2006 Annual Report MOOMBA TO PORT BONYTHON LIQUIDS PIPELINEpetroleum.statedevelopment.sa.gov.au/__data/assets/... · The Moomba to Port Bonython Liquids Pipeline is owned by the South

2006 Annual Report

MOOMBA TO PORT BONYTHON LIQUIDS PIPELINE

Pipeline Licence 2

Document Number S-34-102-AR-007

2006 PL2 Annual Report

TABLE OF CONTENTS 1 PURPOSE ........................................................................................................... 4 2 SCOPE ................................................................................................................ 4 3 TECHNICAL INFORMATION............................................................................... 4 4 OPERATIONAL & MAINTENANCE ACTIVITIES - 2006 ..................................... 6

4.1 Risk Management Review ............................................................................ 6 4.2 Training......................................................................................................... 6 4.3 Operations & Maintenance Activities ............................................................ 7

5 INCIDENT REPORTING.................................................................................... 10 6 LAND MANAGEMENT....................................................................................... 11

6.1 Land Owner Liaisons .................................................................................. 11 6.2 Pipeline Safety Awareness ......................................................................... 11 6.3 Pipeline Location and Referral Services ..................................................... 11

7 ENVIRONMENTAL MANAGEMENT ................................................................. 12 8 EMERGENCY RESPONSE............................................................................... 12 9 REGULATORY COMPLIANCE.......................................................................... 12 10 RISK MANAGEMENT .................................................................................... 12 11 MANAGEMENT SYSTEM AUDITS................................................................ 13

11.1 Environmental Audits .................................................................................. 13 11.2 Health and Safety Audits ............................................................................ 13 11.3 Management Audit...................................................................................... 13

12 REPORTS ISSUED DURING THE 2006 LICENCE YEAR ............................ 13 13 VOLUME OF PRODUCT TRANSPORTED.................................................... 13 14 PROPOSED OPERATIONAL ACTIVITIES FOR 2007................................... 14 15 STATEMENT OF EXPENDITURE ................................................................. 14 16 KEY PERFORMANCE INDICATORS ............................................................ 15 17 CONCLUSION ............................................................................................... 15 Appendix A – Assessment of Declared Objectives ................................................... 16 Appendix B – Pipeline Cathodic Protection Data ...................................................... 24

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LIST OF ABBREVIATIONS

ALARP As Low As Reasonably Practical AS2885 Australian Standard 2885 Pipelines - Gas and Liquid Petroleum AVT Accuracy Verification Test CDP Corrosion Detection Pig CFS Country Fire Service CMMS Computerized Maintenance Management System (MAXIMO) CP Cathodic Protection CPU Cathodic Protection Unit Cu/CuSO4 Copper/Copper Sulphate DCGV Direct Current Voltage Gradient DNV Det Norske Veritas EGP Electronic Geometry Pig EMS Environmental Management System ERE Emergency Response Exercise ESD Emergency Shut Down GPS Geographical Positioning System HAZOP Hazard Operability HELM Heritage, Environment and Land Management HSE Health, Safety and Environment LMS Land Management System MAPS Moomba to Adelaide Pipeline System MFS Metropolitan Fire Service MLV Mainline Valve PIRSA Primary Industries and Resources of South Australia PL2 Pipeline Licence 2 PS 1-4 Pump stations 1, 2, 3 & 4 POMS Pipeline Operating Management System ROW Right of Way RTU Remote Terminal Unit SCADA Supervisory Control and Data Acquisition SEO Statement of Environmental Objectives SES State Emergency Service SMS Safety Management System SRB Sulphate Reducing Bacteria SWER Single Wire Earth Return TJ Tera Joule UHF Ultra High Frequency VHF Very High Frequency


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1 PURPOSE This report is submitted in accordance with the requirements of Pipeline Licence 2 and the SA Petroleum Regulations 2000.

2 SCOPE The Moomba to Port Bonython Liquids Pipeline is owned by the South Australian Cooper Basin Joint Venture and is operated and maintained under contract by Epic Energy. This report reviews operations carried out during 2006 and intended operations for 2007. In accordance with the Petroleum Regulations a performance assessment is also provided with regard to the Statement of Environmental Objectives for PL2.

3 TECHNICAL INFORMATION Table 1 summarizes the technical aspects of the Moomba to Port Bonython Liquids Line and Figure 1 shows diagrammatically the pipeline system.

Table 1 - Moomba to Port Bonython Technical data [PL 2]

Date Constructed 1983 Date Commissioned 1984 Length 659km External Diameter 355.6mm Wall Thickness: - Normal - Special Crossings (rivers, roads etc.)

7.14 mm 8.74mm

Pipe Grade API 5LX 52 MAOP 10,340kPa Coating Double layer polyethylene tape reinforced with

adhesive butyl rubber Depth of cover Nominal 900 mm

1200mm at road, rail and creek crossings Main Line Valves Adamson & Chronsiter Gate valves

(25 in total) Actuators Shafer

(17 in total) Actuators 8 Manual gear type operators Fluid Liquid Hydrocarbon Pump Stations 1 Active (Moomba)

1 Decommissioned (PS3 – 370kms south Moomba) Meter Stations 1 with 3 runs (Moomba) Corrosion Protection Secondary protection provided by an impressed

current CP system 14 transformer rectifier units installed

SCADA system Digital microwave link from Moomba to Port Bonython with VHF radio coverage for voice communication and

UHF from a number of valve sites.


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Figure 1 - Moomba to Port Bonython Pipeline


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4 OPERATIONAL & MAINTENANCE ACTIVITIES - 2006

4.1 Risk Management Review A complete AS2885 Risk Assessment was carried out in 2006 with a number of actions generated as part of the risk assessment process.

Internal Corrosion due to SRB was identified as an ongoing risk in the risk assessment as was ensuing adequate depth of cover to the pipeline system. Regular cleaning pigging functions and patrolling activities along with proposed depth of cover checking at specific locations along the pipeline system will continue to ensure these risks are maintained at ALARP. The final report is to be issued in 2007 and PIRSA have requested a copy of this report.

4.2 Training Epic Energy is committed to developing the skills of their employees and contractors to meet the operational needs of its business. During 2006 staff training was conducted in-house using a number of techniques which included training courses developed specifically for Epic Energy and delivered using self paced modules or as a group presentation using either a training service provider or suitably skilled Epic Energy staff. In addition to internal training, staff attended a range of external courses selected to further enhance their knowledge of the natural gas and liquid hydrocarbon pipeline transmission industry. The range of training staff attended during 2006 included: • Senior First Aid training (conducted by St John Ambulance Australia) • Epic Energy Safety Inductions (Office, field and contractors) • Defensive driving (Collision avoidance and 4WD training) • Pipeline excavation training • Introduction to Pipeline Pigging • Gas Engine Alternator Maintenance Training • Permit to Work training • Emergency Response Refresher training • AS2885 Awareness training • Defect Assessment of Pipelines • Manual Handling training • Atmospheric Testing training • Confined Space entry • Work Zone traffic management • Third Party Works on Pipeline Easements • First Five minutes Fire training • Pipeline locator use • Pipeline Surveillance and easement activities training • Security Awareness training • Santos Permit to Work Revision 7 • Santos level 1 inductions for the Moomba process facility. • Heat stress training • Santos Gas Detector training • Workplace Safety • Workplace HS&E/Operations Field Inductions • Workplace Drugs & Alcohol • Preventing Discrimination & Harassment


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• Fatigue & Stress Management • Hazard & Incident reporting • OHS&W for Managers • OHS&W Responsible Officer Training • Men’s Health Training • Valve Maintenance • Pressure, temperature & Level Indicator Training • Control & Operation of Centrifugal Gas Compressors • Fisher ROC Configuration Training • Instrumentation for Automation Process Control • Maintaining & Troubleshooting SLC-500 Systems using RSLogix 500 • Chainsaw training • Time management

4.3 Operations & Maintenance Activities Epic Energy have been engaged by the South Australian Cooper Basin Joint Venture group (Santos) to operate and maintain the Moomba to Port Bonython liquids hydrocarbon pipeline in accordance with AS2885 and other relevant standards. All routine and corrective maintenance activities identified are specified in Epic Energy’s CMMS and are scheduled by this system which generates work orders for maintenance staff to complete. Some of the key items in the maintenance schedule include: • Two monthly CP system transformer rectifier unit inspections • Quarterly road & aerial patrols are been conducted with all action items identified during the

patrols rectified immediately by the patrolling officer or entered into the CMMS and scheduled for repair during other routine activities.

• Quarterly SCADA system MLV pressure & temperature transducer calibrations • Six monthly CP system full line surveys • Six monthly inspection and servicing of all portable fire extinguishers • Six monthly mechanical inspections, operational checks & servicing of equipment at all

MLV and scraper station sites • Six monthly Pig vessel and mainline valve bypass line relief valve checks • Pressure vessel inspections (using suitably accredited external contractors) on all vessels

on the Moomba to Port Bonython liquids hydrocarbon pipeline system. • Annual cleaning pigging operations • Communications system mast maintenance • Annual communications system un-interruptible power supply and battery maintenance • Annual communications system VHF, UHF and microwave bearer checks and tests • Three yearly DCVG survey • Three ILI verification dig ups were completed to assess the finding of the Intelligent pigging

operations carried out in 2005. No repairs were found to be required • Programmed battery replacements were carried out at Martins Well, CS1, MLVs 14 & 15 • Three Yearly Mast maintenance was carried out A description of the Operations and Maintenance activities for 2006 is provided below.

4.3.1 Patrol Activities Three monthly road and aerial patrols (aerial patrols are conducted between PS3 and the Port Bonython terminal only) scheduled at six week intervals were completed in 2006. The road and aerial patrols ensure that the following pipeline activities are addressed:


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• Signage is in suitable condition and if not, repairs are affected as soon as is practically possible. Any issues not addressed during the patrol are fed back into the CMMS.

• to ensure there are no unauthorized activities occurring along the pipeline route or at any of the facilities

• restoration of any soil erosion due to wind and water is addressed • there are no leaks occurring at any of the pipeline facilities or along the pipeline route • all sites are secure, kept clean, neat and tidy • Items including above ground pipe coating condition, fences, gates, padlocks, signage, fire

extinguishers, weeding and other housekeeping activities are addressed at the mainline valve and scraper station facilities associated with the pipeline system.

In 2006 no significant issues were identified during any of the patrol or other routine maintenance activities.

4.3.2 Leak Detection The Epic Energy Transportation Services Control Centre (TSCC) located in Melbourne operates a SCADA system that continuously monitors the Liquids pipeline. Incorporated into the SCADA is the Pipeline Leak Monitoring System that provides real time leak detection capability based on linepack inventory, flows in and out of the system, hydrocarbon type and, pressure and temperature change rates. This allows the duty controller to instantly identify any action anomalies that may be occurring and notify field maintenance personnel to investigate further onsite as required. The control centre staff can, if required, isolate the pipeline remotely using any one of 17 out of 24 valves, isolating sections of the pipeline to minimize any leakage should the need arise. The real time leak detection system is augmented by maintenance activities along the pipeline which assists in the identification of any pipeline leakage ensuring the appropriate resources are mobilized to address the problem in a timely manner. In addition to the field maintenance staff activities the pipeline operations group and senior maintenance staff carry out a daily check of the hourly line balance to ensure no significant leakage is occurring on the pipeline system again mobilizing staff to inspect any sites that they may identify. During 2006 a minor leak was identified to be coming from the stem seal of MLV 25 which is located in the Port Bonython process facility. Epic Energy and Santos decided to treat this minor leakage as an emergency situation and the first aid treatment was managed by staff from Epic Energy and Santos. Once the leakage had been controlled and redirected to the plant hydrocarbon drain system a planned repair strategy was devised and the seals replaced at the earliest opportunity. This minor level of leak was not significant enough to trigger the leak detection system.

4.3.3 Coating Integrity In 2005 the Liquids Line had both an intelligent pigging survey and a DCVG coating survey performed. In 2006 three defects were dig up for verification purposes. These defects had estimated repair factors (ERF) of 0.91 which correlated well with the onsite verification information. None of these three defects required repair. A repair program has been proposed for 2007 to verify 2 more intelligent pigging defects and 11 DCVG coating defects. A coating disbondment issue was found at KP 0 around an underground monolithic joint from the DCVG survey. The cause of the coating disbondment was from an old method of protection of the monolithic joint. The pipeline at this location in 2007 is intended to be excavated, inspected and the coating disbondment refurbished.


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4.3.4 Cathodic Protection The following routine planned maintenance tasks were scheduled and completed in 2006: • Two full line potential surveys were completed in February & August • Routine bi-monthly CP transformer rectifier unit maintenance inspections were completed • Various minor faults to CP equipment, including TRU’s, anode bed cables and test posts

were repaired as scheduled by the CMMS • 19KV SWER line maintenance Tabular information from the CP survey data can be found in Appendix B. The February survey showed 99.5% of the readings taken satisfied the minimum protection criteria of -850 mV versus a copper/copper sulphate reference electrode. In August the survey showed 100% of all readings satisfied the minimum protection criteria. The Liquids Line is satisfactorily protected. 4.3.5 Electrical and Instrumentation Routine quarterly pressure and temperature transmitter calibrations were completed verifying that accurate data was fed into the SCADA system allowing accurate control of the liquids hydrocarbon transportation process ensuring it stays within the design parameters at all times. Six monthly mainline valve operational checks were completed in conjunction with the pressure and temperature transmitter calibration tasks. No significant electrical or instrumentation corrective maintenance activities were identified during 2006. 4.3.6 Communications All process variables and valve control functions are communicated to the central control system located in Melbourne, Victoria via a microwave link that runs parallel to the buried pipeline system. In addition to the microwave link a VHF radio link to allow voice communications between staff and the control centre plus a UHF link to transmit process data and commands to the main microwave link from remote sites are also supported by the communications system. This system is essential for the safe monitoring and control of the pipeline and the following range of maintenance activities were carried out in 2006 to ensure the communications system provided a high level of availability and reliability: • Routine Microwave bearer, UHF and VHF communications system maintenance tasks. • Routine maintenance tasks associated with the SCADA RTU calibration. • Routine maintenance tasks associated with the communications system uninterruptible

power supply batteries and their associated charging system. • Routine maintenance tasks associated with the communications system solar generated

power supply batteries. • Six monthly communications equipment air conditioning unit maintenance. • 3 yearly mast maintenance which included guy inspection and tensioning, minor mechanical

repairs to the mast structure including touch up painting, antenna security, and alignment checks. Mast aircraft obstacle lighting was re-lamped and lightning arrestors replaced during this mobilisation

As part of routine maintenance inspections two complete sets of storage batteries were replaced at the Martins Well and CS1 shack sites. The batteries at the remote MLV’s 14 & 15 were also


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replaced as part of an ongoing replacement program. In addition to the routine tasks above, the maintenance staff have responded to, investigated and solved numerous minor corrective maintenance issues that have been identified as a result of the routine activities or from failures that occur in the day to day operation of the pipeline communications system. With the exception of the above no other significant communications system maintenance was carried out during 2006.

4.3.7 Mechanical Routine six monthly mainline valve and scraper station site major valves, pig launcher and receiver maintenance tasks completed. All pipeline pressure regulator and over pressure protection devices were tested in accordance with the relevant Australian standard and the maintenance schedule. Ancillary equipment, such as pipe supports, pipe ground entry points, valves and pigging facilities, are routinely inspected as part of the facilities inspections or as a part of mechanical maintenance routines. In addition to the routine activities above, the maintenance staff have investigated and solved a number of corrective maintenance issues that have been identified as a result of the routine activities or from failures that occur in the day to day operation of the pipeline system. The stem packing of MLV 25 failed resulting in the release of a minor amount of product in the form of a mist at the Pt Bonython compound. The pipeline flow was able to be by-passed through the pig receiver allowing the MLV to be closed and the valve cavity blown down with the cavity bleed vented to the Pt Bonython closed drain system. This effectively controlled any leakage to atmosphere with all leaking oil going to the plant waste oil collection tanks. (Epic Energy and Santos carried out this phase of the operation under emergency response conditions) To facilitate the MLV stem seal change-out process a slug of stabilized crude oil was injected into the pipeline allowing maintenance staff to ultimately remove the valve operator and effect a repair. All mechanical and ancillary equipment is considered to be in good condition and fit for purpose.

4.3.8 Pigging operations In November 2006 Epic Energy maintenance staff conducted a cleaning pigging operation to remove water and other contaminates from the pipeline. Sludge samples taken during the cleaning pig run have been analysed by the Port Bonython laboratory staff with the results showing no SRB activity.

5 INCIDENT REPORTING During 2006 there was one reportable incident on the pipeline system: • The stem seal on MLV 25 leaked, discharging product to atmosphere and prompting an

emergency response. The root cause analysis identified degradation of the stem seals due to age as the primary mode of failure. The seals on this valve have been replaced using a controlled engineering change management process. This was reported to PIRSA as required.


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6 LAND MANAGEMENT

6.1 Land Owner Liaisons There are 44 landholders along the Moomba to Port Bonython Liquids Line system. All available landowners on the pipeline were contacted by phone during the year and a questionnaire was completed as part of each call. The questions were centered on people’s awareness of the pipeline location and their responsibilities with respect to works in the pipeline vicinity. In addition to the phone contacts, all available landowners on the Moomba - Port Bonython Liquids Line system were visited personally by an Epic Energy representative during 2006. (The remaining property owners were left a questionnaire to complete along with pipeline safety information pack as they were not home when the Epic Energy representative visited their property). During the property owner visits the Epic Energy representative completes a questionnaire designed to ascertain the landowner’s awareness of the pipeline system. In addition to the questionnaire a safety awareness information pack is provided which explains the requirements an individual must follow when working in the vicinity of an underground pipeline system. As part of Epic Energy’s continuous improvement program for pipeline awareness the landowner was posted two letters during the year containing information covering pipeline safety and the responsibilities landowners have to ensure no safety breaches occur on their properties. An Epic Energy year 2007 calendar reminding the landowner of pipeline safety was also forwarded in December 2006.

6.2 Pipeline Safety Awareness Epic Energy implements a Community Awareness Program, which entails holding awareness meetings with communities along the pipeline route. . To cover the various pipeline infrastructure that Epic Energy operates and maintains in South Australia Epic Energy have set a target of 30 meetings annually with CFS, MFS, Police, Ambulance, SES, councils, earth moving contractors, irrigation and fencing installation contractors.

The presentations for the Moomba to Port Bonython pipeline focus on the general properties of the liquid hydrocarbons transported, the process of liquids hydrocarbon transmission by pipeline, location of the high pressure liquids pipeline in the regions concerned, correct procedures when working within pipeline easements, pipeline threats and dealing with emergency situations. (Note:-This presentation will be tailored to the specific audience and where appropriate Epic Energy will discuss the differences between Liquids Hydrocarbon and natural gas transportation as both pipeline systems exist in a number of areas within South Australia.) To meet its community awareness commitment a total of 44 Community Awareness presentations tailored to reflect the new Epic Energy business were delivered in 2006. To effectively communicate the “Do’s and Don’ts” when working in the vicinity of a high pressure gas or liquids hydrocarbon pipeline Epic Energy encourages the target organizations to allow managers and field operatives attend these presentation to ensure that the work force has all of the information that they require to effectively perform their duties be they members of the emergency services or civil contractors working near the pipeline.

6.3 Pipeline Location and Referral Services Epic Energy provides a free service to locate any pipeline that they own or operate on behalf of third parties. This service is primarily used by other companies and third parties carrying out civil works in the vicinity of the pipelines.


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During 2006 a total of 520 enquiries were received by Epic Energy via the free call 1100 “Dial Before You Dig” asset referral service. Ten in-field responses for pipeline location and the supervision of third party works resulted from these enquiries along the Moomba – Port Bonython Hydrocarbon pipeline easement. 7 ENVIRONMENTAL MANAGEMENT During 2006 Epic Energy complied with all but one of its environmental requirements as detailed in the Statement of Environmental Objectives. Appendix A contains the “Assessment of Declared Objectives” completed for the Liquids Line. 8 EMERGENCY RESPONSE An emergency exercise code named “Flinders” was undertaken during 2006 and focused on testing the emergency field response to an incident. A copy of the report was forwarded to PIRSA inline with the requirements of the licence. A real emergency was declared in 2006 when a stem seal on MLV 25 leaked, discharging product to atmosphere and prompting an emergency response. The response involving both Epic and Santos staff ensured that the site was made safe, constantly monitored and the suspect valve isolated as required. An investigation was conducted and the root cause identified degradation of the stem seals due to age as the primary mode of failure. To facilitate the MLV stem seal change-out process a slug of stabilized crude oil was injected into the pipeline allowing maintenance staff to ultimately remove the valve operator and effect a repair under safer conditions than those presented when high vapour pressure products are in the pipeline. 9 REGULATORY COMPLIANCE Every endeavor is made to ensure that design, manufacture, construction, operation, maintenance and testing of all appropriate facilities, is carried out in accordance with AS2885. There are no known outstanding non compliances for the Liquids Line pipeline that Epic Energy is aware of against: • The Petroleum Act & Regulations 2000 • The Pipeline Licence (PL2) • The Statement of Environmental Objectives Any non-compliance identified is logged in the CMMS where it is tracked to conclusion. Significant items are reported through Santos to PIRSA. All other issues are raised at the quarterly meetings between Santos and Epic Energy and if required at the quarterly Santos/Epic Energy and PIRSA meeting. 10 RISK MANAGEMENT

Epic Energy continually reviews operational risks with assessments including inputs from experienced gas industry personnel and emergency services representatives providing an insight into potential new risks and assisting in the development of appropriate management strategies. Epic Energy utilizes the following risk management strategies to minimize risks to ALARP. • Aerial & ground monitoring of the pipeline easement activities • Permit to Work system


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• Routine maintenance activities to ensure all of the pipeline facilities are maintained in accordance with best industry practices and the relevant codes and standards that apply

• Design change control • In accordance with AS2885 Epic Energy conducts 5 yearly metre by metre risk assessment

reviews • Pipeline & Safety awareness program • Land ownership and use notification system • Landholder and stakeholder contact program • Participation in state forums for external risk management • Free “1100” Dial before You Dig information system

11 MANAGEMENT SYSTEM AUDITS

11.1 Environmental Audits Whilst no formal external environmental audit was carried out on PL2 in 2006, internal processes including ground patrols and landowner contact provided a complete coverage of the environmental status of the Moomba to Port Bonython liquid hydrocarbon pipeline system. During 2006 one environmental non conformance was noted related to a minor uncontrolled leak from a valve. An audit against the “Assessment of Declared Objectives” in the SEO was completed as provided in Appendix A.

11.2 Health and Safety Audits During 2006 Epic Energy continued with its program of conducting health and safety audits of its pipeline facilities. There were no issues identified relating specifically to the Liquids line system requiring follow up action. 11.3 Management Audit Building on from the work undertaken in 2005, further auditing, focusing on all relevant stakeholders and landowners were contacted and aware about pipeline safety and the requirements when working on or near the pipeline easement was performed in 2006. A 5 Yearly risk assessment was completed during the year inline with the requirements of AS2885. The final report is to be issued in early 2007 and did not identify any immediate significant issues requiring rectification. 12 REPORTS ISSUED DURING THE 2006 LICENCE YEAR The following reports were generated and forwarded to Santos for the Liquids Line pipeline in 2006: • PL 2 Annual Report for 2005 (forwarded early 2006) • Monthly maintenance reports • 2007 annual maintenance plan (for approval by Santos) • Approved Statement of Environmental Objectives • Draft Environmental Impact Report 13 VOLUME OF PRODUCT TRANSPORTED 1,652,725 m3 of product was transported through the Liquids Pipeline in 2006.


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14 PROPOSED OPERATIONAL ACTIVITIES FOR 2007 During 2007 the following activities are proposed for the Liquids Line pipeline: • Complete all scheduled routine maintenance activities and corrective maintenance identified • Submission of a 2007 Annual Report in early 2008 • Conduct a Cleaning Pigging Run • Address relevant actions from the 2006 AS2885 risk assessment • Assess and repair any defects identified from the recent intelligent pigging & DCVG programs.

15 STATEMENT OF EXPENDITURE Commercially sensitive

2006 PL2 Annual Report 16 KEY PERFORMANCE INDICATORS The following key performance indicators have previously been established to monitor performance of operations and maintenance activities on the Liquids Line. Outlined below are the KPI results for 2006. 2006

Target 2006

Actual 2006 Comment

Cathodic Protection Percentage of the pipeline protected to AS2832.1 level

100% 100% This represents a satisfactory level of protection over the entire length of the pipeline (latest August survey data).

Internal Corrosion SRB count from 100 ml sludge sample using serial dilution method Sample collected during pig cleaning

3 or less

positive

<3 positive

During 2006 the cleaning pig run monitoring for SRB’s found levels were negligible.

Third Party Incident Number of times pipeline is damaged

0 0 No damaged occurred to the pipeline during the reporting period

Number of near misses (digging within 1m of pipeline)

0 0 No activities of this nature that involved Epic Energy the owner or a third party were identified during the reporting period

Exposure of pipeline due to washout and wind erosion

0 0 During the reporting period, there were no instances of the pipeline cover being eroded due to wind or water

SCADA and Leak Detection Reliability of SCADA and Leak Detection System

100% 98% During the reporting period a number of communications outages were caused as a result of inclement weather or equipment failures and these were rectified in a timely manner.

Environmental Number of uncontrolled hydrocarbon releases

0 1 Stem seal failure resulted in one uncontrolled hydrocarbon leak at MLV25 in the Pt Bonython compound.

Earth Tremor Surveillance Vehiclar surveillance immediately after an earth tremor or flood

100% 100% No floods or earth tremors were reported during 2006

17 CONCLUSION The maintenance and inspection programs carried out on the Liquids Line Pipeline in 2006 indicated the pipeline is in sound condition and is capable of operating at set parameters with no restrictions. The CP Survey results supplied in Appendix B indicate the protection level meets the targeted performance levels for this system. The risk assessment conducted in 2006 did not highlight any significant immediate risks requiring attention. Some follow up work is required to ensure that the risks associated with the pipeline remain ALARP. The pipeline is considered to be in good working condition and well maintained.

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Appendix A – Assessment of Declared Objectives


ASSESSMENT OF DECLARED OBJECTIVES PL 2 Liquids Line Objectives and Assessment Criteria1

OBJECTIVE G OOAL BJECTIVE ACHIEVED OBJECTIVE ACHIEVED YES / NO

SUPPORTING COMMENTS

1.1 To minimise disturbance or damage to infrastructure / land use and remediate where disturbance cannot be avoided

When disturbance to infrastructure (eg. such as fencing or access tracks) occurs less than once every five years.

Yes During the reporting period disruption to the landowners was considered to be minimal.

1. To avoid unnecessary disturbance to 3rd party infrastructure, landholders or land use

1.2 To minimise disturbance to landholders

If access to private property occurs more often than once a year in accordance with landowner agreements.

Yes During the reporting period disruption to the landowners was considered to be minimal.

2.1 To remediate erosion as a result of pipeline operations in a timely manner

When the extent of soil erosion on the easement was consistent with surrounding land.

Yes The pipeline is patrolled routinely (immediately after any significant amounts of rainfall have occurred) and any erosion noted is repaired in a timely manner.

2. To maintain soil stability/integrity

2.2 To prevent soil inversion

Annual land survey to look for soil discolouration, success of vegetation return as an indicator. Disturbance checklist signed off to indicate top soil/subsoil is stockpiled separately and soil profiles appropriately reinstated following the re-instatement of works/excavations.

Yes During the reporting period three excavation activities took place.

Epic Energy staff supervising pipeline excavations is required to advise the plant operators to stockpile topsoil separate from the deeper spoil and return it to the top of the backfilled excavation. (see WM02-134)

Based on this process being followed no soil inversion has taken place and therefore the objective has been met.

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OBJECTIVE GOAL OBJECTIVE ACHIEVED OBJECTIVE ACHIEVED YES / NO

SUPPORTING COMMENTS

3.1 To maintain regrowth of native vegetation on the easement to be consistent with surrounding area

Off ROW vegetation clearing limited to previously disturbed areas or areas assessed to be of low sensitivity. Area of disturbance has been minimised. In event of pipeline repair, open trenches are monitored daily and not left open for more than 72 hours.

Yes The condition of the native vegetation within the pipeline easement is consistent with the surrounding vegetation.

3.2 To minimise additional clearing of native vegetation as part of operational activities

Off ROW vegetation clearing limited to previously disturbed areas or areas assessed to be of low sensitivity. Area of disturbance has been minimised.

Yes During the reporting period three excavation activities took place. Whenever excavations occur care is taken to ensure damage to the local vegetation is minimal.

3.3 To ensure maintenance activities are planned and conducted in a manner that minimises impacts on native faun

Species abundance and distribution in such areas was consistent with the surroundings. Follow-up restoration work was undertaken as necessary.

Yes Maintenance activities during 2006 that may have had an impact on the native fauna were minimal and were conducted so that no impact was felt.

3. To maintain native vegetation cover on the easement

3.4 To minimise disturbance of marine habitats

Not relevant for this pipeline

Yes No leakages or spillage was reported or recorded in any area where a marine environment exists.

4. To prevent the spread of weeds and pathogens

4.1 To ensure that weeds and pathogens are controlled at a level that is at least consistent with adjacent land

The presence of weeds and pathogens on the easement was consistent with adjacent land.

Yes The presence of weeds and pathogens on the easement was consistent with adjacent land.

5. To minimise the impact of the pipeline operations on surface water resources

5.1 To maintain current surface drainage patterns

Surface drainage has been restored and maintained to preconstruction condition.

Yes During the reporting period no alterations have been made to the landscape through which the pipeline traverses and therefore current drainage patterns have been maintained.

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SUPPORTING COMMENTS

6.1 To prevent spills occurring, and if they occur minimise their impact

Spill protection methods are used. All liquid waste is contained within impermeable containers or containment. No evidence of any spills or leaks from operations.

No The stem seal on the Liquids Main Line Valve (LMLV) 25 leaked, discharging product to atmosphere and prompting an emergency response. The leak was caused by seal deterioration and promptly addressed. The amount of leakage that occurred was minimal and any product that found its way to the ground was removed of and disposed in an approved Santos soil facility

6.2 To remediate and monitor areas of known contamination arising from pipeline operations

No evidence of rubbish or litter on ROW or at facilities. Waste material is appropriately contained and disposed of. There is not evidence of any contamination. Records are maintained for all hazardous waste disposal.

Yes There are no areas of contamination occurring as a result of the pipeline operations.

6.3 To prevent the spread of contamination where the easement intersects known contaminated sites

Burns pits are no longer used to collect oil. Contractors are utilised for the collection of waste oil. These sites are audited and inspected on a routine basis.

Yes The Pipeline does not traverse any contaminated sites and therefore this is not an issue. The Burn pits at PS2 and 4 have been rehabilitated back to their natural condition and a 13600 litre liquids hydrocarbon collection tank has been installed allowing all product that is drained as a result of pipeline operations to be collected and removed from site by an approved recycling contractor.

6. To avoid land or water contamination

6.4 To ensure that rubbish and waste material is disposed of in an appropriate manner.

Where practicable, recyclable waste is segregated and returned to Peterborough or sent to a recycling depot. Where not practicable to recycle, waste is disposed of in an appropriate manner.

Yes All rubbish and waste material is removed from all of the pipelines facilities and the easement. This material is transported back to an approved refuse collection and disposal facility.

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SUPPORTING COMMENTS

6.5 To prevent impacts as a result of hydro-test water and waste water (water bath heaters and wash down water) disposal

Inspection of water disposal sites for evidence of water entering a watercourse or environmentally sensitive area. Testing of water quality prior to release/disposal of waste water. Records on source of water and discharge method/location. Water discharged onto stable ground, with no evidence of erosion as a result of discharge. Water disposed of in a manner that prevented discharge or runoff to watercourses or environmentally sensitive areas.

Yes During the reporting period there were no operational requirements to dispose of any waste water.

6.6 To ensure the safe and appropriate disposal of grey water (sullage, sewage)

Compliance with the relevant local government regulations or relevant health and sanitation regulations.

Yes All waste water at Epic Energy’s facilities is managed in accordance with statutory regulations and requirements.

7. To minimise the risk to public health and safety

7.1 To adequately protect public safety during normal operations

The pipeline easement was clearly identified by signs that had been installed in accordance with AS2885. A comprehensive landowner liaison program was implemented. An Emergency Response Plan is in place and staff are adequately trained.

Yes The use of approved work instructions, job hazard analysis, permits to work and experienced staff all contribute to Epic Energy meeting this objective.

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SUPPORTING COMMENTS

7.2 To adequately protect public safety during maintenance

All affected and adjacent landowners were advised of the nature and schedule of maintenance activities. All potentially hazardous areas were signposted or marked with bunting. Adequate traffic management practices were implemented. There were no injuries or incidents involving the public.

Yes All landowners and relevant authorities are advised whenever any work is scheduled on their property or land under their control.

All potentially hazardous work sites are marked

During the reporting period no activities were undertaken that required specific traffic management procedures to be in place. Epic staff are trained in traffic management practices and do employ these techniques whenever required.

In addition to the comments above the comments for 7.1 apply.

7.3 To avoid fires associated with pipeline maintenance activities

Fuel load on the easement was consistent with adjacent land. All operations personnel were trained in fire safety procedures. No pipeline related fires have occurred.

Yes No maintenance activities were performed during the reporting period that may have contributed to a fire situation.

7.4 To minimise oil losses during pigging and other routine pipeline operations

Spill protection methods are used. All liquid waste is contained within impermeable containers or containment. No evidence of any spills or leaks from operations.

Yes During the reporting period one pigging operation was carried out with the liquid waste being captured in purpose built underground tanks.

Page 21 of 37



SUPPORTING COMMENTS

7.5 To monitor the condition of the pipeline to ensure that potential pipeline leaks are identified and appropriate action implemented

Pipeline is pigged at least annually. Slug of bactericide is sent along pipeline following cleaning to kill and prevent any bacterial growth. Waste material is analysed for evidence of pipeline corrosion and appropriate action initiated.

Yes The results of samples taken during the cleaning run conducted in 2006 resulted in no SRB’s being detected in the samples taken.

7.6 To prevent unauthorised activity on the easement that may adversely impact on the pipeline integrity

Inspection / Patrol reports and records. Comprehensive landholder liaison program and records of communications with landholders. Community education program implemented in Regional areas. ‘Dial before you dig’ number available and widely advertised. Clear identification of the pipeline by signs installed in accordance with AS2885. All reports of unauthorized activity are reported and investigated.

Yes A Community awareness and landowner contact program along with routine patrols ensure that unauthorised activities on the pipeline are prevented.

Pipeline signage from Moomba to Port Bonython has been upgraded to a spacing interval of 500 metres which exceeds AS 2885 requirements.

During 2006 Epic Energy conducted phone interviews with all land owners and property managers to ascertain their awareness of the pipeline systems in their area.

Epic have developed a new calendar ready for distribution in 2007 to heighten awareness of third party activities on the pipeline systems

A revised Pipeline Safety Awareness Strategy is being for implementation in 2007.

8. Minimise impact of emergency situations

8.1 To minimise the impact as a result of an emergency situation or incident

The pipeline is inspected, monitored, reviewed and appropriate records kept. All staff were trained in and aware of emergency response procedures.

Yes One emergency situation was recorded and managed during the reporting period. The product discharge at LMLV #25 initiated an emergency response.

During the reporting period one emergency exercise was conducted on the Liquids Line testing field response.

Page 22 of 37


Page 23 of 37


SUPPORTING COMMENTS

8.2 To restore any damage that may occur as a result of an emergency situation

Refer to previous criteria (Objective 1, 2, 3 & 6).

Yes During the one declared emergency in 2006 involving MLV 25 there was no damage reported, either environmental or physical

9. To minimise noise due to operations

9.1 To ensure operations comply with noise standards

Operational activities comply with noise regulations, under the Environment Protection Act 1993. No complaints were received.

Yes All maintenance tasks performed during the reporting period were of a nature that did not contribute to any increased levels of noise pollution. The operation of the pipeline does not require any pumping equipment or the release of high pressure product and therefore no noise is generated from this source.

10.1 To eliminate uncontrolled atmospheric emissions

Spill protection methods are used during routine operations.

Incident/Spill reports.

Scheduled routine maintenance plan.

Yes During the emergency at MLV 25 product discharge was limited to a fine liquids hydrocarbon mist which was directed into a purpose built closed drain system for processing at the Pt Bonython plant shortly after the release was reported.

10. To minimise atmospheric emissions

10.2 To minimise the generation of dust.

Incident reports.

Compliance with work instructions.

Yes During the reporting period three excavations occurred on the pipeline system. These excavations were carried out in a remote area of the state and they in no way caused any noticeable increase in the level of dust emissions near the excavation site.

11. To adequately protect cultural heritage sites and values during operations and maintenance

11.1 To ensure that identified cultural sites are not disturbed

No impact to known or new sites

Yes No operations or maintenance activities occurred during 2006 that had any impact on cultural heritage sites.


Appendix B – Pipeline Cathodic Protection Data


Liquids Line Corrosion Protection On/Off Potentials 2006 Surveys Protection On/Off potentials taken in February and August survey indicated that the pipeline was fully protected for the whole of 2006 and all potentials are compliant with AS 2885 and AS 2832.1 The information presented below in Table 1 is the cathodic protection potentials that were taken during both February and August.

Table 1 – February and August Results 2006

February August Location

KP “On” mV

“Off” mV

“On” mV

“Off” mV

Moomba M/S Outlet (U/S) 0.0 No Reading at TP Moomba M/S Outlet (D/S) 0.0 1430 1190 1250 1080

TR: Moomba 0.2 1380 1080 1240 1080 Telluric Potential: Max, Min 0.2 1400 1070 1240 1070

1.3 1360 1040 1220 1080 3.3 1350 1060 1180 1030 4.8 1360 1050 1210 1040

Interference from Main Gasline 4.8 1340/1324 1380/1340 5.4 1320 1010 1150 990

SANTOS Pipe 5.4 1372/1384 6.4 1330 1020 1170 1020 6.8 1310 1010 1160 101040

SANTOS Pipe 6.8 990/1020 7.8 1270 980 1120 1010 9.4 1280 980 1180 1030 9.6 1260 960 1190 1030

SANTOS Pipe "A" 9.6 806/912 SANTOS Pipe "B" 9.6 1036/1041

11.0 1290 990 1210 1050 SANTOS Pipe 11.0 1590/1550

11.2 1310 1000 1200 1030 12.8 1200 1040 13.2 1290 990 1200 1030

SANTOS Pipe 13.2 1511/1430 14.0 1290 1010 1190 1020

SANTOS Pipe 14.0 1460/1390 14.4 1270 1020 1190 1030 16.1 1230 1040 1170 1010



KP “On” mV

“Off” mV

“On” mV

“Off” mV

17.7 19.4 1330 1030 1170 1000 21.2 1290 1020 1170 980

Interference from Main Gasline 21.2 1330/1285 1350/1315 MLV 2 21.3 1280 1030 1160 960

22.6 1250 1000 1110 950 24.2 1240 980 1090 910 26.0 1230 990 1070 910 27.3 1230 1000 1100 920 29.0 1200 1000 1080 910 30.4 1230 1010 1100 930 32.0 1200 1000 1050 920 33.6 1220 1020 1140 910

Interference from Main Gasline 33.6 1245/1190 1450/1380 35.2 1230 1000 1100 910 36.8 1220 1010 1110 910 38.4 1240 1000 1110 920 40.2 1250 990 1030 900 41.8 1260 1000 1150 910


43.5 1270 1000 1110 900 44.8 1280 1010 1130 920 46.5 1290 1010 1130 920 48.1 1290 1000 1190 950

Interference from Main Gasline 48.1 1330/1290 1390/1395 49.7 1270 990 1200 980 51.3 1280 980 1220 990

Interference from Main Gasline 51.3 1300/1270 52.9 1270 970 1210 980 54.6 1290 980 1220 990 56.1 1300 960 1260 1020

Interference from Main Gasline 56.1 1320/1309 1540/1515 57.8 1280 950 1250 1010 59.4 1310 960 1250 1000 60.9 1320 970 1260 1000 62.6 1360 990 1300 1020 64.2 1380 1000 1280 1010 65.8 1400 1010 1350 1040 67.3 1460 1020 1400 1060


TR: CS1 67.8 1370 1020 1310 1040



KP “On” mV

“Off” mV

“On” mV

“Off” mV

Telluric Potential: Max, Min 67.8 1330/1020 69.1 1410 1030 1380 1070 70.4 1370 1010 1370 1070

Interference from Main Gasline 70.4 1310/1280 MAP anode bed

failed 72.0 1360 1000 1410 1080 73.6 1340 990 1370 1070 75.6 1290 960 1340 1070 77.1 1310 980 1380 1080


Interference from Main Gasline 85.0 1230/1190 1370/1320 86.7 1240 970 1340 1090 88.4 1250 990 1340 1090 89.9 1260 1000 1360 1110 91.5 1250 980 1360 1100 93.2 1230 960 1330 1090 94.7 1250 970 1340 1100 96.4 1240 960 1310 1080 97.9 1250 960 1330 1090


99.6 1240 960 1390 1110 101.4 1210 930 1360 1080 102.8 1240 950 1430 1130

Interference from Main Gasline 102.8 1260/1230 1363/1337 104.5 1190 920 1370 1120 106.0 1180 910 1380 1110 107.7 1210 940 1370 1100 109.3 1220 960 1410 1130 110.8 1200 930 1370 1100 112.2 1220 950 1370 1100 114.1 1200 920 1360 1080 115.6 1220 950 1410 1120

TEG: Carraweena 116.6 1240 970 1440 1140 Interference from Main Gasline 116.6 1260/1230 1375/1350

117.3 1210 940 1370 1080 118.9 1210 950 1340 1060 120.5 1170 910 1330 1040 122.2 1190 920 1320 1040



KP “On” mV

“Off” mV

“On” mV

“Off” mV

122.2 1190 920 1320 1040 123.8 1200 930 1330 1040 125.6 1210 920 1330 1040 127.0 1210 940 1330 1040 128.6 1260 970 1370 1060

MLV 6 130.1 1210 950 1360 1070 Interference from Main Gasline 130.1 1230/1200 1375/1330

130.2 1250 970 1380 1050 131.8 1280 990 1380 1050 133.5 1300 920 1390 1050 135.0 1330 1040 1390 1040 136.4 1320 1030 1410 1050 138.2 1340 1030 1430 1070 139.8 1330 1020 1430 1060 141.4 1380 1040 1420 1050 143.0 1380 1030 1440 1060 144.6 1400 1040 1460 1080 146.2 1370 1010 1460 1040

Interference from Main Gasline 146.2 1350/1290 1540/1490 148.1 1420 1020 1480 1050 149.3 1470 1030 1490 1060 151.1 1480 1020 1500 1060 152.6 1520 1040 1530 1080 154.2 1540 1060 1560 1110 155.9 1580 1080 1580 1120 157.5 1600 1090 1570 1090 159.1 1620 1090 1590 1090 160.7 1660 1080 1650 1080

TR: Pump Station 2 161.4 1720 1050 1670 1140 Interference from Main Gasline 161.4 1520/1500

Telluric Potential: Max, Min 161.4 1670/1140 MLV 7 161.9 1580 1090 1570 1110

162.3 1620 1070 1610 1140 164.0 1610 1040 1610 1130 165.5 1550 1040 1580 1130 167.2 1480 970 1560 1130 168.9 1580 1070 1550 1130 170.4 1550 1070 1540 1140 172.1 1510 1020 1580 1150

Interference from Main Gasline 172.1 1580/1550 173.7 1500 1030 1540 1160 175.4 1570 1060 1520 1150 176.8 1530 1080 1520 1160



KP “On” mV

“Off” mV

“On” mV

“Off” mV

178.5 1540 1070 1500 1150 Interference from Main Gasline 178.5 1590/1550 1562/1528

180.1 1460 1060 1500 1160 181.7 1470 1070 1470 1140 183.3 1450 1050 1460 1140 184.8 1470 1080 1480 1160

Interference from Main Gasline 184.8 No Switching 1545/1518 186.5 1380 1000 1460 1150 188.1 1420 1010 1490 1150

Interference from Main Gasline 188.1 1560/1510 1556/1513 189.7 1340 980 1430 1130 191.3 1330 970 1440 1130 192.0 1350 980 1450 1140


192.9 1320 960 1430 1130 194.5 1290 940 1410 1120

Interference from Main Gasline 194.5 1540/1530 1535/1510 196.1 1280 940 1400 1120 197.8 1290 940 1390 1100

199.3TP over no readings

TP over. No reading

Interference from Main Gasline 199.3 No Reading 201.2 1230 900 1380 1110 202.6 1220 890 1390 1130 204.2 1210 900 1370 1120


Interference from Main Gasline 209.1 1760/1680 1805/1700 210.6 1340 960 1410 1100 212.2 1330 970 1390 1080 213.9 1310 970 1380 1090 214.7 1290 960 1350 1070

TEG: Moolawatana 215.3 1210 930 1330 1060 Interference from Main Gasline 215.3 1480/1450 1576/1540

215.5 1330 950 1280 1020 217.1 1350 960 1380 1080 218.7 1370 970 1390 1080




KP “On” mV

“Off” mV

“On” mV

“Off” mV

223.8 1480 1030 1440 1110 Interference from Main Gasline 223.8 1640/1570 1676/1633

MLV 9 223.8 1450 1000 1440 1120 224.9 1380 980 1430 1100 226.7 1370 980 1420 1100 228.4 1380 980 1420 1090 229.9 1380 980 1440 1100



Interference from Main Gasline 238.8 1580/1530 1623/1570 239.7 1400 970 1490 1120 241.3 1400 980 1570 1140 242.9 1390 970 1510 1140 244.6 1400 960 1510 1130

Interference from Main Gasline 244.6 Solar Site Off 246.1 1590 960 1530 1150 247.8 1590 970 1520 1140 249.4 1680 950 1540 1150 250.9 1670 930 1530 1140 252.6 1660 910 1550 1150 254.2 1680 910 1570 1150

TR: CS3 255.9 1630 940 1580 1120 Interference from Main Gasline 255.9 1400/1090 1390/1120

Telluric Potential: Max, Min 255.9 1590/1120 MLV 10 256.2 1420 930 1380 1070

257.7 1580 940 1520 1140 259.2 1630 970 1530 1150 260.6 1600 960 1510 1130 262.2 1570 950 1520 1140 263.9 1570 960 1510 1130 265.5 1590 970 1510 1130 267.0 1590 980 1500 1120 268.7 1570 970 1490 1120 270.2 1510 950 1470 1110 271.9 1510 950 1480 1110 273.6 1490 940 1460 1090 275.2 1470 940 1460 1090



KP “On” mV

“Off” mV

“On” mV

“Off” mV

276.8 1460 930 1470 1090 278.4 1420 920 1480 1100 279.9 1570 970 1560 1170


MLV 11 288.3 1470 990 1480 1100 289.5 1530 990 1510 1110 291.2 1490 960 1500 1110 292.8 1540 980 1500 1100 294.6 1550 1000 1490 1090 296.0 1540 1000 1500 1090 297.7 1530 1010 1510 1100 299.4 1490 970 1490 1080 300.9 1510 980 1490 1080 302.4 1480 960 1490 1070 304.0 1500 980 1500 1080

TEG: Wertaloona 305.3 1560 1000 1520 1090 Interference from Main Gasline 305.3 1580/1550 1574/1530

307.3 1500 980 1520 1080 309.0 1480 960 1520 1080 310.6 1490 960 1530 1090 312.1 1460 940 1520 1070 313.8 1480 940 1540 1080 315.2 1500 960 1520 1060 316.9 1490 950 1540 1080 318.5 1500 960 1540 1080

MLV 12 320.2 1520 970 1550 1070 321.7 1530 960 1520 1040 323.3 1490 940 1540 1050 325.1 1550 970 1550 1050 326.6 1540 960 1540 1030 328.2 1540 950 1630 1120

Interference from Main Gasline 328.2 Solar site "OFF" 1615/1570 329.8 1560 960 1580 1040 331.4 1530 940 1600 1060 333.0 1560 650 1590 1050 334.6 1570 950 1610 1050 336.3 1580 950 1610 1040 337.8 1590 940 1620 1030



KP “On” mV

“Off” mV

“On” mV

“Off” mV

339.5 1590 950 1630 1040 341.0 1610 950 1640 1040 342.6 1610 940 1650 1040 344.3 1640 950 1670 1040 345.8 1620 940 1690 1040 347.8 1660 960 1690 1040 349.4 1620 920 1710 1050 350.8 1670 930 1710 1040 352.4 1610 900 1740 1060

TR: Pump Station 3 352.6 1430 890 1500 960 Interference from Main Gasline 352.6 1320/1310 1323/1318

Telluric Potential: Max, Min 352.6 1450/880 1230/960 Pump Station 3 - Site 352.6 1290 940 1220 960

MLV 13 352.8 1500 960 1560 1030 354.2 1710 990 1700 1050 355.2 1680 970 1680 1040 357.1 1630 960 1640 1020 358.9 1630 980 1650 1050 361.0 1590 970 1630 1050 362.3 1560 970 1600 1040 363.7 1520 940 1560 1030 364.2 1500 940 1580 1050 365.1 1500 950 1580 1050 365.6 1500 960 1560 1040 367.4 1480 970 1550 1060 369.4 1480 990 1560 1080 370.8 1440 980 1530 1060 372.4 1430 980 1490 1050 374.0 1410 990 1500 1070 375.5 1400 1000 1450 1040

MLV 14 377.1 1370 1010 1450 1070 378.4 1390 1000 1480 1070 379.7 1410 1020 1500 1100 381.4 1390 1010 1460 1080 383.0 1400 1020 1430 1030 384.5 1390 1020 1520 1120 386.0 1420 1030 1480 1080 387.4 1400 1010 1420 1020 388.8 1390 1020 1470 1080 390.0 1390 1030 1450 1050 391.5 1380 1030 1450 1050 393.0 1360 1010 1420 1020 394.3 1390 1030 1510 1130



KP “On” mV

“Off” mV

“On” mV

“Off” mV

395.8 1380 1020 1520 1140 397.5 1390 1030 1510 1130 399.0 1370 1020 1520 1120 400.0 1380 1010 1470 1120

MLV 15 401.7 1350 1020 1450 1080 TR: Martin's Well 402.6 1370 1010 1480 1080

Telluric Potential: Max, Min 402.6 1380/1010 1500 1060 403.7 1370 1010 1460 1080 404.8 1410 1020 1480 1080 405.9 1370 1010 1460 1090 407.0 1380 1020 1500 1110 408.4 1360 1000 1470 1100 409.9 1350 1000 1460 1090 411.3 1320 970 1440 1070 412.4 1350 1010 1480 1120 413.7 1360 1020 1490 1140 415.1 1340 1010 1470 1140 416.3 1340 1020 1460 1130 417.5 1330 1010 1440 1120 418.8 1300 980 1420 1090 420.0 1300 980 1410 1090 421.2 1280 970 1420 1080 422.4 1270 960 1380 1060 423.7 1250 950 1340 1040 424.9 1200 930 1320 1020 426.6 1210 940 1320 1010

MLV 16 428.3 1210 960 1300 1020 430.0 1240 940 1340 1030 431.7 1260 960 1330 1030 433.0 1270 970 1340 1020 434.0 1290 990 1340 1030 434.9 1290 990 1330 1020 436.1 1290 980 13300 1010 437.3 1290 990 1310 1000 438.4 1310 1000 1340 1030 440.1 1290 970 1350 1040 441.5 1280 960 1350 1040 443.0 1310 980 1330 1020 444.0 1300 970 1350 1030 445.1 1300 970 1360 1030 446.0 1340 990 1320 1020 447.2 1380 1020 1360 1030 448.6 1340 980 1380 1040


February August

Location KP

“On” mV

“Off” mV

“On” mV

“Off” mV

449.9 1400 1020 1360 1030 451.6 1390 1010 1350 1010 452.9 1380 1000 1330 1000

MLV 17 454.0 1260 970 1240 980 455.7 1400 1000 1380 1030 456.9 1410 1010 1390 1030 458.4 1460 1020 1420 1030 460.0 1450 1000 1410 1020 461.8 1490 1010 1420 1030 463.0 1490 1000 1400 1010

TR: Hawker 464.1 1540 1010 1420 1010 Telluric Potential: Max, Min 464.1 1550/1010 1430/1010

465.2 1510 1040 1400 1020 466.6 1480 1030 1430 1020

Road Crossing Case 466.6 381/381 369/369 468.1 1480 1040 1440 1060 469.4 1480 1050 1450 1060 470.9 1480 1050 1430 1070 472.8 1440 1040 1410 1050 474.7 1440 1040 1420 1060 476.3 1410 1040 1420 1070

Road Crossing Case 476.3 539/539 564/564 MLV 18 477.5 1460 1060 1300 1000

478.9 1470 1070 1300 1010 480.2 1490 1080 1410 1060 481.3 1470 1070 1390 1050 482.7 1470 1070 1400 1060 483.7 1430 1040 1420 1070 484.7 1450 1040 1420 1060 485.8 1440 1050 1420 1070 486.9 1470 1060 1450 1070 488.0 1480 1060 1430 1060 489.4 1480 1050 1450 1070 491.2 1480 1060 1460 1080 493.1 1480 1030 1420 1030 494.9 1470 1020 1470 1070 496.8 1470 1010 1480 1070 498.3 1440 990 1440 1020 500.0 1490 1020 1490 1060 501.5 1500 1020 1430 1010 503.1 1500 1000 1490 1050 503.6 1520 1020 1510 1060

Rail Crossing Case 503.6 459/462 466/468



KP “On” mV

“Off” mV

“On” mV

“Off” mV

TR: PS4,Neuroodla 503.8 1490 1020 1490 1070 Telluric Potential: Max, Min 503.8 1520/1020 1490/1070.

Pump Station 4 - Site 503.8 1450 1040 1460 1090 MLV 19 503.8 1470 1070 1470 1100

505.0 1530 1050 1570 1140 506.6 1500 1020 1460 1030 508.5 1490 1030 1490 1070 510.2 1480 1030 1470 1080 511.9 1460 1020 1500 1110 513.9 1380 980 1480 1090 515.8 1430 1020 1450 1070 517.2 1420 1020 1420 1050 518.6 1450 1050 1440 1080 520.0 1440 1060 1380 1040 521.8 1450 1070 1390 1050

Private Water Pipe 521.8 394/394 204/204 523.5 1430 1070 1400 1070 525.8 1410 1060 1350 1030

MLV 20 526.6 1360 1040 1340 1030 528.6 1400 1050 1360 1040 530.8 1420 1070 1350 1040 532.7 1430 1080 1360 1050 534.3 1430 1080 1350 1050 536.8 1430 1070 1390 1070 538.6 1430 1060 1420 1100 539.8 1410 1050 1400 1080

Overhead Powerline 541.1 1410 1050 1380 1060 543.3 1430 1060 1380 1060 545.4 1420 1050 1380 1060 547.3 1410 1050 1380 1050 548.7 1330 1050 1320 1070 550.7 1430 1050 1400 1080 552.6 1500 1110 1420 1080 554.2 1470 1070 1400 1060

TR: Monument Hill 556.0 1510 1080 1430 1080 Telluric Potential: Max, Min 556.0 1520/1080 1440/1080

MLV 21 557.8 1390 1060 559.6 1510 1120 1940 1120 561.6 1540 1070 1400 1100 563.3 1430 1070 1420 1120 565.3 1390 1050 1430 1130 566.8 1410 1080 1400 1120 568.2 1390 1070 1380 1110 570.2 1360 1060 1370 1100



KP “On” mV

“Off” mV

“On” mV

“Off” mV

Overhead Powerline 571.7 1360 1060 1360 1110 573.2 1320 1040 1350 1100 575.1 1310 1040 1340 1090 577.1 1270 1020 1320 1080

Rail Crossing Case 577.1 504/504 513/513 579.2 1260 1020 1310 1080 580.3 1260 1020 1300 1070 581.6 1240 1020 1280 1060 581.7 1220 1000 1270 1050

Road Crossing Case 581.7 491/491 505/505 583.4 1170 970 1240 1030 585.2 1190 990 1250 1040 586.7 1160 980 1220 1020

MLV 22 588.0 1150 980 1220 1030 589.7 1180 1010 1220 1030 591.4 1170 990 1210 1020 593.3 1170 990 1210 1020 595.1 1160 980 1200 1020 596.7 1150 980 1210 1030 598.8 1130 960 1200 1010 600.7 1130 970 1200 1020 602.1 1140 980 1190 1010 604.1 1140 970 1190 1010 605.5 1220 1050 1180 1000

Road Crossing Case 605.5 375/375 364/364 605.6 1230 1060 1180 1000

SA Water Pipe 605.6 362/362 350/350 605.7 1260 1090 1190 1010

Rail Crossing Case 605.7 500/500 498/498 TR: Lincoln Gap 606.3 1270 1100 1210 1030

Telluric Potential: Max, Min 606.3 1280/1100 1220/1030 Earthing Anode 607.2 1260 1090 1190 1010 Earthing Anode 608.0 1190 1030 1180 990 Earthing Anode 609.2 1270 1100 1190 1010 Earthing Anode 609.8 1260 1090 1210 1020 Earthing Anode 610.4 1300 1130 1230 1040

Earthing Anode - MLV 23 611.0 1250 1090 1200 1020 Earthing Anode 611.7 1340 1180 1270 1070 Earthing Anode 612.2 1260 1100 1260 1050 Earthing Anode 612.8 1250 1090 1260 1050 Earthing Anode 613.4 1270 1100 1260 1050 Earthing Anode 614.0 1340 1170 1290 1070 Earthing Anode 614.6 1270 1100 1230 1020 Earthing Anode 615.2 1300 1120 1270 1050



KP “On” mV

“Off” mV

“On” mV

“Off” mV

Earthing Anode 615.9 1270 1100 1250 1030 Earthing Anode 617.9 1300 1110 1250 1030

619.8 1310 1100 1260 1030 621.1 1310 1110 1270 1030 622.8 1270 1090 1300 1050 624.4 1310 1120 1320 1060 626.1 1350 1140 1340 1080 627.7 1350 1130 1360 1080 629.2 1360 1140 1380 1100 631.1 1390 1150 1380 1100 633.0 1400 1150 1420 1110 634.9 1410 1150 1430 1100 636.5 1430 1150 1440 1110 638.1 1470 1160 1500 1150 639.7 1490 1170 1520 1160 641.7 1470 1150 1520 1140

MLV 24 642.4 1540 1190 1580 1180 643.2 1450 1100 1480 1070

SA Water Pipe 643.2 1270/1270 1348/1348 Earthing Anode 643.8 1560 1180 1600 1160 Earthing Anode 645.2 1550 1130 1590 1120 Earthing Anode 646.5 1500 1050 1660 1130 T/R: False Bay 646.8 1590 1120 1660 1120

Interference from Whyalla Lateral 646.8 1620/1609 Telluric Potential: Max, Min 646.8 1597/1120 1660/1120

Earthing Anode 648.0 1620 1160 1680 1180 Earthing Anode 649.3 1580 1120 1650 1150 Earthing Anode 650.5 1610 1160 1710 1170 Earthing Anode 651.0 1550 1110 1670 1130 Earthing Anode 651.8 1510 1070 1600 1100 Earthing Anode 653.0 1500 1060 1620 1120 Earthing Anode 654.4 1510 1070 1660 1160 Earthing Anode 655.8 1470 1050 1610 1120 Earthing Anode 657.2 1520 1080 1680 1180 Earthing Anode 657.9 1400 980 1600 1120

658.0 1290 880 1480 1000 Road Crossing Case 658.0 456/458 481/472 TR: Port Bonython 658.1 1240 830 1470 960

Telluric Potential: Max, Min 658.1 1250/840 1480/960 Reference Coupon * 658.1 1270/950

Port Bonython M/S Inlet (U/S) 658.1 1160 780 1350 920 Port Bonython M/S Inlet (D/S) 658.1 810/780 798/826

Documents

2006 Annual Report MOOMBA TO PORT BONYTHON LIQUIDS PIPELINEpetroleum.statedevelopment.sa.gov.au/__data/assets/... · The Moomba to Port Bonython Liquids Pipeline is owned by the South