pipeline licence 1 - department of state...

EPIC ENERGY

South Australia Pty Ltd

2013 Annual Report

MOOMBA TO ADELAIDE PIPELINE

Pipeline Licence 1

Document Number S-1-101-AR-G-014

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1. Purpose ...................................................................................................................................... 5

2. Scope .......................................................................................................................................... 5

3. Technical Aspects ....................................................................................................................... 5

4. Operational and Maintenance Activities ................................................................................. 10

4.1. Risk Management Review ................................................................................................ 10

4.2. Training ............................................................................................................................. 10

4.3. Operations and Maintenance Activities ........................................................................... 12

4.4. Pipeline Patrol Activities ................................................................................................... 13

4.5. Pipeline Integrity .............................................................................................................. 14

4.6. Electrical and Instrumentation Maintenance Activities ................................................... 15

4.7. Communications............................................................................................................... 16

4.8. Mechanical Maintenance Activities ................................................................................. 16

4.9. Pigging .............................................................................................................................. 17

4.10. Cathodic Protection .......................................................................................................... 17

4.10.1. MAP Mainline ................................................................................................................... 18

4.10.2. Wasleys Loop Line ............................................................................................................ 18

4.10.3. MAP Compressor Station Loop ........................................................................................ 18

4.10.4. Peterborough Lateral ....................................................................................................... 18

4.10.5. Port Pirie Lateral ............................................................................................................... 18

4.10.6. Burra lateral ...................................................................................................................... 18

4.10.7. Mintaro Lateral ................................................................................................................. 18

4.10.8. Angaston Lateral............................................................................................................... 19

4.10.9. Pelican Point Lateral ......................................................................................................... 19

4.10.10 Osborne Lateral ................................................................................................................ 19

4.10.11 Dry Creek Lateral .............................................................................................................. 19

4.10.12 Taperoo Lateral ................................................................................................................ 19

4.10.13 Port Bonython Lateral ...................................................................................................... 19

4.10.14 Whyalla Lateral ................................................................................................................. 19

4.10.15 Nuriootpa Lateral ............................................................................................................. 19

4.10.16 Quarantine Lateral ........................................................................................................... 19

4.10.17 Hallett Lateral ................................................................................................................... 19

4.10.18 Tarac Lateral ..................................................................................................................... 20

4.10.19 Summary .......................................................................................................................... 20

4.11. Meter Station Project Work ..................................................................................................... 20

4.12. Compressor Station Project Work ........................................................................................... 21

4.13. Leak Detection ......................................................................................................................... 21

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5. Incident Reporting ................................................................................................................... 22

6. Land Management ................................................................................................................... 23

6.1. Land Owner Liaison .......................................................................................................... 23

6.2. Pipeline Safety Awareness ............................................................................................... 23

6.3. Pipeline Locations and Referral Services .......................................................................... 24

7. Environmental Management ................................................................................................... 24

7.1. Control Document and Training ....................................................................................... 24

7.2. Weed Control – African Rue ............................................................................................. 24

7.3. Soil Erosion and Subsidence Management ...................................................................... 25

7.4. Environmental Audits and Monitoring ............................................................................. 25

7.5. Cultural Heritage .............................................................................................................. 25

7.6. Assessment of Declared Environmental Objectives ......................................................... 26

8. Emergency Response ............................................................................................................... 26

9. Regulatory Compliance ............................................................................................................ 26

10. Risk Management .................................................................................................................... 27

11. Management System Audits .................................................................................................... 27

11.1. Health and Safety ............................................................................................................. 27

11.2. Management Audit .......................................................................................................... 28

12. Reports Issued during the Reporting Period ............................................................................ 28

13. Volume of Product Transported .............................................................................................. 29

14. Proposes Operational Activities for the next year ................................................................... 29

15. Statement of Expenditure ........................................................................................................ 29

16. Conclusion ................................................................................................................................ 29

17. Appendix A –SEO Assessment of Declared Objectives ............................................................ 30

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LIST OF ABBREVIATIONS

AFD Axial Flow Detection ALARP As Low As Reasonably Practical AS2832 Australian Standard 2832 Part 1 – Cathodic Protection – Pipelines and Cables 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 CS 1-7 Compressor Stations 1, 2, 3, 5, 6 & 7 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 GEA Gas Engine Alternator GPS Geographical Positioning System GUF Gas unaccounted for HAZOP Hazard Operability HELM Heritage, Environment and Land Management HSE Health, Safety and Environment ILI In Line Inspection KP Kilometre Point 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 PL1 Pipeline Licence 1 POMS Pipeline Operating Management System RCD Residual Current Device ROW Right of Way RTU Remote Terminal Unit SCADA Supervisory Control and Data Acquisition SEO Statement of Environmental Objectives SES State Emergency Services SMS Safety Management Systems SRB Sulphate Reducing Bacteria SWER Single Wire Earth Return TIPS Torrens Island Power Station 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 1 (PL1) and the

South Australian Petroleum and Geothermal Energy Regulations 2013.

2. Scope The Moomba to Adelaide natural gas transmission pipeline system (MAPS) is owned, operated and

maintained by Epic Energy South Australia Pty Ltd (EESA).

This report reviews the operations carried out during 2013 and the intended operations for 2014. In

accordance with the Petroleum and Geothermal Energy Regulations 2013 a performance assessment

is also provided with regards to the Statement of Environmental Objectives (SEO) PL1.

3. Technical Aspects Table 1 summarises the technical aspects of MAPS, while Table 2 summarises the technical aspects

of the laterals and looping systems on the mainline pipeline system. Figure 1 indicates the pipeline

location and layout.

Table 1 – MAPS Technical Data

Date Constructed 1967/1968

Date Commissioned 1969

Length 781 km

External Diameter 559mm

Wall Thickness

Normal

Special crossings (rivers, roads etc)

Bridge

MLV

7.92mm 9.50mm

11.86mm 9.50mm

Pipe Grade API 5L X52

MAOP

Moomba to KP543 (CS6)

Wasleys (KP731) to Torrens Island

7,322 Voluntary reduction to 6500kPa Voluntary reduction to 6100kPa

Coating Plicoflex Tape

Depth of Cover Nominal 750mm 1200mm at road, rail and creek crossings

Main Line Valves Cameron Ball valves (30 in total)

Actuators (remote activation) Shafer gas over oil valve actuators (13 in total)

Actuators (local activation) 17 Manual gear type operators

Fluid Natural Gas

Mainline Compressor and scraper stations 7 compressor stations installed on mainline (4 operational and 3 mothballed). Each site has two gas turbine powered

centrifugal compressor packages

Lateral Compressor stations 2 compressor units installed on the lateral pipeline located at Whyte Yarcowie and Wasleys

Meter Stations 27 in total (5 direct off main line)

Corrosion protection Impressed current and sacrificial anode CP system, 122 transformer rectifier units installed

Communications and SCADA Digital microwave link from Moomba to Adelaide with VHF radio coverage for voice communication; fully redundant

remote telemetry and control system for all major operable plant and equipment

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Table 2 - Laterals and Looping on Mainline

Item Main Pipeline loop sections

Wasleys to Adelaide loop

Peterborough Lateral

Port Pirie Lateral Burra Lateral Mintaro Lateral

Date Constructed 2000 1986 1972 1975-1976 1974 1984

Date Commissioned 2000 1986 1972 1976 1974 1984

Length (kms) CS1 5.2km CS2 10km CS3 13.3km CS4 6km Total – 34.4km

42 1.9 77.8 15 5.5

External Diameter (mm)

600 508 88.9 168.3 88.9 219.1

Fluid Natural Gas Natural Gas Natural Gas Natural Gas Natural Gas Natural Gas

Wall thickness (mm) Loops 1 to 3 – 7.14 Loop 4 – 8.74

9.0 4.78 4.37 4.78 4.77

Pipe Grade API 5L X65 API 5L X60 ASTM A53 Gr B ASTM A53 Gr B ASTM A53 Gr B API 5L X42

MAOP (kPa) Loops 1 to 3 – 7322 Loop 4 – 8740

7322 690 8240 7322 7322

Coating FBE FBE Armathene Pilcoflex PVC Yellow Jacket FBE

CP Sites 0 2 0 8 1 1

MLVs - 6 - 3 - -

Actuators (remote activation)

N/A 4 N/A - N/A N/A

Actuators (Local activation)

N/A 2 N/A N/A N/A N/A

Compressor Stations

- 1 (at Wasleys) - 1 (at Whyte Yarcowie)

- -

Meter Stations - 5 1 1 1 1

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Item Angaston Lateral Pelican Point Lateral

Amcor Lateral Osborne Lateral Dry Creek Lateral Taperoo Lateral

Date Constructed 1969 2000 2001 1998 1970-1971 1969

Date Commissioned 1969 2000 2002 1998 1971 1969

Length (kms) 38.7 River – 0.855km Land – 1.007km

114.3 River – 0.852 Land 1 – 1.31 Land 2 – 0.188

1.3 1.2


219 356 219 River – 273.1 Land 1 – 273.1 Land 2 – 219.1

323.9 323.9

Fluid Natural gas Natural Gas Natural Gas Natural gas Natural Gas Natural Gas

Wall thickness (mm) 4.78 7.1 4.00 and 4.78 River – 6.4 Land 1 – 9.2 Land 2 – 4.0

9.53 9.53

Pipe Grade API 5L X42 API 5L X42 API 5L X42 API 5L X42 API 5L X42 API 5L X42

MAOP (kPa) 7322 9600 9930 10000 2067 7322

Coating Pilcoflex PVC River – FBE plus powercrete Land – FBE

Yellow Jacket River – FBE concrete coated Land – Yellow jacket

Yellow Jacket Double wrap coal tar epoxy concrete coated

CP Sites 12 0 0 0 1 1

MLVs 1 - - - - -


- N/A N/A N/A N/A N/A


1 N/A N/A N/A N/A N/A

Compressor Stations

- - - - - -

Meter Stations 3 1 1 1 1 1

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Item Port Bonython Lateral

Whyalla Lateral Whyalla Lateral Loop

Nuriootpa Lateral

Quarantine Lateral

Tarac Lateral Hallett Lateral

Date Constructed 1988-1989 1988-1989 1988-1989 1972 2001 1972 2001

Date Commissioned

1989 1989 1989 1972 2002 1972 2001

Length (kms) 5.5 87.8 11.5 1.6 0.14 0.35 0.74


114.3 219.1 114.3 114.3 219 89 219

Fluid Natural Gas Natural Gas Natural Gas Natural Gas Natural Gas Natural Gas Natural Gas

Wall thickness (mm)

4.1 (to KP5.43) 4.8 (KP5.43 to Port Bonython)

4.3 4.3 4.78 8.2 4.78 8.2

Pipe Grade API 5L X42 API 5L X52 API 5L X52 ASTM A53 Gr B API 5L X42 ASTM A53 Gr B API 5L X42

MAOP (kPa) 7322 10130 10130 1379 7322 1379 7322

Coating Polyken 2 layer tape

Polyken 2 layer tape

Polyken 2 layer tape 25 mm concrete coating at crossings

Armathene Yellow Jacket Armahene Yellow Jacket

CP Sites 0 2 0 0 0 0 0

MLVs - 4 - - - - -


N/A - N/A N/A N/A N/A N/A


N/A 4 N/A N/A N/A N/A N/A

Compressor Stations

- - - - - - -

Meter Stations 1 2 - 1 1 - 1

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Figure 1 – Moomba to Adelaide Pipeline System

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4. Operational and Maintenance Activities

4.1. Risk Management Review

A five yearly SMS review for the MAP and laterals was last carried out in 2012 as per the

requirements of AS2885 (refer to EESA document number S-1-101-RAE-G-004).

This workshop review did not identify any significant threats that had not been identified in

previous workshops, nor did it identify any significant shortcomings in the controls required to

be applied in accordance with AS 2885.

4.2. Training

EESA continues to meet its contractual, operational and technical requirements in a safe and

competent manner by ensuring its employees and contractors have the relevant skill set to meet

the challenges of the gas transmission industry.

By maintaining and enhancing current levels of skills/knowledge of its personnel, while

identifying any skill set deficiencies and arranging suitable training to assist meeting those

requirements, EESA will ensure industry currency for itself and personnel under its jurisdiction.

In 2013 EESA has used several methods of training employees and contract labour. In-house

techniques such as self-paced modules, group presentations and one on one session’s. External

Registered Training Organisations and other organisations have provided a range of certified and

specialised external courses, lectures seminars and conferences.

The range of courses/training undertaken by EESA personnel and contract labour during 2013

include:

ACA Corrosion & Prevention Conference 2013

Accommodation Rules.

Alcohol & other Drugs

Apply First Aid

AS 2885.3 Pipelines Gas & Liquid Petroleum - O & M (in-house)

Australian Standards

Basic Fire Prevention & Control (Extinguishers)/Refresher (Phase 3)

Basic Fire Training

CGR Software Training (in-house)

Chainsaw - Basic Operations & Maintenance

Chemical Hazards

Chemical Use and You

Class C Drivers Licence Validity

Combustion Basics

Compressor Service Training Seminar

Confine Space

Confine Space with 'BA'

Confined Space Awareness (in-house)

Corrosion Control Introduction

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Dry Creek Induction On Line

EEHA

Elevated Work Platform WP

Engineering Workshop

Environmental Induction - On line

Epic Field introduction and Familiarisation (in-house)

Excavation of Pipelines (in-house)

Excel Introduction

Fire Aware & Extinguisher

First Aid in the field

Gas Safety

Gas Test Atmospheres 2013

GC700 (Rosemount) Basics & Overview.

Hazard And Incident Reporting

Heat Stress

Heat Stress - Santos (Epic SA & Qld)

High Risk License

HR Class Licence - Heavy Rigid 8t-9t

HR Truck TLIC3004A

HSR level 2

Human Resources Induction

Hydrocarbon Basic

Hydrocarbon Properties & Principles

Inductions Contract Personnel

Inductions Epic personnel

Isolation - SSOW

JHA - SSoW

Land Access Code & Cultural Heritage

Learning & Development Kiosk (in-house)

Liquids Line

LVR

LVR / CPR in the field

Manual Handling

Melbourne Office Induction

Mercury Awareness

Operate Vehicles in the Field

Operations Field Induction On Line

Permit to Work

Personnel Movement & Tracking

Pipe Location - General Epic Module

Pipeline Excavation

Pipeline Location

Pipeline Surveillance

Pipeline Voice Communications

Preventing Discrimination & Harassment

Purchase Requisition & Purchase Order (in-house)

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Review the Maintenance Standard - Basic Overview (in-house)

ROC Training

Rotating equipment sub-committee

Safety Video (in-house)

Santos - EHS Toolbox

Santos - Hazard Management using Stepback & JHA

Santos HR code of conduct

Santos ID

Santos Level 1 Induction - QLD and SA

Santos Level 2 - Moomba/Cooper Basin

Santos Port Bonython Induction - SA

Santos Rev 7.3 - Permit to Work

Snake Awareness 2013

Solar standalone CP supplies training

SSoW Isolation

SSoW JHA

SSoW Permit to Work

STTM Induction

STTM Management Systems

Taxation & Payroll Training

The Atmosphere & Working With Gases

Third Party Works

Valve Training

Vehicle Loading Crane (< 10 metre tonnes)

Voice Communications

Work Orders (in-house)

Working Alone in Remote Locations

Working at Heights

Working at Heights - Awareness

Working in Remote Locations

Workplace Drugs & Alcohol

Workplace Safety

Workzone Traffic Management

X-Info & GBM(gps) Training

4.3. Operations and Maintenance Activities

EESA operates and maintains the MAPS natural gas transmission pipeline and its associated

facilities in accordance with AS2885.3 and other relevant standards.

All Preventative, Corrective and Reactive maintenance can be identified in EESA’s CMMS.

Preventative maintenance is scheduled by this system which generates work orders for

maintenance staff to complete. Some of the key items in the maintenance schedule include:

Daily road patrols on the main line and the looped section of the line in the Adelaide metropolitan area from Two Wells to Torrens Island power station

Fortnightly road patrols from Wasleys to Torrens Island power station and the Angaston lateral

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Monthly road patrols from CS5 to Wasleys as well as the Whyte Yarcowie to Port Pirie, Whyalla, Port Bonython, Burra, Peterborough, and Hallet lateral pipelines.

Quarterly patrols of the mainline from Moomba to CS5

Monthly aerial patrols in the metropolitan area

Quarterly aerial patrols from Adelaide to CS4 including the loop line and the Whyte Yarcowie to Whyalla lateral

Two monthly CP system transformer rectifier unit inspections

Six monthly CP system full line surveys

DCVG 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 maintenance and checks

Quarterly, six monthly and annual compressor and meter station servicing covering:

pressure reduction regulators

relief valves,

isolation valves and their associated actuators,

Filter changes. (based on condition or 2 yearly)

SCADA system pressure, flow and temperature instrumentation calibration

un-interruptible power supply and battery maintenance

fire and natural gas detection equipment testing and calibration

Pressure vessel inspections (using suitably accredited external contractors) at all facilities associated with the Moomba to Adelaide natural gas pipeline system including the Dry Creek maintenance depot.

Compressor and meter station emergency shutdown system testing.

Calibration of all compressor station gas turbine or gas fueled reciprocating engine powered process compressor package control systems including testing of all safety shutdown devices

Compressor station power generation equipment engine control system calibrations and testing of all safety shutdowns

Routine electrical hazardous area equipment inspections and maintenance.

Routine electrical appliance and equipment testing with timings as per the relevant Australian standards

Routine hours based compressor station GEA servicing

Routine hours based compressor station process compressor package maintenance.

Annual communications system mast maintenance.

Annual communications system un-interruptible power supply and battery maintenance

Annual communications system VHF and microwave bearer checks and tests

Routine meter station custody transfer equipment AVT calibrations and checks with frequencies determined by the relevant contracts.

A description of the Operations and Maintenance activities for 2013 is provided below.

4.4. Pipeline Patrol Activities

All road and aerial patrols scheduled by the CMMS were completed in 2013. The road and aerial

patrols ensure that the following pipeline activities are addressed:

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Signage is clearly visible, in suitable condition and maintaining pipeline line of sight. Any issues not addressed during the patrol are fed back into the CMMS and repairs are affected as soon as is practically possible.

there are no unauthorised activities occurring along the pipeline route or at any of the facilities

restoration of any soil erosion due to wind and water is reported, scheduled and 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 all of the facilities associated with the pipeline system.

During the 2013 surveillance activities, no areas of erosion affecting pipeline depth of cover

were identified.

Six unauthorised third party activities within the pipeline easement were detected by patrolling officers during routine surveillance in 2013. Refer to Section 5: Incident Reporting for further detail.

4.5. Pipeline Integrity

EESA continued its pipeline dig up program in 2013 based on the most recent in-line inspection

(ILI) surveys conducted in 2010-11. At the end of 2012, all defects reported by ILI to have a wall

thickness loss of >55% and/or an ‘estimated repair factor’ of ≥0.99 had been inspected and

refurbished.

A further 20 locations were inspected in 2013, selected on the basis of preliminary corrosion

growth rate estimate work carried out for EESA by corrosion specialists. The spread of dig up

locations was as follows:

CS1 – CS2: 7

CS2 – CS3: 2

CS3 – CS4: 9

CS4 – CS5: 1

CS5 – CS6: 1

The corrosion defects at three locations were significant enough to require reinforcement with a

composite wrap repair method. The remaining sites were recoated only, giving a total of

approximately 175 m of refurbished pipeline.

The actual defect dimensions measured in the field demonstrated that the preliminary corrosion

growth rate estimates were conservative (17 of 20 defects had grown less than predicted).

Annual dig ups will be continued as a validation of the corrosion growth rate estimates until data

from the next ILI runs can be used to refine the corrosion growth rate estimates and allow a

reforecasting of future dig up programs.

Coating surveys were carried out in 2013 for Beverley, Whyalla, Port Bonython, Burra,

Nuriootpa, Tarac and Angaston laterals. No defects of concern were identified.

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No further works were carried out on the MAPS compressor station tees reinforcement

program. Whilst the station inlet and outlet tees at CS6 and CS7 were repaired in 2012, the

need to restore the tees from the current voluntary maximum operating pressure of 6,500 kPa

to the design MAOP of 7,322 kPa is under review. The decision to return the pipeline south of

CS6 to 7,322 kPa was made in mid 2013 following discussion with DMITRE.

4.6. Electrical and Instrumentation Maintenance Activities

Routine mainline valve, meter and compressor station pressure and temperature transmitter

calibrations were completed at all pipeline facilities verifying that the inputs to the SCADA

system were within the specified tolerances for the installed devices, thus ensuring that the

control of the natural gas transportation process was within the design parameters at all times.

Routine meter and compressor station emergency and safety shutdown checks were conducted

as per the maintenance schedule to ensure these functions are operational and fit for purpose.

Generally these systems are failsafe, and any malfunctions trigger the shutdowns. Testing

ensures the mechanical devices that perform the valve closures and other functions are

operational. Maintaining these systems as part of a regular testing regime guarantees their

operation in the event of an emergency.

Routine process compressor package control system instrumentation and emergency shutdown checks were carried out, verifying that the machinery control stays within the original equipment manufacturers design parameters at all times, and that the information supplied to the pipeline SCADA system is accurate and within the measuring devices tolerance range.

All process compressor emergency shutdown functions were tested to ensure that in the event they are needed to operate, the correct action occurs and the machinery is brought to a safe condition as per the original equipment manufacturers design.

Routine meter and compressor station fire and gas detection equipment maintenance and tests were conducted to meet statutory requirements and allow the identification and rectification of faulty components ensuring the system operates correctly.

Routine maintenance of the power generation equipment and distribution system, including the testing and calibration of instruments associated with this equipment, were completed as per the maintenance schedule to ensure a reliable supply of AC power at compressor stations.

Generation of AC power at remote compressor stations is a requirement in the process of transporting natural gas through the pipeline system, the availability requirement of power generation is 100% hence it is of key concern to the maintenance effort.

Routine maintenance of the uninterruptible power supply system has been completed to ensure that compressor and meter station batteries, and their associated chargers, are in a serviceable condition. Battery cells are assessed annually, with a charge and discharge regime, identifying remaining service life to prevent unexpected failures.

Programmed routine maintenance of SWER and HT reticulation systems was completed to

ensure operability and reliability. Maintenance includes the inspection of pole top insulators,

high and low voltage earthing grids, pole footings, removal, cleaning and greasing of all line taps

and take offs etc

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All meter and compressor station site electrical equipment was routinely inspected and maintained in accordance with Australian Standards to ensure any defective items are identified and reported via the CMMS and repaired in a timely manner.

A meter at the One Steel facility in Whyalla was replaced with a rotatable spare due to a failure occurring in the gas pickup. This failure did not result in any supply or integrity issues.

A flow computer upgrade was completed at Angaston in Q4 of 2013 as part of EESA’s ongoing replacement strategy of ageing equipment.

Meter station process gas custody transfer metering equipment is tested and calibrated as per the contracts between EESA and their customers. All AVTs were completed during 2013 with no significant anomalies being identified.

Electrical faults and a fire & gas alarm fault resulted in four compressor station ESDs during 2013, all issues were addressed with only minor delays in unit and station operability and no restriction to supply.

A regulator had to be removed from service at Quarantine meter station for a short period due to an internal component failing. The regulator was repaired and returned to service without issue.

Some issues were encountered at Wasleys meter station with the gas chromatograph during Q3 of 2013. An external resource was engaged to assist with refurbishment of internal components. The unit was repaired and returned to service without issue.

A wiring fault on the flow computer at Gepps Cross meter station was identified during the course of 2013. This fault caused data corruption associated with flows at Gepps Cross meter station. As a result a different design concept was researched for the termination point at the flow computer and implemented in Q4 2013.

4.7. Communications

All pipeline facilities control and monitoring functions are communicated to the central control system located at Dry Creek via a microwave link that runs parallel to the buried pipeline system from Moomba to Peterborough and then via the Telstra Next G system network.

In addition to the microwave equipment, a VHF radio link to allow voice communications between staff and the control centre is also supported by the communications system.

The communications link is essential for the safe monitoring and control of the pipeline and the following range of maintenance activities were carried out to ensure the system provides a high level of availability and reliability:

Three and six monthly maintenance tasks associated with the communications system uninterruptible power supply batteries and their associated charging system.

Three monthly radio shack electrical equipment and appliance maintenance.

Six monthly routine air conditioning equipment maintenance.

Twelve monthly Microwave bearer and VHF communications system maintenance.

4.8. Mechanical Maintenance Activities

Routine mainline valve and scraper station maintenance was completed, including valve sealing

integrity checks, stem and ball seal greasing, valve operational checks and valve actuator

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serviceability checks. Scraper trap door seals were inspected and traps were assessed for

leakage.

All pipeline, meter station and compressor station routine pressure regulator and over pressure

protection devices were tested in accordance with the relevant Australian Standard and the

Preventative Maintenance schedule.

All compressor station power generation equipment is serviced at 1000 hourly intervals to

ensure high reliability and availability levels, achieving original equipment supplier

recommended major overhauls timeframes without any premature failures being experienced.

All compressor station process compressor package equipment has varying service requirement

levels, dependent upon operating hours. Typically filter changes and package walk-around type

inspections occur at 1000 hour intervals with major strip downs inspections occurring at 4000

hour intervals. Service intervals at these levels ensure maximum availability and reliability levels

are achieved. All scheduled servicing for the process compressor package equipment occurred

within the specified timeframes during 2013.

In 2013 the following material maintenance tasks were completed at compressor stations:

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.

Routine and on condition meter and compressor station process gas filter changes were

completed as required.

Minor mechanical maintenance tasks identified during routine site work along the

pipeline are prioritized, entered into the CMMS with work orders issued for the

rectification of these faults.

Varying levels of sulphur deposition were found throughout 2013 at some of the

metropolitan meter stations. All components affected were removed, cleaned and re

instated or replaced with rotatable spares.

The buffer air seals were replaced in the Solar Taurus 60 units at compressor stations 1

and 3. This was due to excessive bypass over the buffer air seals.

In addition to the breakdown faults and routine activities above, maintenance staff have

investigated and solved numerous corrective maintenance issues identified as a result of the

routine activities that arise during day to day operation of the pipeline system. These issues are

considered minor in nature and as a result pose no problem to daily operation and supply.

4.9. Pigging

A cleaning pig was run in the Angaston lateral during 2013. No issues were identified as a result

of this.

4.10. Cathodic Protection

Routine maintenance was carried out on the MAPS CP system in 2013 in accordance with the

EESA maintenance plan and the requirements of AS2832.1, including six monthly full line

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potential surveys and two monthly operational checks. EESA has four full-time rostered CP

technicians to maintain and improve the CP system.

Results of system performance are summarised below.

4.10.1. MAP Mainline

CP pipe to soil ON/OFF potential surveys for the MAP mainline from Moomba to Torrens

Island were carried out during February and August 2013.

Results show that there are some locations that require attention to maintain OFF potentials

that are compliant with AS2832.1.

Significant work was done in 2013 with installation of TRs, replacement of ground beds as

well as remediation of solar sites for improving protection levels on the MAP. Other works

carried out in 2013 are discussed further in section 4.3.3.19, and further investigations will

be carried out in 2014 to determine the most effective way to manage the CP system.

4.10.2. Wasleys Loop Line

ON/OFF potential surveys for the Wasleys Loop were carried out during March and August

2013. Survey results indicates that the pipeline is satisfactory protected.

4.10.3. MAP Compressor Station Loop

ON potential surveys only are possible on the loop pipelines because they are protected by

magnesium anodes. A survey was conducted during in February and August 2013, indicating

satisfactory protection levels on the CS1, CS2, CS3 and CS4 loops.

4.10.4. Peterborough Lateral

ON potential survey for the Peterborough Lateral was carried out in February 2013 and

August 2013. Survey results indicate that the pipeline is satisfactorily protected.

4.10.5. Port Pirie Lateral

The September 2011 CP survey reported low protection levels in the Port Pirie pipeline. The

battery bank at KP 31.4 (Caltowie) was replaced, which in addition to ongoing upgrades and

tuning has improved protection levels as per surveys completed in February and August

2013.

4.10.6. Burra lateral

ON/OFF potential surveys for the Burra Lateral were carried out in February and August

2013, showing appropriate protection levels.

4.10.7. Mintaro Lateral

ON potential surveys conducted during February and August 2013 indicated that the

pipeline is satisfactorily protected.

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4.10.8. Angaston Lateral

ON/OFF potential surveys for the Angaston Lateral were carried out in February and August

2013. Apart from some minor issues with capability to adjust outputs on some TRs (which

have been resolved) protection levels were found as appropriate.

4.10.9. Pelican Point Lateral

ON potential surveys was carried out in February and August 2013. These surveys indicated

that the pipeline is satisfactorily protected.

4.10.10. Osborne Lateral

ON potential surveys were carried out in February and August 2013. These surveys

indicated that the pipeline is satisfactorily protected.

4.10.11. Dry Creek Lateral

ON/OFF potential surveys were carried out in February and August 2013. These surveys


4.10.12. Taperoo Lateral



4.10.13. Port Bonython Lateral


indicated that pipeline is satisfactorily protected.

4.10.14. Whyalla Lateral

ON/OFF potential surveys were carried out in February and August 2013, including the gulf

section. These surveys indicated that pipeline is satisfactorily protected.

4.10.15. Nuriootpa Lateral



4.10.16. Quarantine Lateral



4.10.17. Hallett Lateral



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4.10.18. Tarac Lateral



4.10.19. Summary

Ongoing corrective maintenance and system tuning contributed to an increase in CP

reliability and compliance with the AS2832.1 ‘-850 mV criterion’ from 70% at the end of

2012 to 75.5% at the end of 2013. In addition to routine maintenance, several other key CP

activities were undertaken in 2013:

A ‘natural potential’ survey was undertaken on the MAP main line and the Pt Pirie Lateral. This survey is an alternative CP assessment criterion under AS2832.1 which can be used where it is difficult or costly to achieve the more common -850 mV potential method. The ‘100mV criterion’ is measured by interrupting the protective current on an impressed current system. When the current is interrupted, an “instant off” potential is recorded and the structure under CP is then allowed to depolarize until a change of at least 100 mV in potential is observed. As detailed in a separate EESA report (document number S-1-101-TR-P-012),100% of test posts assessed reported a minimum 100 mV shift, indicating full compliance with AS 2832.1. Approximately 12% of test posts were not tested due to potential interference from foreign structures. Interference testing is to be carried out to extend this survey in 2014.

An external audit was carried out on the MAP CP system to provide a health check and inform future investment requirements

A close interval survey was carried out on the MAP between Moomba and CS4 to provide a high resolution survey of actual pipeline protection levels and therefore better data on which to base future system modifications.

On the basis of the various CP works carried out in 2013, several system upgrades will be

completed in 2014, including installation of new CP ground beds, modification of station

earthing systems to avoid interference, further validation of natural potential surveys and

upgrades to SWER and GEA power supplies.

4.11. Meter Station Project Work

Notable works carried out at MAPS meter stations during 2013 includes:

A new gas chromatograph was installed at Pelican Point meter station to address

reliability issues with the previous equipment that was installed in 2000.

The gas chromatograph at the Gepps Cross and Dry Creek meter station was relocated

to outside the control room to improve hazardous area compliance.

Other continuous improvement works carried out on electrical equipment in hazardous

areas included replacing electric valve actuators at Torrens Island meter station, and

updating site drawings.

The existing flow computer at Mintaro meter station was upgraded as part of an ongoing

program to phase out units that have reached the end of their manufacturer’s

supported life. A flow computer for Torrens Island meter station was also built and

delivered to the Dry Creek depot for programming and installation in the first half of

2014.

Replacement meters were installed at Osborne and Whyalla meter stations.

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The earthing and lightning protection system at Angaston meter station was also

upgraded, with new zinc earth electrodes and an extensive system of buried cabling

installed to ensure the earthing system, including step and touch protection, meets

relevant Australian standards. Zinc earth electrodes were chosen to ensure maximum

compatibility with the site CP system.

Following a 2012 audit of meter station distribution boards, various improvement works

were carried out at almost all meter stations to ensure they meet with current

standards. Outstanding minor issues at four sites will be addressed in 2014.

A new flow computer, distribution board and UPS were installed at Burra meter station

after equipment damage from a power surge incident (either lightning or grid-related).

4.12. Compressor Station Project Work

Notable works carried out at MAPS compressor stations during 2013 includes the following:

Following a third party audit of hazard area compliance at CS6 a list of hazardous area

equipment replacement was developed and procured. A work schedule has been

developed for equipment installation in 2014. Completion of the recommended works at

CS6 will then create a benchmark by which all other MAPS compressor stations will be

assessed and addressed if required.

EESA also continued at CS1, CS2 and CS3 in 2013 with the rolling upgrade and

replacement program of the gas powered power generation equipment. At CS1, CS2

and CS3 new control systems were fitted to the existing GEA units to provide enhanced

reliability and inter-unit operability. At CS1, a new GEA was installed.

A review of MAPS compressor stations fire and gas systems was completed in 2013.

Resultant actions were the installation new ethernet cards and consolidation of the PLC

software to ensure consistency across all sites for consistency of maintenance and to

allow remote access for fault finding activities.

The lead acid batteries installed at CS4 and CS6 were replaced with gel type units to

reduce maintenance requirements and the risk of potential hazardous gas release.

All insulators on the SWER line south of CS1 from KP 67.8 to KP 116.6 were replaced

with an enhanced material type to improve resistance against lightning induced damage.

An AC mitigation earthing system was installed on the MAP near Hallett due to a new

high voltage cable crossing at The Bluff wind farm.

4.13. Leak Detection

EESA monitors and operates all of its pipeline assets using a Telvent OASyS DNA 7.4 SCADA

system from the Dry Creek control room.

The SCADA system has leak detection functionality that is configured to monitor the flows in and

out of the system, line-pack inventory, gas quality and pressure and temperature change rates.

Alarms identify the pipeline section with the anomalous readings, allowing the pipeline

controller to investigate further and take actions as appropriate. If required, sections of the

pipeline can be isolated by activation of remotely controlled main line valves on the MAP and

Wasleys Loop, or by mobilizing on-call field staff to close other manually operated isolation

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valves. Isolation valves are routinely tested to ensure operability. The remotely operable valves

include those at compressor stations and MLVs in the more built up areas south of CS7.

These ‘leak alarms’ are augmented by maintenance activities along the pipeline which include

regular patrols and inspections for the identification of leaks.

In addition to the field maintenance activities, control room staff also perform daily gas

balancing of all accountable gas sources and has a procedure to follow if Gas Unaccounted For

(GUF) falls outside accepted limits.

There were no pipeline leaks for the MAPS in 2013.

5. Incident Reporting During 2013 there were seven reportable incidents on PL1. Reportable incidents are prescribed

pursuant to Regulation 32 of the Petroleum and Geothermal Energy Act 2013.

All incidents have been investigated to identify the root cause and possible improvement

opportunities to EESA’s procedures and work instructions. All actions that are raised as a result of

the investigation are tracked through CGR to ensure their timely completion before the incident is

considered to be closed.

A summary of the incidents raised during 2013 are provided in Table 3.

Table 3 – Reportable Incidents for 2013

Description of Incident Root Cause Preventative Measures

Easement Encroachment On 21 March 2013 a post hole had been dug within the easement and approximately 1.5m from the Angaston Lateral Pipeline.

EESA’s Field Maintenance Officer (FMO) not following the updated Dial Before You Dig procedure

Provided additional training to all FMO’s

Easement Encroachment On 26 March 2013 excavation works had been undertaken within the MAP easement on Short Road, Penfield. The pipeline was not exposed or impacted.

DPTI electrical contractor did not follow EESA directions.

EESA staff met with DPTI staff to reinforce the correct protocol when undertaking works near our pipelines.

Easement Encroachment On 8 May 2013 excavation works had been undertaken within the MAP easement on McGee Road, Penfield Gardens. The pipeline was not exposed or impacted.

Landowner had previously followed correct process for similar activity and did not believe necessary to do the same in this instance as he thought he knew what was required.

EESA officers met with land owner to remind them of the risks presented when working near our pipeline and the appropriate notification requirements.

Easement Encroachment On 21 May 2013 excavation works had been undertaken within the easement and approximately 2.2m from the Angaston Lateral. A temporary barrier had also been erected.

Landowner excavated without EESA’s consent or supervision when he was unable to contact the appropriate EESA officer.

EESA officers met with land owner to remind them of the risks presented when working near our pipeline and the appropriate notification requirements. EESA also installed a Danger sign at the location of the encroachment where the pipeline crosses an unsealed road.

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Easement Encroachment On 22 July 2013 during our routine patrol our FMO observed several fence posts had been installed on the MAP easement adjacent to the Penfield Road Meter Station.

Electrical contractor did not contact EESA or submit a DBYD

EESA officers met with land owner to remind them of the risks presented when working near our pipeline and the appropriate notification requirements.

Pipeline Encroachment On 18 July 2013 during our routine patrol our FMO observed three post holes had been excavated 4.5m from the MAP

Landowner engaged contractor who excavated without EESA’s consent or supervision. Land owner had limited understanding of English

EESA installed flagging across the width of the easement and arranged to be on site during fence installation. EESA to amend Pipeline Awarensss documentation to suit non English speaking land owners

Pipeline Encroachment On 15 October 2013 during our routine patrol our FMO observed 4 bollards had been installed on the pipeline easement approx 2m from MAP

Occupier of land (who is not the landowner) engaged contractor who did not contact EESA or submit a DBYD. No mailing address for land occupier, only land owner.

EESA officers met with land occupier to remind them of the risks presented when working near our pipeline and the appropriate notification requirements. EESA updated contact details in mail list database.

6. Land Management

6.1. Land Owner Liaison

There are approximately 580 landholders along the Moomba to Adelaide Pipeline system.

During 2013 EESA visited all properties (or other nominated contact addresses), completing a

questionnaire during the visit, confirming contact details, current and proposed land use,

awareness of the pipeline location and reminding landowners of their responsibilities with

respect to working in the pipeline vicinity. Where landholders were not available to be seen in

person, the questionnaire was completed via telephone.

As part of EESA’s pipeline awareness program, all landowners were also contacted via mail on

two occasions, with a letter sent in June 2013 emphasising the importance of using the DBYD

system and an EESA 2014 calendar containing information on pipeline safety and their

responsibilities sent in December 2013.

6.2. Pipeline Safety Awareness

EESA conducts a Community Awareness Program, which entails holding awareness meetings

with communities, councils, government departments, utilities, emergency services and

contractors along the pipeline route. Sixty four (64) of these meeting were held with services in

close proximity or associated directly with the Moomba to Adelaide Pipeline system.

The presentations focused on the general properties of the high pressure gas transported, the

process of gas transmission by pipeline, location of the high pressure gas pipeline in the regions

concerned, correct procedures when working within pipeline easements, pipeline threats and

dealing with emergency situations. (Note: This presentation is tailored to the specific audience

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and where appropriate EESA will discuss the difference between Liquids Hydrocarbon and

natural gas transportation as both pipeline systems exist in a number of areas within South

Australia).

6.3. Pipeline Locations and Referral Services

EESA continues to provide a free service to locate any pipeline that they own or operate on

behalf of third parties. Historically this service was primarily used by companies and third

parties carrying out civil works in the vicinity of the pipelines, with contact made via either direct

telephone to EESA or via the free call 1100 “Dial Before You Dig” (DBYD) asset referral service.

In 2013 EESA made a concerted effort to encourage all landowners to use the free DBYD service

as it provides more traceability and consistency in response.

During 2013 EESA updated its Dial Before You Dig Procedure to further improve the service.

Updates included adding a ‘Supervision Decision Matrix’ to ensure appropriate supervision, as

described in AS2885.3, is provided in all circumstances, a ‘Standard Conditions Form’ that we ask

be signed by all parties before works commence, and a returnable ‘Work Instruction’ completed

by EESA personnel on site acknowledging all procedural steps have been completed.

During 2013 EESA received 591 enquiries DBYD enquiries in relation to third party activity in the

vicinity of the Moomba to Adelaide Pipeline system.

7. Environmental Management

7.1. Control Document and Training

Environmental procedures and work instructions continue to be regularly reviewed and

updated.

In 2013 EESA updated its Environmental and Land Access Policy to bring in line with the

Australian Standard ISO14001:2004 Environmental management systems – Requirements with

guidance for use.

The online environmental training module was completed by all employees and contractors

entering the field on behalf of EESA. This induction provides an overview of environmental

risks, control measures and responsibilities.

7.2. Weed Control – African Rue

EESA has an African Rue Management Plan in place that has been implemented following

review by the South Australia Arid Lands Natural Resource Management Board.

The plan includes:

Restriction of vehicle and machinery access into infested areas;

Vehicle hygiene procedures implemented where access to infested areas is unavoidable;

Signage to allow for easy identification of infested areas;

A herbicide spray program along the easement conduced annually; and

Monitoring weed distribution.

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The management plan has proven effective in controlling populations and preventing the

spread of African Rue along the pipeline easement.

7.3. Soil Erosion and Subsidence Management

Erosion in Virginia at KP 757 on the Wasleys to Adelaide Loop Pipeline was detected during a

vehicle patrol. The erosion has been caused by rain runoff from glasshouses adjacent to the

easement. EESA has requested that the landowner modify the guttering and down pipes to

prevent erosion. Remediation works are planned for February 2014.

No subsidence was reported in 2013.

7.4. Environmental Audits and Monitoring

The 2013 Moomba to Adelaide Pipeline Repair Program was carried out during May 2013.

Following completion of the repair program, an audit was conducted on compliance with

environmental requirements of EESA’s Excavation Procedure. Excavation checklists and

photograph records completed during the repair program, demonstrate compliance with the

procedure.

Of the 20 pipeline repair locations, 10 were selected as a representative sample to be included in

EESA’s Environmental Monitoring Program, whereby they will be monitored annually for

vegetation cover and erosion for at least five years, or until such time as they are deemed to

resemble the surrounding landscape.

An initial inspection of the 10 sites was conducted between July 1st and July 5th 2013. A

photograph record is maintained in EESA’s Environmental Monitoring Report.

7.5. Cultural Heritage

In 2013 EESA reviewed and updated its Aboriginal Cultural Heritage Management Procedure

and Work Instruction.

During the reporting period, cultural heritage surveys were conducted on the MAP at nine

proposed anode bed sites. The surveys were conducted by Australian Heritage Services in

conjunction with the relevant Indigenous cultural heritage organisation. All sites received

cultural heritage clearance, some with conditions attached (refer Table X).

Table 4 – Cultural Heritage Surveys 2013

Location Results and Recommendations

KP102.5 Cultural Heritage Clearance granted. No cultural issues.

KP178.5 Cultural Heritage Clearance granted.

KP218.7 Cultural Heritage Clearance granted.

KP255.9 Cultural Heritage Clearance granted but exclusion zone immediately north of the new anode bed due to cultural site in low sand dune.

KP280 Cultural Heritage Clearance granted on revised start and end points for new anode bed, to avoid cultural heritage sites. Exclusion zone around one site.

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KP439.5 Cultural Heritage Clearance granted. Exclusion zone around a number of cultural heritage sites. Monitoring required during construction.

KP542.9 Cultural Heritage Clearance granted. No cultural issues.

KP570 Cultural Heritage Clearance granted. Monitoring required during construction due to possibility of buried cultural material.

KP587.2 Cultural Heritage Clearance granted. Monitoring required during construction due to possibility of buried cultural material.

7.6. Assessment of Declared Environmental Objectives

Appendix A contains the “Assessment of Declared Environmental Objectives” completed for the

Moomba – Adelaide Pipeline system.

8. Emergency Response The Petroleum and Geothermal Energy Regulations require that an Emergency Response Exercise is

to be conducted on the MAP once every two years, and that a set of Emergency Response

procedures is to be developed and maintained. These procedures are detailed in EESA’s Incident

Management Plan.

EESA is committed to providing a timely and effective response to any emergency situation affecting

its people, community, environment, assets or business processes. EESA has developed an Incident

Management Plan to ensure that any emergency situation is properly responded to, managed and

controlled. The plan also provides for regular emergency exercises to test and review its adequacy.

Although EESA undertook a joint desktop emergency response exercise with South East Australia

Gas Pty Ltd (SEAGas) in 2012, EESA conducted two desktop exercises in 2013 to maximize the

availability of key personnel in the field and within the Incident Management Team. Slight variations

were made to the scenario for each exercise to ensure that the staff were able to adapt to sudden

and unexpected change.

9. Regulatory Compliance EESA ensures that design, manufacture, construction, operation and maintenance and testing of all

appropriate facilities is carried out in accordance with the relevant Acts of Parliament, licence

conditions and AS2885 requirements.

EESA attends quarterly meetings with DMITRE, where operational regulatory compliance is

discussed in an open manner.

EESA manages legislative changes through SAI Global, an organisation which monitors, tracks and

advises EESA of legislative changes that could affect the operation of the pipeline.

EESA is not aware of any regulatory non compliance for this pipeline, and believe it is fulfilling its

obligations in relation to the following requirements:

Petroleum and Geothermal Energy Act 2000;

Petroleum and Geothermal Energy Regulations 2013;

Pipeline Licence 1 (PL1); and

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The Statement of Environmental Objectives (SEO) for PL1

Significant items are reported through to DMITRE and are raised at quarterly compliance meetings

held between DMITRE and EESA.

There have not been any significant regulatory compliance issues during this reporting period.

10. Risk Management

EESA has established a complete Safety Management System throughout 2013 that meets all

obligations under the harmonised WHS legislation and AS2885:2012; and is aligned to AS4801 –

Occupational Health and Safety Management Systems.

The WHS Safety Management System consists of an overarching Safety Management Plan, Policies,

Guidelines, Procedures and Work Instructions; and has been implemented across all elements of the

business.

EESA utilise an online Risk Management database known as Corporate Governance Risk (CGR). CGR

is a web-based risk management platform that performs the following key functions:

Risks, which incorporates HAZID style workshop outcomes, eg risks, causes, controls,

consequences and risk rankings;

Learnings, which captures HSE and operational lessons learnt, including related actions;

Actions, which tracks actions from risk workshops, incident reporting, inspections/audits and

meetings;

Incidents, which records information on incidents in the areas of clinical health, injury,

environment, asset, reputation, security, legal and financial; and

Audits, which allow audits and other checklists to be created and generated.

Recommendations arising from the checklists can be elevated to actions and transferred to the

action component.

11. Management System Audits

11.1. Health and Safety

WHS audits are undertaken by EESA to provide assurance and to assess the effectiveness of WHS

management practices to determine if they are effective for ongoing and future management of

significant risks in line with best industry practice and company policies. Audits also identify

opportunities for WHS continuous improvement.

WHS audits are important to provide a health check on all WHS governance activities and to

provide confidence that WHS risks are being managed to levels that are As Low As Reasonably

Practicable (ALARP). These audit and assurance activities are also conducted to provide due

diligence WHS reporting data to the officers of EESA to assist them in discharging their WHS due

diligence requirements under the WHS Act (SA) 2012.

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A schedule of audits was developed in order to ensure adequate planning and preparation with

a combination of internal and external audits conducted.

In addition to these systems audits, EESA have established, as part of its Tasks and Targets for

Supervisors and Managers, tools to conduct field based quality assurance inspections to ensure

that the system is being appropriately utilised in the field.

Audits undertaken during 2013 are listed below:

WHS and Assurance

Incident Management

Fitness for work including fatigue, Alcohol and Other Drug & physical and psychological

impairment

DIMTRE Self Assessment audit alignment to AS4801

43 field based safe systems of work observations / audits

Crisis and Emergency Management

Journey Management

Hazardous Substances and Dangerous Goods

11.2. Management Audits

EESA completed a number of management audits during 2013. These were a combination of

EESA’s internal audit program and external audits by industry experts initiated by EESA.

The following topics were subject to audit during 2013:

Aviation Audits;

Compliance with National Greenhouse and Energy Reporting Scheme (NGERS);

Short Term Trading Market (STTM) Compliance;

SWER Maintenance Plan;

Policies and Procedures Audit; and

AS2885 Gap Analysis

The auditing program offers the opportunity to identify and promote continual improvement

within EESA and completion of these audits is recognised as a key performance indicator by

management and the Board.

12. Reports Issued during the Reporting Period The following reports were issued for PL1 during 2013:

2012 MAPS PL1 Annual Report;

2013 MAPS Fitness for Purpose Report

2013 Dig Up Reports (20) CS1-CS6;

MAPS Integrity Management Plan;

MAPS Integrity Management Statement;

2012 MAPS and Laterals Review of AS2885 SMS Report;

Risk Assessment Workshop for CS6 and CS7 Scraper Station Tee Rectification Report;

SCT Rail yard Development SMS Review;

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Installation Report Bluff Wind farm Earthing;

HV Reticulation and Transmission System Safety, Reliability, Maintenance and Technical

Management Plan Audit Report;

MAP Remaining Life Review;

MAPS Gas Pipeline Dig Up Analysis 2013;

MAPS Simulation Verification;

MAP Cathodic Protection Assessment Report; and

Corrosion Growth Assessment Work Conducted on MAPS Preliminary Findings Report

Archaeological survey of five locations intended for pipeline corrosion mitigation works,

Moomba to Adelaide Gas Pipeline, Flinders Ranges, northern South Australia, April 2013

Work Area Clearance of a proposed Anode Ground Bed location on the Moomba to Adelaide

Gas Pipeline, Strzelecki Desert, South Australia, July 2013

13. Volume of Product Transported Approximately 44,607 TJ of product was transported through the MAPS in 2013

14. Proposes Operational Activities for the next year During 2014 the following activities are proposed for the MAPS:

Completion of all scheduled routine maintenance activities and corrective maintenance identified.

CP ground bed and transformer rectifier replacement program.

Continuation of the MAP mainline refurbishment program.

An intelligent pigging run for the MAP mainline and Wasleys Loop

Further assessment of MAP corrosion growth rate estimates

Further close interval surveys for selected MAPS laterals CP systems

Selected dig ups for MAPS laterals on a risk based selection criterion

Selected pipework painting works, including Freeling meter station, MLV24 and CS5

Whyte Yarcowie compressor engine overhaul.

Further investigation of the MAPS compressor station tee rectification requirements.

15. Statement of Expenditure Information relating to expenditure in relation to the regulated activities of the pipeline is provided

as “Commercial in Confidence” in accordance with sub regulation 33(9) of the Petroleum and

Geothermal Energy Regulations 2013, where public disclosure is not required in accordance with sub

regulation 33(4).

16. Conclusion The Maintenance and inspection program carried out on the MAPS during 2013 confirms the

pipeline is in sound condition and is capable of operating safely within the current operating

parameters.

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Appendix A

SEO Assessment of Declared Objectives

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ASSESSMENT OF DECLARED OBJECTIVES

Objectives and Assessment Criteria

Assessment criteria have been developed to be “black and white”. Professional judgement is required to assess whether non-compliance is minor or major.

It is necessary to ensure that adequate information is available to enable this judgement to be made.

OBJECTIVE GOAL MEASURE/HOW OBJECTIVE ACHIEVED OBJECTIVE ACHIEVED

YES/NO

SUPPORTING COMMENTS

1. To avoid unnecessary disturbance to 3

rd party

infrastructure, landholders or land use

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

Incident report.

Records of communications with adjacent landholders / 3rd party prior to and during maintenance work.

Landholder contact records database.

Photo points or inspection reports, specifically to look at: removal of waste products, re-instatement of soil profiles, adequate re-contouring of surface profile, return of land use.

Where disturbance is unavoidable or accidental, infrastructure or land use is restored to the satisfaction of the landholder or to undisturbed condition.

Duration of disturbance does not exceed agreed timeframe.

No reasonable landholder complaints.

Yes There have been no incidents or negative communications with landholders / third parties during 2013.

Environmental Monitoring Report indicates correct reinstatement of soil profiles and re-contouring following pipeline repair program.

1.2 To minimize disturbance to landholders

Records of communications with adjacent landholders / 3rd party prior to and during maintenance work.

Landholder contact records database.

Landholder activities not restricted as a result of pipeline activities.

Completed land disturbance checklist.

No reasonable landholder complaints.

Landholder activities not restricted or disturbed as a result of pipeline activities unless by prior arrangement.

Yes No complaints were received from landholders during 2013.

Excavation checklists were completed for all pipeline repairs, demonstrating compliance with the environmental requirements of EESA’s Excavation Procedure.

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YES/NO

SUPPORTING COMMENTS

2. To maintain soil stability / integrity

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

Timed photo points or annual land survey, specifically to look at evidence of erosion, subsidence, vegetation loss on easement & compare to adjacent land.

Inspections undertaken as part of regular patrols, following specific works, following significant storm events.

Preventative measures implemented and monitored in susceptible areas.

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

Yes Regular vehicle and helicopter patrols are conducted to identify anomalies on the easement.

No erosion was reported or repaired in 2013.

2.2 To prevent soil inversion

Annual land survey to look for soil discoloration, 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.

Vegetation cover is consistent with surrounding land.

No evidence of subsoil on surface (colour).

Landholder signoff.

Yes Land surveys did not identify areas of soil inversion restricting rehabilitation of vegetation following land disturbance. Photo points recorded to monitor revegetation at disturbed sites in following years.

Excavation checklists were completed for all pipeline repairs, demonstrating compliance with the environmental requirements of EESA’s Excavation Procedure.

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YES/NO

SUPPORTING COMMENTS

3. To maintain native vegetation cover on the easement

3.1 To maintain re-growth of native vegetation on the easement to be consistent with surrounding area

Annual land survey to look for evidence of disturbance to vegetation on easement (apart from access tracks).

Disturbance checklist (including timed photos) signed off to indicate adequate steps undertaken to facilitate re-growth.

Follow-up rehabilitation work was undertaken where natural regeneration was inadequate.

Species abundance and distribution on the easement was consistent with the surrounding area.

Note: assessment of the consistency with surrounding areas will take into account that re-growth is a time and rainfall dependent process.

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

Excavation checklists completed for the pipeline repair program.

Land surveys did not identify areas of soil inversion restricting rehabilitation of vegetation following land disturbance. Photo points recorded to monitor revegetation at disturbed sites in following years.

Vegetation is trimmed rather than cleared to maintain line of sight within pipeline easement

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

Annual land survey to look for evidence of disturbance to vegetation on easement (apart from access tracks).

Use of Disturbance checklist and photo points before, during & after any excavation or land disturbance activity.

Vegetation trimmed rather than cleared where possible.

Consideration of sensitive vegetation during vegetation trimming and / or clearing activities.

Vegetation clearing within the easement or on land adjacent to the easement is limited to previously disturbed areas or areas assessed to be of low sensitivity, unless prior regulatory approval obtained.

Yes No previously undisturbed vegetation was cleared on the MAPS in 2013.


Vegetation is trimmed rather than cleared to maintain line of sight within pipeline easement.

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YES/NO

SUPPORTING COMMENTS

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

Use of Disturbance checklist and photo points before, during & after any excavation or land disturbance activity.

In event of pipeline repair, open trenches are monitored daily and not left open for more than 72 hours.

Vegetation clearing within the easement or on land adjacent to the easement is limited to previously disturbed areas or areas assessed to be of low sensitivity, unless prior regulatory approval obtained.

Yes No previously undisturbed vegetation was cleared on the MAPS in 2013.


Open trenches included escape ramps and were monitored for fauna daily.

3.4 To minimize disturbance of marine habitats

Only undertake non-interference maintenance activities in the marine habitat.

Obtain regulatory approval prior to undertaking disturbance in marine habitat (contact should be initially made with DMITRE during the planning process).

Use of Disturbance checklist and photo points before, during & after any excavation or marine disturbance activity.

No ‘interference’ activities undertaken in the marine habitat unless prior regulatory approval obtained.

Yes No interference activities were undertaken in the marine environments through which the pipeline transits.

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YES/NO

SUPPORTING COMMENTS

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

Regular patrols undertaken to look for evidence of weeds on easement and adjacent land (if weeds on easement but not adjacent land must implement control to prevent spread).

Records of outbreaks found, weed control activities and photo monitoring of significant outbreaks.

Vehicle wash down register.

Where appropriate, closure of ROW access road.

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

No new outbreak or spread of weeds reported.

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

Regular vehicle patrols check for any change to weed distribution on the easement.

No new declared weed outbreaks identified, and no pathogens have been identified in the pipeline easement or facilities.

A management program is in place to control the declared weed African Rue.

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

5.1 To maintain current surface drainage patterns

Regular patrols and annual survey undertaken to look for evidence of erosion, abnormal vegetation growth or death.

Observations also to be undertaken following significant storm events.

Use of Disturbance checklist and photo points before, during & after excavations, CP installation, construction activities, etc.

For excavations, surface drainage profiles restored.

For existing easement, drainage is maintained to pre-existing conditions or better.

Yes Soil profiles and contours are reinstated following the pipeline repair program. A photo log of a sample of sites is recorded in the Environmental Monitoring Report.

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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YES/NO

SUPPORTING COMMENTS

6. To avoid land or water contamination

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

Evidence of soil discoloration, vegetation or fauna death during patrols.

Incident / Spill reports.

Use of spill protection methods where work is completed within or adjacent to environmentally sensitive areas.

Containment of all hazardous substances and liquid waste in appropriate vessels.

Prevention program including pigging, intelligent pigging and pipe maintenance.

No evidence of any spills or leaks to areas not designated to contain spills.

In the event of a spill, the spill was:

Reported

Contained

Cleaned-up, and

Cause investigated and corrective and/or preventative action implemented.

Compliance with relevant sections of the Environment Protection Act.

Yes No spills were recorded in 2013.

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

Incident / Spill reports.

Active remediation methods implemented where it is determined that contamination is spreading or level of contamination is not decreasing.

Use of groundwater monitoring bores.

Use of soil farms for remediation.

Contamination confined to known area.

Level of contamination continually decreasing, ultimately to meet EPA guidelines.

Yes A soil and groundwater survey was conducted at all MAP compressor stations in 2012.

The report did not identify any remediation requirements. On-going monitoring of underground tanks is recommended.

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YES/NO

SUPPORTING COMMENTS

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


Identification of contaminated sites along easement and establishment of monitoring points.

No evidence of movement of contaminated material along easement (i.e. vegetation death, soil discolouration, subsidence).

Yes Excavation checklists completed for the pipeline repair program.

No contamination sites have been identified on the pipeline easement.

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

Regular patrols or annual survey undertaken to look for evidence of rubbish, spills (soil discoloration).

Waste disposal records, chemical manifests. Appropriately licensed contractors used for any hazardous waste disposal and records are maintained for all hazardous waste disposal.


No evidence of rubbish or litter on easement or at facilities.

No evidence that waste material is not contained and disposed of in accordance with EESA approved procedures.

Yes All waste is managed according to EESA’s Waste Management Procedure.

Hazardous waste is collected and disposed of by a licensed carrier.

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YES/NO

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

Water disposed of in a manner that prevented discharge or runoff to watercourses or environmentally sensitive areas.

Water discharged onto stable ground, with no evidence of erosion as a result of discharge.

Records on source of water and discharge method/location.

Testing of water quality prior to release/disposal of waste water.

Inspection of water disposal sites for evidence of water entering a watercourse or environmentally sensitive area.

No evidence of impacts to soil, water and vegetation as a result of water disposal (i.e. soil erosion, dead vegetation, water discoloration).

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.

No evidence of non-compliance with local or state government regulations.

Yes All waste water at EESA’s facilities is disposed of in accordance with the Waste Management Procedure (via a licensed carrier).

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YES/NO

SUPPORTING COMMENTS

7. To minimise the risk to public health and safety

7.1 To adequately protect public safety during normal operations

Job Hazard Analysis.

Records of Annual Reports, Fitness for Purpose

Reports, Risk Assessments and inspections.

Records (including above) demonstrating compliance to AS2885.

No injuries or incidents involving the public.

Demonstrated compliance with AS 2885.

Emergency procedures implemented and personnel trained.

Yes No injuries or incidents involving the public occurred in 2013.

Established safe systems of work including the use of approved work instructions and procedures, job hazard analysis, permit to work and experienced staff all contributes to EESA meeting this objective

7.2 To adequately protect public safety during maintenance

Job Hazard Analysis’.

Records of communications with adjacent landholder prior to & during maintenance work including advice of the nature and schedule of maintenance activities.

Use of signage or bunting to identify all potentially hazardous areas.

Adequate implementation of traffic management practices.

Records of regular emergency response training for employees and review of procedures.

Incident Reports.

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.

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YES/NO

SUPPORTING COMMENTS

7.3 To avoid fires associated with pipeline maintenance activities

Incident reports.

Records of regular fire safety and emergency response training for all operations personnel and review of procedures.

Established procedures for minimizing fire risk during maintenance.

No pipeline related fires.


Yes There were no pipeline related fires during the reporting period.

All EESA personnel are trained in fire safety and emergency response.

Field workers comply with EESA’s Bushfire Management Procedure

7.4 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 unauthorised activity are reported and investigated.

No unauthorised activity on the easement that has the potential to impact on the pipeline integrity.

No For further information, refer Table 3 Section 5 Incident Reporting

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YES/NO

SUPPORTING COMMENTS

8. Minimise impact of emergency situations

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

Incident reports.

Emergency response trials (carried out at least annually) and associated documentation.

Records of regular emergency response training for all personnel and review of procedures.

Link between ER exercises and Risk assessment.

Emergency response procedures are effectively implemented in the event of an emergency.

Emergency response exercises are aligned with credible threats and consequences identified in the risk assessment.

Yes No emergency situations have been recorded or managed during this reporting period.

During 2013 EESA developed an Incident Management Plan to ensure that any emergency situation is properly responded to, managed and controlled. The plan also provides for regular emergency exercises to test and review its adequacy.

EESA conducted two emergency response exercises in 2013.

All personnel have current ‘Apply First Aid’ certificates.

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).

Refer to previous criteria

(Objective 1, 2, 3 & 6).

Yes No emergency situations have arisen during this reporting period.

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YES/NO

SUPPORTING COMMENTS

9. To minimise noise due to operations

9.1 To ensure operations comply with noise standards

Incident reports.

Monitoring results, where deemed necessary (e.g. frequent complaints).

Operational activities comply with noise regulations, under the Environment Protection Act 1993.

No complaints received.

Yes No noise related incidents reported.

While the operation of the pipeline compression equipment contributes to the overall background noise levels, all sites meet statutory requirements for noise pollution.

Maintenance activities performed during the reporting period did not contribute to any increased noise levels.

10. To minimise atmospheric emissions

10.1 To eliminate uncontrolled atmospheric emissions

Incident reports. No, uncontrolled atmospheric emission. Yes There were no uncontrolled or reportable gas releases during 2013.

10.2 To minimise the generation of dust.

Incident reports.

Compliance with EMS Procedures (vehicle movement, dust suppression, etc).

No complaints received.

No dust related injuries recorded.

Yes No dust complaints were received in 2013.

Following pipeline excavation and backfill, vegetation is re-spread over the site to stabilise the topsoil and encourage revegetation.

EESA maintains native vegetation cover on the pipeline easement which aids dust suppression.

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YES/NO

SUPPORTING COMMENTS

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

11.1 To ensure that identified cultural sites are not disturbed

Consultation with relevant heritage groups if operations occurring outside known surveyed areas.

Surveys / Cultural heritage monitoring before / during excavations.

Records of site locations on operations GIS.

Use of Disturbance checklist prior to undertaking maintenance works.

Site examined for cultural heritage material prior to work involving off-easement disturbance or in an area of archaeological potential or in an area identified as being of known medium to high archaeological sensitivity.

No impact to known sites.

Any new sites identified are recorded in Land Management System and reported to appropriate authority.

Yes EESA’s Aboriginal Cultural Heritage Management Procedure and Work Instruction were updated in 2013.

These documents describe EESA’s obligations and the process and considerations that apply to the management of cultural heritage sites on or in the vicinity of pipeline easements, access tracks and associated facilities.

Prior to conducting any land disturbance outside of the pipeline easement, all areas are surveyed to identify whether cultural sites are present or not.

EESA maintains a GIS database of known cultural sites.

For a description of cultural surveys conducted in 2013, refer to the ‘Environmental Management’ section above.

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