steep tableland slopes (as defined in EIR).

0, +1 or +2 GAS criteria are attained for goals related to this objective

Construction Activities (e.g. pipelines and roads) Santos operational procedures and guidelines are in place and will be

followed for construction activities, for example to conserve soil resources: topsoil is stockpiled separately from subsoil and respread during

reinstatement

no windrows remain after pipeline construction (except on dunes where some windrows are inevitable after reprofiling but will quickly disappear

if a crown over the pipeline trench is left to alleviate subsidence, periodic breaches are left to avoid channelling water flows down the ROW

areas of compacted soil are ripped Consider alternate routes during planning phase to minimise environmental

impacts. Works are restricted to construction ROW. The need to traverse sensitive land systems and the method of managing

the impacts must be justified in accordance with company procedures, recorded and available for auditing.

Annual audit of construction practices. Spill Response / Contingency Planning Results of emergency response procedures carried out in accordance with

Regulation 31 show that an oil spill contingency plan in place in the event of a spill is adequate and any necessary remedial action needed to the plan is undertaken promptly.


Spill response equipment is audited annually. Annual spill response training exercise is undertaken. Refer to Section 3 “Reporting” for clarification of incident reporting

requirements

Soil disturbance is minimised wherever possible. Rootstock is left intact and top soil is stockpiled for respreading. This is respread during site restoration. Off-road driving is actively discouraged. Alternate routes are considered in planning. Work is restricted to ROW.

No construction activity is carried out on salt lakes, steep tablelands or wetland systems.

Audits of construction activity are undertaken with high level of performance.

Borrow pit construction is minimised by reuse of any suitable existing borrow pit/s. Borrow pits are restored on an ongoing basis to ensure the most time efficient restoration

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Objective 2 cont: Minimise disturbance and avoid contamination to soil

Fuel and Chemical Storage, Handling and Transportation No spills/leaks outside


Soils remediated to a level as determined by the SHI Decision Framework.

Also refer to Objective 12.

Oil/Condensate Spills (Pipeline/Road Transport) No spills/leaks outside




Produced Formation Water (PFW) • 0, +1 or +2 GAS criteria are attained for goals related to produced formation water impacts on soil. • PFW EMP developed

and objectives achieved.

Fuel and Chemical Storage, Handling and Transportation All fuel, oil and chemicals are stored, handled and transported in

accordance with appropriate standards and guidelines e.g. Australian Standard AS 1940, Australian Dangerous Goods (ADG) Code, EPA guidelines 080/07 Bunding and Spill Management.

Fuel and chemical storage, handling and transport procedures are reviewed and monitored in audit process.

Records of spill events and corrective actions are maintained in accordance with company procedures.

Spills or leaks are immediately reported and clean up actions initiated. Logged incidents are reviewed annually to determine areas that may require

corrective action to reduce spill volumes in subsequent years (and drive continual improvement).

Audit against EHSMS standards for underground storage tanks and bunds on a four yearly minimum frequency.

Oil/Condensate Spills (Pipeline/Road Transport) Pipelines are compliant with AS2885 pipeline standards Pipeline Management System is reviewed annually. Pipelines are inspected and maintained in accordance with Pipeline Integrity

Management System Spills or leaks are immediately reported and clean up actions initiated. Records of spill events and corrective actions are maintained in accordance

with company procedures. Produced Formation Water (PFW) Develop (in consultation with PIRSA and the EPA) and implement Environmental Management Plan (EMP) following the PFW facility status review that has been conducted.

Spills that occurred outside areas designed to contain them are reported at quarterly meetings.

Records of spills are maintained.

Spills are reported in accordance with legislative and company requirements.

Incident registers are reviewed to determine areas requiring improvement and to ensure ongoing improvement.

There were four events reported that related to groundwater impacted by hydrocarbon leaks. Phase Separated Hydrocarbon (PSH) was detected at each location (refer Section 5.1). These locations were at Dullingari &

Daralingie

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Objective 2 cont: Minimise disturbance and avoid contamination to soil

Waste Disposal (domestic, sewage and sludges) All domestic wastes are

disposed of in accordance with EPA licensing requirements.

No evidence of rubbish or litter on ROW or at campsites / facilities.

No spills or leaks from sludge treatment process and sludge pits.

No increase in contamination at LTUs designated treatment area. Refer to assessment criteria for Objective 11.

Waste Disposal (domestic, sewage and sludges) Site activities to be audited against EPA licence for Waste Depot on a

minimum two years schedule. EHS04 Waste Management is adhered to. Audit against EHS04 Waste Management – 4 yearly minimum. Covered bins are provided for the collection and storage of wastes. All loads of rubbish are covered during transport to the central waste facility. Disposal areas are not established in locations, which pose an unacceptable

hazard to stock or wildlife. Sewage treatment facilities to be operated in accordance with design

criteria. Refer to Objective 11.Refer to Objective 11.

Domestic wastes are disposed of in accordance with EPA License Requirements. Audits identified good performance. Waste bins and containers are covered during transport. New landfill cell in operation & is as per EPA licence Landfill cells are located only at Authorised facilities and are fenced to exclude stock and wildlife. There were no incidents at installed sewage disposal facilities.

Objective 3: Avoid the introduction or spread of pest plants and animals and implement control measures as necessary.

No weeds or feral

animals are introduced to, or spread in, operational areas as a consequence of activities.

Weed management plans are implemented where priority weed species are identified.

Where appropriate, weed and feral animal management strategy is in place

(avoidance and control strategies). Vehicle and equipment wash downs to be initiated in accordance with the

management strategy.

Weed and feral animal strategies are in place. There is no evidence of the introduction of weeds or feral animals. Vehicles and rig equipment is washed in accordance with the management strategy.

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Assessment Criteria

Guide to How Objectives Can Be Achieved Performance 2012 Report Period

Objective 4: Minimise disturbance to drainage patterns and avoid contamination of surface waters and shallow ground water resources.

Construction Activities (e.g. pipelines and roads) 0, +1 or +2 GAS criteria are

attained for goals related to this objective as listed in Appendix 1 and 2.

Construction activities (e.g. access tracks or pipelines) are located and constructed to maintain pre-existing water flows (i.e. channel contours are maintained on floodplains and at creek crossings).

No water (surface or groundwater) contamination as a result of construction activities.

Produced Formation Water (PFW) Refer to assessment criteria

for Objective 2. No unlicensed discharge of

water to a creek, river or lake.

PFW Waterflood No significant change in

surface or groundwater contamination as a result of waterflood activities.

Construction Activities (e.g. pipelines and roads) • Constructed activities undertaken are designed and managed

to avoid diversion of water flows. • Sensitive land systems (e.g. wetlands) avoided wherever

possible. Where activities are undertaken in or near these areas, appropriate review, assessment and mitigation measures are in place to ensure that surface water flows are maintained and contamination of surface water and groundwater is avoided.

Produced Formation Water (PFW) Refer to Objective 2. Water disposal ponds are located away from areas which are

inundated during floods where possible (preferably above the 100-year flood level).

Interceptor pits are not located in areas prone to inundation by flooding.

PFW Waterflood Pumps and associated equipment installed within containment

device with an adequately sized containment sump (e.g. at least 9m3).

Refer to Objective 2.

Drainage channels and patterns are maintained or restored to minimise impeding or changing natural drainage patterns associated with well leases, access tracks and roads and at creek crossings.

Work programs are modified to avoid periods of flooding and other seasonal influences and variations.

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Objective 4 cont Minimise disturbance to drainage patterns and avoid contamination of surface waters and shallow ground water resources.

Fuel and Chemical Storage, Handling and Transportation Soils remediated to a level

as determined by the SHI Decision Framework. Also refer to Objective 12.

No water (surface or groundwater) contamination as a result of these activities.

Cooper Creek Water Extraction No significant change in flow or

contamination as a result of extraction activities.

Fuel and Chemical Storage, Handling and Transportation All fuel, oil and chemicals are stored, handled and transported

in accordance with appropriate standards e.g. Australian Standard AS 1940, Australian Dangerous Goods (ADG) Code, EPA guideline 080/07 Bunding and Spill Management.

Fuel and chemical storage, handling and transport procedures are reviewed and monitored in an audit process.

Records of spill events and corrective actions are maintained in accordance with company procedures.

Spills or leaks are immediately reported and clean up actions initiated.

Logged incidents are reviewed annually to determine areas that may require corrective action to reduce spill volumes in subsequent years (and drive continual improvement).

Implementation of the SHI Decision Making Framework approved in January 2010.

Cooper Creek Water Extraction Approval to conduct surfacewater extraction from Cooper Creek is subject to the following conditions: An approvals request for any proposed extraction is raised

internally. This request will include estimated total volume required.

The above request must demonstrate that PFW and Borewater of an acceptable quality cannot be sourced within an economically viable haulage distance (maximum 2 hour return journey).

Any approved extraction occurs where water flow at Callamurra is >= 2.15m (>= 0.1m flow at Innamincka Causeway) and rising, and never at permanent water refuges (e.g Callamurra). Maps of approved surfacewater extraction points at Innamincka, Kudrieke and Mitchie Crossings are included in Appendix 2 of the EIR Addendum (Santos, 2010).

Cumulative extraction volume to be capped at 15 ML per year. Cumulative extraction volumes to be recorded in monitoring

database and included in annual PIRSA reporting. Non-conformance with the above is a reportable incident - see

Section 3 “Reporting” for incident definitions.

Records of spills are maintained Spills are reported in accordance with legislative and company requirements. Incident registers are reviewed to determine areas requiring improvement and to ensure ongoing improvement. Santos took no water from the Cooper Creek under this allocation.

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Objective 4 cont Waste Disposal (domestic, sewage and sludges) Refer to assessment criteria

for Waste Disposal for Objective 2.

Refer to assessment criteria for Objective 11.

Oil/Condensate Spills (Pipeline/Road Transport) No spills/leaks outside of

areas designed to contain them.



Waste Disposal (domestic, sewage and sludges) Site activities to be audited against EPA licence for waste depot

on a minimum of every two years. Audit against EHS04 Waste Management – 4 yearly minimum. Covered bins are provided for the collection and storage of

wastes. All loads of rubbish are covered during transport to the central

waste facility. Pits are not established in locations which pose an

unacceptable hazard to stock or wildlife. Sewage treatment facilities to be operated in accordance with

design criteria. Oil/Condensate Spills (Pipeline/Road Transport) Pipelines are compliant with AS2885 pipeline standards. Pipeline Management System is reviewed annually. Pipelines are inspected and maintained in accordance with

Pipeline Integrity Management System. Spills or leaks are immediately reported and clean up actions

initiated. Records of spill events and corrective actions are maintained in

accordance with company procedures. Refer to Section 3 “Reporting” for clarification of incident

reporting requirements Spill Response / Contingency Planning Results of emergency response procedures, carried out in

accord with Regulation 31, show that the oil spill contingency plan in place in the event of a spill is adequate and any necessary remedial action needed to the plan is undertaken promptly.


Spill response equipment is audited annually. Annual spill response training exercise is undertaken.

Soil removed to land farm in some instances to eliminate contamination. No spill is likely to have impacted ground water.

Emergency response procedures for spill response are in place and regularly exercised. Learnings from exercises and actual events are included in Plans. Oil Spill Plans are up-to-date and regularly drilled. Spill response equipment and procedures are regularly audited. Regular drills are conducted.

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Objective 5: Avoid disturbance to sites of cultural and heritage significance.

Proposed well sites and

access tracks have been surveyed and any sites of Aboriginal and non-Aboriginal heritage identified.

Any identified cultural and heritage sites have been avoided.

Consultation with stakeholders (i.e. government agencies,

landholders etc) in relation to the possible existence of heritage sites, as necessary.

Heritage report forms completed for any sites or artefacts identified, and report forms forwarded to the Aboriginal Heritage Branch, Aboriginal Affairs and Reconciliation Division (AARD).

Survey records are kept and are available for auditing. Areas requiring remediation which lie outside previously

surveyed sites should be surveyed in accordance with company heritage clearance procedures.

A procedure is in place for the appropriate response to any sites discovered during drilling activities.

Note: Where a negotiated agreement or determination for heritage clearance is in place, compliance with the negotiated agreement or determination takes precedence over the above criteria.

Construction sites are inspected for cultural heritage sites. Identified sites are avoided. Significant sites are fenced. Identified sites are avoided.

Objective 6 Minimise loss of aquifer pressure and avoid aquifer contamination.

There is no uncontrolled

flow to the surface (i.e. no free flowing bores).

Produced Formation Water (PFW) Waterflood Injection Wells

No significant change in water quality from the injection aquifer

The volume/flow of water used by the Moomba Plant is

continuously monitored to ensure appropriate management. Water usage is monitored, reviewed and management

strategies implemented to minimise wastage. Review water licensing requirements and allocation plans. Produced Formation Water (PFW) Waterflood Injection Wells Aquifer water quality monitored where appropriate through

testing carried out during Waterflood activities.

There were no well bore failures reported

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Assessment Criteria


Objective 7: Minimise disturbance to native vegetation and native fauna.

Construction Activities Any sites of rare,

vulnerable and endangered flora and fauna have been identified, flagged and subsequently avoided.

No removal of trees / vegetation of priority 1, 2 or 3 in Field Guide1 in areas where removal could have been avoided.

No removal of trees at campsites.

No evidence of tree removal where trimming appropriate.

The type and density of vegetation on the rehabilitated ROW is consistent with the surrounding landscape, but less mature. Note: assessment will take into account that regrowth is a time and rainfall dependent process.

0, +1 or +2 GAS criteria are attained for goals related to this objective as listed in Appendix 1 and 2.

Construction Activities Proposed construction areas have been assessed for rare,

vulnerable and endangered flora and fauna species before the commencement of construction.

Consider alternate routes during planning phase to minimise environmental impacts.


Assessment records are kept and are available for auditing. Optimised ROW widths are identified and implemented. Trees are trimmed rather than cleared where possible. Root stock is not removed beyond 3m of trenchline and ROW is

either only lightly graded or not graded. Where vegetation is removed, it is respread over the full width of the ROW (excluding the access track).

Study undertaken to determine habitats for rare, vulnerable and endangered species. Areas identified are avoided. Vegetation impacts are minimised during well lease access and construction by scouting surveys prior to the entry of construction machinery. Wherever possible, significant vegetation is avoided.

1 Field Guide refers to the Field Guide to the Common Plants of the Cooper Basin – South Australia and Queensland (Wiltshire and Schmidt 2003)

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Assessment Criteria


Objective 7 Cont Borrow Pits 0, +1 or +2 GAS criteria

for goals related to this objective, as listed in Appendix 1 are attained during site selection and construction.

Fuel and Chemical Storage and Management Refer to assessment

criteria for objectives 2 and 4.

Waste Management Refer to assessment

criteria for Objective 2, 4 and 11.

Borrow Pits Pits are not established in locations which pose an unacceptable

hazard to stock or wildlife (i.e. not within 50m of any roads or access tracks, well leases or other plant and equipment).


Borrow pits are restored as soon as practicable after material extraction is complete to a standard consistent with the surrounding land use.

Borrow pits are restored to minimise water holding capacity, where agreements are not in place with stakeholders

In recognised conservation reserves (i.e. Innamincka Regional Reserve) excavations are left in a state as agreed with the responsible statutory body.

Fuel and Chemical Storage and Management Refer to Objectives 2 & 4.

Waste Management Covered bins are provided for the collection and storage of

putrescible wastes. All loads of rubbish are covered during transport to the central

waste facility. Pits are not established in locations which pose an unacceptable

hazard to stock or wildlife. Sewage treatment facilities to be operated in accordance with

design criteria. PFW pits are fenced as appropriate to minimise wildlife access.

Borrow pit site selection provides for the avoidance of vegetation impacts. Borrow pits are restored on an ongoing basis to allow natural vegetation regrowth to recommence. Where necessary, borrow pits are reopened to minimise vegetation impacts.

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Assessment Criteria


Objective 7 Cont Native Vegetation Act SEB Significant Environmental

Benefit (SEB) for native vegetation clearance approved by PIRSA (where delegated authority applies) or Native Vegetation Council (NVC).

Significant environmental benefit obligation is ultimately satisfied / implemented.

Fauna Management Native fauna

casualties associated with construction activities restricted to as low as reasonably practical (ALARP).

Native Vegetation Act SEB Work (or payment to Native Vegetation Fund) undertaken to

achieve an SEB for native vegetation clearance. SEB requirement either:

- determined using the Guidelines (DWLBC 2005) or - negotiated with PIRSA or the Native Vegetation Council

where SEB calculation differs from the standard methodology in the Guidelines.

Fauna Management No domestic pets allowed at camps or worksites. Feeding of wildlife (e.g. dingoes) is not permitted. Where possible, provision of fauna exit ramps every 500m in

open trenches, with other mechanisms for fauna exit (branches, mesh etc.) at more regular intervals in between.

Inspection of trenches and removal of trapped fauna, where appropriate.

Minimise length of time trench is open where practicable.

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Assessment Criteria Guide to Objectives Achievement Performance 2012 Report Period

Objective 8: Minimise air pollution and greenhouse gas emissions.

Gathering Systems/Satellite Facilities/Moomba Plant Compliance with EPA

requirements.

Gathering Systems/Satellite Facilities/Moomba Plant Conduct production operations in accordance with

appropriate industry accepted standards. Continually review and improve operations. Appropriate Emergency Response Procedures are in place

in case of a gas leak.

Gas well post fracture stimulation activities remained largely unchanged with dry gas wells typically only flowed 4 to 5 days to atmosphere (flaring where possible) to clean up frac fluids prior to the wells being shut in and connected. Liquids rich gas wells were flowed for similar durations, but were flowed through separators to capture the liquids with the gas going to flare. Different styles of separator are being trialled with the ultimate intention being to capture all produced water and liquids from post frac clean up.

Objective 9: Maintain and enhance partnerships with the Cooper Basin community.

No reasonable stakeholder

complaints left unresolved.

Relevant affected parties are notified and consulted on

proposed activities. Forward development plans are presented to the local

community. Local community projects and events are sponsored and

supported where appropriate. Industry membership of appropriate regional land

management committees and boards

Relevant parties are notified and consulted on proposed activities. There were no complaints, concerns or issues left unresolved. Local community events and activities are actively supported. Membership and active participation is made to regional management committees and Boards.

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Objective 10: Avoid or minimise disturbance to stakeholders and/or associated infrastructure

No reasonable stakeholder

complaints left unresolved. Cooper Creek Water Extraction No impacts on local

stakeholders from the extraction of water from the creek system.

Refer to Objective 4.

Induction for all employees and contractors covers pastoral,

conservation, tourism, legislation and infrastructure issues. Relevant stakeholders are notified prior to survey and

construction of well sites, camp sites and access tracks and undertaking of operations (pursuant to the Regulations). Borrow pits left open (unrestored) if requested by stakeholder and upon receipt of letter of transfer of responsibility to stakeholder.

Gates or cattle grids are installed to a standard, consistent with pastoral infrastructure instead of fences where crossings are required for access.

All gates left in the condition in which they were found (i.e. open/closed).

Fences repaired to ‘as before’ standard following pipeline construction.

Potential sources of contamination (e.g. formation water ponds) are fenced as appropriate to prevent stock access.

Written evidence that stakeholder is satisfied with water disposal arrangements.

System is in place for logging stakeholder complaints to ensure that issues are addressed as appropriate.

Requirements of the Cattle Care and Organic Beef accreditation programs are complied with.

In recognised conservation reserves (i.e. Innamincka Regional Reserve) excavations are left in a state as agreed

Cooper Creek Water Extraction Refer to Objective 4.

The importance of developing and maintaining good relationships with landholders is stressed to all employees and contractors. Relevant stakeholders are notified of and consulted about projects and are provided with information, maps etc. No Borrow pits were formally transferred to landholders. Grids, fences, gates installed are to a standard acceptable to the landholder. All gates are left “as found”. In response to concerns regarding potential for contamination of cattle an extensive fencing of facilities program was completed in 2005 and continues to be installed and repaired as required Landholder complaints and requests are logged to ensure closeout. There were no complaints lodged. Cattle management systems (cattle care) are recognised and complied with.

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Objective 11: Optimise (in order of most to least preferable) waste avoidance, reduction, reuse, recycling, treatment and disposal

Domestic wastes are disposed

of in accordance with EPA licensing requirements.

Wastewater (sewage and grey water) disposed of in accordance with the Public and Environmental Health (Waste Control) Regulations 1995 or to the Department of Health’s satisfaction.

No spills or leaks from sludge treatment process and sludge pits.

No increase in contamination at LTUs designated treatment area

Chemicals and oil are purchased in bulk. ‘Bulki bins’ or

other storage tanks are in place for large volume items. Fencing around waste disposal facility is regularly inspected

and maintained. Waste streams are segregated on site to maximise

opportunities for waste recovery, reuse and recycling. Evidence/records are maintained showing that recyclable

material has been returned to Moomba Waste Management Depot.

Production of waste is minimised by specifying reusable, biodegradable or recyclable materials in procurement, where practical.

Waste audit conducted at 5 year minimum interval. Waste water (sewage) disposal is where possible in

accordance with the Public and Environmental Health (Waste Control) Regulations 1995 (which require that the waste water disposal system must either comply with the Standard for the Construction, Installation and Operation of Septic Tank Systems in SA or be operated to the satisfaction of the Department of Health) and the Environment Protection (Water Quality) Policy 2003.

Evidence/records maintained to show that appropriately designed sewage facilities have been constructed.

Chemicals, cement & inhibitors are purchased in bulk containers.

Waste material is disposed of at EPA Approved facilities.

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Objective 12: Remediate and rehabilitate operational areas to agreed standards.

Contaminated Site Remediation Contaminated sites are

remediated to a level as determined by the approved SHI Decision Framework.

Construction Site and Access Track Restoration Refer to assessment criteria for

Objectives 2, 4, 7 and 11. 0, +1 or +2 GAS criteria are

attained for ‘minimise the visual impact’ and ‘revegetation of indigenous species’ as listed in Appendix 4.

Borrow Pit Restoration The attainment of 0, +1 or +2

GAS criteria as in Appendix 1. Production Facility Abandonment Surface structures are

removed and the ground surface re-contoured to approximate pre-existing contours unless alternative agreement is reached with the regulator and stakeholders.

0, +1 or +2 GAS criteria are attained for ‘minimise the visual impact’ and ‘revegetation of indigenous species’ as listed in Appendix 4, unless alternative agreement is reached with the regulator and stakeholders.

Refer to criteria for contaminated site remediation under this objective (above).

Refer to the assessment criteria for Objective 11.

Rehabilitation/abandonment plans for regulated activities will

be developed in consultation with relevant stakeholders. Construction Site and Access Track Restoration Compacted soil areas have been ripped (except on gibber and tablelands) and soil profile and contours are reinstated following completion of operations. Production Facility Abandonment The following steps will typically be undertaken unless otherwise agreed with the regulator and stakeholders: hydrocarbon and contaminants will be reduced to an

acceptable level in buried structures (e.g. pipelines, tanks, pits) as determined by the approved SHI Decision Framework.

hazardous materials will be stabilised or removed including ground decontamination.

hazardous material dumps will be clearly marked and a monitoring plan developed and implemented.

surface structures will be removed and re-used / recycled where appropriate

waste will be removed and recycled where appropriate (refer to Objective 11).

foundations will be levelled and covered (the standard to which they will be restored will be defined as a result of stakeholder consultations).

disturbed areas will be re-contoured to approximate pre-existing contours, natural drainage restored and compaction relieved (e.g. by scarification or ripping where appropriate) to promote rainwater infiltration and enhance seed capture and germination.

contour banks and energy dissipating structures will be constructed where necessary to protect disturbed areas from erosion prior to stabilisation

No stakeholder complaints are unresolved. No contaminated sites Access tracks are restored in accordance with restoration guidelines. No Activity

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Objective 12 Cont: Pipeline Abandonment Attainment of the following (unless otherwise agreed with stakeholders and approved by the regulatory authority): No evidence of waste,

redundant equipment / infrastructure or signs and markers on abandoned pipelines.

Refer to criteria for contaminated site remediation under this objective (above).

Refer to the assessment criteria for Objective 11.

Pipeline Abandonment The following steps will typically be undertaken unless otherwise agreed with the regulator and stakeholders: all aboveground pipes and supports will be assessed for the

condition of the pipe for either salvage or for dismantling and re-use.

all underground pipe work will be cut-off (at a minimum depth of 750mm below the natural surface or at pipeline depth, removed and blinded below the surface.

all aboveground signs and markers will be removed. all pipeline protection systems will be removed to allow the

pipeline to degrade in-situ. monitoring and auditing of abandoned pipelines will be

undertaken. all pipelines which are partially or wholly left in-situ will be

accurately mapped and recorded. Records will be prepared and submitted to the appropriate authority.

No Activity

Objective 13: Minimise as far as reasonably practicable interruptions to natural gas supply.

No interruptions to natural gas supply that cause significant social disruption.

Adequate contingencies are in place which seek to address a prudent level of security of supply in the case of short and unforseen interruption events (e.g. adequate gas storage).

Pipelines are designed, operated and maintained in accordance with AS 2885.

Plant and equipment are designed, operated and maintained in accordance with appropriate industry accepted standards.

Emergency Response Plan (ERP) and associated procedures are in place and exercised.

Results and recommendations of plant and facility hazard reviews, including the five (5) yearly Fitness for Purpose assessment, are appropriately addressed.

Significant operations-specific hazards and risks are summarised in the Significant Hazard Risk Register (SHRR).

There were no gas supply reduction events from the Moomba Plant during 2012.

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14 REPORTS ISSUED DURING THE 2012 LICENCE YEAR The following reports were generated for Santos purposes or forwarded to DMITRE or others in 2012.

• EHSMS Assessment results 2012• Sustainability Report 2012• EMP for Greater Leleptian 3D 2012 Report• Significant Environmental Benefits Summary July 2011 to June 2012• Bushfire Preparedness Report

15. STATEMENT OF ACTUAL AND PROPOSED EXPENDITURE2012/2013

Confidential

16. GLOSSARY OF TERMSAEGR Asset Engineering Governance Review AAL Associated Activity Licence AIMS Asset Integrity Management System ALARP As Low As Reasonably Practicable APPEA Australian Petroleum Production and Exploration Association

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Santos Ltd ABN 80 007 550 923 SACBJV Operations BBLS Barrels CP Cathodic Protection DA Direct Assessment DCVG Direct Current Voltage Gradient DISCEX Discussion Exercise DPCU Dew Point Control Unit DFW Department for Water (previously DWLBC) DMITRE Department for Manufacturing, Innovation, Trade, Resources and Energy (previously PIRSA) EALT Eastern Australia Leadership Team EHS Environment, Health and Safety EHSMS Environment, Health and Safety Management System EIR Environmental Impact report EIS Environmental Impact statement EPA Environment Protection Authority EPIRB Emergency Position Indicating Radio Beacon EOC Emergency Operations Centre EMP Environmental Monitoring Point ERF Environmental Report Forms ERP Emergency Response Plan ESP Electric Submersible Pump EUE External Upset Tubing Connection FAIR Fixed Asset Integrity Review FSA Formal Safety Assessment GAS Goal Attainment Scaling GLNG Gladstone Liquefied Natural Gas GRE Glass Reinforced Epoxy HAZOP Hazard and Operability ILI In-Line Inspection IMP Integrity Management Plan KPI Key Performance Indicator Kbbls Kilo barrels (1,000 barrels) Kt Kilo tonne (1,000 tonnes) LRP Liquids Recovery Plant LTU Land Treatment Unit MHF Major Hazard Facility MIC Microbiological Induced Corrosion MOC Management of Change mL mega litre (1,000,000 litres) mm BBLS Million barrels OPREX Operational Exercise PAMS Pipeline Asset Management System PEL Petroleum Exploration License PHS Phase Separated Hydrocarbon PJ Peta-joule (a unit of heat) PL Pipeline Licence PFW Produced Formation Water PCP Progressive Cavity Pump PPL Petroleum Production License PPE Personal Protective Equipment PSM Process Safety Management RFDS Royal Flying Doctor Service ROW Right of Way (for pipelines) SACB South Australian Cooper Basin SACBJV South Australian Cooper Basin Joint Venture SEO Statement of Environmental Objectives SHRR Significant Hazard Risk Register SHI Soil Health Index SIMP Santos Incident Management Plan SOP Standard Operating Procedure SWSA Safe Work SA TEWT Tactical Exercise without Troops VSP Vertical Seismic Profile WOPRA Whole of Plant Risk Assessment

17. APPENDICES Appendix 1 DMITRE Meetings - 2012

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Appendix 2 Environmental Incidents Summary - 2012

Appendix 3 Emergency Drills - 2012

Appendix 4 Well Drilling Lease Scout, Construct, Backfill and Restoration - 2012

Appendix 5 Well Workover Summary - 2012

Appendix 6 Well Summary – Producing and Suspended Wells

Appendix 7 Flowlines Constructed – 2012

Appendix 8 Pipeline Inspection, Testing and Repair - 2012

Appendix 9 Details of Seismic Activity Appendix 10a 2012 Production Facility Projects

Appendix 10b 2012 Production Facility Projects – Proposed Appendix 11 Wells Drilled - 2012 Appendix 12 2012 Reports, including Geological and Reserves Reports

Appendix 1 DMITRE Meetings – 2012 Over and above the significant reporting requirement to DMITRE associated with the conduct of operations in the Cooper Basin under the Petroleum and Geothermal Energy

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Act (2000) and Petroleum and Geothermal Energy Regulations (2000), a series of regular meeting are held with DMITRE at quarterly intervals, to review performance. These meetings included the following: Quarterly Santos / DMITRE Performance Meeting

4th Quarter, 2010 - 18 February 2012 1st Quarter, 2012 - 6 May 2012 2nd Quarter, 2012 - 5 August 2012 3rd Quarter, 2012 - 4 November 2012 2012 Development Plan & Operational Review - 19 May 2012

Appendix 2 Environmental Incidents Summary - 2012 Total Incidents

66 % of Total Incidents Comments

Location

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Plant Field -Satellite/Facility -Wells -Pipelines -Other

6

18 45

12 18

Spills Crude Oil Condensate PFW Chemical Lube Oil Hydraulic Oil Diesel Grey Water/Sewage

38 8 35 11 21 3 3 2

Spills can be multiple components eg Crude and PFW

Volume >100 m3 21 – 99 m3 6 - 20 1 - 5 500lt – 1m3 100lt – 499lt 50lt – 99lt 10lt – 49lt 5lt – 10lt <5lt

2 5 - 9 5 9 17 35 9 6

3 events ground water contamination – no volumes

Root Cause – DMITRE Design Monitoring & Maintenance Work Practices Communication Supervision Risk Management Induction/Training

9 73 14 - - 2 -

Consequence Moderate Minor Negligible

- 14 86

Risk Low Moderate Substantial

94 6 -

REPORTABLE to DMITRE 2012 – Includes NOTIFIABLE WORK RELATED INJURY OR DANGEROUS OCCURRENCE

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Total Incidents 28

% of Total Incidents Comments

Report Type Injury Dangerous Occurrence Reportable to DMITRE

- 6 94

Location Plant Field -Satellite/Facility -Wells -Pipelines -Other Camp

31

14 3 49 3 -

Root Cause – DMITRE Design Monitoring & Maintenance Work Practices Communication Supervision Risk Management Induction/Training Other

3 80 14 - - - - 3

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Appendix 3 Emergency Drills – 2012 Date Drill Type Description of Scenarios Comment Actions

20/05/2012 EOC DISCEX EOC Exercise – Tank 3000 leak

This will be treated as a DISCEX ONLY after initial page to attend EOC

The exercise will be instigated by a pager message sent to all EOC personnel by Security. The details of the call will be that the Area operator has discovered a leak in tank 3000 on the eastern side and dialled 222. The leak started out minor, but is increasing with time and is becoming a major concern with signs of metal fatigue appearing around the leak. The area operator has evacuated the area.

The response will be in compliance with Santos procedures, EHSMS 13 Emergency Preparedness and the SA Road Traffic Act.

Objective Outcomes:

1 To measure the time it takes for the EOC participants to arrive at EOC from initial page

2 To practice the exchange of Security personnel from call taker and page dispatcher to relocate to the second communications room to take on all EOC communications and SWQ operator to handle all field transmissions

3 Provide a skills maintenance opportunity for the EOC personnel, Asses the roles and responsibilities of each EOC personnel

• Receiving the 222 call and initiating page, writing down relevant details of the incident and relocating was completed in a timely and effective manner.

• All EOC personnel had a good understanding of their respective roles within the EOC room and were evident in the discussions and tactical approach to the situation, all vests were donned correctly, Excellent ideas were raised on handling the situation and thoughts going into a contingency plan for a breach in bund. Any ideas raised were discussed on how to achieve the desired outcome by input from everyone, not just relying on the one person who raised it.

• Action: Emergency services to visit Field services to

familiarise with the amount and types of spill bunds that they stock

• Action: Purchase and install digital clock for Event Historian.

• Action: Investigate why mobile white board is in EOC, and relocate if not required.

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30/06/2012 OPREX Scenario

Field Services contact Moomba Comms with report of a motor vehicle accident and one IP still inside vehicle at a nominated location identified by local reference.

Moomba Comms to page Emergency Services and RFDS as per standard procedures. T/L ES to deploy personnel and equipment to achieve required objectives.

Objectives

• Assess effectiveness of response procedures for a report of Motor Vehicle Accident/person trapped within the Cooper Basin.

• Assess effectiveness of the deployment by helicopter of appropriate personnel and equipment to facilitate rescue and recovery of injured person.

• Practice stowage of medical and rescue equipment on a Bell 206 Long Ranger aircraft.

• Practice evacuation of IP by helicopter and transport to medical care facility in Moomba.

The exercise was well attended and all associated learning’s and actions were captured in the final emergency response exercise report

Action: Include Pilot Coordinator mobile phone number into procedure.

Action: Restraining strap to be fitted to LH cabin door to hold open while loading/unloading.

Action: Write procedure for loading rescue equipment into helicopter boot. Include photomap and loading Action: solution template into procedure.

Investigate types of plastic cribbing available to supplement rescue equipment.

Action: RFDS to write procedure for loading/unloading casualty in/out of helicopter.

Action: Ensure each E/S vehicle has two HiViz vests for use on airfield.

27/05/2012 DISCEX Central Fields Maintenance

Grass Fire & Injured person

An operator undertakes welding repairs to a piece of field equipment. A spark from the welding ignites a grass fire. Several attempts are made to extinguisher the grass fire, but it becomes unsafe and unachievable to extinguish.

The DISCEX was completed to a high standard. All participants gained a good idea of what was required if they were confronted with this type of emergency.

• Learning: There are varies methods of extinguishing a fire. Discussed what methods would have the most and least effect on extinguishing a grassfire.

• Discussed that knapsacks are available from stores that can be used to extinguish a fire and that they are re-usable.

• Action: Purchase Knapsacks. • Learning: If an emergency is required to be called in

over the radio the words “Priority, Priority, Priority” are to be used.

• Action: Bush Fire Awareness presentation to be delivered.

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One operator receives minor burns to his lower leg and hands. They apply minor first aid to the burns and decide that they will seek medical attention from the Moomba RFDS.

The grass fire is then called in through to Comms via channel 9 and all required information is passed on.

24/08/2012 OPREX Field Vehicle Accident with Entrapment

This exercise was designated as an OPREX (Operational Exercise) as per the 2012 Cooper Basin Emergency Exercise Schedule which is a requirement under EHSMS13 Emergency Preparedness.

Scenario

A vehicle accident has occurred with one entrapment near Daralingie.

Moomba Comms will be notified of the incident and will undertake the appropriate

The exercise included five specific objectives and the measurable outcomes These objectives were discussed during this debrief and reported against in the relevant EHS Toolbox Emergency Exercise Report.

Objective Outcomes:

4 To practice and assess initial emergency response arrangements for the Daralingie Field by Emergency Services.

5 To practice and assess the appropriate notifications and information transfer from the Production Operator, back to the Moomba Communications centre in the event of such an emergency taking place.

6 Provide a skills maintenance opportunity for staff to apply First Aid skills.

• Learning: Provide the vehicle unit number to Comms or the Company they work for. This will assist with Comms to inform their Boss of the incident.

• Learning: Brief details of the incident are required to be provided to the Emergency Services Teamleader (ES1) over the radio, when initiating the pager response tone. More in depth information can be relayed by phone. Moomba Comms need to relay SITREPS to ES 1 when they receive any information from the Emergency Services Officer out in the field.

• Learning: Emergency Services Officers need to slow down their talking while providing a SITREP to Moomba Comms. If Moomba Comms are unsure of the SITREP for any reason, ask Emergency Services to repeat. Emergency Services should use their call sign after the vehicle number when calling Moomba Comms on the radio.

• Learning’s: Not all glass is required to be removed if not involved in the evolution. Use Tim to his full capabilities (e.g. operating the pump, removal of glass, stabilise the vehicle or patient and provide ongoing SITREPS to Comms). More SITREPS were required to Moomba Comms during the incident.

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action, while referring to EHSMS 13 EMERGENCY PREPAREDNESS.

One Emergency Services Officer and RFDS Nurse will respond to the incident via Ambulance and Ute.

A safe removal of the casualty will be undertaken by the Emergency Services Officer and RFDS Nurse.

7 To practise and assess Moomba Comms in managing and relaying information to the appropriate departments whilst undertaking their normal duties.

8 To provide a skills maintenance opportunity to the Emergency Services Officer.

03/10/2012 OPREX This exercise was held at 19:30Hrs to capture a full camp including evacuation of recreational areas including the wet mess.

The Spotless Staff will be required to activate the Evacuation alarms as per the procedure. They will also be required to door knock all vans as per the procedure to ensure evacuation has been completed.

The aim of this exercise is to:

• Practice and refine emergency evacuation arrangements in the event of a generic emergency occurring in the FC 47 Camp,

• Provide an opportunity for skills maintenance training of Spotless camp staff

Objective Outcomes:

• Assess the effectiveness of

evacuation procedures for the FC 47 Camp.

• Practice and assess the operation of the Muster point at the FC 47 Camp.

• Practice and assess procedures for activation of the multiple manual siren activation points.

• Practice and assess procedures for clearance of the FC47

• Action: Amend Muster Point Controller procedures to allow the Main Camp evacuation sirens to be switched off after 15 minutes has elapsed from time of activation to facilitate more effective communication for briefing mustered persons

• Action: Install multiple swipe points along the Administration building wall, this will expedite the recording process and relieve congestion in this area.

• Action: Install lighting that can be activated manually, to provide adequate light to enable persons to carry out function roles at all points within the Muster Point

• Include instructions relating to mustering into site induction, specifically, the requirement for personnel to –

have their ID card with them when mustering, and, remain within the designated muster point until they are delegated another task i.e. firefighting or first aid duties, or an ‘All Clear’ is sounded.

• Action: Investigate cost and technical feasibility of relocating all the main camp siren and light activation points to a single location adjacent to the intercom

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accommodation vans within acceptable time frames (30 minutes).

All persons present at the debrief, concurred that the exercise achieved its documented outcomes and the issues identified would lead to opportunities for improvement.

unit. Review options and consider implement of solution

• Develop and document a plan for the systematic search of all buildings within the Main Camp environment, and ensure all persons who may be involved with building clearance during an evacuation are familiar with its implementation.

• Replace low power UHF portable radios with Motorola type portable radios to ensure adequate communication between the Muster Point and teams conducting clearance activities. Only a limited number of frequencies is required, similar to the EOC Special Events radios.

13/10/2012 OPREX Dullingari/Toolachee

At 1300 hrs Moomba Communications Officer attempts to contact the Toolachee operator as he is two (2) hours over due to Toolachee west Nodal compressor.

Moomba Communications Officer advises the Dullingari Incident Controller that the Toolachee operator is over due to the Toolachee west nodal compressor. The Incident Controller instigates a SAR utilising local Production operators to follow the most commonly known route taken by the Toolachee operator.

Objective Outcomes:

1 To practise and assess initial emergency response arrangements for the Dullingari / Toolachee operators, Spotless OFA, & Moomba Communications teams.

2 To allow both the Production team & Spotless OFA to practices there

management of an incident of this type.

3 To practice and assess the appropriate notifications and information transfer from Moomba Communications to the Emergency services

4 Provide a skills maintenance opportunity for Dullingari OFA &

• Action: Revisit system for ensuring operator at remote locations are safe.

• Action: Consider purchase of a basket type stretcher for more remote satellites, say 30 minutes travel from Dullingari.

• Action: Discuss with OFA extent of role in regards to remote locations response, there was a belief that outside Dullingari the RFDS would be there. This may take an Hour or more before one can attend, OFA would be responsible for casualty management until that time. Consider exercises at location to provide opportunity to practice skills.

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The Toolachee operator arrives at Toolachee west nodal compressor & advises the Dullingari Incident Controller & Moomba Communications Officer that he has located the operators vehicle & is currently searching the surrounding area for the operator.

Out Field Operator locates the Toolachee Operator on top of the Toolachee west nodal compressor dewatering and storage tank & reports that the operator is unconscious.

The Incident Controller requests assistance from the Dullingari OFA to attended site. He also requests the assistance from area operators to safely retrieve the casualty from the top of this tank.

Dullingari / Toolachee Production teams.

5 To measure the effectiveness & skill levels and available resources to affect a rescue of this type with limited resources.

General discussion point for consideration

• Provision of a search and rescue kit for remote Satellites, kit could include Radio, torch, first aid kit and some shade device. However this equipment already exist within each satellite, just need to be centralised for ease of use.

• Extra handheld radios for use during search and rescue, these could also be used for normal operations whilst not within reach of a vehicle.

• Welfare checks is not being conducted as designed. Stokes operator for example attends Stoke and logs in via channel 9 upon arrival and then log off for return journey at end of day. Some days no communication from this operator is heard all day. How do we ensure they are safe???

• Provision of small tarp for vehicles, this would be used to provide sun protection of casualties as required.

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15/10/2012 OPREX Moomba Major Exercise

A tanker has pulled into the load-in/load-out facility; the driver and the Process operator begin to hook up the tanker to the pipe work to decant the 35,000 litres of oil. Whilst in the early stages of the operation smoke and fire is seen from the rear of the prime mover, the driver and the operator see an opportunity to move the prime mover clear of the facility and attempt to suppress the fire. During this heightened level of activity a valve is not completely isolated on the tanker and is passing liquid to grade. The prime mover has only partially cleared the area and the driver is slumped over the steering wheel in an unresponsive state. There will be two casualties – 1 x Process operator injured during first response to the incident and the 1 x driver as previously stated (which will be a training manikin to mitigate any casualty handling issues).

The 2012 Major plant exercise for the Moomba plant was an operational exercise (OPREX) designed to analyse the effectiveness of established emergency response procedures, strategic decisions made by the Incident Management Team within the EOC and tactics employed by the combatants at the incident. Under review will also be the effectiveness of evacuation procedures for a major hazardous facility.

Objective Outcomes:

1 To validate the effectiveness of the current Moomba Emergency Plan, Emergency Response Procedures and the Moomba Plant Contingency Pre-Plan.

2 Measure the effectiveness of call, receive and dispatch procedures and relevant notifications.

3 Measure the effectiveness of first response capabilities and training.

4 To employ fire and rescue tactics to provide continuous improvement opportunities for Emergency Services Officers and Process Personnel.

5 Provide the opportunity to practice casualty assessment, treatment and transportation.

6 To present the Moomba Incident Management Team with a scenario that will require the implementation of the Moomba Emergency Plan, strategic management and support of the incident.

7 Manage any environmental concerns from the incident

8 Identify any weakness in the plans,

Action: Investigate if the speaker is loud enough for the Training Room Muster-point controller to receive instructions from the EOC when there are a large number of people around that point.

Action: Investigate if radios are programmed with the correct frequencies then liaise with Communications Technicians if any alterations need to occur.

Action: Investigate Emergency procedures to ensure the relevant role in the EOC has a prompt to notify the Moomba Plant Environmental Adviser when required

Action: Provide maps in the Ambulances located in Moomba to provide a readily available reference for first-aiders not familiar with the Moomba plant and environs.

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procedures and training so actions can be assigned to rectify any potential issues.

The exercise was well attended and all associated learning’s and actions were captured in the final emergency response exercise report

23/11/2012 OPREX Major Aerodrome Exercise

The exercise was designed to involve full mobilisation of the Moomba Aerodrome Emergency Plan including the EOC.

The number of casualties and type of injuries was decreased from previous exercises to provide the Emergency Services responders greater opportunity to practice fire fighting strategies as per “Respond to an Aviation Incident” whilst still [providing an adequate test of casualty handling and transport process’ carried out by RFDS personnel and onsite first aiders.

Incident scenario

Conquest Shuttle inbound to Moomba with 7 passengers + Crew (passenger numbers depends on volunteers available on the day).

Captain reports an engine fire on the starboard side inside engine some on final approach just prior to landing and has no choice but to continue to execute landing in Moomba. The Captain attempts to quell the fire and shuts engine down.

The aircraft makes an emergency landing from the west?(direction depends on the prevailing wind on the day) bringing the aircraft to a halt on the airstrip between the two taxiways opposite the terminal. A fire is still evident on the starboard side engine of the aircraft after landing.

A full evacuation of the passengers from the aircraft is commenced. All persons are evacuated from the aircraft however, there are a small number of injuries sustained during the evacuation including a suspected heart attack, badly injured ankle and a fractured arm to be treated by on site emergency / first aid personnel and

Observations

• The field services team leader did not receive initial page due to technical issue with EOC group page. Subsequent pager tests have been successful? The FS Team leader was contacted by phone from the EOC and utilised in a logistical support role which is contrary to the plan. Review of airport reporting officer role in the AEP is required for clarity.

• It is important that all EOC position holders refer to a hard copy of the plan during every emergency to ensure compliance with roles and responsibilities.

• There was some delay in the process of responding the second ambulance. There was a suggestion made to improve signage for ambulance storage location however, upon investigation signage appears to be adequate and the problem will be more suitably rectified with improved training as per action assignment below.

• It was noted that there was a four minute delay from time of call to ES response page. The initial response time is critical in an airfield emergency and should not be delayed for any means.

• Although a NOTAM was issued by the airport manager, there was no notification to the EOC of same.

• Some EOC phones have incorrect phone numbers on them.

• EOC record keeping was fractured. Use of message forms to be improved and only one official EOC log to

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transported to Health Centre. Note: all passengers and crew are able to make their own way of the aircraft and any persons requiring assistance will be at grade external to aircraft. No emergency personnel will be required to enter the aircraft during the exercise.

There will be three injured passengers all of which are serious and require immediate attention and evacuation to hospitals. There is 1,000lbs of fuel still on board. CTAF radio frequency 126.7 is Moomba normal operations.

Wind Direction (as per prevailing conditions).

Staging area for all resources is on the Apron in front of the Terminal.

1. Objectives

• To practise Incident management and resource coordination skills.

• To practise and assess Emergency Response Procedures.

• To measure the time required and effectiveness of flaked hose lay operation from fixed water source adjacent terminal to incident scene.

• Provide a skills maintenance opportunity for emergency services personnel in Aircraft engine fire fighting

be maintained by the events historian. • Conquest pilot is not able to isolate oxygen and

batteries from the cockpit, only shut down engines and fuel.

• It was pointed out that greater numbers of first aid and fire fighting personnel may be required if a similar incident involved the 146 aircraft. The logistics officers had identified extra resources and had them on standby for dispatch at short notice if required.

Actions

• Consider the addition of a check prompt for page receipt in CB Emergency Response Procedures

• Formalise and deliver Advanced First Aid Training (including second ambulance operation and disaster equipment deployment) for reliability team members –

• Ensure all EOC phones have the appropriate phone number on them

• Review role of aviation/fleet co-ordinator in AEP and amend as required

• Review reference to page 8 information from section 5 of CB ERP and amend as required

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operations (dry).

• To practice emergency casualty treatment skills and transportation procedures.

• To identify and take steps to eradicate any procedural and functional weakness

• To practise command, control and co-ordination and liaison procedures between participating organizations

Multiple DISKEX/TEWTS Moomba Environs – Bushfire Awareness Sessions

Presentation/Training developed as result 2012 Actions Re: Bushfire Risk

Hazard Reduction

Bush Fire Safety

Bush Fire Awareness

Out Break of Fire

Due to an unusually wet season 2009 -2012 and abnormally high growth of vegetation there is now a significant risk of bushfire throughout the Cooper Basin. The mission of these awareness sessions were also to practice and refine emergency management arrangements in the event of a bush fire occurring and impacting Moomba Operations Boundary and to ensure all personnel whom may be involved in such an incident are adequately trained and resourced to affect a defensive asset protection.

Action: A list of personnel whom have training from a recognised fire service, so that they may be utilised in some manner if the need arises.

Learning’s: Understand that defensive operations will only be under taken & that personnel safety is paramount in any bush fire situation & early evacuation is essential.

Learning’s: The groups ware reminded of there responsibilities when conducting hot work in the field, & that knap sack sprays are required to be on-site during these activities. Hot work should be rescheduled on days of total fire bans.

Learning’s: Vigilance will be needed to ensure fuel loading around all facilities is monitored & addressed on a daily basis, to ensure fuel load is not excessive.

Multiple OPREX Camp evacuation exercises were carried out on all shifts at Moomba Dullingari and Tirrawarra throughout the

These operational exercises also included practical components to provide an opportunity for occupational first aiders and advanced Firefighters to practice their

New defensive Firefighting protective clothing purchased and put in place at each camp.

Extra radios purchased for camps.

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year. skills and use of associated equipment. Review and update of evacuation procedures.

Multiple Other Muster Point Controller Training.

The muster point training delivered on area of responsibility i.e. Airport, Training Room, Operations Camp or Main Gate Muster Points.

Muster Point Controller Training is delivered on a regular basis to capture new employees and new position holders with Muster Point Controller responsibilities. In addition Muster point controllers are now included in exercises to enable practise of their roles.

A copy of training records kept in the Moomba EOC Muster Point Controller training record folder.

Multiple Other Individual EOC Roles and Responsibilities Training.

EOC training is delivered on a regular basis on an as needs basis to cover new employees with EOC position responsibilities, Also covered off number of EOC exercises 2012

A list of EOC position holders is kept in the EOC

A copy of training records kept in the Moomba EOC and recorded on AIMS

Multiple

(weekly)

Drill Emergency Services skills maintenance drills

Moomba ESO's conducted weekly skills maintenance drills including, but not limited to, the following disciplines - Rope Rescue ,Confined Space Rescue, Road Crash Rescue, CABA search and rescue, Live Oil & Gas Fire Fighting, HAZMAT Response, etc.

Develop 2013 schedule for weekly ESO skills maintenance training sessions.

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Date Drill Type Description of Scenarios Comment Actions

Multiple DISCEX Moomba Process Department

Scenarios included:

#2 GTA Turbine Fire

#5 STA, control oil leak and fire

# 7 Boiler Explosion & Fuel Gas Rupture

NAFS 111 Release MS6

Fire Sepco Compressor

The exercises were a discussion exercise designed to extract high levels of knowledge from more experienced personnel and inform new personnel of company policies, procedures, roles, responsibilities and equipment locations in the event of a process incident (generic) in the Moomba plant.

• Confirmation required whether the process coordinator is expected to

scribe/record events, if not who is responsible to document the sequence of

events

• Leave area in safe condition and conduct debrief • Confirmation of operation of air conditioning

positive pressure, when confirmed ok, still await direction from emergency

services before returning to building

• Due to expected duration of incident consider accessing DCS from other

locations to monitor plant, (computer room, white house, switch rooms, marshalling stations where appropriate)

• Has a secondary power supply been considered for the control room air conditioning unit in case of a power failure to the control room system

• Can the NAFSIII System over ride be used if confirmed that there is no issue that would require the NAF system to be deployed, and are all personnel aware of the override system.

89


Appendix 4 Well Drilling Lease Scout, Construct, Backfill and Restoration Activity – 2012

# Well Name Well No.

Scout Date

Construct Commence Well Status

Borrow Pits

Number Restored

Lease Restored

Photos Taken

Road Km

Road Restored

Lease Backfill

1 Moolion 4 1/11/2005 14/02/2006 Gas 1 0 no Yes 0.4 No Yes 3 Moorari 12 1/11/05 22/02/06 Gas 1 0 no no 0.1 Yes Yes 4 Moomba 176 20/07/2006 11/08/2006 Gas 4 0 no no 1 no no 5 Golah Sing 1 24/08/2006 16/01/2007 Oil 1 0 no no 0.4 no no 6 Wheels 1 24/08/2006 16/01/2007 Oil 1 0 no no 0.4 Yes Yes 7 Burke 9 25/08/2006 16/01/2007 Oil 1 0 no no 0.5 no no 8 Burke 10 25/08/2006 16/01/2007 Oil 2 0 no no 0.5 Yes Yes 9 Tirrawarra 73 12/10/2006 10/11/2006 Gas 2 0 no no 1.2 no no 10 Ragno 1 19/10/2006 3/07/2007 Oil 1 0 No No 2.3 No Yes 11 Alwyn 7 13/11/2006 26/01/2007 Oil 1 0 No No 0.8 No No 12 Seccante 1 19/10/2008 21/06/2007 Oil 3 0 No No 1.1 No Yes 13 Barina 8 9/01/2007 17/02/2007 Gas 4 0 no no 0.6 no no 14 Thurakinna 6 9/01/2007 21/03/2007 Gas 1 0 no no 0.9 no no 15 Jena 28 23/02/2007 5/05/2007 C&S 1 0 No No 0.45 No No 16 Jena 22 23/02/2007 5/05/2007 Oil 1 0 No No 0.9 No Yes 17 Big Lake 86 19/04/2007 14/07/2007 Oil 1 1 No No 0.15 No No 18 Calvin 1 30/04/2007 8/06/2007 Oil 1 0 No No 0.5 No Yes 19 Gambero 1 30/04/2007 6/06/2007 Oil 1 0 No No 0.3 No No 20 Granchio 1 30/04/2007 22/06/2007 Oil 1 0 No No 0.05 No Yes 21 McKinlay 5 30/04/2007 22/06/2007 Oil 1 0 No No 0.1 No Yes 22 McKinlay 6 30/04/2007 13/06/2007 Oil 1 0 No No 0.6 No Yes 23 Moomba 182 22/06/2007 10/09/2007 Oil 1 1 No Yes 0.2 No Yes 24 Coonatie 8 26/06/2007 8/07/2007 Gas 2 0 No No 1.25 No No 25 Coonatie 9 26/06/2007 6/08/2007 Gas 1 0 No No 1.3 No No 26 Merrimelia 59 17/07/2007 21/08/2007 Oil 1 0 No No 1 No No 27 Merrimelia 60 17/07/2007 21/08/2007 Oil 1 0 No No 0.3 No No 28 Merrimelia 61 17/07/2007 21/08/2007 Oil 1 0 No No 0.2 No No 29 Mudera 15 19/07/2007 23/01/2008 Gas 1 0 No No 0.5 No No 30 Mudera 14 19/07/2007 20/01/2008 Gas 1 0 No No 1.2 No No 31 Mudera 13 19/07/2007 4/01/2008 Not Drilled 1 0 No No 1.4 No No 32 Coonatie 10 23/07/2007 27/07/2007 Gas 1 0 No No 0.4 No No

Well Name Well No.

Scout Date


Borrow Pits

Number Restored

Lease Restored

Photos Taken

Road Km

Road Restored

Lease Backfill

90


33 Mudlalee 6 24/07/2007 21/01/2008 Not Drilled 1 0 No No 0.05 No No 34 Charo 2 31/07/2007 11/10/2007 Oil 1 1 No No 0.5 No No 35 Charo 3 31/07/2007 19/10/2007 Oil 3 3 No No 1.7 No No 36 Merrimelia 58 1/08/2007 19/09/2007 P&A 1 0 Yes Yes 0.4 0.2 N/A 38 Tirrawarra 74 18/09/2007 3/01/2008 Gas 3 0 No No 3.2 No No 39 Tirrawarra 75 18/09/2007 3/01/2008 Gas 1 0 No No 0.8 No No 40 Jena 25 4/10/2007 27/10/2007 Oil 2 0 No No 1.5 No Yes 41 Coonatie 11 10/10/2007 17/11/2007 Not Drilled 1 0 No No 1.1 No No 45 Mudera 16 11/10/2007 28/01/2007 Not Drilled 1 0 No No 1.25 No Not drilled 46 Mudera North 1 11/10/2007 3/01/2008 SGC 1 0 No No 0.05 No No 47 Squalo 1 14/11/2007 28/01/2008 Oil 1 0 No No 0.8 No Yes 48 McKinlay 9 3/12/2007 13/02/2008 Oil 4 0 No No 1.8 No Yes 49 McKinlay 7 3/12/2007 11/02/2008 Oil 1 0 No No 0.3 No Yes 50 McKinlay 10 3/12/2007 11/02/2008 Not Drilled 1 0 No No 0.1 No Yes 51 Coonatie 12 10/12/2007 30/01/2008 Gas 1 0 No No 0.7 No No 52 Coonatie 13 10/12/2007 3/02/2008 Gas 1 0 No No 0.9 No No 53 Granchio 2 2/02/2008 10/03/2008 Oil 1 0 No No 0.2 No No 54 Narcoonowie 7 2/02/2008 17/03/2008 Oil 1 1 No No 0.2 Yes Yes 55 Big Lake 89 21/03/2008 4/07/2008 Gas 1 0 No No 1 No No 56 Big Lake 91 21/03/2008 4/07/2008 Gas 1 0 No No 1 No No 57 Big Lake 90 21/03/2008 4/07/2008 Gas 1 0 No No 1 No No 55 Mitchie 2 21/03/2008 20/04/2008 Gas 1 0 No Yes 1 No Yes 59 Deparanie 2 24/04/2008 15/05/2008 Oil 9 0 No No 1.6 No No 60 Granchio 3 30/04/2008 19/05/2008 Oil 1 0 No No 0.6 No Yes 61 Mudera 12 19/07/2008 12/01/2008 Gas 1 0 No No 0.9 No No 62 63 Tirrawarra 77 17/09/2008 8/12/2008 P&A 0 0 No No 1.4 No No 65 Muteroo 6 14/10/2008 8/11/2008 P&A 1 0 No No 0.45 No No


Scout Date


Borrow Pits

Number Restored

Lease Restored

Photos Taken

Road Km

Road Restored

Lease Backfill

66 Spencer West 3 14/10/2008 8/11/2008 Oil 1 0 No No 0.45 No No 67 Spencer 13 17/10/2008 8/11/2008 Oil 2 0 No No 0 No No 70 Kanowana 7 16/12/2008 22/12/2008 Oil 1 0 No No 0.3 No No 71 Mudrangie S 1 16/12/2008 20/01/2010 Gas 1 0 No No 1.2 No No 81 Tindilpie 9 27/02/2009 18/04/2009 Gas 1 0 No Yes 1.9 Yes Yes 82 Bobs Well 2 1/05/2009 26/05/2009 Gas 4 0 No Yes 1.18 No Yes

91


83 Daralingie 27 1/05/2009 18/06/2009 Gas 2 0 No No 0.5 No No 84 Dullingari 36 25/05/2009 27/09/2009 Gas 2 0 No Yes 0.32 No Yes 85 Dullingari 40 25/05/2009 22/09/2009 Gas 1 0 No Yes 0.32 No Yes 86 Charo 6 28/05/2009 6/07/2009 Oil 1 0 No No 1.85 No No 87 Charo 5 28/05/2009 4/07/2009 Oil 1 0 No Yes 0.38 No Yes 88 Charo 4 28/05/2009 23/06/2009 P&A 2 0 No Yes 1.65 No Yes 89 Charo 7 19/06/2009 9/07/2009 Oil 1 0 No Yes 0.49 No Yes 90 Narcoonowie 8 17/08/2009 23/10/2009 Oil 1 0 No Yes 0.25 No Yes 91 Narcoonowie 9 17/08/2009 20/10/2009 Oil 1 0 No Yes 0.55 No Yes 92 Narcoonowie 10 17/08/2009 26/10/2009 Oil 1 0 No Yes 0.62 No Yes 93 Burke 11 31/08/2009 3/10/2009 Gas 1 0 No Ye 0.5 No Yes 94 Mettika 6 31/08/2009 10/10/2009 Gas 1 0 No No 1 No No 95 Moomba 184 31/08/2009 16/12/10 Gas 1 0 No No 1 No No 96 Moomba 185 31/08/2009 28/02/11 Gas 1 0 No No 0.6 No No 97 Moomba 186 31/08/2009 16/03/11 Gas 1 0 No No 1 No No 98 Moomba 187 31/08/2009 16/12/10 Gas 1 0 No No 0.4 No No


Scout Date


Borrow Pits

Number Restored

Lease Restored

Photos Taken

Road Km

Road Restored

Lease Backfill

99 Coonatie 14 18/09/2009 31/01/10 Gas 1 0 No No 0.4 No No 100 Coonatie 15 18/09/2009 27/01/10 Gas 1 0 No No 0.3 No No 101 Coonatie 16 18/09/2009 19/12/2009 Gas 2 0 No No 1 No No 102 Coonatie 17 18/09/2009 9/12/2009 Gas 1 0 No No 0.5 No No 103 Coonatie 18 18/09/2009 11/01/2010 Gas 2 0 No No 1.7 No No 104 Coonatie 19 18/09/2009 2/01/2010 Gas 1 0 No No 0.4 No No 105 Coonatie 20 18/09/2009 16/01/2010 Gas 1 0 No No 1.2 No No 106 Cooba Dev C 8/01/2010 Built 1 0 No No 0.36 No N/A 107 Kanowana D Rev 1 28/01/2010 24/03/2012 Built 1 No No 1.425 No N/A 108 Kanowana C Rev 1 29/01/2010 24/03/2012 Built 1 No No 0.765 No N/A 109 Tirrawarra 79 18/06/2010 6/10/2010 Gas 1 0 No Yes 0.52 No Yes 110 Tirrawarra 78 18/06/2010 13/10/2010 Gas 1 0 No Yes 1.33 No Yes 111 Tirrawarra 80 18/06/2010 13/10/2010 Gas 1 0 No Yes 0.39 No Yes 112 Strzelecki NE 1 23/06/2010 12/08/2010 Gas 2 0 No No 0.24 No No 113 Kidman Nth 3 2/11/2010 4/01/11 Gas 2 0 No No 1.5 No No 114 Moomba 189 17/01/11 12/08/11 Gas 2 0 No No 0.7 No No 115 Tindilpie 11 23/01/11 22/05/11 Gas 1 0 No No 1.5 No No

92


116 Hackett 2 26/01/11 30/04/11 2 0 No No 1.85 No No 117 Nephrite Sth 6 27/01/11 13/04/11 Gas 2 0 No No 1.4 No No 118 Tindilpie 12 29/01/11 22/05/11 Gas 4 0 No No 4 No No 119 Nephrite Sth 8 3/02/11 23/04/11 Gas 1 0 No No .045 No No 120 Dilchee 4 9/02/11 14/07/11 Gas 9 0 No No 0.2 No No 121 Moomba 190 25/03/11 23/08/11 Gas 1 0 No No 0.7 No No 122 Moomba 188 25/03/11 3/08/11 Gas 4 0 No No 0.7 No No 123 Nephrite Sth 9 8/04/11 29/05/11 Gas 1 0 No No 0.5 No No 124 Nephrite Sth 7 8/04/11 29/05/11 Gas 1 0 No No 0.5 No No 125 Andree 4 22/07/11 31/10/11 Built 2 0 No No 0.45 No No 126 Leleptian 4 22/07/11 18/10/11 Built 2 0 No No 1.2 No No 127 Moomba 191 11/10/11 8/11/11 Built 4 0 No No 0.35 No No 128 Merrimelia 62 5/11/11 5/12/11 Built 1 0 No No 1.25 No No 129 Tindilpie Pad 13-18 10/11/11 13/12/11 Built 1 0 No No 1.2 No No 130 Charo 8 13/11/11 28/12/11 Built 1 0 No No 0.55 No No 131 Charo 9 17/11/11 28/12/11 Built 0 0 No No 1.3 No No 132 Charo Dev R 18/11/11 Scouted 0 0 No No 0.3 No No 133 Charo 14 19/11/11 Scouted 0 0 No No 0.26 No No 134 Charo Pad 11-13 19/11/11 Scouted 0 0 No No 0.46 No No 135 Charo 15 6/12/11 Scouted 0 0 No No 0.28 No No 136 Charo 10 17/12/11 13/01/12 Scouted 1 0 No No 0.75 No No 137 Big Lake 92 21/03/2012 16/05/2012 Built 1 0 No No 1.23 No no 138 Big Lake 93 25/03/2012 21/05/2012 Built 1 0 No No 0.37 No No 139 Big Lake 94 26/03/2012 20/05/2012 Gas 2 0 No No 0.86 No No 140 Bobs Well 3 12/04/2012 11/06/2012 Built 2 0 No No 1.45 No No 141 Waukatanna Dev E 7/05/2012 25/06/2012 Built 2 0 No No 0.65 No No 142 Waukatanna Dev G 7/05/2012 25/06/2012 Built 2 0 No No 1.85 No No 143 Waukatanna Dev A 11/05/2012 25/06/2012 Built 4 0 No No 2.5 No No 144 Gaschnitz 1 12/06/2012 29/07/2012 Gas 5 0 No No 5.5 No No 145 Van der Waals 1 22/06/2012 1/11/2012 Built 11 0 No No 14 No No 146 Moolion Pad 5&6 8/07/2012 9/08/2012 Gas 2 2 No No 0.065 No No 147 Cowralli Pad 2 12/08/2012 11/12/2012 Built 3 0 No No 1 No No 148 Langmuir 1 24/09/2012 Scouted 4 0 No No 3.6 No No 149 Dullingari Gas 61 26/09/2012 20/12/2012 Built 2 0 No No 1.3 No No 150 Burke 12 30/09/2012 3/12/2013 Built 1 0 No Yes 0.425 No No 151 Dullingari North 12 8/10/2012 30/12/2012 Built 1 0 No No 0.6 No No

93


152 Roswell 1 9/10/2012 15/11/2012 Built 1 0 No No 1.1 No No 153 Roswell 2 9/10/2012 Scouted 1 0 No No 0.6 No No 154 Munkarie Rev 1 23/11/2012 11/01/2013 Gas 1 0 No No 0.8 No No 155 Brumby 13 27/11/2012 Scouted 2 0 No No 2.6 No No

156 Goyder Gas Dev A Rev 1 11/12/2012 Scouted 1 0 No No 0.9 No No

157 Wollemi Oil NFE A 18/12/2012 Scouted 1 0 No No 0.7 No No

158 Big Lake Gas Dev AJ 92 21/03/2012 16/05/2012 Built 1 0 No No 1.23 No no

PEL 114

1 Shazlick 1 30/01/2007 28/02/2007 Oil 5 0 no no 0.3 No No 2 Hoek 2 30/03/2007 5/05/2007 Oil 2 0 No No 1.3 No No 3 Hobbes 1 3/12/2007 10/04/2008 Oil 1 0 No No 0.6 No No 4 Hoek 3 4/04/2008 27/04/2008 Oil 1 0 No No 0.3 No No 5 Hobbes 2 30/11/2008 10/01/2010 Oil 1 0 No No 0.5 No No 6 Cartman 1 18/12/2008 16/02/2010 Oil 8 0 No No 1.3 No No 8 Wallace 1 1/09/11 22/09/11 Oil 3 0 No No 2.3 No No 9 Chimmichurri 1 1/09/11 1/10/11 Oil 3 0 No No 2.3 No No

10 Kakapo 1 2/07/11 6/10/11 Suspended 1 0 No No 1.75 No No

PPL 225

1 Stimpee 3 22/06/2007 28/06/2007 Oil 1 0 No No 0.05 No No 2 Stimpee 5 18/12/2008 29/01/2010 Built 1 0 No No 0.9 No No 3 Stimpee 4 22/12/2008 29/01/2010 Oil 1 0 No No 0.14 No No

PPL 226

1 Teringie 2 1/09/11 28/10/11 Oil 1 0 No No 1.5 No No 2 Cartman 1 18/12/2008 16/02/2009 Oil 8 0 No No 1.3 No 1 3 ChimmiChurri #1 Rev 1 1/09/2011 1/10/2011 Built 3 0 No No 2.3 No 2

3 Hobbes 1 3/12/2007 10/04/2008 Oil 1 0 No No 0.6 No N 4 Hobbes 2 30/11/2008 10/01/2009 Oil 1 0 No No 0.5 No N

94


5 Kakapo Oil NFE A Rev 1 2/07/2011 6/10/2011 Built 1 0 No No 1.75 No N 6 Moe Oil NFE 19/11/2012 7 0 No No 7.6 No N Stimpee App A 5 18/12/2008 29/01/2009 Built 1 0 No No 0.9 No N Stimpee Dev A 4 22/12/2008 29/01/2009 Oil 1 0 No No 0.14 No N Teringie 2 1/09/2011 28/10/2011 Oil 1 1 No No 1.5 No Wallace 1 1/09/2011 22/09/2011 Oil 3 0 No No 2.3 No N

95


Appendix 5 Well Workover Summary

# WELL START DATE END DATE

WORKOVER ACTIVITY

FRACTURE STIMULATION

1 CHIMMICHURRI 1 17-Dec-11 05-Jan-12 Oil Completion N 2 BIG LAKE 26 02-Jan-12 07-Jan-12 Gas Workover N 3 TERINGIE 2 05-Jan-12 09-Jan-12 Oil Completion N 4 TERINGIE 2 06-Jan-12 07-Jan-12 Perforate N 5 MOOMBA 81 08-Jan-12 11-Jan-12 Gas Completion N 6 MOOMBA SOUTH 1 09-Jan-12 10-Jan-12 Perforate N 7 WALLACE 1 09-Jan-12 13-Jan-12 Oil Completion Y

8 CHARO 1 10-Jan-12 15-Jan-12 Water Well Conversion N

9 MOOMBA 190 11-Jan-12 14-Jan-12 Perforate Y 10 WALLACE 1 13-Jan-12 13-Jan-12 Perforate Y 11 DERRILYN 2 14-Jan-12 17-Jan-12 ESP Repair N 12 TINDILPIE 11 15-Jan-12 23-Jan-12 Gas Completion N 13 MOOMBA 189 15-Jan-12 19-Jan-12 Perforate Y

14 CHARO 1 16-Jan-12 29-Jan-12 Water Well Conversion N

15 HOEK 1 17-Jan-12 20-Jan-12 PCP Repair N 16 MOOMBA 188 19-Jan-12 20-Jan-12 Perforate Y 17 MCKINLAY 5 21-Jan-12 23-Jan-12 PCP Repair N 18 NEPHRITE SOUTH 8 21-Jan-12 23-Jan-12 Perforate Y 19 MOOMBA 188 22-Jan-12 23-Jan-12 Perforate Y 20 NEPHRITE SOUTH 7 23-Jan-12 26-Jan-12 Perforate N 21 RAGNO 1 24-Jan-12 27-Jan-12 PCP Repair N 22 NEPHRITE SOUTH 9 26-Jan-12 01-Feb-12 Perforate N 23 DILCHEE 4 27-Jan-12 03-Feb-12 Perforate Y 24 PASTICCIO 1 27-Jan-12 29-Jan-12 PCP Repair N 25 CHARO 7 29-Jan-12 01-Feb-12 Oil Completion N

26 CHARO 2 02-Feb-12 10-Feb-12 Oil Completion/ Workover N

27 MOOMBA 190 03-Feb-12 06-Feb-12 Perforate Y 28 MERRIMELIA 62 07-Feb-12 08-Feb-12 Perforate Y 29 CHARO 1 07-Feb-12 10-Feb-12 Perforate N 30 CHARO 2 08-Feb-12 08-Feb-12 Perforate N 31 TIRRAWARRA 59 11-Feb-12 17-Feb-12 Integrity Repair N 32 ANDREE 4 15-Feb-12 16-Feb-12 Perforate Y 33 DILCHEE 4 15-Feb-12 23-Feb-12 Gas Completion Y 34 MERRIMELIA 62 16-Feb-12 16-Feb-12 Perforate Y 35 MOOMBA 188 18-Feb-12 21-Feb-12 Perforate Y 36 NARCOONOWIE 10 18-Feb-12 21-Feb-12 BP Repair N 37 NARCOONOWIE 5 22-Feb-12 28-Feb-12 BP Repair N 38 LELEPTIAN 1 24-Feb-12 26-Feb-12 Perforate N 39 BIG LAKE 64 24-Feb-12 01-Mar-12 Integrity Repair N 40 ANDREE 3 28-Feb-12 01-Mar-12 Perforate N 41 MUNDI 6 10-Mar-12 11-Mar-12 Perforate N 42 MUNDI 6 20-Mar-12 22-Mar-12 Reperforate N 43 MERRIMELIA 40 24-Mar-12 27-Mar-12 Perforate N 44 GRANCHIO 2 28-Mar-12 07-Apr-12 Integrity Repair N 45 BIG LAKE 64 30-Mar-12 02-Apr-12 Integrity Repair N 46 MOOMBA 159 30-Mar-12 04-Apr-12 Perforate N 47 MOOMBA 191 02-Apr-12 06-Apr-12 Gas Workover Y 48 MOOMBA 189 04-Apr-12 06-Apr-12 Perforate Y 49 MOOMBA 159 06-Apr-12 07-Apr-12 Reperforate N 50 BIG LAKE 64 06-Apr-12 20-Apr-12 Integrity Repair N 51 GRANCHIO 1 07-Apr-12 10-Apr-12 PCP Repair N

- 96 -


52 MOOMBA 191 08-Apr-12 11-Apr-12 Perforate Y 53 LELEPTIAN 4 15-Apr-12 25-Apr-12 Perforate Y 54 HOEK 3 17-Apr-12 22-Apr-12 PCP Repair N 55 MOOMBA 191 20-Apr-12 31-May-12 Gas Completion Y 56 COONATIE 6 22-Apr-12 26-Apr-12 Perforate N 57 MCKINLAY 9 23-Apr-12 25-Apr-12 PCP Repair N 58 COONATIE 5 26-Apr-12 27-Apr-12 Perforate N 59 LELEPTIAN 4 26-Apr-12 27-Apr-12 Perforate Y 60 DERRILYN 3 26-Apr-12 29-Apr-12 PCP Repair N 61 COONATIE 10 28-Apr-12 29-Apr-12 Perforate N 62 MERRIMELIA 62 29-Apr-12 04-May-12 Perforate Y 63 PONDRINIE NORTH 1 30-Apr-12 02-May-12 Reperforate N 64 MERRIMELIA 62 30-Apr-12 14-May-12 Gas Completion Y 65 PONDRINIE 5 04-May-12 05-May-12 Perforate N 66 COONATIE 6 13-May-12 14-May-12 Perforate N 67 PONDRINIE 5 15-May-12 16-May-12 Perforate N 68 PONDRINIE 17DW 20-May-12 22-May-12 Perforate N 69 CHARO 10 20-May-12 26-May-12 Oil Completion N 70 COONATIE 11 22-May-12 26-May-12 Perforate N 71 CHARO 11 26-May-12 31-May-12 Oil Completion N 72 BIG LAKE 64 11-Jun-12 30-Jun-12 Integrity Repair N 73 CHARO 12 12-Jun-12 16-Jun-12 Oil Completion N 74 MOOMBA 188 13-Jun-12 13-Jun-12 Perforate N 75 CHARO 9 15-Jun-12 16-Jun-12 Perforate Y 76 CHARO 13 16-Jun-12 22-Jun-12 Oil Completion N 77 LELEPTIAN 4 21-Jun-12 23-Jun-12 Perforate N 78 MERRIMELIA 17 23-Jun-12 24-Jun-12 Perforate N 79 LELEPTIAN 4 23-Jun-12 03-Jul-12 Gas Completion Y 80 BRUMBY 12 24-Jun-12 24-Jun-12 Perforate N 81 BECKLER 2 25-Jun-12 26-Jun-12 Perforate N 82 DULLINGARI 36DW1 29-Jun-12 30-Jun-12 Perforate Y 83 BIG LAKE 26 30-Jun-12 20-Aug-12 Integrity Repair N 84 MARABOOKA 12 03-Jul-12 03-Jul-12 Reperforate N 85 MOOMBA 189 04-Jul-12 05-Jul-12 Perforate Y 86 NEPHRITE SOUTH 2 05-Jul-12 09-Jul-12 Perforate Y 87 FLY LAKE 9 06-Jul-12 07-Jul-12 Perforate N 88 FLY LAKE 12 09-Jul-12 16-Jul-12 Perforate N 89 CHARO 16 12-Jul-12 17-Jul-12 Oil Completion N 90 BIG LAKE 13 18-Jul-12 20-Jul-12 Perforate N 91 MOOMBA 110 19-Jul-12 22-Jul-12 Reperforate N 92 BIG LAKE 24 20-Jul-12 22-Jul-12 Perforate N 93 MOOMBA 50 23-Jul-12 26-Jul-12 Perforate N 94 COWRALLI 8 24-Jul-12 28-Jul-12 Perforate N 95 DULLINGARI 36DW1 26-Jul-12 30-Jul-12 Gas Completion Y 96 PELICAN 7 27-Jul-12 29-Jul-12 Reperforate N 97 ANDREE 3 28-Jul-12 30-Jul-12 Perforate N 98 PELICAN 8 30-Jul-12 31-Jul-12 Reperforate N 99 SECCANTE 1 30-Jul-12 02-Aug-12 PCP Repair N 100 TOOLACHEE 26 01-Aug-12 04-Aug-12 Perforate N 101 KIRRALEE 2 01-Aug-12 06-Aug-12 Perforate N 102 GAMBERO 1 02-Aug-12 04-Aug-12 PCP Repair N 103 BIALA 2 04-Aug-12 07-Aug-12 BP Repair N 104 MASSY 1 05-Aug-12 10-Aug-12 Perforate N 105 HOEK 3 07-Aug-12 10-Aug-12 PCP Repair N 106 BIALA 1 10-Aug-12 13-Aug-12 BP Repair N 107 BIALA 15 13-Aug-12 15-Aug-12 PCP Repair N 108 TOOLACHEE 50 21-Aug-12 28-Aug-12 Integrity Repair N 109 STRZELECKI 27 22-Aug-12 25-Aug-12 BP Repair N 110 BIG LAKE 25 22-Aug-12 28-Aug-12 Perforate N 111 TOOLACHEE 50 25-Aug-12 26-Aug-12 Perforate N

- 97 -


112 NEPHRITE SOUTH 6 26-Aug-12 04-Sep-12 Gas Workover N 113 COONATIE 7 28-Aug-12 31-Aug-12 Perforate N 114 JACK LAKE 1 29-Aug-12 01-Sep-12 Perforate N 115 DULLINGARI NORTH 6 29-Aug-12 13-Sep-12 Gas Workover Y 116 COONATIE 13 01-Sep-12 01-Sep-12 Perforate N 117 WINDIGO 1 01-Sep-12 01-Sep-12 Perforate N 118 COONATIE 9 02-Sep-12 03-Sep-12 Perforate N 119 MOOMBA 115 02-Sep-12 08-Sep-12 Perforate N 120 COONATIE 8 05-Sep-12 07-Sep-12 Perforate N 121 HOBBES 1 05-Sep-12 07-Sep-12 PCP Repair N 122 MCKINLAY 5 07-Sep-12 08-Sep-12 PCP Repair N 123 PONDRINIE 13 07-Sep-12 08-Sep-12 Perforate N 124 JACK LAKE 1 09-Sep-12 11-Sep-12 Perforate N 125 ULANDI 12 09-Sep-12 11-Sep-12 BP Repair N 126 MOOMBA 115 10-Sep-12 11-Sep-12 Perforate N 127 JENA 22 11-Sep-12 12-Sep-12 LRP Repair N 128 JENA 19 12-Sep-12 14-Sep-12 BP Repair N 129 ALWYN 6 14-Sep-12 16-Sep-12 BP Repair N 130 TALLERANGIE 1 14-Sep-12 02-Oct-12 Integrity Repair N 131 ALWYN 6 15-Sep-12 15-Sep-12 Perforate N 132 MOOMBA 154 15-Sep-12 15-Sep-12 Perforate Y 133 BIG LAKE 17DW 15-Sep-12 17-Sep-12 Perforate N 134 PELICAN 9 15-Sep-12 18-Sep-12 Perforate N 135 ALWYN 7 16-Sep-12 17-Sep-12 Perforate N 136 ALWYN 7 16-Sep-12 18-Sep-12 PCP Repair N 137 RISSIKIA 1 18-Sep-12 19-Sep-12 PCP Repair N 138 MOOMBA 58 18-Sep-12 20-Sep-12 Perforate N 139 MOOMBA 90 19-Sep-12 20-Sep-12 Perforate Y 140 ALLAMBI 1 20-Sep-12 22-Sep-12 Perforate N 141 HOEK 1ST1 20-Sep-12 22-Sep-12 PCP Repair N 142 MOOMBA 105 21-Sep-12 22-Sep-12 Perforate N 143 MOOMBA 158 21-Sep-12 22-Sep-12 Perforate Y 144 MOOMBA 169 22-Sep-12 23-Sep-12 Perforate N 145 TINDILPIE 14 22-Sep-12 29-Sep-12 Gas Completion Y 146 WINDIGO 1 23-Sep-12 23-Sep-12 Perforate N 147 BARINA 8 24-Sep-12 25-Sep-12 Reperforate N 148 BIG LAKE 63 25-Sep-12 27-Sep-12 Perforate N 149 MOOMBA 55 26-Sep-12 27-Sep-12 Perforate N 150 BIG LAKE 30 27-Sep-12 29-Sep-12 Perforate N 151 MOOMBA 55 28-Sep-12 29-Sep-12 Perforate N 152 BIG LAKE 93 29-Sep-12 04-Oct-12 Perforate Y 153 TINDILPIE 13 29-Sep-12 05-Oct-12 Gas Completion Y 154 BIG LAKE 62 30-Sep-12 01-Oct-12 Perforate N 155 MOOMBA 55 01-Oct-12 01-Oct-12 Perforate N 156 MAWSON 2 01-Oct-12 02-Oct-12 Perforate N 157 DILCHEE 2 03-Oct-12 23-Oct-12 Gas Workover Y 158 BIG LAKE 92 05-Oct-12 06-Oct-12 Perforate Y 159 STURT 4 06-Oct-12 13-Oct-12 BP Repair N 160 BIG LAKE 30 07-Oct-12 10-Oct-12 Perforate N 161 GIDGEALPA 15 07-Oct-12 10-Oct-12 Perforate N 162 BIG LAKE 92 08-Oct-12 15-Oct-12 Perforate Y 163 PELICAN 3 10-Oct-12 13-Oct-12 Perforate N 164 GIDGEALPA 15 11-Oct-12 13-Oct-12 Perforate N 165 GIDGEALPA 29 13-Oct-12 25-Oct-12 BP Repair N 166 COWRALLI 10 14-Oct-12 17-Oct-12 Perforate N 167 BIG LAKE 94 15-Oct-12 22-Oct-12 Perforate Y 168 BIG LAKE 77 16-Oct-12 18-Oct-12 Perforate N 169 COWRALLI 2 18-Oct-12 21-Oct-12 Perforate N

170 DULLINGARI NORTH 12 19-Oct-12 22-Oct-12 Reperforate N

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171 KANOWANA 8 23-Oct-12 04-Nov-12 Perforate Y 172 BIG LAKE 4 24-Oct-12 21-Nov-12 Gas Workover Y 173 BURKE 8 26-Oct-12 27-Oct-12 Perforate N 174 TINDILPIE 18 26-Oct-12 31-Oct-12 Gas Completion Y 175 DELLA 23 28-Oct-12 29-Oct-12 Perforate N 176 MERRIMELIA 6 01-Nov-12 03-Nov-12 Perforate N 177 BOONGALA 2 02-Nov-12 03-Nov-12 Perforate N 178 PELICAN 10 04-Nov-12 08-Nov-12 Reperforate N 179 KANOWANA 9 05-Nov-12 06-Nov-12 Perforate Y 180 MOOMBA 103 05-Nov-12 08-Nov-12 Perforate N 181 MERRIMELIA 55 06-Nov-12 10-Nov-12 BP Repair N 182 MOOMBA 59 07-Nov-12 09-Nov-12 Perforate N 183 MOORARI 12 09-Nov-12 14-Nov-12 Perforate N 184 MERRIMELIA 61 11-Nov-12 17-Nov-12 Repair N 185 MOORARI 11 13-Nov-12 16-Nov-12 Perforate N 186 ALLAMBI 1 17-Nov-12 19-Nov-12 Reperforate N 187 PSYCHE 2 17-Nov-12 20-Nov-12 Perforate N

188 MERRIMELIA 47 17-Nov-12 22-Nov-12 Oil Completion/ Workover N

189 TINDILPIE 6 20-Nov-12 21-Nov-12 Perforate N 190 BIG LAKE 75 22-Nov-12 22-Nov-12 Perforate N 191 DILCHEE 2 23-Nov-12 26-Nov-12 Perforate N 192 PSYCHE 2 24-Nov-12 24-Nov-12 Perforate N 193 BIG LAKE 75 27-Nov-12 27-Nov-12 Reperforate N 194 TOOLACHEE 16 27-Nov-12 30-Nov-12 Perforate N 195 DULLINGARI NORTH 6 29-Nov-12 30-Nov-12 Perforate Y 196 MUDERA 16 01-Dec-12 03-Dec-12 Perforate N 197 MUNKARIE 9 01-Dec-12 04-Dec-12 Perforate N 198 ANDREE 4 04-Dec-12 07-Dec-12 Perforate Y 199 BIG LAKE 94 06-Dec-12 07-Dec-12 Perforate Y 200 BIG LAKE 4 08-Dec-12 11-Dec-12 Perforate Y 201 BIG LAKE 93 09-Dec-12 11-Dec-12 Perforate Y 202 TIRRAWARRA 50 14-Dec-12 16-Dec-12 Perforate N 203 BIG LAKE 93 16-Dec-12 19-Dec-12 Gas Completion Y 204 TINDILPIE 8 17-Dec-12 19-Dec-12 Perforate N 205 WAUKATANNA 5 17-Dec-12 20-Dec-12 Perforate Y 206 BIG LAKE 4 18-Dec-12 21-Dec-12 Perforate N 207 KANOWANA 9 18-Dec-12 01-Jan-13 Gas Completion Y 208 TINDILPIE 15 19-Dec-12 25-Dec-12 Gas Completion Y 209 KANOWANA 8 20-Dec-12 22-Dec-12 Perforate Y 210 BIG LAKE 92 20-Dec-12 25-Dec-12 Gas Completion Y 211 DULLINGARI NORTH 9 24-Dec-12 29-Dec-12 Perforate N 212 BIG LAKE 94 25-Dec-12 03-Jan-12 Gas Completion Y 213 TINDILPIE 17 26-Dec-12 01-Jan-12 Gas Completion Y 214 WAUKATANNA 4 30-Dec-12 30-Dec-12 Perforate N 215 DULLINGARI 55 31-Dec-12 04-Jan-13 Perforate N

Well Workover Summary – DERRILYN UNIT

# WELL START DATE

END DATE

WORKOVER ACTIVITY


1 DERRILYN 2 14/01/2012 17/01/2012 ESP Repair N 2 DERRILYN 3 26/04/2012 29/04/2012 PCP Repair N

Well Workover Summary – PPL 225, 226 & 227

# WELL START DATE END DATE

WORKOVER ACTIVITY


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1 CHIMMICHURRI 1 17/12/2011 05/01/2012 Oil Completion N 2 TERINGIE 2 05/01/2012 09/01/2012 Oil Completion N 3 TERINGIE 2 06/01/2012 07/01/2012 Perforate N 4 WALLACE 1 09/01/2012 13/01/2012 Oil Completion Y 5 HOEK 1ST1 17/01/2012 20/01/2012 PCP Repair N 6 HOEK 3 17/04/2012 22/04/2012 PCP Repair N 7 HOEK 3 07/08/2012 10/08/2012 PCP Repair N 8 HOEK 1ST1 20/09/2012 22/09/2012 PCP Repair N

Fracture Stimulation Summary

# WELL FRAC DATE WORKOVER ACTIVITY 1 MOOMBA 190 08-Jan-12 N 2 MOOMBA 189 17-Jan-12 N 3 MOOMBA 188 22-Jan-12 N 4 DILCHEE 4 02-Feb-12 N 5 MERRIMELIA 62 14-Feb-12 N 6 ANDREE 4 20-Feb-12 N 7 MOOMBA 191 25-Mar-12 N 8 WALLACE 1 01-Apr-12 N 9 LELEPTIAN 4 17-Apr-12 N 10 CHARO 9 23-Jun-12 N 11 DULLINGARI 36DW1 29-Jun-12 Y 12 BARINA 6 05-Jul-12 Y 13 NEPHRITE SOUTH 2 12-Jul-12 Y 14 TINDILPIE 18 27-Jul-12 N 15 TINDILPIE 17 28-Jul-12 N 16 TINDILPIE 16 28-Jul-12 N 17 TINDILPIE 13 16-Aug-12 N 18 TINDILPIE 14 17-Aug-12 N 19 TINDILPIE 15 18-Aug-12 N 20 MOOMBA 154 17-Sep-12 Y 21 MOOMBA 90 22-Sep-12 Y 22 MOOMBA 158 25-Sep-12 Y 23 BIG LAKE 93 01-Oct-12 N 24 BIG LAKE 92 08-Oct-12 N 25 BIG LAKE 94 19-Oct-12 N 26 KANOWANA 8 01-Nov-12 N 27 KANOWANA 9 07-Nov-12 N 28 DILCHEE 2 21-Nov-12 Y 29 DULLINGARI NORTH 6 02-Dec-12 Y 30 BIG LAKE 4 14-Dec-12 Y 31 WAUKATANNA 5 26-Dec-12 N

Appendix 6 Well Summary – Producing & Suspended Wells

As at 31/12/2012 Gas or Gas/Oil Oil

1 Number of Wells in Production (Operating) 524 185

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2 Number of Wells Suspended (Suspension plug run or In-active >1yr) 402 217

3 Number of Wells Completed/Not on line 9 9

4 Number of Wells - Cased & Suspended 43 5

5 Number of Wells - Casing Annuli Tested 645 3

6 EHS Risk Analysis of Wells Tested

- Level 4 (High Risk) 1 0

- Level 3 (Substantial Risk) 33 2

- Level 2 (Moderate Risk) 201 1

- Level 1 (Low Risk) 340 0

7 Number of Wells – Integrity Repairs Undertaken 10 0

8 Number of Wells - Plugged & Abandoned (post Completion and/or Production) 0 0

9 Number of Wells - Plugged & Abandoned (Post Drilling) 0 0

10 Number of Wells - Plugged and Suspended (post Drilling) 0 0

11 Planned 2013 - Plug & Abandonment’s (post Completion and/or Production) 2 0

Note: 1) Gas/Oil wells are those that have perforations planned or completed in separate oil and gas bearing reservoirs e.g. Tirrawarra, Moorari or Fly Lake fields

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Appendix 7 Flowlines Constructed – 2012

# From Diameter

(mm) Steel / GRE

Const Finish

Length (metres)

Total metres (mth)

1 Big Lake 6 Replacement Flowline 150 Steel 11/02/12 200 200 2 Burke 4 Gas Flowline Replacement 100 Steel 27/02/12 250 250 3 Moomba 191 Gas Flowline 100 Steel 23/03/12 306 306 4 Charo 15 Oil Flowline 69 GRE 29/07/12 260 260 5 Charo 16 Oil Flowline 69 GRE 27/07/12 574 574 6 Charo 8 Oil Flowline 69 GRE 7/07/12 975 975 7 Tindilpie 11 Gas Flowline 100 Steel 25/03/12 850 850 8 Charo 9 Oil Flowline 69 GRE 27/07/12 1034 1034 9 Charo To Tirrawarra Oil Trunkline 150 GRE 2/08/12 57600 57600

10 Hackett 2 Gas Flowline 100 Steel 31/03/12 980 980 11 Nephrite South 8 Gas Flowline 150 Steel 7/04/12 1016 1016 12 Dilchee 4 Gas Flowline 100 Steel 12/04/12 200 200 13 Nephrite South 7 Gas Flowline 100 Steel 19/04/12 63 63 14 Nephrite South 9 Gas Flowline 100 Steel 19/04/12 63 63 15 Gambero 1 To Mckinlay 7 Oil Flowline 73 EUE 19/11/12 500 500

16 Coonatie 15 Gas Flowline Replacement 150 Steel 10/05/12 650 650

17 Coonatie 20 Gas Flowline Replacement 150 Steel 10/05/12 895 895

18 Merrimelia 62 Gas Flowline 100 Steel 28/05/12 847 847 19 Leleptian 4 Gas Flowline 100 Steel 30/05/12 750 750

20 Gidgealpa 15 Gas Flowline Replacement 100 Steel 6/07/12 1300 1300

21 Dullingari 36 Gas Flowline 100 Steel 18/07/12 513 513 22 Charo 11 & 12 Water Injection Flowline 150 Steel 27/07/12 538 538 23 Daralingie 15 Gas Flowline 100 Steel 27/07/12 1700 1700 24 Tindilpie 13 Gas Flowline 250 Steel 3/10/12 667 667

25 Nephrite South 2 Gas Flowline Replacement 100 Steel 17/10/12 650 650

26 Charo 8 Water Injection Flowline 100 Steel 20/10/12 1869 1869 27 Moomba 17 Debottleneck Gas Pipeline 150 Steel 21/10/12 3242 3242 28 Nephrite To Gidgealpa Bypass 200 Steel 17/11/12 21800 21800

Total Km 100.292 Total Steel Line 39.349 Total GRE 60.443 Total EUE 0.5

Appendix 8 Pipeline Inspection, Testing & Repair – 2012 Integrity Testing

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High Velocity Wellhead Spooling / Swing Wells - Ultrasonic Inspection & Radiography of the Choke Welds (51 in Total):

• Andree 03 • Chookoo 02 • Moomba 084 • Bagundi 06 • Coonatie 20 • Moomba 134 • Baryulah 07ST1 • Cowralli 02 • Moomba 157 • Baryulah 09 • Cowralli 12 • Moomba South 01 • Beckler 02 • Cowralli 13 • Mudera 14 • Big Lake 07 • Cuttapirrie 02 • Nephrite South 05 • Big Lake 16 • Daralingie 09 • Pondrinie 11 • Big Lake 24 • Della 05A • Raven(Sa) 04 • Big Lake 33 • Dullingari North 11 • Stokes 01 • Big Lake 41 • Durham Downs North 01 • Stokes 09 • Big Lake 67 • Epsilon 08 • Tellus 01 • Big Lake 70 • Juno 05 • Theta 01 • Big Lake 77 • Kidman North 04 • Toolachee 18 • Cabernet 03 • Kurunda 03 • Yanda 08 L • Caladan 01 • Moomba 046 • Yanda 10 L • Challum 14DW • Moomba 068 • Yanda 12 • Challum 21DW1 • Moomba 083 • Yawa 02

Mothballed Pipelines - 2012 Nil Final Abandonment - 2012 Nil Pipeline Risk Assessments Field-wide Pipeline Integrity Reviews (PIRs) of: Meranji Gas Field Meranji Oil Field Cowralli Gas Field Tindilpie Gas Field Dullingari Gas Field Pipeline Integrity / Risk Workshops – 2012

Northern Fields Bookabourdie to Tirrawarra Gas Trunkline Charo to Tirrawarra Oil Trunkline Cuttapirrie to Moorari Gathering Line Fly Lake/Brolga to Tirrawarra Trunkline Leleptian Gas Trunkline Meranji Compressor Discharge Flowline Meranji to Merrimelia Gathering Line

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Meranji to Tirra-Moomba Trunkline Merrimelia GRE Oil Trunkline Merrimelia to Moomba GRE Oil Trunkline Moorari to Tirrawarra Gas Spineline Moorari to Tirrawarra Unit Oil Trunkline Pondrinie to Bookabourdie Gas Trunkline Tirrawarra to Merrimelia Oil Trunkline Tirrawarra to Moomba Gas Trunkline Eastern Fields Burke to Dullingari Trunkline Della Southern Gas Spineline 10" Della to Moomba Gas Trunkline Dullingari to Della Gas Trunkline Epsilon to Burke Trunkline Kidman to Kidman Junction Gas Trunkline Marabooka Gas Gathering Line 8" Mettika Gas Gathering Flowline Stokes to Mettika Gas Spineline Thoar to Epsilon Gas Trunkline Toolachee Crossover Gas Trunkline Toolachee Gas Trunkline Pipeline ILI (Inline Inspection) Surveys – 2012 • Big Lake Gas Trunkline (Section 1) • Coonatie 14 • Coonatie 16 • Coonatie 17 • Coonatie 18 • Coonatie 19

Appendix 9 Details of Seismic Activity

The breakdown of square kilometres in each Licence for CPSAN12 GREATER LELEPTIAN 3D SEISMIC SURVEY was as follows:

LICENCE AREA RECORDED - SQ KM

PPL 17 1.050 PPL 20 8.228

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PPL 35 0.810

PPL 52 1.184

PPL 55 9.719

PPL 56 3.749

PPL 68 14.129

PPL 91 3.610

PPL 95 1.634

PPL 124 4.273

PPL 140 59.864

PPL 154 2.309

PPL 160 3.080

PPL 223 27.235

PPL 238 35.455

AAL 164 136.893

AAL 177 75.926

TOTAL 389.280

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Appendix 10a 2012 Production Facility Projects

# Project Project Description Location

1 Moomba Sludge Treatment Plant Construction of new facility Mba Plant

2 Wellhead Compression Phase 4 New Gas Jack Compressors installed in various field locations SA Field

3 Meranji Nodal Compression Relocation of Compressor from Murta South to Meranji Meranji

4 Planned Maintenance Shutdowns Moomba Assets – Field Satellites/assets Plant & Field

5 Moomba Plant Buried Lines Installation of above ground lines instead of buried Moomba Plant

6 Re-life Salt Bath Heater 1 & DPCU #2 Assess repair and upgrade unit Moomba Plant

7 Charo Trunkline Install and Commission pipeline from Charo to Tirrawarra Charo

8 Charo Water Flood Facility Upgrade Install waterflood facilities to enhance oil recovery Charo

9 Big Lake Trunkline Pigging Facilities/ILI Install Pigging facilities at Big Lake Big Lake

10 Area 60 Compressor Controls Control system upgrades to the 60A and 60C compressors Moomba Plant

11 Tirrawarra Evaporation Pond Pond Upgrade (to handle increased water rates from Northern Fields) Tirrawarra

12 Lycium Tie in Crude Oil Pipeline tie in into Moomba Plant Moomba Plant

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Appendix 10b 2013 Production Facility Projects - Proposed # Project Project Description Location Finish

1 Planned Maintenance Shutdowns (inc CBTA) Moomba Assets – Field Satellites/assets Plant & Field Ongoing

3 Gidgealpa Gas Interceptor Pond Upgrade Interceptor Pond Upgrade Gidgealpa Ongoing

4 Big Lake Flare – Permanent solution Permanent solution to correct the lean on the BL flare Big Lake Ongoing

5 Gas Jack Wellhead Compression Phase V Installation of Gas Wellhead compression units at various locations in the Cooper Basin (SA)

Various SA Field

locations Ongoing

6 Moomba South Central LLP Compression Compression solution to increase gas production MSC 2013

7 Moomba Power and Steam Efficency Improvement Project

Feasibility study to increase boiler efficiency and reduce fuel gas consumption (boiler system renewal) Plant 2013

8 Tirrawarra LLP

Compression upgrade (equipment installation) enabling Tirrawarra field wells to flow at higher rates Tirrawarra 2013

9 LRP Heat Exchanger Bypass Installation of bypass line to enable GLNG feedstock spec Plant 2013

10 Moomba Equipment Abandonment Equipment Abandonment Plant 2013

11 Dullingari Oil Pig Barrel Replacement Pig Barrel Replacement Dullingari 2013

3 Tirrawarra Evaporation pond Upgrade Tirrawarra 2013

4 SA Gas Relifing Replace tape wrap pipelines and explore opportunity to improve tie ins Big Lake 2016

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5 Moomba South Central and Big Lake compressor Inlet Filter Upgrade

Inlet upgrade

Moomba South

Central/Big Lake

2013

Appendix 11 Wells Drilled – 2012 # Well Name License Well Type Target Spud Date Rig Release TD (M) Status

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1 Leleptian 4 PPL238 Dev Gas 9/01/2012 4/02/2012 3148 C&S gas well 2 Tindilpie 13 PPL95 Dev Gas 15/01/2012 5/02/2012 3221 C&S gas well 3 Tindilpie 14 PPL95 Dev Gas 7/02/2012 3/03/2012 3289 C&S gas well 4 Charo 8 PPL177 Dev Oil 9/02/2012 18/02/2012 1882 C&S oil well 5 Charo 9 PPL177 Dev Oil 22/02/2012 7/03/2012 1896 C&S oil well 6 Charo 10 PPL177 App Oil 18/03/2012 28/03/2012 1913 C&S oil well 7 Tindilpie 15 PPL95 Dev Gas 17/03/2012 4/04/2012 3220 C&S gas well 8 Charo 11 PPL177 Dev Oil 3/04/2012 11/04/2012 1928 C&S oil well 9 Tindilpie 16 PPL95 Dev Gas 5/04/2012 25/04/2012 3358 C&S gas well 10 Charo 12 PPL177 Dev Oil 13/04/2012 22/04/2012 1976 C&S oil well 11 Charo 13 PPL177 Dev Oil 23/04/2012 5/05/2012 1929 C&S oil well 12 Tindilpie 17 PPL95 Dev Gas 26/04/2012 20/05/2012 3270 C&S gas well 13 Charo 14 PPL177 Oil App Oil 9/05/2012 21/05/2012 1883 C&S oil well 14 Tindilpie 18 PPL95 Gas Dev Gas 21/05/2012 13/06/2012 3203 C&S gas well 15 Charo 15 PPL177 Oil Dev Oil 23/05/2012 6/06/2012 1871 C&S oil well 16 Charo 16 PPL177 Oil Dev Oil 15/06/2012 25/06/2012 1888 C&S oil well 17 Big lake 92 PPL 11 Gas Dev Gas 30/06/2012 24/07/2012 3175 C&S gas well 18 Kanowana 8 PPL28 Gas Dev O&G 26/07/2012 18/08/2012 3137 C&S gas well 19 Big Lake 93 PPL11 Gas Dev Gas 27/07/2012 16/08/2012 2985 C&S gas well 20 Big Lake 94 PPL11 Gas Dev Gas 20/08/2012 10/09/2012 3007 C&S gas well 21 Kanowana 9 PPL28 Gas Dev O&G 21/08/2012 12/09/2012 3144 C&S gas well 22 Bobs Well 3 PPL89 Gas Dev Gas 13/09/2012 30/09/2012 2972 C&S gas well 23 Waukatanna 4 PPL235 Gas Dev Gas 16/09/2012 1/10/2012 2741 C&S gas well 24 Waukatanna 5 PPL235 Gas Dev Gas 4/10/2012 15/10/2012 2710 C&S gas well 25 Moolion 6 PPL167 Gas Dev Gas 5/10/2012 27/10/2012 3091 C&S gas well 26 Waukatanna 3 PPL235 Gas Dev Gas 18/10/2012 31/10/2012 2774 C&S gas well 27 Moolion 5 PPL167 Gas Dev Gas 28/10/2012 19/11/2012 3129 C&S gas well 28 Cooba 4 PPL68 Gas Dev Gas 6/11/2012 6/12/2012 3165 C&S gas well 29 Gaschnitz 1ST1 PPL101 Gas App Gas 3/11/2012 3076 Drilling 30 Roswell 1 PPL9 Gas NFE Gas 11/12/2012 20/01/2013 2815 Drilling

Wells Drilled 2012– Not SACBJV projects – None Appendix 12 2012 Reports, including Geological and Reserves Reports

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Reg # Routine Report Title Comment Yes / No 33 Yes Annual Report – 2011 33 (2) e Yes Proved + Probable Reserves Data, YE 2011. 38 Yes Daily Drilling Reports 39 Yes Wireline Logs – Drilling Yes Wireline Logs – completions 40 Yes Well Completion Reports 41 Yes Quarterly Cased Hole report 42 Yes Well Test Analysis Report 43 Yes Petroleum Reservoir Fluid Analysis Report 44 Yes Downhole Diagrams 45 Yes Production Reports

2012 Reports In Accordance With Reg 33 (2) (e)

Reg # Routine Report Title Comment Yes / No 33 (2) e Yes Proved + Probable Reserves Data, YE 2011.

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