PL6 Annual report 2004 pdf · 2015. 4. 30. · 2004 PL6 ANNUAL REPORT – RIVERLAND PIPELINE ORIGIN...

2004 ANNUAL REPORT

TO

PRIMARY INDUSTRIES AND RESOURCES SA

(Petroleum) On

Pipeline License 6 Riverland Pipeline

Document Number NPSG-008-06-AR04

March 2005

2004 PL6 ANNUAL REPORT – R IVERLAND PIPELINE

ORIG IN ENERGY ASSET MANAGEMENT 2 OF 42

TABLE OF CONTENTS

1.0 PURPOSE........................................................................................................ 6

2.0 SCOPE ............................................................................................................ 6

3.0 PIPELINE INTEGRITY MANAGEMENT ............................................................. 8 3.1 Pipeline Inspections and Assessment ........................................................................................... 8

3.1.1 Leakage Surveys & Detection ....................................................................................................... 8 3.1.2 Pipe Wall Defect Assessment........................................................................................................ 8

3.2 Stress Corrosion Cracking Investigations..................................................................................... 8 3.2.1 External Surfaces........................................................................................................................... 8

3.3 Verification of Intelligent Pig Features: ..................................................................................... 8 3.4 Coatings ............................................................................................................................................ 9 3.5 Pipeline Cathodic Protection ........................................................................................................ 9

3.5.1 Pipeline Potential Profiles ............................................................................................................. 9 3.5.2 CP Corrective Maintenance Work............................................................................................... 10

3.6 Electrical and Instrumentation ................................................................................................... 10 3.6.1 Pressure Control and Protective Equipment ................................................................................ 11 3.6.2 Site Security................................................................................................................................. 11 3.6.3 Structures..................................................................................................................................... 11

3.7 Communications ............................................................................................................................ 12 3.8 Mechanical...................................................................................................................................... 12 3.9 Ancillary Equipment...................................................................................................................... 13

3.9.1 Other ............................................................................................................................................ 13 3.10 Pipeline Patrol and Audit Results, Analysis and Remedial Action Taken ............................ 14

4 THREAT MITIGATION ...................................................................................... 14 4.1 Surveillance.................................................................................................................................... 14 4.2 Maintenance Programs ................................................................................................................. 15 4.3 Marking............................................................................................................................................ 15

4.3.1 Signage ........................................................................................................................................ 15 4.4 External Interference Prevention............................................................................................... 16

4.4.1 Pipeline Location Service............................................................................................................ 16 4.5 Landholder Contacts..................................................................................................................... 16

4.5.1 Community Awareness ........................................................................................................... 17

5.0 MANAGEMENT.............................................................................................. 17 5.1 Risk Assessments ........................................................................................................................... 17

5.1.1 Risk Assessment .......................................................................................................................... 17 5.1.2 AS2885 Risk Assessment............................................................................................................ 18

5.2 Management Systems ................................................................................................................... 19 5.2.1 Reports Generated in 2004 .......................................................................................................... 19 5.2.2 2005 One-off Activities ............................................................................................................... 19 5.2.3 2006 One-off Activities ............................................................................................................... 20 5.2.4 Volume of Product Transported .................................................................................................. 20 5.2.5 Statement of Expenditure ............................................................................................................ 20 5.2.6 Contractual Issues........................................................................................................................ 20

5.3 Emergency Response .................................................................................................................... 20 5.3.1 Emergency Response Incidents ................................................................................................... 21



5.3.2 Emergency Response Exercises .................................................................................................. 21 5.4 Incidents and Corrective/Preventative Action ........................................................................ 22

5.4.1 Incidents ...................................................................................................................................... 22 5.5 Reported Incidents........................................................................................................................ 22 5.6 Audits .............................................................................................................................................. 23

5.6.1 Operational Audits....................................................................................................................... 23 5.6.2 Environmental Audits.................................................................................................................. 23

5.7 Performance Measurement and Analysis of Results ................................................................ 24 5.7.1 Maintenance Performance ........................................................................................................... 24 5.7.2 Key Performance Indicators ........................................................................................................ 25

5.8 Review and Improvement ............................................................................................................ 25 5.8.1 Compliance Issues ....................................................................................................................... 26 5.8.2 Actions to Rectify Non-Compliance ........................................................................................... 26

5.9 Integration Project ....................................................................................................................... 27

6.0 CONCLUSIONS.............................................................................................. 28

7.0 ANNEX A : PIPELINE CATHODIC PROTECTION POTENTIALS PROFILES...... 29

8.0 ANNEX B : ASSESSMENT OF DECLARED OBJECTIVES .............................. 37



LIST OF ABBREVIATIONS

AS2885 Australian Standard 2885–Pipelines-Gas and Liquid Petroleum

CCVT Closed Cycle Vapour Turbine

CS Compressor Station

DOLA Department of Land Administration

EML External Metal Loss

EMS Environmental Management System

FBE Fusion Bonded Epoxy

FRCT Full Retail Contestability Telemetry

GEA Gas Engine Alternator

GSM Mobile Phone Protocol

GPRS Mobile Phone Protocol for Data Transmission

HAZOP Hazard Operability

HELM Heritage, Environment and Land Management

HSE Health, Safety and Environment

HV Hand Valve

KP Kilometer Point

LTI Lost Time Injury

MAOP Maximum Allowable Operating Pressure

MFG Manufacturing Defect

MLV Mainline Valve

MPR Minerals and Petroleum Resources

MTI Medical Treatment Injury

O&M Operations and Maintenance

OEAM Origin Energy Asset Management

PAV Polled Access Value

PII Pipeline Integrity International

PIRSA Primary Industry Resources of South Australia

PL Pipeline License

ROW Right Of Way

RTU Remote Telemetry Unit

SA South Australia

SCADA Supervisory Control and Data Acquisition



SCC Stress Corrosion Cracking

SES State Emergency Service

SMS Safety Management System

TJ Tera Joule



1.0 PURPOSE This report is submitted in accordance with the requirements of South Australian Pipeline License 6 and regulation requirements of the South Australian Petroleum Act 2000.

OEAM operates and manages the Riverland Pipeline on behalf of Envestra in accordance with the legislative requirements in South Australia, all relevant codes, standards and Pipeline Licence 6.

As required by Pipeline Licence 6 an annual review of pipeline operations for the 2004 calendar year is provided herein.

2.0 SCOPE The Riverland Pipeline System is owned by Envestra Limited, with Epic Energy contracted to Origin Energy Asset Management Limited (OEAM), National Pipelines Group to operate and maintain the assets.

This report reviews operations carried out during 2004 and intended operations for 2005 and 2006. In accordance with the Petroleum Regulations, a performance assessment is also provided with regard to the Statement of Environmental Objectives for the Riverland Pipeline.

The design parameters for the Riverland Pipeline System are detailed in Table 1:



Table 1 - Riverland Pipeline System – Design Parameters

Pipeline Section

Angaston to Berri Sedan Junction to

Murray Bridge

Date Commissioned October 1994 December 1994

Length 167.0km 64.1km

Outside Diameter (OD) 114.3mm 114.3mm

Pipe Wall Thickness:

Normal:

Special crossings:

(e.g. – rivers, roads, etc)

Main Line Valves:

3.0mm

4.8mm

4.8mm

3.0mm

4.8mm

4.8mm

Steel Pipe Grade API 5L x 42 API 5L x 42

Pipe Jointing Method Mechanical Joints

(“Zaplock”)

Mechanical Joints

(“Zaplock”)

Maximum Allowable Operating Pressure (MAOP)

10,000 kPa 10,000 kPa

Main Pipe Co-extruded mastic and polyethylene system

(Yellow Jacket)

Field Joints Polyethylene/butylmastic tape system

Protective

Pipeline

Coating Special Crossings

Fusion Bonded Epoxy

(including 5km downstream of Angaston compressor station)

Mainline Valves 8 2

Scraper Stations Provision made Provision made

Meter Stations (major) 2 1

Corrosion protection Sacrificial Anodes



3.0 PIPELINE INTEGRITY MANAGEMENT

3.1 Pipeline Inspections and Assessment All routine pipeline patrols and site inspections of above ground facilities were completed on the Riverland Pipeline System, in accordance with the Operations and Maintenance contract and AS2885.3.

3.1.1 Leakage Surveys & Detection

Dedicated “Leak Detection Surveys” were not carried out on the Riverland Pipeline System during 2004 however, routine patrolling, site inspections and regular maintenance visits by field maintenance staff contribute to pipeline and facility integrity.

Real-time monitoring of station flow, pressure and temperature parameters, and the leak detection model at the Transportation Services Control Centre [TSCC] also contribute to system integrity.

Origin Energy has scheduled an annual leak detection survey in the second half of 2005.

3.1.2 Pipe Wall Defect Assessment

Pipe Wall defect assessments were not carried out on the Riverland Pipeline System during 2004. OEAM will be conducting a DCVG survey on the pipeline system in 2005 to determine if there are any coating defects on the external surface of the pipe.

3.2 Stress Corrosion Cracking Investigations

3.2.1 External Surfaces

No investigation into Stress Corrosion Cracking (SCC) was conducted on the Riverland Pipeline System during 2004. The pipeline system operating parameters are monitored and are relatively stable. In conjunction with the DCVG excavation and assessment program, all exposed pipework was checked using the Magnetic Particle Inspection technique (MPI). There was no evidence of Stress Corrosion Cracking found.

OEAM is currently conducting an investigation on stress corrosion cracking immediately downstream of the Angaston compressor station. The DCVG survey to be held in 2005 will reveal if any SCC occurred since the last survey held in 2000.

3.3 Verification of Intelligent Pig Features: No intelligent pigging program was carried out during 2004. Cathodic Protection results, coating and pipe surface integrity checks conducted as part of the DCVG



and AC Mitigation projects, have all shown positive results. Epic Energy has advised OEAM there are currently no trap facilities on this pipeline system. There is however, a framework in place to accommodate pig launchers and receivers at dedicated locations for future pigging programs. OEAM is currently looking at developing a schedule of intelligent pigging in future maintenance programs.

3.4 Coatings No coating defect survey was conducted on the Riverland Pipeline System during 2004, however four sites were excavated for the installation of the new anodes and the coating at each site was in good sound condition. A DCVG survey was completed in June 2000 and scheduled again for mid 2005.

3.5 Pipeline Cathodic Protection

To mitigate corrosion, the Riverland Pipeline is coated with a protective extruded butyl mastic and polyethylene coating system, which serves to isolate the external pipeline surfaces from corrosive elements in the surrounding environment. Field joints are coated with a polyethylene backed butyl mastic tape system. Secondary protection at coating holidays and imperfections is achieved by applying cathodic protection.

3.5.1 Pipeline Potential Profiles

The effectiveness of the cathodic protection system is monitored, by carrying out two full line potential surveys annually. A summary of the results of those surveys is provided in the following paragraphs, with actual data provided in Annex A. It should be noted that in the dry season, some test points on the lateral show lower potentials than –850mV. As the system is galvanic, this is expected to happen, however, if the locations show low potentials in the wet season and the trend had occurred in the past, further investigations would be required, including inspection programs on the pipework in the effected area. OEAM has also conducted a CP survey in conjunction with Epic Energy during July 2004. This survey identified number of possibilities that could cause low potentials on the Berri and Murray Bridge Laterals, one of them being the soil resistivity in dry seasons. OEAM's Cathodic Protection Engineer is currently conducting an in-depth study to pinpoint the root cause of this problem. The outcome of this study will determine what action, if any, is required to rectify this issue.



3.5.2 CP Corrective Maintenance Work

Cathodic Protection corrective maintenance work carried out during 2004 consisted of;

• The replacement of a cable and Fisher ROC input module at the Berri Gate Station used for monitoring the CP Potential - analogue to SCADA, this fault resulted from a lightning strike.

• An isolation check on the insulation flange installed at Visyboard meter station.

• The replacement of four Magnesium anodes with zinc units in conjunction with the AC Mitigation project to further enhance the cathodic protection system. Installations were at KP 4 ; KP 12.1 ; KP15.6 and KP 34.9, and

• Additional part surveys to confirm potential readings at new zinc anode installation sites and to check initial low reading between KP 0 and KP 60 as a result of dry soil conditions.

3.6 Electrical and Instrumentation

• Routine Accuracy Verification Tests were carried out on the Riverland meter station billing equipment on a two monthly basis.

• Electrical compliance testing was

conducted at all sites on all portable electrical equipment and residual current devices (RCD’s). The tests were carried out in accordance with AS3760 and the OHS&W Act–1995.

Non-billing electrical/instrumentation equipment, such as pressure switches, battery systems, station pressure and temperature transmitters were maintained as part of the 6 monthly routine maintenance tasks. Training and familiarisation of equipment and site layout was provided to OEAM employees during 2004 in prepartaion for the O&M handover on 1 March 2005. The Fisher ROC flow computer memory packs were upgraded at all sites from the original “RocPac”, to the latest version “FlashPac” during 2003. This upgrade was



carried out to address the “billing spiking” issues that occurred randomly from various sites. It also provided access to the latest interface software version revisions from the original equipment manufacturer (OEM). During 2004 it has been confirmed the “FlashPac” upgrade rectified the billing issues at all sites. There were no major faults reported on the Riverland system in 2004. Corrective maintenance tasks included;

• Fisher ROC flow computer replacement at National Dairies meter station,

due to a memory corruption/interface software compatibility issue. A spare unit was installed.

• Respond to several loss of site communications resulting from power outages.

• Assisting OEAM and contractors to program, install and commission Kingfisher RTUs at each metering site in preparation of the O&M contract termination on March 1st 2005. Epic Energy has provided technical information on the configuration and operation of the Fisher ROC RTUs in order for it to communicate to the newly installed King Fisher units.

3.6.1 Pressure Control and Protective Equipment

Routine 6 monthly maintenance inspections are carried out at all meter/gate stations on the Riverland Pipeline System. Tasks performed involve instrument/pilot gas maintenance, over-pressure isolation valve checks, remote valve operations, active/monitor pressure regulation maintenance and station pressure relief valve operational tests.

All tasks are recorded and documented via Epic Energy’s computerised maintenance management system (Maximo) and the Central Filing System.

3.6.2 Site Security

Site security conforms with standard Epic Energy policies and is inspected in conjunction with routine patrols and maintenance activities. Minor acts of vandalism related to graffiti on signage were recorded during routine patrols, however there were no major security breaches at facilities during 2004.

3.6.3 Structures

The Riverland Pipeline System incorporates minimal structures, however all were reported to be in sound condition with minimal outstanding maintenance required.



3.7 Communications The Riverland Pipeline communications system is based on Telstra services. The Telstra services are permanently attached private lines (PAPL) that provide SCADA with the necessary infrastructure to communicate from Dry Creek to the remote terminal units (RTU). The new sytem set up consists of a new King Fisher RTU with GPS/GPRS modem attached to the existing Fisher ROC RTU. The new RTUs on the Riverland sites are communicating to the Master Telemetry Unit at Brompton Gas control over GSM/GPRS. From 1st of March 2005 the Telstra private lines will be disconnected from all the sites except for Berri Gate and Murray Bridge gate stations since the compressor station will still be operated by EPIC and will still be operated by EPIC and is dependant on the pressure levels from these sites. Service level agreements (SLA) provide response and restoration times to attend site to resolve problems. The communications system associated with the Riverland Pipeline proved reliable throughout 2004, with minimal maintenance requirements.

3.8 Mechanical

All scheduled routine maintenance tasks where completed on the Riverland Pipeline System during 2004. Maintenance tasks included; • Mainline Valve servicing, station dust

filter inspections/replacement, isolation valve operational tests and station Y-Strainer inspections and cleaning.

• Fire extinguisher inspection and

maintenance, in accordance with Australian Standards, was carried out by a licensed contractor.

Pressure vessel inspection and testing is carried out on filter vessels in accordance with AS/NZS 3788. Examples of corrective mechanical maintenance conducted during 2004 involved :

• Dust issues within the meter station pipework which continued to cause problems, such as strainer blockages and metering faults at Murray Bridge and Metro Meats meter stations. The problem was eliminated with changes to sealing ring material changes.



• Active regulator faults were rectified at Murray Bridge, Metro Meats and Tarac meter stations

3.9 Ancillary Equipment

The Angaston compressor unit is owned and operated by Epic Energy. This equipment is directly associated with the Riverland Pipeline and it has an important bearing on maintaining pressures and supply to the system. This unit will be transferred to Envestra on termination of the Epic Energy O&M contract for the Riverland Pipeline System.

Maintenance activities carried out on the Angaston Compressor unit during 2004 are detailed as follows.

• Routine 6 monthly instrumentation/electrical calibrations and inspections, covering pressure and temperature transmitters, station battery systems, compressor unit safety shutdown circuits, compressor unit ESD tests, station “Mainline Break” tests and hazardous area electrical inspections.

• Routine 6 monthly mechanical maintenance included oil analysis, oil/filter changes, drive belt inspections, pressure relief valve testing, compressor unit/drive motor and aftercooler maintenance.

• All electrical solenoids installed on the isolation valves associated with the Angaston compressor unit were replaced. This task was carried out to increase the reliability of the compressor package, as the original solenoids were prone to failure on occasions.

• The compressor unit relief valve was replaced with an equivalent unit. The replacement valve incorporates a remote mounted pilot assembly, to reduce the effects associated with vibration, as a result of reciprocating compressors. The original pilot was subject to internal wear, which resulted in a reduction on the specified set pressure and shutdown of the compressor unit.

Epic Energy will continue to operate and maintain the Angaston Compressor station under the Service Level Agreement with OEAM for a further 3 years.

3.9.1 Other

Due to a rationalisation of operations by the “Berrivale Fruit Juice” group, the Berrivale Cannery meter station was isolated on request from OEAM. The manual inlet and outlet isolation valves were closed and locked during June 2003. Site instrumentation and SCADA systems are no longer operational. All SCADA equipment has been removed from site. OEAM will be removing the skid from site in mid 2005.



3.10 Pipeline Patrol and Audit Results, Analysis and Remedial Action Taken

As a result of routine patrol and audit activities, three areas of minor soil erosion on the pipeline easement were detected due to heavy rains. A property at Keyneton which has a history of previous erosion problems had a reoccurrance during 2004. The erosion resulted from water run-off through a natural watercourse causing minor soil erosion. There are no issues relating to pipeline safety and pipeline depth of cover. Additional fill and topsoil was added to the affected area. In consultation with the landowner weed free soil was used to reinstate the effected area back to its original state. Bales of hay were stratigically laid to control the water run off and assist in eliminating any further erosion. Pasture blend seeding was planted in the new soil to reinstate the soil similar to the surrounding environment and assist in reducing wind and water erosion. Minor water erosion on the Rosenzweig Road verge and within the Murray Bridge Lateral pipeline easement was detected during routine patrols. The damaged section was reported and repaired by the Mid Murray council. A minor depression on the pipeline easment at the Marne River crossing was repaired by contractors under Epic Energy's supervision. During routine patrols marker pegs were detected on land near Swan Reach resulting in further investigation. Contact with the land owner identified he owned the land freehold and he had issues with the proposed increased depth of cover for the road crossing he required for he new sub-division of the land. The depth of cover complied with the construction design of a minimum 750mm, the changes to the land use requires increased cover for road crossings to comply with AS 2885.3. Investigations have revealed that during the land transfer from the previous owner, the conveyancer or the Lands Titles Office did not pick up Envestra's underlease on this property. Envestra has been advised of this error. The easements have not been extinguished and still therefore remain. OEAM are working with the Lands Titles Office to rectify this issue.

4 THREAT MITIGATION

4.1 Surveillance All routine patrols were completed as scheduled on the Riverland Pipeline System throughout 2004, in accordance with the O&M contract and AS2885, by Dry Creek based field maintenance officers or a permanent contractor based in the Berri region. Additional patrols are carried out in conjunction with regular maintenance activities. Examples of items identified as part of routine patrols and site inspections included minor leaks from process compression fittings at above ground facilities



and the re-instatement and continued monitoring of wombat holes within the pipeline easement. The disposal of cigarette butts near the meter station compound from an adjacent factory was also identified and addressed. Three minor water erosion areas were detected and rectified as referred in section 3.10.

Ongoing signage replacements and the monitoring of third party activities in the pipeline vicinity assist to maintain pipeline safety and integrity.

4.2 Maintenance Programs The maintenance program outlines the maintenance requirements to ensure the integrity and reliability of the pipeline and associated infrustructure.

The planning department schedules both preventative and corrective maintenance activities through the Workpack system via Maximo with appropriate allocation of personnel, spares, tooling and equipment.

Epic Energy's maintenance department reviewed the Riverland Pipeline Systems maintenace plan and maintenance schedules in 2004 to ensure all contractual and regulatory obligation compliance.

4.3 Marking

4.3.1 Signage

All signage on the Riverland Pipeline System is installed in accordance with AS2885 and maintains “Line of Sight”. The pipeline signage is monitored and replaced as required, as part of the routine patrol duties by Dry Creek based Field Maintenance Officers or the permanent contractor based in the Berri region.

Bamboo growth was again cleared from the railway easement at Berri, and several areas had growth removed or cut back in conjunction with councils to ensure line of site in accordance with AS2885, for pipeline warning signs.

Actions arising from a Environmental Audit conducted by OEAM in April 2004, identified the need for additional signage to improve “Line of Sight” and marking of the pipeline. Additional and replacement signage was completed and reported to OEAM in the close out report dated September 2004.

Compound signage, providing contact details, emergency “Toll Free” numbers, site location and “HAZCHEM” details are installed at all facilities on the Riverland Pipeline System. This signage is maintained in conjunction with routine activities.



4.4 External Interference Prevention

4.4.1 Pipeline Location Service

OEAM via Epic Energy provides a free service to locate pipelines for which they are responsible. This service is primarily used by landowners / occupiers or contractors carrying out civil works in the vicinity of any of the pipelines administered by Epic Energy. During 2004, 159 enquiries were received for pipeline and easement information relating to the Riverland Pipeline System, 132 resulting from the “1100 – Dial Before You Dig” system and the remaining 27 were direct calls from property and land owners along the pipeline Of the 159 requests for pipeline information 95 pipe locations were carried out in 2004, resulting in several third party work activities within the pipeline easement and requiring Epic Energy site supervision.

Pipe location near Angaston

All works carried out within the pipeline easement were conducted under Epic Energy’s "Permit to Work" System and constantly supervised to ensure the safety and integrity of the pipeline system and personnel.

4.5 Landholder Contacts There are 83 landowners and occupiers along the Riverland Pipeline and laterals. A property owner contact scheme is in place to visit each owner or occupier annually. The Land Management Officer visits each owner or occupier along the pipeline. Personal contact was made with all property owners from the Riverland Pipeline (including the Murray Bridge and Berri Laterals). The property owners are given a landowner pack containing pipeline safety awareness brochures, an Epic Energy pen and hat, a drinks holder, stickers and a Dial Before You Dig bag (this bag contains a DBYD brochure, pen, fridge magnet) together with the Land Management Officer’s business card.



An ongoing issue currently in process of being resolved relates to a landholding along a small section of the pipeline in the Swan Reach area. The Lands Titles Office omitted Envestra's easement on the land titles and negotiations between Envestra and landholder continue. It is expected that resolution to the issue will be achieved by June 2005.

4.5.1 Community Awareness

Epic Energy runs a Community AwarenessProgram by holding meetings withcommunities along the pipeline route. The target is to hold annual meetings withCFS, MFS, police, ambulance, SES, councils,contractors and various community members.

The focus of the presentation is to providebackground information on Epic Energy, theproperties of natural gas, information aboutunderground pipelines, identifying hazards,what to do in the event of an emergency andconducting works on or near the easement.

In 2004, Epic Energy held educational sessions with representatives from the Barossa Council, the Rural City of Murray Bridge, Berri-Barmera Council and members of the Gerard Community Council. Members of the Region 3 CFS also attended the sessions.

5.0 MANAGEMENT

5.1 Risk Assessments

5.1.1 Risk Assessment

The risk management system is utilised to ensure that hazards are identified and risks evaluated and managed at all facilities. The process for identifying, assessing and managing risks is documented and includes:

• Hazard identification • Hazard analysis • Risk assessment • Risk control • Reporting and close out

Hazards are identified using the following tools – HAZOP, HAZID, safety reviews, job hazard analysis, incident reports and investigations, audits and inspections together with the AS2885 risk assessment.



Hazard analysis is conducted using HAZAN and job hazard analysis.

Risk assessments are conducted to assess risk against set criteria, to demonstrate that risk reduction measures are as low as reasonably practicable (ALARP). This is done using the following tools: risk matrix, previously conducted risk assessments, AS2885 pipeline risk assessment and comparison against standards, codes and legislation.

Risk control methods include the following – elimination, substitution, engineering controls, administrative (procedural controls) and personal protective equipment (PPE).

Reports are then prepared with tasks allocated to appropriate people for action. Tools used in this area include the hazard register, critical tasks list and close out reports.

5.1.2 AS2885 Risk Assessment

OEAM in conjuction with Epic Energy conducted a 5 yearly AS 2885.3 Risk Assessment Review of the Riverland Natural Gas Transmission Pipeline in August 2004.

The risk assessment incorportated a location class review, which identified any changes to the land use and activities along the pipeline. It also included a review of the threats to the pipeline and the protective measures in place to mitigate any risks arising from these threats. If it was deemed there were not adequate safeguards for any particular threat, then the threat was subject to failure analysis to reduce the risk to ALARP.

The threats identified with the potential to cause a loss of integrity on the Riverland Pipeline [ excluding those that have a negligible risk ] can be summarised as follows:

• The use of trucks or tractor mounted augers to bore holes for fence posts;

• Excavation for new services and roads; • Vertical boring for large poles or posts; • Vandalism or malicious damage to above ground facilities or MLV

pits;

• Stress corrosion cracking [ this risk has been temporarily rated as low, it requires further investigation, before the risk can be more accurately assessed ];

• Vehicle damage to the Berri Delivery Station or the Berri Township #1 Gate Station;

• Excavation for maintenance of services crossing the pipeline;



• Excavation in Fletcher's Transport Terminal Yard; • Horizontal boring across main roads and railways; and • External corrosion of buried pipe.

The three highest rated threats were boring holes for fence posts, excavation for new services and vertical boring for large poles or posts. These threats were classified as intermediate risks, while the remaining threats were rated as low risk.

The actions identified to improve management of the pipeline risks have been summarised in the Risk Assessment Final Report document No. F008-10.0-REP001. Once the actions are completed, identified risks will be updated to reflect the revised risk ratings. Further to this monitoring of changes to risks classified as “Intermediate” or “Low” shall be made a feature of the Operations and Maintenance Manual for the pipeline.

5.2 Management Systems

Interface meetings were held between OEAM and Epic Energy on a 3 monthly basis in relation to the Riverland Pipeline maintenance contract throughout 2004.

5.2.1 Reports Generated in 2004

The following reports were generated during 2004;

• PL6 Annual Report for 2003 in February 2004, prepared by Epic Energy;

• Commissioning report for new anode bed installations forwarded in February 2004, prepared by Epic Energy;

• Environmental Audit report in April 2004, prepared by OEAM; • Operational Assessment report in June 2004, prepared by

OEAM;

• Operational Audit Close out Report in September 2004, prepared by Epic Energy;

• AS 2885 Risk Assessment Review in November 2004, prepared by OEAM; and

• Monthly End of Month Reports, prepared by Epic Energy for OEAM.

5.2.2 2005 One-off Activities

• A Pipeline Coating and Protection Assessment Survey [DCVG] is due for completion in mid 2005;

• Issues related to the hand-over of the Operations and Maintenance contract to OEAM for the Riverland Pipeline – commencing on 1st March 2005. Currently the only outstanding issue is the land division of Angaston compressor station. A subdivision proposal has been put forward to the local council relating to potential soil contamination in



the compound. Soil samples will be taken from the compound in March 2005 to identify any contamination;

• An emergency response exercise is due by June 2005; • Annual Operations audit to be conducted in the second half of 2005;

and

• 5 yearly maximum allowable operating pressure overpressure review of all above ground facilities to be conducted in the second half of 2005.

5.2.3 2006 One-off Activities

• No one off activities scheduled for 2006

5.2.4 Volume of Product Transported

Approximately 784 TJ of natural gas was transported through the Riverland Pipeline System in 2004.

5.2.5 Statement of Expenditure

• Commercial in confidence.

5.2.6 Contractual Issues

There were no contractual issues associated with the Riverland Pipeline System during 2004. OEAM advised Epic Energy that this Operation and Maintenance Agreement will be terminated on the 1st January 2005. An extension to this O&M contract has been agreed by both parties to extend until the 1st March 2005 to ensure a safe and effective handover process.

5.3 Emergency Response Pipeline Licence 6 requires a practice drill to be conducted every two years on the Riverland Pipeline System. Epic Energy's emergency response training policy allows for two emergency response exercises to be carried out in each state, each year. Recommendations and issues arising as a result of these exercises apply equally to the Riverland Pipeline System.

5.3.1 Emergency Response Objectives To further improve Epic Energy’s emergency response preparedness, the escalation of training exercises to include full mobilisation, the involvement of external parties, permanent contractors and emergency services within the regions is being investigated.



This, along with varying roles and responsibilities for staff and contractors during exercises, will help to further refine emergency response capabilities and awareness for all parties involved.

5.3.1 Emergency Response Incidents

There were no emergency response incidents to report for the Riverland Pipeline System during 2004.

5.3.2 Emergency Response Exercises

• While there were no Emergency response exercises conducted on the Riverland Pipeline System Epic Energy carried out two full mobilisation exercises as detailed below in 2004.

Exercise “Blue Lake” A full mobilisation exercise was conducted on the South East of South Australia’s natural gas pipeline system at the Mount Gambier meter station called “Exercise Blue Lake” on 22nd June 2004. The scenario used for this exercise was one of escaping gas which eventually ignited causing a considerable fire. This exercise was coordinated from the South Australian Incident Command Centre at Dry Creek and involved the mobilisation of field staff and equipment to site as well as involvement from the local emergency service providers in the area. (CFS, MFS, Ambulance service, SES and the Police.) A report was prepared by Epic Energy and forwarded to PIRSA.



Exercise “Hawker” A full mobilisation exercise referred to as “Exercise Hawker” was conducted on the Moomba to Port Bonython Liquids Hydrocarbon pipeline system at mainline valve 18 (MLV) near the township of Hawker on the 18th November 2004. The scenario used for this exercise involved the excavation of the mainline pipework near the MLV and the accidental breakage of a one inch section of pipework which for the purposes of the exercise resulted in a substantial loss of hydrocarbon liquid and a large pool fire. Exercise “Hawker” was designed to test the Epic Energy Crisis and Emergency Management team, the field maintenance staff as well as the local area emergency services groups which included CFS, MFS, Ambulance service, SES and the Police. Staff from Santos also attended the exercise as observers in the crisis management centre at Epic Energy’s Dry Creek facility. A report was prepared by Epic Energy and forwarded to Santos for their review and eventual on-forwarding to PIRSA:

These exercises are designed to test the emergency response preparedness of Epic’s personnel, equipment and procedures as well as those of the states emergency service providers.

The last emergency exercise involving the Riverland Pipeline System was in July 2003 and the next one due in 2005.

5.4 Incidents and Corrective/Preventative Action

5.4.1 Incidents

No type A or type B encroachments occurred during 2004.

5.5 Reported Incidents There were no Health and Safety incidents reported on the Riverland Pipeline during 2004. Three type C encroachments were recorded during 2004. They all occurred outside the easement and were recorded for hazard awareness monitoring. During 2004, there were no reports were received relating to gas venting, low station sales pressures or customer complaints for the Riverland Pipeline System.



5.6 Audits

5.6.1 Operational Audits

During 2004 a review of the Maintenance plan for compliance with the Maintenance program, AS 2885.3 and the O&M contract was carried out. As a result of this audit, work frequencies were confirmed, work instructions modified, and additional work files opened.

An Operational Assessment Audit was conducted by OEAM's Technical Services Department in June 2004. An Epic Energy representative was in attendance during this audit.

The objective of the audit was to determine the compliance of the activities performed in the operation and maintenance of the pipeline to the conditions of Pipeline Licence No. 6, AS 2885.3 and OEAM operational procedures, and identify any deficiencies therein; and to determine the key issues to be addressed in relation to transferring operation and maintenance of the pipeline back to OEAM. Issues identified in the operation and maintenance of the pipeline included: • No safety and operating plan exists for the pipeline as per AS 2885.3,

Clause 4.2. This action item was addressed and completed in December 2004;

• The filter body at the Murray Bridge gate station is not registered as a pressure vessel with DAIS Workplace Services;

• Sections of the pipeline, have been not been adequately protected by the CP system (ie. < -850mV) during periods of dry weather since the summer of Year 2000. OEAM is currently conducting a study to develop a program to rectify this problem;

• Properties that do not have formal easements for the pipeline route in the vicinity of Swan Reach (this was being addressed at the time of the audit); and

• No intrinsic safety barrier earthing system checks are being conducted in accordance with AS 2381. Not all hazardous areas have been identified at facility sites in accordance with AS 2430. OEAM will be conducting hazardous area survey which will include earthing system checks and developing hazardous area drawings in the second half of 2005.

5.6.2 Environmental Audits

During the year, monthly surveillance patrols were carried out by Epic Energy along the Riverland Pipeline System and environmental issues were monitored as part of this activity. An audit of the Epic Energy Environmental Management System was due in November 2004. This audit was not completed and has been rescheduled by the Risk management coordinator to be completed in March 2005.



The next annual environmental audit of the pipeline will be conducted during April 2005.

5.6.3 Safety Audits

The Safety Management System [SMS] developed and implemented at Epic Energy provides all Epic Energy personnel with a framework for management of health and safety related risks on facilities operated by Epic Energy, including the Riverland pipeline system.

The safety audit process was taken into consideration during the internal audit framework review undertaken in the 4th quarter of 2004. Audits of safety management will continue to be undertaken in line with the Safety Management System (SMS).

A safety internal audit of the SMS is planned to commence in the first quarter of 2005 and will cover the SMS practices of 2004 and the compliance with procedures during 2004 as these may apply to this pipeline.

5.7 Performance Measurement and Analysis of Results

5.7.1 Maintenance Performance

In 2004, 504 Maintenance Work Orders were produced from Epic Energy's computerised maintenance management system (Maximo). The tasks were completed by Dry Creek based Field Maintenance Officers or the permanent contractor based in the Berri region. The ratio between preventative and corrective maintenance tasks is detailed below;

400 Preventative Maintenance tasks 79%

104 Corrective Maintenance tasks 21%.



5.7.2 Key Performance Indicators

The following key performance indicators have previously been established to monitor performance of operations and maintenance activities on the Riverland Pipeline. Outlined below are the KPI results for 2004.

2004 target 2004 actual 2004 Comment

Cathodic Protection

1. Percentage of Pipeline that has an off pipe to soil potential greater than –850 mV (Winter)

95% 100% Target Achieved

2. Length of the pipeline protected to the AS 2885 level

95% 100% Target Achieved

Third Party Incident

1. Number of times pipeline is damaged 0 0 Met Target

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

0 0 Met Target

3. Exposure of pipeline due to washout and wind erosion

0 0 Met Target

Unplanned Gas Releases

Number of Relief valve/vent discharges

0 0 Met Target

Number of pipeline leaks (more than 200 m3/hr)

0 0 Met Target

Amount of gas discharged (m3) 500



• Training targeted at Epic Energy's Excavation Procedure; • Training on the Installation of " Clockspring " repair procedures; • Traffic management; • Supervisor / OHS; and • Environmental awareness and regulation training.

5.8.1 Compliance Issues

Every endeavour is made to ensure that design, manufacture, construction, operation, maintenance and testing of all appropriate facilities is carried out in accordance with AS2885.3. Any non-compliance identified is logged in Epic Energy's computerised maintenance management system (Maximo), where they are tracked to conclusion. Significant items are reported through OEAM to PIRSA.

There was one non conformance identified in the assessment criteria for the SEO. This related to minor erosion identifed within the pipeline easement. All areas were rehabilitated to their original state. The specific objectives declared in the SEO have been assessed in accordance with the Goal Attainment Scaling. The results of that assessment are provided in Annex B.

5.8.2 Actions to Rectify Non-Compliance

As a result of routine patrol and audit activities, there were three areas of minor soil erosion on the pipeline easement, all caused by heavy rains.

One was a property at Keyneton with a history of previous erosion problems. The erosion resulted from water run-off through a natural watercourse causing minor soil erosion. There are no issues relating to pipeline safety and pipeline depth of cover and additional fill and topsoil was added to the affected area. In consultation with the landowner weed free soil was used to reinstate the affected area back to its original state and bales of hay were strategically laid to control the water run off and assist in eliminating any further erosion. Pasture blend seeding was planted in the new soil to reinstate the soil similar to the surrounding environment and assist in reducing wind and water erosion.

The second was a minor water erosion on the Rosenzweig Road verge and within the Murray Bridge Lateral pipeline easement which was detected during routine patrols. The damaged section was reported and repaired by the Mid Murray council.

The third was a minor depression on the pipeline easement at the Marne River crossing which was repaired by contractors under Epic Energy's supervision.



5.9 Integration Project

The process of integration of the Riverland Pipeline operations into OEAM had commenced in April 2004. A project team for the integration was established and each responsible party has been assigned their respective duties. The Project Management manual and project schedule was prepared to meet the deadline of integrating the pipeline into OEAM. A detailed scope of work to separate the SCADA and electrical power systems at the Angaston Compressor station from Epic’s metering station was prepared. However, due to the costs involved it was agreed for Epic Energy to operate and Maintain the compressor station. A Service Level Agreement was prepared and signed by both parties. TUSC, a telemetry systems specialist was invited to provide a scope of work to integrate the meter stations. The level of upgrade to the sites and the Adelaide Control Centre was determined after a site visit scheduled in August 2004. The site visit helped determine the required functional changes at the meter stations and along the pipeline and highlighted a number of changes required to the SCADA system. These were carefully assessed to determine the most cost effective and operationally sound manner to integrate the system into the OEAM control room. TUSC proposed two possible solutions. After carefully reviewing both options presented in consultation with OEAM's project personnel a decision has made based upon cost effectiveness and operational suitability to install new remote telemetry units at each site along side the existing units to minimise the need to upgrade the entire site. A scope of work was prepared and on site work started in November 2004.

During this period OEAM maintenance personnel joined Epic Energy maintenance personnel on ROW patrols, AVT's and other maintenance activities to familiarise themselves with the Riverland Pipeline system.

The expected termination of the pipeline Operation and Maintenance agreement with Epic Energy was postponed from 1 January 05 till the 1 March 2005 due to issues associated with the asset transfer of the Angaston Compressor Station. An agreement regarding this extension was developed by OEAM and accepted by Epic Energy. The majority of onsite physical changes to the SCADA system was completed during December 2004. An additional site visit was conducted in mid January 2005 to finalise some outstanding issues with the Angaston Compressor Station. This was not a critical issue as Epic Energy agreed to operate the compressor under a service level agreement. The SCADA information from the compressor station is set up for viewing only for OEAM as Epic Energy will have operational responsibility. By the End of January 2005 OEAM was able to receive alarms, and monitor and operate Meter stations from the Brompton Gas Control Room. Epic Energy agreed to keep the datalines from the meter stations live until the 1 March 2005.



6.0 CONCLUSIONS Pipeline coating inspections, cathodic protection monitoring, along with routine maintenance and inspection programs carried out on the Riverland Pipeline System during 2004, indicate that the pipeline is in sound condition and is capable of operating at set parameters with no restrictions.

The results of the Riverland Natural Gas Transmission Pipeline AS 2885 Risk assessment Review carried out in August 2004, suggest that the risks to the pipeline are generally at an acceptable level.

The Riverland Pipeline Integration Project was completed with few outstanding items, which do not affect the operation and maintenance of the pipeline system. OEAM is now able to operate the pipeline system independently and TUSC and OEAM are currently working together to finalise the remaining outstanding items.



7.0 ANNEX A : PIPELINE CATHODIC PROTECTION POTENTIALS PROFILES

ANNEX A

CATHODIC PROTECTION DATA

2004 PL6 ANNUAL REPORT

DATED MARCH 2005

PIPELINE CATHODIC PROTECTION DATA AND ON/OFF POTENTIALS PROFILES



Visy Lateral Full Line Surveys

500

600

700

800

900

1000

1100

1200

1300

1400

1500

0.0 0.1 0.2 0.3 0.4

Kilometres

mV

Jan 04 Jul 04

Visy Lateral % of potential greater than –850mv in winter ( 100 %) Length of pipe ( 0.4 km) % of potential greater than –850mv in summer ( 100 %) Length of pipe ( 0.4 km)



Berri Lateral Full Line Surveys

500

600

700

800

900

1000

1100

1200

1300

1400

1500

0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0 110.0 120.0 130.0 140.0 150.0 160.0

Kilometres

mV

Jan 04 Aug 04

Berri Lateral % of potential greater than -850mV in winter (100%) % of potential greater than -850mV in Summer (79%) Length of pipe (159km)



Berri Dist.Full Line Surveys

200

300

400

500

600

700

800

900

1000

1100

1200

1300

1400

1500

159.7 160.0 160.0 161.7 162.1 162.1 162.5 163.9 164.0 164.0 164.9 165.6 166.5 166.5 166.9

Kilometres

mV

Jan 04 Jul 04

Berri District Lateral % of potential greater than –850mv in winter ( 100 %) Length of pipe ( 7.2km) % of potential greater than –850mv in summer ( 100 %) Length of pipe ( 7.2km)



Murray Bridge Lateral Full Line Surveys

500

600

700

800

900

1000

1100

1200

1300

1400

1500

0.0 10.0 20.0 30.0 40.0 50.0 60.0

Kilometres

mV

Jan 04 Jul 04

Murray Bridge Lateral % of potentials greater than -850mV in winter (100%) % of potentials greater than -850mV in summer (98%) Length of pipe (64km)



National Dairies Lateral Full Line Surveys

500

600

700

800

900

1000

1100

1200

1300

1400

1500

1600

1700

1800

1900

2000

2100

0.0 0.1 0.5 1.0

Kilometres

mV

Jan 04 Jul 04

National Dairies Lateral % of potential greater than –850mv in winter ( 100 %) Length of pipe ( 1km) % of potential greater than –850mv in summer ( 100 %) Length of pipe ( 1km) High potentials before AC mitigation anodes fitted



Tooravale Lateral Full Line Surveys

500

600

700

800

900

1000

1100

1200

1300

1400

1500

0.0 0.5 1.0 1.5 2.0

Kilometres

mV

Jan 04 Jul 04

Tooravale Lateral % of potential greater than –850mv in winter (100 %) Length of pipe (2.3km) % of potential greater than –850mv in summer (100 %) Length of pipe (2.3km)



8.0 ANNEX B : ASSESSMENT OF DECLARED OBJECTIVES

ANNEX B

2004 PL6 ANNUAL REPORT

DATED MARCH 2005

ASSESSMENT OF DECLARED OBJECTIVES

2004 PL6 ANNUAL REPORT – RIVERLAND PIPELINE

S-17-226B-AR-G-001 38 OF 42

ASSESSMENT OF DECLARED OBJECTIVES Riverland Objectives and Assessment Criteria1

OBJECTIVE GOAL MEASURE/HOW ACHIEVED/NOT ACHIEVED COMMENTS

1. Vegetation – to promote and maintain vegetation in accordance with surroundings

1.1 To encourage regrowth of native grasses and shrubs along the right of way, within 3m of the pipeline centreline, where appropriate (ie; not in farmland used for cropping or pasture).

1.2 To maintain land use in accordance with pre-existing conditions.

1.3 To ensure environmental weeds and pathogens along the right of way are managed in a manner consistent with adjoining land.

1.4 To monitor and manage revegetation areas

1.5 To monitor and manage Branched Broomrape (Orobanche ramose) within defined containment area along Murray Bridge lateral pipeline.

Compliance with recommended Code of Control for Broomrape in consultation with landowners and Government authority.

Native vegetation regrowth [grasses, shrubs & tress] along the easement is typical of adjoining areas.

No complaints from landowners in respect to crop losses along the easement.

Minimal new weed infestation as a result of pipeline operations. Minimal spread of weeds along the pipeline easement.

Easement revegetation [as measured by foregoing criteria] confirmed via photographic records. No identified spread along pipeline easement as a result of operations and maintenance activities.

No landowner complaints or non- compliances with code of control for Broomrape in the course of pipeline operations

Achieved Reinstatement of an area near Keyneton was carried out as identified in section 3.10. The land was returned to its natural state and pastoral seeds planted to generate regrowth in line with the surrounding area.

2. Soil – to conserve the 2.1 To ensure that there is no erosion or Soil level and or subsidence are Not Achieved Minor erosion occurred as

1 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 ACHIEVED/NOT ACHIEVED COMMENTS original state of the soil subsidence along the right of way.

2.2 To manage soil rehabilitation areas in an appropriate manner

consistent with the surrounding area

Rehabilitate areas support regrowth consistent with the surrounding area

identified in section 3.10. Area has been reinstated but requires continual monitoring.

3. Fauna – to preserve existing habitats

3.1 To ensure that pipeline operations do not impinge upon existing native fauna habitats.

3.2 To maintain stockpile vegetation.

3.3 To ensure that operations do not impose restrictions to fauna crossing the right of way.

No alterations to existing remnant vegetation areas.

No alterations to existing stockpile vegetation

No obstruction to fauna installed along the easement

Achieved) An area near Sedan has wombat burrows on the easement and a potential to cause pipe coating damage.

This area is monitored on routine patrols and new burrows with the potential to cause pipeline issues are filled in immediately.

4. Water Resources – to prevent pollution of watercourses

To promote and maintain water drainage patterns

4.1 To ensure that operation and maintenance activities do not give rise to pollution of watercourses.

4.2 To ensure that there is no evidence of altered drainage patterns

Soil and liquid waste have not polluted rivers, streams, watercourses, dams or lakes

Bank stability maintained especially following high rainfall events. Likely alterations to drainage patterns not evident by soil erosion or subsidence.

Achieved Confirmed by visual inspection of pipeline route

5. Air Quality – to minimise the potential for emissions that heighten public concern

5.1 To ensure that uncontrolled gas emissions are reported and actioned in a timely manner.

5.2 To minimise dust generation by

No unintentional gas emissions reported

No complaints from third parties in respect of air quality. Compliance with

Achieved

Achieved



OBJECTIVE GOAL MEASURE/HOW ACHIEVED/NOT ACHIEVED COMMENTS management of vehicle operations along the right of way

legislative requirement of the Environmental Protection Act 1993 in respect of gaseous and dust emissions.

6. Land Use – to avoid significant disturbance to land use or damage to infrastructure

6.1 To minimise disturbance to land use and damage to infrastructure.

6.2 To inform landholders of likely land use disturbance as a direct result of operations.

6.3 To maintain accurate records in relation to land ownership and development likely to affect land use and pipeline operations.

No complaints from landowners in relation to land use, modifications or infrastructure damage

Records show that landowners are appropriately consulted regarding pipeline activities, which may affect their particular property.

Accurate property and landowner records maintained in conjunction with landowner/ occupier consultation

Achieved Excavations were carried out on the pipeline easement during 2004 to install new zinc anodes. The excavations were conducted in accordance with Epic Energy policies and procedures, ensuring that landholders and affected parties were notified of the intended works.

7. Public Safety – to minimise risks to public and third party health and safety

7.1 To ensure that adequate measures are in place to protect public and third party safety during operations and maintenance activities.

7.2 To ensure that adequate measures are in place to protect public and third party safety during emergency operations.

7.3 To minimise the risk of fire during routine operations

No unauthorised activity on the pipeline easement. Documentation evidence of public safety management and pipeline awareness sessions, in the course of pipeline operations. Adherence to As 2885 demonstrated via annual reports, emergency response reports and Fitness for Purpose reports.[ ref to Petroleum act 2000 ]

No occupational health, safety and welfare incidents or accidents involving third parties.

No fire outbreaks arising from pipeline operations.

Achieved

Achieved

No incidents or accidents accrued on the pipeline system.

All landowners visited during 2004

All reports as per the Petroleum Act 2000 were forwarded to PIRSA



OBJECTIVE GOAL MEASURE/HOW ACHIEVED/NOT ACHIEVED COMMENTS

8. Fugitive Noise Emissions – to minimise noise due to operations

8.1 To ensure that operations comply with noise standards.

No noise related complaints from landowners or third parties. Compliance with legislation requirements of the environmental protection Act 1993 in respect of noise emissions.

Achieved No unplanned gas vented to atmosphere.

9. Waste – to manage all operational wastes in an appropriate manner

9.1 To ensure that all wastes are removed from the site and, re-used, re-cycled or appropriately disposed of.

No waste evident on or off the easement arising from pipeline operations. Documented waste disposal records to confirm appropriate disposal.

Achieved Normal operational waste such as filters are returned to the Dry Creek depot and dealt with accordingly.

10. Right of Way Clearing – to enable unobstructed access for right of way inspection, routine operation, maintenance and emergency access

10.1 To manage identified Aboriginal and European heritage sites in accordance with prescribed procedures.

10.2 To appropriately manage any newly identified heritage sites in accordance with prescribed procedures

Disturbance of native vegetation restricted to right of way. Avoid disturbance to areas of remnant vegetation.

No new weed infestation as a result of pipeline operations.

Achieved

12. Security of supply – to ensure that security of natural gas supplies are maintained to gas consumers

12.1 To minimise the potential for significant disruption of gas supply to customers in line with contractual agreements

No interruption to supply Achieved No interruptions to supply in the Riverland region during the reporting period

13. Easement restoration and infrastructure state – to appropriately decommission the pipeline in accordance with regulatory requirements and accepted best practice environmental management criteria if

13.1 To decommission pipeline and associated infrastructure in a safe and timely manner in accordance with appropriate regulatory requirements To minimise environmental disturbance to remnant vegetation, landholders and third party stakeholders. To restore the natural environment and

Compliance with relevant occupational health, safety and welfare regulatory requirements. Compliance with relevant environmental regulatory requirements

No complaints from landowners and third party stakeholders

Initiation of revegetation or similar

Not applicable in 2004



OBJECTIVE GOAL MEASURE/HOW ACHIEVED/NOT ACHIEVED COMMENTS and when deemed necessary

promote biodiversity (if applicable) restoration works and monitoring programs as required [ if applicable ]

PL6 Annual report 2004 pdf · 2015. 4. 30. · 2004 PL6 ANNUAL REPORT – RIVERLAND PIPELINE ORIGIN...

Documents

Transcript of PL6 Annual report 2004 pdf · 2015. 4. 30. · 2004 PL6 ANNUAL REPORT – RIVERLAND PIPELINE ORIGIN...