Port Campbell to Adelaide Natural Gas Transmission Pipelineenergymining.sa.gov.au/__data/assets/pdf_file/0004/... · Port Campbell to Adelaide natural gas transmission pipeline (PCA)

South East Australia Gas Pty Ltd

Annual Report

South Australian Pipeline Licence (PL 13)

2013 – 2014 Licence Year

Port Campbell to Adelaide

Natural Gas Transmission Pipeline

Annual Report (PL13) – Port Campbell to Adelaide Pipeline

(PCA) 2013 – 2014 Licence Year

Page 2 of 28

TABLE OF CONTENTS

SCOPE........................................................................................................................ 3 1

SUMMARY OF REGULATED ACTIVITIES ....................................................................... 3 2

2.1 Patrol Activities ............................................................................................................. 3

Table 1 – Pipeline Patrol Schedule .................................................................................................. 3

2.2 Operations and Maintenance Activities .......................................................................... 4

Table 2 –Scheduled Maintenance Activities ................................................................................... 4

2.3 Additional Maintenance ................................................................................................ 5

2.4 Cathodic Protection Potential Survey ............................................................................. 5

2.5 Pipeline Location and Referral Services .......................................................................... 6

2.6 Emergency Response and Preparedness ......................................................................... 6

2.7 Training ........................................................................................................................ 7

REGULATORY COMPLIANCE ....................................................................................... 8 3

RECTIFICATION OF NON-COMPLYING ACTIONS .......................................................... 8 4

MANAGEMENT SYSTEM AUDITS ................................................................................ 8 5

5.1 Workplace Health and Safety ........................................................................................ 8

Table 3 - Overview of Audits Conducted During the Licence Year ................................................. 8

5.2 Environmental Rehabilitation ........................................................................................ 9

REPORTS AND DATA .................................................................................................. 9 6

INCIDENTS ................................................................................................................. 9 7

FORESEEABLE THREATS ............................................................................................ 10 8

FACILITY CONSTRUCTION ......................................................................................... 11 9

PROPOSED OPERATIONAL ACTIVITIES 2014 - 2015 LICENCE YEAR .......................... 11 10

VOLUME OF REGULATED SUBSTANCE TRANSPORTED ........................................... 12 11

STATEMENT OF ANNUAL EXPENDITURE ................................................................ 12 12

APPENDIX A – ASSESSMENT OF COMPLIANCE AGAINST SEO OBJECTIVES ........................ 13

APPENDIX B – EASEMENT REHABILITATION SUMMARY ................................................... 21

APPENDIX C – STATEMENT OF ANNUAL EXPENDITURE .................................................... 22

APPENDIX D – REPORTS GENERATED BY LICENSEE DURING REPORTING YEAR ................. 23

APPENDIX E – OVERVIEW OF REPORTABLE INCIDENTS .................................................... 24



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SCOPE 1

South East Australia Gas Pty Ltd (SEA Gas) submits this report to the Department of State

Development (DSD) - Energy Resources Division, in accordance with sub-regulation 33 (1) of the

Petroleum and Geothermal Energy Regulations (SA) 2013, in relation to its operation of the SEA Gas

Port Campbell to Adelaide natural gas transmission pipeline (PCA) during the licence year (1 July

2013 to 30 June 2014, as per approval from the Minister dated 3 June 2004).

This report validates operational compliance along the South Australian portion of the SEA Gas

pipeline in accordance with the SEA Gas Statement of Environmental Objectives (SEO); the

conditions of Pipeline Licence No. 13 and the requirements of the Petroleum and Geothermal Energy

Act (SA) 2000 and regulations under the Act.

SUMMARY OF REGULATED ACTIVITIES 2

During the licence year SEA Gas conducted its operations in accordance with the requirements of the

Petroleum and Geothermal Energy Act (SA) 2000, conditions applicable to Pipeline Licence No. 13,

and Australian Standard AS 2885. There were no non-compliances against the SEA Gas Statement of

Environmental Objectives (SEO) Revision 4, during the licence year. Compliance outcomes are

detailed at Appendix A.

In accordance with sub-regulation 33(2)(a) the following regulated activities were conducted during

the licence year:

2.1 Patrol Activities

Programmed aerial and ground patrols of the pipeline system were carried out during the licence

year (Ref, Table 1).

Table 1 – Pipeline Patrol Schedule

Activity Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun

Weekly Road Patrol

• Pelican Point PRMS to

Williamstown MLV

� � � �

� � � � � � � �

Road Patrols

• Iona PRMS (Vic) to

Williamstown (SA) MLV

� � � �

Aerial Patrols

• Murray Bridge to Pelican

Point (Rotary Wing) PRMS#

� � � � � � � � � � � �

• Iona PRMS to Murray

Bridge (Fixed Wing) � � � � � � � � � � � �

Daily Security Patrols

• Munno Para MLV and

Cavan PRMS

� � � � � � � � � � � �

# The helicopter patrol was transitioned to a fixed wing patrol during January 2014 to be used going

forward.



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Observations arising from patrol activities are actioned in accordance with SEA Gas Fault Action

Request (FAR) procedure.

2.2 Operations and Maintenance Activities

Scheduled and variable maintenance activities were conducted during the licence year (Ref. Table 2)

and reviewed monthly in consultation with maintenance services providers.

Table 2 –Scheduled Maintenance Activities

Activity Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun

Odorant/Gas Sampling &

Analysis

• Cavan PRMS

� � � � � � � � � � � �

Calibrations of Gas

Chromatographs

• Cavan 1 PRMS

• Cavan 2 PRMS

• Torrens Island PRMS

• Quarantine PRMS

• Pelican Point PRMS

Q� Q� Q� Q�

Scraper Stations

• Coomandook

• Pelican Point

A� Q� Q� Q�

Main Line Valves

• Yallamurray,

Coomandook, Pallamana,

Williamstown, Gawler,

Munno Para, Bolivar,

Cavan & Pelican Point

A� Q� Q� Q�

Metering Facilities

• Naracoorte PRMS A� Q� H� Q�

• Jervois PRMS Q� H� Q� A�

• Cavan Q� A� Q� H�

• Torrens Island Q� A� Q� H�

• Pelican Point Q� H� Q� A�

Corrosion Protection

• Potential survey

• Surge protection testing

A�

Coomandook Compressor

Station Maintenance$

• Site inspection

(fortnightly)

� � � � � � � � � � � �

• Scheduled maintenance A� H�

$APA Group conducts fortnightly maintenance and Solar Turbines conducts the balance.



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Q Quarterly Maintenance

Site inspection, heater inspection, Ultrasonic Flow Meter validations & meter run switching,

calibrations of Gas Chromatographs, Cathodic Protection Transformer Rectifier unit checks, smoke

detector checks, soil and weed management, etc.

H Six Monthly Maintenance

As per quarterly maintenance, including water bath heater maintenance at Cavan, Torrens Island,

Pelican Point, Quarantine & electric gas heaters at Dairy Farmers and Teys Brothers.

A Annual Maintenance

As per six-monthly maintenance, inclusive of heater maintenance (spark arrestor, water sample &

ignition system), mechanical maintenance (Main Line Valves, Shut-off Valves, Scrapers, Filters,

Regulators, Pressure Safety Valves, Pressure Valves, Instrument Gas Checks), Electrical Maintenance

(Batteries, Residual Current Devices, Pressure & Temperature Transducers, Solenoids, Meter Run

Switching, Heat Tracing & Hazardous Area Checks), etc.

2.3 Additional Maintenance

The following additional maintenance activities were conducted during the course of the licence

year:

� Overhaul of Flow Control Valve at Cavan 1 PRMS;

� Erosion and subsidence repairs at Williamstown;

� Pigging (gauging and cleaning) of the section of twin DN350 pipelines between the Miakite

and Coomandook Compressor stations in preparation for in-line inspection;

� Overhaul of Pressure Control Valve at Coomandook Compressor Station;

� Extension of platforms surrounding the Coomandook Compressor station;

� Water Bath Heater air inlet filter modifications at Pelican Point and Torrens Island Meter

Stations;

� Internal and External inspections of all pressure vessels;

� Replacement of compressor station package seals at Coomandook; and

� Tapping and plugging of vent stack holes at scraper station vents.

2.4 Cathodic Protection Potential Survey

An annual Cathodic protection potential survey of the PCA and associated laterals occurred during

August 2013. The survey was completed and results assessed in accordance with AS 2885.3:2001

Pipelines – Gas and Liquid Petroleum Part 3: Operation and Maintenance and AS2832.1:2004

Cathodic Protection of Metals Part 1: Pipes and cables.

The survey involved measuring the pipeline potential with respect to a saturated copper/copper

sulphate reference electrode at each test point. The pipeline potential over a 20-hour period was

also recorded at nominally every fifth test point, as required for pipelines subject to the effects of

telluric currents.



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The results of the survey indicated that the PCA and its associated laterals are fully protected in

accordance with the protection criteria defined in Section 2.2 of AS 2832.1.

The survey also indicated that all AC (Alternating Current) surge protection devices installed along

the pipeline were functional and found to be operating normally.

Readings were taken on all corrosion probes and it was identified that the downstream probe at the

Bolivar site required replacement.

The reconnection of the sacrificial anodes originally installed to provide temporary protection during

construction, continues to be successful in reducing the magnitude of voltage variations due to

telluric currents. Consequently these will remain connected to the pipeline.

2.5 Pipeline Location and Referral Services

During the course of the licence year numerous enquiries were received from the free call 1100,

“Dial Before You Dig” asset referral service, for the South Australian section of the PCA. A portion of

these enquiries related to third party work which had the potential to affect the continued safe

operation of the pipeline, triggering further investigation, or an onsite assessment of the proposed

third party activity.

2.6 Emergency Response and Preparedness

During the licence year, SEA Gas undertook the following emergency response exercises:

• Exercise Aotearoa, assessed the continued safe operation of the SEA Gas and Mortlake

pipeline systems while operating from the Backup System Control Centre. The ability to

activate the SEA Gas Emergency Response Plan in response to an incident occurring along

the pipeline system during a building evacuation was also tested;

• Exercise Litoria, assessed emergency response on the Mortlake high pressure gas

transmission pipeline as a result of a pipeline damage scenario during a coating defect

excavation. The resulting activation of the pipeline Emergency Response Plan ensured the

continued safe operation of the Mortlake pipeline system, pending an investigation of the

damage and implementation of a repair strategy; and

• Exercise Timer, assessed out of hours response by SEA Gas personnel, to ascertain how

quickly SEA Gas could realistically resource up in the event of an incident. The exercise

included notification of all personnel in accordance with call escalation processes.

Recommendations arising from these exercises are being addressed and will contribute to the

continuous improvement of the SEA Gas Emergency Response and Crisis Management Plans. The

progress of each action is tracked via the SEA Gas compliance action tracking system.

During the 2014 / 2015 licence year, SEA Gas intends to host:

• A collaborative emergency response exercise with emergency services providers; and

• A collaborative exercise with the Office of the Technical Regulator and Department of State

Development to test processes for managing off specification gas.



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2.7 Training

SEA Gas employees, third-party maintenance services providers and approved contractors

completed the following training during the licence year:

• Accounting and Reporting Update

• Advanced Diploma of Environmental Management Systems

• APA Group – Permit to Work & Job Hazard Analysis (various permit classes)

• Applied Project Management

• Apply First Aid

• Arc GIS 3 – Performing Analysis

• Auditing & Developing Environmental Management Systems

• Cardio Pulmonary Resuscitation (CPR)

• Certificate IV – Gas Industry Operations

• Certificate IV – Gas Supply Industry Operations

• Certificate IV – Pipeline Control

• Certificate IV – Process Plant Technology

• Company Directors Course

• Director War Stories

• Drafting Leaders Workshop 1 & 2

• Driver Education

• Economic & Regulatory Update

• Fringe Benefit Tax

• Graduate Certificate in Occupational Health & Safety

• High Risk Work Licence - Elevated Work Platform

• High Risk Work Licence – Working Safely at Heights

• Implementing and configuring Cisco Identity Service

• Intermediate & Advanced Data Entry

• Leading Strategic Success

• Natural Gas Metering

• Negotiation – Achieving Goals Through Perseverance

• Negotiation – Persuasion

• Negotiation – Planning

• Occupational Health & Safety Law & Risk Management

• Occupational Hygiene & Ergonomics

• Qlikview Designer

• Qlikview Developer

• Role of SafeWork SA

• Solar Turbines Technical Training

• Spill Response

• TapRooT® – Incident Investigation

• Traffic Control Management

• Training Officers – Your Decision Making and Workplace Health and Safety

• White Card - Construction Induction

• Workplace Health & Safety Act



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REGULATORY COMPLIANCE 3

SEA Gas complied with the legislative requirements of the Petroleum and Geothermal Energy Act

2000 and Petroleum and Geothermal Energy Regulations 2013, its Pipeline Licence (PL13) conditions

and its Statement of Environmental Objectives during the licence year.

RECTIFICATION OF NON-COMPLYING ACTIONS 4

SEA Gas has no outstanding actions to rectify non-compliance with the obligations of the Petroleum

and Geothermal Energy Act 2000 and Petroleum and Geothermal Energy Regulations 2013 or the

Pipeline Licence (PL13).

MANAGEMENT SYSTEM AUDITS 5

In accordance with sub-regulation 33(3)(d) SEA Gas has conducted a series of management system

audits to assess and validate its compliance with legislative requirements during the licence year.

Ensuing observations, recommendations and corrective actions were risk assessed and actioned.

5.1 Workplace Health and Safety

SEA Gas conducted audits to assess and validate occupational health and safety compliance against

its Safety & Operating Plan (Safety Case) and applicable legislative requirements, policies,

procedures and contractual requirements. Operational activities (and sites) throughout Victoria and

South Australia were audited, the results of which indicated general compliance and some

opportunities for continuous improvement.

Table 3 - Overview of Audits Conducted During the Licence Year

Audit Scope Auditor Summary of Observations & Actions

WHSE Audits

� Workplace inspections

� Facility WHSE audits (i.e. Naracoorte

Jervois, Cavan 1, Cavan 2, Torrens

Island, Quarantine & Pelican Point

PRMSs; Coomandook compressor

station; and Yallamurray, Pallamana,

Williamstown, Gawler, Munno Para

and Bolivar MLVs).

SEA Gas

• Compliance with relevant Workplace Health &

Safety legislative requirements was achieved.

• Observations related to housekeeping issues and

suggested improvements to reduce workplace

hazards were noted.

• No legislative non-conformances were noted

during the audits.

Contractor Audits

� Six field Audits and five desktop

audits were conducted to assess

compliance with the new SEA Gas

Permit to Work System

� Maintenance Services Provider

(MSP) Field Audits were conducted

SEA Gas

• Contractors were generally found to be

complying with the new Permit to Work System,

although some opportunities to reinforce

particular requirements were noted.

• Procedural changes relating to Personal

Protective Equipment use, calibration of



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Audit Scope Auditor Summary of Observations & Actions

at Cavan 1, Cavan 2 & Coomandook

Compressor Station

� Hydrostatic Test Audit – Bolivar

Lateral

equipment and document management were

instigated in response to audit findings.

• Fittings were replaced, calibration certificates

were validated, signage was improved and test

equipment changes were instigated in response

to audit findings.

Internal Audits

� WHS Regulations (SA) 2012

compliance audit

� APA Group Purchasing & Emergency

Spares Audit (Vic & SA)

SEA Gas

• Gap analysis resulted in recommendations to

improve procedures and some areas of safety

management and training.

• Procedural changes were instigated in response

to audit findings.

5.2 Environmental Rehabilitation

Environmental monitoring of the pipeline easement occurred during the licence year (Refer

Appendix B). During the course of quarterly meetings throughout the licence year, Department of

State Development (DSD) representatives were briefed regarding environmental management

actions.

REPORTS AND DATA 6

In accordance with Regulation 33(3)(e)(ii) the following documentation was submitted to DSD -

Energy Resources Division, in relation to regulated activities conducted by the licensee during the

course of the licence year:

� Pipeline Licence No. 13 - Annual Report for 2012 - 2013 licence year

� Appendix C – Statement of Expenditure, in respect of the 2012 - 2013 Annual Report

� Quarterly incident report (reporting period July – September 2013)

� Quarterly incident report (reporting period October – December 2013)

� Quarterly incident report (reporting period January – March 2014)

� Quarterly incident report (reporting period April – June 2014)

� Safety Case SEA Gas Pipeline System (TECH-PO-001)

� SMS Report – South Australian Section – SEA Gas 5-yearly SMS Workshop

INCIDENTS 7

During the licence year there were no ‘Serious Incidents’ and eight minor ‘Reportable Incidents’;

which despite their minor nature were reported to DSD – Energy Resources Division, in accordance

with Regulation 33(3)(f)(ii). An overview of Reportable Incidents is provided at Appendix E.



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FORESEEABLE THREATS 8

SEA Gas continues to work with developers, local Councils and DSD – Energy Resources Division to

ensure that the licensee assesses the risks of proposed developments along the pipeline system;

ensuring that there is no foreseeable impact to public safety and continued compliance with AS

2885. Design and investigation continued in relation to the use of noise attenuation during pipeline

venting in the vicinity of developed areas. It has been established that the infrastructure required to

achieve safe venting at an acceptable noise level is substantial and work is continuing to assess

alternative options, which include the construction of a new vent at a more suitable location.

SEA Gas continues to implement risk management strategies to minimise the threat to public safety

and the continued safe operation of the pipeline posed by third party unauthorised activities.

Educational and awareness programs for third party activities along the pipeline system remain a

high priority. Where practicable, educational and pipeline safety awareness programs are offered in

conjunction with other asset operators and local Councils.

Landowner contact remained a particular area of focus throughout the licence year. SEA Gas

contacted 99.5% of landowners across the pipeline system (i.e. in SA and Vic) and reviewed activities

being undertaken on the pipeline easement.

During the course of the licence year, SEA Gas carried out the 5 yearly review of the Safety

Management Study for SEA Gas pipeline system.

Risk management activities during the licence year included:

� Aerial and ground surveillance throughout the pipeline system;

� Security patrols and electronic surveillance;

� Permit to Work, Job Safety Analysis, Lock Out & Tagging and Safety Induction Systems;

� Easement Activity Authorisation processes;

� Pipeline and Safety Awareness programmes;

� Planning and Development around Pipelines seminars;

� Safety awareness in community publications;

� Sponsorship of community events to heighten pipeline awareness in regional areas;

� Monitoring of land-ownership and land-use changes;

� Responding to development applications via DSD – Energy Resources Division;

� Emergency stakeholder consultation programme;

� Participation in SA Engineering Functional Service Committee;

� Participation in pipeline industry operations forums;

� Subscription to the 1100 ‘Dial Before You Dig and Dig Safe (internet based) asset information

and referral systems;

� Five yearly Safety Management Study Review; and

� Overpressure Protection Review.



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FACILITY CONSTRUCTION 9

During the licence year SEA Gas constructed a 416m long, 114mm (Outside Diameter) steel pipeline

lateral and a Pressure Reduction Metering Station (PRMS) to supply natural gas to the Bolivar Waste

Water Treatment Plant (WWTP) Power House at Bolivar, South Australia. The lateral pipeline is

connected to the SEA Gas pipeline at an existing underground DN 100 offtake connection at KP

664.28 and was commissioned during August 2014.

PROPOSED OPERATIONAL ACTIVITIES 2014 - 2015 LICENCE YEAR 10

In accordance with Regulation 33(3)(h), SEA Gas proposes to conduct the following operational

activities during the 2014 / 2015 licence year:

� Scheduled maintenance of pipeline facilities and infrastructure;

� Scheduled aerial and ground patrols of the pipeline easement;

� Monitoring of cathodic protection systems including testing of buried corrosion probes;

� Final validation audit of environmental rehabilitation sites along the pipeline easement in

SA;

� Pipeline awareness seminars for contractors, emergency services, utilities and safety critical

stakeholders;

� In-line inspection of the section of twin DN350 pipelines between the Miakite and

Coomandook Compressor stations;

� Direct inspections of the pipeline to validate data from in-line inspection reports;

� Coomandook Compressor guide vane actuation and enclosure heater installation;

� Refurbishment of Coomandook compressor after cooler fan motors;

� Upgrade of Coomandook enclosure fire and gas fire system controller.

� Design of a pipeline vent noise attenuator;

� Coomandook Compressor Station access road maintenance;

� Overhaul of flow control valves at Cavan and Pelican Point Meter Stations;

� Modification of gas chromatograph huts to enable unimpeded safe access to the rear of

each unit at Cavan 1 & 2, Torrens Island and Pelican Point PRMS facilities;

� Modification of inlet air filters at the Pelican Point PRMS facility to improve filter accessibility

and reduce the likelihood of injury;

� Upgrade to ‘DanielTM New Gen Electronic Mark III’ ultrasonic flowmeters at Cavan 1 and 2,

Torrens Island and Pelican Point PRMS facilities; and

� Installation of pipe racks for certified emergency spare pipe at the Coomandook Compressor

Station.



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VOLUME OF REGULATED SUBSTANCE TRANSPORTED 11

In accordance with Regulation 33(3)(k), the volume of regulated substance (i.e. natural gas)

transported by SEA Gas during the course of the 2013 / 2014 licence year was approximately 46.4 PJ

(exclusive of gas deliveries into the SESA pipeline system).

STATEMENT OF ANNUAL EXPENDITURE 12

In accordance with Regulation 33(4), information relating to SEA Gas’ expenditure 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).

A statement of expenditure is detailed at Appendix C (Restricted Distribution) and is provided under

separate cover.



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APPENDIX A – ASSESSMENT OF COMPLIANCE AGAINST SEO OBJECTIVES

Statement of Environmental Objectives - Operational Environmental Objectives & Compliance Outcomes

Environmental

Aspect

Potential Impacts SEO Objective Compliance Outcomes

Soils and Terrain � Erosion and sedimentation

� Soil inversion

� Soil compaction

� Soil contamination

� Disturbance to significant

geological features

� Trench subsidence

11. To maintain soil stability

along the easement

• No un-remediated soil erosion or subsidence along the pipeline easement

� Soil erosion due to a heavy rainfall event along a steeply sloping

hillside at Williamstown was repaired in consultation with landholders

during the licence year. Repairs included stabilisation of a creek

crossing, maintenance to blocked drains, installation of berms and

direct seeding.

• Pipeline operations do not enhance soil erosion on the easement

� Pipeline operations did not contribute to soil erosion during the licence

year.

• Vegetative cover is consistent with surrounding land.

� Pipeline operations contributed to the enhancement of vegetative

cover over the easement as a result of revegetation activities.

• No evidence of sub-soil in surface

� There were no excavation activities during the licence year which

resulted in the deposition of sub-soil along the easement.

• No visual evidence of soil compaction

� There was no observed evidence of soil compaction along the

easement, nor any related complaints received during the licence year.

• No evidence of likely acid sulphate soil exposure

� There are no known acid sulphate soil sites along the pipeline

easement.



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Environmental

Aspect


• Surface contours along the easement are consistent with adjoining land

� Installation of berms along the easement at Williamstown has

improved the stability of the easement by reducing erosion potential

and improving vegetative cover.

• Alternation of surface contours are initiated in consultation with stakeholders

� Installation of berms was implemented in consultation with

landholders, inclusive of maintenance to off easement drainage to

improve drainage across the easement.

Water Resources � Contamination of

groundwater

� Disruption to surface

drainage patterns

� Disruption to third party

use of surface waters

12. To minimize and manage

impacts to water resources

• Drainage along the easement is maintained to pre-existing conditions or better

• Surface drainage profiles are restored following maintenance activities.

• No reasonable complaints received from Stakeholders in relation to use of

surface waters

� During the course of the licence year, operational activities did not

impact upon groundwater quality.

� No complaints were received in relation to any environmental impacts

during the licence year.

� Previously completed rehabilitation along the easement, including re-

vegetation of riparian zones and installation of sedimentation traps,

has resulted in improved water quality due to improved stability.

Land and Water

Emissions

� Land and water

contamination

� Disruption to third party

use of surface waters

13. To effectively manage

spill prevention and to respond

to spill events to minimize their

impact

• No spills or leaks in other than areas designated to contain spills

� There were only very minor spill incidents (i.e. <2 litres) reported (Refer

Appendix E). The impact of spills was minimised by spill response, all

spills were immediately cleaned up and waste material disposed to

landfill.

• No waste on easement, at other than designated storage areas within facilities,

pending disposal



Page 15 of 28

Environmental

Aspect


• Waste is disposed of in accordance with approved protocols

� Operational waste is not stored on the easement and is temporarily

stored within designated areas at facilities, prior to collection by licensed

waste collection providers.

� SEA Gas recycles operational and office wastes were appropriate.

• Wastewater meets appropriate ANZECC criteria at point of discharge and is

disposed onto land, well away from any place from which it is reasonably likely to

enter any waters

• No evidence of impacts to soils, water and vegetation as a result of water

disposal

• Waste water complies with the requirements of Public and Environmental Health

(Waste Control) Regulations 1995

� Waste water from hydrostatic testing of the Bolivar lateral was

appropriately disposed of by SA Water.

Vegetation and

Fauna � Removal of remnant

vegetation

� Spread of ecological

weeds

� Spread of pathogens

14. To minimise adverse

impacts to vegetation and

native fauna and livestock

• Species abundance and vegetative cover along the easement to be as near as

practicable to adjoining areas in accordance with site specific management

criteria

� Revegetation activities during the licence year enhanced species

abundance and biodiversity along the easement.

• No reasonable complaints received from landholders or third party users in

relation to adverse impacts to vegetation, native fauna or livestock

� No complaints were received during the licence year.

• Trimming of native vegetation to be restricted to the minimum necessary to

ensure line of sight between pipeline marker posts

� Vegetation trimming was restricted to line of sight maintenance along

the pipeline easement to ensure compliance with AS 2885.



Page 16 of 28

Environmental

Aspect


• Vegetation management within the easement or on adjacent land to the

easement is limited to previously disturbed areas unless regulatory approval has

been obtained

� Vegetation management has continued to be consistent with stated

rehabilitation guidelines. DSD – Energy Resources Group representatives

will be invited to accompany SEA Gas during an audit of revegetation

sites in SA during the 2014/2015 licence year.

• Clearing (other than originally approved) of remnant vegetation to be avoided

unless approved.

� No vegetation clearing was conducted during the licence year.

• Native fauna, flora and livestock impacts associated with maintenance activities

to be restricted to As Low As Reasonably Practicable.

� There were no observed impacts to native flora, fauna or livestock

arising from operational activities, during the licence year.

Weeds and

Pathogens � Spread of noxious weeds

and pathogens

15. To prevent the

introduction and spread of

weeds and pathogens

• Presence of weeds and pathogens on the easement is consistent with or better

than adjoining land

� Weed management strategies continued to be implemented at facilities

and along the easement .

• No new outbreaks or spread of weeds or pathogens

� There were no reported or observed new outbreaks of weeds or

pathogens during the licence year.

• No reasonable complaints received from landholders in relation to outbreaks or

spread of weeds or pathogens

� No complaints were received during the licence year in relation to weeds

or pathogens.



Page 17 of 28

Environmental

Aspect


• Maintenance records, facility inspections and audits

� All South Australian Facilities were audited during the licence year and

weed management was found to be generally acceptable.

Cultural and Historic

Heritage � Damage to shallow

artefact scatters

� Damage to significant

vegetation (for example

scarred trees)

� Disturbance to smaller

scattered items occurring

on or immediately below

the land surface as a

result of earthworks

16. To adequately protect

heritage and culturally sensitive

sites and values during

operational activities

• No impact to identified sites without prior approval in accordance with

applicable legislative requirements

� There were no impacts to any cultural heritage sites as a result of any

operational activities.

• Newly identified sites are reported and managed appropriately

� No new cultural heritage sites were identified during the licence year.

Noise Emissions � Generated operations

noise may disturb people,

stock and wildlife in the

immediate area

17. To minimise noise

impacts that may arise from

operational activities

• Compliance with EPA noise abatement guidelines

� Operational activities continued to comply with noise abatement

guidelines during the licence year.

� There were no operational activities that impacted upon the EPBC listed,

south-eastern Red-tailed Black Cockatoo breeding habitat, during the

licence year.

� SEA Gas continues to work with developers, to design a suitable noise

attenuator to be installed at the Gawler MLV, or an alternative venting

site, in response to residential encroachment.

• No reasonable complaints received in relation to noise abatement issues




Page 18 of 28

Environmental

Aspect


Atmospheric

Emissions � Generation of dust from

the easement and access

tracks

� Minor reduction in air

quality resulting from

vehicle emissions

� Release of Greenhouse

Gas Emissions from

Compressor Station

18. To minimise

atmospheric emissions

• No uncontrolled atmospheric emissions.

� There were no uncontrolled atmospheric emissions in other than areas

specifically designed to contain a gas escape.

� SEA Gas continues to report Scope 1 and Scope 2 Greenhouse Gas

Emissions.

� Following consultation with the SA EPA, the SEA Gas Coomandook

Compressor Station is now licenced (Licence No. 43402) for fuel burning

at a rate of heat release exceeding 5 megawatts.

• No reasonable complaints received in relation to dust management issues


Disturbance to third

party infrastructure,

landholders and

modified land use

� Adverse effects to

agricultural productivity

or other primary

production activities in

long term

� Disruption to important

land use periods (that is,

calving, lambing,

breeding, sowing,

harvesting or recreation)

� Spread of noxious weeds

and diseases

� Disruption to

conservation,

recreational, industrial or

other third party land use

activities

� Disruption or damage to

roads and other transport

19. To minimise disturbance

to third party infrastructure,

landholders and land use

• Where disturbance is unavoidable or accidental, infrastructure or land use is

restored to as near as practicable to the satisfaction of stakeholders

� There was no disturbance to any third party activities during the licence

year.

• No disturbance outside the easement or approved access and work areas

without prior consultation.

� In consultation with landholders, maintenance activities were restricted

to agreed sections of the pipeline easement and within facility

boundaries.

• Duration of disturbance does not exceed agreed timeframes without prior

consultation.

� In consultation with landholders, maintenance activities did not exceed

agreed timeframes.

• No reasonable complaints received in relation to disturbance




Page 19 of 28

Environmental

Aspect


infrastructure or networks


utility services


private infrastructure

• Pre-existing land use not restricted or impeded as a result of maintenance

activities unless by prior arrangement

� Pre-existing land use was not restricted or impeded as a result of

operational or maintenance activities.

� SEA Gas continues to work with developers, local Councils and DSD, in

response to proposed developments in close proximity to the pipeline

system.

• No unauthorized disturbance to third party utilities or infrastructure

� Pipeline operations and maintenance activities did not result in any

disturbance to third party utilities or infrastructure during the licence

year.

• No reasonable complaints received in relation to unauthorized disturbance of

third party utilities or infrastructure


• Vegetation cover along the easement to be as near as practicable to adjoining

areas in consultation with stakeholders

� Environmental restoration activities implemented in consultation with

affected stakeholders has resulted in vegetative cover along the

easement which exceeds that of the adjoining areas.

Risk to public health

and safety � A threat to the pipeline

can be assumed to include

any element which can

potentially cause pipeline

failure, including threats

due to location (including

crossing and land use

segments) and general

threats common to the

entire system (for

20. To minimise the risk to

public health and safety

• No injuries or incidents involving members of the public

� There were no injuries or incidents involving members of the public

during the course of the licence year.

• No fires as a consequence of maintenance activities

� Operations and maintenance activities did not result in any fires during

the licence year.



Page 20 of 28

Environmental

Aspect


example, corrosion) • No unauthorized activity on the easement that has the potential to impact on

integrity

� There were two reports of unauthorised activity on the easement (Refer

Appendix E). Neither activity impacted the integrity of the pipeline.

• Emergency response and crisis management tools applied to mitigate emergency

management risks; and to minimise likely incident impacts

� Emergency response and crisis management tools were applied

operationally during the licence year during scheduled emergency

response exercises (Refer Section 2.6).

• Effective management of emergency incidents

� There were no incidents which required activation of the SEA Gas

Emergency Response Plan during the licence year.



Page 21 of 28

APPENDIX B – EASEMENT REHABILITATION SUMMARY

SEA Gas continued to conduct environmental maintenance activities along the pipeline system,

including:

� vegetation management to ensure unobstructed line of sight of above ground pipeline

marker signage and cathodic protection test posts along the easement at various sites; and

� erosion stabilisation and revegetation along the easement at Menzel Road, Williamstown,

(MD 616.5) following a high rainfall event.

No further Sustainable Environmental Benefit (SEB) activities were conducted during the licence

year.



Page 22 of 28

APPENDIX C – STATEMENT OF ANNUAL EXPENDITURE

Distribution of the Statement of Annual Expenditure is limited to the Department of State

Development – Energy Resources Division, in accordance with Regulation 33(4).

Information relating to SEA Gas expenditure 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).



Page 23 of 28

APPENDIX D – REPORTS GENERATED BY LICENSEE DURING REPORTING YEAR

In accordance with sub-regulation 33(3)(e)(i) of the Petroleum and Geothermal Energy Regulations

(SA) 2013, the following reports were generated by the licensee, during the license year.

These reports relate to the operation of the PCA in accordance with the Petroleum and Geothermal

Energy Act (SA) 2000.

Report Title Issued By Date Issued

April – June 2013 Quarterly Report SEA Gas July 2013

Annual Report (PL13) – 2012/2013 Licence Year SEA Gas August 2013

July – September 2013 Quarterly Report SEA Gas October 2013

Cathodic Protection (CP) Survey APA Group (Vic) October 2013

October – December 2013 Quarterly Report SEA Gas January 2014

January – March 2014 Quarterly Report SEA Gas April 2014

Safety Case SEA Gas Pipeline System (TECH-PO-

001)

SEA Gas February 2014

SMS Report – South Australian Section – SEA Gas

5-yearly SMS Workshop

SEA Gas June 2014



Page 24 of 28

APPENDIX E – OVERVIEW OF REPORTABLE INCIDENTS

Incident

Date &

SEA Gas

Ref. No.

Approx.

MD

DSD Incident

Classification

Root Causes Corrective Actions Status

26 Aug 13

12930

645.7 Work

Practices

During the course of a site inspection an oily stain was noted on

a patch of gravel within the compound, in the near vicinity of

the Schaffer gas over oil actuator. A subsequent investigation

revealed that an oily mist had been discharged onto the gravel

during venting of the cavity on the main line valve.

� The major causal factor attributed to this incident was

design, as the vent points for the MLV do not cater for

liquids to be captured. Small amounts of liquids can

become trapped in the MLV cavity. The liquids are likely

to be from minor leakage of compressor seals. There was

also an oversight by the maintenance personnel to clean

up the spill, which is standard operating practice.

� The stained gravel was removed from the site

and disposed to landfill.

� Design modifications are being considered to

allow capture of any liquids when venting

MLVs.

Closed

17 Sep 13

13701

293.043 Work

Practices

During the course of a landholder liaison visit by SEA Gas

personnel, the landholder indicated that he had recently crossed

the pipeline easement with a ripper to install a 32mm diameter

irrigation pipeline to a depth of 400 mm, without seeking

approval from SEA Gas. The separation distance from the twin

350mm diameter SEA Gas pipelines at the crossing point was

confirmed following a site assessment to be 1,000mm.


‘work practices’. There was an oversight by the

landholder to contact SEA Gas or request a ‘Dial Before

You Dig’ asset location referral (as he had done on

numerous past occasions), due to time constraints

associated with the loan of his neighbour’s ripper and a

� SEA Gas has completed an on-site investigation

of the foreign crossing site, and has confirmed

a separation distance of 1,000mm and no

damage to its assets.

� The foreign crossing has been detailed on

alignment drawings for future reference.

� Correct procedures for conducting third party

work on the pipeline easement were re-

affirmed to the landholder, by the SEA Gas

Land Liaison Officer and Maintenance Systems

and Land Officer during a site visit.

Closed



Page 25 of 28

Incident

Date &

SEA Gas

Ref. No.

Approx.

MD

DSD Incident

Classification


break in the weather.

� The landholder acknowledged that he had not followed

the correct process and apologised for conducting work

on the pipeline easement without prior notification and

indicated that he would take more care in the future.

Note: this landholder has notified SEA Gas of work on the

easement in the past and has contacted SEA Gas at least three

times during 2013, when conducting work along the easement.

23 Sep 13

6762

Near Miss

397 Work

Practices

During a scheduled easement patrol, a SEA Gas patrol officer

observed that existing fence posts had been removed from the

easement and a fencing contractor was installing a new fence

and working towards the easement. An investigation revealed

that no ‘Dial Before You Dig’ enquiry had been requested and

nor was any prior contact made (or likely to be made) with SEA

Gas prior to commencing work.

Upon investigation it was discovered that a new fence post

would have been installed close to one of the twin 350mm

diameter pipelines on the easement.


‘work practices’. There was an oversight by both the

landholder and the fencing contractor who did not

contact SEA Gas or request a ‘Dial Before You Dig’ asset

location referral.

� Both parties had assumed that the other had initiated the

appropriate approvals prior to commencing work.

� Both the landholder (reaffirming previous

communications) and the fencing contractor

were advised in relation to the correct process

to be adopted when intending to carry out

work on the pipeline easement.

� Correspondence was sent to both parties,

including pipeline awareness material.

� A SEA Gas Land Liaison representative visited

the landholder.

Closed



Page 26 of 28

Incident

Date &

SEA Gas

Ref. No.

Approx.

MD

DSD Incident

Classification


06 Nov 13

1347

Bolivar

Lateral

Work

Practices

While filling a diesel generator the operator over filled the fuel

tank, resulting in the spillage of 1 - 2 litres of diesel oil onto the

ground.

The contaminated soil was cleaned up and disposed to landfill,

immediately following the incident.


‘Work Practices’ due to inattention while filling the fuel

tank, compounded by the absence of a bund to contain

any spillage.

� Diesel spill was cleaned up and disposed to

landfill;

� A spill tray was installed beneath the

generator.

Closed

12 Nov 13

4258

682.7 Work

Practices

During repeated closing/opening of the Shafer actuator controls

for maintenance purposes, an oily mist was vented from the

Shafer exhaust port tubing.

The oily discharge (<1 litre) sprayed over the surrounding

pipework and gravel, requiring immediate clean-up following

the incident. Waste material was disposed to landfill.


‘design’, as the actuator vent ports do not capture liquid

discharges. Maintenance personnel responded by

cleaning up the spill, in accordance with standard

operating procedures.

� Oily residue over pipework was cleaned up;

� Stained gravel was removed from the site and

disposed to landfill;

� The ‘poppet’ block control unit is to be

replaced and the valve actuator operation will

be retested; and

� Maintenance procedures will be modified to

minimise valve actuations and the likelihood of

oily mist discharge.

In Progress



Page 27 of 28

Incident

Date &

SEA Gas

Ref. No.

Approx.

MD

DSD Incident

Classification


29 Nov 13

12059

685 Work

Practices

While testing operation of the Shafer actuator on the Main Line

Valve 12 to investigate oily discharge from the exhaust port

tubing, an oily mist was vented after several open/close

operations, resulting in some oil dripping onto the ground and

onto surrounding pipework.

The pipework was wiped down and approximately 500ml of oily

discharge to ground was cleaned up, requiring the removal of

some gravel and soil to landfill.






� Oily residue over pipework was cleaned up;

� Stained gravel was removed from the site and


� The ‘poppet’ block control unit is to be

replaced and the valve actuator operation will

be retested; and

� Maintenance procedures will be modified to



In Progress

13 Jan 14

9023

Bolivar

Lateral

Work

Practices

Approximately 1.5 litres of hydrostatic test water spilled to

ground as a result of a leaking hose connection between the

vacuum truck and a 2 inch socket on the test header.

The contaminated soil was cleaned up and disposed to landfill,

immediately following the incident.


‘design’, as there should have been a bund beneath hose

connections to contain any spillage.

� Hydrostatic test water spill was cleaned up and


� Hose connection was tightened and a spill tray

was installed beneath the connections.

Closed



Page 28 of 28

Incident

Date &

SEA Gas

Ref. No.

Approx.

MD

DSD Incident

Classification


13 Mar 14

13001

Quarantine

PRMS

Work

Practices

While conducting scheduled quarterly maintenance at the

Quarantine Meter Station an Emergency Shut Down (ESD)

function check was conducted, requiring actuation of the

station inlet valve. Following remote actuation of the valve, an

oily mist was vented, with some oil deposited on the ground.

The incident was reported to SEA Gas System Control and the

contaminated soil was cleaned up and removed from site for

disposal to landfill.






� Oily residue and soil was cleaned up for offsite

disposal to landfill;

� The ‘poppet’ block control unit has been

replaced and the valve actuator operation

retested resulting in no oily discharge;

� A trial is being conducted to establish if

draining the vent line prior to valve actuation

minimises the risk of oily discharge during

valve actuation for maintenance purposes; and

� Modification of maintenance procedures to



In Progress

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