Environment Report - Santos

Environment Report 

Casino Gas Field Development 

May 2004



May 2004 

CR 1086_ 7_v2 

Prepared by: Enesar Consulting Pty Ltd 

124 Camberwell Road Hawthorn East Victoria Australia 3123 

p 61-3-9882 3555 f 61-3-9882 3533 

e office@enesar.com.au www enesar.com.au

Preface 

The Casino Gas Field Development requires approval under the Commonwealth Petroleum (Submerged Lands) Act 

1967, the Victorian Petroleum (Submerged Lands) Act 1982 and the Victorian Pipelines Act 1967. This Environment 

Report (ER) has been lodged in support of an application for a Pipeline Permit under the Victorian Pipelines Act 1967. 

Public Display and Availability of the ER 

Copies of the ER will be on display and available during the exhibition period for public review at the following locations: 

Department of Sustainability and Environment, Customer Information Centre 

Nauru House, 80 Collins Street, MELBOURNE, Victoria 3000 

Department of Primary Industries, Minerals and Petroleum Reference Centre 

Level 8, 240 Victoria Parade, EAST MELBOURNE, Victoria 3002 

Port Campbell Visitor Information Centre 

26 Morris Street, PORT CAMPBELL, Victoria 3269 

Corangamite Shire Civic Centre 

181 Manifold Street, CAMPERDOWN, Victoria 3260 

Department of Sustainability and Environment 

78 Henna Street, WARRNAMBOOL, Victoria 3280 

Department of Sustainability and Environment 

83 Gellibrand Street, COLAC, Victoria 3250 

Electronic copies may be downloaded from the Santos website at: http//:www.santos.com.au. 

Queries and requests for hard copies or electronic copies on CD should be directed to: 

Catriona McTaggart, Casino Environmental Adviser 

Santos Ltd, GPO Box 2319, ADELAIDE, South Australia 5001. Telephone: 08-8224 7894 

Opportunity for Public Comment on the ER 

The ER provides a basis for the public to comment on the proposal, the environmental impacts and proposed mitigation 

measures. 

Public submissions will be considered by the Department of Primary Industries (DPI) in accordance with the Victorian 

Pipelines Act 1967. 

Lodging a Submission 

In your submission, you will need to: 

• Identify the proposal on which you are commenting and provide your name and address. 

• Where relevant, identify any special interest you have in the proposal. 

• If you are commenting on specific text within the ER, mention the section number and heading used in the ER. 

Written submissions should be sent to: 

Phil Roberts, Director, Minerals and Petroleum Victoria 

Department of Primary Industries, PO Box 500, EAST MELBOURNE, Victoria 3002 

Deadline for Lodging a Submission 

Written submissions must be received by close of business 30 days after the date of the pipeline permit application 

public notice. 

Further Information 

Further information regarding the Casino Gas Field Development can be obtained by contacting Catriona McTaggart 

(details above).

Executive Summary 


1. Introduction 

Project and Proponent 

Santos Ltd (Santos) proposes to develop 

the Casino gas field approximately 30 

km offshore from Port Campbell on Victoria’s 

southwest coast. The Casino Gas 

Field Development is a AUD$200 million 

project and comprises subsea installations 

and pipeline development that will 

carry gas from offshore wells to an existing 

TXU gas processing facility near Port 

Campbell. 

Joint venture partners in the Casino Gas 

Field Development with Santos (50% interest), 

include Peedamullah Petroleum 

Pty Ltd (Australian Worldwide Exploration 

Limited) (25% interest) and Mitwell 

Energy Resources Pty Limited (Mitsui & 

Co. (Australia) Ltd) (25% interest). 

Project Justification 

The demand for natural gas is increasing 

steadily. Santos, as operator of the 

Commonwealth exploration permit area 

Vic/P44, is obliged to explore for petroleum 

resources and, if feasible, develop 

any discovered resources to meet consumer 

demand. 

Gas from the Casino gas field is earmarked 

for use by Victorian consumers 

during 2006 as a supplement to existing 

Victorian gas reserves catering for the 

predicted increase in demand. In the 

medium-term and longer-term, the gas 

will be available for distribution into the 

Victorian and South Australian gas markets 

but the gas may also be temporarily 

stored in depleted underground gas reservoirs, 

awaiting withdrawal during periods 

of peak demand. 

Other potential benefits of the project 

include: 

• Employment opportunities. 

• Direct and indirect commercial benefits. 

• Provision of an alternative independent 

supply of gas to supplement existing 

gas reserves and further 

improve security of supply and reliability. 

• Increasing inter-basin competition 

between gas producers. 

• Increased use of the TXU gas 

processing and storage facility. 

• Potential for reduction in greenhouse 

gas emissions (compared to the use 

of alternative fossil fuels). 

Regulatory Framework 

The proposed Casino Gas Field Development 

falls within three jurisdictions including 

Commonwealth and Victorian 

waters and onshore Victoria. Consequently, 

permits and licences are required 

respectively under the 

Commonwealth Petroleum (Submerged 

Lands) Act 1967, the Victorian Petroleum 

(Submerged Lands) Act 1982 and 

the Victorian Pipelines Act 1967. 

The Minister for Planning has determined 

that the magnitude and significance of 

potential impacts would not necessitate 

the preparation of an environment effects 

statement. Accordingly, this Environment 

Report has been prepared in 

support of the pipeline permit application 

under the Pipelines Act 1967 and is available 

for public review and comment. 

In December 2003, the project was determined 

to be a controlled action under 

the Environment Protection and Biodiversity 

Conservation Act 1999 (EPBC 

Act) based on the lack of certainty in 

construction timing and pipeline alignments 

and therefore potential impacts 

upon blue whales, and to a lesser degree, 

listed terrestrial flora and fauna. 

The subsequent Commonwealth environmental 

assessment under the EPBC Act 

has been undertaken through separate 

documentation, i.e., Preliminary Documentation. 

Stakeholder Consultation 

Santos has been consulting with relevant 

stakeholders on an ongoing basis since 

2000 when they commenced exploration 

and production activities in southwest 

Victoria. With the proposed Casino Gas 

Field Development, Santos embarked on 

a consultation program that focused on 

stakeholders potentially affected by the 

project, in particular landowners and 

commercial fishers, but also local interest 

groups. Information from stakeholders 

has been used to enhance the design 

and operation of the project. 

Stakeholder consultation will continue 

through the approvals process and the 

detailed design, construction, operation 

and decommissioning phases of the 

project. 

2. The Project 

Overview 

The Casino gas field was discovered in 

September 2002. It contains estimated 

recoverable reserves of 211 billion cubic 

feet (bcf) of natural gas and has an expected 

field life of up to 12 years. The 

Casino Gas Field Development comprises 

the offshore production of gas and 

its transportation to shore in a dedicated 

pipeline to the existing TXU Western 

Underground Gas Storage (WUGS) facility 

at Iona near Port Campbell for 

processing (Figure 1). Specifically, the 

development comprises: 

• Drilling two offshore development 

wells. 

• Installation of wellheads on the seafloor. 

No structures will be visible from 

shore. 

• Installation of a subsea pipeline and 

control umbilical (each approximately 

36.7 km long) on the sea floor to 

transfer gas from the wells to shore. 

• Horizontal directional drilling (HDD) 

of the shore crossing from farmland 

outside the Port Campbell National 

Park. 

• Construction of a buried onshore 

pipeline (11.5 km in length) from the 

HDD shore crossing to the TXU 


v


TXU WUGS 

facility 

Raw gas pipeline 

HDD pipeline section 

Optic fibre cable 

MEG pipeline 

Umbilical line 

Mainline valve site 

Onshore pipeline 

(11.5 km) 

HDD shore crossing 

(1.6 km) 

Casino 5 

Casino 4 

Subsea pipeline and control umbilical 

(36.7 km) 

2 subsea wells 

Figure 1 

Casino Gas Field Development schematic 

WUGS facility. A mainline valve site 

will be located in farmland near the 

coast. 

• Processing of the gas by TXU at the 

WUGS facility prior to distribution to 

Victorian and interstate customers 

through the existing pipeline network. 

The raw gas has very low carbon dioxide 

content (less than 1%) and no detectable 

sulfur oxides or nitrous oxides, and 

is therefore within sales gas specifications. 

Small quantities of liquids, including water 

and condensate may be transported 

to shore with the gas and these will be 

removed at the TXU WUGS facility. Condensate 

will be transported to an existing 

refinery by road tanker (estimated at 

two or three trucks per week for the first 

two years, then delcining to about one 

per week thereafter). 

Pipeline Route Selection 

Santos has implemented a pipeline route 

selection process that considered social, 

environmental, engineering and financial 

criteria. Foremost in this process was 

the desire to find a pipeline alignment 

that is acceptable to local landowners. 

The key phases in the route selection 

process were: 

• Shore crossing site. 

• Offshore pipeline alignment. 

• Onshore pipeline alignment. 

Shore Crossing. The selection of the 

preferred option for the shore crossing 

was the primary determinant in the overall 

alignment of the pipeline from the 

Casino gas field to the TXU WUGS facility. 

Following preliminary engineering and 

environmental assessments and consultation 

with key stakeholders, Santos identified 

Two Mile Bay as the preferred shore 

crossing location (Figure 2). Key benefits 

of this location are: 

• The consolidation of shore crossings 

for the Minerva, Otway and Casino 

gas fields to one area. 

• From the HDD site, it is possible to 

locate the offshore pipeline route in 

predominantly sandy seabed, thereby 

avoiding nearshore reef habitat and 

minimising impacts on offshore reefs 

and commercial fishing grounds. 

Santos proposes to locate the HDD site 

outside of the Port Campbell National 

Park to the west of BHP Billiton’s Minerva 

Project HDD site. The drill will then extend 

beneath the surface of the Port 

Campbell National Park (but through the 

park, as tenure extends to the centre of 

the earth) to exit approximately 1,225 m 

offshore, beyond the surf zone and 

nearshore reef habitat, at approximately 

the 15 to 16 m water depth. The total drill 

length would be 1,573 m. 

Offshore Pipeline. Having selected Two 

Mile Bay as the preferred shore crossing 

site, it was necessary to verify that the 

offshore seabed conditions were suitable 

for a pipeline. Preliminary bathymetric 

data obtained from Santos’ earlier 

seismic exploration survey and published 

seabed mapping identified several areas 

of potentially problematic seafloor 

features. Commercial fishers later confirmed 

the existence of these features. 

Santos consequently selected an align- 

vi 

Casino Gas Field Development


640 000 650 000 660 000 670 000 

AUSTRALIA 

VICTORIA 

Flaxman's Hill 

North Paaratte 

Gas Plant 

Heytesbury 

Gas Plant 

Proposed 

Otway Gas 

Project Plant 

Lovers Nook 

Campbells Creek 

Curdies 

Inlet 

Peterborough 

N 

VICTORIA 

Melbourne 

N 

NEW SOUTH WALES 

Tasman 

Sea 

Minerva Gas 

Plant 

10m 

20m 

30m 

Bass Strait 

0 km 

100 

Port Campbell 

40m 

Newfield Bay 

HDD shore 

crossing site 

50m 

Two Mile Bay 

TXU WUGS 

Facility 

60m 

Minerva Pipeline 

N 

0 km 5 

70m 

Map projection: AMG, ADG 66 Zone 54 

Minerva 

Gas 

Well 

Proposed Otway gas pipeline 

Bay of Islands Coastal Park 

Peterborough Coastal Reserve 

Port Campbell National Park 

Preferred Casino pipeline alignment 

HDD section 

Existing gas pipeline 

Proposed Otway Gas pipeline 

Casino gas reservoir 

Gas well 

Bathymetry 

Casino 5 Casino 6 

Casino 4 

Figure 2 Casino Gas Field Development pipeline alignment 

5 710 000 5 720 000 5 730 000 


vii


ment from the Casino gas field to the 

preferred shore crossing location that 

would traverse predominantly sandy seabed, 

thereby avoiding nearshore reef 

habitat and minimising impacts on offshore 

reefs and commercial fishing 

grounds. 

Santos then commissioned a bathymetry 

survey so that these features could 

be characterised and precisely located 

and a subsea pipeline route could be 

selected that avoids these features, 

where practicable (Figure 3). 

Onshore Pipeline. Santos investigated 

several potential onshore pipeline route 

options aimed at identifying an alignment 

that met environmental, social and technical 

criteria. 

The preferred onshore pipeline alignment 

was selected to traverse farmland and 

avoid remnant native vegetation, minimise 

impacts to farm operations and future 

land development, avoid highly 

unstable terrain in the Campbells Creek 

valley and cross Campbells Creek adjacent 

to existing pipeline easements. Following 

minor realignment to follow 

fencelines, the preferred alignment received 

in-principle agreement from 

landholders, subject to the negotiation of 

easement agreements. The preferred 

onshore pipeline alignment follows existing 

easements or fence lines for approximately 

90% of its 11.5 km length. 

Figure 4 shows the route traversed by 

the preferred onshore pipeline alignment 

and illustrates the typical land uses along 

the preferred pipeline route. 

Construction 

Construction is scheduled to commence 

in January 2005 to enable commercial 

operation and first gas by January 2006. 

Offshore drilling and completion of the 

two wells will take approximately two to 

three months. Mobilisation of the drill rig 

is scheduled for January 2005 to enable 

commencement of drilling in late January/early 

February 2005. 

The offshore pipeline will be installed by 

either pipelay barge or pipe reel-lay vessel 

and is scheduled to commence in 

November 2005 and take approximately 

20 days, subject to weather conditions. 

The installation of the shore crossing is 

expected to take about seven months, 

and is scheduled to take place between 

January and July 2005. This incorporates 

setting up the HDD site, mobilising 

equipment to the site, drilling and reaming 

the two holes (gas pipeline and umbilical 

lines), installation of the pipe and umbilical, 

grouting and demobilisation. The end 

of the pipeline will be rigged up with a 

‘pullhead’ ready for pick up by the pipelay 

vessel and connection to the offshore 

pipeline. 

Onshore pipeline installation is undertaken 

as a production line, with multiple 

specialist crews, that progresses along 

a cleared and graded 24-m construction 

right-of-way (ROW), and involves pipe 

stringing, trenching, bending, welding, 

installation, backfilling and rehabilitation 

of the ROW on completion. The duration 

of onshore construction at any one location 

is expected to take approximately 

eight weeks from clear and grade to 

trench backfill. The ROW is then 

revegetated with appropriate seed mixes. 

Total onshore pipeline construction is 

expected to take about six months including 

mainline valve (MLV) installation 

and easement reinstatement. The legal 

easement for Casino pipeline operations 

is 15 m. 

3. Project Setting and Issues 

Project Setting 

The offshore portion of the project area 

extends from the Casino gas field to the 

pipeline shore crossing at Two Mile Bay. 

The characteristics of the marine environment 

and coastline of this region include 

very steep to moderate offshore 

gradients, high wave energy and cold 

temperature waters. 

Migratory marine birds and whale species 

occur in the project area, several of 

which are listed as threatened under the 

EPBC Act. A variety of marine species 

including reef-dependent and deep-water 

species are commercially harvested 

in the vicinity of the proposed development. 

A component of the onshore project areas 

lies within the Port Campbell National 

Park (in that the HDD will extend 

through, but beneath the surface of the 

Park), which is listed by the Register of 

National Estate (RNE) as an area of national 

significance and is the only conservation 

reserve within the onshore 

project area. The area is mostly undulating 

terrain, the main geomorphological 

features of which include steeply-sloping 

valleys, undulating terrain, gorges, 

tall limestone cliffs, coastal embayments 

and coastal sand dunes. 

The region surrounding Port Campbell 

and Peterborough supports 14 ecological 

vegetation classes (EVCs) but is 

dominated by cleared land and its predominantly 

introduced vegetation. Many 

of these EVCs exist as linear native vegetation 

remnants on public land along 

roadsides and watercourses that vary in 

condition from good to poor. Campbells 

Creek is the only watercourse traversed 

by the onshore pipeline. 

The onshore section of the proposed 

pipeline is located in the southern part of 

the Corangamite Shire. Towns within the 

shire have experienced varying changes, 

i.e, decline or growth, in population over 

the past two census periods. 

Land use in the onshore project area is 

primarily farmland, of high agricultural 

quality, which is used predominantly for 

grazing dairy cattle. The non-farmland 

areas (excluding remnant vegetation) are 

those covered by the Port Campbell National 

Park, which comprises unique 

coastal features (e.g., the Twelve Apostles 

rock formations) and is the focus for 

the region’s significant tourism industry. 

The Otway region is considered prospective 

for gas reserves and is increasingly 

becoming a secondary hub of gas supply 

to Victoria and interstate. Consequently, 

there are a number of existing 

and proposed gas production and 

processing infrastructure projects within 

the Casino Gas Field Development 

project area. 

Issues 

The significant environmental and social 

issues associated with the proposed Casino 

Gas Field Development are: 

• Drilling activities and discharges associated 

with the project may affect 

sea water quality and aquatic habitats. 

• Construction of subsea wellheads 

and offshore pipeline installation will 

disturb the sea bed. 

• Offshore construction activities will 

require temporary 500-m radius exclusion 

zones and during operations 

500-m radius exclusion zones will be 

in-place around the wellhead. These 

access constraints may affect commercial 

fisheries. 

• Noise generated by the drilling rig, 

pipelay vessels and support craft (including 

helicopters) may impact on 

marine mammals. 

viii 



• Construction of the shore crossing 

site and installation of the onshore 

pipeline will unavoidably require vegetation 

clearing and land disturbance 

that may result in erosion and downstream 

sedimentation. Consequent 

issues include impacts on biodiversity 

and conservation resources, surface 

water quality and flow 

characteristics, land use and amenity, 

and Aboriginal and historical heritage 

sites. 

• The development will have the potential 

to impact on visual amenity if 

inappropriately designed and implemented. 

• Construction of the onshore components 

of the project will generate dust 

and noise. The consequent issues 

focus primarily on potential effects 

on local air quality (including greenhouse 

gas emissions), public amenity 

and safety. 

• Existing roads that will provide access 

to the project are used by multiple 

users including the local 

community, school buses and tourists. 

The proposed project will temporarily 

increase traffic on these 

roads. The consequent issues focus 

on traffic delays, amenity and public 

safety. 

• The proposed Casino Gas Field Development 

will create jobs which will 

result in a temporary increase in the 

local population. There are a range 

of positive and negative consequent 

issues that concern increasing pressure 

on community facilities, services 

and infrastructure, increasing 

social tensions and increasing expenditure 

locally. 

4. Impact Assessment 

A number of specialist studies were undertaken 

as part of the approval process 

to examine the existing environmental 

and social condition and determine the 

potential impacts of the Casino Gas Field 

Development. The key findings are summarised 

below. 

Bathymetry and Oceanography 

The Casino gas field is located on the 

continental shelf within Bass Strait. Factors 

influencing current flow through Bass 

Strait are tidal forcing, waves, winds and 

large-scale ocean circulation. The maximum 

water depth is 70 m at the proposed 

well sites and the seabed includes 

shallow valley and ‘spur’ features. The 

presence of the pipeline and associated 

equipment on the seabed is expected to 

have only a very localised effect on bottom 

currents that may lead to the localised, 

but negligible, redistribution of sea 

floor sediment. 

Marine Ecology 

Four marine habitats are expected to 

occur between the well sites and the 

shore and include intertidal, shallow, middepth 

and deep environments. Within 

these habitats there are 17 threatened 

marine bird species (most of which are 

migratory), 3 threatened whale species 

(blue whale, southern right whale and 

humpback whale) and a number of fish 

listed species (e.g., pipefishes, 

seahorses and seadragons) that may 

occur. 

The offshore pipeline traverses mainly 

sandy seabed and occassional patchy 

sponge gardens of varying density cover, 

and avoids significant raised relief reef 

habitat. 

Mitigation of effects on the marine environment 

is largely achieved by appropriate 

offshore pipeline route selection. 

Other mitigation and management measures 

in relation to drilling and well completion, 

pipeline construction and HDD 

shore crossing will be implemented such 

that biological, e.g., increased concentrations 

of heavy metals, and physical, 

e.g., turbid plumes and smothering, effects 

are expected to be minor, localised 

and temporary. 

Noise derived from offshore drilling and 

construction activities has the potential 

to impact on marine animals. The principal 

sources of ambient ocean noise in 

the project area are from air-ocean interaction 

and other oceanic processes, 

naturally occurring and biogenic background 

noise and noise from shipping 

activities. The reaction of marine animals 

to project-generated noise from drilling 

rigs and ships, supply vessels and 

helicopters will vary between species and 

individuals, but is predicted to range from 

localised avoidance to no reaction at all. 

Marine Commercial Fisheries 

The region supports a number of commercial 

fisheries. Localised and temporary 

disturbance may occur to target 

species from turbidity associated with 

construction activities. Safety exclusion 

zones (500-m radius) around the wells 

and pipelay vessel during construction, 

and around the wells during operations, 

will reduce the available fishing area, 

however this will not significantly impact 

the total fishing grounds available as the 

wells and pipeline do not impact on key 

fishing grounds. Various measures will 

be implemented to minimise the risk for 

trawling gear to interfere with the pipeline. 

Landform and Soils 

The Port Campbell National Park contains 

many sites of geological and 

geomorphological interest. Two Mile Bay 

(the site of the shore crossing) is rated 

as being of regional, and possibly state, 

significance. Measures will be implemented 

to minimise erosion and sedimentation, 

slope instability, soil inversion, 

compaction and subsidence along the 

pipeline alignment. Appropriate pipeline 

route selection, implementation of these 

measures and HDD of the shore crossing 

will provide long-term protection of 

the geological and geomorphological 

sites. 

Hydrology and Hydrogeology 

The ephemeral Campbells Creek is the 

only watercourse crossing along the onshore 

pipeline alignment, and it is classified 

as a regional drain and used for 

domestic, stock and irrigation purposes. 

The onshore pipeline will be placed below 

ground and where the pipeline 

crosses Campbells Creek below the bed 

of the waterway. Open trenching will be 

used to cross Campbells Creek and instream 

activity is not expected to take 

more than one day. Pipeline installation 

will be timed to occur during nil to low 

flow thereby minimising impacts to the 

hydrological regime of the creek. Erosion 

and sediment control measures will 

be put in place to control transport of 

sediment from construction areas and 

potentially impacting surface water quality. 

Two main aquifers occur in the project 

area: Port Campbell Limestone Aquifer 

and Dilwyn Formation Aquifer. No effects 

on groundwater are likely. 

Terrestrial Ecology 

The extent of remnant native vegetation 

within the project area is limited to the 

Port Campbell National Park, fragments 

within road corridors and scattered 

patches on private land. The remaining 

areas have been substantially modified 

through clearing of vegetation for agricultural 

land use. The majority of fauna 

species known to occur in the area were 

recorded from the Port Campbell National 

Park. 


ix


9 

8 

N 

Casino offshore pipeline route 

alignment 

Proposed gas wellhead location 

ROV footage location 

8 

7 

4 5 6 

Habitat description 

Subcropping/outcropping low relief 

hummocky calcisiltite/calcarenite 

interspersed with a patchy veneer of shelly 

calcareous course sand/fine gravel 

Fine to medium sand 

Fine to coarse gravel with patches of 

subcropping cemented sediments 

Course sand/fine gravel 

3 

Casino 4 

2 

Water 

depth 

(m) 

0 

10 

40 

50 

60 

70 

1 

Casino 5 

x 



ROV location 3 

Sponges, hydrozoans, bryozoans and algae. Several demersal 

fish species 


Little or no epifaunal communities. Biological component 

principally infaunal and pelagic 






fish species 



fish species 




Figure 3 Seabed habitat classification of the Casino pipeline route 



fish species 








xi


668 000 670 000 672 000 674 000 676 000 678 000 

North–South Road 

Timboon–Peterborough Road 

Creek 

Camerons 

Hill Road 


Gas Plant 

Heytesbury 

Gas Plant 

Boundary Road 

Cheynes South Road 

Photo 5 

Photo 7 

Photo 6 Photo 8 

Proposed 

Otway Gas 

Project Plant 

Tregea Road 

Creek 

Waarre Road 

Wallaby 

TXU 

WUGS 

Facility 

Eastern Creek 

Road 

Smokey Point Road 

Road 

Curdie Vale–Port Campbell Road 

EasternCreekRoad 

Campbell Road 


Langleys 

Brumbys Road 

Minerva 

Gas Plant 

Pascoe 

Photo 3 

Photo 4 

Photo 9 

Cobden–Port 

Rounds Road 

Currells Road 

HDD 

shore 

crossing 

site 

N 

0 km 1 


Sharps Road 

Photo 2 

Photo 1 

Port Campbell 

Casino pipeline route alignment 

HDD section 



Road 

Creek 

Great Ocean Road 

Spring 

Jarvis Road 

5 724 000 5 726 000 5 728 000 5 730 000 

xii 



Photo 2 

Proposed location of the HDD site, located in background in 

pasture behind dense roadside vegetation on the northern 

side of the Great Ocean Road 

Photo 6 

Site of the proposed Campbells Creek open trench crossing, 

adjacent to the recently constructed SEAgas pipeline 

Photo 9 

The TXU WUGS facility at Iona. Tie-in point for the Casino 

pipeline 

Photo 4 

View south of the Smokey Point Road proposed crossing 

location 

Photo 5 

View south of the Cheynes South Road proposed crossing 

location 

Photo 8 

Proposed site of the Cobden - Port Campbell Road HDD 

crossing 

Figure 4 Casino Gas Field Development onshore pipeline route travelogue 

Photo 1 

Two Mile Bay and Port Campbell National Park. 

HDD shore crossing will drill under this location. 

Photo 3 

East side of the Curdie Vale–Port Campbell Road proposed 

HDD road crossing 

Photo 7 

Campbells Creek Valley, showing the recently constructed 

and restored SEAgas pipeline easement 


xiii


Alignment of the proposed pipeline to 

avoid significant stands of native vegetation 

(habitat areas) is the most important 

mitigation measure employed for 

minimising impacts to terrestrial flora and 

fauna. 

Vegetation loss and fragmentation, and 

consequent fauna habitat and species 

loss, will also be minimised by the HDD 

shore crossing which will drill under and 

not disturb coastal vegetation in the Port 

Campbell National Park. A temporary 6- 

m wide access track will be required to 

the HDD site through native vegetation 

in the Great Ocean Road verge. The 

location of the access track will be selected 

based on a detailed botanical assessment 

during spring and the track 

will be fully revegetated following construction 

with local indigenous species. 

Permanent access to the MLV site during 

the operations phase will be via an 

existing track, which will require clearing 

of regrowth. 

Pipeline construction will require the removal 

of a limited number of trees (2 to 

3) and shrubs, at two road crossings 

(Smokey Point Road and Cheynes Road 

South), however vegetation at these locations 

is significantly degraded. Mitigation 

and management measures, such 

as narrowing the right-of-way from 24 m 

down to 5 m at these roadsides, will 

minimise impacts to native vegetation. 

Similarly, the Curdie Vale to Port 

Campbell Road will be drilled to avoid 

impacting significant roadside native vegetation. 

Consequentially, the onshore pipeline is 

not expected to impact significantly on 

terrestrial flora and fauna. 

Aboriginal and Historical Heritage 

Two broad zones of archaeological sensitivity 

were identified during the field 

survey: a moderate sensitivity zone located 

on the margin and valley slopes of 

Campbells Creek and a low to moderate 

sensitivity zone covering a wider area 

impacted by land clearing and pastoral 

land use activities. 

It is expected that the implementation of 

suitable management measures such as 

further pre-construction surveys and engagement 

of Aboriginal community representatives 

to monitor vegetation 

clearing and initial earthworks activities 

(within the framework of a heritage management 

agreement), will prevent adverse 

impacts occurring. 

No zones of historic archaeological sensitivity 

have been identified therefore impacts 

to known historic heritage sites 

are unlikely to occur. The offshore pipeline 

route avoids all known shipwrecks 

by several kilometres, the nearest being 

the Napier, 3 km away from the pipeline 

alignment. 

The greatest potential for impact relates 

to disturbing previously unrecorded heritage 

sites. Mitigation and management 

measures will include training project personnel 

in the identification of potential 

artefacts and developing protocols to 

manage heritage material identified during 

construction. 

Land Use and Infrastructure 

The pipeline traverses land that is used 

for agriculture. With the exception of the 

MLV site and marker signs, there will be 

no above ground infrastructure and all 

land will be reinstated to its previous 

land use. Therefore, only some shortterm 

impacts to agricultural land use are 

expected to arise during construction and 

installation of the pipeline from the HDD 

shore crossing location to the TXU 

WUGS facility. 

Potential impacts to infrastructure have 

been mitigated to the greatest extent 

practicable by aligning the pipeline to 

accommodate landholder and asset 

owner requirements. Residual impacts 

will be managed through ongoing consultation 

with landholders and asset owners 

to address property specific issues 

and agree measures to mitigate or compensate 

any potential disruption or 

losses. Consequently, long-term detrimental 

impacts are not likely to result. 

Socio-economics 

Construction of the onshore components 

of the Casino Gas Field Development 

will require a small workforce of up to 45 

personnel resulting in a short-term increase 

in the local population. Given the 

small size of the onshore construction 

workforce, it is not expected to place 

significant pressure on community infrastructure, 

accommodation facilities and 

services such as medical facilities. It is 

possible that a construction camp will be 

established to avoid impacting on local 

facilities as construction will coincide with 

the summer tourist period. The offshore 

construction workforce of about 250 personnel 

will be accommodated on the drilling 

rig and pipelay vessel. 

Development of the Casino gas field is 

expected to generate employment opportunities 

and a requirement for support 

services. Although some positions 

will require specialist skills, there will be 

a requirement for positions to be filled 

locally and for the provision of local goods 

and services. This will have a positive 

economic impact through increased local 

expenditure. 

Visual Amenity 

Impacts to visual amenity during construction 

will be temporary, and are 

largely able to be avoided through the 

application of appropriate planning, design 

and construction strategies. Longerterm 

impacts have been mitigated by 

electing to install subsea wellheads, constructing 

the shore crossing by HDD from 

farmland and by screening the MLV site 

behind remnant native vegetation at the 

Great Ocean Road. Visual impacts of 

the onshore pipeline corridor will be limited 

to the construction phase after which 

the easement will be rehabilitated. 

Consequently, significant long-term impacts 

to the visual amenity of the region 

are unlikely to result from construction 

and operation of the Casino Gas Field 

Development. 

Noise 

Onshore noise emissions are associated 

with pipeline construction activities and 

HDD of the shore crossing and will be 

mitigated by locating the pipeline and 

shore crossing at a sufficient distance 

from sensitive receptors. The HDD operation 

will potentially result in noise nuisance 

at the nearest residence (300 m 

from the HDD site) and so further mitigation 

measures are being considered in 

consultation with the relevant landholder 

to achieve EPA requirements. No significant 

noise emissions are expected during 

normal pipeline operations. 

Air Quality 

The composition of the Casino gas is 

such that additional emissions from its 

processing at the TXU WUGS facility will 

not occur. 

The project has the potential to generate 

dust (resulting from soil disturbance) or 

exhaust emissions (associated with vehicles 

and heavy machinery). Mitigation 

and management measures will be implemented 

to manage these emissions. 

Given the short period of onshore pipeline 

construction and the application of 

xiv 



appropriate mitigation and management 

measures, impacts to air quality are unlikely 

to occur as a result of the construction 

or operation of the Casino Gas Field 

Development. 

Greenhouse Gas 

Greenhouse gas emissions will vary over 

the life of the Casino Gas Field Development. 

The project will generate minor 

greenhouse gas emissions during the 

construction and installation stages, primarily 

from vehicle exhaust emissions, 

however, these emissions are short-term 

and not significant contributors to Victoria’s 

or Australia’s total emissions. Emissions 

during operation of the pipeline will 

be minimal comprising potential fugitive 

emissions and minor quantities of vehicle 

emissions. As a signatory to the 

APPEA Greenhouse Challenge, Santos 

will continue to address reduction management 

of greenhouse gas emissions. 

Traffic 

The roads within the project area are 

multi-user roads. The potential impacts 

associated with construction traffic include 

road safety and potential interruption 

to traffic movements. A construction 

traffic management plan will be developed 

in consultation with relevant regulatory 

authorities and implemented as 

appropriate. It is expected that impacts 

resulting from construction traffic can be 

mitigated with the implementation of this 

plan. 

Condensate will be transported from the 

TXU WUGS facility to a refinery by single 

road tankers, resulting in 2 to 3 trucks 

per week. The volume of condensate 

and therefore trucks is expected to decline 

to about one per week after the first 

two years of field production. Based on 

this low and declining volume of condensate 

transport road traffic, and the application 

of the existing road safety 

management requirements for current 

traffic from the TXU WUGS facility, this 

minor increase in volume is not expected 

to significantly impact local traffic conditions. 

Hazard and Risk 

The Pipelines Act 1967 requires that a 

detailed risk assessment be undertaken 

in accordance with the requirements of 

the Australian standard for high-pressure 

gas pipelines, AS2885.1. Consequently, 

the Casino Gas Field Development is 

designed and operated to achieve hazard 

and risk levels that are as low as 

reasonably possible. Prior to the granting 

of the Pipeline Licence Santos will 

undertake such a risk assessment the 

results of which will be incorporated into 

final project planning and design as required. 

5. Environmental 

Management 

Santos has developed an environment, 

health and safety management system 

(EHSMS) which consists of two sets of 

standards: management standards and 

hazard standards. A project-specific environment 

plan (EP), for offshore components, 

and environmental 

management plan (EMP), for onshore 

components, will be prepared for the 

Casino Gas Field Development within 

the framework of the EHSMS. 

Pipeline alignment is the most effective 

mitigation measure for minimising impacts. 

Residual impacts are then mitigated 

and managed through the 

implementation of appropriate measures 

and procedures. Table 1 summarises the 

impacts associated with the project, together 

with the mitigation and management 

measures, additional to pipeline 

alignment that will form the basis of the 

EP and EMP. 


xv


Table 1 

Environmental mitigation and management measures 

Element Potential Issue/Impact Proposed Mitigation and Management Measure 

Bathymetry and 

oceanography 

Marine ecology 

Commercial 

fisheries 

Landform and 

Soils 

Pipeline stability on the seabed 

Spanning of pipeline 

Effect on sea water quality and 

aquatic habitats 

Impacts of project-generated 

noise on marine animals 

Effects on fishery operations 

Wind and water erosion 

Pipeline will be weighted (concrete coating or thicker wall steel pipe) to provide onbottom 

stability 

Pipeline route was selected to avoid significant spans 

Grout-filled bladders will fill minor spans to support pipeline 

Pipeline will be surveyed and retrospective maintenance as necessary to address 

pipeline spanning 

Offshore pipeline is aligned to avoid key reef habitats and predominantly traverse 

sandy seabed 

HDD will be employed for the shore crossing to avoid impacts to nearshore reef and 

coastal habitat 

Oil spill contingency response plan implemented for exploration drilling will be 

expanded to include all field development and operation activities 

Strict vessel refuelling procedures will be employed to prevent spillage at sea 

A waste management strategy will be developed for all marine activities based on 

Australian and international standards 

Vessels will comply with standard requirements for the prevention of the introduction 

of pests 

Low toxicity, water-based drilling fluid additives will be used 

HDD fluid discharge to the marine environment will be minimised 

Hydrostatic test water will be low-toxicity and discharged from the Casino 5 wellhead 

over a four-day period to ensure further dilution and dispersion 

Protocols will be developed in accordance with EPBC regulations to minimise 

interaction with whales during construction and drilling 

Construction will minimise or avoid the types of vessel and aircraft movements that 

are known to elicit disturbance reactions 

Aerial observations will be undertaken to monitor whale activity during the period 

leading up to and during the drilling program, where it coincides with whale migration 

or presence 

Helicopters will be flown at a minimum altitude of 1,000 m over ocean 

Watch will be maintained for whales in the vicinity of vessel activities during 

pipelaying such that responses including reduction of speed, minimisation of sonar 

use, and instructions to helicopter pilots/ancillary vessels to avoid whales can be 

implemented 

Offshore pipeline is aligned to avoid key fishing areas 

HDD will be employed for the shore crossing to avoid impacts to nearshore lobster 

and abalone habitat 

500-m radius exclusions zones will be implemented during construction (well sites 

and pipelay vessel) and operation (wellheads only) to minimise collision risk and 

gear loss 

Digital information on position of wellheads and subsea pipeline will be provided to 

commercial fishers 

Location, timing and duration of construction activities will be communicated with 

commercial fishers 

A gear retrieval or replacement policy will be implemented where it becomes 

snagged on project infrastructure 

Construction is scheduled for the drier months of the year and activity will be limited 

during heavy rain 

Maximum coverage of vegetation will be retained and rehabilitated expeditiously 

A special crossing crew will construct the Campbells Creek crossing and will retain a 

vegetation buffer on the banks and approach slopes, reinstate immediately following 

pipelay using appropriate stabilisation measures and undertake additional 

revegetation to enhance the riparian corridor 

Erosion and sediment control measures will be installed and maintained during 

construction and operations 

The pipeline easement will be monitored for erosion, sedimentation and stability 

xvi 



Table 1 

Environmental mitigation and management measures (cont’d) 


Landform and 

Soils (cont’d) 

Hydrology and 

hydrogeology 

Terrestrial 

ecology 

Slope instability 

Soil inversion, compaction and 

subsidence 

Soil contamination 

Disturbance to significant 

features 

Water quality 

Disruption to water flow regimes 

Clearing of remnant native 

vegetation and loss of significant 

flora and fauna with consequent 

biodiversity and conservation 

impacts 

Onshore pipeline alignment was selected to avoid areas of significant slope 

instability and slumping 

Topsoil will be stripped and stockpiled separately to trench spoil 

Soils will be reinstated in the reverse order of excavation to avoid inversion of soil 

profiles 

Construction ROW access during or immediately after heavy rain will be limited 

Trench backfill will be compacted and if necessary a raised crown will be installed 

(less than 20 cm) over the trench to mitigate subsidence 

Soils will be scarified to relieve compaction, where necessary 

Temporary and permanent storage of fuels, lube oils and other hazardous chemicals 

will be within areas or facilities designed to contain spills 

Appropriate hazardous chemical handling procedures will be implemented 

Appropriate measures to prevent third party rupture of the MEG pipeline will be 

implemented including pipeline marker signs, in-trench marker tape and appropriate 

depth of burial 

A spill contingency response plan will be developed and implemented 

HDD will be employed for the shore crossing to avoid surface impacts to coastal 

landforms 

Construction is scheduled for the driest months of the year 

The Campbells Creek crossing will be constructed during period of nil to low flow, 

where practicable or employ stream flow diversion measures (flume or dam and 

pump) to minimise sediment release 

The pipeline will be buried at a greater depth at the Campbells Creek crossing to 

minimise risk of scour 

Stockpiles will be placed more than 10 m from the top-of-bank at Campbells Creek 

Temporary and permanent storage of fuels, lubes and other hazardous chemicals 

will be within areas or facilities designed to contain spills 

Appropriate hazardous chemical handling procedures will be implemented (e.g., no 

refuelling of machinery and equipment within 20 m of Campbells Creek) 

A spill contingency response plan will be developed and implemented 

A raised crown will be installed over the trench to compensate for subsidence and 

crown breaks created every 30 m to prevent impedance of surface flows 

The Campbells Creek crossing will be constructed during nil to low flow, where 

practicable or stream flow diversion measures employed (flume or dam and pump) to 

maintain flow 

Positive HDD fluid pressure will be maintained during drilling and the drill hole cased 

to prevent preferential flow of groundwater along the drill hole 

HDD shore crossing will drill under the surface of Port Campbell National Park and 

Great Ocean Road avoiding native vegetation clearance 

Temporary access to the HDD site will be selected based on a targeted search for 

rare or endangered species to avoid any that may be present, where practicable. 

The access will be revegetated with local native species following construction to 

reflect the existing ecological vegetation class (EVC) 

The pipeline route is aligned through open farmland and traverses native vegetation 

at two minor road crossings only where it is aligned through degraded native 

vegetation. The ROW will be narrowed from 24-m down to 5-m at these road 

crossings 

Impacts to native vegetation within the Port Campbell National Park to enable 

temporary surface placement of the HDD sensing cable will be kept to an absolute 

minimum, involve hand trimming only, include restoration of any disturbed areas and 

be undertaken in consultation with Parks Victoria. 


xvii


Table 1 



Terrestrial 

ecology (cont’d) 

Aboriginal and 

historic heritage 

Land use and 

infrastructure 

Socio-economic 

Visual amenity 

Potential for disturbance to 

Aboriginal and historic heritage 

sites 

Construction and operation of 

the pipeline may effect current 

land use activities 

Interference with the operation 

of existing infrastructure 

Creation of jobs and requirement 

for supporting goods and 

services 

Short-term additional demand 

for services, facilities and 

infrastructure, potential to create 

social tensions 

Alteration to the visual 

landscape associated with 

vegetation clearing and the 

introduction of project 

infrastructure 

Campbells Creek crossing is aligned to avoid clearance of significant riparian 

vegetation 

Cleared native vegetation will be retained on site and respread over the easement 

during rehabilitation 

The period and length of time the trench remains open will be minimised and the 

open trench will be monitored for fauna 

Weed and pathogen hygiene measures will be implemented for the project, 

particularly in relation to access to the Port Campbell National Park 

Any areas of native vegetation impacted by the project shall be revegetated with 

indigenous species to reflect the original EVC in line with the principles of net gain 

Disturbed areas will be revegetated as soon as practicable following construction 

Permanent access to the MLV site will be via an existing narrow track, which will 

require minor clearing of native regrowth and weed species. 

An Aboriginal heritage management plan will be implemented in consultation with the 

relevant Aboriginal communities 

Additional sub-surface Aboriginal heritage surveys will be undertaken in the 

Campbells Creek valley prior to construction in consultation with the relevant 

Aboriginal communities 

Representatives from the relevant Aboriginal communities will be engaged to monitor 

clearing and initial earthworks for previously undetected heritage artefacts 

Appropriate site management will be implemented in consultation with relevant 

Aboriginal heritage communities and regulatory authorities 

A protocol for the management of any new potential Aboriginal or historic heritage 

sites uncovered during construction will be implemented within the heritage 

management plan framework 

The pipeline has been aligned through properties in consultation with landholders to 

minimise impacts to farm operations (e.g., follow existing easements and fence 

lines), where practicable 

A weed and pathogen management plan will be implemented, including appropriate 

hygiene measures to prevent the introduction and spread of weeds and pathogens 

Liaison with landholders will be undertaken to determine the most appropriate 

measures to minimise impacts to farm operations 

The easement and farm infrastructure will be reinstated in a manner that minimises 

disruption and losses to landholders 

Santos will continue to liaise with Woodside Energy Ltd with regard to minimising 

impacts where pipeline construction for the Casino Gas Field Development and the 

Otway Gas Project is within the same property 

Crossing of the Curdie Vale to Port Campbell Road and Cobden to Port Campbell 

Road will be by HDD 

Utility infrastructure asset owners will be consulted regarding potential impacts to 

utilities associated with pipeline route selection, construction and operation activities 

Where possible, employees and goods and services will be sourced locally 

The field interaction protocol will continue to be implemented to guide personnel on 

appropriate standards of conduct during field activities 

Santos and the construction contractor will consult with local authorities and service 

providers regarding resourcing issues 

Installation of subsea wellheads will avoid offshore visual impacts 

Well locations will be identified on marine charts and coordinates provided to 

commercial fishers to negate the need for marker buoys to mark well locations 

The shore crossing will be constructed by HDD 

xviii 



Table 1 



Visual amenity 

(cont’d) 

Noise 

Air quality 

Potential noise nuisance to 

adjacent residents during 

construction and operation 

Generation of dust and exhaust 

emissions 

The pipeline alignment selected minimises vegetation clearance 

The onshore pipeline will be buried 

The HDD and MLV site will be screened behind dense roadside vegetation at the 


The location of the construction camp, if required, will be in an area of previous 

disturbance and established and operated in a manner that minimises visual 

intrusion 

Noisy activities will be scheduled for during the day to coincide with higher ambient 

noise, where practicable 

Measures will be undertaken to attenuate noise from the HDD, if necessary, e.g., 

noise barriers, or alternatively arrangements will be implemented with the affected 

residents to avoid noise nuisance 

Potentially affected residents will be informed of the status of construction activities 

The extent of clearing and earthworks will be limited and the period surfaces are 

exposed minimised 

Vehicle speeds will be restricted on unsealed tracks and the pipeline easement 

Appropriate means to stabilise soils in dusty conditions will be used, e.g., water 

trucks 

Vehicles and plant will be appropriately maintained 

The pipeline and associated appurtenances will be appropriately maintained to 

minimise fugitive emissions during operations 

Planned venting operations, if undertaken, will be during appropriate weather 

conditions to facilitate rapid dispersion 

Greenhouse gas Emissions of greenhouse gases The pipeline and associated appurtenances will be appropriately maintained to 

minimise fugitive emissions during operations 

Traffic 

Hazard and Risk 

Alteration to existing traffic 

conditions, e.g., increased road 

use 

Risk of rupture of the gas or 

MEG pipelines, or impacts to 

wellhead facilities 

Bushfire resulting from 

construction activities 

Vehicles and other internal combustion equipment will be appropriately maintained 

Quantities of vented natural gas during commissioning and operations will be 

minimised 

A traffic management plan for the construction and operations phases will be 

developed and implemented in consultation with VicRoads and the Corangamite 

Shire 

The pipeline and associated appurtenances will be located to minimise risk of 

interference 

Design and construction of wellhead facilities, the pipeline and associated 

appurtenances will be in accordance with Australian standard AS2885 and 

consequently, the project risk assessment study 

Bushfire prevention and response procedures will be developed in consultation with 

relevant regulatory authorities for incorporation into the Safety Management Plan 


xix


xx 


Contents 

Contents 


v 

1. Introduction 1 

1.1 Project Outline 1 

1.2 Project Proponent 1 

1.2.1 Santos Ltd 1 

1.2.2 Australian Worldwide Exploration Limited 3 

1.2.3 Mitsui & Co. (Australia) Ltd 3 

1.3 Project Justification 3 

1.4 About This Document 4 

1.5 EIA Study Team 4 

2. Regulatory Framework 5 

2.1 Approval Process Overview 5 

2.2 Planning and Environmental Approvals 5 

2.2.1 EPBC Act 1999 5 

2.2.2 Environment Effects Act 1978 6 

2.2.3 Planning and Environment Act 1987 7 

2.2.4 Coastal Management Act 1995 7 

2.2.5 Native Title 7 

2.2.6 Net Gain Policy 8 

2.3 Well Development Approvals 8 

2.3.1 Commonwealth Petroleum (Submerged Lands) Act 1967 8 

2.4 Pipeline Approvals 8 

2.4.1 Commonwealth Petroleum (Submerged Lands) Act 1967 8 

2.4.2 Victorian Petroleum (Submerged Lands) Act 1982 8 

2.4.3 Pipelines Act 1967 8 

2.4.4 Easement Acquisition 8 

2.5 Subsequent Approvals 9 

3. Stakeholder Consultation 11 

3.1 Relevant Stakeholders 11 

3.2 Stakeholder Consultation Program 11 

3.3 Consultation Records 13 

4. Project Rationale 15 

4.1 Australia’s Gas Industry 15 

4.2 Rationale for Development 15 

4.3 Benefits of the Proposal 15 

4.3.1 Supplementation of Existing Gas Reserves 15 

4.3.2 Security of Supply 15 

4.3.3 Increased Gas Supply Competition 16 

Casino Gas Field Development xxi

Contents 

4.3.4 Commercial Benefits 16 

4.3.5 Potential Greenhouse Benefits 16 

4.4 Project Alternatives 17 

4.4.1 The ‘Do Nothing’ Scenario 17 

4.4.2 Alternative Gas Supplies 17 

4.4.3 Alternative Energy Sources 17 

4.4.4 Alternative Development Scenarios 18 

5. Project Description 19 

5.1 Reservoir and Gas Specifications 20 

5.2 Project Design Specifications 20 

5.3 Pipeline Route Selection 20 

5.3.1 Shore Crossing 21 

5.3.2 Offshore Pipeline 21 

5.3.3 Onshore Pipeline 21 

5.4 Description of Construction Activities 25 

5.4.1 Drilling and Wellhead Installation 25 

5.4.2 Offshore Pipeline and Umbilical Installation 30 

5.4.3 Shore Crossing 30 

5.4.4 Onshore Pipeline 32 

5.4.5 Ancillary Facilities 42 

5.5 Commissioning 43 

5.6 Operations 43 

5.7 Decommissioning 43 

5.8 Project Life 44 

5.9 Project Development Schedule 44 

6. Impact Assessment 45 

6.1 Climate 45 

6.2 Bathymetry and Oceanography 45 

6.2.1 Sources of Information 45 

6.2.2 Existing Environment 45 

6.2.3 Potential Impacts 46 

6.2.4 Mitigation and Management Measures 46 

6.2.5 Residual Impacts 47 

6.3 Marine Ecology 47 

6.3.1 Survey Methodology 47 



6.3.4 Impact Assessment 51 


6.4 Marine Acoustics 54 


6.4.2 Construction Related Noise 56 

6.4.3 Potential Impacts to Whales 57 


6.5 Marine Commercial Fisheries 61 


xxii 


Contents 


6.5.3 Mitigation and Management Measures and Residual Impacts 63 

6.6 Landform and Soils 64 




6.7 Hydrology and Hydrogeology 69 




6.8 Terrestrial Ecology 70 





6.9 Aboriginal Heritage 84 






6.10 Historical Heritage 88 

6.10.1 Methodology 88 





6.11 Land Use and Infrastructure 89 



6.11.3 Impact Assessment, Mitigation and Management Measures 93 


6.12 Socio-economic 96 




6.13 Visual Amenity 99 





6.14 Noise 103 




6.15 Air Quality 106 

Casino Gas Field Development xxiii

Contents 





6.16 Greenhouse Gas 107 

6.16.1 Background 107 

6.16.2 Sources of Greenhouse Gases 107 


6.17 Traffic 108 





6.18 Hazard and Risk 109 

7. Environmental Management Framework 111 

7.1 Environment, Health and Safety Management System 111 

7.1.1 Policy 112 

7.1.2 Plan 112 

7.1.3 Implement 113 

7.1.4 Monitor and Evaluate 116 

7.1.5 Review 116 

8. References 117 

9. Glossary 121 

Figures 

1.1 Casino Gas Field Development pipeline alignment 2 

1.2 Casino Gas Field Development schematic 3 

2.1 Casino Gas Field Development lead environmental approvals process flow chart 6 

4.1 Total natural gas consumption in Australia, 1979-2001 15 

4.2 Australia’s primary energy consumption by fuel type, 1980-81 and 2000-01 16 

4.3 Australia’s natural gas consumption by state, 2001 16 

4.4 Australia’s gas pipelines and gas fields 17 

5.1 Casino Gas Field Development schematic 19 

5.2 Casino Gas Field Development HDD shore crossing options 22 

5.3 Casino Gas Field Development onshore pipeline route sub-options 24 

5.4 Casino Gas Field Development onshore pipeline route 27 

5.5 Casino Gas Field Development onshore pipeline route travelogue 29 

5.6 Typical subsea wellhead configuration 30 

5.7 Offshore pipeline cross section (umbilical shown strapped to pipeline, but may be laid separately 

adjacent to pipeline) 32 

5.8 Typical offshore pipeline spanning stabilisation treatment 32 

5.9 HDD shore crossing - site location and construction site layout 33 

5.10 HDD shore crossing profile 34 

xxiv 


Contents 

5.11 Typical mainline construction ROW cross section 35 

5.12 Onshore pipeline construction ROW 36 

5.13 Onshore pipeline and trench cross-section 39 

5.14 Typical open trench isolation crossing (dam and pump method) 40 

5.15 Typical open trench isolation crossing (flume pipe method) 41 

5.16 Typical MLV site layout 42 

5.17 Project development timeline 44 

6.1 Sea surface temperature satellite image, showing cold water upwelling off the Bonney Coastline 

in March 1995 46 

6.2 Seabed habitat classification of the Casino pipeline route 48 

6.3 Blue whale sightings between February 1998 - May 2002 50 

6.4 Geology of the Port Campbell area 65 

6.5 Idealised geological profile of the HDD shore crossing 68 

6.6A Vegetation units 72 

6.6B Vegetation units (Great Ocean Road to Curdie Vale to Port Campbell Road) 73 

6.6C Vegetation units (Curdie Vale to Port Campbell Road to Campbells Creek) 74 

6.6D Vegetation units (Campbells Creek to the TXU WUGS facility) 75 

6.7 Ecological Vegetation Classes of the Port Campbell area 76 

6.8 HDD shore crossing site 81 

6.9 Curdie Vale to Port Campbell Road HDD crossing 82 

6.10 Smokey Point Road open trenched crossing 82 

6.11 Cheynes Road South open trenched crossing 83 

6.12 Campbells Creek open trenched crossing 83 

6.13 Cobden to Port Campbell Road HDD crossing 84 

6.14 Landuse and infrastructure 90 

6.15 Corangamite Shire planning schemes and overlays 91 

6.16 Residences within 500m of the proposed Casino pipeline 105 

7.1 Santos’ Environment, Health and Safety Management System 111 

Tables 

1.1 Casino Gas Field Development EIA Project Team 4 

2.1 Summary of key regulatory approvals 5 

2.2 Subsequent approvals 9 

3.1 Key stakeholders 12 

3.2 Casino Gas Field Development consultation summary 13 

5.1 Pipeline and well design specifications 20 

5.2 Preliminary assessment of shore crossing options 23 

5.3 Assessment of onshore route options 26 

5.4 Length of preferred onshore pipeline route following new, existing or proposed easements 30 

5.5 Depths of cover along the proposed pipeline route 39 

5.6 Proposed road crossing methods 41 

6.1 Climatic averages for southwest Victoria 45 

6.2 Average rainfall and raindays in Port Campbell (1885 to 1993) 45 

Casino Gas Field Development xxv

Contents 

6.3 Locations of commercial fisheries in the study area 63 

6.4 Geology of the project area 66 

6.5 Summary of vegetation types and EVCs along the proposed Casino pipeline route 77 

6.6 Habitat quality 78 

6.7 Fauna conservation significance 80 

6.8 Summary of proposed mitigation measures and residual impacts on native vegetation 85 

6.9 Potential impacts to flora and fauna habitat and actions for avoidance and minimisation 86 

6.10 Previous historical research undertaken in the vicinity of the study area 88 

6.11 Shipwrecks within 15 km of the proposed offshore pipeline route 89 

6.12 Existing and proposed gas infrastructure in the project area 92 

6.13 Corangamite Shire population data 96 

6.14 Location of population within Corangamite Shire 96 

6.15 Corangamite Shire employment by industry 97 

6.16 Typical background noise levels within the project area 103 

6.17 EPA (N3/89) maximum noise limit guidelines 103 

6.18 EPA (TG 302/92) noise control guidelines 104 

6.19 Maximum predicted noise levels, LA 10 

dB(A) 104 

6.20 Predicted noise levels at residences within 500 m of the pipeline route 104 

7.1 Santos EHSMS management standards 112 

7.2 Casino Gas Field Development environmental responsibilities 114 

Plates 

5.1 Well testing by semi-submersible rig during drilling of Casino 3 well 30 

5.2 Typical subsea wellhead similar to that proposed for the Casino Gas Field Development 31 

5.3 The “Semac 1” pipelay barge 31 

5.4 The “Apache” pipe reel-lay vessel 31 

5.5 A typical HDD rig used for road and river crossing operations 34 

5.6 Raised rock creek causeway 37 

5.7 A cleared and graded ROW in preparation for trenching 37 

5.8 Trench excavation using a bucket-wheel ditcher 37 

5.9 Stringing of pipe lengths along the ROW 37 

5.10 Field bending of pipe 37 

5.11 Pipe welding 37 

5.12 Coating of welded pipe joints 38 

5.13 Lowering in of pipeline 38 

5.14 Backfilling the trench 38 

5.15 Soil ripping to alleviate heavily compacted soils 38 

5.16 Revegetation, showing pasture restoration shortly after sowing 38 

5.17 Typical pipeline marker post and cathodic protection test point 43 

6.1 Panoramic view of Two Mile Bay , showing the intertidal environment 49 

6.2 Coastal cliff formations typical of the Port Campbell National Park 66 

6.3 West side of the Curdie Vale to Port Campbell Road HDD road crossing location 82 

xxvi 


Contents 

6.4 East side of the Curdie Vale to Port Campbell Road HDD road crossing location 82 

6.5 North side of the Smokey Point Road crossing location. Note the predominantly weedy 

roadside vegetation 82 

6.6 South side of the Smokey Point Road road crossing location, heavily infested with blackberries 82 

6.7 South side of the Cheynes Road South road crossing location. Little, if any, of this native vegetation 

will be cleared to accommodate the ROW 83 

6.8 North side of the Cheynes Road South road crossing location. Note the predominantly weedy 

vegetation and sparse native overstorey 83 

6.9 Campbells Creek crossing location, adjacent to the recently constructed SEAgas pipeline 83 

6.10 The Twelve Apostles, 21 km west of the Casino Gas Field Development shore crossing 99 

6.11 Casino 3 drilling rig (circled) in operation as seen from the shore near Port Campbell, barely visible 

on the horizon 100 

Boxes 

7.1 Santos’ environmental vision, commitment and policy 112 

Appendices 

1 Terrestrial Flora and Fauna Species Lists 

2 Santos Environment, Health and Safety Management System 

Casino Gas Field Development xxvii

Contents 

xxviii 




Santos Ltd (Santos) is proposing the 

Casino Gas Field Development located 

approximately 30-km offshore from Port 

Campbell on Victoria’s southwest coast. 

This Environment Report has been prepared 

in support of applications for statutory 

approval. 

1.1 Project Outline 

The Casino gas field was discovered in 

September 2002 and contains estimated 

recoverable reserves of 211 billion cubic 

feet (bcf) of natural gas. The Casino Gas 

Field Development comprises a subsea 

completion and a pipeline development, 

which will carry gas from offshore wells 

to an existing gas processing facility near 

Port Campbell, operated by Texas Utilities 

(TXU) (Figure 1.1). Specifically, the 

proposed development comprises: 

• Drilling of two offshore development 

wells using a floating semi-submersible 

drilling rig. 

• Installation of subsea wellheads on 

the seafloor in approximately 70 m of 

water. 

• Installation of a subsea pipeline (approximately 

36.7-km long) on the seafloor 

using a pipe-lay vessel. Gas will 

flow from the wells via the subsea 

pipeline to shore. 


of the shore crossing from cleared 

farmland on the northern side of the 

Great Ocean Road at Two Mile Bay, 

approximately 2-km west of Port 

Campbell, to avoid disturbance to the 

surface of Port Campbell National 

Park and coastal marine habitat. Two 

drill holes, each approximately 1,570 

m in length, will be required to accommodate 

the gas pipeline and a 

control umbilical cable bundle. 

• Construction of an onshore pipeline 

(with nominal diameter of 300 mm 

and approximate length of 11.5 km) 

from the HDD shore crossing site to 

TXU’s Western Underground Gas 

Storage (WUGS) facility at Iona, near 

Port Campbell. A mainline valve 

(MLV) compound will be constructed 

at the HDD site and over the pipeline 

easement after the completion of the 

shore crossing. 


TXU WUGS facility, prior to its distribution 

to Victorian and interstate customers 

through the existing pipeline 

network. A new gas processing plant 

is not required for the Casino Gas 

Field Development. 

A schematic layout of the proposed development 

is shown in Figure 1.2. 

Reservoir testing has shown that the raw 

gas has very low carbon dioxide content 

and no detectable sulfur oxides or nitrous 

oxides. Stripping of impurities from 

the gas is therefore not required and 

hence no additional air emissions from 

the TXU WUGS facility are expected. 


and condensate (a light petroleum 

liquid), may naturally occur in the gas 

and will be removed at the TXU WUGS 

facility. 

The water will be disposed through TXU’s 

existing water treatment facility. The condensate 

will be stored at the TXU WUGS 

facility and then transported to a refinery 

by a single road tanker approximately 

two to three times a week. Condensate 

production from the Casino gas field is 

expected to decline significantly after one 

to two years of operation to the equivalent 

of about one tanker per week. 

1.2 Project Proponent 

The proponent for the Casino Gas Field 

Development is Santos (50% interest), 

which operates exploration permit VIC/ 

P44 on behalf of its joint venture partners, 

Peedamullah Petroleum Pty Ltd 

(Australian Worldwide Exploration Limited) 

(25% interest) and Mitwell Energy 

Resources Pty Limited (Mitsui & Co. 

(Australia) Ltd) (25% interest). 

1.2.1 Santos Ltd 

Santos was formed in South Australia in 

1954 and is now a major Australian energy 

company. The core business of the 

company is oil and gas exploration and 

production with interests in every major 

Australian petroleum province. Santos is 

the largest producer of natural gas for 

the Australian market supplying all mainland 

states and territories. Santos’ head 

office is located in Adelaide with offices 

also located in Brisbane and Perth. 

The core gas operations for Santos are 

in the Cooper Basin with gas being distributed 

to customers in South Australia, 

New South Wales, Queensland and the 

Australian Capital Territory. Santos also 

operates gas fields in the Northern Territory, 

Western Australia and Victoria, has 

exploration and production interests in 

the United States of America and exploration 

acreage in Indonesia and Papua 

New Guinea. 

In the Otway Basin, Victoria, Santos holds 

interests in three exploration permits onshore 

and three exploration permits and 

two retention licences offshore. Santos’ 

offshore interests include a 10% share 

in the retention leases that contain the 

Minerva and La Bella gas fields operated 

by BHP Billiton Petroleum Pty Ltd. 

Santos has been the operator of the Vic/ 

P44 exploration permit (Santos interest 

50%) since 2001 and in August 2002 

was awarded exploration permits VIC/ 

P51 (Santos interest 80%) and VIC/P52 

(Santos interest 33.3%). Santos, on behalf 

of its joint venture partners, also 

operates four recently awarded Commonwealth 

exploration permits in the adjacent 

Sorrell Basin. Since becoming 

operator of these permit areas, Santos 

has undertaken exploration including 

seismic surveys and drilling. 

Casino Gas Field Development 1


640 000 650 000 660 000 670 000 

AUSTRALIA 

VICTORIA 



Gas Plant 

Heytesbury 

Gas Plant 

Proposed 

Otway Gas 

Project Plant 

Lovers Nook 


Curdies 

Inlet 

N 


VICTORIA 

Melbourne 

Tasman 

Sea 

N 

Peterborough 

Minerva Gas 

Plant 

10m 

20m 

30m 

Bass Strait 

0 km 

100 

Port Campbell 

40m 

Newfield Bay 

HDD shore 

crossing site 

50m 

Two Mile Bay 

TXU WUGS 

Facility 

60m 


N 

0 km 5 

70m 


Minerva 

Gas 

Well 


Bay of Islands Coastal Park 

Peterborough Coastal Reserve 



HDD section 




Gas well 

Bathymetry 


Casino 4 

Figure 1.1 Casino Gas Field Development pipeline alignment 

5 710 000 5 720 000 5 730 000 

2 Casino Gas Field Development


Existing TXU WUGS 

facility 

Port Campbell 

National Park 

Sales gas 

30 km (16 nm) 

Nearshore 

rocky reef 

Two subsea wellheads 

Horizontal directional drill 

shore crossing under 


Gathering manifold 

70 m 

water depth 

Subsea pipeline to shore and 

control umbilicals 

Reservoir depth 

up to 2,000 m 

below sea level 

Development wells 

drilled by jakck-up rig 

Not to scale 

Casino 

Gas Reservoir 

Figure 1.2 


1.2.2 Australian Worldwide 

Exploration Limited 

Australian Worldwide Exploration Limited 

(AWE) is an Australian oil and gas 

exploration and production company 

listed on the Australian Stock Exchange 

(ASX). AWE was founded in Australia in 

1997. Its assets include interests in the 

Kipper, Basker and Manta gas and oil 

fields in the Gippsland Basin (interests 

sold in 1999), the Pillantoqui light gas 

field in Argentina and exploration acreage 

in the Taranaki Basin of New Zealand. 

In late 1999, AWE acquired a 96% controlling 

interest in Omega Oil NL and this 

became a wholly-owned subsidiary in 

September 2002. In January 2000, AWE 

acquired all of the Australian assets of 

Premier Oil plc, including a 33% share of 

the producing Beharra Springs gas field 

located in the Perth Basin, Western Australia. 

AWE also has a 30% interest in 

the Yolla gas field in Bass Strait that is 

currently being developed. 

During 2001, AWE commenced development 

of the Las Bases and Estancia 

el Colorado gas fields in Argentina and 

the Beharra Springs North onshore gas 

field in Western Australia. In mid 2003, 

AWE acquired a 25% interest in VIC/ 

P44, containing the Casino gas field. 

1.2.3 Mitsui & Co. (Australia) Ltd 

Mitsui & Co. (Australia) Ltd (Mitsui) is 

100% owned by its parent company, 

Mitsui & Co., Ltd of Japan, which has 

offices in 210 cities spanning 93 countries. 

Mitsui opened its first Australian office in 

Sydney in 1909, followed by a Melbourne 

office in 1917. Since the 1960’s, Mitsui’s 

activities have expanded to include working 

with the public and private sectors in 

Australia. Mitsui is active in the development 

of minerals, energy and agricultural 

exports, investment and, more 

recently, promoting new areas, including 

telecommunications and forestry. 

Australian petroleum joint ventures include 

the Northwest Shelf LNG project, 

Timor Sea exploration and 25% of VIC/ 

P44 which contains the Casino gas field. 

1.3 Project Justification 

Gas from the Casino gas field is earmarked 

for use by Victorian consumers 

during 2006 as a supplement to existing 

Victorian gas reserves, catering for the 

predicted increase in demand. The 

project development schedule aims to 

have the gas available to consumers to 

meet the winter peak gas use period. 

Other potential benefits of the Casino 

Gas Field Development include: 

• Employment, particularly during construction. 

• Direct and indirect commercial benefits 

during construction and operation 

through the provision of support 

services to the project. 



• Provision of an alternative independent 

gas supply, further improving security 

of supply and reliability in the 

Victorian gas market. 

• Supplementing existing available gas 

reserves. 

• Increasing inter-basin competition 

between gas producers. 

• Increased utilisation of the TXU 


• Potential for reduction in greenhouse 

gas emissions compared to the use 

of alternative fossil fuels. 

1.4 About This Document 

This Environment Report has been prepared 

in support of an application for a 

Pipeline Permit by Santos under the provisions 

of the Victorian Pipelines Act 

1967. It assesses the environmental, social 

and economic impacts of the construction 

and operation of all aspects of 

the Casino Gas Field Development and 

identifies Santos’ intentions for the avoidance, 

mitigation and management of the 

residual impacts. 

This document has been prepared following 

consultation with a range of stakeholders 

throughout the planning and 

impact assessment process. 

The Environment Report enables the 

public, determining authorities, assessment 

agencies and referral agencies to 

understand the environmental consequences 


and provides a basis on which 

comment can be made on the proposal. 

Specifically, this Environment Report provides: 

• For interested bodies and persons, a 

basis for understanding the proposal, 

alternatives and preferred solutions, 

the existing environment, and the 

potential change to that environment 

that may occur if the proposal is implemented. 

• For groups or persons with rights or 

interests in land, an outline of the 

effects of the proposal on that land, 

including information on access, acquisition 

and easements, and how 

those effects will be managed. 

• For government decision-makers, information 

for assessing the impacts 

of the proposed project and associated 

development, having regard to 

the legislative and policy provisions 

of their jurisdictions. 

• For the proponent, a definitive statement 

of measures or actions taken to 

avoid, manage or mitigate any po- 

Company 

Santos Ltd 

Table 1.1 

Enesar Consulting Pty Ltd 

Centre for Marine Science and 

Technology, Curtin University 

Worley 

Ian A. Gordon 

Brett Lane & Associates 

Framlingham Aboriginal Trust 

Andrew Long & Associates 

Weather News International (WNI) 

Fugro-TGS 

tential adverse impacts during and 

following the implementation of the 

proposal. 

1.5 EIA Study Team 

Santos has appointed Enesar Consulting 

Pty Ltd to coordinate a detailed investigation 

of the potential environmental 

impacts from the proposed Casino Gas 

Field Development. The impact assessment 

has been undertaken by a team of 

specialists from a range of disciplines 

(Table 1.1). The contributions of team 

members are gratefully acknowledged. 

Casino Gas Field Development EIA Project Team 

Project management 

Role 

EIA project management 

Planning and environmental approvals 

Marine ecology 

Socio-economic (visual, traffic, land and marine uses) 

Emissions (air and noise) 

GIS 

Underwater acoustic recording and analysis 

Engineering concept study 

Front-end Engineering and Design (FEED) 

Lands and easements 

Terrestrial and stream ecology 

Aboriginal heritage study coordination 

Aboriginal site surveys 

Aboriginal, historic and maritime heritage 

Oceanography 

Offshore pipeline route survey 


2. Regulatory Framework 


2.1 Approval Process 

Overview 

The proposed Casino Gas Field Development 

will impact on three jurisdictions 

including Commonwealth waters, Victorian 

State waters and onshore Victoria. 

Consequently, the project will require 

permits and licences under the Commonwealth 

Petroleum (Submerged 

Lands) Act 1967, the Victorian Petroleum 

(Submerged Lands) Act 1982 and 

the Victorian Pipelines Act 1967, respectively. 

Where a project displays the potential to 

significantly impact upon matters of national 

environmental significance, as defined 

under the Commonwealth 

Environment Protection and Biodiversity 

Conservation Act 1999 (EPBC Act) (Section 

2.2.1), an assessment under the 

EPBC Act may be required. Similarly, 

where a project displays a potential for 

significant environmental impacts or community 

concern, the provisions of the 

Victorian Environment Effects Act 1978 

may also be triggered. 

In November 2003, Santos sought 

determinations from the Commonwealth 

Environment and Heritage Minister and 

the Victorian Minister for Planning regarding 

the required level of environmental 

assessment under the respective 

acts. Santos was subsequently advised 

that Commonwealth environmental assessment 

under the EPBC Act will be 

undertaken through Preliminary Documentation 

and that the Victorian environmental 

assessment will require the 

preparation of an Environment Report 

under the Pipelines Act 1967. Both the 

Preliminary Documentation and the Environment 

Report (this document) are 

required to be available for public review 

and comment. 

Figure 2.1 provides a flow chart of the 

approval processes applied to the Casino 

Gas Field Development. 

In addition, a number of technical approvals 

are required under a range of 

Commonwealth and State legislature. 

These are summarised in Table 2.1 and 

discussed in detail in the following sections. 

2.2 Planning and 

Environmental Approvals 

2.2.1 EPBC Act 1999 

The EPBC Act enables the Commonwealth 

to join with the States and Territories 

in a national approach to 

environment protection and biodiversity 

conservation. Under the EPBC Act, actions 

that are likely to have a significant 

Table 2.1 

impact on a matter of national environmental 

significance will trigger Commonwealth 

assessment. 

Matters defined as nationally significant 

include the presence of: 

• A World Heritage property. 

• A Ramsar wetland of international 

importance. 

• Nationally threatened animal and 

plant species and ecological communities. 

• Internationally protected migratory 

species. 

Summary of key regulatory approvals 

Element Legislation Approval 

Offshore well 

drilling 

Completion of 

offshore 

production wells 

Offshore 

pipeline 

HDD shore 

crossing 

Onshore 

pipeline 

(includes HDD) 

Commonwealth Petroleum 

(Submerged Lands) Act 1967 



Victorian Petroleum 


Victorian Coastal Management 

Act 1995 



Victorian Coastal Management 

Act 1995 

Victorian National Parks Act 

1975 

Victorian Land Act 1958 

Victorian Pipelines Act 1967 

Victorian Land Act 1958 

Approval to drill 

Environment plan acceptance 

Drilling rig safety case 

Production licence 

Consent to construct and install a 

facility 

Consent to use a facility 

Pipeline licence 

Consent to construct a pipeline 

Consent to operate a pipeline 

Consent for the use or development of 

coastal crown land 

Pipeline licence 

Consent to construct a pipeline 

Consent to operate a pipeline 

Consent for the use or development of 

coastal crown land 

Consent to enter a National Park 

Authority to cross crown land 

Pipeline permit to own and use 

pipeline 

Pipeline licence to construct and 

operate a pipeline 

Authority to cross crown land 



• Commonwealth land and marine 

area(s). 

• Nuclear action(s). 

A referral and assessment process determines 

the application of the EPBC 

Act, which involves: 

1. The proponent submitting a referral 

detailing project information, and the 

proponent’s assessment of the 

project’s implications on the abovelisted 

criteria. 

2. The referral is posted on the Commonwealth 

Department of Environment 

and Heritage (DEH) website 

(www.deh.gov.au) and public comment 

is invited over a ten-day period. 

3. The Federal Minister for Environment 

and Heritage makes a determination 

on whether the project is deemed to 

be a controlled action (i.e., potential 

for significant impacts on a matter of 

national significance) 20 days after 

lodgement of the referral. If a controlled 

action, then Commonwealth assessment 

of the project under the 

EPBC Act is required. 

Assessment under the EPBC Act may 

take one of four paths: 

1. Preliminary Documentation. 

2. Accreditation of State assessment 

process. 

3. Public Environment Report. 

4. Environmental Impact Statement. 

In December 2003, the Casino Gas Field 

development was determined to be a 

controlled action under the EPBC Act 

based on the lack of certainty in construction 

timing and pipeline alignments 

and therefore the potential for the proposed 

development to impact upon blue 

whales, and to a lesser degree, listed 

terrestrial flora and fauna. Subsequently, 

DEH have advised that assessment will 

be by Preliminary Documentation, which 

includes public exhibition of the Preliminary 

Documentation for 20 business days 

and invitation to lodge submissions. 

Santos is required to address any submissions 

raised in a supplementary report 

to DEH, which together with the 

Preliminary Documentation, will enable 

the Federal Minister for Environment and 

Heritage to assess the project. 

2.2.2 Environment Effects Act 1978 

Under the Victorian Environment Effects 

Act 1978, the Minister for Planning may 

require that a proponent prepares an 

Figure 2.1 

Victoria 

Seek Planning Minister's 

determination 

Minister advises EES 

is not required 

Prepare Environment Report 

under Pipelines Act 1967 

Pipeline Permit application 

lodged, supported by 


(public notice) 

DPI and DSE assessments 

Pipeline Permit granted 

Submit safety case – Onshore 

Environmental Management 

Plan & offshore Environment 

Plan (Vic waters) 

Onshore and Victorian offshore 

Pipeline Licences granted 

Final project approvals 

(granted sequentially): 

• Consent to Construct 

• Consent to Operate 

DEH 

DPI 

DSE 

EES 

EPBC 

Commonwealth 

NO 

Department of Environment & Heritage 

Department of Primary Industries 

Lodge EPBC Act Referral 

(20 day public review) 

Is it a "controlled action"? 

YES 

Submit Preliminary 

Documentation (20 day public 

notice and review) 

DEH EPBC Act assessment 

Submit offshore Environment Plan 

for drilling and offshore pipeline 

(Commonwealth waters) 

Approved to drill 

Commonwealth Pipeline Licence 

and Production Licence granted 

Department of Sustainability & Environment 

Environment Effects Statement 

Environment Protection & Biodiversity Conservation 

Casino Gas Field Development lead environmental approvals process 

flow chart 



Environment Effects Statement for a development 

proposal. In determining the 

application of the Environment Effects 

Act 1978 to a development proposal, the 

Minister for Planning must take into account: 

• The character of the receiving environment. 

• Any potential impacts of the proposal. 

• The resilience of the environment to 

cope with change. 

• The level of confidence in impact prediction. 

• The presence of planning or policy 

framework. 

• Statutory decision-making processes. 

• The degree of public interest. 

The Minister for Planning has determined 

that the magnitude and significance of 

potential impacts would not necessitate 

the preparation of an EES on the basis 

that: 

• The coastal crossing is adjacent to 

that of the Minerva Project, using similar 

horizontal directional drill (HDD) 

techniques including drilling from outside 

the Port Campbell National Park. 

• Construction of the onshore pipeline 

is adjacent to, or within, existing gas 

pipeline easements 1 . 

• The existing TXU gas plant is used 

for processing of the Casino field gas. 

• An Environment Report describing 

the potential impacts of the pipeline 

development and proposed environment 

management measures is to 

be prepared by Santos to the satisfaction 

of the Department of 

Sustainability and Environment (DSE) 

and the Department of Primary Industries 

(DPI), and then exhibited for 

public comment in conjunction with 

the pipeline permit application. 

• A report on the environmental outcomes 

of the project to the post-construction 

stage is to be provided to 

DSE (and DPI) by Santos. 

Accordingly, this Environment Report has 

been prepared in support of the pipeline 

permit application under the Pipelines 

Act 1967, which will only be granted following 

advice on the project from the 

Minister for Planning and the Minister for 

Environment and Conservation. 

2.2.3 Planning and Environment 

Act 1987 

In Victoria, planning approvals are governed 

by the Planning and Environment 

Act 1987. This Act regulates the use and 

development of land through planning 

schemes and the granting of planning 

permits. 

The onshore part of the pipeline for the 

Casino Gas Field Development is located 

within the Corangamite Shire and 

traverses land zoned as environmental 

rural zone (ERZ), rural use zone (RUZ) 

and special use zone (SUZ) 2 . By definition, 

a pipeline development in these 

zones would require a planning permit 

as a utility installation. However, by virtue 

of Section 12(h) of the Pipelines Act 

1967, separate planning approvals are 

not required as land use is taken into 

account when approving the pipeline 

route. 

Under the Pipelines Act 1967, ancillary 

facilities such as valve stations are 

deemed to be appurtenances to the pipeline 

and are not gas processing facilities 

as such, and do not require separate 

planning approval. 

2.2.4 Coastal Management Act 1995 

Installation of the pipeline on the seabed 

within Victorian waters (out to the 3-nm 

limit) and by horizontal directional drilling 

beneath the surface of the Port 

Campbell National Park (i.e., coastal 

Crown Land) will require consent for the 

use and development of coastal Crown 

Land. An application will be lodged with 

the Department of Sustainability and Environment 

under Part 4, Sections 37 and 

38 of the Coastal Management Act 1985. 

2.2.5 Native Title 

The Commonwealth Native Title Act 1993 

applies indigenous Native Title rights, 

unless extinguished by freehold title or 

the validation of certain acts. The Act 

also sets out procedural requirements 

and potential entitlements to compensation 

when an action may impact on native 

title rights. The Pipeline Permit 

cannot be granted by the minister until 

DPI are satisfied that a relevant procedure 

under the Commonwealth Native 

Title Act 1993 has been followed. 

Santos has sought advice from the DSE 

Crown Land Management on an appropriate 

process who advised that a notification 

and acquisition process should 

be pursued under Section 24KA of the 

Native Title Act 1993. This involves: 

1. Notification of intentions to seek 

easements over land that may be subject 

to native title and invitation to 

make a submission on the proposed 

activity in relation to their native title 

rights and interests. 

2. If there are no registered native title 

claimants, Native Title Services Victoria, 

an indigenous community native 

title representative body, has 28 

days to make a submission on behalf 

of any other person or party that they 

certify as having a relevant native title 

interest in the area concerned. 

3. Santos Ltd must address all submissions 

that are received within the 28- 

day period, and attempt to resolve 

any relevant issues that have been 

raised. 

4. Victorian Government policy allows a 

period of up to 6-months, from the 

date of the notice, for resolution of 

issues. 

5. The Manager of the Indigenous Land 

and Resource Management Policy 

Unit of DSE will accept that submissions 

have been resolved where there 

is evidence that native title parties 

agree to the future act. Alternatively, 

where a resolution can not be reached 

Santos must provide evidence that 

negotiations have been conducted in 

good faith. 

There are currently no native title claims 

over any areas affected by the Casino 


Additional to the requirements of the Native 

Title Act, the preservation and protection 

of Aboriginal areas, sites or 

objects is afforded under the provisions 

of the Aboriginal and Torres Strait Islander 

Heritage Protection Act 1984. This 

Commonwealth Act supplements the 

state heritage protection legislation, 

namely the Victorian Archaeological and 

Aboriginal Relics Preservation Act 1988. 

The provisions of these acts with regard 

to heritage approvals are applied during 

the environmental assessment of route 

investigations and impacts prior to the 

granting of project approvals. 

1 In its submission to DPI Santos committed to 

following existing easements, where practicable. 

Where technical or landuse considerations prevent 

the use of existing easements the pipeline alignment 

has been selected in consultation with relevant 

landholders and regulatory authorities. 

2 Shire of Corangamite Planning Scheme. 



Santos has formed an excellent working 

relationship with the Framlingham Aboriginal 

Trust as a result of previous development 

projects in the region and is 

committed to establishing appropriate 

heritage management agreements. 

2.2.6 Net Gain Policy 

The principle of net gain is embodied in 

the Victorian Government’s Native Vegetation 

Management Framework (DNRE, 

2002a). The framework sets out goals 

for native vegetation management. The 

primary goal is a reversal, across the 

entire landscape, of the long-term decline 

in the extent and quality of native 

vegetation, leading to a Net Gain. 

Net gain is where losses of native vegetation 

and habitat are first minimised 

and then more than offset by commensurate 

gains in habitat hectares. A habitat 

hectare is an equivalence measure of 

the quality and quantity of native vegetation 

that can be applied across the state. 

While net gain recognises that natural is 

best, it is possible to recover both the 

extent and quality of native vegetation 

through management. Impacts to native 

vegetation have been minimised through 

appropriate route selection. Further impact 

reductions can be achieved by minimising 

the extent of significant vegetation 

removal at sensitive sites such as 

roadsides and creek crossings, by applying 

appropriate management measures 

such as narrowing the right-of-way 

(ROW) clearing and maintaining canopy 

trees (see Section 6.8). 

The application of net gain to the Casino 

Gas Field Development is subject to discussion 

with the DSE. While it is recognised 

that buried pipelines have potential 

environmental impacts that are largely 

temporary in nature, net gain is intended 

to offset significant vegetation losses arising 

from developments with permanent 

environmental effects (such as those requiring 

a permanently cleared easement 

through forest). Santos will work with 

DSE to develop an appropriate strategy 

that reflects the minor and temporary 

impacts associated with the Casino Gas 


2.3 Well Development 

Approvals 

2.3.1 Commonwealth Petroleum 


The development and operation of the 

offshore production wells within Commonwealth 

waters will require a range of 

approvals under the provisions of the 

Commonwealth Petroleum (Submerged 

Lands) Act 1967. Approvals include a 

production licence, approvals to drill and 

test wells, approval to construct and install 

facilities and consent to use facilities. 

The Commonwealth Department of Industry, 

Tourism and Resources (DITR) 

grants the production licence. Day-today 

administration of petroleum resources 

in Commonwealth waters 

offshore from Victoria is delegated to the 

Victorian DPI as the designated authority, 

and so approvals to drill, construct 

and install wells are issued by DPI. Licences 

and approvals will only be granted 

following EPBC Act approval. 

2.4 Pipeline Approvals 

2.4.1 Commonwealth Petroleum 


The offshore section of pipeline from the 

well field to the 3-nm Victorian State limit 

occurs in Commonwealth waters and will 

require a pipeline licence under the provisions 

of the Commonwealth Petroleum 

(Submerged Lands) Act 1967. 

The pipeline licence application requires 

a risk-based Environment Plan to be submitted 

to DPI. A pipeline licence application 

will be made once approval has been 

received under the EPBC Act. 

2.4.2 Victorian Petroleum 


The offshore pipeline in Victorian waters, 

from the 3-nm limit to the mean low 

water mark, will require licensing under 

the Victorian Petroleum (Submerged 

Lands) Act 1982. Whilst not specified in 

the Act, a risk-based Environment Plan 

will be submitted to DPI with the pipeline 

licence application. 

It is anticipated that a single Environment 

Plan will be prepared for all offshore 

development activities. 

2.4.3 Pipelines Act 1967 

In Victoria, onshore natural gas pipelines 

with an operating pressure above 

1,050 kPa require licensing under the 

Pipelines Act 1967. Santos expects operating 

pressures in the Casino pipeline 

to be greater than 1,050 kPa. Pipeline 

approvals are a two stage process: the 

first being an application for a pipeline 

permit to own and use the pipeline; the 

second being an application for a pipeline 

licence to construct and operate the 

pipeline. Section 20 of the Pipelines Act 

1967 authorises pipeline construction and 

operation through or over Crown land. 

The Pipelines Act 1967 is administered 

by Minerals and Petroleum Victoria 

(MPV), and relates to the onshore pipeline 

from the low water mark at the coast 

to the TXU WUGS facility, and therefore 

includes the horizontal directional drill 


This Act requires that an assessment of 

potential environmental effects and proposed 

mitigation measures be submitted 

in support of the permit application. 

This application is exhibited for public 

comment. The proponent is then required 

to submit an environmental management 

plan in support of a licence application. 

Key steps in the granting of approvals 

under the Pipelines Act 1967 include: 

1. An application for a pipeline permit 

(to own and use) supported by an 

Environment Report (i.e., this document). 

The permit application is advertised 

for at least 30 days for public 

comment. 

2. An application for a pipeline licence 

(to construct and operate) supported 

by a safety case document. 

3. Proponent submissions leading to the 

granting of final project approvals, 

which are issued in sequence as compliance 

is verified, including: 

– Consent to construct. 

– Consent to operate (supported by 

operations safety and environment 

management plan). 

2.4.4 Easement Acquisition 

The granting of an easement over land 

through which the pipeline is to be constructed 

provides present and future protection 

of the asset by identifying it on 

titles and property plans. The easement 

prevents inappropriate development over 

the pipeline, whilst providing for the continuation 

of existing land uses, where 

they are not inconsistent with the construction 

and operation of a pipeline. 

Santos has committed to following existing 

easements for the onshore pipeline, 

where practicable, to consolidate encumbrances 

on properties with developed 

corridors. Where this is not practicable, 

new easements will be sought. 

The following section outlines, step-bystep, 

the process Santos is following for 

gaining land access for the onshore pipeline. 



1. Title searches: Santos has identified 

potential pipeline corridors within a 

broad study area, and completed title 

searches of all land parcels to 

establish the status and ownership 

of the land. 

2. Consent to survey: Santos approached 

each landholder and occupier 

in person to seek written 

voluntary consent to enter private 

property for the purpose of conducting 

engineering and environmental 

surveys. The landowners and occupiers 

were informed of the proposed 

project with the aim of establishing 

access arrangements. Details of title 

and landowner/occupier information 

and any issues that could affect the 

pipeline route were identified. Voluntary 

consent was provided for all properties 

along the preferred pipeline 

corridor. 

3. Pipeline Permit application: Santos 

will lodge a pipeline permit application 

under the provisions of the Pipelines 

Act 1967. The permit application 

will be advertised to enable public 

comment and affected landholders 

will be advised in writing. The permit 

application will identify all lands affected 

by the proposed pipeline and 

will be supported by this document. 

4. Easement agreements: Santos will 

seek to negotiate easement agreements 

with affected landholders. The 

easements (once agreed) will be registered 

on the relevant titles. Compensation 

will be paid for the impact 

of the easement on the property, 

based on assessments obtained from 

a registered independent valuer. 

Plans for each easement to be acquired 

will be provided to the valuer 

for assessment. The valuer will make 

contact with landowners to establish 

any pertinent information and to inspect 

the land. Information from the 

centreline and cadastral survey will 

be used to produce the easement 

plans required for valuations. Every 

reasonable effort will be made to acquire 

easements through voluntary 

agreement. Where this can not be 

achieved, Santos may seek to compulsorily 

acquire easements. Compensation 

for compulsory acquisition 

will be paid in the same manner as 

for voluntary easement agreements. 

2.5 Subsequent Approvals 

In addition to the key planning and environmental 

approvals, a range of additional 

approvals is required to facilitate 

the implementation of the project. These 

approvals shall be sought following the 

granting of the pipeline and production 

licences and generally relate to construction 

activities. Construction approvals 

shall be sought by either the proponent 

or the construction contractor, depending 

on the activity, once the pipeline licences 

have been granted. The 

subsequent approvals are identified in 

Table 2.2. 

Table 2.2 

Subsequent approvals 

Activity Legislation Approval Authority 

Removal of native vegetation Pipelines Act 1967 Considered under Pipelines Act 

1967 approvals 

Impacts to listed flora or fauna 

species or habitat 

Construction works on or 

beneath waterway 

Construction across or beneath 

roads 

Drilling of a water well or drawing 

from existing water sources for 

construction (e.g., HDD, dust 

suppression, hydrotesting) 

Operation of construction 

equipment in the open air during 

a Total fire ban 

Disturbance to known Aboriginal 

heritage sites 

Disturbance to known Register of 

the National Estate (RNE) sites 

Disturbance to known historic 

heritage sites 

Flora and Fauna Guarantee Act 

1988 

Victorian rare or threatened 

species (VROTS) permit 

Water Act 1989 Works on waterway permit Corangamite Catchment 

Management Authority 

Local Government Act 1989 Works permit Corangamite Shire, VicRoads 

Water Act 1989 Licence to drill and/or draw water Southern Rural Water 

Country Fire Authority Act 1958 

Archaeological and Aboriginal 

Relics Preservation Act 1972 

Commonwealth Australian 

Heritage Commission Act 1975 

Permit under Section 40 to ‘Use 

fire in the open air’ 

Consent to destroy 

Approval to disturb 

DPI 

DSE 

Country Fire Authority (CFA) 

Framlingham Aboriginal Trust, 

Aboriginal Affairs Victoria 

Australian Heritage Commission 

Victorian Heritage Act 1995 Approval to disturb Heritage Victoria 




3. Stakeholder Consultation 


Stakeholder 1 consultation is a requirement 

of the project permitting process. 

Santos sees it as an effective mechanism 

for establishing relationships with 

key individuals and organisations with 

an interest in the project. It also builds 

on those relationships in a way that both 

encourages stakeholders to express their 

views in a receptive and constructive 

atmosphere whilst at the same time providing 

opportunity for the delivery of accurate 

information about the project in a 

timely fashion. The overall goal is a situation 

where stakeholder concerns are 

actively sought, considered and acted 

upon, as appropriate, during the planning 

and design phase of the project. 

In November 2003, Santos prepared a 

stakeholder consultation plan to guide 


project team in the implementation of an 

effective consultation program. 

The principal objectives of stakeholder 

consultation for the project are to: 

• Identify relevant stakeholders. 

• Provide appropriate opportunities for 

involving and communicating with relevant 

stakeholders. 

• Provide a process in which project 

planning can take account of issues 

raised by stakeholders at the earliest 

possible stage. 

• Provide a means for recording all initiatives 

in which consultation is undertaken, 

issues are raised and 

responses to these issues are provided 

to stakeholders. 

Specifically, the stakeholder consultation 

process will: 

• Provide accurate information about 

the project to stakeholders in a timely 

fashion, thereby reducing the potential 

for stakeholder disaffection which 

can result from a misunderstanding 

of the project and, particularly for local 

communities, either a real or perceived 

exclusion from the environmental 

assessment and approvals 

process. 

• Ensure that local communities and 

government are properly informed 

about the project and that there are 

adequate and timely opportunities for 

these stakeholders to provide input 

into the environmental assessment 

and approvals process and express 

any relevant problems, difficulties or 

concerns, they may have. 

• Minimise the risk of delays to project 

permitting so as to deliver approvals 

as scheduled. Ensuring that issues 

or concerns are dealt with during the 

environmental assessment and approvals 

process rather than after 

submission of the required documentation. 

• Ensuring that the relevant regulatory 

requirements are being met with regard 

to appropriate stakeholder input 

to the process. 

• Provide the groundwork for final 

presentation of the environmental 

assessment findings and ongoing 

consultation through construction, 

operation and (eventually) 

decommissioning. 

3.1 Relevant Stakeholders 

A diverse range of stakeholders has been 

identified as having an interest in the 

proposed Casino Gas Field Development. 

Table 3.1 identifies the stakeholders 

and groups them into broad 

categories reflecting their differing interests. 

It also identifies the key issues 

raised by various parties during consultation 

undertaken to date. 

3.2 Stakeholder Consultation 

Program 

Santos has been undertaking petroleum 

exploration and production activities in 

southwest Victoria since 2000, and has 

consequently been undertaking consultation 

with relevant stakeholders on an 

ongoing basis since. With the proposed 

Casino Gas Field Development, Santos 

has embarked on a program of consultation 

that has focused specifically on those 

stakeholders potentially affected by this 

proposal. 

The Casino Gas Field Development 

stakeholder consultation process has utilised 

a number of mechanisms, both formal 

(e.g., scheduled presentations and 

meetings) and informal (e.g., visits to 

landholders and telephone conversations), 

to communicate with stakeholders. 

These mechanisms are listed below. 

• Project briefings – project briefings 

have been held with key stakeholders 

at key project milestone points 

(e.g., project inception, environmental 

assessment scoping, study findings 

and mitigation planning). 

• One-on-one technical discussions – 

one-on-one meetings with stakeholders 

for information dissemination and 

obtaining stakeholder input to technical 

issues. 

• Lands and easement meetings – held 

with landholders and occupiers, land 

managers and Aboriginal communities 

in relation to land access and 

easement negotiations. 

• Information releases – dissemination 

of information to the wider community, 

including: 

– Media releases. 

– Public notices advising of invitations 

to comment on project information 

and permit applications. 

– Information mail-outs (e.g., project 

brochures and notifications). 

1 A stakeholder is defined as any group or individual 

that has an interest in the project or may be 

affected in any way by the project. 



Table 3.1 

Key stakeholders 

Stakeholder 

Category 

Organisation/Agency/Role 

Key Issues Raised 

Landholders Private landholders along the onshore pipeline route options Impact to existing and future farm operations 

Construction duration and timing 

Pipeline alignment location 

Compensation 

Impacts of previous gas facility and pipeline 

developments 

Commercial fishers Apollo Bay Professional Fishermen’s Association 

Port Campbell Professional Fishermen’s Association 

Port Fairy Professional Fishermen’s Association 

Warrnambool Professional Fishermen’s Association 

Well-field exclusion zones 


Interaction during construction 

Compensation for lost catch 

Portland Professional Fishermen’s Association 

Victorian Abalone Divers Association 

Seafood Industry Victoria 

Indigenous groups Framlingham Aboriginal Trust Heritage assessment process 

Heritage management during construction 

Interest groups Port Campbell Environment Group 

Shipwreck Coast Regional Tourist Authority 

Shipwreck Coast Tourism 


Additional shore crossings 

Potential for impacts to significant marine habitat 

Port Campbell Recreational Fishers Association 

Port Campbell Progress Association 

Victorian Farmers Federation (VFF) 

Construction traffic 

Condensate transport 

Adverse impacts to local community 

Gas infrastructure rationalisation 

Minimising new easements 

Campbells Creek crossing water quality 

Recreation and tourism 

Politicians 

Victorian State Premier 

Victorian Minister for Energy and Resources 

Victorian Minister for Innovation, Industry and Regional 

Development 

Victorian Minister for Planning 

Corangamite Shire Councillors 

Local State and Federal MPs 

Regulatory approvals 

Capital expenditure 

Regional development 

Landholder liaison 

Potential environmental impacts 


Government revenue 

Lead regulatory 

authorities 

Government 

technical 

advisory/land 

management 

agencies 

Victorian Department of Primary Industry (DPI), Minerals and 

Petroleum 

Victorian Department of Sustainability and Environment (DSE) 

Commonwealth Department of Environment and Heritage 

(DEH) 

Commonwealth Department of Industry, Tourism and 

Resources (DITR) 

DPI Fisheries 

Environment Protection Agency (EPA) 

DSE, Flora and Fauna 

Parks Victoria 

Corangamite Catchment Management Authority (CCMA) 

Glenelg-Hopkins Catchment Management Authority (GHCMA) 

Corangamite Shire Council 

Regulatory approvals 

Potential for impacts in the Port Campbell National 

Park 


Potential impacts to whales 

Potential environmental impacts 



TXU WUGS facility upgrades 

Regulatory approvals process 

Campbells Creek crossing 

Potential impacts to whales 

Impacts on terrestrial habitat 

Impacts on terrestrial flora and fauna 

Impacts on marine habitat 

Recreation and tourism 



Table 3.1 

Key stakeholders (cont’d) 

Stakeholder 

Category 

Government 

technical 

advisory/land 

management 

agencies (cont’d) 

Infrastructure and 

utilities 

Moyne Shire Council 

Western Coastal Board 

Department of Human Services 

Organisation/Agency/Role 

Department of Victorian Communities - Aboriginal Affairs 

Victoria 

Department of Industry Innovation and Regional Development 

WorkSafe 

Country Fire Authority 

BHP Billiton 

TXU 

Woodside Energy Limited 

Corangamite Shire Council 

GasNet 

Optus 

Southern Rural Water 

Telstra 

Key Issues Raised 

Construction traffic 


TXU WUGS facility upgrades 

HDD water resources 

Impacts on archaeological sites 

VicRoads 

Media Cobden Times General interest 

Warrnambool Standard 

Camperdown Herald 

Colac Herald 

Proximity to existing infrastructure 

Construction timing (potential for simultaneous 

construction of pipelines and shore crossing with 

Woodside) 

Reinstatement 

Table 3.2 

Communication 

Activity 

Casino Gas Field Development consultation summary 

Subject 

Date 

Media release Casino gas sales agreement with TXU September 2003 

Media release Casino 3 appraisal drilling successful November 2003 

Invitation for public 

comment 

Stakeholder briefings 

Mail-out 


EPBC referral lodged on DEH website 

for public comment 

Project development inception 

briefings to key stakeholders 

Notification to commercial fishers of 

timing of planned bathymetry survey 

Initial briefings to landholders – access 

consent requested 

November 2003 

December 2003 

December 2003 

January 2004 

Landholder liaison Pipeline route options February 2004 

Media release 


comment 

Media briefings 

Casino front-end engineering and 

design contract awarded 

EPBC Preliminary Document lodged 

on DEH website and advertised for 

public comment 

Project briefings to regional Victoria 

media 

February 2004 

March 2004 

March 2004 

Landholder liaison Pipeline route survey April 2004 

Landholder liaison Easement compensation negotiations May 2004 

Mail-out 


comment 

Notification to landholders of Pipeline 

Permit application 

Pipeline Permit application and 

Environment Report (this document) 

May 2004 

May–June 2004 

– Project information displays at regional 

and metropolitan centres. 

• Project information telephone number 

– to provide the opportunity for stakeholder 

input. 

Site inspections of the project area were 

conducted as required to support an increased 

understanding of the development 

proposal and the on-ground 

technical issues. 

Table 3.2 lists the communication activities 

undertaken specifically in relation to 

the development of the Casino gas field 

at the time of preparing this Environment 

Report. Further consultation is planned 

for the detailed design, construction and 

operation phases, including the timely 

dissemination of project information (e.g., 

brochures) to stakeholders. 

3.3 Consultation Records 

A project specific stakeholder database 

has been established for the Casino Gas 

Field Development to record the contact 

details of relevant stakeholders and to 

document consultation undertaken and 

the relevant outcomes, such as commitments 

and requirements for the construction 

phase. 



This record of consultation will also serve 

due process requirements for regulatory 

approvals and easement acquisition, and 

also enable generation of the property 

line list 2 for construction and operation 

purposes. 

2 The property line list is a standard pipeline construction 

document that identifies, in sequential order, 

property tenure information as well as property 

specific requirements for route planning and construction 

activities. Following construction, the stakeholder 

database can be carried over for use in the 

operations phase. 


4. Project Rationale 


4.1 Australia’s Gas Industry 

Use of natural gas in Australia for primary 

energy generation has risen from 

almost zero in 1970 to nearly 20% in 

2001 (Figures 4.1 and 4.2). Approximately 

3.5 million natural gas users exist 

Australia-wide, of which 3.4 million are 

domestic users and 105,000 are from 

the commercial and industrial sectors 

(AGA, 2004). 

During 2001, Victoria represented 25% 

of Australia’s natural gas consumption 

(Figure 4.3) with approximately 1.48 million 

domestic natural gas users. Commercial 

and industrial users accounted 

for 46.8% of the total consumption of the 

176 PJ of natural gas in Victoria during 

this period (AGA, 2004). 

The Australian gas industry has historically 

been characterised by geographically 

separate markets where a single 

basin supplied the gas to the major markets 

via a single transmission pipeline. 

However, the Australian gas market has 

been gradually moving towards an integrated 

market, where gas is traded 

across state boundaries and between 

markets via a network of transmission 

pipelines (Figure 4.4). 

4.2 Rationale for Development 

The demand for natural gas is increasing 

steadily and is the driver for the development 

of the Casino gas field. 

Santos, as operator of the Commonwealth 

exploration permit area Vic/P44, 

is obliged to explore for petroleum resources 

and, if feasible, develop any discovered 

resources to meet consumer 

demand. 

The Casino Gas Field Development is 

scheduled to come on line in early 2006 

and is expected to operate for some 12 

years at an initial production rate of approximately 

106 terajoules per day 

(TJ/d). Santos has negotiated a sales 

agreement with TXU for gas from the 

Casino Gas Field Development to be 

piped to the TXU WUGS facility for 

processing and distribution. In the shortterm, 

gas from the Casino Gas Field 

Development is expected to fill increasing 

consumer demand in Victoria during 

the winter of 2006. 

In the medium-term and longer-term, the 

gas will be available for distribution into 

the Victorian and South Australian gas 

markets via a network of existing transmission 

pipelines (see Figure 4.4). The 

gas may be temporarily stored in depleted 

underground gas reservoirs at the 

existing TXU WUGS facility at Iona, 

awaiting withdrawal during periods of 

peak demand. 

4.3 Benefits of the Proposal 

In addition to the immediate and shortterm 

gas requirements of TXU, the Casino 

Gas Field Development will 

potentially provide significant benefits to 

Victoria and Australia. These are discussed 

below. 

Petajoules (PJ) 

1,200 

1,000 

800 

600 

400 

200 

4.3.1 Supplementation of Existing 

Gas Reserves 

The Casino Gas Field Development has 

an estimated 300 bcf of gas-in-place 

(GIP), of which approximately 211 bcf 

are expected to be recoverable for sale 

to consumers. To put this is into perspective, 

between June 2002 and July 

2003 Victorian gas fields produced approximately 

174 bcf of natural gas 1 . 

Therefore, the gas reserves in the Casino 

Gas Field Development represent 

about one and a half years of additional 

gas supply for Victoria. 

4.3.2 Security of Supply 

Approximately 90% of Victoria’s current 

gas supplies come from Esso/BHP-operated 

gas fields in the Gippsland Basin 

in eastern Victoria, whilst the vast majority 

of South Australia’s gas consumers 

are supplied by the Santos-operated gas 

fields of the Cooper and Eromanga basins 

in Central Australia (AGA, 2004). 

Gas fields in the Otway Basin largely 

supply the balance, or peak demand, in 

both states. 

Recent gas shortages due to plant failure 

in Victoria (Longford in 1998) and 

South Australia (Moomba in 2004) have 

highlighted the need for alternative gas 

supplies. The Casino Gas Field Development 

provides an alternative independent 

gas supply, improving security of 

supply and reliability in the Victorian and 

South Australian gas markets. 

The Casino Gas Field Development will 

lead to a greater security of supply for 

south eastern Australia and this security 

of supply is further enhanced by TXU’s 

0 

1979 1982 1985 1988 1991 1994 1997 2000 

Year 

Source: AGA, 2004 

Figure 4.1 Total natural gas consumption in Australia, 1979-2001 



ability to store processed Casino gas in 

depleted gas reservoirs at the TXU 

WUGS facility at Iona for later withdrawal 

to meet peak demand. 

4.3.3 Increased Gas Supply 

Competition 

Victorian gas fields in the Otway Basin 

are already linked to the South Australian 

and Victorian gas markets by the 

recently completed SEAgas Pipeline and 

GasNet’s existing Southwest Pipeline, 

respectively, and therefore present additional 

gas reserves to both these markets. 

This generates competition between 

gas producers ‘at the wellhead’. 

4.3.4 Commercial Benefits 

Gas exploration and production in the 

Otway Basin has generated significant 

10.2% 

27.1% 

13.1% 

27.5% 

Source: AGA (2004). 

6.3% 

11.6% 

1980-81 

5.3% 

2000-01 

Oil 

19.7% 

Black coal 

Renewables 

Natural gas 

Brown coal 

44.8% 

34.4% 

Figure 4.2 Australia’s primary energy 

consumption by fuel type, 1980-81 and 

2000-01 

economic activity at the local, regional, 

state and national levels. Whilst relatively 

modest in size, the Casino Gas 

Field Development will contribute significantly 

to economic activity with a total 

capital expenditure of approximately 

A$200 million for the project. 

The project’s total construction workforce 

is estimated to be 320 personnel comprising 

250 for the offshore pipe lay 

(mostly Australian workers), 25 for offshore 

drilling and 45 for onshore pipeline 

construction and HDD operations as 

well as additional project management 

and other technical support services. 

Where practicable, Santos and its contractors 

will seek to provide opportunities 

for local contractors and individuals 

to be engaged on the project. 

A significant proportion of the total capital 

expenditure will be directed to pipe 

and wellhead infrastructure manufacture 

and construction. Australian manufacturers 

will be invited to bid on the supply of 

pipe and pipe coating. Similarly, Australian 

construction firms will be invited to 

bid on the onshore pipeline construction 

and HDD. Offshore drilling and pipeline 

construction is limited to a small number 

of international companies with the specified 

capabilities, however, Australian 

companies will be invited to bid for offshore 

construction logistical support activities, 

such as helicopter transport and 

supply and tender vessels. 

During construction, local economic opportunities 

will be provided through the 

provision of support services, which may 

include: 

• Labour supply (both skilled and semiskilled). 

• Construction services, such as 

earthmoving, concrete batching, road 

making, fencing and minor metal fabrication. 

• Support services for construction activities, 

such as equipment hire, motor 

vehicle hire, short-term 

accommodation, food and beverage 

supply, fuel supply and security patrols. 

During operations, the gas field and pipeline 

are likely to be operated under contract 

by personnel at the TXU WUGS 

facility, whilst technical support services 

will be provided by specialist contractors 

as required. Santos envisages that no 

dedicated field workforce will be required. 

25% 

Source: AGA (2004). 

14% 

8% 

2% 

14% 

37% 

Northern Territory 

South Australia 

Western Australia 

Queensland 

Victoria 

NSW/ACT 

Figure 4.3 Australia’s natural gas 

consumption by state, 2001 

When gas is produced from the Casino 

Gas Field Development, the Commonwealth 

government will receive revenue 

through the payment of resource rent 

tax and corporate tax and revenue will 

be received by the Victorian government 

through the redistribution of the goods 

and services tax (GST) from the Commonwealth. 

4.3.5 Potential Greenhouse Benefits 

Natural gas is recognised as having significantly 

less greenhouse gas emissions 

than alternate fossil fuels, particularly 

coal. A significant potential greenhouse 

benefit will arise where gas-fired electricity 

or gas water heating is selected 

over electricity derived from coal-fired 

power stations. 

4.4 Project Alternatives 

The development of the Casino gas field 

has required consideration of a range of 

alternatives that influence the commercial 

viability and feasibility of the project. 

1 Calculation based on Australian Petroleum Production 

and Exploration Association (APPEA) estimate 

of Victoria producing 15% of Australia’s total 

gas production for 2002–2003 (1156.7bcf) (APPEA, 

2004). 



Greater Sunrise 

from Papua New Guinea 

Bayu Undan 

Browse 

Basin 

21.4% 

Bonaparte Basin 

17.2% 

Darwin 

Gove 

Katherine 

Mataranka 

Daly Waters 

McArthur River 

Weipa 

0 

N 

km 

500 

Perth Basin 

0.6% 

Carnarvon 

Basin 

51.9% 

Onslow 

Carnarvon 

Geraldton 

Bunbury 

Dampier 

Mt Magnet 

Perth 

Port Hedland 

Windimurra 

Worsley 

Wiluna 

Newman 

WESTERN AUSTRALIA 

Leonora 

Broome 

Kalgoorlie 

Telfer 

Jundee 

Existing natural gas pipelines 

Natural gas pipelines under construction 

Proposed natural gas pipelines 

Mt Margaret 

Murrin Murrin 

Kambalda 

Esperance 

Reserves are shown as a percentage of total reserves. 

Estimated Australian gas reserves as at 1 January 2001 

157, 343 PJ (Geoscience Australia, 2002). 

Source: AGA (2004) and Encom Petroleum Information (2004). 

Figure 4.4 

NORTHERN TERRITORY 

Mereenie 

Tennant Creek 

Alice Springs 

Amadeus Basin 

0.2% 

Australia’s gas pipelines and gas fields 

Eromanga 

Basin 

Cooper/Eromanga 

Ballera 

Basins 

2.8% Moomba Cooper Basin 

SOUTH AUSTRALIA 

Beverley 

Otway Basin 

0.3% 

Mt Isa 

Cannington 

Noranside 

QUEENSLAND 

Gilmore (Field) 

Bunya 

Barcaldine 


Tamworth 

Adavale Basin 


mary energy sources of coal currently 

utilised in Victoria and South Australia. 

Renewable energy technology, such as 

wind farms and solar panels, involve 

higher energy costs and are unlikely to 

be able to meet the total, near-term energy 

demands in Victoria and South Australia. 

4.4.4 Alternative Development 

Scenarios 

During feasibility assessments, concept 

development studies examined several 

options for development of the Casino 

gas field before settling on the proposed 

option. These included: 

• Tie-in to the Minerva gas field or offshore 

pipeline. 

• Tie-in to the Woodside Otway Gas 

Project offshore pipeline. 

• Utilising the existing TXU onshore 

pipeline from the Heytesbury gas 

plant to the TXU WUGS facility. 

The first two options of tie-in to either the 

Minerva gas field or offshore pipeline or 

the Woodside offshore pipeline were discounted 

on technical and commercial 

grounds. Casino gas is much drier (i.e., 

contains less condensate) than that from 

the nearby fields, has very low levels of 

carbon dioxide and contains no nitrous 

oxides or sulphur oxides making commercial 

arrangements very complex and 

impossible to effectively monitor. There 

are also gas pressure differential factors 

that require an exclusive pipeline to transport 

Casino gas to the TXU WUGS facility. 

The Minerva option would also limit 

the market available for Casino gas to 

South Australian consumers via the 

SEAgas pipeline. 

Utilising the existing TXU onshore pipeline 

from the Heytesbury gas plant to the 

TXU WUGS facility was considered as 

an option to limit further pipeline development, 

particularly across the 

Campbells Creek valley. Whilst this option 

may be technically feasible, it was 

discounted based on future planned use 

of the pipeline by TXU. 

The Casino Gas Field Development utilises 

the existing TXU WUGS facility and 

consequently, the need for additional 

processing (albeit minor) and gas compression 

for transportation are avoided. 


5. Project Description 


The Casino Gas Field Development comprises 

the offshore production of gas and 

its transportation to shore in a dedicated 

pipeline to the existing TXU WUGS facility 

at Iona near Port Campbell for 

processing (Figure 5.1). The proposed 

development comprises the following 

components: 

• Drilling two offshore development 

wells using a floating semi-submersible 

drilling rig. 

• Installation of subsea wellheads on 

the seafloor in 70 m of water by a 

floating semi-submersible drilling rig. 

• Installation of a subsea pipeline (approximately 

36.7 km long and 300 

mm nominal diameter) on the seafloor 

by a pipe-lay vessel. Gas will 

flow from the wells via the subsea 

pipeline to shore. 


of the shore crossing from cleared 

farmland on the northern side of the 

Great Ocean Road at Two Mile Bay, 

approximately 2 km west of Port 

Campbell, to avoid disturbance to the 

surface of Port Campbell National 

Park and shoreline habitat. Two drill 

holes, each 1,573 m in length, will be 

required, one for the gas pipeline and 

the other for the control umbilical cable 

bundle. 

• Construction of an 11.5 km long onshore 

pipeline (300 mm nominal diameter) 

from the HDD shore crossing 

drill site to the TXU WUGS facility. A 

MLV compound will be constructed 

at the HDD site and over the pipeline 

easement after the completion of the 



TXU WUGS facility, prior to its distribution 

to Victorian and interstate customers 

through the existing pipeline 

TXU WUGS 

facility 


HDD pipeline section 

Optic fibre cable 

MEG pipeline 

Umbilical line 

Mainline valve site 


(11.5 km) 


(1.6 km) 

Casino 5 

Casino 4 

Subsea pipeline and control umbilical 

(36.7 km) 

2 subsea wells 

Figure 5.1 




network. A new gas processing plant 

is not required for the Casino Gas 


This chapter provides a description of 

the Casino Gas Field Development detailing 

technical specifications, the pipeline 

route selection process, and the 

construction, operations and 

decommissioning stages for the onshore 

and offshore components. 

5.1 Reservoir and Gas 

Specifications 

The Casino gas field is located about 

30-km southwest of Port Campbell at a 

depth of approximately 1,700 to 2,000 m 

below the seabed. The gas field is situated 

in the Waarre Formation, a geologic 

unit with two distinct lenses. The 

field is estimated to contain a total of 

about 300 bcf of gas, of which 211 bcf 

are estimated as recoverable reserves. 

The raw gas has very low carbon dioxide 


sulfur oxides or nitrous oxides, and 

is therefore within sales gas specifications. 


and condensate may be transported 

to shore with the gas and these will be 

removed at the TXU WUGS facility. 

5.2 Project Design 

Specifications 

The Casino Gas Field Development onshore 

pipeline will be buried for its entire 

length, emerging from ground only at the 

mainline valve site (near the coast) and 

at the entry point to the TXU WUGS 

facility. Offshore, the pipeline will be laid 

on the seafloor and is expected to bury 

itself over time where bottom conditions 

allow. 

The onshore pipeline will be designed to 

comply with the Australian pipeline standard 

AS2885.1 Pipelines - Gas and Liquid 

Petroleum. The offshore pipeline will be 

designed to comply with the DNV Offshore 

Pipeline Code. 

Design specifications may be subject to 

variation based on the finalisation of commercial 

negotiations and detailed design. 

Table 5.1 summarises the proposed pipeline 

design specifications. 

5.3 Pipeline Route Selection 

Santos has implemented a pipeline route 

selection process that considered social, 

environmental, engineering and financial 

criteria. Foremost in this process was 

the desire to find a pipeline alignment 

that is acceptable to local landowners. 

As for all linear infrastructure, route selection 

is the single most effective means 

of minimising social and environmental 

impacts, minimising costs and maximising 

engineering efficiency of a gas transmission 

pipeline. To this end, the 

alignment for the Casino Gas Field Development 

was chosen on the basis of 

extensive stakeholder consultation and 

detailed engineering and environmental 

field investigations. The primary objec- 

Feature 

Well Sites 

Table 5.1 

Pipeline and well design specifications 

Number of wells Two (Casino 4 and 5) 

Separation between Casino 4 and 5 wells 

Wellhead dimensions 

Exclusion zone for vessels in the vicinity 

Offshore pipeline 

Pipeline length (Casino 5 to HDD exit hole) 

Pipeline internal diameter 

External coating 


Pipeline length (HDD entry hole to the TXU WUGS facility), Option 4 

(Otway) with sub-option 4A, see Section 5.2. 

Standard construction ROW width 

Easement width 

HDD drill length 

6.5 km 

Specification 

1.8 m diameter by 2.4 m height above sea floor 

500 m radius 

36.7 km 

300 mm 

Fusion Bonded Epoxy (FBE), plus concrete coating ranging from 

40 mm to 80 mm thick or thick walled pipe for stabilisation 

11.5 km (excludes HDD section of 1.57 km) 

24 m 

15 m 

1.57 km 

HDD exit point 15 to 16 m water depth, Kilometre Point 36.715 

Pipeline internal diameter (raw gas line) 

Pipeline wall thickness (raw gas line) 

Monoethylene glycol umbilical internal diameter 

Monoethylene glycol umbilical wall thickness 

Pipe steel grade 

Maximum allowable operating pressure 

External corrosion coating – raw gas line 

External corrosion coating – MEG line 

Valve sites (incorporating pigging facility) 

Burial depth (average) 

Cathodic protection 

300 mm 

9.7 mm 

50 mm 

5.5 mm 

X70 

15,300 kPa 

Fusion Bonded Epoxy (FBE), 550 µm thickness 

HDPE 

One 

900 mm 

Impressed current 



tives were to minimise impacts on agricultural 

land and to avoid known constraints; 

the secondary objective was to 

fully understand constrained areas that 

cannot be avoided so that the impacts of 

pipeline installation can be planned for 

and properly managed through these areas. 

The key phases in the route selection 

process for the Casino Gas Field Development 

included: 

• Shore crossing site selection – the 

identification and assessment of four 

shore crossing options and the determination 

of a preferred shore 

crossing site. 

• Offshore pipeline alignment – a series 

of marine environmental and engineering 

investigations contributed 

to the assessment of offshore pipeline 

alignment options, leading to selection 

of the preferred option for the 

offshore pipeline alignment. 

• Onshore pipeline alignment – a progressive 

and iterative assessment of 

onshore pipeline alignment options 

from the preferred shore crossing to 

the TXU WUGS facility involving 

stakeholder consultation, environmental, 

engineering and construction 

assessments leading to the selection 

of a preferred onshore pipeline alignment. 

• Detailed Design – recording of the 

preferred onshore pipeline alignment 

with centreline survey and preparation 

of detailed design drawings of 

the alignment. 

These phases are discussed in detail in 

the following sections. 

5.3.1 Shore Crossing 

The selection of the preferred option for 

the shore crossing was the primary determinant 

in the overall alignment of the 

pipeline from the Casino gas field to the 

TXU WUGS facility. During the concept 

development stage, Santos committed 

to using HDD technology for the pipeline 

shore crossing to drill from sites outside 

of the Port Campbell and Bay of Islands 

National Parks to pre-empt impacts on 

the parks and shoreline habitats. 

In selecting the shore crossing options, 

the following key criteria were considered: 

• Horizontal directional drill length – 

HDD is limited by the length of the 

required drill (relative to the diameter 

of the drill hole). Current known length 

capability for a HDD of the required 

diameter for the Casino pipeline is 

approximately 1,600 m. As Santos 

had previously committed to locating 

the drill site outside of the Port 

Campbell National Park and Bay of 

Islands National Park, the distance 

between the park boundary and a 

point offshore where the water depth 

was at least 15 m (deep enough to 

enable access by the pipe lay vessel) 

needed to be less than 1,600 m 

in length. 

• Avoidance of significant environmental 

features – the HDD site was required 

to avoid significant natural 

vegetation and geological features. 

• Avoidance of nearshore reefs and 

minimisation of impacts on offshore 

reefs – in particular, the seaward terminus 

of the HDD needed to be located 

in an area devoid of nearshore 

reef outcrops. It was realised that, 

further offshore, crossing of some reef 

areas would be unavoidable. In those 

offshore areas, it was the intention of 

Santos to minimise the length of 

subsea pipeline that traversed reef 

areas. 

• Proximity to existing onshore gas 

pipeline easements – early in the 

project planning stage Santos committed 

to following existing onshore 

easements, where practicable, to 

minimise land use and ecological impacts. 

Subsequently, four potential shore crossing 

locations were identified for further 

investigation (Figure 5.2). They included: 

• Option 1: Flaxman’s Hill – south 

west of Nirranda South. 

• Option 2: Lover’s Nook – west of the 

Bay of Islands. 

• Option 3: Newfield Bay – east of the 

Timboon to Peterborough Road. 

• Option 4: Two Mile Bay – west of 

Port Campbell. 

Following preliminary engineering and 

environmental assessments and consultation 

with key stakeholders, Santos identified 

Option 4: Two Mile Bay as the 

preferred shore crossing location (see 

Figure 5.2). Table 5.2 highlights the detailed 

assessment undertaken of the 

shore crossing options. 

Santos proposes to locate the HDD site 

outside of the Port Campbell National 

Park to the west of BHP Billiton’s Minerva 

Project HDD site. The drill will then extend 

beneath the surface of Port 

Campbell National Park (but still through 

the park as tenure extends to the centre 

of the earth) to exit approximately 1,225 

m offshore, beyond the surf zone and 

nearshore reef habitat, at approximately 

the 15 to 16 m water depth. The total drill 

length would be 1,573 m. 

Key benefits of this location are: 

• The consolidation of shore crossings 

for the Minerva, Otway and Casino 

gas fields to one area. 

• From the HDD site, it is possible to 

locate the offshore pipeline route in 

predominantly sandy seabed, thereby 

avoiding nearshore reef habitat and 

minimising impacts on offshore reefs 

and commercial fishing grounds. 

5.3.2 Offshore Pipeline 

Having selected Option 4: Two Mile Bay 

as the preferred shore crossing site, it 

was necessary to verify that the offshore 

seabed conditions were suitable for a 

pipeline. Preliminary bathymetric data 

obtained from Santos’ earlier seismic 

exploration survey and published seabed 

mapping identified several areas of 

potentially problematic seafloor features. 

Commercial fishers later confirmed the 

existence of potentially problematic seafloor 

features. Santos then decided to 

commission a bathymetry survey so that 

these features could be characterised 

and precisely located and a subsea pipeline 

route could be selected that avoids 

these features, where practicable. 

In January 2004, Santos engaged Fugro 

TGS to undertake a survey of the seabed 

bathymetry along a potential offshore 

pipeline route (see Figure 5.2). The 

bathymetry survey was conducted using 

a side scan sonar and a remotely-operated 

vehicle (ROV) to gather video footage 

of the seafloor, observe the objects 

identified by the bathymetry and sidescan 

sonar recordings. The survey also 

provided information on seabed habitats 

that was used in the marine ecology assessment 

(see Section 6.2). 

Based on the results of the bathymetry 

survey (see Section 6.2), the preferred 

option for the subsea pipeline alignment 

was confirmed, as shown in Figure 5.2. 

5.3.3 Onshore Pipeline 

Identification of Route Options 

The onshore pipeline will extend from 

the preferred HDD shore crossing site at 

Two Mile Bay (Option 4) to the existing 

TXU WUGS facility. Based on the objective 

of co-locating the pipeline to be within 



640 000 650 000 660 000 670 000 



Gas Plant 

Heytesbury 

Gas Plant 

Proposed 

Otway Gas 

Project Plant 

Option 1 

Lovers Nook 


Option 2 

10m 

20m 

30m 

N 

40m 

0 km 5 

Option 3 

Curdies 

Inlet 

Peterborough 

Newfield Bay 

50m 


Preferred HDD shore crossing location 

Alternative HDD shore crossing location 


Minerva Gas 

Plant 

Option 4 

Port Campbell 

Two Mile Bay 

TXU WUGS 

Facility 

60m 





Gas well 

Bathymetry 

Minerva 

Gas 

Well 



Casino 4 

Figure 5.2 Casino Gas Field Development HDD shore crossing options 

70m 

5 710 000 5 720 000 5 730 000 



Table 5.2 

Preliminary assessment of shore crossing options 

Criteria Option 1 

Flaxman’s Hill 

Option 2 

Lover’s Nook 

Option 3 

Newfield Bay 

Option 4 

Two Mile Bay 

#1 Horizontal 

directional drill 

Unknown geotechnical 

conditions. 


conditions. 


conditions. 

Required drill length (to 15-m 

water depth) from outside 


exceeds the current technical 

limit for HDD. Therefore, this 

option carries significant 

technical risk. 

Co-located with Minerva and 

Otway Gas Project shore 

crossings. Known 

geotechnical conditions 

(Minerva HDD geological 

profile has been made 

available to Santos (Santos 

is a joint venture partner in 

the Minerva Project). Key 

stakeholders indicated 

support for concept of colocation 

of shore crossing 

site. Required drill length 

within technical limits. 

#2 Offshore 

Environment 

Bathymetry indicates 

significant reef outcrops 

and rocky seafloor 

conditions between gas 

field and shore. Confirmed 

by commercial fishers 

during consultation and 

offshore bathymetry 

survey. 


significant reef outcrops and 

rocky seafloor conditions 

between gas field and shore. 

Confirmed by commercial 

fishers during consultation 

and offshore bathymetry 

survey. 


significant reef outcrops and 

rocky seafloor conditions 

between gas field and shore. 

Confirmed by commercial 

fishers during consultation 

and offshore bathymetry 

survey. 

Bathymetry east of Casino 

gas field and near Minerva 

indicates significant areas of 

sandy seafloor. Confirmed by 

commercial fishers during 

consultation and offshore 

bathymetry survey. 

#3 

Commercial 

Fisheries 

Offshore pipeline would 

traverse good lobster 

fishing grounds. 

Creates new pipeline 

corridor. 


traverse good lobster fishing 

grounds. 


corridor. 


traverse good lobster fishing 

grounds. 


corridor. 

Offshore pipeline can avoid 

main lobster grounds. 

Co-location with Minerva and 

Otway Gas Project pipeline 

and therefore limits snagging 

hazards to one corridor. 

Commercial fishers indicated 

preference for this option 

over others. 

#4 Onshore 

Environment 

Requires crossing of 

Curdies River and 

Campbells Creek (both 

using existing easements). 

Greenfield shore crossing. 

Potential for approximately 

90% of onshore pipeline 

route to follow existing 

easements. 

Requires crossing of Curdie 

River and Campbells Creek 

(both using existing 

easement). Greenfield shore 

crossing. Potential 

approximately 90% of 

onshore pipeline route to 

follow existing easements. 


Campbells Creek (using 

existing easement). 

Greenfield shore crossing. 

Potential for approximately 

80% of onshore pipeline 

route to follow existing 

easements. 


Campbells Creek (using 

existing easement). Shore 

crossing consolidated with 

Minerva and Woodside 

Otway Gas projects. 

Potential to follow existing 

easement for 90% of 

onshore pipeline route. 

or adjacent to existing easements, where 

practicable, two options are available 

from the HDD site to Smokey Point Road 

and three sub-options are then available 

from here to the TXU WUGS facility. 

Note that the naming protocol for the 

various onshore pipeline route options 

uses ‘Option 4’ followed by either the 

word ‘Minerva’ or ‘Otway’ (depending on 

which alignment it follows) and the suboptions 

are identified as ‘4A, B or C’. 

Between the preferred HDD shore crossing 

site at Two Mile Bay (Option 4) and 

Smokey Point Road, there are two options 

(Figure 5.3): 

• Option 4 (Minerva) – follows the existing 

Minerva pipeline easement to 

the Minerva gas plant and then the 

SEAgas pipeline to Smokey Point 

Road. 

• Option 4 (Otway) – follows the proposed 

Woodside Otway Gas Project 

alignment to Smokey Point Road. 

Between the Smokey Point Road and 

the existing TXU WUGS facility, there 

are three sub-options (see Figure 5.3): 

• 4A – Crosses north over Smokey 

Point Road and Cheynes Road South 

and follows the existing GasNet Iona 

to Portland pipeline into the TXU 


• 4B – Follows the SEAgas pipeline 

from Smokey Point Road into the TXU 


• 4C – Follows the proposed Woodside 

Otway gas pipeline from Smokey 

Point Road into the TXU WUGS facility. 

Selection of the Preferred Onshore 

Pipeline Alignment 

The selection and assessment process 

for the route alignment was based on: 

• Environmental impact assessment – 

studies of the various alignments 

have been conducted by specialist 

consultants, based on desktop and 

field investigations. The field studies 

were undertaken at the end of summer 

2004 and included investigations 

of: 

– Ecology (flora, fauna and stream 

ecology). 



Proposed 

Otway Gas 

Project Plant 

TXU 

WUGS 

Facility 

Rounds Road 

0 0.5 

Kilomet 

Map projection: AMG, 

Legend 

Road 

Creek 

Existing gas pi 

Proposed Otw 

Casino pipelin 

E astern C reek 

Eastern Creek Road 

Currells Road 

C amerons Hill Road 

North -South R 


Gas Plant 

Heytesbury 

Gas Plant 

4A 

4B 


Tregea 

Road 

C r e e k 

W alla b y 

4C 

Smokey Point 

Road 

Curdie Vale-Port Campbell Road 

Cobden-Port 

Campbell Road 

r e e k 

Pascoe Road 

Langleys Road 

Brumbys Road 

C 

am pbells 

C 

Option 4(Minerva) 

Option 4(Otway) 

Sharps Road 

Port Campbell 

Figure 5.3 Casino Gas Field Development onshore pipeline route sub-options 

Timboon-Peterborough 

Minerva 

Gas 

Plant 


Boundary Road 

g C 



– Aboriginal cultural heritage. 

– Historical heritage. 

• Stakeholder consultation – since all 

of the options and sub-options are 

located almost entirely within farmland, 

consultation with stakeholders, 

particularly landholders, has been pivotal 

in determining the most appropriate 

alignment. Stakeholders 

consulted included private 

landholders, Aboriginal communities, 

regulatory authorities, land management 

agencies and interest groups. 

• Engineering survey – engineering 

considerations included terrain, land 

stability and side slope, watercourse 

crossings, presence of rock and potentially 

problematic soil types, 

groundwater issues, public amenity 

and safety. 

Table 5.3 summarises the assessment 

of key criteria on the onshore pipeline 

route options and sub-options. 

Based on the findings summarised in 

Table 5.3, the preferred onshore pipeline 

alignment is Option 4 (Otway) to 

Smokey Point Road and then sub-option 

4A from Smokey Point Road to the TXU 

WUGS facility (Figure 5.4). The principal 

driver for selection of this alignment was 

that it avoids unstable terrain in the 

Campbells Creek valley and it crosses 

Campbells Creek adjacent to existing 

easements. Following minor realignment 

to follow fencelines, the preferred alignment 

received in-principle agreement 

from all landholders, subject to the negotiation 

of easement agreements. The 

preferred onshore pipeline alignment follows 

existing easements or fencelines 

for approximately 90% of its 11.5 km 

length (Table 5.4). 

Onshore Route Travelogue 

The following section provides a description 

of the route traversed by the preferred 

onshore pipeline alignment, Option 

4 (Otway) and sub-option 4A, otherwise 

known as a travelogue. Figure 5.5 illustrates 

the typical land uses along the 

preferred pipeline route. 

From the HDD site on the northern side 

of the Great Ocean Road, the preferred 

pipeline route heads directly north, adjacent 

to a fenceline for a distance of about 

2.1 km, traversing open pasture and 

crossing the BHP Minerva gas pipeline. 

At the northern end of the fenceline, it 

deviates northeast for about 650 m until 

it reaches the Curdie Vale to Port 

Campbell Road where it joins the proposed 

Woodside Otway Gas Project 

pipeline. Both pipelines run parallel along 

the western side of the Curdie Vale to 

Port Campbell Road for about 350 m 

before crossing it (by HDD for the Casino 

Gas Field Development pipeline), 

then paralleling the eastern side of the 

road for a further 500 m. Both pipelines 

then head northeast along a fenceline 

for about 1,250 m through open pasture. 

The Casino Gas Field Development pipeline 

route then deviates away from the 

proposed Woodside Otway Gas Project 

pipeline avoiding a stand of remnant vegetation 

on the south side of Smokey Point 

Road, and runs north for about 2 km. 

The pipeline then crosses the unsealed 

Smokey Point Road by open trenching, 

and continues north along a fenceline. It 

then crosses the unsealed Cheynes 

Road South by open trenching, and continues 

to follow a fenceline northward 

until joining GasNet’s Iona to Portland 

gas pipeline easement. From this point, 

the pipeline route runs east and parallel 

to the GasNet gas pipeline easement on 

its northern side for about 5 km, through 

open pasture, to the TXU WUGS facility. 

Along this easterly traverse, the pipeline 

crosses Campbells Creek and its valley 

in one of only a few locations that are not 

prone to instability and where native vegetation 

is of degraded quality or has been 

previously cleared. The pipeline will then 

cross the Cobden to Port Campbell Road 

by HDD and continue to follow the Gas- 

Net Iona to Portland gas pipeline easement 

east to the TXU WUGS facility. 

5.4 Description of 

Construction Activities 

This section describes the proposed construction 

methods for the Casino Gas 

Field Development, including: 

• Offshore drilling and well completion. 

• Offshore pipeline and umbilical installation. 

• HDD shore crossing. 

• Onshore pipeline and ancillary facility 

installation. 

Construction of these components will 

be carried out simultaneously, under the 

schedule presented in Section 5.9. 

5.4.1 Drilling and Wellhead 

Installation 

Santos has drilled three exploration and 

appraisal wells into the Casino gas field. 

Casino 1 and 2 were drilled during September 

and October 2002 and Casino 3 

was drilled during October 2003. These 

wells were plugged and abandoned, as 

they were not optimally located for gas 

field development. Consequently, field 

development will require drilling of two 

new wells (Casino 4 and 5) using a semisubmersible 

drilling rig (Plate 5.1). Another 

well (Casino 6) is proposed as a 

contingency should production during 

field life indicate that it is necessary to 

meet the required production rates and 

may be drilled at a later date. The impact 

assessment for the Casino Gas Field 

Development has considered two wells 

(Casino 4 and 5) being drilled and developed. 

Drilling will be undertaken using waterbased 

drilling muds, consisting of seawater, 

bentonite clay and freshwater. 

Some non-water-based (and non-oilbased) 

drilling muds may need to be 

used. The latter two components of the 

drilling muds will assist in removing drill 

cuttings from the hole. Based on the 

appraisal drilling of the Casino 1, 2 and 3 

wells, it is estimated that the volume of 

drill cuttings per well will be about 350 

m 3 , with a total fluid discharge of about 

2,000 m 3 per well. Drill cuttings and water-based 

drilling muds will be disposed 

of to sea, while any non-water-based 

drilling muds will be recovered for return 

to shore where they will be treated for 

reuse or otherwise disposed of appropriately. 

Early in project planning, Santos identified 

that use of subsea facilities would 

be a technically and commercially feasible 

option. As a result, the Casino Gas 

Field Development will not require an 

offshore production platform and there 

will be no permanent visual impact in the 

offshore zone. 


comprise two subsea wellhead completions 

(Casino 4 and 5) with 150-mm (6- 

inch) flowline jumpers connecting to a 

300-mm (12-inch) offshore pipeline (Figure 

5.6). Each wellhead is about 5.2 m 

wide x 5.2 m deep x 5.2 m high (basal 

area of approximately 27 m 2 ) (Plate 5.2), 

and will be installed by the semi-submersible 

drilling rig. The wells will be 

spaced 6.5 km apart and provision will 

be made to tie-in the third well (Casino 

6) midway between Casino 4 and 5, by 

installing an inline-T and an additional 

umbilical termination assembly (UTA). 

A diver support vessel (DSV) will install 

the well flowline jumpers and electrical 



Table 5.3 Assessment of onshore route options 

Criteria Route Options 

(Two Mile Bay to Smokey Point Road) 

Route Sub-options 

(Smokey Point Road to TXU WUGS Facility) 

Option 4 (Minerva) Option 4 (Otway) Sub-option 4A Sub-option 4B Sub-option 4C 

Landholder issues Landholder preference to follow 

fencelines. 

Landholder preference to follow 

fencelines. 

Mole drain network adjacent 

to Campbells Creek will 

require restoration. 

No significant constraints. Restricted easement 

imposed by landholder. 

Property development 

restrictions (close to potential 

house site). 

Terrain, landform and 

soils 

No significant constraints. No significant constraints. Avoids areas of known 

instability in Campbells Creek 

valley. 

Scour potential for about 500 

m where alignment runs 

parallel to Campbells Creek 

(from future flood events). 

Alignment traverses 

significant areas of side slope 

requiring cut and fill. 

Traverses areas of known 

instability in Campbells Creek 

valley. 

Restricted area at Cobden to 

Port Campbell Road 

crossing. 

Native vegetation and 

habitat 

Co-locating with SEAgas 

easement at Curdie Vale to 

Port Campbell Road needed to 

avoid impacts on significant 

vegetation. 

HDD needed at Curdie Vale to 

Port Campbell Road to avoid 

impacts on significant 

vegetation. 

Requires minor clearing of 

degraded vegetation 

community at Smokey Point 

and Cheynes Road South. 

No significant issues. Requires some native 

vegetation clearing at 

Campbells Creek crossing. 

Heritage No known sites. No known sites. Single artefact located on 

SEAgas easement on north 

bank of Campbells Creek 

(low sensitivity due to prior 

pipeline construction 

disturbance). 

Alignment runs parallel to 

Campbells Creek for some 

distance and then crosses it 

– an area of moderate 

Aboriginal heritage 

sensitivity. 

Alignment crosses 

Campbells Creek in area of 

moderate Aboriginal heritage 

sensitivity. 

Alignment crosses 

Campbells Creek in area of 

potentially moderate 

Aboriginal heritage 

sensitivity. 

Section length (km) 7.3 4.8 6.9 6.4 5.3 

Road crossings 4 1 3 3 2 

Waterway crossings None None Campbells Creek - adjacent 

to existing easements. 

Campbells Creek - adjacent 

to existing easements. 

Campbells Creek - new 

easement. 



668000 670000 672000 674000 676000 678000 

Co 


North - South Road 


Gas Plant 

Heytesbury 

Gas Plant 

Timboon-Peterborough Road 


Waarre Road 

Proposed 

Otway Gas 

Project Plant 

Tregea 

Road 

W allab y C r e ek 

TXU 

WUGS 

Facility 

Smokey Point 

Road 




Cobden-Port 

Campbell Road 

r e ek 

Pascoe Road 

Langleys Road 

Brumbys Road 

Minerva 

Gas 

Plant 

a m p bells C 

C 

Rounds Road 

Currells Road 

Sharps Road 

0 0.5 1 

Kilometres 


Port Campbell 

Legend 

Road 

Creek 





HDD section 

HDD shore crossing site 

Figure 5.4 Casino Gas Field Development onshore pipeline route 

r ee k 

Boundary Road 

S pring C 

Jarvis Road 

5724000 5726000 5728000 5730000 



668 000 670 000 672 000 674 000 676 000 678 000 

North–South Road 

Timboon–Peterborough Road 

Creek 

Camerons 

Hill Road 


Gas Plant 

Heytesbury 

Gas Plant 

Boundary Road 


Photo 5 

Photo 7 

Photo 6 Photo 8 

Proposed 

Otway Gas 

Project Plant 

Tregea Road 

Creek 

Waarre Road 

Wallaby 

TXU 

WUGS 

Facility 

Eastern Creek 

Road 


Road 

Curdie Vale–Port Campbell Road 

EasternCreekRoad 

Campbell Road 


Langleys 

Brumbys Road 

Minerva 

Gas Plant 

Pascoe 

Photo 3 

Photo 4 

Photo 9 

Cobden–Port 

Rounds Road 

Currells Road 

HDD 

shore 

crossing 

site 

N 

0 km 1 


Sharps Road 

Photo 2 

Photo 1 

Port Campbell 


HDD section 



Road 

Creek 


Spring 

Jarvis Road 

5 724 000 5 726 000 5 728 000 5 730 000 



Photo 2 

Proposed location of the HDD site, located in background in 

pasture behind dense roadside vegetation on the northern 

side of the Great Ocean Road 

Photo 6 

Site of the proposed Campbells Creek open trench crossing, 

adjacent to the recently constructed SEAgas pipeline 

Photo 9 

The TXU WUGS facility at Iona. Tie-in point for the Casino 

pipeline 

Photo 4 

View south of the Smokey Point Road proposed crossing 

location 

Photo 5 

View south of the Cheynes South Road proposed crossing 

location 

Photo 8 

Proposed site of the Cobden - Port Campbell Road HDD 

crossing 

Figure 5.5 Casino Gas Field Development onshore pipeline route travelogue 

Photo 1 

Two Mile Bay and Port Campbell National Park. 

HDD shore crossing will drill under this location. 

Photo 3 

East side of the Curdie Vale–Port Campbell Road proposed 

HDD road crossing 

Photo 7 

Campbells Creek Valley, showing the recently constructed 

and restored SEAgas pipeline easement 



and hydraulic cable jumpers, assisted 

by a remote operated vehicle (ROV). 

Drilling and well completion will take approximately 

two months subject to 

weather conditions, with each well taking 

in the order of 35 days to drill and 

complete. Mobilisation of the drill rig is 

scheduled for January 2005 to enable 

commencement of drilling in late January/early 

February 2005. 

Marker buoys will not be installed as the 

risk of interference from commercial vessels 

is extremely low, the wellheads are 

designed to withstand moderate interference 

and their location will be identified 

on marine charts. 

5.4.2 Offshore Pipeline and 

Umbilical Installation 

The offshore pipeline is a 300-mm (12- 

inch) internal diameter steel pipe with a 

fusion-bonded epoxy (FBE) coating (0.5 

mm thick). The pipeline will not be internally 

coated. 

The pipeline can be installed by either 

pipelay barge or pipe reel-lay vessel 

(Plates 5.3 and 5.4), which are either 

anchored or Dynamically Positioned (DP) 

vessels, respectively. The pipeline installation 

is scheduled to start in November 

2005 and will take approximately 20 

days, subject to favourable weather conditions. 

In the event of an anchored pipelay barge 

(e.g., “SEMAC 1”, see Plate 5.3), two 

anchor handling tugs will be used to shift 

the anchors as the pipelay barge 

progresses along the offshore pipeline 

route. If a pipelay barge is used the pipeline 

will be weighted with a concrete coat 

Table 5.4 

Type of Easement Length of Easement – km (%) 

Proposed (Otway Gas Project) 2.0 (18%) 

Existing (GasNet Iona to Portland pipeline) 5.3 (45%) 

Fencelines 3.1 (27%) 

None (does not follow existing or proposed 

easements or existing fencelines) 

Total 

Length of preferred onshore pipeline route following new, existing or 

proposed easements 

1.1 (10%) 

11.5 km 

(ranging from 40 mm to 80 mm thick). If 

a pipe reel-lay vessel is used, thicker 

wall pipe is used instead of concrete 

weight coating to stabilise the pipeline 

on the seafloor (Figure 5.7). 

Continuous injection of two chemicals 

will be required at the Casino wellheads: 

a hydrate inhibitor (monoethylene glycol 

(MEG)) and a corrosion inhibitor (amine 

compound), which will flow through 25 

mm (1 inch) diameter lines in the control 

umbilical. Chemical injection will be metered 

individually to each wellhead, with 

the injection pumps and meters located 

at the TXU WUGS facility. The subsea 

control system is an electro-hydraulic 

system and skid mounted hydraulic 

power unit (HPU), which will be located 

at the mainline valve site (see Section 

5.4.5). This will supply hydraulic power 

to the subsea well controls through the 

control umbilical, which will also be controlled 

and monitored from the TXU 

WUGS facility control room. The umbilical 

will be either strapped to the pipeline 

during the laying of the pipe or will be 

laid separately using the DSV. Installation 

of the umbilical and jumpers between 

the pipeline and the subsea wellhead 

will take approximately 25 days. 

The offshore pipeline will rest on the 

seafloor. In sandy sections, which accounts 

for most of the seabed to be traversed 

by the offshore route, the pipeline 

is expected to become buried through 

the combined action of waves, currents 

and localised sediment movement. 

Where the pipeline spans across depressions 

in hard substrate areas it may be 

necessary to place supports beneath the 

pipeline so that it is not suspended. Canvas 

groutbags will be placed under the 

pipeline and then filled with cement slurry 

grouting so that the freespan is supported 

as the groutbag inflates (Figure 5.8). It is 

envisaged that 90 freespan supports may 

have to be installed and this number will 

be verified during the post pipelay survey. 

This freespan correction work will 

be conducted by the DSV. The DSV allocated 

work will take approximately 25 

days, subject to weather conditions. 

5.4.3 Shore Crossing 

The shore crossing for the Casino Gas 

Field Development will be horizontally 

directionally drilled (HDD) in order to 

Subsea wellhead 

Flowline 

jumper 

In-line tee 

Umbilical 

Courtesy of Santos 

Plate 5.1 

Well testing by semi-submersible rig during drilling 

of Casino-3 well 


Figure 5.6 

Trawl guard 


Typical subsea wellhead configuration 



avoid impacting the coastal zone, in particular 

the surface of the Port Campbell 

National Park, shoreline habitat and 

nearshore reef habitat. The boundary of 

the Port Campbell National Park is from 

the freehold boundary to the low water 

mark and goes to the centre of the earth. 

Therefore, although the HDD will occur 

below the surface of the park, this activity 

is still within the park. 

The HDD site is proposed to be located 

on private property on the northern side 

of the Great Ocean Road, about 250 m 

west of the Minerva Project HDD site. 

The dimensions of the HDD site will be 

100 m by 100 m, with a temporary 

hardstand area (crushed rock or similar) 

required at the site to provide all weather 

access for heavy vehicles. Figure 5.9 

shows a plan view of the proposed HDD 

site. Due to safety concerns (proximity 

to a bend in the Great Ocean Road and 

farm operations traffic), the existing access 

west of the HDD site will not be 

used and a new 6 m wide access road 

will be constructed off the Great Ocean 

Road. The exact location of the access 

will be determined following a botanical 

assessment as it will impact native roadside 

vegetation. 

The HDD site and access road will be 

stripped of topsoil, which will be stockpiled 

in an adjacent area away from construction 

activities. Sediment control 

measures, including diversion berms, a 

settling basin and sediment fences will 

be employed, as appropriate, to manage 

site run-off. 

Two HDD holes will be drilled from this 

site (located 700 m inland from the 

coastal cliffs); i.e., one hole for the gas 

pipeline (26 to 30 inch diameter hole) 

and one for the umbilical (12 to 22 inch 

Courtesy of Worley 

Plate 5.2 Typical subsea wellhead 

similar to that proposed for the Casino 

Gas Field Development 

hole diameter). The holes will be cased 

with HDPE or steel. A distance of 15 m 

will horizontally separate these holes and 

drill profiles. A profile of the HDD operation 

is shown in Figure 5.10. The HDD 

exit hole is 1,573 m from the entry hole 

(via the drill section), in a sandy substrate 

under 15 to 16 m of water. There is no 

nearshore reef in the vicinity of the proposed 

exit hole. 

A specialised HDD rig will be used for 

the shore crossing (Plate 5.5). For each 

of the two holes, a pilot hole will be 

drilled which will then be reamed out to 

the required diameter. 

To ensure the accurate positioning of 

the HDD drill string a “Tru-Trak” or similar 

survey system will be used in conjunction 

with downhole survey tools. This 

system utilizes loops of wire laid on the 

ground surface that are energised by a 

portable generator to create a magnetic 

field by which the position of the drill bit 

may be calculated. One or two such loops 

will be required within the Port Campbell 

National Park above the path of the HDD. 

The wire loops will be laid out by foot 

and surveyed in by a land surveyor. Minor 

trimming of vegetation may be necessary 

to ensure that this system is setout 

at ground level and functions correctly. 

The portable generator will be located 

on a drip tray or in a small bunded area 

and, depending on the required location 

of the coils, may be located on the side 

of the fishing track or in the fishing track 

carpark in the National Park. 

At the completion of the work, all wires 

and any survey pegs which may be required 

will be removed from the park and 

any disturbed areas will be restored in 

consultation with Parks Victoria. 

Bentonite clay (a naturally occurring, nontoxic 

clay) is mixed with freshwater and 

used as the drilling fluid. The drilling fluid 

keeps the drill hole open, lubricates the 

drill bit and string, and removes cuttings 

from the drillhole. Drill cuttings will be 

separated from the drilling fluid at the 

surface using vibrating screens, and directed 

to a settling tank, while the drilling 

fluid will be recirculated to the drillhole 

with additional bentonite added as required. 

Excess liquids from the drill fluid, 

if any, will be carted away by tanker to 

an approved disposal site. 

While the HDD holes are being drilled, 

about 2 km of pipeline will be strung out 

along the onshore pipeline easement as 

it extends north from the HDD site, 

welded into a continuous length and 

hydrotested (Section 5.4.4). The pipeline 

will then be pushed through the HDD 

hole from land using a hydraulic thruster. 

The end of the pipeline will be rigged up 



Plate 5.3 The “Semac 1” pipelay barge Plate 5.4 The “Apache” pipe reel-lay vessel 



with a ‘pullhead’ ready for pick up by the 

pipelay vessel. Once the pipeline has 

been pushed through the HDD hole, the 

offshore pipeline and seaward section of 

the HDD pipe will be lifted up to the 

pipelay vessel and welded, that is, tiedin. 

A pull line will be installed in the HDD 

liner ready for pick up by the pipelay 

vessel for connection to the umbilical 

pullhead on the pipelay vessel. The umbilical 

will then be pulled from the pipelay 

vessel through the HDD liner to the HDD 

entry using a winch on the HDD site. 

The HDD process is expected to take 

about seven months, and is scheduled 

to take place between January and July 

2005. This time incorporates setting up 

the HDD site, mobilising equipment to 

the site, drilling and reaming the two 

holes, installation of the pipe and umbilical, 

grouting and demobilisation. Drilling 

is likely to be undertaken continuously, 

24 hours a day, 7 days a week for three 

months, as any significant shut-down 

may lead to drill hole collapse and the 

drill string becoming stuck down hole. 

The HDD site will be artificially lit at night 

during drilling operations (about three 

months). 

At the completion of the HDD operations, 

the site will be restored with the 

exception of a 20 m x 30 m chain-mesh 

fenced (painted or coated black to reduce 

visual impact) compound around 

the MLV (see Section 5.4.5 ‘Ancillary 

Facilities’). 

5.4.4 Onshore Pipeline 

This section describes the activities associated 

with the construction of the onshore 

pipeline and ancillary facilities of 

the Casino Gas Field Development. 

Construction 

A construction right-of-way (ROW) of 24- 

m will be required, incorporating a 15-m 

wide permanent easement and an additional 

temporary 9-m wide workspace 

adjoining the easement. The ROW accommodates 

construction equipment and 

vehicle travel, along with the storage of 

trench spoil and topsoil, as shown in 

Figure 5.11. The width of the ROW also 

ensures that construction activities can 

be safely performed with minimum risk 

of accident or injury to construction personnel. 

The width of the ROW is a balance 

of considerations, including safety, 

timing, environmental and cost criteria. 

A wider easement means greater costs 

for construction earthworks, rehabilita- 

Between 15 m and 70 m water depth to pipe 

Umbilical 

Metal 

fastening 

strap 

Figure 5.7 

DETAIL OF UMBILICAL 

100 mm 

300 mm 

Concrete coating 

(40–80 mm thick) 

FBE coating 

(0.5 mm thick) 

Carbon steel pipe 

(13–22 mm wall 

thickness) 

Offshore pipeline cross section (umbilical shown strapped to pipeline, but 

may be laid separately adjacent to pipeline) 

Sandy seabed 

Figure 5.8 

Outer casing 

Inner 

polypropylene 

rovings 

Hydraulic control 

fluid (12.5 mm) 

Electrical quad 

(4 mm 2 ) 

Chemical injection 

(25 mm) 

Spanned 

depression 

Rocky seabed 

Protective steel 

armour wire 

Rope fillers 

Umbilical 

Metal fastening strap 

String 

fillers 

Typical offshore pipeline spanning stabilisation treatment 

Raw gas pipe 

Cement-filled bladder 



0 100 200 300 400 500 

Meters 

0 10 20 30 40 50 

Meters 

Inset 

Pipe HDD 

entry 

HDD contractor 

access 

See inset 

Great 

Ocean 

Road 

KP 38.3 

Equipment and 

materials storage 

13 

Proposed 

access road 

HDD 

drilling site 


Umbilical 

entry 

Fishing 

Track 

HDD site 

temporary 

access 

5 

6 

4 

3 

3 

11 

8 

7 

12 

10 

9 

16 17 18 19 15 14 

1 

2 

Proposed permanent 

operations access 

track to MLV site 

5 


10 

15 

20 

25 

30 

Pipe HDD exit 

KP 36.7 

23 

24 

26 

27 

28 

29 

20 

21 

22 

30 

25 

12 

18 

14 

16 

11 

13 

15 

17 

19 

20 

21 

22 

23 

24 

25 

26 

27 

28 

29 

30 

Umbilical exit 

Property boundary 

Bathymetry 


HDD section 

1 Pipeline HDD inlet pit 

2 Umbilical HDD inlet pit 

3 Anchor block 

4 Rig unit 

5 Drill pipe storage 

6 Crane 

7 Rig control room 

8 Rig power unit 

9 Bentonite storage 

10 Slurry mixing tank 

N 

11 Slurry pump 

12 Cuttings separator 

13 To cuttings settling pond 

(location t.b.c.) 

14 Generators 

15 Spares shed 

16 Engineer's office 

17 Contractor's office 

18 Amenities 

19 Mess room 

Figure 5.9 

HDD shore crossing - site location and construction site layout 



HDD Profile 

KP 36.7 KP 38.3 

+100 

0 

-60 

HDD exit point 15 m 


HDD entry at 

ground level 

Enhanced HDD profile 

1:5 vertical exaggeration 

HDD exit point 15 m 


HDD entry at 

ground level 

+90 

+80 

+70 

+60 

+50 

+40 

+30 

+20 

+10 

0 

-10 

-20 

-30 

-40 

-50 

203 m 52 m 655 m 103 m 548 m 

1,561 m horizontal distance – 1,571 m pipe length HDD 

Figure 5.10 

HDD shore crossing profile 

tion and compensation, but ensures there 

is efficient use of space for workplace 

safety and management of topsoil for 

successful reinstatement of the easement. 

Due to the short length of the onshore 

pipeline, construction will progress on 

one front, with multiple specialised crews, 

and is likely to progress from the HDD 

Enesar 

Plate 5.5 

shore crossing site to the TXU WUGS 

facility. The direction of construction may 

be reversed to accommodate schedule 

changes. 

Trenching progress is expected to be in 

the order of three to four km per day 

depending upon conditions (e.g., terrain, 

rock and weather), with relatively minor 

disruption to land use. In most areas, the 

A typical HDD rig used for road and river crossing operations 

pipeline will be laid and backfilled in about 

28 to 42 days (i.e., from clear and grade 

to reinstatement), dependant on weather 

and site conditions. In areas with difficult 

terrain and other infrastructure, construction 

will be slower. Overall, onshore pipeline 

construction is expected to be 

completed within about eight weeks and 

is scheduled for the summer months to 

avoid wet weather and boggy ground 

conditions. 

The mainline crew will undertake the 

majority of construction. Tie-in crews will 

be responsible for linking the mainline 

construction sections with special crossings, 

such as roads and waterways, and 

pipe bend sections. 

Specifically, construction involves: 

• Access. 

• Pre-construction surveying. 

• Clear and grade. 

• Pipe stringing. 

• Trenching. 

• Bending. 

• Welding and joint coating. 

• Lowering-in. 

• Backfilling. 

• Hydrostatic testing. 

• Clean-up and restoration. 



Right of Way 24 m 

Easement 15 m 

Workspace 9 m 

Sideboom tractors 

(staggered distance from 

trench during lowering-in) 

Access for general 

construction traffic 

Topsoil 

Trench spoil 

Pipe 

Boxing 

Trench 

6 m 9 m 

Figure 5.11 

Typical mainline construction ROW cross section 

These construction activities are discussed 

below. A diagrammatic representation 

of a typical onshore pipeline 

construction spread is shown in Figure 

5.12. A photographic representation 

of pipeline construction activities is presented 

in Plates 5.6 to 5.16. 

Access. To facilitate access along the 

construction ROW, temporary strainer 

assemblies and gateways are installed 

at every fence line. This provides continued 

security for cattle, sheep and other 

farm stock while construction progresses 

along the ROW. Access to the ROW and 

construction sites will generally be via 

existing tracks and roads, where practicable. 

However, a new access road to 

the HDD site will be required through the 

roadside verge and farmland, and it is 

likely that some existing tracks may require 

upgrading and ongoing maintenance 

to accommodate construction 

vehicles. 

Access across Campbells Creek will run 

parallel to the existing GasNet Iona to 

Portland pipeline and SEAgas pipeline 

crossings. The timing of construction is 

scheduled to coincide with the watercourse 

being either dry or in low summer 

flow. A temporary causeway will be constructed 

across the creek if required. 

Where a hard-base substrate is required 

to be added, it will consist of clean stone 

or rock that does not impede water flow. 

If a raised rock causeway is required 

due to moderate water flows then pipe 

culverts adequate to accommodate a 1 

in 10 annual rainfall index (ARI) storm 

event will be installed. 

Pre-construction Surveying. The pipeline 

centreline was surveyed in April 

2004. This involved surveying the limits 

of the ROW, any additional work areas 

and the centreline of the pipeline. Limits 

have been marked using 1.5-m long 

stakes at 200-m intervals, and these will 

be retained until easement restoration. 

These will be periodically replaced as 

the centreline survey pegs are disturbed 

during construction. 

Fences to be cut have been marked by 

the surveyors. The edge of the easement 

has been marked with ranging poles 

to ensure clearing occurs within the designated 

ROW. Special features not to be 

disturbed have also been marked. 

During construction, an as-built survey 

will be conducted to record the actual 

pipeline depth (ground surface to top of 

pipe in ground) and location of the pipe 

along the entire pipeline route. The asbuilt 

survey will also record the sequence 

of each pipe-by-pipe number, the sequence 

of each weld-by-weld number, 

the location of each ancillary facility, 

drawings of all crossings (roads, pipelines, 

watercourses) and the profile of 

the HDD installations. 

Clear and Grade. Clear and grade will 

involve the removal of vegetation and 

surface debris (e.g., fallen timber) and 

the grading of topsoil to a depth of about 

150-mm to 200-mm from the ROW, depending 

on soil profile. The topsoil will 

be stockpiled along the edge of the easement 

to permit safe and practical construction 

access whilst preserving the 

topsoil for later reinstatement (see Figure 

5.11). Topsoil from the mainline ROW 

will not be stockpiled for any greater than 

two to three months. The period of stockpiling 

topsoil from the HDD site and shore 

crossing pipeline fabrication area will be 

about six to seven months due to the 

duration of these activities. 

Appropriate route selection has largely 

avoided the need for the removal of native 

vegetation, with about 1% of the 

pipeline route traversing areas of native 

vegetation of varying quality. Wherever 

practicable, vegetation clearing from the 

ROW will be further minimised by HDD 

crossings of sealed roads, reducing the 

easement width at unsealed roads to be 

trenched to 5 m, working around trees 

and significant species, or by trimming 

overhanging branches. At the Campbells 

Creek crossing, clear and grade will not 

be undertaken within 10 m of the stream 

channel top-of-bank until construction is 

imminent. Clearing of tree species is unlikely 

to be required at Campbells Creek, 



Restoration 

of existing 

fences etc 

Replacement 

of topsoil 

Backfilling Pipeline laying Pipeline construction Trench excavation Clearing and topsoil 

stripping 

Pipe welding 

Disturbance 

corridor (ROW) 

Restored 

existing 

fences 

PLAN VIEW 

Excavated trench 

Spoil stockpile 

Topsoil stockpile 

Dozer Sideboom tractors Pipe welding Transport truck Trench excavator Dozer 

ELEVATION VIEW 

Excavated trench 

(Not to scale) 

Figure 5.12 

Onshore pipeline construction ROW 

but if so, will be limited to the trench-side 

only. 

A further cut (between 50 to 150 mm) of 

topsoil (known as boxing, see Figure 

5.11) will be made over the trench line 

area and this material will be stockpiled 

for later reinstatement. Boxing out over 

the trench will be undertaken to reduce 

the potential for soil inversion, resulting 

from trenching through different soil horizons. 

Santos will ensure that the vegetation 

and boxing material is stockpiled separately 

from the excavated trench material 

to ensure for successful reinstatement 

of the easement following construction. 

Cleared vegetation will be stockpiled and 

preserved for use during easement restoration. 

Side slope areas are normally benched 

(cut and filled) to provide a level surface 

for the trenching machines to operate 

on. However, the requirement for any 

significant side slope has been avoided 

through appropriate route selection, i.e., 

aligning the pipeline easement at right 

angles to contours in undulating terrain, 

avoiding slope instability upon reinstatement. 

Pipe Stringing. Stringing involves the 

delivery of pipe to the easement by semitrailer. 

The pipe will be laid end-to-end 

alongside the trench on raised timber 

skids that protect the pipe from damage 

and enable to it be welded into continuous 

lengths or ‘strings.’ Sufficient gaps 

will be provided for public and private 

access including the movement of vehicles, 

farm equipment and livestock. 

Each length of onshore section of raw 

gas pipe is 18 m long, with one standard 

semi-trailer able to carry approximately 

13 pipe lengths. Approximately 740 pipe 

lengths are required based on an onshore 

pipeline length of 11.5 km and 

HDD section of 2 km, therefore approximately 

57 semi-trailer return trips will be 

required to deliver the onshore and HDD 

raw gas pipe to the easement. In addition, 

each length of MEG pipe is 12 m 

long, with one standard semi-trailer able 

to carry approximately 232 pipe lengths, 

therefore requiring four semi-trailer return 

trips to deliver MEG pipe to the 

easement. 

The construction contractor will develop 

a traffic management plan in consultation 

with the Corangamite Shire and 

VicRoads, as appropriate, prior to the 

commencement of construction. 

Trenching. The trench will be excavated 

using a range of specialised equipment 

including wheel ditchers, excavators and 

rock saws, to a depth that provides an 

appropriate cover over the pipe commensurate 

with the terrain and land use 

characteristics. Trenching can typically 

occur at a rate of three to four km per 

day depending upon terrain, rock and 

soil conditions. The period of time the 

trench will be open will be kept minimal, 

typically ranging from 14 to 21 days at 

any location along the mainline section. 

Depth of soil cover will be increased at 

road and river crossings as appropriate, 

as outlined in Table 5.5. Trench spoil will 

be stockpiled separately on the trench 

side of the easement and returned to the 

trench during the backfilling stage. As a 

general rule, the minimum cover over 

the pipeline will be 900 mm, except as 

outlined in Table 5.5. A typical crosssection 

of the Casino pipeline and trench 

is shown in Figure 5.13. 

Bending. Bending will be undertaken to 

enable the pipe to conform to land contours 

or facilitate changes in pipeline 

route direction. Pipe may either be ‘cold 

bent’ in the field, or roped (using the 

natural flexibility of the pipe) or by applying 

heat in a factory to produce hotformed 

bends. Pipe diameter, length and 

wall thickness are variables that may 

limit the radius of curvature of a cold 

field bend (reducing the angle that may 

be pulled from a pipe length). Factory 

bends can achieve much tighter radii 

and will be used where cold bends are 

not sufficient. 



Enesar 

Enesar 

Plate 5.6 Raised rock creek causeway Plate 5.7 A cleared and graded ROW in preparation for trenching 

Enesar 

Courtesy of GasNet (Operations) Australia Pty Ltd 

Plate 5.8 Trench excavation using a bucket-wheel ditcher Plate 5.9 Stringing of pipe lengths along the ROW 

Enesar 

Enesar 

Plate 5.10 Field bending of pipe Plate 5.11 Pipe welding 



Enesar 


Plate 5.12 Coating of welded pipe joints Plate 5.13 Lowering in of pipeline 


Plate 5.15 

Soil ripping to alleviate heavily compacted soils 

Enesar 

Plate 5.14 

Backfilling the trench 

Enesar 

Plate 5.16 

Revegetation, showing pasture restoration shortly 

after sowing 


Welding and Joint Coating. The pipe 

segments will be welded into continuous 

lengths or ‘strings’, with gaps for roads, 

fences and stock crossings. Pipe strings 

will be a maximum length of 1,200 m or 

as agreed with landholders to accommodate 

stock crossings and farm operations. 

The welded joints will be 100% 

X-rayed before sand blasting removes 

surface scale and rust, and then coated 

with a fusion bonded epoxy (FBE) to 

provide a continuous external coating, 

with a minimum thickness of 550 µm. 

FBE coated pipe for HDD crossings will 

be overcoated with an abrasion resistant 

coating (Nap Rock) with a minimum thickness 

of 1,000 µm. 

The MEG line will be externally coated 

with two layer extruded high-density 

polyethylene (HDPE) to a minimum thickness 

of 900 µm. 

Lowering-in. Lowering-in refers to the 

placement of the pipe strings into the 

900 mm average depth to pipe 

Figure 5.13 

Carbon steel pipe 

(13 mm wall thickness) 

FBE coating 

(0.5 mm thick) 

Location 

Marker tape 

Table 5.5 

MEG/chemical 

injection lines 

Topsoil 

Backfill (spoil) 

Padding (fine spoil) 

150 mm 300 mm 300 mm 

150 mm 

50 mm 

Onshore pipeline and trench cross-section 

Depths of cover along the proposed pipeline route 

Outer 

casing 

Fibre optic 

cable 


Minimum Depth of Cover (mm) 

Open farmland 900 

Campbells Creek 1,200 

Roads 1,200 

trench by side-boom tractors as they 

gradually move along the easement lowering 

in the pipe string. The side booms 

require enough distance from the 

trenchline to place the pipeline into the 

ditch without touching the trench wall 

(which could damage the pipe coating). 

Prior to lowering-in the pipe, it may be 

necessary to de-water the trench (e.g., 

in areas of high water table or after rain). 

Any such water will be discharged to 

land through artificial or natural sediment 

filters and energy dissipaters to prevent 

sediment and erosion, and only in accordance 

with regulatory requirements. 

Immediately prior to lowering-in, all coating 

will be visually inspected and using a 

high-voltage holiday detector to detect 

any coating defects, which will then be 

repaired. 

In areas where subsurface ground conditions 

are rocky and may damage the 

pipe coating, either bedding or padding 

materials may be required to protect the 

coating. A specialised padding machine, 

such as the ‘Ozzie Padder’, may be used 

to sort fine material from the trench spoil 

for placement around the pipe, or alternatively, 

quarried sand may be used. 

Sand-filled hessian bags or foam pillows 

may be placed at intervals of 5-m along 

the bottom of the trench to allow bedding 

and padding (fine soil or sand) material 

to be placed in one operation. 

Backfilling. Once laid, the pipe will be 

covered with marker tape denoting “Buried 

High Pressure Gas Pipeline”. Stockpiled 

trench spoil excavated during 

trenching will then be backfilled and compacted. 

Topsoil removed during grading 

will be respread over the ROW and contours 

reinstated. Special care will be 

taken to ensure that excavated spoil and 

soil profiles are re-established to avoid 

soil inversion. Excess spoil may be removed 

from site and transported to approved 

landfill sites. Where complete 

backfilling cannot be done on the same 

day as lowering-in, the pipe will be required 

to be covered by not less than 

150 mm of padding over and around the 

pipe. 

Where subsidence may occur, a trench 

crown may be centred over the trench. It 

will not exceed 200 mm in height, be no 

less than 2 m in width, and breaks in this 

crown will be spaced at intervals no 

greater than 30 m. 

Hydrostatic Testing. The entire pipeline 

(onshore and offshore sections) will 

be hydrostatically tested (i.e., leak tested 

by pressurising with water), in accordance 

with the Australian pipeline standard 

(AS2885), to verify the integrity of 

the pipeline. Prior to hydrostatic testing, 

the pipeline will be pre-cleaned to re- 



move weld debris, dust and surface 

scale. The pipeline will be tested in sections. 

The onshore section will be tested 

first and then the water will be transferred 

into the offshore section, with additional 

water added to the longer 

offshore section. The exception to this is 

the HDD pipe section, which will be tested 

separately prior to installation. Water from 

the HDD pipe hydrostatic testing will be 

disposed of to land in accordance with 

EPA requirements. Once full of water, 

the pipeline will be pressurised for a 3- 

hour period. The pressure is then lowered 

and held for a period of 24 hours 

and monitored for pressure drops. 

Water will be sourced from local bores or 

town water supply in consultation with 

landholders or South West Water, as 

appropriate, and appropriate approvals 

and agreements put in place. Chemical 

inhibitors will be added to prevent corrosion. 

The hydrotest water will be discharged 

from the pipe to sea at the 

wellhead in accordance with relevant 

regulatory requirements and approvals. 

Once the water is removed from the pipe, 

drying pigs (dense foam ‘bullets’), will be 

inserted into the pipe and pushed through 

to remove all water residues. After the 

displacement pigs arrive in the temporary 

offshore pig receiver, the pipeline 

end termination valves will be closed and 

the temporary pig receiver removed. 

Clean-up and Restoration. Following 

backfill and compaction of the pipe 

trench, clean-up will be undertaken by 

removing all temporary infrastructure and 

machinery, re-establishing contours and 

respreading of stockpiled topsoil. Cleanup 

and restoration will be undertaken 

progressively so as not to lag behind 

completed backfill by more than 6 km. 

The construction sites and equipment 

lay-down areas will be ripped to relieve 

compaction if necessary. Erosion and 

sediment controls, such as diversion 

berms and sediment traps, will be put in 

place as appropriate to protect water 

quality, e.g., at Campbells Creek and 

roadside table drains, and divert run-off 

away from potentially unstable rehabilitation 

areas. 

Revegetation of the ROW and the HDD 

site will be undertaken by broadcasting 

appropriate seed and fertiliser. Seed 

mixes, and the use of fertilisers, will be 

based on specialist advice and consultation 

with landholders. The success of 

restoration will continue to be monitored 

until the easement is stable. 

Once reseeding has been completed, 

the temporary gates will be removed and 

the fences reinstated to their original design 

using new materials. A permanent 

security fence and gates will be installed 

at the MLV site. 

A revegetation plan will be developed for 

native vegetation areas (HDD access 

track, Smokey Point Road and Cheynes 

Road South) for approval by DSE in line 

with Net Gain principles. 

Special Crossings and Tie-ins 

Watercourse Crossings. Campbells 

Creek is the only watercourse crossing 

on the preferred onshore pipeline alignment. 

As construction is scheduled for 

summer and therefore during periods of 

nil to low flow, the Campbells Creek 

crossing will be by standard trenching as 

has been successfully applied on three 

previous pipeline crossings of this creek 

in the same location. The selection of 

the crossing location is based on minimising 

potential impacts and achieving 

long-term site stability. The proposed 

method involves surface excavation 

across the watercourse. Sediment and 

water quality control measures, such as 

silt curtains, or construction isolation 

methods using dam and pump (Figure 

5.14) or flume pipe (Figure 5.15), 

may be applied dependent upon sitespecific 

sensitivities. 

Flow diversion pump 

and pipework 

Stream 

flow 

Upstream 

sandbagging 

or bund wall 

Figure 5.14 

Pipeline 

Spoil pile 

Stream bed 

trench spoil 

ROW 

Trench 

breaker 

However, isolation methods would generally 

only be applied where significant 

environmental sensitivities are present 

and significant sediment loads are expected 

based on stream substrate conditions. 

These conditions are not 

expected to occur. In-stream activity using 

the standard open trenching method, 

without isolation techniques, can be completed 

within one day, assuming hard 

rock is not present. Isolation methods 

generally increase the period of in-stream 

activity to three days, so risk increases 

(e.g., flood potential); however, sediment 

loads may decrease. It is unlikely that 

the use of isolation methods will be warranted 

as the crossing is scheduled for a 

period of nil to low flow. 

Appropriate measures to restore and stabilise 

the open-trenched watercourse 

crossing will be undertaken using methods 

such as rock rip-rap, geotextile fabric 

and stream bank revegetation as 

necessary. 

Verification of crossing techniques is subject 

to the completion of engineering investigations, 

together with continued 

consultation with relevant authorities (i.e., 

CCMA and DSE), prior to finalising the 

creek crossing techniques and gaining 

creek crossing approvals. 

Trench 

Vehicle crossing 

Downstream 

sandbagging 

or bund wall 

Topsoil 

Rock 

rip-rap 

Clean 

pretrenching 

water 

Trench 

breaker 

Post-trenching 

worksite 

dewatering 

Not to scale 

Typical open trench isolation crossing (dam and pump method) 

Flow 


Road Crossings. The crossing of public 

roads is subject to approval from the 

relevant Victorian authority, being either 

the Corangamite Shire Council or 

VicRoads. Private road and track crossings 

are subject to the conditions of negotiated 

easement agreements with 

landholders. 

Sealed bitumen roads will be horizontally 

directionally drilled to minimise disruption 

to traffic movements, prevent any 

degradation of road surface integrity and 

avoid significant native vegetation. Unsealed 

roads and tracks will be open 

trenched and compacted during 

backfilling to required standards, and is 

typically completed in one day. All roads 

will have a minimum depth of cover over 

the pipe of 1,200 mm. Table 5.6 identifies 

the proposed crossing methods for 

specific roads. 

Roadsides are generally noted as areas 

of potentially significant native vegetation. 

The pipeline route selection process 

(and subsequent survey) has avoided 

or minimised impacts to native vegetation 

at roadsides by targeting gaps wherever 

present. Residual impacts will be 

further mitigated by undertaking HDD 

under sealed roads (thereby avoiding 

remnant native roadside vegetation), 

hand clearing vegetation at some locations 

where preferrable, trimming overhanging 

vegetation rather than clearing, 

and narrowing the cleared area (from 24 

m to 5 m) on open trench crossings. 

Service Crossings. Crossings of pipelines 

and other services requires approval 

from the relevant asset management 

authority. Pipeline crossings will be ‘hand 

dug’ with representatives of the third party 

pipeline asset present during construction, 

as required. Hand digging involves 

the use of an excavator in the vicinity of 

the pipeline and then the use of shovels 

closer to the pipeline. The minimum separation 

at crossings between the existing 

pipeline, or other buried services, and 

the new pipeline is 300 mm. 

Road 


Table 5.6 

Curdie Vale to Port Campbell 


Cheynes Road South 

Cobden to Port Campbell Road 

Spoil pile 

Stream bed 

trench spoil 

Stream 

flow 

Upstream 

sandbagging 

or bund wall 

Figure 5.15 

Pipeline 

Flume (steel 

Construction Facilities 

A range of temporary construction 

worksites may be required, including: 

• Construction depot and site office. 

• Equipment lay-down areas. 

• Temporary pipe storage. 

• HDD pipe string fabrication. 

• Construction camp. 

While it is likely that some of these 

worksites will be consolidated on the 

same site, this is dependent upon construction 

logistics, which will be determined 

by the selected construction 

contractor during detailed design and 

construction planning. 

The key principles when selecting 

worksites will be to avoid or minimise 

impacts to: 

Proposed road crossing methods 

Crossing Method 

HDD 

HDD 

Trenched (narrow ROW) 

Trenched (narrow ROW) 

HDD 

ROW 

Trench 

breaker 

pipe) 

Trench 

breaker 

Trench 


Vehicle crossing 

Topsoil 

Stream 

flow 

Downstream 

sandbagging 

or bund wall 

Not to scale 

Typical open trench isolation crossing (flume pipe method) 

• Native vegetation. 

• Aboriginal cultural heritage. 

• Historic heritage. 

• Water resources. 

• Soils. 

• Socio-economic aspects (such as 

farm operations, recreation, tourism 

and traffic). 

Where practicable, areas of previous disturbance, 

such as sections of the Santos 

Heytesbury gas facility, the TXU WUGS 

facility or hard stand area within the HDD 

site will be selected to accommodate 

such facilities. The HDD pipe string will 

be fabricated in an area 35-m wide and 

2,000-m long extending north from the 

HDD site (incorporating the 24-m wide 

onshore pipeline ROW). Negotiations are 

currently underway to lease this land from 

the landholder. 

Construction is expected to require a 

workforce of up to approximately 45 personnel, 

comprising specialist technical 

expertise and general labour. The 

workforce will be accommodated in motels 

and other rental accommodation in 

Port Campbell and surrounding towns 

such as Peterborough, Cobden and 

Curdie Vale or alternatively the construc- 



tion contractor may establish a construction 

camp. If required, the construction 

camp will be located in an area of prior 

disturbance (preferably an area previously 

used for a construction camp) and 

the site determined in consultation with 

DPI and the Corangamite Shire. 

5.4.5 Ancillary Facilities 

The ancillary facilities required for pipeline 

operation, monitoring and maintenance 

purposes include: 

• One mainline valve (incorporating future 

pig launching/receiving facility, 

Hydraulic Power Unit and Electrical 

Power Unit). 

• Metering facilities. 

• Cathodic protection test-points. 

• Pipeline marker posts. 

These are described below. 

Mainline Valve 

One MLV (Figure 5.16) is required for 

the Casino Gas Field Development to 

enable emergency shut down and isolation 

of sections of the pipeline or routine 

pipeline maintenance. The MLV compound 

will measure about 30-m by 20- 

m, have a compacted gravel surface and 

be surrounded by a 2.8-m high cyclone 

security fence (painted or coated black 

to reduce visual impact). The compound 

will be located at the HDD site and over 

the pipeline easement, screened from 

the Great Ocean Road by roadside vegetation 

and landscaping around its perimeter. 

The mainline valve will be 

prefabricated at a factory and transported 

to site for installation. Construction of 

the mainline valve compound essentially 

involves civil and pipe work installation. 

Access to the MLV during operations by 

small four-wheel drive vehicles will be 

accommodated by the construction of a 

permanent 3-m wide access track off the 

Great Ocean Road. 

The MLV compound will also accommodate 

a hydraulic power unit (HPU). The 

HPU is a skid mounted unit (total dimensions 

being 2.5 m high, 4 m wide and 6 

m long), incorporating a pump and 

painted stainless steel tank that will store 

6,000 litres of hydraulic control fluid 

(Castrol® Transaqua HT or McDermid® 

HW540). This fluid is a non-toxic waterbased 

fluid that is used in the umbilical 

line to control the operation of the offshore 

wells. The chemical injection lines 

will connect to the onshore umbilical termination 

assembly (OUTA). A methanol 

trap (a small volume vessel) may be installed 

at this assembly, but should remain 

empty for the life of the gas field. 

The HPU will be fitted with an internal 

bund that is part of the skid frame to 

contain any potential spills. An electrical 

power unit (EPU) will be installed within 

an electrical equipment room at the MLV 

site to power the umbilical. 

Pig launching and receiving facilities permit 

the insertion and retrieval of in-line 

30 m 

Fence 

Double gates 

Vehicle access 

and 

tooling area 

Future receiver 

Future pig signal 

Vehicle access 

and 

tooling area 

Anchor block 

MCS-EPU 

Barred tee 

Junction box 

MIJ 

cleaning and inspection tools (commonly 

referred to as ‘pigs’) through the pipeline. 

The Casino pipeline will not be fitted 

with permanent pigging facilities. 

Instead, provision will be made to allow 

for the attachment of temporary pigging 

facilities at the mainline valve compound 

to pig the onshore and offshore pipelines 

separately. 

20 m 

OUTA 

SITE PLAN 

MIJ 

Offshore umbilical 

Personnel gate 

Anchor block 

Fibre optic cable 

3 x G/CI lines 

Removable bypass 

to be installed for 

pressure balancing 

across main line valve 

Support 

Future launcher 

HPU 

Figure 5.16 

Typical MLV site layout 



Metering Facilities 

Metering will be provided by TXU at the 

gas transfer point within the TXU WUGS 

facility site to measure the gas volume 

as it enters the TXU system. 

Cathodic Protection Test Points 

Cathodic protection applies an impressed 

current, generated from an impressed 

current system with an external power 

source, onto the pipeline. This protects 

the gas pipeline and MEG pipeline from 

corrosion (and therefore leaks) provided 

that sufficient electric potential is maintained 

on the pipeline. In Victoria, the 

operation of impressed current systems 

requires the approval of the Victorian 

Electrolysis Committee. The spacing and 

location of impressed current units will 

be determined following further engineering 

investigation. Cathodic protection test 

points (Plate 5.17) will be installed at 

intervals of about one to two km along 

the pipe to enable systems operation to 

be monitored. 

Pipeline Marker Signs 

The location of the buried pipeline will be 

identified by permanent marker signs 

(see Plate 5.17). The Australian pipeline 

code (AS2885) specifies that marker 

signs are to be designed to a particular 

specification (size and height) and located 

so that each marker post can be 

clearly seen by line of sight from adjacent 

marker signs (as a minimum), and 

recommended for: 

• Infrastructure and utility crossings 

(such as roads, water and power services). 

• Watercourse crossings. 

• Horizontal change in direction. 

• Ancillary facility locations. 

• Property boundary fencelines. 

No pipeline marker signs will be located 

above the path of the HDD section within 

the Port Campbell National Park. 

5.5 Commissioning 

The pipeline will be commissioned at the 

completion of construction and testing. 

Commissioning involves completely purging 

the pipeline of air to ensure safe 

operation and ensure the achievement 

of market specifications for gas quality. 

5.6 Operations 

TXU personnel will operate the Casino 

pipeline facilities and wells, on behalf of 

Enesar 

Plate 5.17 

Santos, from the TXU WUGS facility control 

room. Minimal operator intervention 

is expected during normal operation, with 

the main involvement occurring during 

restart of the Casino wells after a shutdown. 

The small quantities of liquids produced 

from the reservoir with the gas, including 

water and condensate will be removed 

from the gas at the TXU facility. Any 

produced water will be disposed through 

TXU’s existing water treatment facility. 

The condensate will be stored at the 

TXU WUGS facility and then transported 

by a single road tanker to a refinery approximately 

two to three times a week. 

Condensate production from the Casino 

gas field is expected to decline after one 

to two years of operation to the equivalent 

of about one tanker per week. Condensate 

transport is expected to replace 

that which is currently being transported 

from Santos’ Heytesbury Gas Plant near 

Timboon, where condensate production 

is in decline. 

Once the pipeline is installed and restoration 

work has been completed, little 

evidence of the buried pipeline will remain, 

except for pipeline marker signs at 

various intervals along the onshore route. 

Routine ground patrols will be undertaken 

to monitor the onshore pipeline 

easement for operation and maintenance 

issues. Particular attention will be paid 

to easement stability, revegetation and 

weed invasion, watercourse crossings 

and any third party activities on the ease- 

Typical pipeline marker sign and cathodic protection test point 

ment. Santos will conduct ongoing consultation 

with affected landholders, commercial 

fishers and regulatory authorities 

with regard to the maintenance and operation 

of the pipeline and wells. 

The offshore pipeline will be inspected 

using a remotely operated vehicle immediately 

following construction, 12 

months after commissioning and then at 

regular intervals thereafter to check for 

pipeline integrity and stability. Both the 

onshore and offshore pipelines will be 

designed and constructed so that in-line 

inspection tools (pigs) can be passed 

through the pipelines to inspect their integrity 

if required. 

5.7 Decommissioning 

The Casino gas field has an expected 

life of 12 years, however, the proposed 

development infrastructure could have a 

significantly longer physical life should it 

prove useful for other gas field developments 

in the area. Santos is continuing 

to explore for petroleum reserves in the 

area and has designed the infrastructure 

to accommodate the tie-in of other gas 

fields, thereby potentially minimising the 

need for further shore crossings and pipelines. 

Any such future developments 

would be subject to separate assessment 

and approvals. 

If future use is viable then the pipeline 

will be preserved or ‘mothballed’, by filling 

it with inert gas (e.g., nitrogen) and 



corrosion inhibitor, and maintaining cathodic 

protection. Warning signs will remain 

in-place. 

In the event that the pipeline infrastructure 

is decommissioned, it will be undertaken 

in accordance with the regulatory 

requirements of the day. The current 

strategy for decommissioning is to abandon 

the pipeline in place by pigging it, 

capping it, removing onshore above 

ground facilities (except marker signs) 

and allowing the pipeline to deteriorate 

over time. 

The production wells will be plugged and 

abandoned. All casing strings will be cut 

off below the seabed and subsea wellheads, 

manifolds and other well control 

infrastructure removed. 

5.8 Project Life 

Commissioning and first gas from the 

Casino Gas Field Development is scheduled 

to commence in January 2006. It is 

expected that gas from the Casino gas 

field will continue to be produced until at 

least 2017. Peak gas flow is expected to 

occur at the start of reservoir life and is 

expected to be in the order of 106 TJ/d. 

Thereafter it is expected to gradually decline. 

At the commencement of operations, the 

maximum annual quantity of gas expected 

to be delivered to the TXU WUGS 

facility is 35 PJ/a. This is expected to 

remain steady for several years, and 

gradually decline over the life of the 

project to about 14.5 PJ/a in 2017. However, 

gas production may continue as 

other Santos gas fields in the region are 

developed and brought on line. 

5.9 Project Development 

Schedule 

The environmental impact assessment 

process began in October 2003 and is 

expected to be completed, with all approvals 

in place by December 2004. Construction 

is scheduled to commence in 

January 2005 to enable commissioning 

to start by December 2005, and commercial 

operation and first gas by January 

2006. Figure 5.17 identifies the 

detailed project timeframe and key milestones. 

Activity 

Pre-feasibility study 

Contract signed with TXU 

Preliminary engineering (FEED) 

Environmental Impact Assessment 

Government approvals 

Easement acquisition 

Construction 

Well drilling and construction 

Offshore pipeline & umbilical 


Onshore pipeline* 

Commissioning 

First gas 

2003 2004 

2005 

2006 

J A S O N D J F M A M J J A S O N D J F M A M J J A S O N D J F M A M J 

*January to March: includes pipeline construction. April to June: includes TXU tie-in and MLV construction. 

Figure 5.17 

Project development timeline 




6.1 Climate 

The Koeppen climate classification describes 

the southwest region of Victoria 

as having a temperate climate, with no 

dry season (warm summer) (BoM, 2004). 

The climatic averages for the region are 

outlined in Table 6.1. 

The closest Bureau of Meteorology (BoM) 

synoptic station is at Warrnambool, about 

60 km to the west of the project area. 

Rainfall data has been collected in Port 

Campbell for 106 years, between 1885 

and 1993, and is reported to have an 

average annual rainfall of 914 mm, with 

an average of 170 rain days (Enviromet, 

1998). Monthly average data is presented 

in Table 6.2. This indicates that December 

to March are the driest months with 

the least number of rain days, with May 

to September being the wettest months 

and having the most number of rain days. 

However, the highest daily rainfall totals 

mostly occur between November to 

March (Enviromet, 1998). 

The average wind speed at Port 

Campbell is 6.5 m/s. Wind direction is 

predominantly from the northwest between 

May and August, and from the 

southern half of the compass between 

November and March (Enviromet, 1998). 

6.2 Bathymetry and 

Oceanography 

6.2.1 Sources of Information 

The meteorologic and oceanographic 

environment of the study area was described 

by WNI Oceanographers and 

Meteorologists (WNI, 2003) during 

project conceptualisation and included 

site-specific data and regional published 

information. 

Table 6.1 

Climatic Characteristic 

Temperature and humidity 

A detailed bathymetric survey along the 

proposed pipeline route was carried out 

during January 2004 (Fugro, 2004). Both 

single-beam and multi-beam soundings 

were collected. All soundings were reduced 

to the lowest astronomical tide. 

The velocity of sound in seawater was 

determined by probe numerous times 

during the survey. 

6.2.2 Existing Environment 

Bioregion 

The offshore portion of the project area 

lies within the Otway meso-scale region 

as defined by the Interim Marine and 

Coastal Regionalisation for Australia 

(IMCRA, 1998). The characteristics of 

the coastline and marine environment of 

this region include very steep to moderate 

offshore gradients, high wave energy 

and cold-temperature waters, and 

the area is subject to upwelling events 

(IMCRA, 1998). 

Climatic averages for southwest Victoria 

Range 

Average annual temperature range 12 to 15°C 

Average minimum temperature 9 to 12°C 

Average maximum temperature 15 to 18°C 

Average daily 3pm relative humidity 60 to 70% 

Average daily 9am relative humidity 70 to 80% 

Rainfall and evaporation 

Average annual rainfall 

Average rainfall (January) 

Average rainfall (June) 

Average annual evapo-transpiration 

Average annual evaporation 

BoM, 2004. Based on climate data 1961-1990. 

800 to 1,000 mm 

25 to 50 mm 

50 to 100 mm 

500 to 600 mm 

1,000 to 1,200 mm 

Oceanography 

The Casino Gas Field Development is 

located on the western fringe of Bass 

Strait. Factors influencing the current flow 

through the strait are tidal forcing, waves, 

winds and large-scale ocean circulation. 

Winds in western Bass Strait are generally 

strong, exceeding 13 knots (more 

than 23.4 km/h) for 50% of the time, and 

are predominantly from the southwest. 

Winds contribute to the generally high 

wave-energy environment of western 

Bass Strait and at Port Campbell. Winds 

are predominantly southwesterly to northwesterly, 

with September being the windiest 

month with speeds averaging 8.08 

m/sec (WNI, 2003). Waves, therefore, 

are also predominantly southwesterly to 

westerly and the largest waves occur 

during winter months with mean wave 

heights ranging from 3.1 to 3.7 m and 

maximum wave heights between 7.6 and 

Table 6.2 Average rainfall and raindays in Port Campbell (1885 to 1993) 

J F M A M J J A S O N D 

Mean rainfall (mm) 42 39 53 77 94 99 109 110 92 84 62 54 

Mean raindays 9 8 11 14 17 17 19 19 18 16 12 11 



10.3 m (WNI, 2003). Wave heights in the 

summer months average between 2.5 

and 3.0 m, with maximum wave heights 

between 5.6 and 7.7 m (WNI, 2003). In 

the area of the Minerva Project, in-situ 

wave measurements have been collected. 

This data revealed that 2 to 3.5- 

m waves occur for 50% of the time and 

waves over 7.6 m in height occur during 

winter (BHP–Santos, 1999). Close to 

shore, waves are estimated to break at 

the 7-m depth contour about 50% of the 

time. 

Winds are also the primary factor driving 

currents in western Bass Strait, which 

are predominantly from west to east. 

Bottom currents can exceed 0.5 m/s in 

nearshore areas during storms (BHP– 

Santos, 1999). Current velocities through 

Bass Strait are highly correlated with local 

wind stress (Butler et al., 2002a). In 

the Port Campbell area, the predominant 

southwesterly swell direction means 

that there are minimal longshore currents 

as most waves reach the shore 

parallel to the coast. Therefore, in waters 

less than 10 m deep, water movements 

are influenced mainly by orbital 

motion waves and localised wave-generated 

currents (BHP–Santos, 1999). 

Tidal currents in western Bass Strait also 

flow predominantly from east to west at 

a speed of approximately 0.1 m/s (BHP– 

Santos, 1999). The maximum range of 

(˚N) 

-33 

-34 

-35 

-36 

-37 

-38 

-39 

-40 

Temperature (˚C) 

13 14 15 16 17 18 19 20 21 22 23 24 25 

spring tides in western Bass Strait is 

approximately 1.2 m. Tides are predominantly 

semi-diurnal with two tide cycles 

every day, but can shift to become diurnal 

with one cycle each day (BHP– 

Santos, 1999). Sea level variation in the 

area can arise from storm surges and 

wave set up. 

The temperature of surface waters in 

western Bass Strait ranges from approximately 

10 to 18˚C over the year. A seasonal 

thermocline is evident at 

approximately 30-m water depth in early 

December. This thermocline migrates 

deeper to reach approximately 100-m 

depth in May, when it dissipates through 

mixing. When the thermocline is established, 

temperatures in surface waters 

can be up to 4˚C higher than waters 

below the thermocline (BHP–Santos, 

1999). 

The coastal area of western Bass Strait 

is known to be an upwelling area and the 

seasonal phenomenon is named the 

Bonney 1 Upwelling (Butler et al., 2002a). 

Upwelling occurs when steady wind 

stress and the earth’s rotational forces 

cause a net transport of surface water 

offshore 2 . The water displaced offshore 

is replaced by deeper and colder water 

moving inshore and up-slope. The 

upwelling water is nutrient rich and the 

Bonney Upwelling corresponds with increases 

in the abundance of zooplankton 

(including krill, Nyctiphanes australis) 

which attract baleen whales, and other 

species, that feed on the plankton 

swarms (Butler et al., 2002a) (see below). 

Figure 6.1 shows a satellite image of 

sea surface temperatures of the region 

and cooler water upwelling offshore of 

the Bonney Coast. 

Bathymetry 

Bass Strait consists of a broad shallow 

region, bordered on the eastern and 

south western sides by very deep waters 

of the continental slope. The Casino gas 

field is located on the continental shelf, 

with the proposed well sites in water 

depths of approximately 70 m. The detailed 

bathymetry of the project area is 

shown in Figure 1.1. 

Along the proposed pipeline route, from 

the Casino gas field towards the shore, 

the seabed rises from 70 m to 50 m 

water depth over a distance of some 20 

km. Shoreward of the 50 m depth contour, 

the proposed pipeline route 

traverses through a shallow valley feature 

on the seafloor, but avoids a ‘spur’ 

feature on the seabed between 50 and 

70 m water depth by deviating east of 

the feature. 

6.2.3 Potential Impacts 

Potential impacts associated with marine 

bathymetry and oceanography include: 

• Pipeline stability on the seabed. 

• Pipeline spanning. 

6.2.4 Mitigation and Management 

Measures 

The following mitigation and management 

measures are proposed to minimise 

impacts on the marine environment: 

• Concrete weight coating or heavy wall 

pipe will be used to ensure that the 

pipeline remains on the seafloor under 

all operational and oceanographic 

conditions. The heavier pipe is ex- 

-41 

-42 

-43 

-44 

-45 

135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 151 152 153 154 155 

Adapted from Butler et al. (2002a). 

(˚E) 

Figure 6.1 

Sea surface temperature satellite image, showing cold water upwelling off the 

Bonney Coastline in March 1995 

1 Bonney Coast stretches from Robe in South Australia 

to Portland in Victoria. 

2 In the Southern Hemisphere, whenever a wind 

blows persistently along a coastline, water is drawn 

to the left of the wind. Along the Bonney Coast, it is 

the southeasterly winds (which are common from 

November to March) which cause nearshore waters 

to flow away from the coast. It is the combination of 

persistent southeasterly winds and the geometry of 

the coastline that causes upwelling to occur during 

the warmer months of the year. 



pected to become buried wherever 

the substrate is predominantly sandy. 

• Santos will undertake remote operated 

video surveys (by underwater 

video camera) of the pipeline to visually 

inspect the condition of the pipeline 

on the seafloor (where visible) 

and to search for any lengths of the 

pipeline where spanning 3 has occurred. 

• If survey identifies significant spanning 

of the pipeline, retrospective 

maintenance work may be required 

such as the placement of artificial infill 

(grout bags placed beneath the 

spanned section of pipe then filled 

with concrete slurry) to fill the void to 

support the spanned sections of pipe. 

6.2.5 Residual Impacts 

The presence of the subsea wellheads 

and associated equipment on the seabed 

at the Casino gas field and the pipeline 

to shore will have highly localised 

effects on bottom currents. This may lead 

to the localised redistribution of seafloor 

sediment, such as the build-up of sand 

on the lee-side of the wellheads and 

other equipment as well as the self-burial 

of the pipeline where conditions permit. 

6.3 Marine Ecology 

6.3.1 Survey Methodology 

Seabed Classification 

The textural characteristics and reflective 

strengths of the seafloor were investigated 

during January 2004 using dual 

frequency side scan sonar transducers 

mounted in a tow-body and a sonar transceiver 

(Fugro, 2004). Side scan sonar 

data quality was good and not significantly 

affected by weather conditions 

experienced during the survey. 

Underwater Video Footage 

At the time of the acoustic survey, video 

footage of the seabed was obtained at 

seven sites along the proposed subsea 

pipeline route using a digital video camera 

housed in a remotely operated vehicle 

(ROV) (Figure 6.2). The ROV was 

deployed from the survey vessel whilst 

stationary and the operator controlled 

the ROV with a joystick while viewing a 

video monitor on deck. The video footage 

was recorded to classify the seabed 

habitats and ground-truth the acoustic 

seabed classification survey results. 

Video footage was transferred to DVD 

and digital images extracted from each 

of the seven deployments to show representative 

habitat type. Video footage from 

an additional two sites near the Casino 4 

and Casino 5 well sites was obtained in 

2002 during exploration drilling. Frame 

grabs from these two sites were also 

extracted to show representative habitat 

types in the well sites areas that were 

not covered in the later video survey. 

Seabed Sampling 

At each of the seven ROV deployment 

sites, a sample of the seabed sediment 

was collected. Samples were used for 

visual classification of sediment grain size 

and to ground-truth seabed classification 

results from the side scan sonar 

survey. 


Regional Western Bass Strait 

Review of previous studies in the Port 

Campbell area (BHP–Santos, 1999) indicate 

that the following habitats can be 

expected to occur between the shore 

and the well sites: 

• Intertidal environment (0 to 2 m): 

– Rock platform. 

– Cliff face. 

– Sandy beach. 

• Shallow environment (2 to 8 m): 

– Contiguous kelp reefs. 

– Patch sandy reefs. 

– Sand. 

• Mid-depth environment (8 to 20 m): 

– Eklonia reef. 

– Sand. 

• Deep environment (20 to 70 m): 

– Sponge-dominated reef. 

– Sand. 

Intertidal Environment. The intertidal 

environment at Two Mile Bay comprises 

a small sandy cove with rock platforms 

on either side (BHP–Santos, 1999). The 

rock platforms are relatively uniform, low 

gradient benches that are tidally submerged 

or wetted by waves or wave 

spray (Plate 6.1) and are dominated by 

brown, red and green algae. As is typical 

for rock platforms on the Victorian coastline, 

there is horizontal zonation of algal 

types and the edge of the platform is an 

abrupt, steep ledge. Invertebrates colonising 

the rock platform include gastropods, 

polychaetes and bivalves. 

Shallow Environment. Extending from 

the intertidal rock platforms are areas of 

contiguous kelp reef consisting of large 

areas of hard substrate dominated by 

large brown algae (bubble weed, 

Phyllospora comosa and bull kelp, 

Durvillaea potatorum). In some areas, 

kelp reef rises close to the surface and 

waves may break on these features. 

Epifauna such as sponges, ascidians and 

molluscs, including abalone, are also 

associated with this habitat (BHP– 

Santos, 1999). Fishes such as wrasse, 

leatherjacket, scalyfin and morwong are 

also likely to inhabit contiguous kelp reef. 

Small patches of non-contiguous reef 

dominated by large brown algae (bubble 

weed, Phyllospora comosa and bull kelp, 

Durvillaea potatorum) or a turf of red and 

brown algae interspersed with the green 

algae Caulerpa sp. and Codium sp. also 

occur in the shallow environment. Tracts 

of open sand separate these small patch 

reefs and similar species of epifauna and 

fish to those occurring on contiguous 

reef are likely to occur here. 

Shallow reefs give way to open sand 

further offshore. The sand areas in the 

shallow environment are characteristically 

devoid of significant epifauna but 

may contain significant infaunal communities 

including bivalves, crustaceans and 

polychaetes. The infauna provides food 

resources for some foraging fish such as 

bream and flounder and cephalopods 

such as octopus that may inhabit these 

areas. Shallow sand areas typically have 

coarse-grained sand forming sand waves 

caused by wave action. 

Mid-depth Environment. The mid-depth 

environment is the most extensive and 

is relatively uniform, dominated by sand. 

Open sand in this environment comprises 

a range of grain sizes although sand is 

usually finer and sand waves of lower 

crest height and inter-crest distance than 

in the shallower environment. BHP– 

Santos (1999) identified intermittent 

patch reefs dominated by the brown alga, 

Ecklonia sp. Red algae and coralline algae 

were also identified on these reefs, 

in addition to epifauna including 

echinoderms, ascidians, bryozoans and 

sponges. These isolated reefs probably 

represent centres of high species diversity 

and abundance of epifauna and fish 

compared to the open sand. 

Deep Environment. Large tracts of open 

sand, with little or no epifauna, charac- 

3 Spanning can occur in predominantly sandy seafloor 

areas. Storms can result in movement and 

redistribution of seafloor sediment and, if severe, 

can cause sand waves to form. Wherever sand 

waves form, the pipeline may not be resting on the 

seafloor in the gap between individual sand waves 

i.e., the swales. The spanning length depends on 

the inter-crest distance between successive sand 

waves. 



9 

8 


5 730 000 N 

Casino 5 

1 

Casino 6 

Biological Description 

Sponges, hydrozoans, bryozoans and algae dominate 

epifauna. Several demersal fish species 

Little or no epifaunal communities. 

Biological component principally infaunal and pelagic 





Definitions: 

Epifauna: organisms living in and anchored to the surface of 

the substrate. 

Infauna: organisms (macro-and micro-scopic) living within 

the sediment to a depth of about 20 cm. 

Demersal: organisms inhabiting the bottom layers of the water 

column and closely associated with the substrate. 

Pelagic: organisms inhabiting the surface layers of the water 

column with little or no association with the 

Physical Description 

Subcropping/outcropping low relief 

hummocky calcisiltite/calcarenite 

interspersed with a patchy veneer of shelly 

calcareous course sand/fine gravel 

Fine to medium sand 

3 nm limit 

40m 

5 720 000 N 

Fine to coarse gravel with patches of 

subcropping cemented sediments 

50m 

Course sand/fine gravel 

60m 

5 710 000 N 

Lovers Nook 

Peterborough 

Curdies Inlet 

Newfield Bay 

5 730 000 N 

Port Campbell 

5 720 000 N 

Two Mile 

Bay 

5 710 000 N 

N 

650 000 E 

660 000 E 

670 000 E 

650 000 E 

660 000 E 

670 000 E 

Casino offshore pipeline survey corridor 

Casino offshore pipeline route alignment 

Bathymetry (2 m intervals) 

Casino 

Gas Reservoir 


Casino 4 

0 km 5 

2 

Casino 4 

7 

3 4 5 9 

6 

8 

Casino offshore pipeline route alignment 

Proposed gas well-head location 

ROV footage location 

8 

1 2 3 4 5 6 7 

Figure 6.2 Seabed habitat classification of the Casino pipeline route 



Enesar 

Plate 6.1 

Panoramic view of Two Mile Bay , showing the intertidal environment 

terise the deep environment in the project 

area. Infaunal communities of bivalves, 

polychaetes and crustaceans probably 

dominate the biological component in the 

open sand habitat. However, areas of 

reef, dominated by sponges, have also 

been observed in the deep environment. 

Other epifauna occurring in this habitat 

includes hydrozoans, bryozoans, algae, 

echinoderms and molluscs. Fishes such 

as wrasse, gurnard and perch inhabit 

these reefs. Abalone and lobster are also 

likely to occur. 

Sponge ‘gardens’ in Bass Strait have 

received scientific attention recently and 

very high sponge diversity and abundance 

in central Bass Strait has conservation 

significance for the region (Butler 

et al., 2002b). While no information is 

available for western Bass Strait, O’Hara 

(2002) noted that sponges were collected 

south of Cape Otway. Sponge reefs in 

the deep environment are more likely to 

be centres of higher species diversity 

and abundance than the open sand habitats 

and have some conservation significance 

as a consequence. The sponge 

reefs are also of conservation significance 

from a ‘scientific interest’ point of 

view. 

Sponge ‘gardens’ in central Bass Strait, 

which are particularly abundant in the 65 

to 75 m depth contour, are considered 

‘special areas’ as defined by the Australian 

and New Zealand Environment and 

Conservation Council (ANZECC) Task 

Force on Marine Protected Areas 

(TFMPA, 1999; Butler et al., 2002b). 

However, the sponge ‘gardens’ of central 

Bass Strait are not selected as part 

of the Comprehensive, Adequate and 

Representative (CAR) system of Marine 

Protected Areas (MPAs) for Australia, 

although Butler et al. (2002b) believe 

that creation of an MPA in central Bass 

Strait would increase the representativeness 

of the habitat. 

The sponge ‘gardens’ in central Bass 

Strait are likely to be representative (although 

probably more diverse and abundant) 

of those in western Bass Strait. 

Therefore, the sponge reefs in western 

Bass Strait are not expected to warrant 

separate MPA classification. 

Threatened Species. Fauna of national 

significance that may be encountered 

within the project area are provided in 

the EPBC referral for the project (Ref: 

EPBC 2003/1295). There are 17 species 

of marine birds listed, most of which are 

migratory (and protected by international 

agreements such as CAMBA and 

JAMBA), and may overfly the project 

area. Among these are thirteen species 

of albatross (three are endangered and 

eight are vulnerable) and four species of 

petrel (one endangered, two vulnerable). 

Bird species are highly unlikely to be 

impacted by the proposed activities for 

the Casino Gas Field Development due 

to the lack of suitable habitat and roosting 

sites and the avoidance of impacts to 

shoreline habitat. There are also a 

number of listed fish species (pipefishes, 

seahorses and seadragons) that may 

occur in the area. However, their known 

habitat comprises the kelp reefs that are 

located predominantly close to shore and 

in much shallower water than that of the 

proposed drilling location, which is 30 km 

offshore of the coastline in 70 m water 

depth. The proposed offshore pipeline 

route has been specifically selected so 

that it minimises effects on reef habitats. 

There are seven whale species that may 

occur in the project area; three of these 

(blue whale, southern right whale and 

humpback whale) are listed as threatened 

under the EPBC Act. 

Blue whales have widespread migratory 

paths. Sightings of blue whales have 

been recorded during the summer 

months from November through to May 

(with more whales sighted in March and 

April than other months) on the continental 

shelf at water depths of less than 

200 m between longitudes 139°18’E to 

143°03’E (Gill, 2002). The exact time 

and location of the blue whale appearance 

is difficult to predict (Gill, pers. com., 

2003), however, it has been suggested 

that their appearance is related to 

aggregations of the krill species, 

Nyctiphanes australis, which are common 

along the Bonney Coast upwelling 

region (Gill, 2002). Observations suggest 

that western Victoria and southeast 

South Australia are primarily used for 

feeding grounds by the blue whales in 

summer and early autumn (Gill, 2002). 

The blue whales congregate mainly along 

the 100 m isobath (Gill, 2002), which is 

about 24 km south of the Casino gas 

field, although sightings extend both inshore 

and offshore of this contour and 

encompass the project area (Figure 6.3). 

Southern right whales migrate each year 

from the Antarctic summer feeding areas 

to warmer waters along the western 

and eastern coasts of Australia, where 

they calve and mate. Migration along the 

eastern coastline is expected to occur 

between mid-May and September (Environment 

Australia, 2001), and they pass 

through the latitude of the Casino gas 

field to reach inshore areas. 

Warrnambool is an important calving and 

nursery area, with the majority of 

sightings occurring just outside the surfbreak 

in water depths of approximately 5 

to 6 m. They are believed to have a 

breeding cycle of three years (Environment 

Conservation Council, 2000) and 

females with calves are present every 

year off Warrnambool. 

Humpback whales can be found off the 

coast in winter and spring. However, Victorian 

coastal waters are not a key location 

for this whale species (Bannister et 

al., 1996). A discrete population of humpback 

whales migrates annually along the 

east coast of Australia between summer 

feeding grounds in the Antarctic and winter 

breeding and calving grounds in the 

tropics. Most pass to the east of Tasmania 

but some pass to the west and 

through Bass Strait. In recent years, an 

increased number of sightings have been 



640 000 650 000 660 000 670 000 



Gas Plant 

Curdies 

Heytesbury 

Gas Plant 

Proposed 

Otway Gas 

Project Plant 

Spring Creek 

River 

Creek 

Wallaby 

Lovers Nook 

Curdies 

Inlet 

Peterborough 

10m 

20m 

30m 

Port Campbell 

40m 

Newfield Bay 

50m 

Two Mile Bay 

TXU WUGS 

Facility 

Eastern 


Minerva Gas 

Plant 

Creek 

N 

0 km 5 


HDD shore 

crossing site 

60m 



Blue whale sighting 


HDD section 




Gas well 

Bathymetry 

70m 

Minerva 

Gas 

Well 

VICTORIA 

Warrnambool 


Port Campbell 

Casino 4 

N 

0 km 50 

Adapted from Gill (2002). 

Figure 6.3 Blue whale sightings between February 1998 - May 2002 

5 710 000 5 720 000 5 730 000 


made along the Victorian coastline from 

May to early August and also November 

and December (Gill, pers. com., 2003). 

During the autumn period, there have 

been sightings from the shore of humpback 

whales heading east off Portland 

and Warrnambool (Woodside, 2003). 

Proposed Pipeline Route 

Seabed habitat classification determined 

from the acoustic survey is shown in 

Figure 6.2. Physical descriptions of the 

seabed along the proposed pipeline route 

are based on side scan sonar data and 

biological descriptions from the remote 

operated video footage and visual inspection 

of seabed samples. 

Much of the seabed traversed by the 

proposed pipeline from the directional 

drilling exit point to approximately 60 m 

water depth is classified as sand or fine 

gravel. No epifauna were observed in 

these large tracts of sand and the biological 

component of this habitat is likely 

to be primarily infaunal or pelagic. 

Beyond 60 m water depth, extending out 

to the well sites, the seabed is characterised 

by concreted outcroppings with 

very low relief and structural complexity 

separated by gullies of sand or fine 

gravel. Video footage from one location 

in 2003, Kilometre Point (KP) 15.70, and 

two locations surveyed in 2002 in the 

vicinity of the proposed well sites (ROV 

Locations 1 and 2 in Figure 6.2) indicates 

that this broad, flat area has a 

sparse cover of filter-feeding epifauna 

dominated by sponges and also probably 

including hydrozoans, bryozoans 

and algae. Some small fish species were 

observed at the well sites but were unable 

to be identified to species level in 

the video footage. 

This large area of sparse epifauna cover 

is differentiated from a more abundant 

and diverse sponge reef feature identified 

at KP 19.50. This site is located on 

the northern side of a ridge that is traversed 

by the proposed pipeline route 

(see Figure 6.2). The landward slope of 

this ridge is steep and the acoustic physical 

characterisation of the top and edge 

of the ridge is the same as that for the 

broad float area further offshore. However, 

the biological classification of the 

seabed at KP 19.50 is sponge reef habitat 

with diverse and abundant epifauna 

consisting of sponges, hydrozoans, 

bryozoans and algae. Fish species identified 

in video footage at this location 

(KP 19.50) are magpie morwong 

(Cheilodactylus nigripes), blue-throated 

wrasse (Notolabrus tetricus), gurnard 

(Neosebastes scorpaenoides), goatfish 

(probably Upeneichthys vlamingii), butterfly 

perch (Caesioperca lepidoptera) 

and another wrasse species that could 

not be identified. These species are typical 

of temperate sub-tidal reefs and, while 

not identified in the video footage, various 

other epibenthic organisms such as 

crustaceans and molluscs are likely to 

be associated with this habitat. This 

sponge reef habitat also represents the 

only potential abalone and rock lobster 

habitat along the pipeline route, although 

vertical profile normally associated with 

such reef is largely absent. 

Therefore, while it is confirmed that 

sponge reef habitat occurs on the edge 

of the ridge at KP 19.50, sponges and 

other epifauna may also occur, albeit in 

reduced density and diversity, intermittently 

along the proposed pipeline route 

between the ridge and the well sites 

where the seabed was acoustically classified 

as having the same physical characteristics 

as the ridge (see Figure 6.2). 

Video footage from KP 19.60, just 100 m 

further down slope from KP 19.50, shows 

sand habitat, as does footage from KP 

17.30 on the seaward side of the ridge. 

Hence the sponge reef habitat at KP 

19.50 is localised and isolated and does 

not cover a large area. 

Kelp-dominated reef, that is known to 

occur in the region, does not appear to 

feature along the proposed pipeline route 

in the depths covered by the acoustic 

survey. However, the acoustic seabed 

survey did not extend into the shallow 

areas immediately offshore from the intertidal 

zone in Two Mile Bay, where 

kelp reefs are known to occur (see 

above). The proposed pipeline will not 

impact this habitat, as it will be 

directionally drilled beneath the substrate 

to a distance of some 800-m offshore, 

exiting in sand habitat. The route between 

the HDD exit point and KP 3.20 

was recommended by commercial fishers 

specifically to avoid the known offshore 

areas of kelp-dominated reef. 


The following potential impacts to the 

marine environment are associated with 

the development of the Casino gas field: 

• Physical effects to marine flora and 

fauna and marine habitat. 

• Chemical effects from discharges 

during the construction and operation 

phases. 


The following section addresses the assessment 

of these potential impacts. 

Marine noise is assessed in Section 6.4. 

6.3.4 Impact Assessment 

Construction 

The construction phase of the offshore 

component of the Casino Gas Field Development 

will involve: 

• Drilling at the two well sites: 

– Drilling will be carried out from an 

anchored semi-submersible rig, to 

a depth of approximately 2,000 m 

below the seabed. Drilling will be 

carried out over a period of about 

2 months (i.e., 35 days per well). 

• Placement of wellheads at the well 

sites: 

– Two wellheads, with dimensions 

of 5.2 m wide x 5.2 m depth x 5.2 

m high (approximately 27 m 2 basal 

area), will be placed on the 

seabed at the well sites (see Plate 

5.2). 

• Laying of an offshore pipeline from 

the well sites to the HDD exit point: 

– The offshore gas pipeline will be 

300 mm in diameter, running for 

a total distance of 36.7 km. As 

there will be no excavated burial 

of the pipeline, stabilisation will 

be achieved through concrete 

coating or thicker wall pipe, weighing 

the pipeline down. Laying of 

the pipeline will be by pipelay 

barge or pipe reel-lay vessel (see 

Plates 5.3 and 5.4). 

• Horizontal directional drilling under 

the shoreline: 

– The HDD exit point will be located 

approximately 800 m from the 

shore, in a water depth of approximately 

15 to 16 m. 

• Hydrostatic Testing: 

– Once completed, the offshore 

pipeline will be tested for leaks by 

hydrostatic means by filling with 

potable water and pressurising, 

requiring approximately 2,660 m 3 

of water. Hydrotest water will contain 

chemical additives of biocide 

and an oxygen scavenger to prevent 

corrosion. A suitable dye may 

also be used in the offshore pipeline 

fill water to aid in the detection 

of any leaks during the 

offshore hydrostatic test. 



Drill Fluid and Cutting Disposal at the 

Well Sites. Drill cuttings are ground-up 

rock fragments generated by the drill bit 

as it penetrates the geological formations 

below the seafloor. These sediments 

vary from very fine to coarse 

particles. Total expected volume of drill 

cuttings is approximately 350 m 3 per well. 

Drill cuttings are returned directly to the 

seafloor for the shallower sections, but 

from the deeper sections are returned to 

the rig in a closed system that allows 

recycling of the drill fluid. The cuttings 

and fluids are then passed over a shale 

shaker that separates the cuttings from 

the fluids, and the cuttings are then disposed 

to sea via a chute. Most of the 

fluid is recycled (i.e., returned as drilling 

mud to the well) and only that adhering 

to the surfaces of the cuttings is discharged 

to sea. Discharge of spent fluid 

(estimated up to 2,000 m 3 ) at the end of 

drilling will be undertaken as is normal 

procedure in offshore drilling operations. 

The Casino drilling program will use only 

low toxicity, water-based drilling additives, 

comprising 40 to 70% seawater. 

Barium is used as a weighting agent to 

increase the density of the drilling fluid. 

The biological effects from the discharge 

of cuttings and drilling fluids are expected 

to be localised and confined to within 

about 100 to 250 m of the drill site and 

short lived (less than 24 months). Concentrations 

of heavy metals or hydrocarbons, 

due to the discharge of cuttings 

are not expected to be detectable beyond 

1,000 m (Hinwood et al., 1994; 

APPEA, 1998). 

Cuttings disposed from the rig are expected 

to form a turbid plume, within 

which the larger particles (90 to 95%) 

should quickly settle on the seabed (usually 

within a radius of 200 m from the 

rig), and the remainder dispersed by 

ocean currents (Currie, 1995). Disposal 

of cuttings and adhered fluid will create 

turbid plumes below and down current of 

the point of discharge. Tidal currents and 

the interaction of waves are expected to 

facilitate the rapid dispersion and dilution 

of the turbid plumes so that their 

effects are localised. 

As most of the cuttings are expected to 

settle on the seafloor, the main impact to 

the seabed will be localised smothering 

of epibenthic fauna and infauna and minor 

substrate modification, typically within 

a 200 m radius of the well (Currie, 1995). 

The habitat in the general area of the 

wells is classified as ‘subcropping/lowrelief 

outcropping separated by sand gullies’. 

Potentially impacted epibenthic 

communities on hard sediments near the 

wells are dominated by sponges, hydrozoans, 

bryozoans and algae. Other 

epifauna, such as gastropod molluscs, 

some species of crustacean and 

echinoderms that may occur in low abundance 

in this habitat type would also be 

exposed to impacts of smothering due to 

their limited mobility. There is little or no 

epifauna on unconsolidated sand and 

macro- and microscopic infauna such as 

polychaete worms, bivalve molluscs and 

crustaceans, are likely to dominate the 

communities in the sand gullies that will 

be affected. Fish and other mobile fauna 

(e.g., crabs, octopus) in the area of disturbance 

are expected to physically avoid 

unsuitable areas and as such will not be 

directly impacted. 

Environmental studies undertaken in the 

offshore Gippsland and Otway basins 

showed that localised effects were generally 

short-lived, with most benthic organisms 

recovering within four months 

(BHP–Santos, 1999; Terrens et al., 

1998). The latter study was conducted in 

70-m depth in eastern Bass Strait, and 

showed that impact to benthic organisms 

was restricted to within 100 m of 

the platform, with recovery evident after 

four months. In addition, no elevated concentrations 

of trace element indicators 

were detected when water-based fluids 

alone were used. 

Wellhead Installation. Installation of the 

wellhead on the seafloor will be undertaken 

by the drilling rig and is expected 

to cause minimal impact to epifaunal 

communities. The wellheads will be 

placed on the seabed, on a substrate 

that would have already been modified 

by the discharge of drill cuttings (see 

above). The hard surfaces of the wellheads, 

along with the deposited drill 

cuttings, are likely to be colonised by 

epifauna. Anchoring of the drill rig during 

drilling and placement of the wellheads 

is expected to cause localised physical 

damage to epibenthic organisms. 

Pipeline Installation. Physical effects 

are expected to arise from the settling of 

the pipe on epifaunal organisms directly 

beneath the pipe and from anchors used 

to position the pipelay barge. Anchors 

would be deployed as the vessel moves 

along the pipeline route. The setting and 

possible dragging of these anchors may 

physically disturb epifauna. Much of the 

36.7 km pipeline route is sand with little 

or no epifauna. In these areas, there is 

expected to be passive burial of the pipe 

in the sandy seafloor. 

Potential impacts to epifauna will be restricted 

to the sponge-reef habitat on the 

ridge feature about half way along the 

pipeline route and epifauna associated 

with the low relief outcropping between 

the wells and the ridge (see Figure 6.2). 

However, the extent of the impact is limited 

to that directly underneath the pipeline, 

and underneath anchors during the 

pipe lay. There is likely to be colonisation 

of exposed hard surfaces of the pipe 

by epifauna such as sponges, hydrozoans, 

bryozoans and algae both in the 

sand habitat and in the sponge-reef/ 

outcropping habitat. 

Pipe laying will take approximately 

20 days and so the potential impacts of 

physical damage to epibenthos along the 

pipeline corridor will be both localised 

and short-lived. Fish and other mobile 

fauna are expected to avoid areas of 

physical disturbance, although there is 

some anecdotal evidence of fishes being 

attracted to activity that physically 

disturbs the seabed because food items 

are agitated from the sediments and 

therefore made available for fish. There 

is expected to be no direct impact to fish 

and, although there may be a short-term 

loss of some habitat and food resources 

due to the physical damage to epifauna, 

fish and other predators would be expected 

to move back into the impacted 

areas shortly after the pipe laying. As 

there will be no active burial of the pipeline, 

sediment and turbidity issues are 

not expected to be significant. 

Horizontal Directional Drilling. Circulating 

drilling mud will be used to clean 

cuttings out of the drill hole. Immediately 

prior to break through, the drill string 

may be flushed with fresh water to minimise 

the amount of drilling fluid that is 

released to the ocean. Despite this precaution, 

the seabed exit point, which is 

located in sand habitat in approximately 

15 to 16 m water depth, will discharge 

about 200 m 3 of water and some sediment 

to the nearshore environment. This 

is expected to cause a temporary increase 

in turbidity in the immediate vicinity 

of the exit point. Currents will rapidly 

disperse the turbid water. 

Hydrostatic Pressure Testing. Small 

quantities of corrosion prevention additives 

will be used during hydrostatic testing. 

These include biocide (Bacton 

B1150) at approximately 190 ppm and 

oxygen scavenger (OS2) at approximately 

250 ppm. The quantities and type 

of additives may vary depending on the 

duration of the pipeline testing. A suit- 



able dye may also be used to aid the 

detection of leaks in the offshore pipeline. 

Hydrotest water will be discharged 

in a continuous manner in the vicinity of 

the wellhead over a period of four days. 

Upon discharge, the active component 

of the additives are expected to be rapidly 

diluted and transported by currents 

so that no adverse impacts to marine 

ecology are expected from the discharge 

of hydrotest water. 

Other Discharges. Apart from the well 

drill cuttings, the offshore drilling and construction 

activities will produce very little 

waste. An appropriate waste management 

plan, compliant with MARPOL requirements, 

will be in place. Discharge 

of sewage will result in very localised 

enriched nutrient levels, which may also 

stimulate microbial growth. However, as 

the permit area is in 70-m water and 

30 km distant from the coast, adverse 

consequences are not expected as it will 

rapidly disperse. 

Very low volumes of produced formation 

water are expected to occur within the 

gas stream but no disposal at sea will 

occur. Any produced formation water will 

be disposed to TXU’s existing water treatment 

facility onshore at the TXU WUGS 

facility. 

Accidental Hydrocarbon Spills. Risks 

of major spills from drilling in Australian 

waters are low, estimated at 4.4 x 10 -3 

per annum (WA EPA, 1997). 

Santos maintains an approved oil spill 

contingency response plan for its operations 

in the Otway Basin, including trajectory 

modelling which was undertaken 

for the Casino 1 and 2 exploration drilling 

program in 2002 (APASA, 2002) and 

updated for the Casino 3 appraisal drilling 

program in October 2003 (APASA, 

2003). The oil spill contingency response 

plan will be amended to incorporate field 

development and operation activities in 

accordance with permitting approvals. 

The main source of a potential ‘worst 

case’ spill during the drilling program are: 

• Highly volatile gas condensate associated 

with a blowout. 

• Diesel fuel associate with a shipping 

accident at the drilling rig. 

• Spill of lubricants and drilling fluid 

additives. 

Oil spill modelling examined a worst-case 

spill (443 m 3 ) for the Casino exploratory 

drilling program and modelled 100 hypothetical 

spill simulations using OILMAP 

spill model and regional metocean data 

for the past three years. 

The results from worst case spills in terms 

of volumes and time of spill indicated a 

97% probability of condensate reaching 

the Victorian coastline within 20 hours. 

However, because of the high volatility 

of gas condensate, complete evaporation 

would occur (less than 0.3% remaining) 

after 14 days. By the time any (of 

the worst case volume) did reach the 

shoreline, it would be visible only as a 

thin and patchy film and would continue 

to evaporate over time. The gas is known 

to be predominantly dry with very low 

condensate content, hence risks of landfall 

from any spill are low. This conclusion 

does not account for the application 

of response measures such as containment 

booms and dispersion, to prevent 

a spill from grounding at the coastline. 

All hydrocarbon-contaminated drainage 

from the drilling deck will be retained 

and either treated in the rigs oily waste 

treatment facility prior to disposal or periodically 

taken to shore for appropriate 

disposal. 

Strict refuelling and operations procedures 

mitigate potential diesel spills during 

drilling operations. Impacts 

associated with potential diesel spills are 

generally less likely, as diesel is a light 

petroleum product, which would spread 

rapidly after spillage to form a thin sheen. 

Diesel will also evaporate and disperse 

relatively rapidly under typical conditions 

(i.e., 95% of initial spill volume would be 

lost by weathering during the first five 

days (GEMS, 2001). Given that the drilling 

rig will be located some 30 km offshore, 

a small diesel spill during refuelling 

is considered unlikely to pose a significant 

threat to the near-shore or coastal 

environment. 

Introduction of Exotic Species. The 

drill rig and support vessels will not take 

on or discharge ballast water and so any 

risk of introducing exotic marine pests is 

from attachment to vessel hulls. Standard 

procedures for minimising the introduction 

or translocation of exotic pest 

species into waters of the Otway Basin 

include the treatment of the rig and vessels 

with anti-fouling paints. Verification 

of anti-fouling of the hull, in particular, 

the date and location of its latest application 

(in equivalent or dissimilar latitudes), 

and general hull hygiene 

maintenance will be provided to regulatory 

authorities, once the identity of all 

vessels is known. It is possible that 

Santos may take over the rig and pipelay 

vessel on completion of a contract in an 

adjacent lease area, in which case, the 

risks would be minor as the rig and vessels 

will already be based in the Otway 

Basin. 

Operations 

During the operations phase of the 

project, there is minimal potential for ongoing 

adverse impacts. After the completion 

of drilling and commissioning of 

the pipeline, infaunal and epifaunal communities 

will begin to re-colonise areas 

that were smothered by drill cuttings during 

the construction phase. The pipeline 

is expected to become colonised by various 

epifauna and any sponge-reef habitat 

physically damaged will begin to 

recover, attracting fish and other mobile 

fauna. Studies at exploratory drilling sites 

at the Minerva gas field indicated that a 

decline in infauna abundance at the drill 

sites was significant after drilling, but confined 

to an area less than 200 m from the 

disturbance (Currie, 1995). Infaunal communities 

appeared to recover after just 

four months. 

During operations, a small amount (less 

than 1 litre) of hydraulic fluid is discharged 

from the wellhead each time a valve or 

choke is activated remotely via the umbilical 

control. This is normal for subsea 

gas production facilities throughout the 

world. It is expected that the average 

volume would be 184 litres per annum 

for the first five years and approximately 

115 litres per annum after that. The hydraulic 

fluid is classified as non-toxic. 

Being less dense than seawater, the 

small releases of hydraulic fluid will be 

buoyant and will tend to rise from the 

seafloor and are not expected to have 

any impact on benthic communities. 

Rapid dilution, evaporation and dispersal 

of the small quantities of vented fluid 

is expected to occur and no measurable 

effects on planktonic organisms are likely 

to occur. Fishes are expected to sense 

and avoid the small plumes of dilute hydraulic 

fluid. Each plume is expected to 

be substantially diluted and dispersed 

before or upon reaching the surface, were 

any residue would rapidly evaporate and 

weather, and as such is not expected to 

cause adverse impacts to seabirds or 

cetaceans. 

The offshore gas pipeline and umbilical 

line will be designed based on the risk 

assessment and therefore able withstand 

snagging and potential rupture. The offshore 

pipeline will be either concrete 



coated or thick wall pipe for negative 

buoyancy, and similary, the umbilical will 

be armoured within a steel casing with 

rope reinforcers. The risk of rupture and 

consequent spillage is therefore very remote. 

Intermittent maintenance and inspection 

of the pipeline and wellheads by vessel 

are not likely to significantly impact marine 

communities. 

Decommissioning 

At the end of well life, the wells will be 

cut and sealed below seabed level and 

the wellhead structures removed. There 

are not expected to be any impacts to 

marine ecology from decommissioning 

activities. The need for removal of the 

pipeline will be dependent on the extent 

of its burial at the time of 

decommissioning and agreement with 

the authorities at the time. 


Measures 

Mitigation in the marine environment is 

largely achieved by appropriate route 

selection. Other mitigation and management 

measures are described below. 

General 

• Vessels will be subjected to standard 

requirements for the prevention of 

the introduction of exotic pests including 

verification of anti-fouling and 

general hull hygiene maintenance. 

• Santos’ oil spill contingency response 

plan for the Casino 3 drilling program 

will be updated to incorporate all field 

development and operation activities. 

• Strict refuelling and operations procedures 

will be in place to mitigate 

potential diesel spills during construction. 

• An appropriate waste management 

strategy will be developed for all marine 

activities to avoid adverse effects 

to the marine environment. 

Hazardous solid and liquid wastes 

will be containerised and transported 

to shore for appropriate disposal during 

the drilling and construction 

phases. Discharges of putrescible 

solids and sewage and grey water 

will follow primary maceration, in compliance 

with MARPOL requirements. 

• A marine monitoring program will be 

developed to verify predicted marine 

environment impacts. 

• A protocol to minimise adverse interaction 

with whales during construction 

and drilling (e.g. support vessel 

movements) based on DEH guidelines 

(Environment Australia, 2001). 

Drilling and Well Completion 

• The Casino drilling program will use 

only low toxicity, water-based drilling 

additives, comprising 40 to 70% seawater. 

• All hydrocarbon-contaminated drainage 

from the drilling deck will be retained 

and either treated in the rig’s 

oily waste treatment facility prior to 

disposal or periodically taken to shore 

for appropriate disposal. 

Pipeline Construction 

• The low ridge feature at KP 19.5 will 

be protected to the maximum extent 

practicable to minimise the risk of 

damage. Anchoring by the pipe lay 

and support vessels will be avoided 

if possible in this area. 

Horizontal Directional Drilled Shore 

Crossing 

• The HDD drilling program will use 

low toxicity, water-based drilling additives 

only. 

• Prior to break-through of the drill bit 

into the marine environment, drilling 

will pause to allow the HDD rig to 

flush cuttings from the drilling fluid, 

thereby significantly reducing the potential 

quantity of sediment discharge 

at the time of break through. 

Potential impacts associated with marine 

acoustics are addressed in Section 

6.4. 

6.4 Marine Acoustics 

This section deals with underwater noise 

derived from offshore drilling and construction 

activities and its potential impact 

on marine animals. It focuses on 

the construction phase, there being little 

noise of consequence during project operations, 

and mainly considers impacts 

to cetaceans because of the likely occurrence 

of drilling operations at a time 

when blue whales may be expected in 

the vicinity. Other species of whales are 

less likely to be encountered in the area 

or are known to be less sensitive than 

blue whales to drilling noise levels and 

frequencies. 

The primary issue associated with the 

proposed drilling and construction is the 

additional noise over ambient noise levels 

and above that of regular commercial 

(shipping and fishing) traffic, and 

whether the noise extends into the blue 

whale feeding habitat along the Bonney 

Coast at levels sufficient to cause significant 

impacts. 


The principal sources of ambient ocean 

noise in the project area are from airocean 

interaction and other oceanic processes, 

naturally occurring and biogenic 

background noise and noise from shipping 

activities. 

Natural Physical Sources 

The dominant source of naturally occurring 

noise across the band frequencies 

from 1-100 Hz is associated with ocean 

surface waves generated by wind. Below 

5-10 Hz, the dominant ambient 

source is non-linear interaction of oppositely 

propagating ocean surface waves 

(called microseisms). Above 100 Hz, 

thermal noise caused by the pressure 

fluctuations associated with thermal agitation 

of the ocean is the dominant contributor. 

Across the remainder of the 

band, the main sources are bubbles oscillating 

individually or collectively in the 

water column (NRC, 2003). The impact 

of raindrops on the sea surface can increase 

the naturally occurring ambient 

noise levels by up to 35 dB across a 

broad range of frequencies extending 

from several hundred Hz to more than 

20,000 Hz. Thunder and lightening is an 

atmospheric source of noise, and spectra 

peaks between 50 to 250 Hz up to 

15 dB above ambient have been recorded 

5 to 10 km away (NRC, 2003). 

Seismic energy from geological and tectonic 

sources can travel over great distances, 

extending to frequencies higher 

than 100Hz with sharp onset and variable 

duration. However, in the project 

area, wind action on surface waves is 

expected to be the dominant background 

source. 

Information on the time-averaged ambient 

acoustic climate of the project area 

can be inferred from noise measurements 

undertaken during similar drilling activities 

in the nearby Thylacine gas field 

permit area (T/30P) in 2001 (Woodside, 

2003), and from recent noise measurements 

of appraisal drilling at the Casino 

gas field by Santos during 2003. 

Woodside’s Thylacine monitoring used 

two acoustic loggers, one positioned 5.1 

km southwest of the drilling location and 

the other in a shipping lane, approximately 

15 km to the south. The Thylacine 

drilling area is approximately 50 km south 

of the proposed Casino gas field, in 

100 m water depth. Baseline broadband 

underwater noise over the monitoring pe- 



riod was of the order of 93 to 97 decibels 

re one micro Pascal (dB re 1 µPa). This 

mostly reflects wind and wave noise, typical 

of rough sea conditions in exposed 

ocean. This is consistent with other published 

estimates. Richardson et al. (1990) 

determined average ambient noise levels 

of 98 dB in the range of 20 to 1,000 Hz 

in the Canadian Beaufort Sea. 

An acoustic monitoring program commissioned 

by Santos was conducted during 

exploratory drilling of the Casino 3 

well between 20 October and 11 November 

2003 (McCauley, 2004). Five 

bottom-mounted noise recorders with 1 

to 200 Hz bandwidth were set at doubling 

distance increments from the Casino 

3 exploratory drilling site, of which 

four were successfully recovered at distances 

of 1.88, 4.05, 7.97 and 28.03 km 

from the drill site. The furthest sensor 

(28.03 km) recorded no drilling noise and 

only ambient noise that ranged between 

90 and 110 dB re 1 µPa. Preliminary 

data analysis suggests that distant shipping 

noise contributed to the ambient 

noise at this location but the 120 dB re 1 

µPa level was exceeded only 0.04% of 

the time (McCauley, 2004). These results 

are consistent with ambient measurements 

at the Thylacine gas field and 

other published data for exposed ocean 

(Woodside, 2003). 

Commercial Shipping 

Commercial shipping traffic is a major 

contributor to noise, especially at low 

frequencies between 5 and 500 Hz (NRC, 

2003). Low frequency ship noise sources 

include propeller noise, cavitation, blade 

frequency, blade passage forces), engines 

and other machinery, and hydrodynamic 

hull flow. The noise of merchant 

shipping falls into two categories. First is 

the noise of distant traffic that is not 

really audible as a ship but contributes 

to elevated sea noise levels across a 

defined frequency range affecting large 

geographic areas. Second is from nearby 

traffic that is identifiable as such. Sound 

levels and frequency characteristics are 

roughly related to ship size and speed, 

but vessel signatures can be specific. 

Generally, the more distant the source, 

the more indiscernible are the characteristics. 

Richardson et al. (1995) reports 

data from commercial vessels from literature 

sources. Noise levels are highest 

(more than 180 dB (re 1 µPa-m) 2 /Hz) 

at the lowest frequencies (20 Hz) measured 

for the larger classes of vessels 

such as supertankers. 

The southernmost Southern Ocean main 

shipping channel passes through the 

Bonney upwelling area, to the south of 

the Casino project area. About five to six 

large ships per day were detected passing 

through this area during Woodside’s 

monitoring (Woodside, 2003). These 

were sufficiently close for the noise to be 

discernible as regular, short duration 

spikes up to 125 dB re 1 µPa, mostly in 

the 10 to 100 Hz band. Noise with higher 

frequency energy (more than 100 Hz) is 

thought to be from higher levels of cavitation 

from the propellers and tonals, and 

related to the propeller rates and characteristics. 

In the shipping lane, ships 

raised the average noise level above 

100 dB re 1 µPa (close to rough sea 

background) 13% of the deployment time, 

above 105 dB re 1 µPa 6% of the time, 

and above 120 dB re 1 µPa 0.23% of the 

time. At passage speeds in excess of 20 

knots, there may be little noise ahead of 

fast-moving large ships but a dramatic 

rise as it passes, giving rise to concerns 

about risks of collision with whales (Gill 

and Morrice, 2003). 

Woodside (2003) recorded an average 

of 5.4 ships per day on a logger deployed 

close to the shipping lane, 60 km 

due south of Port Fairy (about 40 km to 

the west of the Casino 3 well) between 

28 November 2001 and 5 March 2002. 

Here, shipping noise levels exceeded 

100, 110 and 120 dB re 1 µPa for about 

13%, 2% and 0.2% of the time, respectively. 

Data from the array of noise loggers deployed 

by Santos near to the Casino 3 

appraisal drilling location in October/November 

2003, showed that shipping noise 

was equal to that of noise of exploratory 

drilling at the recorder located 7.97 km 

from the Casino 3 well. The array of five 

loggers straddled the shipping lane. At 

the outer-most recorder located 28 km 

from the Casino 3 well, noise was principally 

related to distant shipping and was 

considered ‘ambient’. The passage of 

three ships was recorded by the logger 

array, where the signal was strongest 

and the vessel transit closest, at the logger 

deployed approximately 4 km from 

the Casino 3 well. The maximum noise 

level recorded during the passage of 

these ships was approximately 128 dB 

re 1 µPa (McCauley, 2004). 

Biological Sources 

Marine mammal vocalisations cover a 

wide range of frequencies. Odontocetes 

(dolphins and toothed whales) produce 

broadband clicks that can be characterized 

by species, covering a wide energy 

range from less than 10 Hz to higher 

than 200 kHz (NRC, 2003). Vocalisations 

of mysticetes (baleen whales) are significantly 

lower in frequency than those 

of odondocetes, and are broadly categorized 

as low-frequency moans. Peaks 

around 20 Hz, created by calls of large 

baleen whales are often present in deep 

ocean noise spectra. However, there are 

a wide variation of calls and songs, potentially 

used in long-distance communication 

and topological echolocation 

(NRC, 2003). 

Source levels for cetacean vocalisations 

have been reported as high as 228 dB re 

1 µPa at 1 m for echolocation of false 

killer whales (Thomas and Turl, 1990, 

cited in NRC, 2003) and bottle-nosed 

dolphins echolocating in the presence of 

noise (Au 1993, cited in NRC, 2003). 

The highest levels are calculated at 232 

dB re 1 µPa at 1 m for adult male sperm 

whales (Mohl et al., 2000, cited in NRC, 

2003). Such high source levels are required 

for acoustic imaging of the environment 

using return echoes from objects 

with low target strength. The short duration 

of the echolocating clicks (50 to 200 

µs) means that the energy content integrated 

over time is low, even though the 

source levels are high (Au 1993, cited in 

NRC, 2003). Baleen whale vocalisations 

have the potential to be detected over 

long distances because of their low frequencies. 

Blue whales and fin whales 

produce low frequency (10 to 25 Hz) 

moans with estimated source levels up 

to 190 dB re1 µPa at 1 m (NRC, 2003). 

Blue whales produce the lowest frequency 

sounds of any cetacean – as low 

as 9 Hz, but their most common call 

frequencies are in the energy range 15 

to 20 Hz in the North Atlantic and 10 to 

30 Hz off Western Australia (Gill and 

Morrice, 2003). Vocalisations below 

1 kHz and source levels above 180 dB 

re1 µPa at 1m have also been recorded 

for other large baleen whales such as 

bowhead, southern right and humpback 

whales (Richardson et al., 1995). 

Biological sources make contributions at 

certain seasons or times of day. Seasonal 

choruses of whales can add up to 

20 dB to ambient noise (NRC, 2003). 

Humpback whales can significantly increase 

background noise during their 

breeding season. Time-averaged peak 

levels recorded 2.5 km offshore (Hawaii) 

reached 125 dB re1 µPa (Au and Green, 

2000, cited in NRC, 2003). Other marine 



mammals such as seals can contribute 

locally to noise, but it is the baleen whales 

that can be detected over the longest 

distances. 

Many species of marine fish and invertebrates 

produce sound and use it for communication. 

Fish produce sounds by 

means such as striking bony structures 

against one another, or by muscle movement 

amplified by the gas-filled swim 

bladder (NRC, 2003). Most fish sounds 

are pulsed, with energy below 1 kHz. 

Many species participate in chorusing 

behaviour (when a large number of individuals 

call simultaneously), often at 

dawn or sunset, which can increase ambient 

noise at these times. 

A number of biological sources of noise 

were recorded in the Thylacine area including 

whale calling and fish choruses 

(Woodside, 2003). Blue whale vocalising 

was in the frequency range 15-28 Hz, 

with some harmonics up to 100 Hz. At 

the shipping lane monitoring site, Blue 

whales were heard at close range, first 

on 29 November 2001, then after 31 

December 2001. The Thylacine acoustic 

logger recorded blue whales less frequently 

and usually at long range. Most 

of the whales were travelling and did not 

linger at any particular place. 

Fish choruses were another regular 

source of biological noise. These were 

characterised by morning and evening 

peaks at levels of 74-85 dB re 1 µPa 2 /Hz 

(Woodside, 2003). The fish choruses 

were more evident at the shipping lane 

than at the Thylacine monitoring site. 

Preliminary analysis of data collected 

from the October–November 2003 deployment 

of loggers by Santos in the 

vicinity of the Casino 3 well during exploratory 

drilling, indicates acoustic 

events that are consistent with blue whale 

calls (McCauley, 2004). Further analysis 

is currently being undertaken to confirm 

this. However, the straight-line arrangement 

of the logger array, designed primarily 

to examine drilling noise 

attenuation, may preclude the determination 

of direction and distance of the 

whale calls. 

An additional logger array, arranged in a 

crucifix-shaped configuration, was deployed 

from November to December 

2003 specifically to detect the presence, 

direction and distance of blue whale 

vocalizations. These loggers were located 

approximately 100 km to the eastnortheast 

of the earlier deployment, in 

the vicinity of a different drilling exploration 

program (Hill 1), conducted by 

Santos. 

6.4.2 Construction Related Noise 

Drilling Rigs and Ships 

Noises associated with drilling activities 

are from the drilling vessels, support vessels 

and helicopter support movements, 

and post-drilling pipe laying. 

The noise emitted from drill vessels consists 

of a combination of drill pipe operation 

and onboard machinery, and typically 

produces low intensity but continuous 

sound. Semi-submersible drilling rigs are 

generally less noisy than drillships 

(Richardson et al., 1995), as they lack 

large hull areas, and the machinery is 

mounted on decks raised above the sea 

on risers supported by submerged flotation 

chambers. In contrast, the drillship 

hull contains the rig, the generators and 

other machinery and is well coupled to 

the water. 

Measurements from the Sedco 708 semisubmersible 

rig operating in water 114 m 

deep in the Bering Sea (API, 1986; 

Richardson et al., 1995) showed that 

some tonal components were detectable 

at 10 nautical miles (18.5 km), but sound 

at most frequencies became indistinguishable 

from background at 0.5 nm 

(approximately 0.9 km). 

In the Otway Basin, Woodside (2003) 

measured ocean noise levels at a distance 

of approximately 5.1 km from the 

Thylacine drill rig over a period of 32 

days. After an initial 7-day (pre-drilling) 

period, during which ambient noise and 

the passage of ships was evident, drill 

rig and rig tender noise was readily discernible. 

Drilling noise was dominated 

by sharp tones less than 100 Hz, with 

little high frequency noise, while the rig 

tender noise had higher levels of high 

frequency noise probably produced by 

cavitation from bow thrusters. 

Similarly, noise recorded at the Casino 3 

exploration drilling site was dominated 

by that of the drilling rig support vessel 

moving slowly around the site of holding 

position (McCauley, 2004). Drilling and 

support vessel noise was recorded primarily 

in the 10 to 60 Hz frequency range, 

and noise was greatest at a logger deployed 

approximately 2 km from the drilling 

site. Noise was detectable to 8 km 

distance but not at the receiver located 

28 km from the drilling site (McCauley, 

2004). At the 2 km recorder, noise levels 

were above 100, 105, 110, 115 and 

120 dB re 1 µPa for 80, 60, 36, 8 and 2% 

of the time respectively. These proportions 

dropped accordingly at the loggers 

located at increasing distance from the 

drilling rig and were not detected at 

28 km. The proportions of exceedence 

at 4 km (McCauley, 2004) were in very 

close agreement with a similar set of 

values recorded 5 km from exploration 

drilling at the nearby Thylacine site 

(Woodside, 2003). 

In the Timor Sea, McCauley (1998) 

measured underwater noise source emitted 

from a semi-submersible drilling rig 

and found that broadband noise was approximately 

146 dB re 1µPa when not 

actively drilling and 169dB re 1 µPa when 

drilling. A range of source level 

broadband values (59-185 dB re 1 µPa) 

are quoted for various drillships and jackup 

drilling rigs (WDCS, 2003) and Greene 

(1987) estimated noise source levels of 

154 dB re 1 µPa for drilling rigs for the 

frequency band 10 to 500 Hz. Noise 

measurements in the Timor Sea also 

recorded drilling noise up to 30 km from 

the rig, indicating greater sound attenuation 

in the shallow area of the Otway 

Basin, where drilling noise became 

undetectable at some distance between 

8 and 28 km from the drilling rig. 

Supply Vessels 

During drilling, Santos estimates a requirement 

for about one to two support 

vessel trips per week to the drill rigs/ 

ships, with one support vessel ‘on station’ 

close to the drill rig/ship for safety 

purposes. McCauley (1998) observed 

that the noisiest action of the Timor Sea 

drilling program was at a broadband level 

of approximately 182 dB re 1 µPa, caused 

by the support vessel using bow thrusters 

to maintain station at the drilling rig. 

The acoustic signal of the support vessel 

depends on its size, hull construction, 

speed, mode of operation and state 

of maintenance. The expected source 

level of noise from the rig supply vessels 

and tenders is in the broadband range 

167 to 185 dB re 1 µPa (Richardson et 

al., 1995; Woodside, 2003). There is 

great variation in noise levels between 

vessels and even for the same vessel, 

depending on the nature of the activity 

conducted. 

Woodside (2003) found that most of the 

noise at the acoustic monitoring site 

5.1 km from the Thylacine drilling rig was 

from the supply tenders. Rig tender noise 

was evident either at a low but persistent 

level for days or in short bursts of high 

level noise for several hours associated 

with manoeuvring and use of bow thrusters, 

and evident as broader tones around 


15 and 30 Hz, but occasionally above 

100 Hz. 

The maximum broadband noise level recorded 

during the time the drilling rig 

and tender were on site was 145 dB re 

1 µPa. Noise levels exceeded thresholds 

of 100 dB re 1 µPa and 120 dB re 1 

µPa for 70.55% and 0.69% of the time 

respectively for the duration of drilling 

operations (Woodside, 2003). 

Helicopters 

An estimated three to five helicopter trips 

per week will be required to ferry personnel 

and equipment during drilling operations. 

This will contribute to the noise 

associated with the drilling operation. 

The main acoustic source is the impulsive 

noise from the main rotor, which 

consists of blade-vortex interaction noise 

in descent or level flight at low and medium 

velocities and high-speed impulsive 

noise related to trans-sonic effects 

on the advancing blade. The rotating 

blades of helicopters produce tones with 

fundamental frequencies proportional to 

the rotation rate and number of blades. 

Dominant tones in noise spectra from 

helicopters and fixed wing aircraft are 

generally below 500 Hz (Richardson et 

al., 1995). Other tones associated with 

the main and tail rotors and other engine 

noise can result in a larger number of 

tones at various frequencies. 

Sound travelling from a source in the air 

(e.g., helicopter) to a receiver underwater 

is affected by both in-air and underwater 

propagation processes, which are 

further complicated by processes occurring 

at the air-seawater interface. The 

level received underwater depends in a 

complex way on source altitude and lateral 

distance, receiver depth, water 

depth, and other variables. The angle at 

which the line from the aircraft and receiver 

intersects the water surface is important. 

In calm conditions, at angles 

greater than 13° from the vertical much 

of the sound is reflected and does not 

penetrate into the water (Richardson et 

al., 1995; NRC, 2003). Therefore, strong 

underwater sounds are detectable for a 

period roughly corresponding to the time 

the helicopter is within a 26° cone above 

the receiver. The zone of ensonification 

can be enlarged in rough seas. It can 

also be enlarged in shallow waters, where 

the bottom is reflective and lateral propagation 

is increased (Richardson et al., 

1995), though shallowness is not defined 

to any specific depth. 

Most aircraft traffic supporting offshore 

installations involves turbine helicopters 

flying along straight lines. Underwater 

sounds from helicopters are transient 

events. Usually, a helicopter can be heard 

in air well before and after the brief period 

it passes overhead and is heard 

underwater. Sound pressure in the water 

directly below a helicopter is greatest 

at the surface and diminishes with increasing 

receiver depth. The peak-received 

level diminishes with increasing 

helicopter altitude, but the duration of 

audibility often increases with altitude. 

Richardson et al. (1995) reports that a 

Bell 214 helicopter (stated to be one of 

the noisiest) was audible in air for four 

minutes before it passed over underwater 

hydrophones but detectable underwater 

for only 38 seconds at 3 m depth, 

and for 11 seconds at 18 m depth. 

Helicopter and fixed wing aircraft traffic 

in the Port Campbell area associated 

with tourism adds to the background helicopter 

noise in the coastal and nearshore 

area and may result in habituation of 

marine animals to helicopter noise. 

Pipelaying 

There is sparse information in the literature 

about underwater noise from pipe 

laying. Most noise is expected from the 

pipelay vessel and other attendant vessels, 

for which characteristics would be 

expected within the range of vessels described 

above. 

6.4.3 Potential Impacts to Whales 

Thresholds of Audibility and 

Response 

The reaction of cetaceans to underwater 

noise varies between species and individuals 

within species and there are numerous 

confounding factors such as 

activity at the time, phases of life cycle, 

gender and reproductive cycles. 

The main issues with regard to impacts 

of drilling noise on whales, particularly 

baleen whales are the ranges of audibility 

of these noise sources, and the distance 

within which behavioural response 

is observed. Richardson et al. (1995) 

described the criteria for defining the radius 

or zone of influence of underwater 

noise: 

• The zone of audibility, within which 

the whales might detect the sound, 

generally where the received sound 

signal equals the level of background 

noise in the same band. 


• The zone of responsiveness, within 

which the whales react behaviourally 

or physiologically, e.g., by avoidance, 

duration of surfacing, and dives and 

numbers of blows. Response may 

depend on sound level, or on a signal 

to noise ratio, and will vary with 

different species and individuals of 

species. 

• The zone of masking, where noise 

might be strong enough to interfere 

with detection of other sounds. Theoretically, 

this could extend to the distance 

of audibility but varies in part 

with distances, directions, relative 

strengths of masking noise and to a 

large extent with the animals’ ability 

for directional detection, and ability 

to adapt call intensity and frequency 

in response to the masking noise. 

• The zone of hearing loss, discomfort 

and injury. Typically considered as 

temporary, or permanent threshold 

shifts, depending mainly on the duration 

and intensity of exposure, most 

quantitative understanding comes 

from humans with application to marine 

mammals inferred only from observed 

behavioural responses. 

Zones of audibility and responsiveness 

are more amenable to observation and 

measurement, e.g., from experiments 

involving playback of recorded noises 

typical of drilling and associated noises 

(Richardson et al., 1985; 1990; 1995), 

than are zones of masking and hearing 

impairment, and consequently, more is 

known of the former. Information on the 

various sources of background and 

project-related noise are summarised 

below in relation to likely ranges of audibility 

and responses. It excludes noise 

from seismic activity, which is not proposed 

as part of this project. 

A continuous industrial sound level of 

120 dB re 1 µPa has been put forward as 

the level at which avoidance or significant 

behavioural changes are triggered 

in marine mammals (Richardson et al., 

1995). 

Drilling Noise 

Richardson et al. (1995) estimated radii 

of noise detection from drillships in 

nearshore and offshore waters of California 

to be 25 km and 100 km respectively, 

there being greater attenuation in 

shallower water (inshore of the shelf 

break). Several studies of the responses 

of the migrating grey whales exposed to 

underwater playbacks of various drilling 



noise were reduced swimming speeds 

and diversions away from the sound 

source (Richardson et al., 1995), with 

50% avoiding drillships when sounds 

exceeded 117 dB re 1 µPa. Sounds were 

estimated to diminish below these levels 

3 km distant from the drilling in nearshore 

waters, where grey whales occurred, and 

6 km away at the shelf break. The distances 

at which responses occur would 

be expected to vary between the noisier 

drillships and the quieter platforms and 

semi-submersibles. 

Richardson et al. (1990) determined the 

potential range of audibility of drillship 

activities to be between 21 and 29 km in 

the Beaufort Sea (Arctic Ocean). Received 

broadband levels were expected 

to equal the average ambient noise level 

(98dB re 1 µPa) 18 km from the drillship. 

McCauley (1998) found that under quiet 

conditions (with rig tenders shut down) 

drilling rig noise was not audible beyond 

11 km in the Timor Sea. 

Bowhead whales have been observed to 

approach within a few kilometres or less 

(0.2 to 5 km) of operating drillships, within 

ensonified zones, and to remain for several 

hours (Richardson et al., 1985). At 

other times (for example during some 

autumn migrations) most whales remained 

at least 10 km from drilling operations. 

Some bowhead whales around 

drillships demonstrated avoidance when 

exposed to underwater playback of drilling 

noise, even at levels equivalent to 

those already tolerated. These different 

reactions suggest prior habituation, individual 

variation in tolerance and responsiveness, 

or possibly the confusing 

element of the sudden introduction of 

sound playback without the evident mechanical 

source. Most did not react to 

drillship noise unless levels were 20 to 

30 dB above ambient, suggesting that 

the signal to noise ratio, rather than the 

absolute received level may be the criterion 

of response. Richardson et al. (1995) 

calculated that bowhead whales would 

be exposed to these noise levels if they 

were within 4 to 10 km of the drillship. 

Correlating noise and radii of responsiveness 

by whales is an imprecise science 

and application to drilling in the 

Otway Basin requires observational validation. 

The proposed Casino development 

drilling area is located 

approximately 24 km or more inshore of 

the 100 m isobath where the majority of 

blue whale sightings have been made 

(Gill and Morrice, 2003). At this location, 

some blue whales would be expected to 

be within the zone of detection, but not 

necessarily the zone of responsiveness, 

even allowing for greater sensitivity than 

for bowhead whales. Gill and Morrice 

(2003) observed that blue whales can 

tolerate airgun sounds at a range of 

20 km, hence risks of eliciting adverse 

responses from drilling activities are expected 

to be low and manageable due to 

the nature of the activity and through the 

use of the proposed mitigation measures 

(see Section 6.4.4). 

Blue whale calls in the Otway Basin were 

measured by Woodside Energy to be in 

the frequency range 18 to 26 Hz with 

overtones of up to 100 Hz (Woodside, 

2003). The frequencies of blue whale 

calls closely overlap those produced by 

drilling and Gill and Morrice (2003) consider 

it possible that blue whales might 

be sensitive to masking of communication 

by sounds in the range produced by 

drilling. Effects can be reduced by adaptations 

such as changes in call intensity 

and frequencies in response to background 

noise, directional hearing capabilities 

and variations in received levels 

(and distances) of noise. Many species 

of toothed and baleen whales frequently 

emit extended low frequency sound of 

greater or equal intensity of that produced 

by man made activities and therefore 

signal to noise ratio may be the key 

criterion, as suggested by Richardson et 

al. (1990). Where behavioural responses 

might be observed during proposed monitoring, 

some may in part, be adaptive to 

masking but, this would remain speculative. 

Using the 120 dB re 1 µPa value as a 

sound level at which significant behavioural 

responses of marine mammals 

may be expected, significant effects of 

the Casino 3 drilling were confined to 

within a 3-km radius of the drilling source. 

Based on highest levels and distances 

recorded during drilling at Casino 3 

(McCauley, 2004), preliminary analyses 

shows that this disturbance will occur for 

1.4% of the time that a rig is on station. 

Noise levels during construction are not 

expected to exceed those of the exploratory 

drilling, with the possible exception 

of additional noise due to pipelaying. The 

construction drilling period for the Casino 

Gas Field Development is estimated 

to be approximately 70 days, resulting in 

a total of 0.98 days of threshold 

exceedence within 3 km, for approximately 

five minutes per exceedence 

event (McCauley, 2004). 

Support Vessel Noise 

Support vessel noise is likely to be a 

significant component of noise from the 

drilling operations. Depending on activity, 

vessels may be audible only as far as 

500 m from the rig, or up to 30 km away 

(Woodside, 2003). McCauley (1998) 

(cited in Woodside, 2003), reported that 

periodic cavitation noise from support 

vessels holding station at a drilling rig in 

the Timor Sea was evident 30 km distant. 

Otherwise, reactions to support vessel 

activities may be gauged from 

responses to vessels generally. Casino 

3 acoustic monitoring indicated that drilling 

operation was not audible at 30 km 

distant from the rig. 

The generalised response of migrating 

humpback whales to seismic vessels was 

to take some avoidance reaction at more 

than 4 km and to allow the vessel to 

pass no closer than 3 km. Pods with cow 

and calf pairs involved in resting behaviour 

can provide the most sensitive indications 

of response to an approaching 

vessel (McCauley et al., 2003). However, 

observations of responses to seismic 

vessels may be confounded by 

vessel and/or seismic noise source. Much 

of the information is also anecdotal. Some 

species react strongly, some react weakly 

or inconsistently, and some do not react 

at all (Richardson et al., 1995). Most 

reactions are assumed to be attributed 

to the noise created by moving ships 

and boats, but the direction of movements 

of the vessels also affects responses. 

Single baleen whales that were resting 

quietly seemed more likely to be disturbed 

than were groups of whales engaged 

in active feeding, social 

interactions, or mating (Richardson et 

al., 1995). Since the predominant activity 

of blue whales along and inshore of 

the 100 m isobath is feeding on krill in 

the upwelling waters, the amount of disturbance 

from passing rig supply vessels 

and those on station may be 

reduced. 

The continued presence of various whale 

species in areas such as the offshore 

Otway Basin, trafficked by commercial 

shipping indicates some degree of tolerance/habituation 

to ship noise. Santos 

supply vessel traffic would be an intermittent 

and temporary addition. Blue 

whales would be expected to swim away 

from vessels that approach them rapidly 

and directly, or move erratically. Avoidance 

in baleen whales usually begins 



when a boat is 1 to 4 km away depending 

on boat speed and direction. Fleeing 

from vessels generally stops within minutes 

after the vessel has passed, but 

some scattering may persist for a longer 

period (Richardson et al., 1985). In general, 

whales are more tolerant of vessels 

that move slowly or in directions other 

than towards them. 

Some inference on the tolerance of blue 

whales to vessel noise can be drawn 

from recent observations of blue whales 

near seismic operations. In October and 

November 2003, Santos conducted a 2D 

seismic survey in inshore waters of VIC/ 

P51 (about 60 km north west of the Casino 

gas field), in an area known to be 

critical feeding habitat for blue whales. 

The period was chosen so that work 

would be completed prior to the start of 

what was thought to be the blue whale 

feeding season, (around the 1 st of December, 

2003). However, from 13th November 

2003, blue whales were seen 

from aerial survey, often in association 

with krill swarms as close as 11 km from 

the actively surveying vessel. A number 

were observed around 20 km away moving 

slowly, in various directions including 

towards the seismic source. 

The unexpected presence of blue whales 

during these November surveys challenges 

the ‘official start’ of the blue whale 

feeding season as 1 December. However, 

this situation presented a unique, 

adaptive opportunity to observe the behaviour 

of blue whales exposed to airgun 

sounds during a seismic survey. Whales 

actively feeding or purposefully moving 

appeared to show less avoidance and 

greater tolerance than those resting or 

moving slowly. Santos’ observations during 

November 2003 indicated that the 

range of total avoidance for these species 

(to seismic survey noise) was considerably 

less than the 60 km previously 

considered, and potentially less than 

20 km. During a 2D seismic survey conducted 

by Santos west of Kangaroo Island 

(in permit area EPP32) a shut-down 

procedure was initiated when a blue 

whale moved within the 3-km zone of the 

operating seismic vessel. Other species 

including fin, sei and pilot whales and 

dolphins were also observed in the area 

during the November 2003 survey. 

The observations suggest that the summer 

feeding migration is more robust to 

offshore exploration and production activities 

than first thought and that management 

of whale interactions is 

therefore better achieved through an improved 

understanding of radii of response. 

As mentioned earlier, support vessel 

noise contributed significantly to the total 

noise generated during the Casino 3 

drilling program while holding tender at 

the drilling rig and this will likely be the 

case during the drilling and construction 

of the Casino Gas Field Development. 

Recent acoustic monitoring undertaken 

during the drilling of the Casino 3 appraisal 

well indicated that the majority of 

noise above the threshold that is likely to 

result in avoidance by cetaceans is confined 

within a 3 km radius. No behavioural 

observations of blue whales or 

other baleen whale species were made 

during the drilling program and therefore 

no correlation between noise levels and 

avoidance behaviour can be made at 

this stage. 

Aircraft Noise 

Information on reactions of whales to 

aircraft are mostly anecdotal. Reactions 

of baleen whales to circling aircraft (fixed 

wing or helicopter) are sometimes conspicuous 

if the aircraft is below an altitude 

of 300 m (1,000 ft), uncommon at 

460 m (1,500 ft) and generally 

undetectable at 600 m (2,000 ft) 

(Richardson et al., 1995; NMFS, 2001). 

No specific information on the reaction 

of blue whales to helicopter noise is available. 

Baleen whales sometimes dive or 

turn away during overflights, but sensitivity 

seems to vary depending on the 

activity of the animals. The effects on 

whales are transient, and occasional 

overflights are unlikely to have any longterm 

consequences on cetaceans 

(NMFS, 2001). The relative roles of sound 

and vision in eliciting responses to aircraft 

are potentially confounding. 

Richardson et al. (1985) reported conspicuous 

reactions of bowhead whales 

to fixed wing aircraft that approached or 

circled at, or below, 305 m above average 

sea levels but infrequent reactions 

at heights above 450 m. Most reactions 

were hasty dives and tail slaps. Bowhead 

whales engaged in mating or feeding 

were less sensitive to aircraft. 

Noise from helicopters would generally 

be higher than the fixed wing aircraft, but 

audible for only a brief period (tens of 

seconds) (Richardson et al., 1985). At 

flight heights below 150 m, whales may 

react by diving in response to helicopter 

noise, but resume normal feeding activity 

within minutes. Leatherwood et al. 

(1982) observed that minke whales responded 

to helicopters at an altitude of 

230 m by changing course or slowly diving. 

Observations by Richardson and 

Malme (1993) indicate that, for bowhead 

whales, most individuals are unlikely to 

react significantly to occasional single 

helicopter passes by low-flying helicopters 

ferrying personnel and equipment to 

offshore operations at altitudes above 

150 m (500 feet). 

In addition, helicopters following a direct 

course (straight-flight path) also minimize 

audible noise to only a few tens of seconds 

directly over whales, which have 

been observed to resume their pre-disturbance 

activity within a few minutes 

(Richardson and Malme, 1993). 

The frequent helicopter traffic in the Port 

Campbell area associated with tourism 

is likely to provide some conditioning and 

habituation by seabirds and mammals to 

the visual and noise-related aspects of 

helicopters. 

Indirect Effects 

Indirect effects on whales could be 

caused by the disturbance or dissipation 

of krill aggregations, which provide the 

main food supply for blue whales. There 

is little information on the effects of noise 

on krill. Crustacea possess statocyst organs 

which are capable of responding to 

the particle motion component of sound 

waves but it is not certain if this applies 

to krill. It is generally considered however, 

that crustacea (including their planktonic 

larvae) are not adversely affected 

by noise. Experimentally observed effects 

on varieties of crustaceans (and 

fish) of various ages and sizes have been 

continued within 1 to 5 m (Pearson et al. 

1994). For example, survival and development 

of dungeness crab larvae was 

not significantly affected by exposure to 

seismic energy release as close as 1 m 

from a 13.8 litre array of seven air-guns, 

nor from mean squared sound pressure 

of 231 dB re 1 µPA, (considered the 

maximum likely to be experienced by 

planktonic crab larvae during a seismic 

survey). The aerial observations made 

by Santos in November 2003 of abundant 

krill surface swarms within 5 km of 

the 2 dimensional (2D) seismic survey in 

VIC/P51 does not suggest large scale 

noise-related impacts to krill. Habituation 

to commercial vessel noise in the 

region may also reduce the likelihood of 

adverse responses of krill to drilling and 

support vessels. 



Physiological Effects 

A single incidence of disturbance-induced 

interruption to feeding, or triggered rapid 

swimming, is expected to have little impact 

on the energetic status of a marine 

mammal, however, repeated periods of 

this type of disturbance-induced behaviour 

probably have negative effects on 

the health of the exposed individuals 

(Richardson et al., 1995). Little is known 

about the physiological effects of repeated 

stress induced swimming and diving. 

Variables such as abundance and 

distribution of food in an area have an 

effect on the consequences of energy 

usage in response to disturbance. The 

reproductive status of an animal is another 

important variable. Lactating or 

pregnant females would be most severely 

affected by extra energy demands 

(Richardson et al., 1995). 

Many mammals exhibit a common physiological 

response to stress in the form of 

activation of the pituitary-adrenal axis 

(Richardson et al. 1995) and release of 

adrenal corticoid hormones, which are 

often found in stressed mammals. Thomas 

et al. (1990) (cited in Richardson et 

al., 1995) investigated the physiological 

effects of captive beluga (toothed) whales 

in response to playbacks of semi-submersible 

drill-rig noise. No increase in 

catecholamine levels in the blood after 

the playback of drill-rig noise was observed. 

The applicability of this finding to 

baleen whales is not known and probably 

extremely difficult to research effectively, 

either in terms of blood hormone 

measurements or interpretation of significance. 

Hence the need to avoid actions 

causing rapid and repeated 

swimming or diving. 

Summary of Acoustic Impacts to 

Whales 

While there is wide variation in underwater 

noise propagation and the responses 

of whale species and individuals in different 

situations, general thresholds of 

tolerance of drilling activities are expected 

to be as follows. 

• A behavioural response radius of approximately 

3 km is expected based 

on reported observations of other species 

and underwater noise recordings 

of drilling in the Otway Basin. 

• Within this distance, the threshold 

level of 120 dB re 1 µPa may be 

exceeded about 1.4% of the time that 

the drilling rig is operating on site. 

• Beyond 3 km distance, noise levels 

would be below ambient for the majority 

of the time. 

• Whales may show behavioural response 

within or outside 3 km to sudden 

changes in activities such as 

bow-thruster noise levels, or sudden 

changes in vessel/ helicopter direction. 

• Individual whales may avoid or show 

tolerance or habituation to activities 

within 3 km distance from the rig. 

• Habituation to the stationary rig is 

expected for resident fauna. 

• Some individual whales are likely to 

be more tolerant, and others more 

sensitive to drilling activities. 

• Responses may also depend on behaviour 

at the time of interaction; resting 

animals being generally more 

sensitive than those engaged in feeding, 

mating or migration. 


Measures 

Offshore Mitigation 

From the above assessment, closure 

periods (or ‘black-out’ periods) for drilling 

activities are considered unnecessary 

and are not proposed. Santos 

proposes management and mitigation 

measures along two lines. 

Firstly, procedures will be put in place to 

minimise or avoid the types of vessel 

and aircraft movements (speed, sudden 

change in direction of travel or height) 

that are known to elicit disturbance reactions 

in accordance with EPBC Regulations. 

Secondly, aerial observations to 

monitor blue whale activity in the area 

during the period leading up to and during 

the drilling program will be undertaken, 

preferably in conjunction with the 

Deakin University Blue Whale Study. 

Recording of observations will include 

factors such as date, time, numbers, distance, 

behaviour (resting/feeding etc.), 

directions of movement, presence of krill 

swarms which may subsequently be related 

to acoustic levels measured underwater. 

Vessel Noise Mitigation 

Vessel operations will be undertaken in 

accordance with the relevant sections of 

Part 8, Division 8.1 of the EPBC Regulations 

(Interacting with Cetaceans). The 

direction of movement of any whales (particularly 

blue, southern right and humpback) 

observed from the supply vessel 

will be noted and a vessel speed reduction 

and/or detour will be taken around 

the area of the whales to remove as far 

as is possible, the potential for disruption 

of whale behaviour or collision. 

This will minimise the general disturbance 

of blue whales in their known feeding 

habitat. The low vessel movement frequency 

(one to two trips per week) in 

relation to normal commercial shipping, 

and the transient nature of passing rig 

supply vessels mitigates against any prolonged 

disturbance to blue whales from 

supply vessel activities. 

Aircraft Noise Mitigation 

Santos proposes to control and mitigate 

potentially adverse impacts from helicopter 

noise by flying its helicopters at a 

minimum altitude of 1,000 m (in accordance 

with Regulation 8.08 of the EPBC 

Regulations), except for takeoffs, landings 

and adverse weather conditions 

(e.g., cloudy weather with low ceilings). 

Hence, turbo-shaft noise will be negligible. 

Sound levels will also be minimised, 

where possible, by pilots maintaining a 

straight flight path and avoiding sharp 

deviations, which increases rotor bladevortex 

interaction noise. 

Based on the above information, Santos 

does not expect its low frequency helicopter 

traffic flying at high altitude 

(1,000 m) to affect blue whale behaviour 

to any significant extent within their feeding 

habitat near the Victorian coastline. 

The proposed mitigation measures will 

decrease the probability of noise exposure 

and act significantly to reduce the 

interaction of helicopter traffic and blue 

whales. 

Pipelaying Mitigation 

During pipelaying, responsibility for whale 

observation will be allocated to appropriate 

personnel on the pipe lay vessel during 

all shifts to maintain watch for whales 

in the vicinity of vessel activities. Vessel 

movement is expected to be very slow, 

hence risks of adverse impact are low. 

Sighting observations will be recorded 

on appropriate sighting forms. Responses 

in the event of approach within 

a proposed caution zone (1.5 km) or risk 

zone (300 m) include reduction of speed, 

minimisation of use of sonar, and instructions 

to helicopter pilots/ancillary 

vessels not to approach whales and 

maintain separation. 


6.5 Marine Commercial 

Fisheries 

This section describes the commercial 

fisheries within the offshore permit area, 

the proposed mitigation and management 

measures and the residual impacts. 

The socio-economic implications of the 

residual impacts on fisheries are addressed 

in Section 6.12. 


The region supports a number of commercial 

fisheries. Major commercial fisheries 

occurring within or in proximity to 

the Casino Gas Field Development include: 

• Gillnet, Hook and Trap Fishery. 

• South East Trawl Fishery. 

• Southern Rock Lobster Fishery. 

• Southern Squid Jig Fishery. 

• Abalone Fishery. 

These fisheries are discussed in detail 

below. 

The fisheries industry bodies relevant to 

the project area include: 

• Seafood Industry Victoria (SIV). This 

is the peak industry body and has 

individual fishery representatives and 

regional representatives. 

• Fisheries Co-Management Council – 

Commercial Rock Lobster and Giant 

Crab Fishery Council (CRLGCFC). 

• Victorian Abalone Divers Association 

(VADA). 

• Australian Fisheries Management 

Authority (AFMA). 

• Port Campbell Professional Fishermen’s 

Association. 

• Warrnambool Professional Fishermen’s 

Association. 

• Port Fairy Professional Fishermen’s 

Association. 

• Portland Professional Fishermen’s 

Association. 

• Apollo Bay Professional Fishermen’s 

Association. 

Gillnet, Hook and Trap Fishery 

The Gillnet, Hook and Trap Fishery was 

previously two separate fisheries; the 

Southern Shark Fishery and the South 

East Fishery (SEF) Non-trawl Fishery. 

These fisheries were merged at the start 

of 2003 (AFMA, 2003a). 

Location. The Gillnet, Hook and Trap 

Fishery (GHTF) extends from the southern 

most part of the Queensland coast 

around to the South Australia–Western 

Australia border, and encompassing Tasmania, 

but excluding Victorian state waters. 

In Victorian waters, the fishery is 

broken down into the scalefish hook, 

shark hook and gillnet sectors (AFMA, 

2003a). The GHTF extends from the 

3-nm mark out past the continental shelf 

to great depths. Discussions with shark 

fishers has indicated that there are at 

least three fishers based at Warrnambool 

and Port Fairy, who periodically set nets 

in the vicinity of the proposed Casino 

wells and offshore section of the pipeline. 

Otherwise, netting and long lining 

activities are not affected by the location 

of the development. 

Target Species. About 21 species are 

subject to quota arrangements in this 

fishery (AFMA, 2003a). It predominantly 

targets gummy sharks, saw sharks and 

school sharks, with gummy sharks accounting 

for more than 60% of the total 

catch from the fishery in the area. The 

remaining target species include blue eye 

trevalla, blue warehou, blue grenadier, 

flathead, John dory, ocean perch, silver 

trevally and redfish, many of which are 

caught in the waters at the edge of the 

continental shelf (AFMA, 2003a). 

Fishing Method. Sharks are fished using 

predominantly demersal gillnets 

(Walker et al., 2001; AFMA, 2003a), with 

a small percentage caught by demersal 

longlines. Gillnets are set on the seabed 

with a surface marker buoy. Vessels usually 

sit at anchor overnight before retrieving 

the nets. Consultation with 

professional fishermen’s associations indicates 

that gummy shark catches are 

highest in January, but relatively constant 

throughout the rest of the year. 

School shark catches are highest between 

November to February (Walker et 

al., 2002). However, discussions with 

shark fishers suggest that the seasonality 

and locations of shark movements are 

not always predictable from year to year. 

Fishing for scalefish uses one of four 

demersal hook methods; longline, 

dropline, trotline and handline, with no 

limits on the number of hooks which can 

be attached to each of these lines for 

operators fishing outside 3 nm (except 

for longlines) (AFMA, 2003a). 

Licences and Management. In 2001, 

the number of vessels with Commonwealth 

shark permits was 53 net permits 

and 15 hook permits. At the same time, 

there were 115 gill net and 25 long line 

Victorian licences. The Southern Shark 


Fishery component of this new Gillnet, 

Hook and Trap Fishery is the oldest 

registered commercial shark fishery 

in the world. It is worth about $14 

million a year to Victoria (AFFA, 

2003a; SIV, 2003). 

Consultation with the various professional 

fishermen’s associations in the 

region indicates that one shark fisher 

operates out of Apollo Bay, while 

three operate from the ports of 

Warrnambool and Port Fairy. Shark 

vessels from other ports may also 

fish occasionally in the project area. 

Fishing in the project area is seasonal, 

depending on migrations of 

sharks, although these movements 

are not predictable. 

South East Trawl Fishery (SEF) 

Location. The South East Trawl Fishery 

(SEF) extends from Cape Jervis 

in South Australia to the mid-NSW 

coast, encompassing Victoria and 

Tasmania (Bureau of Resource Sciences, 

1994). 

The Casino gas field is in the western 

management zone of the southwestern 

sector (extends from Cape Jervis 

in South Australia to Wilsons Promontory). 

Mean annual trawl effort from 

1995 to 1999 indicates most trawling 

occurs on shelf break and slope 

grounds (between 200 and 1,000 m 

water depth), well south of the Casino 

Gas Field Development project 

area (Larcombe et al., 2001). High 

trawling activity occurs southwest of 

Portland. The SEF is an extremely 

complex fishery with many sub-fisheries. 

The SEF targets a large range of 

species from depths of 10 m to over 

1,200 m but catch results indicate 

that it is predominantly comprised of 

species found in water depths greater 

than 200 m. Local fishers have advised 

that the area around the Casino 

gas field is too rough and the 

seafloor too uneven for trawling or 

Danish seining. 

Target Species. The SEF fishes 

more than 100 species, but 21 species 

provide the bulk (more than 80%) 

of trawl landings and are subject to 

quota management (SIV, 2003). Such 

species include the orange roughy, 

gemfish, flathead, blue grenadier, 

redfish, school whiting, warehou and 

jackass morwong (Bureau of Resource 

Sciences, 1994; AFFA, 2003b, 



SIV, 2003). Key targeted species south 

of the project area include blue grenadier, 

king dory, orange roughy, spotted 

warehou, ling and spikey oreo (all deepwater 

trawl species). There is little information 

on the seasonality of the SEF, 

however it can be fished year-round, dependent 

on availability, market price and 

progress with quotas. Blue grenadier contributes 

the highest volume of fish, while 

orange roughy is the highest valued trawl 

fish (SIV, 2003). 

Fishing Methods. The trawl sector includes 

otter-board trawl and Danish seine 

(SIV, 2003; Larcombe et al., 2001; Bureau 

of Rural Sciences, 1998). Otterboard 

trawlers are large, generally 

greater than 20 m long, while Danish 

seiners are smaller boats and operate in 

inshore shelf areas. Typical demersal 

trawl gear comprises the trawl net itself, 

with a head rope length of 40 to 55 m 

and sweeps of 180 to 280 m in length, 

leading to the otter boards. The net, head 

rope and footrope are strongly constructed 

and kept open by the otter 

boards while being towed over the seabed. 

The Danish seine is set in a large 

arc and sweeps an area as it is retrieved. 

It is much lighter than otter-board trawl 

gear, having no otter-boards. Fish are 

herded into the net by the spread of the 

ropes. It is not towed over a long distance 

and can be used in more restricted 

areas unsuitable for otter-board trawlers. 

Little if any Danish seining or otterboard 

trawling occurs in the project area. 

Trawling off Port Campbell is generally 

in water depths deeper than 350 m 

(Woodside, 2003). The Western Management 

Zone is not the most heavily 

fished region of the SEF. 

Licences and Management. The SEF 

is Australia’s most important trawl fishery 

for scalefish. In 1999, between 5 and 

14 vessels operated in the broader region 

(Grieve and Richardson, 2001). The 

Otway Basin makes up only a small proportion 

of the total kilometres trawled in 

the SEF. Trawling intensity in and around 

the project area is low and a very large 

decrease in trawling in the Otway Basin 

occurred between 1989 to 1998. 

Southern Rock Lobster Fishery 

Location. The Southern Rock Lobster 

Fishery operates in coastal waters and 

out to the shelf break (approximately 80- 

100 km from shore). Southern rock lobsters 

are abundant from the shoreline to 

depths of 200 m (DPI, 2003), but are 

generally fished from rocky reefs in shallower 

waters up to 150 m deep (and 

more normally less than 20 m deep). 

The project area is within the ‘Western 

Zone’ (Apollo Bay to the South Australian 

border) of the fishery. 

Discussions with rock lobster fishers have 

confirmed that the pipeline route alignment 

avoids all their known inshore reef 

areas where they set their pots and that 

the offshore sections of the pipeline 

traverses ground that is not productive 

for pot-fishing. The rock lobster fishers 

(inter alia) assisted in the HDD and marine 

pipeline route alignment selection, 

particularly the siting of the shore crossing 

and subsea pipeline in sandy seafloor 

areas thereby avoiding the reef 

areas. 

Target Species. Southern rock lobster 

(Jasus edwardsii) is the only target species 

of this fishery. 

Fishing Method. Lobsters are trapped 

in commercial pots (shaped like beehives), 

normally set on reef habitat. Pot 

numbers and dimensions are restricted 

(pot and escape gap size) to ensure sustainable 

harvests. Pots are generally set 

and retrieved each day, with a surface 

buoy marking its location. Recreational 

fishers use SCUBA and hook netting to 

fish for lobster. Lobster fishers operate 

out of Apollo Bay, Port Campbell, 

Warrnambool, Port Fairy and Portland, 

with the latter being the main port for the 

western zone (SIV, 2003). 

Licences and Management. The Southern 

Rock Lobster Fishery is Victoria’s 

second most valuable fishery, worth 

$21.3 million in 2000/01 (DPI, 2003; DSE, 

2003a). Catches are managed on an 

annual quota per zone, divided into individual 

transferable quota units per licence. 

There were 85 rock lobster fishery 

access licences in the Western Zone in 

2002 (DPI, 2003), with 5,388 licensed 

pots over 2000/01 (Hobday and Smith, 

2001). The fishing season is closed during 

the following months (DPI, 2003; 

DSE, 2003a): 

• Females (during spawning): 1 June 

to 15 November. 

• Males (during moulting): 1 September 

to 15 November. 

Southern Squid Jig Fishery 

Location. The Southern Squid Jig Fishery 

operates in waters ranging from 50 m 

to 200 m depth and generally does not 

occur in the vicinity of the Casino Gas 

Field Development. The main squid jigging 

areas in Victoria are around the 

Port Phillip Bay heads, and in Commonwealth 

waters over the continental shelf 

and slope between Portland and 

Warrnambool (SIV, 2003; Bureau of Rural 

Sciences, 1998). 

Target Species. Arrow squid 

(Nototodarus gouldi) comprise the bulk 

of the catch in this fishery. 

Fishing Method. Squid jigging at night 

time is the most common method of fishing 

for squid, with boats using bright 

lamps strung above the deck that attract 

small fish. The squid tend to group in the 

boat’s shadow and then dart into the 

light to feed on the fish. Automatic jigging 

machines wind a line with jigs 

(barbless hooks) attached up and down 

over an oval spool creating a jigging motion. 

Squid are held on the hook by the 

pressure of the line and when this is 

released, squid are flicked onto a wire 

mesh tray landing on the boat deck (SIV, 

2003). Parachute sea anchors (parachutes 

deployed on a short line on the 

windward side of a boat that remain just 

below the sea surface) are sometimes 

set from the boat to reduce the pitch and 

roll of the vessel to produce a more stable 

working platform, while reducing drift, 

allowing the vessel to stay fishing over a 

congregation for a longer period. 

No gear is in contact with the seabed 

during squid fishing and therefore no interference 

will occur due to the Casino 


Licences and Management. The fishing 

season for arrow squid starts in February 

and ends in June, with most activity 

in the project area occurring towards the 

latter part of the season, following the 

squid migration route east to west (SIV, 

2003). Most fishing in western Victoria 

occurs in April and May (Bureau of Rural 

Sciences, 1998). The Southern Squid 

Fisheries Management Advisory Committee 

(SquidMAC) was established in 

1998. As at August 2002, there were 84 

Commonwealth squid jig entitlements, 

though the number of entitlements for 

the project area is not known. The catch 

for the 2000/01 season was valued at 

$2.8 million (AFMA, 2003b). 

Abalone Fishery 

Location. Abalone are present along the 

entire Victorian coastline, occurring on 

rocky reefs from low tide down to a depth 

of 20 m (McShane et al., 1986; Garnham, 

pers. com., 2003), but are mainly fished 

from depths shallower than 15 m (Gorfine 

and Walker, 1997). This generally correlates 

to within about 2 km (1.1 nm) of the 

shore. The Casino Gas Field Development 

area occurs within the ‘Central 

Zone’ Abalone licence area (that is, from 



the Hopkins River mouth to Lakes Entrance) 

of the fishery (DNRE, 2002b). 

Target Species. The target species in 

this fishery are the blacklip abalone 

(Haliotus rubra) which accounts for 99% 

of the catch, and greenlip abalone 

(Haliotus laevigata) (DNRE, 2002b). 

Fishing Methods. SCUBA and hookah 

(on-board compressor and air-line) diving 

are the only methods of fishing for 

abalone (SIV, 2003), sub-tidally to 20 m 

depth. 

Licences and Management. Fishing for 

blacklip abalone is managed by quota 

year-round, while fishing for greenlip is 

presently banned due to depletion of 

stock. The fishery is closed to commercial 

and recreational operators at night 

time (DNRE, 2002b). There are currently 

71 Abalone Fishery Access Licences 

(AFAL) in total, 34 for the Central Zone. 

It is the most valuable Victorian fishery, 

worth about $70 million a year (DNRE, 

2002b). Not all abalone fishers are represented 

by the Victorian Abalone Divers 

Association (VADA). Discussions with 

VADA indicate that one or two divers 

periodically operate from Port Campbell. 

However, the proposed seabed exit point 

from the HDD shore crossing reaches 

beyond any shoreline reefs and the pipeline 

route is located in a sandy corridor 

and therefore will not affect reef areas 

that are prospective for abalone. Therefore, 

minimal, if any, interference with 

the abalone diving operations is anticipated 

during construction or operation. 

Summary 

Table 6.3 summarises the locations of 

the various commercial fisheries in relation 

to the Casino gas field and offshore 

pipeline. 


The potential impacts of offshore pipeline 

construction to commercial (and to a 

lesser extent, recreational) fisheries in 

and around the Casino Gas Field Development 

project area are: 

• Temporary exclusion from fishing 

grounds during drilling and pipe laying. 

• Safety risk to fishing vessels during 

pipe laying. 

• Localised disturbance to habitat for 

target commercial species. 

The potential impacts of pipeline operation 

to commercial (and to a lesser extent, 

recreational) fisheries in and around 


project area are: 

• Interference with demersal trawl gear. 

• Reduction in fishing grounds by the 

safety exclusion zone around subsea 

wellheads. 

These potential impacts and the proposed 

mitigation and management measures 

are discussed below. 


Measures and Residual 

Impacts 

Construction Impacts 

Interference to Fishing Grounds from 

Drilling. During drilling operations (which 

are expected to take up to 35 days per 

well, or about two months in total), a 

500-m radius safety exclusion zone will 

be established around the rig. Once drilling 

is completed, the same exclusion 

zone will apply around each wellhead for 

the life of the project. 

Table 6.3 Locations of commercial fisheries in the study area 

Fishery Location Fishing Method In Project Area 

Gillnet, Hook and 

Trap 

South East Trawl 

Southern Rock 

Lobster 

Southern Squid Jig 

Abalone 

Out to continental 

shelf break, depth to 

2,000 m. 



200 m (generally). 



150 m. 



200 m. 

Out to 2 km, depth to 

20 m. 

Demersal gill nets, 

demersal hook and 

long lines. 

Otter-board trawl and 

Danish Seine. 

Lobster pots and 

SCUBA diving. 

Pelagic jig (barbless 

hooks) line. 

SCUBA diving. 

Yes. 

No. 

Yes. Reef. 

Likely. 

Yes. Nearshore 

reef. 

Artificial lighting on the drill rig and support 

vessels at night (used as a safety 

measure for passing ships) may attract 

squid away from fishing vessels, but the 

lighting on the drill rig and support vessels 

will be of a lower intensity than that 

used on squid jigging boats. However, 

the main squid jigging grounds are located 

west of the project area. 

Given the short duration of drilling at 

each well site, the impact of this will be a 

localised temporary exclusion. The location, 

timing and duration of drilling will be 

communicated to commercial fishers and 

mariners through the provision of notices 

to the appropriate fisheries associations 

and Australian Maritime Safety 

Authority (AMSA). The location of the 

subsea wellheads will be provided on 

mariners charts and to AMSA once completed. 

Safety Risk to Fishing Vessels and 

Fisheries during Pipe Laying. During 

installation of the offshore pipeline, movements 

of pipe lay and support vessels 

(and their anchoring systems) may provide 

an obstacle to the movement of 

commercial fishing boats. As a result, a 

temporary 500-m exclusion zone will be 

established around the pipe lay vessel. 

As offshore pipe lay will only take in the 

order of 20 days, moving at a rate of 2- 

3 km per day, potential interference with 

fishing vessels will be temporary and 

short term. When the pipe lay vessel is 

close to shore for tie in at the HDD location, 

southern rock lobster fishers (including 

recreational divers) may be 

temporarily restricted from accessing 

nearby reef areas as a result of this exclusion 

zone (for a period of about seven 

days). 

The planned movements of the pipe laying 

and support vessels will be communicated 

to fishers and AMSA as described 

above. 

Disturbance to Target Fish Species. 

Disturbance to target fish species may 

arise from localised turbidity caused by 

drill cuttings, wastes (inert, hazardous or 

putrescible) discharged from drill rig and 

support vessels, smothering of habitat 

and the effects of underwater noise. However, 

these effects are expected to be 

localised and temporary. A chase boat 

will operate to ensure divers remain clear 

of the exclusion zone. 

Physical Disturbance to Reef Habitat. 

Disturbance to reef habitat has the potential 

to affect the habitat requirements 

of the southern rock lobster. However, 



the proposed subsea pipeline and route 

and HDD shore crossing avoid reef areas 

that are fished by commercial lobster 

fishermen. In the area where the 

proposed pipeline unavoidably crosses 

a low-profile reef area, a narrow section 

of reef is encountered at KP 19.5 (approximately 

60 m water depth), rock lobster 

fishers have indicated that this is not 

an area where pots are normally set. 

The stated preference by professional 

lobster fishers for a shore crossing at 

Two Mile Bay to avoid key lobster fishing 

grounds has been built into the project 

design, and this avoidance of key habitat 

is the main mitigation measure. 

Operational Impacts 

Interference with Demersal Fishing 

Gear. Fishing gear such as otter-board 

or Danish seine trawl nets and shark 

gillnets would have the most potential 

for snagging. However, the risks are low 

as the pipeline alignment does not pass 

through any significant trawling grounds 

and the shark fishers have indicated the 

few operators would set gillnets away 

from the structures. As discussed above, 

squid fishing involves no contact of gear 

with the seabed and therefore squid jigging 

is unlikely to be affected. A permanent 

500-m exclusion zone will be 

established around each of the wellheads, 

as is standard practice in offshore 

gas fields, to protect the 

infrastructure from damage, likely to be 

due to gillnet fishing or anchoring. 

Exclusion zones for fishing around pipelines 

have generally not been favoured. 

They are extremely difficult to enforce, 

particularly where applied to long, narrow 

corridors. Furthermore, as offshore 

production facilities increase in a newly 

developing basin, the network of pipelines 

that develops over time is difficult 

to predict, and would result in a very 

complex maze of exclusion corridors if 

these were to be imposed. In the Gippsland 

Basin, for example, there are now 

over 800 km of subsea pipelines linking 

production facilities and transferring oil 

and gas to shore. 

The fishers have reported no trawling 

occurs over the Casino gas field area, 

but periodic shark netting does occur 

when sharks are migrating through this 

region. This will give rise to minor inconvenience 

to fishing, having to set nets to 

avoid the exclusion zone, but little or no 

overall impact on the commercial fisheries 

of the region. Once the positions of 

the structures are known the fishers indicate 

that they can set nets accordingly 

and anchor so as to avoid risks of hookup. 

Digital information of the subsea wellhead 

positions will be provided to 

commercial fishers in a format compatible 

with fishing vessel navigational equipment. 

This will ensure that fishers from 

as far as Port McDonnell (to the west) 

and San Remo (to the east) who may be 

less aware of the project due to their 

infrequent fishing trips in the region would 

still be aware of the subsea structure. 

Local fishers suggested that the provision 

of digital information is most practical, 

as they do not necessarily hold the 

most updated charts. 

Port Campbell fishers have advised 

Santos that they have recently had to 

adapt to marine park restrictions and gas 

developments in the Otway Basin. They 

are concerned about the incremental effects 

of gas field and pipeline development 

and the consequences of this on 

access to fishing grounds (i.e., exclusion 

zones). There will be no exclusion zone 

over the offshore pipeline, and only a 

500-m radius exclusion zone around the 

subsea wellheads. The wellhead is outside 

the area fished by Port Campbell 

fishers and so no permanent restrictions 

to their operations are likely to result 

from this project. 

Much of the offshore pipeline route is 

located over sandy seabed, where, over 

time these sections of pipeline are likely 

to become partially buried by natural bed 

sediment transport (sand movements), 

especially during storm events. This in 

itself will decrease the likelihood of interference 

with gillnet or trawl gear. 

Means to reduce or avoid the potential 

for hook-up of fishing gear include: 

• Initiating and maintaining consultation 

with commercial fishing groups 

regarding pipeline locations. 

• Provision of digital information to fishers 

on pipeline and wellhead positions. 

• Selection of the pipeline alignment to 

avoid or minimise traversing any important 

fishing grounds as far as 

practical. 

• Ensuring locations are known in advance 

to all fishermen by provision of 

notices to mariners. 

• Following construction, removing all 

equipment (such as slings used to 

support the pipe and equipment during 

laying or tie-in) will be removed to 

reduce the risk of entanglement with 

fishing gear. 

• Establishing a temporary 500-m exclusion 

zone around the pipelay vessel 


• Establishing a permanent 500-m exclusion 

zone around the wellheads 

and marking their location on marine 

charts. 

• Designing pipelines to withstand impacts 

of trawl gear and to minimise 

or eliminate features (e.g., weights) 

upon which trawl gear could become 

caught. 

• Having a gear replacement policy in 

the event that a vessel’s gear is 

snagged, or the skipper has reason 

to believe that the gear is snagged 

on project infrastructure 4 . 

Operation and maintenance of all offshore 

pipelines will be conducted in accordance 

with the Australian Standard 

AS2885.4, and consequently, the international 

offshore pipeline code (DnV-OS- 

F101). Regular underwater surveys will 

be conducted to monitor the external condition 

of the pipelines and their corrosion 

control systems. The external surveys 

can also be used to observe and recover 

any fishing gear that has been lost or 

discarded following hook-up. Internal corrosion 

surveys may be conducted on the 

offshore pipeline utilising ‘smart’ or 

instrumented pigs at intervals approved 

by the Victorian DPI. 

6.6 Landform and Soils 


Information about the existing geology, 

landforms and soils has been sourced 

from recent environmental assessments 

undertaken in the project area, including 

Woodside (2003), BHP–Santos (1999), 

NSR (2002) and associated public technical 

reports. 

Geology 

Figure 6.4 illustrates the geology of the 

Port Campbell area. From oldest to 

youngest, the geological formations 

present in the project area are described 

in Table 6.4. 

Geomorphology 

The project area is covered by one 

geomorphic region, the Port Campbell 

Coastal Plain (LCC, 1981). The Port 

4 Esso operates such a system around its offshore 

facilities in the Gippsland Basin, eastern Bass Strait. 



668000 670000 672000 674000 676000 678000 


North - South Road 


Gas Plant 

Heytesbury 

Gas Plant 



Waarre Road 

Proposed 

Otway Gas 

Project Plant 

Tregea 

Road 

W allab y C r e ek 

TXU 

WUGS 

Facility 


Ea stern C ree k 

Cobden- Port Campbell Road 



Pascoe Road 

Langleys Road 

Brumbys Road 

Minerva 

Gas 

Plant 

r e ek 

am pbells C 

Currells Road 

C 

Sharps Road 

Rounds Road 

Port Campbell 

Legend 

Geology 

0 0.5 1 

Kilometres 


Road 

Creek 




HDD section 


Alluvium, colluvium, lagoon and swamp deposits: 

gravel, sand, silt, clay 


Fluvial and marginal marine deposits: 

gravel, sand, calcarenite, silt, clay. Includes Parilla Sand 

Gellibrand Marl and equivalents, Clifton Formation: 

marine marl, silt, calcarenite, basalt 

Port Campbell Limestone: marine calcarenite, marl 

Figure 6.4 Geology of the Port Campbell area 

r ee k 

Boundary Road 

Spring C 

Jarvis Road 

5724000 5726000 5728000 5730000 



Table 6.4 

Geology of the project area 

Geological 

Unit 

Tbp 

Tmc 

Nmn 

Formation Age Details 

Hanson 

Plains Sand 

Port 

Campbell 

Limestone 

Gellibrand 

Marl 

Tertiary 

Tertiary 

(Heytesbury 

Group) 

Tertiary 

(Heytesbury 

Group) 

Location: Covers an extensive area west of Campbells Creek, but not reaching the coast. 

Geological regime: Deposited as a terrestrial sheet (generally less than 10 m thick) over 

the uplifted and eroded older Tertiary marine sediments. 

Characteristics: Fine to coarse-grained quartz sands, with minor gravel and 

carbonaceous clay that overlies the Port Campbell Limestone and Gellibrand Marl 

formations. Often ferruginous (iron-rich) in outcrop. 

Location: Forms coastal cliffs and dissected tablelands, forming much of the terrain west 

of Campbells Creek. The karst terrain and the Twelve Apostles Formation are part of this 

formation. 

Geological regime: Deposited in a moderate energy, continental shelf environment. 

Characteristics: Moderately well bedded, with bedding planes often marked by calcareous 

concretions that are laterally continuous for several kilometres. Mainly grey to yellow, 

weakly cemented calcarenite with minor calcilutite. 

Location: Extensive outcropping in the east of the project area, dipping gently to the 

southwest, where the outcrop area is the Campbells Creek valley. 

Geological regime: Thick marine deposit outcropping extensively in coastal area. 

Characteristics: Massive to moderately well bedded, consisting of grey calcareous silty 

clay to clayey silt, with minor fine to coarse-grained calcarenite beds and locally abundant 

glauconite pellets. 

Qra Quaternary Location: Valleys of Campbells Creek and Curdies River and tributaries. 

Geological regime: Sediments deposited by waterways, generally less than 6 m in 

thickness, overlying the Tertiary sedimentary terrain. 

Characteristics: Floodplain and stream alluvium consisting of poorly consolidated and 

moderately sorted silt, sand and gravel of Pleistocene to Holocene age. 

Source: Woodside (2003), GHD (2003), HLA-Envirosciences (2002a). 

Campbell Coastal Plain is a generally 

flat to undulating plain, extending from 

the coast up to 50-km inland and bounded 

in the north by basalt plains (the Western 

Victorian Basalt Plains geomorphic 

region). Relief ranges from less than 

100 m above sea level (asl) in the west 

to over 200 m at Fergusson’s Hill. 

In the east, the plain is dissected by 

steeply incised valleys that have formed 

in Gellibrand Marl. This material has low 

shear strength and evidence of slumping 

is common on slopes (GHD, 2003). 

In the west, a relatively flat plain occurs 

and this is underlain by Port Campbell 

Limestone (GHD, 2003). Karst topography 

has formed in some places but the 

sinkholes and depressions are generally 

restricted to the west of Curdies River 

(GHD, 2003). 

Drainage generally flows from the northeast 

to the southwest. Some of the drainage 

lines are deeply incised such as 

Campbells Creek which flows along the 

Paaratte geological fault line (Goodwin, 

1995). 

Coastal Geomorphology. The region’s 

spectacular coastline is characterised by 

near-vertical cliffs up to 60 m high exposing 

Port Campbell Limestone and 

numerous coastal rock stacks, arches 

and islands (GHD, 2003) (Plate 6.2). The 

cliffs are actively eroding and rate of 

coastal retreat is estimated to be 0.2 m a 

year, although this is dominated by episodic 

cliff face collapses (Goodwin, 

1995). 

Enesar 

Plate 6.2 

Coastal cliff formations typical of the Port Campbell National Park 

The coastline at Two Mile Bay is atypical 

(see Plate 6.1) as a ‘stranded coastal 

landform’ (Goodwin, 1995), where the 

coastal plateau ends about 250 m from 

the coastline giving way to a 30° and 40° 

scarp sloping towards the sea. The scarp 

is thought to be an old landslip. A depression 

at the base of the scarp supports 

a wetland. A long, narrow sand 

ridge with a crest rising over 20 m in 

height occurs on the seaward side of the 



depression. A raised rocky shore platform 

lies seaward of the sand ridge, extending 

over 400 m to water depths of 12 

m (Parks Victoria, 1998). 

Sites of Geological and 

Geomorphological Significance. Numerous 

sites of geological and 

geomorphological exist to the east and 

west of the project area, concentrated 

mainly along the coastline. The description 

of significant sites in this section 

focuses on those within the Casino Gas 

Field Development project area. 

The Port Campbell National Park was 

first registered under the Register of the 

National Estate (RNE) in 1980 for its 

national natural significance (ID: 3,778 & 

103,709). The geological exposures and 

landforms are of national significance 

(Parks Victoria, 1998). Two Mile Bay (described 

in the section above) was rated 

as regionally significant by the Land Conservation 

Council in 1993. However, in 

addition to the site being of regional significance, 

the assessment of the area for 

the Minerva Project by Goodwin (1995) 

classifies the site as being of possible 

state significance. 

Parks Victoria (1998) has classified Two 

Mile Bay as a Special Protection Area, 

based on its geology, wetlands, Aboriginal 

heritage and faunal diversity. 

Soils 

In the Digital Atlas of Australian Soils 

(using the Northcote (1979) scheme), 

the project area is classified as having 

hard acidic yellow mottled duplex soils. 

Jenkin et al (1991) classifies soils in the 

area as consisting of sandy topsoils with 

poor nutrient levels and ironstone concretions 

that are loose but occasionally 

cemented. 


The construction and operation of the 

proposed onshore gas pipeline may 

cause the following potential impacts to 

landforms and soils: 

• Erosion and sedimentation. 

• Slope instability. 

• Soil inversion, compaction and subsidence. 

• Soil contamination. 

• Disturbance to significant features. 

Excess rock and acid sulfate soils are 

not expected to be encountered along 

the proposed pipeline route and are consequently 

not discussed below. 



Impacts 

Erosion and Sedimentation 

Specific zones of erosion and sedimentation 

hazard along the pipeline alignment 

are: 

• The Hanson Plain Sands occurring 

on top of the Port Campbell Limestone 

is an area of potential susceptibility 

for moderate wind erosion 

(HLA-Envirosciences, 2002a). 

• The Quaternary Alluvium in the Port 

Campbell Coastal Plain together with 

moderate relief would classify the 

project area as having moderate susceptibility 

to gully and tunnel erosion, 

with high susceptibility in silty alluvium 

(HLA-Envirosciences, 2002a). 

Dispersive soils ‘slake’ when wetted i.e., 

are readily eroded and can rill and gully 

rapidly, even on low-angle slopes. Dispersive 

soils when dry tend to form a 

surficial crust that can impede moisture 

infiltration and root penetration for revegetation 

works. Some of the soils traversed 

by the proposed pipeline route are classified 

as ‘sodic (sodosols) and potentially 

dispersive’ (HLA-Envirosciences, 

2002a). 

Measures to be implemented to minimise 

erosion and sedimentation impacts 

include: 

• Pipeline construction will be scheduled 

to commence and be completed 

during the summer months. 

• Priority will be given to retaining maximum 

coverage of vegetation (including 

pasture grasses) on steep slopes 

for as long as possible before disturbance. 

• A buffer zone will be established to 

protect the riparian zone of Campbells 

Creek, (nominally 20 m from top-ofbank). 

• Appropriate placement and construction 

of diversion berms and erosion 

and sediment control structures so 

that they are stable and drain to the 

downstream side of the ROW. In principle, 

structures will be installed to 

minimise sediment entering waterways 

or waterbodies (e.g., Campbells 

Creek, drainage lines, table drains 

and dams) such as sediment fences 

and/or weed-free straw bales down 

slope of exposed soil and stockpiles. 

Greater controls will be applied in 

areas of dispersive soils. 

• Expeditiously complete construction 

across Campbells Creek and its valley 

by special crossing crew, not as a 

mainline construction activity, thereby 

limiting bank and in-stream activity to 

a one to two day period. Campbells 

Creek will be constructed by opentrench 

method during nil to low flow, 

if practicable, as has been successfully 

applied on three previous pipeline 

crossings at this location. 

Isolation techniques such as dam and 

pump or flume pipe (see Figures 5.14 

and 5.15) will be applied were there 

is a risk of significant impacts to water 

quality. The pipe will be buried at 

least 1.2 m under the invert of the 

Campbells Creek (and out to a lateral 

distance of approximately 5 m 

from the edge of the banks) to minimise 

the potential for scouring to expose 

the pipeline. 

• Campbells Creek, including the banks 

and approach slopes, will be reinstated 

using appropriate stabilisation 

measures, such as rock rip-rap, diversion 

berms, sediment fences, jute 

matting and immediate reseeding and 

plantings. 

• The time between clearing and grading 

of the mainline ROW and 

trenching and backfilling will be minimised 

to limit the time of exposure to 

the elements of the cleared ROW. 

• Dispersive soils will be treated with 

gypsum or lime (where they occur in 

agricultural land). 

• Every attempt will be made to reestablish 

vegetation as soon as practicable 

after reinstatement earthworks 

to stabilise the exposed soils. 

• The pipeline easement will be monitored 

during operations for erosion 

and sedimentation. 

Slope Instability 

Evidence of mass movement in the soils 

of the project area exist in the steep 

slopes of the Campbells Creek valley. 

Existing gas pipelines running east from 

the TXU WUGS facility at Iona are not 

known to have experienced any slope 

instability problems. 

Mitigation and management measures 

to address impacts associated with slope 

instability include: 



• Route planning to avoid areas of 

sever slope instability and slumping. 

• Installation of trench breakers on 

steep slopes to slow water flow along 

the pipe trench and minimise soil erosion. 

• Monitoring ground stability by survey 

marker, as appropriate. 

Soil Inversion, Compaction and 

Subsidence 


to address impacts associated with soil 

inversion, compaction and subsidence 

include: 

• Topsoil will be stripped and stockpiled 

separately to trench spoil (see 

Figure 5.11). 

• Avoid construction during or immediately 

after prolonged or heavy rain 

events. 

• Subsoil will be reinstated first followed 

by the topsoil to minimise the chance 

of inversion. 

• During rehabilitation, where the soil 

surface has been excessively compacted 

due to construction traffic, 

lightly scarify or rip the soils to aid 

water infiltration. 

• Compact trench backfill and if necessary 

install a raised crown (less than 

20 cm) over the trench to mitigate 

subsidence. 

Soil Contamination 

During operations, up to 6,000 L of hydraulic 

oil will be stored in the HPU at the 

MLV site near the Great Ocean Road. 

The risk of soil contamination from a spill 

will be minimised as the HPU will be 

fitted with an internal bund that is part of 

the skid frame (see Section 5.4.5). The 

hydraulic oil will be periodically replenished 

and so a filling protocol will be 

developed to minimise the risk of spillage. 

Potential also exists for the MEG supply 

pipeline, which parallels the gas pipeline, 

to be ruptured during operations 

and this could result in a spill. Marker 

posts will be placed along the easement 

and marker tape placed in the backfilled 

trench to warn of buried services should 

unauthorised excavation be undertaken 

(Section 6.18). 

Disturbance to Significant Features 

HDD of the shore crossing will pre-empt 

impacts to the regionally significant 5 

5 In addition to the site being of regional significance, 

the assessment of the area for the Minerva 

Project by Goodwin (1995) classifies the site as 

being of possible state significance. 

HDD entry 

+90 m 

+80 m 

+70 m 

+60 m 

+50 m 

+40 m 

+30 m 

+20 m 

HDD exit 

+10 m 

0 m 

-10 m 

-20 m 

-30 m 

-40 m 

-50 m 

1,500 m 1,000 m 

500 m 

0 m 

1:10 vertical exaggeration 

Soil (average 4 m thick) Limestone (yellow/white) Port Campbell limestone Marl (depth unknown) 

Sand (estimated thickness) Talus Unknown 

Figure 6.5 

Idealised geological profile of the HDD shore crossing 



coastal features (Section 6.6.1) by drilling 

beneath them. Figure 6.5 shows the 

geological profile of the HDD shore crossing. 

6.7 Hydrology and 

Hydrogeology 

This section reviews the hydrology (surface 

water) and hydrogeology (groundwater) 

of the Casino Gas Field 

Development project area. It is based on 

recent EIAs undertaken in the project 

area and associated technical reports. 


Hydrology 

The proposed onshore pipeline route will 

cross Campbells Creek (sometimes referred 

to as Port Campbell Creek) (see 

Figure 6.5). Other creeks present in the 

project area, but not impacted by the 

Casino Gas Field Development include 

Wallaby Creek and its tributaries (west 

of North South Road) and Eastern Creek 

(east of Cobden to Port Campbell Road), 

and a tributary of Campbells Creek. 

Campbells Creek catchment covers an 

area of 74.4 km 2 (Woodside, 2003) and 

is about 10 km in length. Its valley is 

located along the Paaratte geological 

fault line (Goodwin, 1995). The creek is 

generally no wider than 2 m. Remnant 

riparian vegetation is sparse and generally 

in poor condition (see Section 6.8). 

Campbells Creek is classified as a regional 

drain; its management is the responsibility 

of the CCMA. Water from 

the creek is used for domestic, stock 

and irrigation purposes. The creek 

traverses agricultural land (mainly dairy 

grazing) and is known to have elevated 

nutrient levels (e.g., nitrogen and phosphorous), 

resulting in high levels of weed 

and algae growth (Woodside, 2003). 

Hydrogeology 

Two main aquifers occur in the project 

area: 

• Port Campbell Limestone Aquifer 

(shallow regional aquifer). 

• Dilwyn Formation Aquifer. 

Port Campbell Limestone Aquifer. The 

Port Campbell Limestone underlies the 

entire proposed onshore pipeline route. 

This aquifer has variable water quality 

and yield and, where available, is utilised 

for stock watering and irrigation 

(Woodside, 2003). Regionally, it is also 

used to supply potable water for domestic 

and industrial consumption to towns 

including Koroit, Casterton, Sandford and 

Lismore (all to the west of the project 

area) (HLA-Envirosciences, 2002b). 

Based on the Victorian Groundwater Beneficial 

Use Map Series, Woodside (2003) 

reported that the salinity of the Port 

Campbell Limestone Aquifer varies between 

1,001 to 3,500 mg/L. 

This aquifer system also discharges to, 

and is recharged by (either directly or 

indirectly via other formations), the many 

local creek, river and wetland systems. 

This aquifer is also expected to discharge 

to the Southern Ocean. Recharge is expected 

to occur largely from direct rainfall 

infiltration and leakage from overlying 

formations and, to a lesser extent, underlying 

formations. The water table 

within this aquifer can be above ground 

surface (i.e., forming springs where 

unconfined) to tens of metres below surface 

along the pipeline route. 

Dilwyn Formation Aquifer. The Dilwyn 

Formation Aquifer is separated from the 

shallower Port Campbell Limestone Aquifer 

by more than 300 m of low permeability 

calcareous clays belonging to the 

Gellibrand and Narrawatuk Marls (SKM, 

1999). These marls act as aquitards, confining 

significant aquifers in underlying 

formations. This aquifer provides town 

water for Port Campbell and Peterborough 

and several towns further west of 

the project area (HLA-Envirosciences, 

2002b) and is accessed from bores sunk 

to a depth of approximately 500 m. 


The potential hydrological and 

hydrogeological impacts associated with 

the construction and operation of the 

Casino Gas Field Development include: 

• Impacts to water quality. 

• Disruption to water flow regimes. 






Impacts 

Potential impacts of the Casino Gas Field 

Development to and from the local hydrological 

and hydrogeological environment 

have been assessed for the 

construction, operation and 

decommissioning stages of the development. 

This following section identifies 

proposed mitigation and management 

measures and residual impacts. 

Water Quality 

Sediment Release. Erosion of the exposed 

soils and therefore sedimentation 

on the cleared ROW could occur if heavy 

rain falls during the construction period. 

Construction of the onshore component 

of the Casino Gas Field Development is 

scheduled to commence in January 2005 

and continue through to March 2005. 

Rainfall data from the closest weather 

station at Warrnambool (60 km to the 

west of the project area) indicate that 

January through to March are the driest 

months (with the least number of rain 

days) in the region (see Section 6.1). 

Therefore, scheduling construction during 

the driest time of year should assist 

in minimising the potential for erosion on 

the easement. 

Excavation of the pipeline trench in undulating 

terrain will include temporary 

trench plugs that will remain in place 

until immediately before the pipe is laid 

to minimise the risk of erosion if heavy 

rainfall should occur. Sensitive areas, 

such as remnant vegetation and waterways 

will be protected by constructing 

and maintaining sediment containment 

measures downstream of the ROW (e.g., 

straw bales and/or fine shade cloth). 

Trench spoil and topsoil stockpiles will 

not be placed closer than 10 m from the 

top-of-bank at Campbells Creek and will 

be placed so that they do not impede 

drainage. 

The location of erosion-prone soils, shallow 

ground water and recharge areas 

will be identified on alignment sheets for 

recognition by construction crews and 

cross-referenced to management measures 

in the Environmental Management 

Plan (EMP), as required. 

Spills. A spill contingency response plan 

will be developed for the construction 

and operations phases addressing fuels, 

lubricants and chemicals. Spill response 

equipment will be located at the 

HDD site and at the waterway crossing 

during construction. In the event of a 

spill, HDD will be shut down and the spill 

response will be activited (as outlined in 

the HDD environmental management 

plan). Measures will be put in place to 

prevent reoccurrences. Pipeline construction 

machinery and equipment will 

not be refuelled within 20 m of Campbells 

Creek. In addition, site specific procedures 

for HDD set-up, operation and 

decommissioning will be developed and 

implemented in the HDD environmental 

management plan. 

Drilling fluids used for HDD will be bentonite-based 

(a naturally occurring nontoxic 

clay). Drilling fluids will be monitored 

for potential sub-surface losses. As a 

joint venture partner of the Minerva 



Project, Santos has access to drilling 

logs of the HDD shore crossing for that 

project which will assist in the planning 

and management of the HDD for the 

Casino Gas Field Development. 

The HPU will be located within a bund to 

contain any potential spills. During construction, 

other hazardous chemicals will 

be stored in accordance with EPA guidelines. 

Visual observation for ‘frac-out’ at the 

coast (loss of drilling fluids into rock fractures 

and fissures) and appropriate remedial 

action in consultation with 

regulatory authorities will take place, as 

appropriate. 

Water Scouring. To minimise the risk of 

scour, the pipeline will be buried at 

greater depth at the Campbells Creek 

crossing. 

Disruption to Water Flow Regimes 

Campbells Creek. Open trenching 

across Campbells Creek is not likely to 

take longer than one day for actual instream 

activity. This will be timed to occur 

during a period of nil to low flow, 

where practicable, thereby minimising 

impacts on the hydrological regime of 

the creek. Alternatively, isolation techniques 

may be applied to prevent impeded 

water flow (see Figures 5.14 and 

5.15). 

Impacts on freshwater aquatic fauna and 

flora habitat are discussed in Section 6.8. 

Surface Water. Once pipeline construction 

is complete and the pipe trench is 

backfilled and compacted, there is a period 

of time whereby subsidence along 

the trench line can occur as the backfill 

material settles. The risk of this happening 

depends on soil type, soil moisture 

and level of backfill compaction. Given 

that trench subsidence is evident on other 

gas pipelines within the project area, 

there is a chance it may also happen on 

the Casino Gas Field Development. The 

impact of trench subsidence is such that 

it can divert surface water flows along 

the trench and lead to erosion, it can 

effect ROW revegetation by influencing 

regrowth and it can create a crossing 

hazard for stock and vehicles. 

The trench backfill will be compacted 

and a raised crown or windrow (up to 

200 mm in height) will be installed over 

the trench to compensate for settling of 

trench backfill and avoid subsidence. 

Crown breaks (gaps in the trench crown) 

will be created at least every 30 m and at 

drainage lines to permit continued surface 

water flows and prevent scouring 

along the trench or ponding on the easement. 

Groundwater. Positive pressure caused 

by drilling fluids during HDD of the shore 

crossing will prevent any disruption to 

near-surface groundwater. The drill holes 

will be cased to prevent any preferential 

flows of groundwater along the drill hole. 

The location of any nearby groundwater 

bores will be mapped during the detailed 

pipeline design phase and the pipeline 

route will avoid these bores. 

6.8 Terrestrial Ecology 

Brett Lane & Associates have undertaken 

the flora and fauna assessment which is 

summarised below (BLA, 2004). Appendix 

1 contains the flora and fauna species 

list for the project area. 


Flora 

Flora records were obtained from a 

search of the Flora Information System 

(FIS) database maintained by DSE. This 

listed all plant species, including rare 

and threatened plants, found in a search 

area within approximately 10 km of the 

study area. 

Information on the Ecological Vegetation 

Classes (EVCs) in the area and the 

region was obtained from: 

• State-wide EVC mapping at 

1:100,000 scale. 

• Southwest region EVC mapping carried 

out as part of Regional Forest 

Agreement Comprehensive Regional 

Assessments for Midlands and Otway 

regions. 

• Port Campbell and Princetown 

1:100,000 biomaps with EVC and 

threatened species data overlays. 

• Relevant EVC benchmarks for the 

Warrnambool Plain bioregion. 

A flora survey was conducted in late 

February 2004 and reviewed all onshore 

pipeline route options (and sub-options) 

as 100 m wide corridors. During the 

course of the survey, there was a minor 

re-alignment of Option 4A at the request 

of a landholder. Both variations to 

Option 4A were surveyed and are reflected 

in Figure 6.6. All areas identified 

as vegetation parcels from the aerial photography 

were inspected on foot. Cleared 

agricultural land dominated by exotic pasture 

was reconnoitred. The specialist 

ecologists advised that timing of the flora 

survey was considered sufficient to detect 

the majority of life forms present or 

likely to be present in areas of native 

vegetation within the project area (BLA, 

2004). 

Plant species within the specified study 

area were recorded (i.e., 50 m either 

side of proposed pipeline route 

centreline) in areas of native vegetation 

(public and private land), on roadsides 

and creek crossings. No detailed plant 

species lists were compiled for pipeline 

route options that traverse cleared agricultural 

land dominated by exotic pasture. 

For remnant native vegetation, two general 

categories can be recognised. These 

categories are defined for the purpose of 

this report and are based on the general 

rules of ‘intactness’ as contained in Victoria’s 

Native Vegetation Management 

Framework (NVMF) (DNRE, 2002a). 

Clearly definable EVCs were assessed 

in the field using the methodology for 

assessing vegetation and habitat quality 

developed as part of the NVMF, known 

as ‘habitat hectare scoring’. The habitat 

hectare methodology provides a quantitative 

measure of vegetation quality, 

which ultimately assists in defining the 

values of remnant vegetation and offsets 

if native vegetation is to be unavoidably 

cleared. At present the finalised 

‘operational’ guidelines for the implementation 

of this methodology have not been 

publicly released and all work carried 

out for this assessment has been done 

according to draft and interim guidelines. 

Vegetation categories include: 

• Category 1 vegetation - patches of 

remnant native vegetation composed 

of indigenous plant species that are 

considered to be part of a clearly 

definable EVC. This vegetation category 

was assessed in the field using 

NVMF. 

• Category 2 vegetation – all ‘other’ 

native vegetation including individual 

remnant specimens or populations of 

native plants that are highly modified 

and are not considered part of a 

clearly definable EVC. Examples of 

such vegetation include stands of 

remnant vegetation with less than 

10% cover of indigenous understorey 

species or where overstorey density 

has been significantly reduced. 

Such vegetation is considered to be 

of poor quality and no formal quality 

assessment was therefore under- 



taken. Where appropriate, the conservation 

significance of Category 2 

vegetation has been assessed as part 

of this investigation (e.g., presence 

of hollow-bearing trees or significant 

plant species). 

The habitat hectare methodology has 

been applied to 10 vegetation units as 

part of the botanical assessment. 

Fauna 

The fauna field survey was undertaken 

in conjunction with the flora survey. A 

number of techniques were used to identify 

fauna species inhabiting the study 

area. These comprised: 

• Desktop searches of the Atlas of Victorian 

Wildlife (AVW) and EPBC 

databases. 

• Searches for mammal scats, tracks 

and signs. 

• Spotlighting. 

• Bird observation. 

• Searches for reptiles. 


Flora 

Plant Species. A total of 131 plant species 

were recorded during the field survey 

(see Appendix 1). Of the species 

recorded, 76 (58%) were indigenous and 

55 (42%) were exotic. 

Vegetation Types and Ecological Vegetation 

Classes (EVCs). The extent of 

existing native vegetation, including vegetation 

type and EVC classification intersected 

by the project is shown in Figure 

6.6, while Figure 6.7 shows the extent of 

EVCs within the project area. Each vegetation 

type observed during the field 

survey was given a unique identifier, 

which includes the EVC and vegetation 

category. Vegetation units were also defined 

for the purpose of assessment, as 

discrete patches of a similar type and 

quality of vegetation. Vegetation types 

recorded are briefly summarised in Table 

6.5 and include: 

• Vegetation type 1 – Damp Heath 

Scrub (EVC 165), Category One. 

• Vegetation type 2 – Damp Heathy 

Woodland (EVC 793), Category One. 

• Vegetation type 3 – Lowland Forest 

(EVC 16), Category One. 

• Vegetation type 4 – Heathy Woodland 

(EVC 48), Category One. 

• Vegetation type 5 – Degraded native 

vegetation (EVC indeterminate), Category 

Two. 

• Vegetation type 6 – Exotic grassland/ 

pasture and shelterbelts (no EVC), 

exotic vegetation. 

EVCs present above the path of the HDD 

and within the Port Campbell National 

Park, but not present elsewhere along 

the alignment (and not described in Table 

6.5), include Coastal Headland Scrub 

(EVC 161) and Coast Gully Thicket (EVC 

181). Both EVCs are considered Category 

1 vegetation. Figure 6.7 illustrates 

their distribution above the path of the 

HDD. 

Coastal Headland Scrub occurs as exposed 

wind-pruned shrubland on the 

limestone cliffs around Port Campbell. 

This vegetation is mostly treeless, other 

than occasional stunted messmate (Eucalyptus 

obliqua). The closed heathland 

is dominated by manuka (Leptospermum 

scoparium), silver banksia (Banksia 

marginata) and prickly tea-tree 

(Leptospermum continentale). The lower 

heath layer is composed of species including 

coast beard-heath (Leucopogon 

parviflorus), honey-pots (Acrotriche 

serrulata) and cranberry heath 

(Astroloma humifusum) with sedges including 

common bog-sedge (Schoenus 

apogon) and coast saw-sedge (Gahnia 

trifida). 

Coast Gully Thicket occurs along drainage 

lines close to the coast and within 

the Port Campbell National Park. The 

dominant trees are short, wind-pruned 

swamp gum (Eucalyptus ovata) and 

messmate (Eucalyptus obliqua). A dense 

cover of rough guinea-flower (Hibbertia 

aspera), manuka (Leptospermum 

scoparium) and bracken (Pteridium 

esculentum) dominate the thicket. Species 

including spiny-headed mat-rush 

(Lomandra longifolia), black-anther flaxlily 

(Dianella revoluta) and coast saw 

sedge (Gahnia trifida) occupy the ground 

layer. 

Fauna Habitats 

Terrestrial Habitats. The habitat type 

and quality for each of the identified units 

of native vegetation (see Figure 6.6) traversed 

by all of the route options and 

sub-options identified in Section 5 is described 

below in Table 6.6. The impact 

assessment and mitigation measures focus 

on the selected preferred route alignment 

(Option 4 (Otway) and sub-option 

4A). 

Aquatic Habitats. Campbells Creek is 

the only waterway to be traversed by the 

proposed pipeline. The proposed eastwest 

crossing point is near Camerons 

Hill Road. Campbells Creek is a freshwater 

ephemeral creek and was not flowing 

at the time of the field survey. 

Fauna Species Distribution and 

Conservation Significance 

This section describes the faunal habitat 

features of the study area and the fauna 

recorded or likely to occur in the area, 

based on database records. 

The study area is known to, or likely to, 

support 150 species of fauna, including: 

• 23 mammal species (five introduced). 

• 110 bird species (seven introduced). 

• 9 reptile species. 

• 8 frog species. 

In addition to the terrestrial fauna listed 

above, there were four native fish species 

recorded during previous studies in 

Campbells Creek. All fauna species are 

listed in Appendix 1. 

Mammals observed during the current 

survey include the common ringtail possum, 

the eastern grey kangaroo and the 

introduced red fox. Other mammal species 

that have been recorded in the AVW 

that are of State significance (but were 

not detected during the survey) are described 

below: 

• White-footed dunnart: previously recorded 

in the Port Campbell National 

Park and cemetery at Loch Ard 

Gorge. This species has a ‘vulnerable’ 

status in Victoria. It occurs in a 

variety of habitats but all have in common 

a heathy under- or mid-storey. It 

is likely to be found in the Port 

Campbell National Park but not in 

remnant roadside vegetation. 

• Southern brown bandicoot: previously 

recorded in the Port Campbell National 

Park, Loch Ard Gorge and the 

Port Campbell rifle range area. This 

species is listed as ‘lower risk near 

threatened ‘ in Victoria and classified 

as ‘endangered’ under the Commonwealth 

EPBC Act 1999. It inhabits 

heath, shrubland and heathy forests 

and woodlands usually on welldrained 

soils. No bandicoot diggings 

were observed during the field survey. 

• Swamp antechinus: previously recorded 

in the Port Campbell National 



668000 670000 672000 674000 676000 678000 

Co 


North -South Road 


Gas Plant 

Heytesbury 

Gas Plant 


Unit J 

Unit K 

4B 


Tregea 

Road 

C r e ek 

W allab y 

Waarre Road 

Smokey Point 

Road 



Eas tern Creek Road 

Cobden-Port 

Campbell Road 

r e ek 

Pascoe Road 

Langleys Road 

Brumbys Road 

C 

Minerva 

Gas 

Plant 

Proposed 

Otway Gas 

ProjectPlant 

TXU 

WUGS 

Facility 

am pbells 

Unit C 

C 

Unit B 

Rounds Road 

Currells Road 

Sharps Road 

Unit A 

Unit E 

Unit F 

Unit Q 

Unit G 

Unit L 

Unit I 

4A 

Unit D 

Unit P 

Unit H 

Unit M 

Unit N 

Unit O 

4C 

Option 4 (Minerva) 


Port Campbell 

Legend 

0 0.5 1 

Kilometres 


Road 

Creek 



Alternative Casino pipeline route option 


HDD section 



Vegetation unit 

Figure 6.6A Vegetation units 

C r eek 

Boundary Road 

S prin g 

Jarvis Road 

5724000 5726000 5728000 5730000 



668000 670000 672000 

Langleys 

Road 

Minerva 

Gas 

Plant 

Unit C 

Unit F 

Curdie Vale - 

Unit B 



Sharps Road 

Unit A 

Legend 

Road 

Creek 

0 0.5 1 

Kilometres 



Existing Pipeline 

Proposed Otway 

Gas pipeline 

Alternative Casino 

pipeline route option 

Casino pipeline 

route alignment 

HDD section 

HDD shore 

crossing site 

Vegetation type 1 

Damp Heath Scrub EVC (165) 


Damp Heathy Woodland EVC (793) 


Lowland Forest EVC (16) / Exotic Vegetation 


Heathy Woodland EVC (48) 


Heathy Woodland EVC (48) / Exotic Vegetation 


Degraded Native Vegetation 

EVC Indeterminate 



EVC Indeterminate / Exotic Vegetation 


Exotic Vegetation 

Figure 6.6B Vegetation units (Great Ocean Road to Curdie Vale to Port Campbell Road) 

5724000 5726000 



670000 672000 674000 

Unit J 

4B 


Tregea 

Road 

Unit Q 

Unit I 

North - South 

Road 

Wallaby Creek 

4A 

4C 

Unit P 

Unit D 

Unit E 

Unit H 


Unit N 

Unit G 


b 

Pascoe Road 

Langleys Road 

Brumbys Road 

Port Cam 

pbells C reek 

Unit F 

Unit L 

Unit M 

Legend 

Road 

0 0.5 1 

Creek 


Gas pipeline 






Kilometres 




















Figure 6.6C Vegetation units (Curdie Vale to Port Campbell Road to Campbells Creek) 

boon-P 

Minerva 

Gas 

Plant 

5728000 5730000 



674000 676000 678000 

Unit J 

Unit K 

4B 

Proposed 

Otway Gas 

Project Plant 

Tregea Road 

Waarre Road 

Unit O 

TXU 

WUGS 

Facility 

4C 

Unit N 

Unit M 

Legend 

0 0.5 1 

Kilometres 


Eastern Creek 

Road 



Cobden-Port 

Campbell Road 


Creek 


Gas pipeline 























Figure 6.6D Vegetation units (Campbells Creek to the TXU WUGS facility) 

A 

5728000 5730000 



668000 670000 672000 674000 676000 678000 




Gas Plant 

Heytesbury 

Gas Plant 



Waarre Road 

Proposed 

Otway Gas 

ProjectPlant 

Tregea 

Road 

C r e ek 

W allab y 

TXU 

WUGS 

Facility 


Ea stern C ree k 



Cobden- 


r e e k 

Pascoe Road 

Langleys Road 

Brumbys Road 

C 

Minerva 

Gas 

Plant 

am pbells 

C 

Currells Road 

Sharps Road 

Rounds Road 

Port Campbell 

Legend 

0 0.5 1 

Kilometres 


Road 

Creek 




HDD section 


Ecological Vegetation Class and Number 

Cleared/Severely Disturbed (58) 

Coast Gully Thicket (181) 

Coastal Dune Scrub Mosaic (1) 

Coastal Headland Scrub (161) 

Coastal Tussock Grassland (163) 

Damp Heath Scrub (165) 

Estuarine Wetland (10) 


Herb-rich Foothill Forest (23) 

Lowland Forest (16) 

Private Land - No Tree Cover (997) 

Swamp Scrub (53) 

Figure 6.7 Ecological Vegetation Classes of the Port Campbell area 

C r ee k 

Boundary Road 

Spring 

Jarvis Road 

5724000 5726000 5728000 5730000 



Table 6.5 Summary of vegetation types and EVCs along the proposed Casino pipeline route 

Vegetation Type EVC EVC Description Distribution in Study Area Category 

1 Damp 

Heath 

Scrub 

(EVC 165) 

2 Damp 

Heathy 

Woodland 

(EVC 793) 

3 Lowland 

Forest 

(EVC 16) 

4 Heathy 

Woodland 

(EVC 48) 

5 EVC 

indeterminate 

6 Exotic 

vegetation 

Generally form closed heathland 3 m to 4 m tall with scattered emergent 

eucalypts. 

Dominant species include tea-trees (Leptospermum spp.), silver banksia (Banksia 

marginata), scrub she-oak (Allocasuarina paludosa), myrtle wattle (Acacia 

myrtifolia). Other dominant lifeforms include sedges and graminoids such as saw 

sedges (Gahnia spp.) and grass-trees (Xanthorrhoea spp.). Perennial herbs are 

limited in this vegetation type. 

Open to closed woodland with a low overstorey 10 m-15 m tall. Dominant canopy 

species include Jimmy’s shining peppermint (Eucalyptus willisii), swamp gum (E. 

ovata). The understorey is composed of ericoid shrubs such as tea-trees 

(Leptospermum spp.), silver banksia (Banksia marginata), honey-pots (Acrotriche 

serrulata), creeping bossiaea (Bossiaea prostata). Graminoids also common 

include saw-sedges (Gahnia spp.), sword-sedges (Lepidosperma spp.) and grasstrees 

(Xanthorrhoea spp.). Herb diversity is quite depauperate in this EVC, tends 

to occur on soils that are seasonally waterlogged. 

Structure is commonly an open forest to 25 m tall with a dominant overstorey of 

messmate (Eucalyptus obliqua). Understorey species include shrubs such as 

blackwood (Acacia melanoxylon), tree everlasting (Ozothamnus ferrugineus), 

silver banksia (Banksia marginata), tea-trees (Leptospermum spp.), kangaroo 

apple (Solanum laciniatum), large-leaf bush-pea (Pultenaea daphnoides), hop 

wattle (Acacia stricta). Herbaceous and graminoid life-forms include pennywort 

(Hydrocotlye sp.), ivy-leaf violet (Viola hederacea), Senecio spp., common appleberry 

(Billardiera scandens), forest wire grass (Tetrarrhena spp.), sword-sedges 

(Lepidosperma spp.), spiny-headed mat-rush (Lomandra longifolia). Austral 

bracken (Pteridium esculentum) is also a common element. 

The overstorey is low to about 10 m tall with dominant canopy species including 

Jimmy’s shinning peppermint (Eucalyptus willisii) and to lesser extent messmate 

(Eucalyptus obliqua) and brown stringybark (Eucalyptus baxteri). The understorey 

is dominated by ericoid shrubs such as tea-trees (Leptospermum spp.), silver 

banksia (Banksia marginata) and honey-pots (Acrotriche serrulata). 

Degraded native vegetation from various indeterminate EVCs. The vegetation 

associated with this type is not attributable to an EVC due to its degraded nature 

and lack of character species and life forms. Generally composed of hardy or 

resilient indigenous species that are subject to disturbances such as grazing, 

slashing, weed invasion and ploughing. 

Dominated by exotic vegetation such as exotic pasture, planted exotic shelterbelts 

and dense shrublands of woody weeds. The exotic shelterbelts that have been 

planted on grazing land generally include cypress (Cupressus spp.) and pines 

(Pinus spp.), more recent plantings of native and indigenous species have also 

taken place. The dense stands of woody weeds found on roadsides and along 

streams and drainage lines are mostly dominated by blackberry (Rubus spp.), 

hawthorn (Crataegus sp.) and sweet pittosporum (Pittosporum undulatum). 

Found adjacent to the HDD site in the northern road 

reserve of the Great Ocean Road and on the 

southern road reserve of Brumby’s Road (Option 

4(Minerva)). Also a dominant EVC within the Port 

Campbell National Park. The vegetation on 

Brumby’s Road has been disturbed in the past, 

lacks, diversity and structure apparent in other 

examples of this vegetation around Port Campbell. 

Occurrences of this EVC within the study area are 

associated with buckshot soils along the Curdie 

Vale to Port Campbell Rd, such soils are indicative 

of seasonally waterlogged conditions. 

Found on moderately fertile well-drained soils in 

study area. Lowland Forest grades into Heathy 

Woodland in several places as soils become 

sandier and less fertile. In some places wide 

ecotonal bands between these two EVCs are 

apparent and the understorey of these formations 

supports a mix of ericoid and herbaceous elements 

with a forest or woodland overstorey. 

Found on unconsolidated sandy soils in the 

elevated parts of the study area. The rare species, 

Port Campbell guinea-flower (Hibbertia truncata), 

was observed in association with this vegetation 

type on the Smokey Point Road and Cheynes Road 

South reserves. The examples of this EVC in the 

study area were generally disturbed and had a high 

cover of woody weeds such as blackberry. 

Along Campbells Creek this vegetation is composed 

of scattered remnant trees. In other situations 

Vegetation type 5 included native regrowth on 

roadsides mixed with exotic species. 

Exotic pasture is the most common and extensive 

vegetation type in the study area and is generally 

composed of a range of annual and perennial 

pasture species and common agricultural and 

environmental weeds (see Appendix 1). 

Vegetation type 1 is 

considered Category One 

vegetation as it retains a 

greater than 10% cover of 

indigenous species. 










indigenous species. Major 

weeds of this EVC include 

exotic pasture grasses and 

blackberry. 






This vegetation type is 

considered Category Two 

due to the generally less 

than 10% cover of 


This vegetation type is 

considered Category Two 

due to the generally less 

than 10% cover of 




Park and Loch Ard Gorge. The species 

has a ‘lower risk near threatened’ 

status in Victoria. It inhabits 

near coastal areas comprising dense 

wet heath, tussock grassland or 

sedgeland. 

During the field assessment, 26 bird species 

were observed. Bird species that 

have been recorded in the project area 

according to AVW records and are of 

state conservation significance (but were 

not recorded during the current survey) 

are described below: 

• Rufous bristlebird: Has been recorded 

from Port Campbell National Park and 

roadsides in the area (Curdie Vale to 

Port Campbell Road). The species is 

considered to be ‘lower risk near 

threatened’ in Victoria and is listed 

under the Flora and Fauna Guarantee 

Act 1988. This bird species occurs 

mainly in dense shrubland and 

heathland on coastal dunes and cliffs, 

while it inhabits the dense undergrowth 

of forests further inland. It uses 

connected areas of remnant vegetation 

such as roadside remnants as 

movement corridors. 

• Grey goshawk: Has been recorded 

in the Timboon area as well as 

Smokey Point Road in Port Campbell. 

The species is listed as ‘vulnerable’ 

in Victoria. It typically inhabits wooded 

and forested lands where rainfall exceeds 

750 mm per annum. 

• Chestnut-rumped heathwren: A single 

record of this species from the 

Port Campbell Coastal Plain occurs. 

The species is listed as ‘vulnerable’ 

in Victoria. It occurs in dense 

heathland or dense heathy understorey 

of sclerophyll forests and woodlands. 

This species may occur along 

Table 6.6 

Habitat quality 

Unit Option Location Habitat Quality Description 

A 4 (Minerva and Otway) Great Ocean Road 

adjacent to HDD site 

High 

Most habitat elements of this vegetation type are intact. 

Same habitat and quality as that within the Port 

Campbell National Park on the south side of the Great 

Ocean Road 

B 4 (Minerva) Sharps Road Low Dominated by exotic vegetation with some native sheoaks 

C 4 (Minerva) Brumby’s Road Low South side of road has dense stand of tea-tree while 

northern side is exotic pines 

D 4 (Minerva) Curdie Vale to Port 

Campbell Road 

Moderate – 

High 

Relatively intact heathy woodland but with sweet 

pittosporum invading 

E 4 (Minerva) North South Road Low Heavily disturbed, dominated by exotic grasses with 

some native shrubs 

F 4 (Otway) Curdie Vale to Port 

Campbell Road 

G 4 (Otway) Remnant patch on private 

land south of Smokey 

Point Rd 

Moderate – 

High 

Moderate 

Reasonably intact with some large trees but with sweet 

pittosporum invading 

Lack of large trees, lots of fallen timber from tree 

felling, high cover of blackberry in areas 

H Sub-Option 4A Smokey Point Road Low Route crosses road in a cleared section approximately 

50 m in width. High cover of blackberry. Outside 50 m 

cleared area canopy reasonably intact but lots of 

blackberry in understorey. 

I Sub-Option 4A Cheynes Road South Low Crosses an area highly disturbed with some scattered 

trees. 

J Sub-Option 4A & B Campbells Creek Low Creek side has been highly disturbed, riparian 

vegetation consists of scattered blackwoods and 

sedges. 

K Sub-Option 4A & B Disused road reserve 

east of Cobden to Port 

Campbell Road 

Low 

Area of trees in paddock with pasture grasses forming 

understorey. Trees showing signs of stress. 

L Sub-Option 4B & C Smokey Point Road Moderate Reasonably intact canopy with some blackberry in the 

understorey, few hollow bearing trees. 

M Sub-Option 4B & C Link of revegetation 

between patches on 

private property 

Low 

Linear patch of revegetation approximately 15 years 

old. No mature trees, few weeds. 

N Sub-Option 4C Campbells Creek Low Riparian vegetation contains scattered eucalypts and 

blackwoods with high cover of blackberries in areas. 

O Sub-Option 4C Cobden to Port Campbell 

Road 

Low 

Some scattered blackwoods with exotic trees, shrubs 

and pasture grasses. 

P Sub-Option 4A Smokey Point Road Moderate Reasonably intact canopy and understorey, few hollowbearing 

trees. 

Q Sub-Option 4A Cheynes Road South Moderate Reasonably intact canopy with dense blackberry 

understorey and few hollow-bearing trees. 



the Curdie Vale to Port Campbell 

Road where heathy vegetation is 

present. 

• Australasian shoveler, hardhead and 

great egret (aquatic birds): may be 

found in farm dams in the vicinity of 

the project area. These species are 

listed as ‘vulnerable’ in Victoria. 

Reptiles were also surveyed in the study 

area. Only the common blue-tongued lizard 

was observed. One reptile species 

has been recorded in the AVW within the 

project area that is of state significance 

(but was not recorded during the current 

survey): 

• Swamp skink: Recorded from Port 

Campbell National Park and listed as 

‘vulnerable’ in Victoria. This species 

is known to occur in the margins of 

low-lying areas with sedges and 

stands of melaleucas. 

During the survey, no frog callings were 

heard whilst spotlighting. One frog species 

recorded in the AVW from within the 

project area that is of state conservation 

significance is: 

• Southern toadlet: most records are 

from the Loch Ard Gorge area, however 

there are also records from 

Curdie Vale to Timboon Road. The 

species is listed as ‘vulnerable’ in 

Victoria and is known to occur in 

damp areas of sclerophyll forests, 

woodlands, heathlands and 

grasslands. 

Aquatic fauna previously recorded in 

Campbells Creek (Yugovic et al., 2003 

cited in BLA, 2004) include: 

• Short-finned eel (Anguilla australis). 

• Common galaxias (Galaxias 

maculatus). 

• Spotted galaxias (Galaxias truttaceus). 

• Southern pygmy perch (Nannoperca 

australis). 

Of the four native species known to occur 

in the freshwater environments of 

the project area, none are considered 

threatened at the State or Commonwealth 

level. No platypus, freshwater 

crayfish or tortoises are known in the 

project area. 

There were no exotic fish species captured 

in Campbells Creek in the Yugovic 

et al. (2003) study (cited in BLA, 2004). 

Other nearby creeks; Eastern, Squirrel, 

Wallaby and Spring creeks, were found 

to have a similar fish fauna to that of 

Campbells Creek (Yugovic et al., 2003, 

cited in BLA, 2004). 

The project area has been substantially 

modified from its pre-European condition 

through clearing of most of the vegetation 

for agricultural land use. Native 

vegetation within the study area is now 

largely confined to the Port Campbell 

National Park, roadsides and scattered 

patches on private land. 

The fauna conservation significance of 

each of the identified units (see Figure 

6.6) of native vegetation intersected by 

all of the route options and sub-options 

identified in Section 5 is outlined below 

in Table 6.7. The impact assessment 

and mitigation measures focus on the 

selected preferred route alignment (Option 

4 (Otway) and Sub-option 4A). 


The potential impacts to vegetation and 

flora species as a result of the onshore 

pipeline construction and operation include: 

• Vegetation loss and fragmentation. 

• Weed invasion. 

• Loss of significant species. 

• Disturbance to ecologically sensitive 

sites. 

The potential impacts to fauna as a result 

of the onshore pipeline construction 

and operation include: 

• Habitat loss. 

• Disturbance to species of conservation 

significance. 

• Species disturbance, injury and/or 

mortality. 

• Sedimentation of watercourses. 






Impacts 

Alignment selection of the proposed pipeline 

was the single most important mitigation 

measure employed by the project 

in minimising impacts to flora and fauna. 

A preferred alignment was selected following 

an assessment of the route options 

(see Section 5.5.3). This section 

details the assessment of potential ecological 

impacts on the preferred alignment 

(Option 4 (Otway) and Sub-option 

4A) and describes proposed mitigation 

and management measures. 

Table 6.8 outlines the potential impacts 

and mitigation measures that will be employed 

to minimise impacts. Figures 6.8 

to 6.13 and Plates 6.3 to 6.9 provide 

details of site conditions and mitigation 

measures. 

Flora 

Vegetation Loss and Fragmentation. 

Because the HDD shore crossing will 

drill below the surface of Port Campbell 

National Park, the only native vegetation 

that will be cleared by the proposed 

project is limited to remnant roadside 

vegetation. Minor trimming (no clearing) 

of vegetation within the park may be 

required for setting out the “Tru-Trak” 

survey system (see Section 5.4.3). Careful 

selection of the pipeline alignment 

has made it possible to avoid significant 

stands of native vegetation. Table 6.9 

provides a summary of the likely residual 

impacts of pipeline construction to vegetation 

units identified along the proposed 

route. 

Preliminary habitat hectare scores (see 

Section 6.8.1) of each vegetation unit 

have been calculated (BLA, 2004) and 

are presented in Table 6.8. These scores 

are preliminary and will be finalised following 

on-site review of the project alignment 

by DSE representatives and 

subsequent completion of detailed design. 

Habitat hectare scores are only calculated 

on Category 1 vegetation, and 

are reported as a score out of one (0.1 

representing a low habitat hectare score 

[vegetation in poor condition] and 0.9 

representing a high habitat hectare score 

[vegetation in very good condition]). 

ROW construction will require the clearance 

of some trees and shrubs to maintain 

a clear ROW for safe construction 

access and working conditions. Any 

cleared vegetation will be retained on 

site and respread over the ROW during 

rehabilitation, subject to agreement with 

the landholder. 

Proposed impact mitigation and management 

measures include: 

• Where possible, align the pipeline 

route through existing breaks in roadside 

vegetation. 

• Align the pipeline route through 

roadsides at points of disturbed or 

low quality vegetation. Where road- 



side native vegetation is to be removed, 

the width of the construction 

ROW will be narrowed from 24 m to 

5 m (see Figures 6.10 and 6.11). 

• Determine a method for laying the 

“Tru-Trak” sensing cable and minimising 

vegetation trampling within 

Port Campbell National Park in consultation 

with Parks Victoria. 

• Where it is necessary to cross 

roadsides that support higher quality 

native vegetation (e.g., Category 1 

vegetation), then these crossings will 

be drilled by HDD, such as at the 

proposed crossing of the Curdie Vale 

to Port Campbell Road (see Figure 

6.9). 

• Avoid areas of vegetation and tree 

clusters in farm paddocks. 

• Clearing of native vegetation at 

Campbells Creek will be restricted to 

those individuals directly over the 

trench, where practicable (see Figure 

6.12). 

Table 6.7 Fauna conservation significance 

Unit 

No. 

A 

4 (Minerva and 

Otway) 

Option Description Fauna 

Conservation 

Significance 

Comments 

Great Ocean Road National Southern brown bandicoot and rufous bristlebird recorded in 

Port Campbell National Park. Potential occurrence of 

chestnut-rumped heathwren and white-footed dunnart within 

and adjacent to the park. These species may potentially 

occur in habitat on this roadside. 

B 4 (Minerva) Sharps Road Local Unlikely to support species of higher than local conservation 

significance. 

C 4 (Minerva) Brumby’s Road Local Unlikely to support species of higher than local conservation 

significance. 

D 4 (Minerva) Curdie Vale to Port 

Campbell Road 

State 

Known to support rufous bristlebird 

E 4 (Minerva) North South Road Local Unlikely to support species of higher than local conservation 

significance. 

F 4 (Otway) Curdie Vale to Port 

Campbell Road 

G 4 (Otway) Remnant patch on 

private land south of 

Smokey Point Rd 

State 

Local 

Known to support rufous bristlebird, previous studies 

identified likely southern brown bandicoot habitat 

Unlikely to support species of higher than local conservation 

significance. 

H Sub-Option 4A Smokey Point Road Local Unlikely to support species of higher than local conservation 

significance. No direct vegetated link to Port Campbell 

National Park. 

I Sub-Option 4A Cheynes Road South Local Unlikely to support species of higher than local conservation 



J Sub-Option 4A & B Campbells Creek Local Unlikely to support species of higher than local conservation 

significance. 

K Sub-Option 4A & B Disused road reserve 


Campbell Road 

Local 


significance. 

L Sub-Option 4B & C Smokey Point Road Local Unlikely to support species of higher than local conservation 



M Sub-Option 4B & C Link of revegetation 

between patches on 

private property 

Local 


significance. 

N Sub-Option 4C Campbells Creek Local Unlikely to support species of higher than local conservation 

significance. 

O Sub-Option 4C Cobden to Port 

Campbell Road 

Local 


significance. 

P Sub-Option 4A Smokey Point Road Local Unlikely to support species of higher than local conservation 



Q Sub-Option 4A Cheynes Road South Local Unlikely to support species of higher than local conservation 





• Development of a rehabilitation plan 

for areas of native vegetation, in consultation 

with DSE (and Parks Victoria 

in the case of revegetation in the 

Port Campbell National Park, should 

it be required). 

• Revegetating disturbed areas of native 

vegetation with a mix of indigenous 

species that reflect the original 

EVC of the site as soon as possible 

following construction. 

• Revegetated areas will be monitored 

for success and additional works undertaken 

as required. 

Weed Invasion. Environmental weeds 

identified in the project area include 

dense stands of woody weeds found on 

roadsides and along streams and drainage 

lines mostly dominated by blackberry 

(Rubus spp.), hawthorn (Crataegus 

sp.) and sweet pittosporum (Pittosporum 

undulatum). 

Although most of the project area is 

cleared and is therefore dominated by 

introduced grasses and other plants, 

there is still the potential for the spread 

of weeds into areas of native vegetation 

during construction activities. This can 

be caused by earth moving equipment 

and other vehicles. 

Mitigation measures for the avoidance 

of weed invasion include: 

• Washing down of all construction 

machinery prior to initially entering 

the project construction zone and at 

regular intervals (as required) to prevent 

the introduction and spread of 

weeds and soil pathogens. 

• Revegetating disturbed areas as soon 

as practicable after construction to 

provide vegetation that will out-compete 

weed growth. 

• Post-construction weed monitoring 

and control (for up to five years) to 

minimise noxious weeds colonising 

disturbed areas (e.g., spraying fruiting 

blackberries at roadsides) and 

maximise survival of revegetated areas. 

Detailed hygiene procedures (including 

those for access to Port Campbell National 

Park) will be outlined in the environmental 

management plan (see also 

Section 6.11.3). 

Loss of Significant Species. There is 

potential, albeit minor, for some disturbance 

to the Port Campbell guinea flower 

(Hibbertia truncata) at the Great Ocean 


Port Campbell 

National Park 

Coast gully thicket 

and damp heath 

scrub vegetation 




HDD crossing 

Figure 6.8 

35m wide ROW 

(shared HDD pipe 

laydown and mainline 

pipeline ROW) 

Temporary HDD 

site access 

Umbilical 

Pipeline 

Road (creation of temporary HDD and 

permanent MLV access tracks), and at 

the trenched road crossings at Smokey 

Point Road and Cheynes Road South. 

Whilst reductions of this population are 

not likely to be significant (because the 

species is well represented in the Port 

Campbell National Park), prior to construction, 

a spring search for the presence 

of threatened species (that were 

not detectable during the late-summer 

survey), and in particular the the Port 

Campbell guinea flower, will be undertaken 

in vegetation to be cleared for the 

project. Appropriate mitigation measures 

will then be implemented in consultation 

with DSE to avoid or minimise impacts to 

these species. Road crossings at 

Smokey Point Road and Cheynes Road 

South will be reduced from 24 m to 5 m 

in width to avoid impacting roadside habitat. 

The temporary HDD access track 

HDD shore 

crossing site 

MLV site 

access 


Fishing 

Track 

Road 

reserve 

Park boundary 


0 100 200 

Meters 

will be revegetated with indigenous species 

following construction. 

Disturbance to Ecologically Sensitive 

Vegetation. Key areas of sensitivity identified 

along the proposed pipeline route 

include: 

• Curdie Vale to Port Campbell Road, 

containing remnant vegetation. 

• Remnant patch of forest vegetation 

on private land south of Smokey Point 

Road. 

• Cheynes Road South , containing native 

vegetation. 

Fauna 

Mitigation measures for impacts to fauna 

are arrived at through appropriate pipeline 

route selection to avoid significant 

habitat areas. Additional to this, the following 

mitigation measures can be employed 

to further reduce impacts. 

N 



Curdie Vale – Port CampbellRoad 

Langleys Road 

Courtesy of Ian A. Gordon 

Plate 6.3 West side of the Curdie Vale to Port 

Campbell Road HDD road crossing location 

Remnant damp 

heathy woodland 

roadside vegetation 




HDD crossing 

Figure 6.9 


0 100 200 

Meters 

Curdie Vale to Port Campbell Road HDD crossing 

N 


Plate 6.4 East side of the Curdie Vale to Port 

Campbell Road HDD road crossing location 

Remnant heathy 

woodland roadside 

vegetation 

Farm dam 


Remnant stands 

of lowland forest 

avoided by the 

pipeline route 

alignment 


Plate 6.5 North side of the Smokey Point Road 

crossing location. Note the predominantly weedy 






Figure 6.10 


0 100 200 

Meters 

Smokey Point Road open trenched crossing 

N 


Plate 6.6 South side of the Smokey Point Road road 

crossing location, heavily infested with blackberries 



Degraded lowland 

forest and exotic 




Plate 6.7 South side of the Cheynes Road South road 

crossing location. Little, if any, of this native vegetation 

will be cleared to accommodate the ROW 

Remnant lowland 

forest 




Figure 6.11 


0 100 200 

Meters 

Cheynes Road South open trenched crossing 

N 


Plate 6.8 North side of the Cheynes Road South road 

crossing location. Note the predominantly weedy 

vegetation and sparse native overstorey 

Camerons Hill Road 

Campbells 

Degraded native 

and exotic riparian 

vegetation 

Creek 


Plate 6.9 Campbells Creek crossing location, adjacent 

to the recently constructed SEAgas pipeline 

Tregea Road 





Creek 

0 100 200 

Meters 

N 

Figure 6.12 

Campbells Creek open trenched crossing 



Habitat Loss. 

• Parallel existing easements where 

practicable to minimise habitat loss. 

• Select gaps along roadside remnant 

vegetation through which to align the 

pipeline to reduce habitat disturbance. 

• Select temporary HDD and permanent 

MLV access tracks to minimise 

clearing of structural habitat elements 

in the roadside vegetation (e.g., trees) 

and revegetation of the HDD access 

track with a mix of indigenous species 

representative of the original 

habitat type. 

• Minimise construction traffic through 

sensitive areas. 

• The Campbells Creek crossing will 

be constructed at a time of low flow 

so that it does not significantly impede 

water or fish movement. 

Species of Conservation Significance. 

As a result of the temporary nature of 

pipeline construction (about 2 months) 

and by avoiding remnant native vegetation 

on private land (where practicable), 

potential effects on species of conservation 

significance are expected to be minimised. 

Mitigation measures to be 

employed to reduce the impacts to fauna 

species of conservation significance are 

based on avoiding or minimising habitat 

loss (see Tables 6.7, 6.8 and 6.9). 

Species Disturbance, Injury and/or 

Mortality. Mitigation options to minimise 

faunal injury or mortality include: 

Cobden – Port Campbell Road 




HDD crossing 

Figure 6.13 

Remnant lowland forest 

Unused road reserve 


0 100 200 

Meters 

Cobden to Port Campbell Road HDD crossing 

N 

• Minimising the period and length of 

time that the trench remains open, 

particularly in areas where sensitive 

habitat has been identified nearby. 

• Daily monitoring of open sections of 

trench at regular intervals for trapped 

animals such as reptiles and small 

ground-dwelling mammals, particularly 

in areas where sensitive habitat 

has been identified. 

• Keeping trench plugs in place to allow 

the movement of fauna across 

the open trench. 

• Constructing trench plugs with slopes 

no greater than 50% at regular intervals 

along the pipeline trench to provide 

ramps for fauna exit. 

• Restrict traffic along the temporary 

HDD access track to essential vehicles 

only and adopt a safe speed 

limit to minimise the potential for collision 

with fauna moving through the 

roadside vegetation. 

• Report injured or dead wildlife within 

construction sites to regional DSE 

personnel. 

• Helicopter flights to the pipelay vessel 

will be infrequent (two to three 

times per week) during pipelay, will 

take higher altitude flight paths (minimum 

altitude of 1,000 m) than existing 

tourism helicopter services 

operating out of Port Campbell, and 

are highly unlikely to impact terrestrial 

or marine avifauna in the project 

area that may be habituated to helicopter 

noise. 

• Night time lighting at the HDD site is 

not expected to significantly impact 

fauna as it will be short-term (about 

three months) and buffered from key 

habitat within the Port Campbell National 

Park by the Great Ocean Road. 

Sedimentation of Watercourses. Mitigation 

measures to minimise or eliminate 

impacts to water quality, and 

therefore to freshwater fauna, are discussed 

previously in Sections 6.6 and 

6.7. 

6.9 Aboriginal Heritage 

The Framlingham Aboriginal Trust was 

engaged by Santos to project manage 

the Aboriginal cultural heritage assessment 

who in-turn engaged consulting archaeologists, 

Andrew Long and 

Associates (ALA) to conduct the study 

(ALA, 2004). The following is a summary 

of findings from the study. 


The area surveyed during the study was 

limited by the need to systematically survey 

the range of landforms present and 

to survey areas with high surface visibil- 



Table 6.8 

Summary of proposed mitigation measures and residual impacts on native vegetation 

Vegetation 

Unit 

Location 

Vegetation 

Type (1-6) 

Habitat 

Hectare 

Score # 

Mitigation Measures and Residual Impact 

A Great Ocean Road 1 N/A^ Temporary HDD access track will be a maximum of 6 m wide 

and permanent MLV access track will a maximum width of 3 m 

(Figure 6.8). MLV access track will be located on area of 

previous disturbance (former track) where practicable. 

Revegetation of temporary HDD access track with indigenous 

species. 

F 

G 

Curdie Vale to Port 

Campbell Road 

Remnant patch on 

private land south of 


2 0.44 Removal of heathy woodland vegetation will be avoided using 

HDD/boring techniques. No fragmentation of continuous 

roadside vegetation expected (Figure 6.9 and Plates 6.3 and 

6.4). 

3 and 6 0.47 Possible loss of forest vegetation, however, pipeline route was 

realigned to avoid remnant vegetation. 

P Smokey Point Road 4 0.41 Cleared exotic areas exist in road reserve but some native 

vegetation may require removal (1 to 2 small trees) (Figure 6.10 

and Plates 6.5 and 6.6). 

Q Cheynes Road South 3 and 6 0.34 Minor potential impact on native vegetation. Some areas of 

exotic vegetation also exist (Figure 6.11 and Plates 6.7 and 6.8). 

J Campbells Creek 5 and 6 N/A* Highly degraded area adjacent to existing pipeline. Potential for 

minor unavoidable loss of native plant species (1 to 2 small 

trees) (Figure 6.12 and Plate 6.9). 

K 

Disused road reserve 


Campbell Road 

5 and 6 N/A* Well-established direct seeded vegetation and small, scattered 

trees may require removal. 

* Vegetation units J and K are Category 2 vegetation types and cannot be assessed for habitat hectares. 

# 

These habitat hectare calculations were based on averaging the habitat quality of each vegetation unit (50 m either side of the pipeline route options) and 

are therefore likely to be considerably higher scoring than the actual vegetation to be cleared. The vegetation to be intersected at the Smokey Point Road 

and Cheynes South Road crossings and Campbells Creek are of lower quality than surrounding vegetation and road crossing vegetation clearance will be 

reduced to a 5 m ROW where significant vegetation is present. A quantification of potential losses and Net Gain offset requirements will be recalculated, if 

necessary, in a subsequent Net Gain assessment for the specific vegetation parcels required to be cleared. 

^ The habitat hectare score for vegetation unit A will be calculated when the sites of the temporary HDD access track and permanent MLV access track are 

decided by Santos in consultation with DSE. 

ity. Pasture grasses cover most of the 

study area and this affected ground surface 

visibility and decreased the effectiveness 

of the survey accordingly. 

However, parts of the eastern section of 

the study area had high ground surface 

visibility due to the recent installation of 

the SEAgas pipeline and that easement 

was almost all clear of vegetation and 

grass cover. The Aboriginal heritage survey 

was carried out in conjunction with 

the historical heritage survey (Section 

6.10). 


Historical Background 

At the time of European contact, regional 

Aboriginal populations were organised 

into small bands that were associated by 

language into larger tribe-like groups, with 

land boundaries generally defined by 

drainage basins. 

The Port Campbell area is thought to 

have been occupied by clans from the 

Girai Wurrung language group. They occupied 

the area between the Gellibrand 

River and the Hopkins River, extending 

inland as far as Hamilton. Closest to the 

study area were the Ngaragurd Gundidj 

clan who occupied land to the east of 

Curdies River. 

There is a lack of documented information 

relating to the Girai Wurrung people; 

however, it is thought that their lifestyle 

was one of hunting and gathering, moving 

from one location to the next to make 

use of seasonal resources, and trading 

opportunities and meeting ritual and kinship 

obligations. 

European settlement changed the local 

Aboriginal population and subsistence 

patterns dramatically. The permanent 

settlement by European colonialists 

brought about a decline in the Aboriginal 

population in the Port Campbell and 

Western Plains region. The Aboriginal 

people began to live in the fringes of 

towns such as Warrnambool, in search 

of food and other basic food items. They 

were later moved to Framlingham Aboriginal 

Mission, in western Victoria, when 

it opened in 1865. 

Survey Results 

Eleven Aboriginal Affairs Victoria registered 

sites occur within 4 km of the project 

area comprising stone artefacts (surface 

scatters and isolated stone artefacts) 

which occur on disturbed surfaces (such 

as dam walls, tracks etc.) or during the 

monitoring of construction works. Most 

of these sites have been recorded as 

part of archaeological assessments of 

proposed developments in the region. 

The sites were identified in a range of 

landforms within the Port Campbell Plain 



Table 6.9 Potential impacts to flora and fauna habitat and actions for avoidance and minimisation 

Vegetation 

Type (1 -6) 

Potential Impact Actions to Avoid and Minimise 

Impacts 

Mitigation Measures 

1 Removal of damp heath scrub 

vegetation for temporary HDD and 

permanent MLV access tracks, 

fragmenting roadside vegetation. 

Maximum clearing width for temporary 

HDD access track will be 6 m and 3 m 

for permanent MLV access track (see 

Figure 6.8). 

Spring search for Port Campbell guinea flower 

(Hibbertia truncata) and impact avoidance 

measures put in place in consultation with DSE. 

Revegetation of the temporary HDD access track 

with indigenous species. Locate permanent MLV 

access track on area of previous disturbance 

(former track), where practicable. 

2 Removal of heathy woodland vegetation 

will be avoided through using HDD 

techniques. No fragmentation of 

continuous roadside vegetation likely. 

All works should be conducted from 

exotic pasture on adjoining private land 

or road verge areas void of native 

vegetation (see Figure 6.9). 

Ensure HDD depth is sufficient to avoid substantial 

impact to root zone of vegetation. 

3 and 6 Possible loss of several trees within 

forest vegetation. 

Align pipeline route to west of this patch 

of forest. Minimise width of disturbance if 

necessary. 

Pipeline re-aligned to avoid vegetation patch. 

4 Cleared exotic areas exist in road 

reserve but some native vegetation may 

require removal. No loss of habitat for 

significant fauna species. 

Align pipeline through exotic vegetation 

(see Figure 6.10). 

Minimise width of disturbance. Spring search for 

Port Campbell guinea flower (Hibbertia truncata) 

and impact avoidance measures put in place in 

consultation with DSE. 

3 and 6 Potential impact on native vegetation. 

Some areas of exotic vegetation also 

exist. No loss of habitat for significant 

fauna species. 

Align pipeline through exotic vegetation 

(see Figure 6.11). 

Minimise width of disturbance. Spring search for 

Port Campbell guinea flower (Hibbertia truncata) 

and impact avoidance measures put in place in 

consultation with DSE. 

5 and 6 Highly degraded area adjacent to 

existing pipeline. Some impacts on 

scattered native plant species possible. 

Avoid remnant and regrowth trees where 

possible (see Figure 6.12). 

Minimise width and duration of disturbance during 

open trenching. 

5 and 6 Well-established direct seeded 

vegetation and small scattered trees 

may require removal. 

Minimise width of disturbance. Minimise width of disturbance. 

Vegetation 

Unit 

Description/L 

ocation 

A Great Ocean 

Road 

F Curdie Vale to 

Port Campbell 

Road 

G Remnant 

patch on 

private land 

(Loft) south of 

Smokey Point 

Rd 

P Smokey Point 

Road 

Q Cheynes Road 

South 

J Campbells 

Creek 

K Disused road 

reserve east of 

Cobden to 

Port Campbell 

Road 



including flat land, hill slopes, valleys 

and creek banks. Sites in the Port 

Campbell region, away from the coast, 

tend to contain isolated stone artefacts 

or diffuse scatters of stone artefacts located 

either on or within shallow subsurface 

deposits (i.e., less than 10 cm). 

Most of the stone artefacts are made 

from flint and quartz, although other raw 

materials have been identified. 

One Aboriginal site (AAV 7520-174) was 

identified in the area studied by ALA 

(2004). It contains a single silcrete flaked 

stone artefact located on a steep valley 

slope, 300 m east of Campbells Creek. 

This artefact was found due to its visibility 

on the easement of the recently constructed 

SEAgas pipeline. No other 

cultural material was found in the area 

making it difficult to interpret the significance 

of this artefact. 

Two broad zones of archaeological sensitivity 

were identified during the field 

survey and these are described below: 

Zone 1–Moderate Sensitivity. This zone 

is located on the margin and valley slopes 

of Campbells Creek. Sites of Aboriginal 

significance in the area are likely to have 

been disturbed by land use practices in 

the area, however there is potential for 

some sites to be in good condition. This 

is particularly true for sites adjacent to 

Campbells Creek where alluvial deposits 

have been generally less impacted. 

Zone 2–Low to Moderate Sensitivity. 

This zone covers the remaining study 

area and has been impacted by land 

clearing and pastoral land use activities 

as well as other gas easements. While 

no Aboriginal sites were identified in this 

zone, sites have previously been identified 

within similar landforms in the wider 

Port Campbell Coastal Plain area. However, 

all sites in this area are likely to 

have been disturbed by past land use 

practices and there is little potential for 

intact sites in this zone. 


Potential impacts to Aboriginal sites of 

importance may include: 

• Construction of the onshore pipeline 

poses the greatest potential risk to 

impacting Aboriginal sites of importance. 

Clearing and grading the pipeline 

easement has the potential to 

impact on both known and unknown 

Aboriginal cultural heritage material. 

• Additional construction related vehicle 

movement outside of the easement 

or in the area of the newly 

recorded site (AAV 7520-174) may 

also impact on Aboriginal sites of importance. 

• Stockpiling of soil during the excavation 

of the easement may bury uncovered 

artefacts. 


Measures 

Measures to minimise the impact of pipeline 

construction on Aboriginal archaeological 

sites will include: 

• Formulation of a cultural heritage protocol 

in consultation with the 

Framlingham Aboriginal Trust to manage 

aboriginal heritage sites during 

the construction phase. The protocol 

is expected to include: 

– Conduct of further surveys prior 

to construction, as required, to 

identify culturally significant sites 

in previously unsurveyed areas 

(i.e., route changes) and in archaeologically 

sensitive areas 

where conditions of ground surface 

visibility or exposure prevented 

the detection of sites 

during this assessment. This may 

involve subsurface testing. All survey 

work will be conducted in consultation 

with, and will include 

on-site representation by, 

Framlingham Aboriginal Trust. 

– Establishment of an appropriate 

buffer zone around the one recorded 

site (AAV 7520-174) and 

any new cultural heritage sites 

identified to reduce the risk of impact 

in co-operation with 

Framlingham Aboriginal Trust. If 

impacts to Aboriginal sites of importance 

cannot be avoided, 

Santos will apply for consent to 

disturb. 

– Engagement of Framlingham 

Aboriginal Trust representatives 

during construction to monitor initial 

clearing and grading activities 

for the presence of sub-surface 

artefacts and to assist in implementing 

and reviewing Aboriginal 

heritage site management measures. 

– In the event of cultural material 

being uncovered during construction, 

the following actions will be 

followed: 

– Framlingham Aboriginal Trust representatives 

will immediately notify 

the machinery operator(s) who 

shall immediately stop work at that 

location. 

– Machinery will be moved an appropriate 

distance from that site 

(a minimum distance of 60 m) 

where it may recommence work 

with Framlingham Aboriginal Trust 

representatives in attendance. 

– An archaeologist will assess the 

site and work with the 

Framlingham Aboriginal Trust and 

Santos to establish appropriate 

management strategies. 

• Protect registered sites through careful 

selection of locations for off-easement 

activities such as equipment 

laydown areas. Exclusion areas will 

protect known sites. 

• Restrict and monitor construction activities 

in areas that have moderate 

archaeological potential, where cultural 

heritage material may be exposed 

during construction (e.g., 

Campbells Creek). 

• Consultation with Aboriginal Affairs 

Victoria, before and during construction, 

regarding the protection of cultural 

heritage values and to advise 

on the discovery of any new sites 


• An archaeologist will be on call if 

cultural heritage material is detected. 

The archaeologist will assist the 

Framlingham Aboriginal Trust representatives 

to record any uncovered 

cultural material, in accordance with 

Aboriginal wishes and Aboriginal Affairs 

Victoria requirements. They will 

also be able to provide management 

advice and if necessary, make arrangements 

for consent to disturb the 

site. 

• Training of all project personnel 

(Santos and contractors) to ensure 

they are aware of their responsibilities 

and procedures for managing 

Aboriginal cultural heritage. In particular, 

all project personnel (Santos 

and contractors) will be advised of 

the general location of Aboriginal sites 

and areas of archaeological sensitivity 

so as to reduce the likelihood of 

damage to sites/sensitive areas. 




The landscape traversed by the onshore 

pipeline alignment is highly modified and 

consequently lacks intact Aboriginal heritage 

sites. It is highly unlikely that construction 

or operation of the Casino Gas 

Field Development will impact significantly 

upon Aboriginal heritage sites. 

6.10 Historical Heritage 

Andrew Long and Associates Pty Ltd 

(ALA) were also engaged by Santos to 

undertake an assessment of potential 

impacts of the project on matters of historical 

heritage significance (ALA, 2004). 

The following is a summary of findings 

from their study. 

6.10.1 Methodology 

Field surveys detailing the historical archaeological 

aspects of European settlement 

in the Port Campbell region were 

conducted over two days along the proposed 

pipeline alignments. These were 

conducted in conjunction with Aboriginal 

cultural heritage field surveys. The information 

presented is derived from the field 

observations and a desktop study. The 

desktop study included searches of the 

Victorian Heritage Inventory, the Victorian 

Heritage Register, the Register of 

the National Estate and the Register of 

the National Trust to determine locations 

Table 6.10 

Development 

Works 

Minerva Project 

Minerva gas 

treatment plant 

South Western 

Natural Gas 

Pipeline Project 

Southern Gas 

Pipeline 

Otway Gas 

Project 

SEAgas 

Natural Gas 

Pipeline 

of historical sites in the vicinity of the 

study area. 


Historical Background 

The identified phases of non-indigenous 

exploration and settlement history include 

the following: 

• Exploration. 

• Sealing and whaling. 

• Squatting. 

• Land selection. 

• Development of local industries. 

• Maritime history. 

Sites relating to activities associated with 

the settlement patterns and agricultural 

practices in the area are the most common 

site types encountered in the area. 

Previous Survey Results 

Numerous historical archaeological studies 

have been undertaken in the study 

area as part of heritage assessments of 

major development works, predominantly 

other gas pipelines, which partially share 

alignments with the proposed Casino Gas 

Field Development. Table 6.10 below 

provides a brief summary of their findings: 

Current Survey Results and 

Conclusions 

Historical Heritage. There are no previously 

registered historical sites within the 

Previous historical research undertaken in the vicinity of the study 

area 

Survey 

Location 

Port 

Campbell 

coastline and 

6.5 km inland 

Refined 

corridor 

Iona to Port 

Campbell 

section 

Victorian 

section 

Pipeline 

route in Port 

Campbell 

area (Curdie 

Vale to Port 

Campbell 

Road) 

Iona Gas 

Plant to 

Macarthur 

Historical Sites Significance Author 

H 7420-1: Port 

Campbell 

Racecourse/Rifle 

Range 

Low 

Brown, 1996a 

cited in ALA 

2004 

None recorded None Brown, 1996b 

cited in ALA 

2004 

None recorded Low Lane, 1996 

cited in ALA 

2004 

None recorded 

H 7420-4: 

Thatchleigh Park; 

H 7420-3: 

Wiggins Bridge 

H 7321-22: series 

of stone 

foundations found 

on Moyne River 

Low to 

moderate 

Moderate 

scientific and 

local heritage 

HCA, 2001 

cited in ALA 

2004 

Nicolson et al., 

2003 cited in 

ALA 2004 

Not stated Wood 2003 

cited in ALA 

2004 

study area and none were located during 

the field survey of ALA (2004). No 

zones of historic archaeological sensitivity 

have been identified. 

The study area is believed to have primarily 

been used for pastoral and agricultural 

purposes since c.1840s. These 

activities are unlikely to have involved 

the construction of many significant historical 

features. 

Maritime Historical Heritage. The Victorian 

Heritage Inventory, Victorian Heritage 

Register, Register of the National 

Estate and Register of the National Trust 

were examined to determine locations of 

registered shipwrecks along the coast 

within a 15 km radius of the notional 

offshore pipeline route. There were six 

shipwrecks listed however these were 

all some distance from the proposed pipeline 

route. Table 6.11 lists the shipwrecks 

sites in the vicinity of the offshore pipeline. 


Potential impacts to historical heritage 

sites may potentially originate from onshore 

construction activities (such as 

clearing and grading, trenching, horizontal 

directional drilling, ancillary facilities 

and access tracks) or installation of the 

offshore pipeline. 

The greatest potential for impact relates 

to disturbing previously unrecorded heritage 

sites. Historical archaeological features 

often include subsurface deposits 

and occupation sites, many of which cannot 

be detected until ground clearing and/ 

or excavation has occurred. Albeit a lowrisk, 

the potential exists for historic sites 

or artefacts to be uncovered during construction 

earthworks. 



Impacts 

No sites of historical significance were 

identified on land in the vicinity of the 

study area and the closest shipwreck to 

the offshore pipeline, the Napier, is located 

3 km away from the proposed offshore 

pipeline alignment. 

Impacts to known historic heritage sites 

are unlikely to occur. The following mitigation 

measures will be implemented to 

minimise the potential impacts to previously 

unrecorded heritage sites: 

• Training shall be undertaken for all 

project personnel (Santos and contractor) 

to assist in the identification 

of potential historic artefacts during 



Register 

VHR S417 

RNE PLACE ID 

3780 

Table 6.11 Shipwrecks within 15 km of the proposed offshore pipeline route 

Shipwreck 

Name 

Date Lost 

Distance from Proposed 

Pipeline Route 

Location 

Loch Ard 1/6/1878 9 km Off Mutton Bird Island, south east of Port Campbell 

RNE Place ID 3933 Schomberg 6/1/1856 7 km 1 km south east of Peterborough 

VHR S483 Napier 19/9/1878 3 km West side of the cove on the east bluff of Port 

Campbell 

VHR S34 Antares Nov 1914 13 km Bay of Islands 

VHR S488 Newfield 29/8/1892 6 km 1.5 km east of Curdies Inlet 

VHR S255 Falls of Halladale 14/11/1908 10 km Massacre Bay 

construction and to ensure they are 

aware of their responsibilities and procedures 

for managing such finds. 

• Protocols to manage historic heritage 

material identified during construction 

shall be established. In the 

event of cultural material being uncovered, 

work will cease at that location 

and an appropriate buffer will be 

established to protect the site. An 

archaeologist will assess the site, and 

work with Santos and Heritage Victoria 

to establish an appropriate management 

strategy for the site. 


Impacts to known historic heritage sites 

are unlikely to occur. 

6.11 Land Use and 

Infrastructure 

This section describes the existing onshore 

land use and infrastructure setting 


project area, with a focus on areas along 

the proposed pipeline route. The potential 

impacts to land use and infrastructure 

are assessed and mitigation and 

management measures for the impacts 

are described. 


Land Use 

The onshore project area is comprised 

predominantly of agricultural land. The 

other main land uses in the study area 

are the Port Campbell National Park, the 

Port Campbell township, and petroleum 

exploration, production and processing. 

At a regional level, agriculture remains 

the dominant land use, accounting for 

66% (851,507 ha) of the land in the 

Corangamite region. The main agriculture 

in the region is dairy, cropping and 

beef and veal cattle, which accounted 

for 44%, 21% and 15% respectively of 

Corangamite’s total value of agricultural 

commodity production in 1998/99 

(CCMA, 2003). 

Land Use Travelogue. The pipeline 

alignment extends from offshore, under 

the Port Campbell National Park at Two 

Mile Bay by HDD, then exits on private 

farmland on the northern side of the Great 

Ocean Road, about 2 km west of Port 

Campbell. The Port Campbell National 

Park is State-owned Crown Land which 

is licensed to the Commonwealth. 

From the HDD site to the TXU WUGS 

facility, the pipeline will be installed underground 

by trenching. This section of 

the pipeline passes through private freehold 

land, which is used for dairying and 

grazing. Five areas of remnant native 

vegetation, varying in quality (see Figure 

6.6 and Section 6.8 for further detail), 

will be intersected by the pipeline route; 

these occur at Curdie Vale to Port 

Campbell Road, Smokey Point Road, 

Cheynes Road South, Cobden to Port 

Campbell Road and Campbells Creek. 

Planning Scheme Zones and Overlays. 

The pipeline route is located entirely 

within the Corangamite Shire and is subject 

to the following planning scheme 

zones and overlays, as shown in Figure 

6.14: 

• Environmental Rural Zone (ERZ) – 

Extends from the boundary of Port 

Campbell National Park inland approximately 

3 km. 

• Rural Zone (RUZ) – Extends from 

the boundary of the ERZ inland. 

• Road Zone 1 (RDZ1) and Road Zone 

2 (RDZ2) – Occurs on roads the pipe 

route intersects. 

• Vegetation Protection Overlay Schedule 

2 (VPO2) – Occurs on roadsides 

that the pipeline route will intersect. 

• Public Conservation and Resource 

Zone (PCRZ) – Occurs over the Port 

Campbell National Park, which the 

HDD will pass under. 

The majority of the Casino Gas field Development 

onshore pipeline will be located 

within land zoned as Rural Zone 

(RUZ) under the Corangamite Planning 

Scheme. This zone places no restrictions 

on the development of gas pipelines, 

therefore any changes to planning 

scheme zones or overlays will not be 

required to accommodate the Casino Gas 



Existing infrastructure and services within 

the project area and the wider region 

(Figure 6.15) are described below. 

Roads. A network of sealed and unsealed 

roads, which vary in standard and 

purpose, service the project area. The 

major roads in the region are the Princes 

Highway, which passes through Colac, 

Camperdown, Terang and Warrnambool, 

and the Great Ocean Road, which passes 

through Port Campbell and Peterborough 

before connecting to the Princes Highway 

on the outskirts of Warrnambool. 

The pipeline route will intersect four 

roads; Curdie Vale to Port Campbell 

Road (sealed), Smokey Point Road (unsealed), 

Cheynes Road South (unsealed) 

and Cobden to Port Campbell Road 

(sealed). Roads that will be utilised by 

the project for transport are discussed in 

the traffic section (Section 6.17). 

Rail. The nearest rail line to the project 

is the Geelong to Warrnambool line, 

which connects the region to Melbourne. 

The closest railway station to the project 

area is in Camperdown, approximately 

50 km by road from Port Campbell. 


o 


630000 650000 670000 690000 

y 

a 

P rin c e s H ig h w 

R o a d 

b d e n 

ry sdale Creek 

iv er 

Merri R 

D 

ra n g 

-T e 

n 

n -C 

C o b d e 

R 

C a m p e r d o w 

o a d 

a y 

h w 

H ig 

Hopkins Highway 

P r i n c e s 

Hopkin s River 

R ussell Creek 

L a v e 

r s 

D eep Creek 

H i 

C urdies River 

Mount Emu Creek 

Bruc k nell Creek 

ll - C 

G 

o b d e n R 

Cobden-Warrnambool Road 

re a t 

o a d 

O c 

Ayresford Road 

R 

e a n 

o a d 

Timboon-Colac Road 

Legend 

Pow er Creek 

R o a d 

r e 

a r 

ll a w 

o n - N u 

o 

T im b 

Ross Creek 

Cobden- 


reek 

C 

Fenton 

Land use areas 

Highway 

Road 

River/Creek - Major 

-Minor 


Warrnambool 



HDD section 


Forestry - Private softwood 

Spri ng Creek 

Forestry - Public softwood 

Broad acre cropping and crop pasture 

S herbrook R 

Curdies 

Inlet 

Terang 

Timboon 

Cobden 

Camperdown 

iver 

Little Cooriem ungle Creek 

Horticulture 

Remnant native vegetation 

C ampbells Cre ek 

Unspecified private land 

Unspecified non-public terrestrial land 

Non-farmland (excluding remnant veg) 

Other private land (non-farmland) 

Pasture - Dryland 

No data available 

0 5 10 

Kilometres 


Peterborough 

Port Campbell 

Figure 6.14 Landuse and infrastructure 

5740000 5760000 



Waarr 

666000 668000 670000 672000 674000 676000 678000 



Gas Plant 


C r ee k 


S pring 

SUZ2 

Heytesbury 

Gas Plant 

Boundary Road 


RUZ 

SUZ4 

Proposed 

Otway Gas 

ProjectPlant 

Tregea 

Road 

C r e ek 

W allab y 


E astern C ree k 


Legend 

0 0.5 1 

Kilometres 


TXU 

WUGS 

Facility 


Cobden- 


r e e k 

Pascoe Road 

Langleys Road 

Brumbys Road 

C 

Minerva 

Gas 

Plant 

lls 

RUZ 

am pbe 

C 

Jarvis Road 

Planning Schemes 

SUZ3 

Currells Road 

Sharps Road 

ERZ 

ERZ 

Rounds Road 

RDZ1 

PCRZ 

LDRZ 


ERZ 

PCRZ 

SUZ1 

RDZ2 

B1Z 

ERZ 

LDRZ 

PCRZ 

PPRZ 

PUZ5 

PUZ7 

R1Z 

RDZ1 

RDZ2 

RUZ 

SUZ1 

SUZ2 

SUZ3 

SUZ4 

Overlays 

VPO2 

Road 

Creek 




HDD section 


Business 1 Zone 

Environmental Rural Zone 

Low Density Residental Zone 

Public Conservation and Resource Zone 

Public Park and Recreation Zone 

Public Use Zone -Cemetary/Crematorium 

Public Use Zone - Other Public Use 

Residental 1 Zone 

Road Zone - Category 1 

Road Zone - Category 2 

Rural Zone 

Special Use Zone 1 




Corangamite Vegetation Protection Overlay 

B1Z 

LDRZ 

PUZ7 

R1Z 

PUZ5 

Port Campbell 

PPRZ 

SLO3 

Significant Landscape Overlay - Schedule 3 

Figure 6.15 Corangamite Shire planning schemes and overlays 

5724000 5726000 5728000 5730000 



Electricity. Powercor Australia distributes 

electricity to the project area predominantly 

via overhead lines, however 

some low voltage underground cables 

are also used. 

Petroleum Production and Processing. 

The Otway region is considered prospective 

for gas reserves and is 

increasingly becoming a secondary hub 

of gas supply to Victoria and interstate. 

Existing and proposed gas production 

and processing infrastructure within the 

Casino Gas Field Development project 

area is listed in Table 6.12 and shown in 

Figure 5.4. 

Communication Lines. Underground fibre-optic 

telecommunication cables exist 

throughout the project area. The 

Casino Gas Field Development onshore 

pipeline intersects an underground telecommunications 

cable at the Curdie 

Vale to Port Campbell Road and possibly 

other road crossings. These will be 

verified by the survey. 

Water, Wastewater and Irrigation. Water 

main pipelines and private water irrigation 

pipelines and irrigation channels 

run through farmland and public land. 

The main South West Water supply pipeline 

servicing Port Campbell is intersected 

by the Casino Gas Field 

Development pipeline at the Curdie Vale 

to Port Campbell Road. Private water 

irrigation pipelines have been identified 

during the consultation process with individual 

landholders affected by the proposed 

alignment and survey and then 

noted in the landholder database and on 

survey drawings. 

Domestic water supplies in the project 

area are sourced from a single production 

bore which taps the Dilwyn formation 

(SWWA, 2004) and is supplied to 

customers by South West Water. The 

water from this bore is treated at the Port 

Campbell Water Treatment Plant and distributed 

to Port Campbell, Timboon and 

Peterborough. 

Port Campbell and Timboon townships 

have sewage treatment plants, also operated 

by South West Water. The township 

of Peterborough and rural properties 

in the region utilise septic systems. There 

are no wastewater pipelines intersected 

by the proposed Casino Gas Field Development 

pipeline alignment. 

Ports. The Port of Portland (about 

130 km west of the project area) is the 

major import and export facility of southwest 

Victoria. Closer to the project area 

the smaller regional ports at Port 

Campbell, Warrnambool and Port Fairy 

support a professional fishing industry 

and recreational fishing and boating. 

The nearest airfield to the project area is 

located in Warrnambool (60 km west of 

the project area). 

Community Infrastructure. Warrnambool 

is the major regional service centre for the 

project area offering a full range of facilities 

and services. Colac also offers a 

wide range of facilities and services but 

not to the same extent as Warrnambool. 

Closer to the project area the township 

of Timboon acts as a service centre for 

Port Campbell and surrounding rural areas. 

Timboon’s facilities and services include 

a combined primary and secondary 

school, district health care service, police 

station, library, post office, two banks, 

swimming pool, chemist, supermarket, 

cafes, hardware store, bakery, newsagents, 

hotel and hairdresser. Port 

Campbell is a smaller town with a strong 

focus on tourism, therefore it has a 

greater number of accommodation facilities 

and a small shopping strip, but no 

banks, library, or school. 

Other Infrastructure. Key industrial facilities 

in the region are outlined in Section 

6.12.1, and aside from the three 

Utility 

Owner/Operator 

BHP Billiton 

GasNet 

Santos 

SEAgas 

TXU 

Table 6.12 

Woodside 

Gas Pipeline 

Minerva offshore and onshore 

pipeline, with shore crossing in 

farmland 200 m east of proposed 

Casino shore crossing completed 

Iona (TXU WUGS facility) to 

Portland pipeline 

Southwest Pipeline (TXU WUGS 

facility to Lara) 

Short length flowlines (production 

pipelines) between onshore 

production wells (9) and gas 

facility 

existing gas facilities identified in Table 

6.12 there are no other industrial facilities 

within the project area. 

Infrastructure on private property includes 

houses, sheds and agricultural facilities 

such as milking sheds, hay barns, irrigation 

pipes, fences and gates. 


The potential impacts to agricultural land 

use that may arise as a result of construction 

and operation of the pipeline 

include: 

• Spread of weeds and pathogens 

(plant and animal diseases). 

• Farm production impacts: 

– Stress to dairy cows and consequential 

decrease in milk production. 

– Temporary loss of grazing pasture 

during, and for the season 

immediately following, construction. 

– Temporary loss of agricultural produce 

and profits. 

– Stock movement, access and 

safety. 

– Soil erosion and compaction and 

disruption of soil profile 

– Altered lateral water flow regime. 

Existing and proposed gas infrastructure in the project area 

Pipeline from TXU WUGS facility 

to Adelaide, via Minerva gas plant 

Pipeline from Santos Heytesbury 

gas plant to TXU WUGS facility. 

Minor well field gathering flowlines 

Proposed Otway Gas offshore and 

onshore pipeline, with shore 

crossing at the Rifle Range 

(1.3 km east of proposed Casino 

shore crossing) 

Gas Plant 

Minerva gas processing plant 

under construction 

N/A. 

Heytesbury Gas Facility 

N/A. 

TXU WUGS facility 

North Paaratte (mothballed) 

Proposed gas plant adjacent to 

TXU WUGS facility 



– Interference with mole drainage. 

– Constraints on future farming activities. 

– Impeded property access, internal 

and external. 

The potential impacts to infrastructure 

that may arise as a result of construction 

and operation of the pipeline include: 

• Temporary damage to unsealed 

roads and general wear and tear on 

roads through the project area. 

• Contact between construction equipment 

and overhead electrical transmission 

lines. 

• Damage to existing gas pipelines paralleled 

or crossed by the Casino gas 

pipeline. 

• Damage to existing buried infrastructure 

(communication lines and water, 

sewage and irrigation pipelines). 

These potential impacts are assessed 

and the proposed mitigation and management 

measures are discussed below. 

6.11.3 Impact Assessment, 

Mitigation and Management 

Measures 

Land Use 

Agriculture is the only land use crossed 

by the pipeline apart from small areas of 

native vegetation along roadsides that 

are discussed in Section 6.8. 

Construction will directly impact an area 

of about 30.8 ha, comprising: 

• 27.6 ha of pipeline construction ROW 

(11.5 km long, 24-m wide). 

• 3.2 ha at the HDD site (100 m x 100 

m) and HDD pipeline fabrication 

laydown (2 km long, 35-m wide – 

however this overlaps with the 24-m 

pipeline ROW, therefore only 11-m 

additional width). 

The pipeline will be buried to an average 

depth of 900 mm. The only above ground 

infrastructure that will remain after construction 

will be the MLV and HPU site at 

the shore crossing location, an area of 

20 m x 30 m. All other land will be reinstated 

to its previous land use. 

The potential impacts to agricultural land 

use that may arise as a result of the 

various phases of pipeline construction 

include the spread of weeds and pathogens 

(plant and animal diseases) and 

impacts to farm production. 

Weeds and Pathogens. Biosecurity, as 

it is now often referred to, relates to the 

prevention and management of agricultural 

weeds and pathogens. Construction 

projects by their very nature (i.e., 

transporting equipment from outside the 

region and earthmoving) have a significant 

potential to introduce weeds and 

pathogens. Being primarily agricultural 

lands a moderate level of existing common 

weed infestation is present in the 

lands traversed. In addition, blackberry 

(a significant noxious weed) has been 

recorded in virtually all roadsides along 

the proposed pipeline alignment. 

The risk of weed outbreak is therefore 

related to their spread from roadside 

clearing and also introduction from an 

external source (e.g., construction equipment 

brought to site). Standard hygiene 

practices employed during construction 

have proved effective in preventing significant 

long-term impacts from weeds. 

Such procedures, including washdown 

(prior to arriving at site and then as required 

during construction), will be strictly 

applied during construction. In addition, 

spraying blackberries at roadsides will 

be considered prior to vegetation clearing 

to minimise the risk of spread, particularly 

as construction will coincide with 

fruiting. 

The risk of transfer of pathogens (i.e., 

animal and plant diseases) is negligible 

with no recorded pathogen occurrences 

along the proposed pipeline alignment. 

The hygiene measures applied for weed 

control will serve as a precaution to the 

introduction and spread of pathogens. 

During pipeline operations similar hygiene 

procedures will be applied. 

Specific mitigation measures to minimise 

the introduction and spread of weeds 

and pathogens (plant and animal) include: 

• Decontamination by washdown of all 

equipment and machinery and certification 

prior to accessing project 

sites. 

• Regular inspection of, and if necessary, 

washdown of machinery and 

vehicles that contain excess mud or 

plant matter on tyres and 

undercarriages. 

• Minimising the extent and duration of 

soils exposure to minimise the risk of 

weed invasion. 

• Minimise construction in boggy areas 

to reduce transfer of mud and 

potentially weed seeds. 

• Pre-clearing herbicide spraying of 

blackberries along the easement if 

fruiting at the time of construction. 

• Timely reinstatement of the easement 

and ongoing monitoring for weed invasion. 

• Operations weed control to control 

construction induced weed introductions. 


for weeds and pathogens are also discussed 

in Section 6.8. 

Farm Operations. The primary impact 

mitigation tool in pipeline development is 

the selection of an appropriate alignment. 

Santos, assisted by a specialist Lands 

Advisor, has selected an alignment based 

on the direct advice of the landholders 

whose properties are affected. As a consequence 

the pipeline follows existing 

easements and fencelines for about 90% 

of its onshore route, in an effort to minimise 

disruption to farm operations. 

Once the alignment is selected, any residual 

impacts to farm operations can be 

managed, such that, the impact of pipeline 

construction on agricultural land and 

farm operations is short-term once the 

construction phase is completed and the 

ROW rehabilitated. After which, cropping 

and grazing over the pipeline easement 

can continue. 

Pipeline construction, including HDD of 

the shore crossing, is scheduled to commence 

in the summer of 2005 to avoid 

land access issues during wetter months. 

Pipeline construction, from clear and 

grade to reinstatement, is expected to 

take about 28 to 42 days at any one 

location (see Section 5.5.4), followed by 

tie-ins, ROW rehabilitation, installation 

of marker signs and fencing. Overall, 

pipeline construction along the entire 

onshore alignment is scheduled to take 

about 3 months to complete. Santos is 

working with landholders to identify property-specific 

measures to ensure impacts 

are mitigated. 

The HDD shore crossing will take about 

6 to 7 months to complete. The drilling 

will be confined to a location on the southern 

boundary of the property measuring 

approximately 100 m x 100 m for this 

period. A pipe stringing lay down area, 

measuring up to 2 km long x 30 m wide, 



will be required for fabrication of the HDD 

pipeline section. This will overlap the onshore 

pipeline ROW through the property 

and therefore the effective width of 

disturbance will be 35 m in total. The 

HDD pipeline laydown will be in place for 

about 4 months. Santos is currently working 

with the relevant landholder to identify 

access and site specific mitigation 

requirements. 

The temporary loss of pasture as a result 

of the clearing and grading along the 

ROW may immediately impact on the 

quantity of pasture available for stock 

grazing. In most circumstances, there 

will be sufficient pasture available on 

each affected property to allow grazing 

to continue, although some changes to 

farm management may be required. In 

some cases, where paddock rotation is 

disrupted or where access to sections of 

the property is temporarily blocked by 

construction, external supplementary 

feed may be either supplied or paid for 

by agreement on a case-by-case basis. 

Stockpiling trench spoil and top soil as 

separate windrows along the ROW preserves 

the topsoil, enabling the original 

soil profile to be reinstated (avoiding soil 

inversion) and the pasture to be successfully 

re-established. During the rehabilitation 

stage, a recommended seed 

mix (developed in consultation with individual 

landholders) will be sown over the 

reinstated topsoil and fertilised where 

appropriate. 

The construction spread may interfere 

with the usual movement of stock between 

paddocks, to watering points and 

in the case of dairy cattle, to milking 

sheds twice daily. Landholders will be 

consulted about how to minimise these 

inconveniences and disruptions on each 

individual property. 

The Woodside Otway Gas Project onshore 

pipeline is scheduled to be constructed 

at about the same time as the 

Casino Gas Field Development onshore 

pipeline. This being the case Santos is 

endeavouring to work with Woodside to 

coordinate construction activities through 

those properties traversed by both pipelines 

to minimise disruption to 

landholders. This only occurs for a short 

section (about 900 m) immediately east 

and west of the Curdie Vale to Port 

Campbell Road where the pipelines are 

adjacent to each other. 

During operations regular inspections of 

the pipeline will occur, but this will generally 

not require regular vehicular access 

along the easement. 

Issue specific mitigation measures are 

discussed in the following. 

• Early identification of landholder issues 

during initial survey consent consultation 

to influence route selection. 

• Liaison with relevant landholders to 

determine the most appropriate 

measures to minimise impacts to farm 

operations. Measures may include 

alteration to paddock rotation, provision 

of supplementary feed and temporary 

water troughs and temporary 

electric fencing or coordinating construction 

to accommodate the immediate 

farming activities. 

• Any losses (including income and 

farming amenity) resulting from pipeline 

construction activities will be investigated 

and where necessary, 

compensation paid upon agreement. 

• Hard trench plugs shall be left in place 

to allow stock movement across the 

trench for access to watering points, 

fresh pasture, holding yards or milking 

sheds. 

• In some cases, farm tracks may be 

treated as special crossings and excavated 

and backfilled in less than a 

day. In all instances, access will be 

accommodated where required by the 

landholder. 

• During construction access to, and 

within, properties for farm operations 

shall be accommodated as required 

by the landholder. 

• Paddocks will remain secure for stock 

whilst accommodating the movement 

of construction equipment and vehicles 

along the ROW through the use 

of temporary gates. 

• Reinstating all effected infrastructure 

and property (such as fences, tracks, 

cattle grids, etc.) to their prior condition 

as a minimum in consultation 

with landholders. 

• Final sign-off on ROW restoration by 

landholders and asset managers. 

Soils Management and Reinstatement. 

Trench spoil and topsoil will be stockpiled 

as separate windrows along the 

ROW during the grading and trenching 

process. Trench spoil is less fertile than 

topsoil and may contain rock and other 

material that is unsuitable for pasture 

establishment and growth. The separation 

of trench spoil and topsoil avoids 

soil inversion (where subsoil remains at 

the surface following ROW restoration). 

Areas of significant soil compaction shall 

be ripped (to promote soil aeration and 

water penetration) to allow pasture reestablishment. 

Trench backfill shall be compacted to 

minimise the risk of soil subsidence over 

the trench (see also Section 6.7). A raised 

crown (less than 20 cm) will be left over 

the trench during reinstatement to compensate 

for trench subsidence. 

The potential for loss of soil through wind 

and/or water erosion from agricultural 

lands during construction and rehabilitation 

is high because of the exposed nature 

of the stockpiled trench spoil and 

topsoil in windrows, which can be spread 

by strong winds or heavy rainfall. Erosion 

and scouring of the trench itself can 

also occur. 

The relevant construction personnel will 

monitor weather forecasts for heavy 

rains, upstream flooding or high winds 

and take preventative action. Keeping 

the length of spread to a workable minimum 

(i.e., the time between clearing and 

grading to backfilling and restoration) will 

also minimise the time that soil is exposed 

to the elements. Soil erosion will 

be mitigated through the use of appropriate 

erosion and sediment control 

measures to control site run-on, such as 

diversion banks to divert water away from 

the trench and windrows and trench 

breakers to slow the flow of water in the 

trench (thus minimising trench scour) and 

trap sediment. Replanting the ROW with 

the appropriate pasture mix as soon as 

possible after construction further minimises 

erosion risk. 

Trench excavation and the creation of 

soil windrows will only temporarily alter 

surface hydrology. Water flow regimes 

are expected to return to pre-existing 

conditions following backfill and 

compaction of the trench and ROW rehabilitation. 

The cost of land rehabilitation, pasture 

reinstatement and remedial works will 

be borne by Santos. 

Mole Drainage. In the steeper terrain 

along the pipeline route either side of 

Campbells Creek, a grazier has installed 

mole drains on his property, which minimise 

winter waterlogging and increases 

pasture production over the winter period 

because of a free-draining root zone 

(Phillips Agribusiness, 2004). The proposed 

pipeline route traverses this property 

and will impact the sub-surface 

drainage system. Phillips Agribusiness 

(2004) has assessed that 10 ha of this 



property would require re-moling, eight 

collector drains would need replacing and 

two water pipelines would need relocation 

or replacing after pipe laying. 

Constraints on Future Agricultural 

Activities. The main constraints imposed 

by the pipeline easement are: 

• Deep-rooted woody plants may not 

be planted within the easement without 

prior written approval of Santos. 

• Structures such as houses, hay sheds 

and milking sheds must not be 

erected on the easement without prior 

written approval from Santos. 

• Excavation or ripping to a depth 

greater than 300 mm is not permitted 

without prior written approval from 

Santos. 

The renovation of pastures and planting 

of crops are activities generally not affected 

by the easement. Landholders are 

compensated for the creation of the easement 

on their property. 


Roads. Construction is likely to result in 

additional wear and tear to road surfaces, 

and in the case of the two road 

crossings (Smokey Point Road and 

Cheynes Road South) the unsealed surface 

will be trenched. Impacts are only 

likely to occur during the construction 

phase and will be temporary. Disruption 

to traffic is discussed in Section 6.17.2. 

Prior to construction Santos will be required 

to seek road crossing permits, 

which will include agreement with the 

Corangamite Shire as the relevant road 

authority on construction and reinstatement 

requirements. In addition, the construction 

contractor will be required to 

maintain roads to appropriate standards 

and reinstate all road surfaces damaged 

due to construction traffic to pre-construction 

conditions or as agreed with 

the Corangamite Shire. 

Measures to mitigate traffic impacts are 

outlined in Section 6.17.3. Measures to 

mitigate the potential impacts to road 

infrastructure includes: 

• HDD of the Curdie Vale to Port 

Campbell Road and Cobden to Port 

Campbell Road to minimise damage 

to road integrity. 

• Road crossings will be undertaken in 

consultation with, and in accordance 

with permits issued by the relevant 

authorities (Corangamite Shire and 

VicRoads). 

• Trenching of the two unsealed roads 

intersected by the pipeline (Smokey 

Point Road and Cheynes Road 

South) will typically be completed in 

the minimum time practicable (generally 

within a day) by a special crossing 

crew. Continual traffic access will 

be accommodated. 

• All road surfaces will be maintained 

during construction and reinstated to 

pre-construction conditions or as 

agreed with the Corangamite Shire. 

Electricity Transmission Lines. When 

aligning gas pipelines near overhead 

electrical transmission lines potential interactions 

such as inductive coupling and 

earth potential rise may occur, which can 

damage infrastructure and pose safety 

risks. During construction there is also 

potential for construction equipment to 

directly contact electricity transmission 

lines (and the associated safety risks for 

construction workers) and risk of interruption 

of supply for electricity consumers. 

The onshore pipeline route avoids 

paralleling transmission easements and 

so induction potential is not significant. 

The pipeline will cross under overhead 

power lines in several locations and so 

appropriate safety precautions will be 

implemented during construction. 

Mitigation measures to minimise potential 

impacts associated with the close 

proximity of power transmission lines and 

steel pipelines may include: 

• Identifying locations of transmission 

lines. 

• Locating the pipeline a safe distance 

from transmission lines. 

• Crossing high voltage transmission 

lines at 90° angles to avoid induction 

potential. 

• Adhering to industry standards (AS 

2885 Pipelines – Gas and Liquid Petroleum 

and AS2832.1 Guide to Cathodic 

Protection of Metals) on the 

location of these infrastructure in 

close proximity to one another. 

• Flagging and temporarily installing 

overhead covers (‘tiger tape’) on overhead 

lines for clear visibility and 

avoidance by construction equipment. 

• Installing a cathodic protection system 

to prevent corrosion. 

Gas. The proposed alignment parallels 

existing gas pipeline easements for about 

7.3 km, and crosses the Minerva Project 

pipeline, the proposed Woodside Otway 

Gas Project pipeline twice, the SEAgas 

pipeline and the TXU and GasNet pipelines 

at a fourth location. 

Potential impacts arising from locating 

gas pipelines in close proximity to each 

other are related to safety of an existing 

pipeline and are addressed through risk 

assessment and pipeline design and operation 

standards (see Section 6.18). 

Construction over an existing pipeline 

can cause soil compaction over the pipeline, 

leading to possible damage of the 

pipeline coating through rock movement 

in the trench or by shear pressure caused 

by the equipment therefore the easement 

is adjacent to existing pipeline 

easements to avoid any interaction. 

Measures to mitigate against impacts to 

gas infrastructure include: 

• Design and operation of the pipeline 

to comply with Australian Standards 

(AS2885) based on a hazard and 

safety risk (see Section 6.18). 

• Construction over an existing pipeline 

will be avoided to minimise the 

risk of potential damage to the coating 

of the buried pipeline from heavy 

equipment. 

• As existing pipelines and other assets 

are generally still operating they 

are crossed by trenching beneath by 

careful excavation and hand-digging 

to expose the asset. This will be done 

in consultation with the asset operator. 

Communication, Water, Waste Water 

and Irrigation Infrastructure. The precise 

location of surface and underground 

communication, water, waste water and 

irrigation infrastructure is identified during 

the detailed alignment survey. This 

infrastructure is marked on alignment 

drawings and in the field for the construction 

crew to avoid the potential for 

infrastructure damage. A mains water 

pipeline crosses the Curdie Vale to Port 

Campbell Road close to the proposed 

HDD pipeline road crossing in this location 

and so will not be effected by construction 

activities. 

Appropriate construction management to 

avoid damage, in consultation with the 

asset owner will be implemented. 


Potential impacts to land use and infrastructure 

have been mitigated to the 

greatest extent practicable by aligning 

the pipeline to accommodate landholder 



requirements. Residual impacts will be 

managed through consultation with 

landholders to address property specific 

issues and agree measures to mitigate 

any potential disruption or losses. Consequently, 

long-term detrimental impacts 

to land use and infrastructure are not 

likely to result. 

Table 6.13 Corangamite Shire population data 

Corangamite Shire Population 1996 2001 

Corangamite North 9,443 9,094 

Corangamite South 7,520 7,581 

Total 16,963 16,675 

Source: ABS 1996 as cited in CSC, 2004a; CDATA, 2001 as cited in CSC, 2004a. 

6.12 Socio-economic 


The onshore section of the proposed 

pipeline is located in the southern part of 

the Corangamite local government area 

(LGA), in the statistical local area of 

Corangamite South. The next nearest 

government municipalities to the project 

area are the Moyne Shire and 

Warrnambool City local government authorities. 

Table 6.14 

Demographics 

The 2001 population of Corangamite 

Shire was 16,675 persons (Table 6.13), 

comprising 8,347 males (50.1%) and 

8,328 females (49.9%) (CDATA, 2001 

as cited in CSC, 2004a). Between 1996 

and 2001 the population of Corangamite 

decreased by 288 persons representing 

0.3% decline per year (CSC, 2004a). 

However, during this same period the 

population of Corangamite South slightly 

increased. This increase may be a reflection 

of a general trend in the state of 

drifts toward urban and coastal areas. 

Within the Corangamite Shire the townships 

experienced varying changes in 

population over the past two census periods 

(Table 6.14). Camperdown, 

Derrinallum, Lismore and Terang all declined 

during the period 1996 to 2001, 

Skipton remained stable, while Cobden 

and Noorat marginally increased in population. 

The two towns closest to the 

project area, Timboon and Port Campbell 

have experienced the greatest population 

growth. The population of Port 

Campbell in 2001 was 459 people, nearly 

double the 1991 count of 234. 

Local Communities 

Local landholders, and the communities 

of Timboon and Port Campbell are the 

most likely to be influenced by the project, 

therefore the characteristics of these 

communities are described in further detail. 

Timboon acts as a service centre for 

Port Campbell and surrounds and offers 

a range of services and facilities, including 

a school for years prep to 12. Timboon 

is a dairying community and the township 

itself is picturesque, set among natural 

bushlands, rolling hills and lush 

pastures (CSC, 2004d). 

Port Campbell is a seaside township located 

along the Great Ocean Road. The 

town is a popular tourist destination and 

the facilities of the town reflect this. Port 

Campbell offers a relaxed seaside atmosphere, 

safe swimming, surfing, scuba 

diving at nearby wrecks, excellent fishing 

and great food and wine (CSC, 

2004d). 

Perceived benefits and negatives of living 

in the region were examined in the 

EES/EIS for the Otway Gas Project which 

found the following (Woodside, 2003): 

• Perceived benefits: dependable 

weather (particularly reliable rainfall), 

sense of community (sporting, cultural 

and community groups and helping 

attitudes), environmental features 

Location of population within Corangamite Shire 

Population 1991 1996 2001 

Camperdown 3,315 3,153 3,130 

Cobden 1,477 1,408 1,420 

Derrinallum 280 265 261 

Lismore 325 323 267 

Noorat 250 249 268 

Port Campbell 234 281 459 

Simpson 158 148 128 

Skipton 462 453 454 

Terang 1,973 1,867 1,862 

Timboon 735 690 792 

Source: Towns in Time as cited in CSC, 2004a. 

(coastline, national parks, walking 

tracks, fishing spots) and community 

facilities (mainly in Timboon). 

• Perceived negatives: conditions of 

roads and increased traffic (particularly 

trucks and tourist traffic), lack of 

diverse local employment opportunities 

(mainly problem for Timboon), 

lack of consistency in planning across 

shire (in particular council promotion 

of new industries such as gas development, 

tourism and wind farms instead 

of supporting existing 

industries). 

Economy 

Employment. In 2001 the Corangamite 

Shire had a labour force of 7,703 people 

representing a workforce participation 

rate of 61.3% and an unemployment of 

4.3% (CSC, 2004b). The rural area of 

the Shire had the greatest participation 

rate at 75.4% and Port Campbell had the 

highest participation rate for a township 

(70.7%) (CSC, 2004b). Both Port 

Campbell and the rural area also experienced 

the lowest unemployment rates 

for the shire of 1.7% and 2.5% respectively 

(CSC, 2004b). 

The agriculture, forestry and fishing industries 

employed the largest number of 

people in Corangamite in 2001 (Table 

6.15). Other major employers were 

the retail trade, manufacturing and health 

and community service industries (see 

Table 6.15). 

Industries. Major industries in the 

Corangamite Shire include agriculture, 

fishing, manufacture and construction 

and tourism. The agricultural sector is 

the greatest economic contributor and is 

worth approximately $237 million per 

annum, comprising (CSC, 2004c): 

• Milk—$158.3 million. 

• Livestock—$43.1 million. 

• Pasture—$20.4 million. 

• Wool—$14.9 million. 

Growth industries for the shire include 

the dairy sector, increasing by around 

7% per annum (FSS DBA Dairy Web 

Report, 2002 as cited in CSC, 2004c) 



and tourism, which is increasing by an 

estimated 10% per annum (CSC, 2004c). 

There has also been considerable shortterm 

growth in the construction industries 

as a result of activities such as the 

TXU and Minerva gas projects, as well 

as some ongoing employment (CSC, 

2004c). 

Key industrial developments throughout 

the region include (CSC, 2004c): 

• Milk manufacturers Dairy Farmers 

(Simpson), Bonlac (Cobden) which 

are supplied by local milk. Milk produced 

in Corangamite is also used in 

other regions including Murray 

Goulburn (Koroit) and the 

Warrnambool Cheese and Butter 

Factory (Allansford). 

• Small food manufacturers including 

Timboon Fine Ice Cream, Timboon 

Farmhouse Cheeses, Heytesbury 

Ridge Wines, Mount Emu Creek 

Sheep Milk Cheese, and various 

smoked eel producers and exporters. 

• Manufacturers of stockfeed pellets, 

including CopRice (Cobden), Ridley 

Agriproducts (Terang) and 

Heytesbury Stockfeeds. 

• Timber processing operations, including 

McVilly Treated Timber in 

Timboon and Terang. 

• Bushman Poly Products in Terang. 

• Gas facilities, including the BHP 

Minerva Gas Plant, Santos 

Heytesbury gas processing facility, 

TXU WUGS facility, and the proposed 

Woodside gas processing plant. 

• Tourism facilities and services, particularly 

in Port Campbell. 

Table 6.15 

Employment by Industry North South Total % 

Agriculture, forestry and fishing 1,042 1,630 2,672 36.2 

Retail trade 514 275 789 10.7 

Manufacturing 363 358 721 9.8 

Health and community services 422 211 633 8.6 

Education 268 164 432 5.8 

Construction 204 178 382 5.2 

Accommodation, cafes, restaurants 135 140 275 3.7 

Wholesale trade 152 122 274 3.7 

Transport and storage 133 95 228 3.1 

Property and business services 128 97 225 3.0 

Non-classifiable and not stated 98 93 191 2.6 

Personal and other services 109 45 154 2.1 

Government admin. and defence 94 39 133 1.8 

Cultural and recreational services 54 28 82 1.1 

Communication services 43 25 68 0.9 

Finance and insurance 43 22 65 0.9 

Electricity, gas and water supply 29 4 33 0.4 

Mining 3 29 32 0.4 

Total 3,834 3,555 7,389 

Source: CDATA, 2001 as cited in CSC, 2004a. 

Tourism and Recreation 

The proposed development is within the 

area defined by Tourism Victoria as the 

Great Ocean Road tourist region. The 

region covers the coastal area from the 

beginning of the Great Ocean Road at 

Torquay through to the South Australian 

border. The Great Ocean Road Region 

Strategy (DSE, 2003b) defines the Great 

Ocean Road Region as a 6,000 km 2 area 

extending east-west from Torquay to 

Warrnambool and northward to the 

Princes Highway. 

The Great Ocean Road tourist region is 

noted for its spectacular coastlines, 

strong maritime and shipwreck heritage, 

national parks and scenic hinterland. The 

region offers visitors an array of adventure 

style activities such as scuba diving 

and surfing through to general leisure 

activities including site seeing, fishing, 

walking and camping. 

Some of the region’s main attractions 

include the Twelve Apostles, Port 

Campbell National Park, Otway Ranges, 

Cape Bridgewater, Cape Nelson, Discovery 

Bay Coastal Park and Tower Hill 

Game Reserve. Townships in the 

Corangamite Shire also offer tourism and 

recreation activities, Port Campbell and 

Timboon are popular tourist destinations. 

Visitor numbers to Port Campbell are 

expected to increase to 3.5 million by 

the year 2009 (Parks Victoria, 2002 as 

cited in CSC, 2004c). 


The following section assesses the potential 

impacts to the project area’s social 

and economic environment. 

Impacts on Communities 

The following section addresses potential 

impacts of the Casino Gas Field Development 

on the broader community. 

Impacts to individual landholders directly 

affected by the onshore pipeline are discussed 

in detailed in Section 6.11 whilst 

the intermittent and temporary impacts 

to public amenity including visual, noise, 

air quality and traffic are discussed in 

Corangamite Shire employment by industry 

Sections 6.13, 6.14, 6.15 and 6.17, respectively. 

During the onshore construction period 

there will be a short-term increase in the 

local population (6 to 7 months for pipeline 

construction, with a peak of approximately 

45 people). This may place 

pressure on community infrastructure, accommodation 

facilities and services such 

as medical facilities, however the impact 

is likely to be minimal given the small 

size of the construction workforce. 

Construction workforces are often of a 

different demographic to the communities 

they work in—they are typically male, 

under the age of 50 and have high proportions 

of singles. The introduction of 

construction workforces into local communities 

can sometimes create social 

tension. This is unlikely to be a significant 

issue for this project given the size 

of the workforce and short duration of 

construction, particular in a region with 

significant fluctuations in population numbers 

due to tourism. 

Santos has implemented a Field Interaction 

Protocol to guide all Santos and 

contractor personnel on appropriate 

standards of conduct during field activities 

to avoid adverse impacts on the local 

community. The Field Interaction 

Protocol will remain in place for the life 



of the project, and will be amended as 

appropriate to reflect any changes in 

policy. 

Economic and Employment 

Potential impacts of the project on the 

local commercial fishing and agricultural 

industries are discussed in Sections 6.5 

and 6.11, respectively. 

The total capital expenditure for the Casino 

Gas Field Development is approximately 

AUD$200 million. A significant 

proportion of this amount is accounted 

for in materials manufacturing for which 

Australian companies are being invited 

to bid. 

At the local level the key potential benefits 

relate to employment directly by the 

project or in support services, although 

the majority of positions will require specialised 

skills. Construction workforce 

employment resulting from the project 

will comprise approximately: 

• 25 people for drilling and subsea installation 

(2 to 3 months). 

• 200 to 250 people for offshore pipeline 

installation (up to 4 to 5 months). 

• 45 people (at its peak) for onshore 

pipeline installation and HDD construction 

and installation (up to 6 to 7 

months). 

In addition, a team of design and project 

management personnel, and other technical 

support services will be maintained 

during the planning, detailed design, construction 

and commissioning phases. 

The majority of these positions require 

specialised personnel and contract service 

companies, who are experienced in 

pipeline construction and gas field development 

projects. Therefore, local employment 

opportunities are limited. 

Potential for local employment does exist 

however in areas such as ROW rehabilitation 

and fencing. There will also be 

indirect employment opportunities associated 

with the project such as the supply 

of goods and services. 

During operations the processing and 

export of the gas will be undertaken by 

TXU within the existing operations at the 

TXU WUGS facility. Additional contractor 

services will be engaged to undertake 

pipeline and well-field maintenance 

as required. No additional jobs are anticipated 

at the TXU WUGS facility as a 

result of the project. The Casino Gas 

Field Development may however extend 

the operating life of the plant. 

Impacts on Tourism and Recreation 

The tourism and recreation activities most 

likely to interact with the project are siteseeing 

from the many vantage points 

east and west of Port Campbell, surfing 

at Two Mile Bay and recreational boating 

(predominantly fishing) along the proposed 

offshore pipeline alignment. 

During construction the pipelay vessel 

and, to a far lesser degree, the drilling 

rig will be visible from site seeing vantage 

points along the coast (see Section 

6.13.3). The activities of greatest visibility 

potential are offshore pipeline construction 

in shallow water and the HDD 

at the coast. The short duration of construction 

and the screening of the HDD 

rig behind roadside native vegetation limit 

the potential for impacts and is unlikely 

to have adverse effects upon tourism 

and recreation. Visual impacts are discussed 

in greater detail in Section 6.13.3. 

The presence of such unique construction 

equipment has in fact got the potential 

to generate interest and therefore 

visitors, albeit a minor overall contribution. 

Both the pipeline and shore crossing construction 

workforces will be accommodated 

in existing tourist accommodation 

facilities in nearby towns, most likely Port 

Campbell and Timboon, subject to agreement 

with the accommodation facility 

owners. The offshore construction 

workforces will be accommodated on the 

drilling rig and pipelay vessel and flown 

in and out of site via Essendon airport. 

The onshore construction workforce will 

place additional demand on accommodation 

facilities, particularly over the peak 

tourist period in summer, however the 

low numbers of construction personnel 

are unlikely to significantly impact upon 

tourism activity in the area. Alternatively, 

the construction contractor may elect to 

establish a temporary camp to accommodate 

the construction workforce. This 

would be done in accordance with state 

and local government regulatory requirements, 

and in consultation with DPI and 

the Corangamite Shire. The camp, if required, 

would be established at a location 

of previous disturbance. Santos has 

a pre-existing camp site near the 

Heytesbury Gas Facility which could be 

used for this purpose. 

Impacts to recreation activities, in particular 

surfing at Two Mile Bay and boating, 

are unlikely to be significant. The 

nearest surfing occurs between 650 m to 

1400 m from the HDD exit point at the 15 

to 16 m water depth and so is outside of 

the pipelay vessel’s 500-m construction 

exclusion zone. During offshore construction 

activities radio communications will 

be maintained with commercial recreation 

operators, e.g., fishing and dive charters, 

and chase boats will maintain the 

pipelay vessel exclusion zone. As the 

duration of offshore construction is short 

(2 to 3 months) it is unlikely that recreational 

boating will be significantly impacted. 

Similarly, the offshore 

construction avoids reef habitat areas 

and shipwrecks and so will not impact 

upon favoured recreational diving sites. 

In the long-term, the project is unlikely to 

effect tourism or recreational pursuits in 

the area. 

On balance the Casino Gas Field Development 

will have a positive economic 

impact on the broader local community, 

and the State in general, through local 

expenditure and employment. Negative 

socio-economic impacts of the project 

may potentially occur during the construction 

period, but these are generally 

minor and temporary in nature, and will 

be managed by appropriate mitigation 

measures. 


Measures 

The potential negative socio-economic 

impacts resulting from the Casino Gas 

Field Development will be mitigated and 

managed as follows: 

• Santos will maintain the Field Interaction 

Protocol for the life of the 

project, to guide all Santos and contractor 

personnel on appropriate 

standards of conduct during field activities. 

The protocol will be amended 

as appropriate to reflect any changes 

in policy. 

• Throughout project development and 

operation, Santos shall continue to 

liaise with relevant stakeholders and 

provide project updates to the wider 

community through appropriate communication 

forum. 

• Where practicable, Santos shall employ 

locally and will require the construction 

contractor to do likewise. 

• Santos, and the construction contractor, 

will liaise with various accommodation 

providers to find appropriate 

accommodation for the construction 

workforce, taking into consideration 

that construction will coincide with 

the peak summer tourist period. It is 

possible that the construction con- 



tractor may elect to establish a construction 

camp, in which case it would 

be established in accordance with 

regulatory requirements. 

• During offshore construction activities 

radio communications will be 

maintained with commercial recreation 

operators, e.g., fishing and dive 

charters, to advise of construction 

vessel operations. 

• During offshore construction activities 

chase boats will maintain the 500- 

m pipelay vessel exclusion zone. 

6.13 Visual Amenity 

An assessment of visual amenity incorporates 

three key factors: views (areas 

that can be seen), distance from views 

and landscape (the context of a view, 

such as its physical setting taking into 

account topography, land cover and land 

use). The assessment of visual amenity 

is essentially a subjective one, in that 

each person has a different perspective 

on what is or is not visually appealing. 


Landscape 

The existing landscape of the project 

area can be divided into the following 

units: 

• Coastal cliffs. 

• Heathy coastal shrubland. 

• Undulating farmland. 

These landscape units are described 

below. 

Coastal Cliffs. In 1875, the coastal zone 

of this region became the first scenic 

area in Victoria to be afforded public 

protection (AHC, 2004). The sheer 

coastal limestone cliffs (up to 70 m in 

height) contribute greatly to the visual 

amenity of the region, and it is widely 

recognised as one of the most scenic 

sections of coastline in Australia (see 

cover photo), easily accessible along the 

Great Ocean Road. Coastal rock stacks 

and arches visible from the coastline add 

to the aesthetic appeal of this section of 

coast. This area is considered sensitive 

to visual disturbance given its significance 

as a tourist attraction. 

Moving east to west from Princetown (25 

km east of the project area) to Peterborough 

(20 km west of the project area), 

coastal formations of visual interest attracting 

high visitor numbers include: 

• The Twelve Apostles (Plate 6.10). 

• The Island Archway. 


Plate 6.10 

The Twelve Apostles, 21 km west of the Casino Gas Field Development 

shore crossing 

• Loch Ard Gorge. 

• The Blowhole. 

• Two Mile Bay (see Plate 6.2). 

• The Arch. 

• Point Hesse. 

• London Bridge. 

• The Grotto. 

Heathy Coastal Shrubland. Port 

Campbell National Park and the Bay of 

Islands Coastal Park contain most of the 

remaining remnants of coastal heath vegetation 

in the region. This vegetation generally 

grows up to about 2 m in height, 

with a diverse range of species making 

up the various strata of these vegetation 

communities, growing on flat cliff tops. 

Views of this vegetation can be seen 

while driving along the Great Ocean Road 

(mainly on the southern side of the road, 

but some vegetation in very narrow remnants 

on the north side of the road), and 

from vantage points and lookouts along 

the coast used predominantly to view 

the coastal features (outlined above). 

Undulating Farmland. The landscape 


project area is a mainly undulating agricultural 

landscape that has necessitated 

the need for broad-scale vegetation clearance. 

This provides a typically ‘rural’ 

visual setting largely void of vegetation 

except for some remnant roadside vegetation 

and coastal parks. The Campbells 

Creek valley is more moderately to 

steeply undulating than the remainder of 

the project area. 

The perception of the existing visual 

amenity of the region can thus vary from 

low (i.e., not visually appealing due to 

loss of ‘naturalness’) or high (i.e., visually 

appealing because of the idealic rural 

setting) depending on one’s values 

and perspective. For local communities, 

these views are from rural residences 

and local roads. For visitors and tourists, 

views are seen mainly from the Great 

Ocean Road, Cobden to Port Campbell 

Road and Curdie Vale to Port Campbell 

Road. 


A number of existing buried gas pipelines 

are present within the project area 

(see Section 6.11), although they are 

not often obvious, despite the presence 

of marker signs. As such, this infrastructure 

does not detract from the visual 

amenity of the area. 




Assessment of visual impacts is extremely 

subjective as what appears to 

be incongruous with the surrounding 

landscape to some may not be to others. 

This section provides an assessment of 

the potential visual impacts of the Casino 

Gas Field Development based on 

the current known socio-economic values 

of the area (see Section 6.12.1), 

namely a rugged natural coastline in a 

rural setting. 

Drilling rig 

In broad terms the key potential visual 

impacts relate to: 

• Offshore well and pipeline construction 

activities. 

• Construction of the shore crossing 

by HDD adjacent to the Great Ocean 

Road. 

• Onshore pipeline construction. 

• Installation of the MLV site in farmland 

adjacent to the Great Ocean 

Road. 


The following provides a visual impact 

assessment of the Casino Gas Field Development. 

Well Drilling and Completion 

Drilling of the offshore wells and their 

completion with the use of a semi-submersible 

rig will take place 30 km offshore, 

and take about 35 days per well 

(about two months). At this distance the 

rig will be very difficult to see, as indicated 

in Plate 6.11 which is a photograph 

of the semi-submersible rig during 

drilling of Casino 3 (dated 22 October 

2003). Whilst visibility would be improved 

when viewed with the naked eye and 

under clearer conditions, it clearly indicates 

that vessels at this distance from 

the coast are not visually intrusive. Impacts 

to visual amenity from the drilling 

rig, and from the pipelay vessel for more 

than 50% of the offshore pipeline alignment, 

will not occur. 

Offshore Pipelay 

As the pipelay vessel moves from the 

Casino wells to the coast, it will become 

more visible from the coast. Based on 

the photographic image of the drilling rig 

(see Plate 6.11) and visual assessments 

conducted for the Minerva project and 

during actual offshore construction, the 

pipelay vessel will not be clearly discernible 

until it is within about 15 km of the 

coast. The vessel can lay pipe at the rate 

of about 2-3 km per day, with offshore 

pipelay expected to take about 20 days. 

Enesar 

Plate 6.11 

Casino 3 drilling rig (circled) in operation as seen from the shore near Port 

Campbell, barely visible on the horizon 

When connecting the subsea pipeline to 

the terrestrial pipeline at the HDD exit 

point (i.e., HDD tie-in at about the 15 to 

16 m water depth, approximately 800 m 

from the coast), the vessel is expected 

to remain at this location for about 2 or 3 

days. While at this location the vessel 

will be a prominent feature of the coastal 

environment, but only for a very short 

time and from limited locations. The steep 

coastal cliffs and dense heath vegetation 

along the coast will prevent views of 

the vessel from the Great Ocean Road 

while it is completing the HDD tie-in and 

for much of the pipeline construction activity. 

The HDD exit point at Two Mile Bay is 

located the following approximate distances 

from tourist viewing areas: 

• 21 km west of the Twelve Apostles 

lookout. 

• 15 km west of the Broken Head lookout. 

• 7 km east of the London Bridge lookout. 

• 5 km east of The Arch lookout. 

• 3 km west of the Port Campbell township 

lookout. 

Impacts to views from these locations 

follow: 

• The HDD exit location at Two Mile 

Bay is not visible from the main viewing 

platform at the Twelve Apostles 

lookout as the cliffs at Loch Ard Gorge 

and Broken Head to the west obstruct 

views. The pipelay vessel will 

be visible from the Twelve Apostles 

lookout as it progressively installs the 

offshore pipeline, however, it will only 

be present in the camera field of view 

of the Twelve Apostles for about 2-3 

days (whilst it is within about 8 km of 

the coast) (see Plate 6.10). 

• The main focus of views from Broken 

Head are looking inland along the 

coast past Sherbrooke River. Views 

of the ocean, and therefore the 

pipelay vessel, are limited from this 

vantage point. 

• Views of Two Mile Bay are not possible 

from the London Bridge lookout. 

The main focus from the lookout is 

London Bridge itself, looking southwest. 

The horizon over the ocean is 

dominant in photographs from this 

location. The drilling rig will be in the 

field of view but barely visible as a 

very small object on the horizon (see 

Plate 6.11). The pipelay vessel will 

be in the background of the field of 

view and will become more discernible 

between about 15 km to 3 km 

from the coast as it progresses along 

the offshore pipeline alignment (approximately 

10 days). It is unlikely 

that the presence of this vessel will 

significantly impact the visual amenity 

of the area due to the short duration 

of visibility. 

• Photographs of The Arch from the 

viewing platform have little ocean or 



horizon in the background, as the 

view is looking down from the platform 

to the rock structure. The pipelay 

vessel may be visible briefly (less 

than 5 days) as a small object from 

this location as it travels towards Two 

Mile Bay in a west–east direction. 

• Expansive views of the Southern 

Ocean are afforded from the Port 

Campbell township lookout, however, 

the main focus of the lookout is looking 

back north over the town. The 

pipelay vessel will be in the background 

of the field of view and will 

become more discernible from about 

15 km from the coast as it progresses 

along the offshore pipeline alignment 

(approximately 10 days), but will be 

obscured by coastal cliffs (from about 

2 km offshore) during HDD tie-in at 

Two Mile Bay. Close views of the 

pipelay vessel will be possible from 

this lookout when it is within about 2 

to 5 km of the coast. Beyond that and 

the vessel will become progressively 

smaller and harder to define. 

Rather than being a distraction to coastal 

views however, it is possible that the 

pipelay vessel may in fact be a temporary 

attraction. BHP-Santos (1999) report 

that the drilling rig used for the 

Minerva exploration drilling 10 km 

(5.5-nm) offshore was an attraction, particularly 

for local residents. At this distance, 

it indicates that tourists and locals 

actively sought out views of the rig (with 

the aid of binoculars). 

Pipeline 

The very nature of underground pipelines 

means that disruption to the visual 

amenity of the rural landscape is largely 

limited to the construction phase. Because 

the proposed pipeline route 

traverses open farmland with a low and 

interspersed human population, the 

visual sensitivity of the proposed pipeline 

is considered to be low, as the pipeline 

and restored ROW will not be obvious 

or contrast with the existing landscape. 

This takes into account pre-existing disturbance 

of the natural landscape, and 

the measures being applied to minimise 

environmental impacts (e.g., HDD of the 

Port Campbell National Park, Great 

Ocean Road and Cobden-Port Campbell 

Road, and subsea wellheads). 

Potential visual impacts associated with 

the proposed onshore pipeline component 


include: 

• Visual presence of large construction 

equipment in the project area, 

including the HDD rig near the Great 

Ocean Road. 

• Construction ROW across an open 

rural landscape for about three 

months (from clear and grade to 

backfill) and up to six months until 

ROW restoration is complete. 

• Some narrow gaps in roadside vegetation 

(about 5 m) resulting from 

selective clearing, though areas 

largely limited to weedy understorey. 

• Due to their very nature and intent, 

flagging tape, ‘tiger tape’ and signage 

used for construction safety purposes 

will be visible from a distance. 

• Temporary establishment of work 

sites. 

Many of these impacts will be temporary 

in nature and minor in extent. 

The HDD of the shore crossing adjacent 

to the Great Ocean Road has the greatest 

potential for visual impact during onshore 

pipeline construction. This activity 

will, however, be largely screened from 

view by the roadside vegetation. It will 

be possible to occasionally view construction 

equipment, such as cranes, 

above the vegetation canopy however 

this will be limited to short periods whilst 

the shore crossing pipeline and other 

equipment is installed. 

The HDD site will be lit at night during 

drilling operations. Whilst largely obscured 

from view from the Great Ocean 

Road by vegetation, light will emanate 

from the site. This impact is temporary 

(about three months during actual drilling) 

and therefore not likely to detract 

significantly from the visual aesthetics of 

the area. 

A HDD site access track (6 m wide) will 

be constructed across the road verge 

from the Great Ocean Road to the HDD 

site (see Figure 5.9). Vegetation will be 

cleared and so views through to farmland 

and the HDD site would be possible 

depending upon the final location of the 

track. However, the length of the access 

track and the perpendicular orientation 

to the track to the Great Ocean Road 

limits direct views along the track to brief 

glimpses, and so would not lead to imposing 

visual impacts from the HDD site 

for passing traffic. The construction site 

will be screened from view from the road 

by shade cloth, as necessary, attached 

to the security gate. 

The “Tru-Trak” sensing cable will be laid 

through the Port Campbell National Park 

down to within a few metres of the 

waterline, but will not significantly impact 

on visual amenity as it will largely be 

obscured by vegetation. 

During operations the HDD site access 

track will be restored and revegetated 

using indigenous plant species in consultation 

with DSE. Permanent access 

to the MLV site (an area of 20 m x 30 m 

to be installed within the HDD site and 

over the pipeline easement, following 

shore crossing construction) is discussed 

under ‘Ancillary Facilities’ below. 

Construction of the pipeline will be most 

visible at and near roadside crossing locations, 

though the road crossings themselves 

will be completed within a day 

where they are open trenched (unsealed 

roads), and within about 20 days for 

sealed roads (where HDD will take place). 

Pipeline construction will largely be 

screened from all roads by dense roadside 

vegetation and the two unsealed 

roads to be trenched (Smokey Point 

Road and Cheynes Road South) are low 

traffic back roads. Construction will be 

visible where the pipeline traverses the 

Campbells Creek valley and Cobden to 

Port Campbell Road but is limited by 

HDD of the road crossing and the short 

duration of construction for this section 

(about 2 to 3 months). Views of pipeline 

construction from the Great Ocean Road 

will be screened by existing roadside 

vegetation and will therefore not impact 

upon the visual amenity. 

Ancillary Facilities 

Permanent ancillary facilities (i.e., appurtenances) 

will be located along the 

proposed pipeline, including: 

• One MLV site located at the HDD 

site (incorporating the HPU and EPU). 

• Pipeline marker signs located at regular, 

short-span intervals along the 

alignment. 

• Cathodic protection test points (located 

beside pipeline markers). 

MLV Site. The MLV site will be located 

at the HDD site, over the pipeline easement, 

in farmland on the north side of 

the Great Ocean Road. This site will be 

about 20 m by 30 m in size and will 

contain the MLV, HPU and EPU (see 

Figure 5.16 and Section 5.4.5), however 

the tallest feature will be the perimeter 

black wire mesh cyclone fencing, at 2.8 m 

high. Following construction the HDD site 



will be contracted back from 100 m x 

100 m to the 20 m x 30 m area. The 

remainder of the HDD site will be restored 

to grazing land. The temporary 

HDD access track will be revegetated 

using indigenous species. 

Access to the MLV site will be via an 

existing, overgrown, access track located 

west of the temporary HDD access track 

(see Figure 6.8). Shared HDD access 

and MLV access is not viable due to the 

need to balance safety concerns associated 

with heavy equipment accessing 

the HDD site and landholder requirements 

for minimising long-term pasture 

loss. The permanent access track will be 

about 3 m wide and will extend from the 

Great Ocean Road through the road 

verge to the south east corner of the 

MLV site. 

The general arrangement of the MLV 

site is shown in Figure 5.16. The site 

itself will be undetectable to vehicles travelling 

along the Great Ocean Road (in 

both directions), and the top 50 cm or so 

of the perimeter fencing would only be 

visible when standing on the southern 

side of the Great Ocean Road. As this is 

not a site where tourists would have 

cause to stop for site seeing the MLV 

site (and perimeter fence) would largely 

go unnoticed. The 3-m wide access track 

is narrow and obvious views along the 

track of MLV infrastructure will not be 

possible for traffic travelling on the Great 

Ocean Road. Facility signage will be 

placed at the fenceline and not at the 

roadside. Additional native vegetation will 

be planted, if necessary, at the end of 

the access track to screen views through 

to open farmland. 

The MLV site will not be directly visible 

from the private residence on the property, 

which is located approximately 

250 m to its west. Private residences 

along the proposed pipeline route, and 

those nearby, will also be temporarily 

impacted by a loss of visual amenity 

during construction and early rehabilitation. 

Pipeline Marker Signs and Cathodic 

Protection Test Points. Pipeline marker 

signs are required to be installed in accordance 

with the specifications of the 

Australian Standard for high-pressure 

pipelines (AS2885) to advise of the buried 

utility. Signs are required to be placed 

at property boundaries, pipeline bends 

and line-of-sight. In the rural landscape, 

pipeline markers are common place 

along roadsides, however, the Casino 

Gas Field Development pipeline is largely 

located away from roads as so marker 

signs will not be commonly seen. Unless 

one is looking out for marker signs, they 

generally go unnoticed in the landscape 

and are therefore unlikely to pose anything 

other than a low visual impact. 

Cathodic Protection Test Points. The 

pipeline will be protected from corrosion 

by applying an impressed current onto 

the pipeline to maintain a negative charge 

in a process known as cathodic protection 

(see Section 5.5.5). Cathodic protection 

test points (see Plate 5.17) are 

installed at intervals along the pipeline, 

generally at roadsides for easy access, 

to enable systems operation to be verified. 

The above ground component of 

the test point consists of a 1.5 m post. 

The test points are not intrusive and 

therefore will not impact on visual amenity. 

A test point will not be visible from 

the Great Ocean Road as it will be located 

within the MLV compound. 


Measures 

Appropriate pipeline route selection and 

facility planning is the foremost means 

of achieving minimal impacts on the 

visual amenity of this visually sensitive 

area. Measures to mitigate potential impacts 

to visual amenity include: 

• Subsea wellhead completion to avoid 

any potential impacts to visual amenity 

from the shore that might otherwise 

detract from the high scenic 

values of the area. 

• Onshore, the pipeline will be buried 

below ground, and traverses open 

farmland for over 99% of its length 

(resulting in very little vegetation 

clearance). 

• HDD of the shore crossing prevents 

visual intrusion of a cleared ROW 

through the Port Campbell National 

Park. 

• Minimising vegetation trimming in the 

Port Campbell National Park when 

installing the “Tru-Trak” HDD survey 

system. 

• Locating the HDD rig in farmland obscured 

by vegetation largely avoids 

visual impacts to tourists on the Great 

Ocean Road. 

• Aligning the pipeline to minimise vegetation 

clearance, particularly at 

roadsides. Where clearing native vegetation 

is required (i.e., the permanent 

MLV access track and the 

unsealed roads Smokey Point Road 

and Cheynes Road South), tree canopies 

will be left intact and continuous 

where practicable, and over hanging 

branches trimmed rather than whole 

trees removed, and the ROW narrowed 

from 24 m to 5 m. 

• Drilling (HDD) of sealed roads (i.e., 

Curdie Vale to Port Campbell Road 

and Cobden to Port Campbell Road) 

avoids vegetation clearance and road 

disruption, and therefore impacts to 

visual amenity. 

• The temporary HDD site access track 

will be removed and revegetated with 

local native species following construction 

and an existing narrow track 

further east will be cleared to 3 m 

wide for use as permanent access to 

the MLV site. 

• The MLV site will be located and 

configured to be screened by existing 

dense vegetation to minimise its 

visual presence on the landscape. 

The security fence will be painted or 

coated black and shade cloth will be 

attached, if necessary, to reduce 

visual impact. 

• Construction worksites will be located 

in existing disturbed areas where 

practicable, and away from populated 

areas and main roads. They will be 

structured and maintained in accordance 

with good industry housekeeping 

practices and site restoration 

undertaken post-construction. 

• All construction sites, including the 

pipeline ROW, will be maintained in 

an orderly manner and free of litter. 

• Construction equipment and infrastructure 

will be demobilised from site 

as soon as practicable and all unnecessary 

project environmental and 

safety flagging and signage will be 

removed and disposed of at the completion 

of construction. 

• Expeditious and appropriate ROW 

restoration (e.g., restoration of original 

contours and pasture planting) 

will minimise the time of bare-earth 

exposure and result in little visual 

evidence of the pipeline after several 

months (dependent on climatic conditions). 

• Native vegetation will be permitted to 

regenerate over the easement (excluding 

deep rooted vegetation directly 

over the pipeline) in areas 

where it is appropriate, for example, 

Campbells Creek and roadsides. Additional 

plantings of local native species 

shall be established where native 



vegetation has been cleared at 

roadsides and Campbells Creek. 

6.14 Noise 

This section deals with onshore noise 

describing existing conditions, potential 

impacts, and mitigation and management 

measures. Due to the complexity of underwater 

noise interactions with marine 

life, offshore noise impacts are addressed 

separately in Section 6.4. 


The proposed pipeline route traverses 

sparsely populated rural areas and is 

located a significant distance from highly 

populated areas (Port Campbell is located 

3 km east to the nearest point of 

the pipeline route and the HDD site). 

Background noise in the area is dominated 

by fauna (especially birds, frogs 

and insects such as crickets), wind (interaction 

with trees), ocean waves, rain, 

road traffic and agricultural sources such 

as farm machinery and general residential 

activities. All these noises vary in 

intensity and duration based on numerous 

factors, including meteorological and 

seasonal factors (Watson Moss 

Growcott, 1998). 

Noise levels are generally higher during 

the day than during the night, corresponding 

to higher levels of human activity 

during daylight hours (Watson Moss 

Growcott, 1998). Noise near the coast is 

dominated by the sound of waves, wind, 

birds and car traffic (Great Ocean Road), 

while in farmland, noise is dominated by 

fauna, wind, agricultural activity and occasional 

road traffic. 

Background noise measurements using 

continuous unattended logging and spotcheck 

attended logging in the project 

area have been undertaken by Watson 

Moss Growcott (1998, 2003) for the 

Minerva Project and Otway Gas Development 

respectively. As there are no 

permanent or continuous noise sources 

associated with the Casino Gas Field 

Development this information was relied 

on for this assessment. 

These noise measurements are provided 

in Table 6.16 and indicate the high variability 

in background noise levels within 

the project area. 

Noise Regulations 

The Interim Guidelines for Control of 

Noise from Industry in Country Victoria 

(EPA, 1989) are the most relevant noise 

guidelines for the Casino Gas Field Development 

and have been used in the 

Table 6.16 

Area 

Background Noise Level 

Comments 

dB(A) L A90 

Shore crossing 30 Calm conditions 

35 Light breeze, intermittent 

traffic 

50 Windy, breezes greater than 

4 m/second 

60 Light breeze conditions at 

Flaxman Hill 

Vicinity of Minerva Gas Plant 

site (pre-construction) 

Farmland north of Great 

Ocean Road 

Delaney property, Curdie 

Vale to Port Campbell Road 

WUGS site prior to 

construction 

Northeast corner of WUGS 

site during operation 

Source: Watson Moss Growcott (1998; 2003). 

design of existing and proposed gas facilities 

in the project area. These guidelines 

place limits on industrial noise 

during the day, evening and night (Table 

6.17). During construction, the background 

daytime noise limit can be raised 

by 10 dB(A), with an upper limit of 68 

dB(A). 

The EPA publication Noise Control 

Guidelines TG 302/92 (EPA, 1992) contradicts 

N3/89 in so far as it places no 

limit on noise created during the day, but 

places a limit on noise during the evening 

and requires that noise be inaudible during 

the night within a habitable room of 

any residential premises (Table 6.18). 


aim to meet the requirements of TG 302/ 

92. 


The onshore noise emissions associated 

with pipeline construction activities and 

HDD of the shore crossing are discussed 

below. 

Table 6.17 

Typical background noise levels within the project area 

21-27 Calm conditions 

30-36 Predominantly natural 

sources 

25-45 Insect and frog activity 

50-60 Windy conditions 

25-30 Slightly west of project area, 

but indicative of background 

rural noise 

25-30 Often below 25 dB(A) L A90 

during the day 

32-57 Higher levels correlating to 

higher wind speed rather 

than variations in plant noise 

output 

Onshore Pipeline Construction 

Noise emissions will result from all aspects 

of pipeline construction, primarily 

from diesel-powered, earth-moving 

equipment. The intensity of the noise 

generated by the construction activity will 

vary according to the equipment in operation 

at any one time. A list of construction 

activities and their associated 

typical noise levels are provided in Table 

6.19. 

This sequence of construction events is 

expected to take up to eight weeks at 

any one location but it is not constant, 

generally limited to two to three days at 

a time with intermittent breaks, as crews 

progress along the construction ROW. 

There are 10 residences located within 

500 m of the proposed pipeline route, 

three residences within 200 m and one 

residence within 100 m. Table 6.20 identifies 

residences within a 500 m radius of 

the proposed pipeline route and the pre- 

Period Day Evening Night 

dB(A) measured at residential 

premises 

EPA (N3/89) maximum noise limit guidelines 

45 37 32 

Day: 0700 - 1800 Monday to Friday, 0700 - 1300 Saturdays. 

Evening: 1800 - 2200 Monday to Friday, 1300 - 2200 Saturdays, 0700 - 2200 Sundays and public holidays. 

Night: 2200 - 0700 Monday to Sunday. 



dicted noise levels from pipeline construction 

that could potentially occur at 

each property. Figure 6.16 shows the 

locations of these residences. 

Potential noise levels from pipeline construction 

at residences F (100 m), and 

residences B, C and H (each 200 m) 

could be as high as 69 L A10 

dB(A) and 58 

dB(A)L A10 

, respectively. The higher predicted 

level (69 dB(A)L A10 

) is equivalent 

to the noise associated with being inside 

a moving vehicle (Woodside, 2003) and 

only marginally higher than times of moderate 

winds (see Table 6.16). These predicted 

noise levels are not continuous 

and are estimated to occur for approximately 

10% of the time and during daylight 

hours only. As pipeline construction 

activities will progress along the ROW at 

a rate of between 3-5 kms per day per 

activity over an 8-week period, significant 

noise nuisance is not likely to occur. 

HDD Shore Crossing 

The only dwelling located within 500 m 

of the HDD onshore shore crossing site 

is residence A, being 300 m to the northwest. 

Construction of the shore crossing 

is expected to take approximately 6 to 7 

months to complete, with actual drilling, 

the noisiest activity likely to take about 

30 days for each of the two drill holes 

depending upon geotechnical conditions. 

Drilling may be undertaken continuously, 

24 hours a day, 7 days a week for three 

months, as any significant shut-down 

may lead to drill hole collapse and the 

drill string becoming stuck down hole. 

A maximum noise level of 75 dB(A) at a 

distance of 50 m from unattenuated HDD 

rigs has been recorded during site testing 

studies for the Woodside Otway Gas 

Project (Watson Moss Growcott, 2003). 

Based on this, and the construction noise 

levels quoted in Table 6.19, maximum 

noise levels at residence A would be in 

the order of the 50 to 55 dB(A) during 

drilling. Background noise levels at the 

shore crossing site were recorded at between 

30 to 60 dB(A)L A90 

(Watson Moss 

Growcott, 2003) and so it can be concluded 

that noise levels are unlikely to 

exceed the EPA guidelines of 10 dB(A) 

above background levels (Table 6.16) 

for any significant period during the day. 

However, night time noise level requirements 

are more onerous in that they 

must not be audible within any room of 

the residence. To achieve this additional 

attenuation may be employed, such as 

mobile noise attenuation barriers, or alternatively 

arrangements made with the 

Table 6.18 

Table 6.19 

EPA (TG 302/92) noise control guidelines 

Schedule Monday - Friday Saturday Sunday/Public 

Holiday 

Normal working 

hours 

07 00 - 18 00 07 00 - 13 00 N/A 

Noise level at any 

residential premises 

not to exceed 

background by (i) 

10 dB(A) or more 

for up to 18 months 

after project 

commencement, (ii) 

5 dB(A) or more 

after 18 months 

Noise inaudible 

within a habitable 

room of any 

residential premises 

Maximum predicted noise levels, L A10 

dB(A) 

Activity 

Receptor Location in Relation to Activity 

100 m 200 m 300 m 

Clearing 68 56 47 

Grading 61 51 42 

Trenching 66 56 50 

Stringing 59 49 43 

Bending 58 49 42 

Welding 61 52 46 

Joint coating 59 50 44 

Lowering-in and backfill 66 56 50 

Fabrications 60 50 44 

Tie-ins 66 56 50 

Clean-up 61 52 45 

Road crossings 65 55 49 

Hydrotesting 69 58 49 

Source: Watson Moss Growcott (2003). 

Table 6.20 

Residence 

06 00 - 22 00 13 00 - 22 00 07 00 - 22 00 

22 00 - 07 00 22 00 - 07 00 22 00 - 07 00 

Predicted noise levels at residences within 500 m of the pipeline route 

Distance to Pipeline 

(m) 

Predicted Highest 

Noise 

(dB(A)L A10 ) * 

A 300 (to HDD site) 50 Quiet street 

Comparable Common 

Sound Levels 

(dB(A)) # 

B 200 58 Normal conversation 

C 200 58 Normal conversation 

D 350


668000 670000 672000 674000 676000 678000 

Co 


North -SouthRoad 


Gas Plant 

Heytesbury 

Gas Plant 


F 

G 

H 

I 


J 

Tregea 

Road 

Waarre Road 

Proposed 

Otway Gas 

ProjectPlant 

C r e ek 

W allab y 

TXU 

WUGS 

Facility 





Cobden-Port 

Campbell Road 

Pascoe Road 

Langleys 

Road 

r e ek 

Brumbys Road 

C 

Minerva 

Gas 

Plant 

C 

B 

D E 

am pbells 

C 

Sharps Road 

0 0.5 1 

Currells Road 

Rounds Road 

A 

Port Campbell 

Legend 

Kilometres 


Road 

Creek 


Proposed Otway Gas Pipeline 


HDD section 



Casino pipeline route alignment - 500m buffer 

House 

Figure 6.16 Residences within 500m of the proposed Casino pipeline 

C r eek 

Boundary Road 

S prin g 

Jarvis Road 

5724000 5726000 5728000 5730000 



occupants of Residence A to ensure 

noise nuisance does not result from the 

drilling activity. Santos has commenced 

discussions with the potentially effected 

landholder. 

Operations 

The TXU WUGS facility will provide compression 

facilities for the withdrawal and 

transport of gas from the Casino Gas 

Field Development. As operation and licensing 

of the TXU WUGS facility is the 

responsibility of TXU any potential noise 

issues associated with the processing of 

gas from the Casino Gas Field Development 

are required to be considered under 

the current EPA licence for the facility. 

Whilst it is unlikely that the processing of 

gas from the Casino Gas Field Development 

will in itself result in increased noise 

emissions from the TXU WUGS facility, 

this assessment can only be made by 

TXU. 

There are no noise impacts associated 

with the operation of the pipeline, with 

the exception of an emergency gas release 

(this would take place either at the 

offshore well site, the TXU WUGS facility, 

or at the mainline valve site, in order 

of preference). The occurrence of emergency 

venting would be extremely infrequent, 

if at all, and would only be required 

in response to a significant emergency. 


Measures 

The following mitigation measures will 

be adopted to reduce the potential for 

noise impacts: 

• Schedule pipeline construction in accordance 

with relevant EPA guidelines, 

TG 302/92 (EPA, 1992). Given 

the existing background noise of the 

project area, and the low number of 

houses within 100 m of the proposed 

pipeline route, the EPA guidelines 

are not likely to be exceeded. 

• Schedule noisy activities associated 

with the HDD for the day period, 

where practicable (0700 - 1800 Monday 

to Friday, 0700 - 1300 Saturdays). 

• To achieve this additional attenuation 

may be employed, such as mobile 

noise attenuation barriers. 

• Undertake measures to attenuate 

noise at the HDD site to limit noise 

impacts to Residence A, as appropriate. 

Alternatively implement arrangements 

with the occupants of 

Residence A to ensure noise nuisance 

does not result from the drilling 

activity. 

• Keep local residents informed about 

the progress of construction activities, 

the duration of works and noise 

that may be expected, particularly, 

when unavoidable out-of-hours work 

is required, especially at the HDD 

site. 

• All motorised earthmoving equipment 

will be fitted with suitable mufflers 

and be maintained in good condition. 

• Construction access shall be located 

away from houses, where practicable. 

• Complaints of excess noise from local 

residents will be promptly investigated 

and appropriately addressed. 

A register of any such complaints 

shall be maintained. 

6.15 Air Quality 

This section outlines the existing air quality 

in the study area, and describes the 

potential impacts associated with the proposed 

Casino Gas Field Development, 

and mitigation and management measures. 


Climatic conditions of the project area 

are described in Sections 6.1 and 6.2. 

Wind is one of the more important climatic 

parameters when considering air 

quality, as it can transport emissions to 

and from an area. The most frequent 

wind directions around Port Campbell 

are southwesterly, westerly, northeasterly 

and northerly, with an average speed 

of 6.5 m/s. Wind is predominantly from 

the northwest between May and August, 

and from the southern half of the compass 

between November and March 

(Enviromet, 1998). 

Quantitative data on regional ambient 

air quality was acquired for the environmental 

assessment of the Minerva, TXU 

WUGS and Otway Gas projects. Air emissions 

from sources within the project area 

generally result from road traffic, agricultural 

practices (e.g., stock) and emissions 

from the three operational gas 

facilities. Air emissions from the gas facilities 

predominantly includes nitrogen 

dioxide, sulphur dioxide and carbon monoxide 

(ERM, 2003). Emissions from these 

gas facilities are required to meet EPA 

nominated criteria for air quality at the 

gas plant boundaries. 

Outside, but near to the project area 

(i.e., Timboon, Cobden, Allansford) are 

numerous fixed emission sources, including 

dairy product manufacturing, mineral, 

metal and chemical wholesaling and sewage 

and drainage services which emit 

particulate matter, nitrogen dioxide, carbon 

monoxide and volatile organic compounds 

(ERM, 2003). 

In general, the concentration of these 

pollutants is very low (within accepted 

air quality targets) and are rapidly diffused 

and dispersed by prevailing winds. 

Therefore, the project area and surrounds 

can be characterised as having good air 

quality. 


Well testing undertaken during the drilling 

of Casino 1, 2 and 3 indicates that 

the raw gas has a very low carbon dioxide 


sulfur oxides or nitrous oxides, 

and is therefore within sales gas specifications. 

Similarly, gas compression will 

be provided by existing infrastructure at 

the TXU WUGS facility. Consequently, 

the receipt and processing of natural gas 

from the Casino Gas Field Development 

is not expected to contribute to emissions 

from the TXU WUGS facility. 

Potential air quality impacts associated 

with the Casino Gas Field Development 

are limited to construction activities that 

may generate dust or exhaust emissions, 

including: 

• Vegetation and topsoil removal. 

• Movement (exhaust emissions and 

generation of dust on unsealed roads, 

construction sites and the ROW) and 

operation of vehicles and heavy machinery. 

• Wind erosion from exposed soil surfaces 

and spoil stockpiles. 

Sensitive receptors for nuisance or hazard 

dust include road users and individual 

residences located near the 

pipeline. The 10 residences within 500 m 

of the pipeline (see Figure 6.16) could 

potentially experience temporary nuisance 

dust during onshore construction, 

for the scheduled three-month construction 

period. 

During construction dust emissions will 

be controlled by limiting the extent of 

disturbed soils, applying slow traffic 

speeds on unsealed roads and the construction 

ROW, applying water to stabilise 

exposed soils and avoiding 

earthworks adjacent to sensitive 


eceptors during periods of high winds 

where dust nuisance may result. 

No dust will be generated once the pipeline 

is installed and the ROW is 

revegetated. 


Measures 

The following measures will be implemented 

to mitigate potential impacts to 

air quality: 

• Limiting the extent of clearing and 

earthworks. 

• Minimising vehicle access to the 

ROW where it is adjacent to residences 

and poses a risk of dust nuisance. 

• Monitoring for dust generation during 

construction and undertaking water 

stabilisation (using water trucks) as 

appropriate. 

• Restricting vehicle speeds on unsealed 

tracks, the construction ROW 

and all work sites. Vehicle speeds 

will be restricted further during windy 

conditions. 

• Clearing and grading (and all other 

earthworks) will be avoided in windy 

conditions where there is risk of dust 

nuisance or loss of soil through wind 

erosion. 

• Complying with vehicle and equipment 

exhaust emission standards 

(Environment Protection (Vehicle 

Emission) Regulations, 1992) and 

ensuring that vehicles and plant are 

mechanically sound, appropriately 

maintained and fitted with appropriate 

emission control equipment. 

• Covering truck loads (for example, 

for transportation of sand for pipeline 

bedding, or additional topsoil for ROW 

restoration) where they are higher 

than the top of the tray. 

• Minimising the period surfaces are 

exposed, and promptly rehabilitating 

and reseeding the construction ROW 

and worksites at the completion of 

construction. 


Given the short period of onshore pipeline 

construction and the application of 

the aforementioned mitigation measures, 

impacts to air quality are unlikely to occur 

as a result of the construction or 

operation of the Casino Gas Field Development. 

6.16 Greenhouse Gas 

6.16.1 Background 

The ‘greenhouse effect’ is the phenomenon 

by which global temperature rise 

occurs due to the trapping of heat by 

layers of gas in the earth’s atmosphere. 

Gases that contribute to this effect are 

termed ‘greenhouse gases’. 

The Kyoto Protocol to the United Nations 

Framework Convention on Climate 

Change sets out obligations of specified 

parties to reduce their anthropogenic 

emissions of greenhouse gases with a 

target of 5% below 1990 levels in the 

period 2008 to 2012. 

Almost 99% of emissions from the combustion 

of fossil fuels are the greenhouse 

gas, carbon dioxide (CO 2 

). The other 

major greenhouse gases associated with 

fuel combustion include methane and nitrous 

oxide. Different greenhouse gases 

have different global warming potential. 

To enable direct comparisons between 

the effects of different gases, the global 

warming potential gases are expressed 

relative to CO 2 

over a set time horizon (a 

100-year horizon is generally used in 

policy analyses) and are referred to as 

CO 2 

-equivalents (CO 2 

-e) 6 . The global 

warming potentials applied by the Australian 

Greenhouse Office are: 1 for CO 2 

, 

21 for methane and 310 for nitrous oxide. 

6.16.2 Sources of Greenhouse Gases 

Greenhouse gas emissions vary over the 

life of the project. During the construction 

stages the direct sources of greenhouse 

gas emissions associated with the 

project include: 

• Combustion emissions from onshore 

vehicles, offshore vessels, plant and 

equipment (e.g., generators). 

• Flaring natural gas during well testing 

(limited to less than 24 hours per 

well). 

• Venting natural gas during pipeline 

purging on commissioning (limited to 

minor amounts for economic reasons). 

During the operation stage of the project 

there will be minimal emissions including: 

• Minor emissions associated with pipeline 

maintenance and condensate 

transport vehicles. 

• Low-level fugitive emissions from the 

gas pipeline facilities (e.g., seals, 

flanges and valves). 


• Planned maintenance or emergency 

venting of natural gas. 


generate minor greenhouse gas emissions 

during the construction and installation 

stages. These emissions are 

short-term and not significant contributors 

to Victoria’s or Australia’s total emissions. 

Emissions during operation of the pipeline 

will be minimal comprising fugitive 

emissions and minor vehicular emissions. 

The end use of the gas is the other stage 

in the product life (rather than project 

life) where greenhouse gas emissions 

occur. It is not known what the exact end 

use of gas from the processing facility 

will be, however, it will almost definitely 

be used to produce energy. Natural gas 

emits less carbon dioxide equivalents 

per unit of energy than the combustion 

of any other fossil fuel. Therefore, assuming 

the gas replaces the use of some 

other fossil fuel there will be an overall 

reduction in greenhouse gas emissions 

at the consumer end. 


Measures 

Santos recognises the importance of pursuing 

strategies to address greenhouse 

gas emissions associated with its operations 

and are a voluntary signatory to the 

APPEA Greenhouse Challenge. Santos 

has developed an environment, health 

and safety standard which addresses the 

quantification and reporting of greenhouse 

gas emissions and their reduction 

management from all Santos operated 

facilities. 

Within this policy framework Santos will 

work to minimise potential emissions by: 

• Ensuring that company owned/operated 

vehicles, as well as those operated 

by construction contractors and 

operations contractors (e.g., condensate 

transporters) are well maintained 

to maximise their fuel efficiency and 

minimise emissions. 

• Implementing an operations maintenance 

program which aims to minimise 

fugitive emissions from the 

system. 

6 This is calculated by multiplying the actual mass 

of emissions by the appropriate Global Warming 

Potential factor published by the Intergovernmental 

Panel on Climate Change (IPCC, 1995 as cited in 

AGO, 1998). 



• Minimising quantities of vented natural 

gas during commissioning and 

operations. 

• Design and operation of the Casino 

Gas Field Development to achieve 

as low as reasonably possible 

(ALARP) risk of an event which may 

lead to a gas rupture and/or an emergency 

release of gas (Section 6.18). 

6.17 Traffic 

This section outlines existing traffic conditions 

in the study area, and describes 

potential impacts of traffic associated with 

the onshore aspects of the proposed 

Casino Gas Field Development and impact 

mitigation and management measures. 

Issues relating to impacts to road 

infrastructure are addressed in Section 

6.11. 


Road Types and Conditions 

A summary of the conditions of the roads 

intersected by the pipeline are presented 

in Table 6.21. Roads are listed in order 

of crossing, from the coast to the TXU 

WUGS facility. Figure 5.4 shows the locations 

of these and nearby roads in the 

project area in relation to the proposed 

pipeline route. 

Traffic Types and Volumes 

The trafficked roads in the project area 

are the Great Ocean Road and Cobden 

to Port Campbell Road. Estimated traffic 

levels in 2002 indicate daily total traffic 

movements (2-way, 24-hr) on these 

roads at about 1,400 and 660 vehicles 

respectively (Maunsell, 2003). 

Common vehicles, such as passenger 

cars, light trucks and certain categories 

of prime mover and semi-trailer combinations 

and mini B-doubles (up to 50 

tonnes) can travel on the Victorian network 

of roads without the need for a 

permit (Maunsell, 2003). Some other vehicle 

types, however, require permits to 

travel on the road network along approved 

routes only. These include B- 

doubles in the 50 to 68 tonne category 

(Woodside, 2003). The only road in the 

project area approved for B-double use 

is the Cobden to Port Campbell Road 

(south of the Timboon to Colac Road). 

Most roads within the project area are 

school bus routes. Port Campbell and 

Peterborough are not serviced by school 

buses (as there are no schools in these 

towns), however, 14 school buses service 

the nearby towns of Timboon and 10 

service Cobden. Hours of operation generally 

coincide with morning pick-ups 

(7.30 am to 9 am) and afternoon drop 

offs (3 pm to 5 pm). 

Tourist coaches operate year-round in 

the region, predominantly along the Great 

Ocean Road, where access to natural 

features such as The Twelve Apostles is 

made easy. Milk tankers commonly travel 

the local roads servicing the numerous 

local dairies. 

Heavy traffic and passenger vehicle traffic 

from the areas gas plants predominantly 

use the sealed road network that 

can accommodate heavy and frequent 

traffic loads. 


Potential impacts from project traffic relate 

to access to project areas by construction 

vehicles and the transportation 

of condensate during project operation. 

Construction Traffic 

The highest traffic numbers will occur 

during construction with the transport of 

equipment, plant, materials and personnel 

to and from, and within the project 

area. 

The following equipment and materials 

will be transported to the project area: 

• Raw gas line pipe delivered by semitrailer. 

• MEG line pipe delivered by semitrailer. 

• Plant, equipment and material (including 

MLV, HPU and EPU) delivered 

by semi-trailer. 

• HDD rig and support equipment (e.g., 

crane, pumps, generators, portable 

offices, storage sheds) delivered by 

semi-trailers. 

• Clearers, graders, bucket-wheel 

ditcher, pipe-bending machinery, 

side-boom tractors delivered by lowloader 

semi-trailer. 

Pipeline construction equipment will be 

delivered to the pipeline ROW. HDD plant 

and equipment will be delivered to the 

HDD site at the Great Ocean Road and 

the MLV site plant will be delivered to the 

MLV site (within the HDD site) following 

shore crossing construction. Pipeline 

lengths will be delivered directly to the 

appropriate section of the construction 

ROW for welding. 

Each length of raw gas pipe is 18 m 

long, with one standard semi-trailer able 

to carry approximately 13 pipe lengths. 

Approximately 633 pipe lengths are required 

based on a pipeline length of 

11.5 km, therefore approximately 48 

semi-trailer return trips will be required 

to deliver raw gas pipe to the ROW. In 

addition, each length of MEG pipe is 

12 m long, with one standard semi-trailer 

able to carry approximately 232 pipe 

lengths, resulting in 4 semi-trailer return 

trips required to deliver the 942 MEG 

pipes to the ROW. 

A construction workforce of between 25 

to 45 personnel (at its peak) will be used 

for the onshore component of the project 

and will be required to access the project 

areas between the TXU WUGS facility 

and the shore crossing, as well as travel 

to and from the region. In addition, Santos 

project management and other support 

services personnel will travel to the 

project area on a less frequent basis. As 

the workforce will be accommodated in 

local motels or a construction camp, vehicle 

sharing will be maximised to reduce 

the number of project-related 

vehicles. 

Operations Traffic 

During operations the Casino gas field 

will produce minor amounts of condensate 

liquid which will be removed from 

the gas stream at the TXU WUGS facility 

and transported by Santos to a refinery 

as petroleum feedstock. Condensate production 

is expected to be low, about 

0.01 m 3 /h per MMscfd (million standard 

cubic feet per day). This equates to two 

to three single (not B-double) condensate 

truck movements per week, declining 

to about one truck per week after the 

first two years of production, for the remaining 

of field life (about 10 years). As 

Santos’ Heytesbury gas plant is nearing 

the end of production, the condensate 

truck traffic from the Casino Gas Field 

Development will replace the condensate 

traffic from the Heytesbury gas plant, 

effectively resulting in no net increase in 

condensate traffic. 

Other operational traffic will be limited to 

infrequent inspections of the pipeline by 

4WD-passenger vehicle generally from 

roadsides and by foot, as vehicles will 

not frequently travel over the easement 

except during maintenance activities. 


Measures 

Mitigation of traffic impacts relates primarily 

to the planning and management 

of construction access, and the subsequent 

implementation of a traffic management 

plan. This will be developed in 

consultation with VicRoads and the 

Corangamite Shire. 



The construction traffic management plan 

would identify: 

• Project safety requirements—e.g., 

identifying project area speed limits 

and other protocols. 

• Approved project transport routes and 

procedures—e.g., avoiding heavy, 

oversized vehicle transport on single-lane 

country roads or other highrisk 

routes, and convoys of trucks 

and heavy vehicles will be avoided to 

minimise traffic delays. 

• Periods of controlled access—e.g., 

avoiding heavy vehicle transport on 

school bus routes during school bus 

schedules. 

• Protocols for notification to road users 

of impending construction activities—e.g., 

notifications through local 

media and road signage in accordance 

with VicRoads and Corangamite 

Shire requirements. 

Procedures for access and traffic management 

during construction will be 

agreed with relevant landholders, 

VicRoads and Corangamite Shire, as 

appropriate, and documented in operations 

procedures. In particular, condensate 

traffic shall follow those routes 

already identified for such traffic from 

the TXU WUGS facility. 


The potential impacts associated with 

pipeline construction traffic include road 

safety and potential interruption to traffic 

movements. Road safety is recognised 

as a significant issue for the project to 

manage, particularly when other road 

user types are considered (e.g., tourists 

unfamiliar with road conditions, school 

buses, farm machinery, and milk and 

condensate transporters). 

A detailed construction traffic management 

plan will be developed and implemented 

in consultation with the 

Corangamite Shire, Parks Victoria, 

VicRoads and landholders, as appropriate. 

The plan will comply with the Road 

Safety Act 1986 and relevant Australian 

Standards and will consider the principles 

of the draft Great Ocean Road Region 

Land Use and Transport Strategy 

(DSE, 2003b). 

6.18 Hazard and Risk 

This chapter addresses safety hazard 

and risk associated with the onshore and 

offshore pipeline and ancillary facilities. 

Environmental risks are addressed in previous 

sections of Chapter 6. 

Due to statutory safety regulations and 

the petroleum pipeline industry’s diligence 

in risk assessment and management, 

pipelines are a significantly low 

risk means of gas transportation. 

Gas pipeline safety in Victoria is regulated 

under the Pipelines Act 1967 and 

the Gas Safety Act 1997, administered 

by Minerals and Petroleum Victoria and 

the Office of Gas Safety, respectively. In 

January 2005, responsibility for offshore 

petroleum safety regulation in Commonwealth 

and state waters will be transferred 

to the new National Offshore 

Petroleum Safety Authority (NOPSA). 

Mitigation planning will be implemented 

under the new regulatory framework. 

The Pipelines Act 1967 requires that a 

detailed risk assessment be undertaken 

in accordance with the requirements of 

the Australian standard for high pressure 

gas pipelines, AS2885.1 prior to 

the granting of a Pipeline Licence. 

The key steps in the risk assessment 

process include: 

• Risk identification. 

• Risk assessment. 

• Risk management. 

A safety case study is also required for 

the pipeline and offshore production facilities 

and is submitted in support of 

applications for the relevant pipeline and 

production licences. 

The pipeline alignment has been selected 

based on risk criteria identified under 

Australian standard AS2885. Pipeline 

design will be finalised during the detailed 

phase based on the outcome of 

the detailed risk assessment and safety 

case. 

A qualitative risk assessment has also 

been conducted for the offshore pipeline 

and wellhead production facilities, and 

considers risks associated with potential 

snagging by commercial fishing and shipping 

activities. 

The key safety features in the design 

and management of the Casino Gas Field 

Development are: 

• Undertaking a route selection process 

that has resulted in the minimisation 

of potential risks, based on 

the criteria identified in AS2885. 

• Design, operation and maintenance 

of the pipeline and production wells 

to ensure risk level is As Low As 

Reasonably Practicable (ALARP). 

• Design measures include: 

– Burial of the onshore pipeline with 

appropriate depths of cover, commensurate 

with potential risk. 

– Selection of appropriate pipe wall 

thickness commensurate with 

level of risk (e.g., pipe wall thickness 

is increased for the offshore 

section to add weight and at roads 

and creeks for increased 

strength). 

–A mainline valve near the coast 

to permit isolation and venting of 

sections of the pipeline in the 

event of an emergency. 

– Pipeline warning signs erected 

over the pipeline easement to 

identify the buried utility. 

– Buried marker tape placed above 

the pipe in the trench backfill to 

alert third parties to the presence 

and location of the pipe during 

excavation over the pipe. 

– Marking of well exclusion zones 

on maritime charts and provision 

of offshore pipeline and well coordinates 

for commercial fishers 

navigation systems. 

– Security fencing to prevent unauthorised 

access to the mainline 

valve site. 

– External barrier protection in highrisk 

areas to protect the pipe from 

collision (e.g., bollards to prevent 

work vehicle collision with aboveground 

structures at mainline 

valve site). 

- Trawl and anchor-proof offshore 

well and umbilical termination assembly 

infrastructure. 

• Management measures include: 

– Continued liaison by operations 

personnel with all relevant 

landholders, asset/utility managers 

and commercial fishers regarding 

pipeline and well 

operations and maintenance activities. 

– Santos personnel present during 

any third party excavations near 

the pipeline. 



– Pipeline monitoring by experienced 

operations personnel who 

will conduct ground patrols over 

the entire easement for the life of 

the pipeline. 

– Implementation of the Santos 

Construction Safety Management 

System during pipeline construction, 

incorporating a project specific 

Safety Management Plan. 

– Incorporation of the Casino Gas 

Field Development into the 

Santos Safety Management System 

including the development of 

a project specific Safety Plan, 

Emergency Response Plan and 

Oil Spill Response Contingency 

Plan for the construction and operations 

phases. 

– Incorporation of the Casino Gas 

Field Development into the 

Santos Operations and Maintenance 

Program. 

– Project specific safety and emergency 

response training for operations 

personnel, but also 

emergency services organisations. 

–One-call public information hotline 

(phone: 1100). Santos subscribes 

to the Dial before you Dig program, 

which is a national database 

providing information on the 

location of underground services 

upon request, and a pipeline incident 

reporting system. 

Bushfires 

Bushfires are a common occurrence in 

Australia, although rainfall in the project 

area is relatively high the risk of bushfire 

cannot be overlooked, particularly as construction 

will be during the summer. 

Characterisation of the Issue. Although 

considered low, bushfire risk associated 

with the Casino Gas Field Development 

is based on two primary issues; the first 

is the potential for construction of the 

pipeline to generate a bushfire; and the 

second and lesser risk is the potential 

for bushfires to impact on the project. 

Construction of the pipeline involves a 

range of activities that present potential 

ignition sources and therefore fire risk. 

Of particular concern are the ‘hot work’ 

activities of grinding and welding the steel 

pipe. Construction is proposed for the 

drier months of the year, in particular 

summer, a time that presents the best 

ground conditions for construction, but 

highest potential fire risk. Other potential 

ignition sources include the hot engines 

of construction vehicles, particularly 

where vegetation debris can be lodged 

between the belly plates and engine or 

gearbox of vehicles and machinery. 

Chainsaws used in vegetation clearing 

can also generate sparks or hot exhausts. 

The risk of fire resulting from pipeline 

construction activities is largely reduced 

by the absence of significant tracts of 

forest and woodland along the alignment. 

Pipeline construction is also undertaken 

within a 24 m-wide ROW that is generally 

cleared of all fuel sources, such as 

vegetation, and the topsoil graded and 

stockpiled, which greatly reduces the risk 

of fire. 

Residual risk is managed through additional 

fire prevention measures, applied 

in accordance with the APIA Code of 

Environmental Practice (APIA, 1998), 

through the development of project specific 

guidelines created in consultation 

with relevant fire authorities. 

Bushfire Prevention and Response. 

Project specific fire prevention and response 

procedures shall be developed, 

within the project Safety Management 

Plan, in consultation with Victorian fire 

authorities (i.e., CFA, DSE and Shire 

Councils). The procedures shall include: 

• Equipping construction vehicles (particularly 

welding and vegetation clearing 

crews) with appropriate fire 

fighting equipment (e.g., knapsacks, 

rakehoes). 

• Ensuring that a water tanker with fire 

hose and power pump is in the project 

area during ‘hot work’ on days of 

elevated fire risk. The water tanker 

would also serve to control dust. 

• Training construction crews in the prevention 

and response to bushfires, 

including bushfire survival and evacuation 

procedures. 

• Undertaking continual consultation 

with fire authorities throughout the 

fire danger period, with regard to 

project progress and fire risk. 

• Complying with all relevant fire protection 

legislation, in particular, obtaining 

necessary permits for 

undertaking construction activities 

during days of Total Fire Ban. 

• Ensuring spark guards are fitted to 

chainsaws. 

• Erecting canvas shields, or similar, 

adjacent to welding or grinding activities 

during high fire risk periods to 

shield spark emissions. 

• Using diesel-fuelled vehicles only, to 

minimise spark risk. 

• Containing the generator for the Port 

Campbell National Park section of 

the “Tru-Trak” sensing cable within 

an area free of any fire hazards. 

• Ensuring survey or front-end construction 

crew vehicles are not parked 

over vegetation (e.g., long grass), and 

that vegetation debris is cleared from 

the belly plates of all vehicles regularly. 

• Prohibiting the lighting of open campfires 

on the easement or at work sites. 

During pipeline operations the risk of resultant 

bushfires is negligible, however, 

fire prevention and response measures 

will be incorporated into the project specific 

Safety Management Plan, based on 

those identified for the construction phase 

above. 


7. Environmental Management Framework 


This chapter describes the environmental 

management framework that will be 

applied to the Casino Gas Field Development. 

It describes the management 

system elements that will aim to achieve 

the project environmental objectives and 

targets, through the application of mitigation 

measures described throughout 

Chapter 6. Prescriptive environmental 

management planning will be undertaken, 

subject to the granting of environmental 

approvals and completion of the 

detailed design, in consultation with relevant 

stakeholders, in particular, commercial 

fisheries, landholders and 

regulatory authorities. 

7.1 Environment, Health and 

Safety Management 

System 

Santos has developed an environment, 

health and safety management system 

(EHSMS) based on international standards 

and industry best practice for application 

to all Santos operations 

(Figure 7.1). An overview of the Santos 

EHSMS is included as Appendix 2. 

The Santos EHSMS has been developed 

to be in accordance with the requirements 

of AS 4801:2000 

Occupational Health and Safety Management 

Systems and AS/NZS ISO 

14001:1996 Environmental Management 

Systems and is applicable to all existing 

and proposed Santos sites. 

The Santos EHSMS consists of two sets 

of standards: management standards 

and hazard standards. 

Management standards are documents 

that define the requirements necessary 

to ensure that environmental, health and 

safety risks are systematically managed. 

The management standards are grouped 

into five categories, as listed in Table 7.1. 

Hazard standards are documents which 

detail the specific controls required to 

manage the risks of specific hazards to 

acceptable levels. 

Policy 

EHS Standards 

System standards-management 

and hazard standards 

Assessment 

Common Group Processes 

Business Unit & Department 

Processes and Procedures 

IMS & Incident Reporting 

Santos Incident Management Plan 

Safety Leadership Training 

Developed to address unique 

features relating to the 

Business Unit or Department 

Environment and Safety Tools & Programs 

(common where possible) 

Figure 7.1 

Santos’ Environment, Health and Safety Management System 



For each standard, an assessment guide 

and auditor guide has or will be developed. 

The assessment guide is used to 

evaluate the status of implementation of 

the standard while the auditor guide is 

used to determine the level of conformance 

to the standard. The auditor guide 

provides additional detail as to the requirements 

for practical implementation. 

Within the framework of the Santos 

EHSMS, a project-specific environment 

plan (EP), for offshore components, and 

environmental management plan (EMP) 

for onshore components, will be prepared 

for the Casino Gas Field Development. 

The following sections provide a description 

of the important components of the 

Santos EHSMS management standards. 

7.1.1 Policy 

Santos is committed to conducting its 

operations in a manner that minimises 

the environmental footprint of their operations 

and protects employees and 

contractors. Santos’ environmental vision, 

commitment and policy statement 

(EHSMS 01) is outlined in Box 7.1. This 

policy outlines the company’s environmental 

goals and provides guidance for 

the EHSMS. 

7.1.2 Plan 

Legal and Other Obligations 

(EHSMS 02) 

Understanding legal and other obligations 

allows management to ensure the 

activities of Santos and contractors comply 

with environment, health and safety 

legal requirements. 

At the project level, the identification and 

review of relevant legislation, regulations, 

policies, industry standards and 

protocols, and the determination of implications 

for environmental management, 

commenced during the feasibility 

stage of the project and will continue 

through to decommissioning. 

Chapter 2 identifies key legislation and 

approvals applicable to the Casino Gas 

Field Development. An environmental 

compliance register will be established 

upon the receipt of project approvals to 

track legislation, procedural requirements 

and compliance. 

Objectives and Targets (EHSMS 03) 

Objectives and targets provide benchmarks 

upon which performance against 

the Environment, Health and Safety 

(EHS) Policies can be measured. Corporate 

environmental objectives and targets 

are set under Santos’ EHSMS. 

Category 

Policy 

Plan 

Implement 

Monitor and Evaluate 

Review 

Box 7.1 

Table 7.1 

Santos EHSMS management standards 

Management Standards 

EHSMS 01—Environment, Health and Safety Policies 

EHSMS 02—Legal and Other Obligations 

EHSMS 03—Objectives and Targets 

EHSMS 04—Environment, Health and Safety Improvement Plans 

EHSMS 05—Responsibility and Accountability 

EHSMS 06—Training and Competency 

EHSMS 07—Consultation and Communication 

EHSMS 08—Document and Records Management 

EHSMS 09—Hazard Identification, Risk Assessment and Control 

EHSMS 10—Contractor and Supplier Management 

EHSMS 11—Santos Operations 

EHSMS 12—Management of Change 

EHSMS 13—Emergency Preparedness 

EHSMS 14—Monitoring, Measurement and Reporting 

EHSMS 15—Incident and Non-conformance Investigation, 

Corrective and Preventative Action 

EHSMS 16—Management System Audit and Assessment 

EHSMS 17—Management Review 

Santos’ environmental vision, commitment and policy 

As Santos’ Managing Director, I am personally committed to working with our Environmental 

Committee of the Board, management and supervisors to ensure that the staff and 

contractors working for the Company have the knowledge and tools to act with high levels 

of environmental responsibility and achieve a standard of excellence in this field. 

At Santos, the term ‘Environment’ encompasses not only nature and the physical environment 

in which we work, but includes people, their work and the things they value. We 

believe that people are part of the environment - part of the problems, but also very much 

a part of innovative solutions. 

We intend to shrink and lighten the environmental footprint of our operations. We will build 

on past successes and continue to learn from past mistakes. This requires us to work 

together, strengthen the partnerships with our stakeholders and admit our dissatisfaction 

with the status quo. 

As with safety, environmental stewardship is the responsibility of all Santos employees 

and contractors. Environmental and cultural heritage induction and training will continue 

to receive high priority and will be supplemented with a renewed focus on our Companywide 

goal of meeting our corporate responsibilities in full. 

New ideas and new ways of avoiding or minimising our environmental impacts will be 

encouraged and rewarded. Our prime objective of growing Santos will be nurtured not at 

the expense of, but on the basis of, ethical behaviour, safe operations, partnerships with 

the community and an environmental objective of continuous improvement. 

We intend to be a leader in the petroleum industry. Excellence in environmental performance, 

safety and community partnerships will be a fundamental component of this goal. 

J. Ellice-Flint 

Managing Director 

November 2001 

Santos Ltd 



Project-specific, measurable environmental 

objectives and targets will be detailed 

in the EMP and EP for the Casino 


Environment, Health and Safety 

Improvement Plans (EHSMS 04) 

Environment, Health and Safety (EHS) 

improvement plans set out the specific 

initiatives, actions and milestones for 

achieving the EHS performance objectives 

and targets. Improvement plans are 

internal strategic planning documents 

rather than prescriptive environmental 

management procedures for mitigation 

of specific impacts. Prescriptive procedures 

will be provided in the EMP and 

EP prepared for the Casino Gas Field 

Development under EHSMS management 

standard 09. 

7.1.3 Implement 

The key aspects to the implementation 

of Santos’s EHSMS are outlined in management 

standards EHSMS 05 to 

EHSMS 13 (see Table 7.1). Preliminary 

information regarding implementation 

procedures and definition of responsibilities 

is outlined below. This will be further 

expanded following detailed design 

and the awarding of construction contracts, 

and will then be detailed in the 

EMP and EP. 

Responsibility and Accountability 

(EHSMS 05) 

Assignment of roles, responsibility and 

accountability ensures resources are 

appropriately used to implement, maintain 

and improve the EHSMS. Environment, 

health and safety outcomes are a 

line management responsibility. Line 

management is defined as: 

Management with direct responsibility 

and accountability for all aspects, 

operations, products and services, including 

environment, health and 

safety. 

In practice, line-management puts responsibility 

on the individual to ensure 

that they comply with all relevant EHS 

requirements as advised by Santos. 

Specific environmental responsibilities 

and accountabilities for the project will 

be assigned to Santos personnel and 

construction contractors. Table 7.2 provides 

a summary of the responsibilities 

of the key personnel who will oversee 

environmental management of construction 

and operation of the project. 

The construction contractors will be 

bound by their contracts with Santos, 

but are bound by all laws irrespective of 

their obligations to the proponent. The 

environmental obligations placed on 

Santos will also be placed on the construction 

contractor through the contract 

arrangements. 

The Casino Gas Field Development 

project will be regularly audited to ensure 

compliance with requirements of 

Santos’ EHSMS. Compliance with the 

terms of the environmental approvals, 

and specifically the EMP and EP, will be 

constantly reviewed and assessed by internal 

inspectors and external auditors. 

Any breach of the terms of the environmental 

approvals will require rectification 

to the satisfaction of the proponent. 

Training and Competency 

(EHSMS 06) 

An environmental training program will 

be conducted to raise awareness, provide 

information and enable construction 

personnel to fulfil their environmental 

management responsibilities. 

Field personnel involved in the construction 

and operation of the project, regardless 

of company, position or work duties, 

will attend an environmental induction 

session, designed to raise awareness of 

the project environmental management 

and legal requirements. 

Environmental inductions will include 

such topics as: 

• EHSMS requirements. 

• Environmental sensitivities. 

• Construction site access. 

• Waste management. 

• Aboriginal and historic heritage site 

management. 

• Weed and pathogen control. 

• Bushfire prevention. 

• Emergency response. 

• Incident reporting. 

Job-specific environmental training will 

also be conducted for personnel whose 

duties have significant potential to cause 

environmental impacts (e.g., earthworks 

crews) or where specialised environmental 

controls are required (e.g., construction 

of erosion and sediment control 

devices). In addition, job-specific environmental 

training will be provided for 

personnel whose duties involve the inspection 

and monitoring of construction 

activities (e.g., construction supervisors 

and field inspection personnel). 

The success of the environmental induction 

and training programs will be assessed 

through the monitoring and 

auditing programs, and training will be 

modified as necessary. 

During construction, environmental matters 

will be raised at the daily tool box 

sessions and EHS committee meetings, 

as required, for example, where a particular 

issue warrants discussion or modifications 

to work practices are necessary. 

Consultation and Communication 

(EHSMS 07) 

Stakeholder consultation has been an 

integral component of the environmental 

assessment process and it has facilitated 

stakeholder input into the planning 

of the Casino Gas Field Development. A 

range of consultation initiatives has been 

undertaken and will be continued 

throughout the life of the project (see 

Chapter 3). The proponent will undertake 

appropriate action in response to 

any issues raised during the construction 

or operations phases. 

Internal communication is facilitated by 

the Santos Board and Business Unit environment 

committees, as well as EHS 

site committees. Environmental matters 

are also communicated on a daily basis, 

as necessary, in the normal course of 

operations. 

Santos also undertakes reporting and 

notification of EHS incidents to relevant 

government agencies, as required by 

statute. Public reporting of EHS matters 

is included in the Santos annual report. 

Document and Records Management 

(EHSMS 08) 

Efficient information storage and retrieval 

is an essential aspect of project management, 

particularly to achieve issue 

resolution and continuous improvement. 

Santos has established an electronic 

document management system. Key to 

this system is the allocation of custodial 

responsibility to nominated individuals for 

all EHSMS documents. 

Hazard Identification, Risk 

Assessment and Control (EHSMS 09) 

Processes are necessary to systematically 

identify hazards, assess their risk 

and adopt control strategies to reduce 

risk to as low as reasonably possible 

(ALARP). 

The potential environmental impacts of 

the Casino Gas Field Development have 

been identified through a comprehen- 



Table 7.2 

Casino Gas Field Development environmental responsibilities 

Role 

Santos Project 

Manager 

Santos Offshore 

Engineering and 

Construction 

Manager 

Santos Offshore 

Drilling Manager 

Santos Onshore 

Engineering 

Coordinator 

Santos Onshore 

Construction 

Manager 

Santos Chief 

Environmental 

Adviser 



Adviser 

Responsibility 

• Reports directly to Santos executive management 

• Responsible for ensuring overall implementation of the Santos EHSMS at the project level 

• Establishes appropriate resources to ensure the Santos EHSMS is implemented 

• Reports to the Project Manager on environmental matters 

• Ensures the design and construction of the offshore pipeline and wellhead facilities is in accordance with Santos 

EHSMS requirements 

• Assesses compliance with the Santos EHSMS, EMP, EP and work procedures through regular inspection 


• Ensures the drilling and completion of the wells is in accordance with Santos EHSMS requirements 



• Ensures the design of the onshore pipeline and ancillary facilities is in accordance with the Santos EHSMS 

requirements 



• Ensures the construction of the onshore pipeline and ancillary facilities is in accordance with the Santos EHSMS 

requirements 


• Reports to Santos executive management on environmental matters 

• Oversees the implementation and review of, and assesses compliance with the Santos EHSMS 

• Oversees the duties of the Santos Environmental Adviser 

• Reports to the Santos Chief Environmental Adviser and Project Manager on environment matters 

• Coordinates development and implementation of project specific aspects of the Santos EHSMS for the planning, 

construction and operations phases 

• Oversees the development and implementation of the EMP and EP for the operation phase 

• Reviews and assesses the environmental aspect of written work procedures and method statements prepared by 

the contractor prior to their implementation 

• Coordinates stakeholder consultation for the project on lands and environmental matters 

• Monitors the activities of the construction contractors and assesses compliance with the Santos EHSMS, and 

specifically the EMP and EP, and other relevant environmental procedures, policies, guidelines and legislation 

• Coordinates the Aboriginal heritage monitors 

• Engages and oversees the work of additional environmental and lands personnel or specialists, as required 

Lands Adviser • Reports to the Santos Environmental Adviser and Project Manager on lands and environmental matters 

• Responsible for advising and responding to landowner related matters 


Specialists 

Construction 

Contractors 

• Environmental auditors will conduct compliance audits against the requirements of the Santos EHSMS including 

environmental procedures, relevant legislation, licence and permit conditions and industry standards. The auditors 

will report to Santos Project Manager through the Santos Environmental Adviser 

• Specialist environmental consultants may be engaged by Santos or the construction contractor on an ‘as needed’ 

basis to provide specialist technical advice during construction and operation of the project. Issues that may be 

addressed by specialist consultants include construction environmental management, heritage, terrestrial and 

marine ecology, soil conservation, rehabilitation and weed management 

• Undertakes work in a manner that complies with contractual requirements, and in particular, the Santos EHSMS, 

relevant environmental procedures and legislative requirements 

Heritage Monitors • Represent the interests of the relevant Aboriginal community 

• Reports to the Santos Environmental Adviser 

• Monitors for new Aboriginal cultural heritage material during initial clear and grade, and trenching activities 

• Consults with relevant Aboriginal community representatives with regard to construction progress and Aboriginal 

cultural heritage site management 

• Advises on and monitors the management of Aboriginal cultural heritage sites 



sive and systematic review and assessment 

process, culminating with their 

documentation in this report. The steps 

in this process included: 

• Preliminary feasibility assessment 

identifying broad potential development 

concepts and potential risks. 

• Consultation with key stakeholders 

to identify risks and scope the environmental 

impact assessment. This 

will continue throughout project planning, 

construction and operation. 

• Preliminary environmental advice to 

the Victorian Minister for Planning 

identifying the proposed development 

concept, potential environmental impacts 

and strategies for their investigation 

and management. 

• Preliminary assessment of potential 

impacts on matters of national environmental 

significance documented 

in the EPBC Act referral to the Commonwealth 

Minister for Environment 

and Heritage. Public comment was 

invited on the EPBC Act referral. 

• Environmental investigations and impact 

assessment involving a team of 

multi-disciplinary specialists. 

• Submission of preliminary documentation 

under the EPBC Act 1999 providing 

further clarification and 

assessment on project development 

and impact assessment in relation to 

matters of national environmental significance. 

Public comment was invited 

on the EPBC Act preliminary 

documentation. 

• Submission of this Environment Report 

in support of the pipeline permit 

application to document the wholeof-project 

impact assessment and 

mitigation measures to be implemented. 

Environmental Management Plan (Onshore) 

and Environment Plan (Commonwealth 

offshore). A risk based EMP 

and EP will be submitted for regulatory 

approval. The primary purpose of the 

EMP and EP is to: 

• Document project commitments and 

impact mitigation requirements. 

• Document conditions of approval resulting 

from the planning review and 

environmental approval process. 

• Provide the basis for the development 

of prescriptive environmental 

guidelines and work procedures to 

be prepared by the construction contractor. 

The EMP and EP will be based on the inprinciple 

guidelines outlined as mitigation 

measures in Chapter 6 of this report 

and the following key industry standards: 

• Australian Petroleum Production and 

Exploration Association, Code of Environmental 

Practice (APPEA, 2000). 

• Australian Pipeline Industry Association, 

Code of Environmental Practice 

(APIA, 1998). 

• Environmental guidelines for major 

construction sites (Victorian EPA 

Publication 480, 1996) (EPA, 1996). 

• Guidelines on the application of the 

Environment Protection and Biodiversity 

Conservation Act to interaction 

between offshore seismic operations 

and larger cetaceans. Department of 

Environment and Heritage, October 

2001 (Environment Australia, 2001). 

During the construction and operation 

phases, the review and assessment of 

impact predictions will continue through 

the environmental monitoring and auditing 

programs and environmental management 

procedures amended 

accordingly. 

Alignment Drawings. Alignment drawings 

are technical drawings displaying 

the survey and cadastral data for the 

entire pipeline alignment at a scale of 

approximately 1:10,000. Ortho-rectified 

(geographically referenced) photos 

based on strip aerial photography of the 

alignment are also incorporated into the 

drawings, providing a combined visual 

and cadastral interpretation of the pipeline 

route. 

Environmental sensitivities are identified 

on the alignment drawings, with crossreferencing 

to site-specific management 

requirements. 

Technical Drawings. The technical 

drawing series will provide a visual interpretation 

of the engineering specifications, 

work procedures or method 

statements for the Casino Gas Field Development. 

They will include environmental 

considerations in the technical notes 

or appendices, as appropriate, and may 

cover a range of design aspects. For 

example, they may address typical construction 

situations, which are common 

to a number of areas or situations (such 

as sediment fence installation), or they 

may address site-specific construction 

issues (e.g., open trenching of the 

Campbells Creek). 

Property Line List. The property line 

list is derived from the project stakeholder 

database, which will be used to 

record and advise construction and operations 

personnel of stakeholder details. 

The database was established at the 

time of property title searches and subsequent 

easement investigations. The 

database records landholder contact and 

notification details for each property or 

utility intersected along the route in sequential 

order. It also records information 

relating to safety, engineering, 

environment and agriculture practices 

(e.g., access points, stock management, 

pasture protection and weed issues). 

The list is constantly updated to reflect 

new information as it comes to hand and 

serves as a record of landholder consultation. 

Contractor and Supplier 

Management (EHSMS 10) 

Specialist construction contractors, who 

in turn will engage additional specialist 

construction firms and service companies 

as necessary, will construct the Casino 

Gas Field Development. The 

environmental performance of the construction 

contractors bidding for the 

project will be assessed within the tender 

evaluation process. 

Third parties working on behalf of Santos 

are required to have appropriate systems 

in place to ensure their activities 

are consistent with Santos’ policies and 

business objectives. 

Santos Operations (EHSMS 11) 

Operations are required to be conducted 

within established parameters and regulations. 

This requires effective procedures, 

inspection and maintenance 

systems, reliable safety and control facilities 

and qualified personnel who consistently 

execute these procedures and 

practices. 

Management of Change (EHSMS 12) 

Processes are required to ensure that 

changes in organisational structure, operations, 

procedures, standards, facilities 

or personnel, are evaluated and 

managed so that EHS risks arising from 

these changes remain at an acceptable 

level. 



Emergency Preparedness 

(EHSMS 13) 

Processes are required to ensure any 

foreseeable emergencies are able to be 

managed, so as to minimise any adverse 

impacts to the safety or health of 

people or the environment. 

The Santos incident management plan 

(SIMP) is the overarching emergency 

response document for all of Santos’ activities 

and details high-level responses 

to emergencies that may occur. In accordance 

with the SIMP, project specific 

emergency response plans (ERPs) will 

be prepared for the construction and operation 

phases. 

A marine oil spill contingency response 

plan (OSCRP) was developed for drilling 

of the Casino exploration wells during 

October 2003. This will be revised to 

incorporate drilling and completion of the 

proposed Casino development wells and 

offshore pipelay activities. Spill prevention 

and response during operations will 

also be detailed in the SIMP and ERP. 

7.1.4 Monitor and Evaluate 

Monitoring, Measurement and 

Reporting (EHSMS 14) 

Collection, analysis and reporting of EHS 

performance data is necessary to establish 

whether risks associated with Santos’ 

operations are being managed, minimised 

and, where reasonably practicable, 

eliminated. 

Environmental monitoring programs will 

be established for the construction and 

operation phases of the project in consultation 

with DSE and DPI. During construction, 

monitoring will be undertaken 

to gauge the success of the EHSMS in 

achieving the environmental management 

objectives, and to identify any required 

on-site remedial action or 

modifications to procedures. 

During operation inspections of the easement 

will be conducted on a regular basis. 

The easement and associated 

facilities will be inspected for a number 

of issues including land stability, weed 

infestation and revegetation progress. In 

the event that problems are identified, 

remedial work will be carried out as necessary 

by appropriately qualified and experienced 

personnel. Monitoring 

methods and records will vary depending 

on the environmental issues. Records 

will be logged into a database for analysis. 

In accordance with the determination by 

the Minister for Planning (dated 10 February 

2004) on the requirements for environmental 

approvals, a report on the 

environmental outcomes of the project 

to the post-construction stage will be submitted 

to DSE and DPI. 

Incident and Non-conformance 

Investigation, Corrective and 

Preventative Action (EHSMS 15) 

The purpose of an EHSMS is to systematically 

identify and manage environmental 

risks and impacts; the key principle of 

environmental management being to prevent 

significant environmental effects. 

This is realised through the implementation 

of the various EHSMS management 

standards. In the event of unforeseen 

events or system failures, the EHSMS 

also provides guidance to promptly identify 

and respond to such events to minimise 

impacts and prevent recurrence. 

At a practical level, the supervision and 

monitoring aspects of environmental 

quality control include formal processes 

for environmental improvement and rectification. 

These are: 

• Non-compliance reports (NCR) – issued 

when potential policy breaches 

are noted and investigation is required. 

• Corrective action request (CAR) – 

specifies the required rectification 

action. 

Where monitoring results indicate a potential 

excursion or abnormality from the 

performance criteria established under 

the statutory conditions, appropriate action 

will be undertaken to prevent and 

minimise the potential for environmental 

impacts in accordance with the Santos 

incident management system (SIMS) for 

the site. Investigation procedures will be 

initiated and appropriate rectification and 

improvement undertaken to minimise 

impacts and prevent a recurrence. 

The reporting of environmental performance 

and incidents will be undertaken 

internally in accordance with SIMS procedures, 

and externally in accordance 

with relevant regulatory requirements. 

Management System Audit and 

Assessment (EHSMS 16) 

The auditing of environmental performance 

will be undertaken regularly through 

informal and formal auditing processes. 

Santos personnel and construction contractor 

inspectors will monitor the environmental 

performance of the project 

against pre-determined performance criteria 

as a standard daily workplace procedure. 

In addition, a suitably qualified environmental 

auditor will undertake formal performance 

measurements. 

An environmental audit program will be 

developed comprising the audit protocol 

and schedule. A compliance register will 

be established to track and report on 

compliance with statutory requirements, 

such as licence conditions. 

The indicative audit schedule is as follows: 

• Construction — the first environmental 

audit will be conducted prior to 

commencing construction to ensure 

systems and procedures are in place 

in readiness for construction. Thereafter, 

environmental audits will be 

undertaken every three months up to 

commissioning. 

• Operations — the first environmental 

audit will be conducted within six 

months of commissioning. Thereafter, 

audits will be undertaken dependent 

upon rehabilitation success and 

due diligence requirements. 

The results of formal environmental audits 

will be reported to government and 

statutory authorities in accordance with 

relevant statutory requirements. Inspections 

and audits will also be conducted 

by regulatory authorities to assess project 

performance. 

7.1.5 Review 

Management Review (EHSMS 17) 

Periodic reviews of the overall effectiveness 

of the EHSMS will be undertaken 

by senior management to ensure continual 

improvement, sustainability and 

effectiveness. 


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WNI. 2003. Casino Project, conceptual 

development metocean study (Permit 

VIC-P44, Otway Basin) offshore 

Port Campbell Victoria. Report prepared 

by WNI Oceanographers and 

Meteorologists for Worley Oil and Gas 

Limited. 

Woodside Energy. 2003. Otway Gas 

Project Environment Effects Statement/Environmental 

Impact Statement. 

Main Report, Volume 1. 

Woodside Energy Ltd, Perth. 


9. Glossary 

9. Glossary 

The following terms and abbreviations 

are defined in the context in which they 

are used in this report. 

AAV abbr: Aboriginal Affairs Victoria. 

AC abbr: Alternating Current. 

AGA abbr: Australian Gas Association. 

AGO abbr: Australian Greenhouse Office. 

ALARP abbr: As Low as Reasonably 

Possible. 

ancillary facilities: facilities associated 

with a gas pipeline, such as metering 

facilities, valves and marker signs. 

ANZECC abbr: Australian and New 

Zealand Environment Conservation 

Council. 

API abbr: American Petroleum Institute. 

APIA abbr: Australian Pipeline Industry 

Association. 

AS abbr: Australian Standard. 

AVW abbr: Atlas of Victorian Wildlife. 

bathymetry: the science of measuring 

ocean depths in order to determine 

the sea floor topography. 

bcf abbr: billion cubic feet. 

bedding: imported material (typically 

sand) placed around the pipe to protect 

the coating from rocks in the 

trench spoil. 

bending: involves the bending of pipe, 

where necessary, to conform with 

land contours and changes in the 

pipeline route direction. 

bentonite: a type of naturally occurring 

non-toxic clay added to drilling mud. 

biota: living components of the ecosystem, 

such as plants, animals and 

microorganisms. 

BS abbr: British Standard. 

CAMBA abbr: China-Australia Migratory 

Bird Agreement. 

CAR abbr: Corrective Action Request. 

CFA abbr: Country Fire Authority. 

CMA abbr: Catchment Management 

Authority. 

compressor station: facilities which 

are often required to pump gas along 

the pipeline. 

CO 2 

abbr: Carbon dioxide. 

DEH abbr: Commonwealth Department 

of Environment and Heritage. 

DPI abbr: Department of Primary Industries. 

DSE abbr: Department of Sustainability 

and Environment. 

DSV abbr: Diver Support Vessel. 

easement: the legal property encumbrance 

within which the pipeline is 

placed. 

EIA abbr: Environmental Impact Assessment. 

EMP abbr: Environmental Management 

Plan. 

EMS abbr: Environmental Management 

System. 

EP abbr: Environment Plan. 

EPA abbr: Environment Protection Authority. 

EPBC Act abbr: Environmental Protection 

and Biodiversity Conservation 

Act 1999 (Cwlth). 

ephemeral: temporary in nature, such 

as creeks that flow only after rainfall. 

EPU abbr: Electrical Power Unit. 

ER abbr: Environment Report. 

EVC abbr: Ecological Vegetation Class. 

extant: existing, alive. 

FBE abbr: Fusion Bonded Epoxy. 

FIS abbr: Flora Information System. 

gas: a compressible fluid that completely 

fills any container in which it 

is confined. 

geotechnical: a term employed to describe 

the fields of soil and rock mechanics 

and engineering geology. 

GIS abbr: Geographic Information System. 

ha abbr: hectares. 1 ha equals 10,000 

square metres. 

HDD abbr: Horizontal directional drilling. 

HPU abbr: Hydraulic Power Unit. 

HSE abbr: Health, Safety and Environment. 

hydrotest: or hydrostatic testing is pressure 

testing of pipelines (for pipe and 

weld integrity) or other pressure-containing 

equipment using water as the 

pressure-test medium. 

ISO abbr: International Standards Organisation. 

JAMBA abbr: Japan-Australia Migratory 

Bird Agreement. 

km abbr: kilometre. 

KP abbr: kilometre point. An approximate 

measure of the horizontal distance 

along the proposed alignment. 

Kt abbr: Kilotonne (1,000 tonnes). 

landholder: a general term used to refer 

to the legal owner or manager of 

a parcel of land, be it a private 

landholder, government or private utility, 

or a government agency responsible 

for the management of a 

particular area of land (e.g., National 

Parks). 


9. Glossary 

laydown area: sites at which pipe and 

other equipment and supplies may 

be stored prior to delivery to the right 

of way or the construction camp. 

LGA abbr: Local Government Area. 

limestone: sedimentary rock that consists 

mainly of carbonate (CaCO 3 

), 

typically formed from the skeletal remains 

of marine or freshwater organisms. 

m abbr: metre. 

mainline valve: a valve used to control 

flow along a pipeline. 

mainline: alternate term for the open 

country sections of the pipeline. 

MEG abbr: Mono ethylene glycol. An 

anti-freeze chemical added to the gas 

stream to prevent hydrates (liquids) 

from forming in the pipeline. 

metering: measurement of gas flow 

volume. 

mm abbr: millimetre(s) 

MSDS abbr: Material Safety Data Sheet. 

Mt abbr: Megatonne (1,000 tonnes) 

MW abbr: Megawatt. 

natural gas: a highly compressible, 

highly expansible mixture of hydrocarbons 

having a low specific gravity 

and occurring naturally in gaseous 

form. Besides hydrocarbons gases, 

natural gas may contain appreciable 

quantities of nitrogen, helium, carbon 

dioxide, hydrogen sulfide, and 

water vapour. Although gaseous at 

normal temperatures and pressures, 

the gases comprising the mixture that 

is natural gas are variable in form 

and may be found either as gases or 

as liquids under suitable conditions 

of temperature and pressure. 

NB abbr: Nominal Bore. 

NCR abbr: Non-compliance Report. 

NZS abbr: New Zealand Standards. 

odourant injection: the injection of 

mercaptans, a chemical used to give 

the naturally odourless natural gas, 

an odour to enable detection during 

leaks. 

oil: a simple or complex liquid mixture 

of hydrocarbons, which can be refined 

to yield gasoline, kerosene, diesel 

fuel and various other products. 

padding: trench material suitable for 

backfilling the trench around the 

newly laid pipeline. 

petajoule: a derived SI unit of energy: 

one thousand trillion (10 15 ) joules (unit 

of work or energy). 

petroleum: a substance occurring naturally 

in the earth and composed 

mainly of mixtures of chemical compounds 

of carbon and hydrogen, with 

or without other non-metallic elements 

such as sulfur, oxygen and 

nitrogen. The compounds that compose 

it may be in the gaseous, liquid 

or solid state, depending on their nature 

and on the existent conditions of 

temperature and pressure. 

pig: a tool which is inserted into a pipeline 

and propelled along by the gas 

flow to internally clean and inspect 

the pipe. 

PJ abbr: Petajoule. 

planning scheme: a set of controls, 

comprising a set of maps and ordinance 

used to regulate the use and 

development of land, usually developed 

on a local council or shire basis. 

PSI abbr: Pounds per Square Inch. 

rehabilitation: the active restoration of 

a landscape, especially the vegetation, 

following its disturbance. 

riparian: pertaining to, or situated on, 

the bank of a river or stream. 

ripping: to rake soil with tynes or shallow 

ploughing to relieve compaction 

and aerate soils. 

ROW abbr: Right-of-way; the 24-m wide 

construction area. 

scraper station: an above ground facility 

used to launch and receive inline 

tools (pigs) which are inserted 

into the pipeline system. 

semi-submersible drilling rig: a floating, 

offshore drilling rig that has hulls 

submerged in the water but not resting 

on the sea floor. 

special crossing: roads and watercourses 

etc. along the pipeline which 

are constructed by small specialised 

crews. 

stringing: the delivery of pipe to the 

easement which is then laid end-toend 

alongside the trench. 

tie-in: to join two sections of a pipeline, 

such as between mainline and special 

crossing sections. 

TJ abbr: Terajoule. 

trench breaker: an engineering structure 

used to intercept the flow of water 

along a pipeline in a trench after 

the trench has been back-filled. 

trench spoil: material excavated from 

the trench. 

umbilical: controlling cable extending 

from onshore facilities to well heads 

used to control well operation. 

UNFCCC abbr: United Nations Framework 

Convention on Climate Change. 

VFD abbr: Victorian Fauna Database. 

wetland: a low-lying area regularly inundated 

or permanently covered by 

shallow water. Usually important areas 

for birds and other wildlife. 

WUGS abbr: Western Underground 

Gas Storage (gas plant at Iona) operated 

by TXU. 

x-ray inspection: a method of nondestructively 

testing weld joint integrity. 


Appendix 1 

Terrestrial Flora and Fauna Species Lists

Appendix 1 

Appendix 1 – Terrestrial Flora and Fauna Species Lists 

Flora Species List 

Vascular plant species were recorded along the proposed Casino Gas Field Development pipeline alignments as part of a flora and 

fauna survey undertaken by Brett Lane and Associates between the 24 th and the 26 th of February 2004. Taxonomy follows DSE/DPI 

(2003) with reference to Ross and Walsh (2003). Conservation status follows DSE (2003) and Ross and Walsh (2003). 

Status of species is designated as follows: 

X (national) 

E (national) 

e (state) 

V (national) 

v (state) 

R (national) 

r (state) 

K (national) 

k (state) 

Extinct 

Endangered 

Endangered 

Vulnerable 

Vulnerable 

Rare 

Rare 

Poorly Known 

Poorly Known 

Vegetation unit locations: 

Veg Unit No. 

A 

B 

C 

D 

E 

F 

G 

H 

I 

J 

K 

L 

M 

N 

O 

P 

Q 

Description/Location 

Port Campbell National Park adjacent to HDD site 

Sharps Road 

Brumby’s Road 


North to South Road 


Remnant patch on private land (Loft) south of Smokey Pt Rd 



Port Campbell Creek (north crossing) 

Disused road reserve east of Cobden-Port Campbell Road 


Link of revegetation b/n patches on Tregea and McCue properties 

Port Campbell Creek (south crossing) 

Cobden to Port Campbell Road 

Smokey Point Road (west crossing) 

Cheynes Road South (west crossing) 

Notes: 

∗ exotic species. 

# native species away from its natural range. 


Appendix 1 

Status 

List of flora species that occur or are likely to occur in the study area 

Vegetation Units 

Species Name Common Name 

D & 

F 

G 

L & 

H 

N M J E K O C B I 

Origin 

# Acacia longifolia ssp. longifolia Sallow Wattle x 

# Acacia longifolia ssp. sophorae Coast Wattle x 

Acacia melanoxylon Blackwood x x x x x x 

Acacia myrtifolia Myrtle Wattle x x x 

Acacia stricta Hop Wattle x x x x 

Acacia verticillata Prickly Moses x x x 

Acaena novae-zelandiae Bidgee-widgee x x x x x x x 

* Acetosella vulgaris Sheep Sorrel x 

Acrotriche serrulata Honey-pots x 

* Agrostis capillaris s.l. Brown-top Bent x x x x x x 

Allocasuarina paludosa Scrub Sheoak x x x x x 

Amperea xiphoclada var. xiphoclada Broom Spurge x 

* Anagallis arvensis Pimpernel x x x x x x 

* Anthoxanthum odoratum Sweet Vernal-grass x x x x x x x 

Arctotheca calandula Cape Weed x 

* Aster subulatus Aster-weed x 

Austrodanthonia pilosa Velvet Wallaby-grass x x 

Austrodanthonia sp. Wallaby Grass x x x x x 

Banksia marginata Silver Banksia x x x x 

Billardiera scandens Common Apple-berry x x 

Bossiaea prostrata Creeping Bossiaea x 

Bursaria spinosa ssp. spinosa Sweet Bursaria x 

Carex addressa Tall Sedge x 

Cassytha melantha Coarse Dodder-laurel x 

* Centaurium erythraea Common Centaury x x x x x x 

* Chenopodium album Fat Hen x x x 

* Cirsium vulgare Spear Thistle x x x x x x x x x 

Clematis aristata Mountain Clematis x 

* Conyza bonariensis Flaxleaf Fleabane x 

* Conyza sp. Fleabane x 

Coprosma quadrifida Prickly Currant-bush x 

* Cortaderia selloana Pampas Grass x x 

* Cotoneaster sp. Cotoneaster x 


Appendix 1 

List of flora species that occur or are likely to occur in the study area (cont’d) 


Origin 

Status 


D & 

F 

G 

L & 

H 


* Cretaegus monogyna Hawthorn x x x 

* Cupressus macrocarpa Monterey Cypress x 

* Cynodon dactylon Couch x x x 

* Dactylis glomerata Cocksfoot x x x x x x x x x 

Eleocharis acuta Common Spike-sedge x 

Epilobium billardierianum Variable Willow-herb x 

Eucalyptus kitsoniana Bog Gum x x 

Eucalyptus baxteri s.l. Brown Stringybark x 

Eucalyptus obliqua Messmate Stringybark x x x x 

Eucalyptus ovata Swamp Gum x x x x 

Eucalyptus viminalis Manna Gum x x 

Eucalyptus willisii Peppermint x x x x x 

Euchiton collinus s.l. 

Clustered/Creeping 

Cudweed 

x x 

Gahnia clarkei Tall Saw-sedge x x x x 

Gahnia radula Thatch Saw-sedge x x x x x 

* Galium murale Small Goosegrass x 

Gonocarpus micranthus ssp. micranthus Creeping Raspwort x x 

Gynatrix pulchella s.l. Hemp Bush x 

* Helminthotheca echioides Ox-tongue x x x x x x x 

Hemarthria uncinata var. uncinata Mat Grass x x 

Hibbertia truncata Port Campbell Guinea-flower R, r 

* Holcus lanatus Yorkshire Fog x x 

Hydrocotyle sp. Pennywort x 

* Hypochoeris glabra Smooth Cat's-ear x x x x x 

* Hypochoeris radicata Cat's Ear x x x x x x 

Hypolaena fastigiata Tassel Rope-rush x 

* Juncus articulatus Jointed Rush x 

Juncus bufonius Toad Rush x x x 

Juncus procerus Tall Rush x x x x x x 

Juncus spp. Rush x x x x 

Lachnagrostis filiformis Common Blown-grass x x 


Appendix 1 

Status 




D & 

F 

G 

L & 

H 


Origin 

Lemna sp. Duckweed x 

Lepidosperma filiforme Common Rapier-sedge x 

Lepidosperma laterale Variable Sword-sedge x x x x 

Leptospermum continentale Prickly Tea-tree x x x x x x 

Leptospermum scoparium Manuka x x x x x x x x 

Leucopogon australis Spike Beard-heath x x 

Leucopogon parviflorus Coast Beard-heath x 

Linum marginale Native Flax x x x 

Lobelia anceps Angled Lobelia x 

* Lolium sp. Rye-grass x x x x x 

Lomandra longifolia ssp. longifolia Spiny-headed Mat-rush x x x x 

Lythrum hyssopifolia Small Loosestrife x x x x x x 

# Melaleuca decussata Totem-poles x 

Melaleuca squarrosa Scented Paperbark x x 

* Melilotus indicus Sweet Melilot x x x x x 

* Modiola caroliniana Red-flower Mallow x 

Olearia ramulosa Twiggy Daisy-bush x 

Oxalis corniculata s.l. Yellow Wood-sorrel x 

Ozothamnus ferrugineus Tree Everlasting x x x x x x 

* Paspalum dilatatum Paspalum x x x 

* Pennistetum clandestinum Kikuyu Grass x x 

Persicaria decipiens Slender Knotweed x x 

* Phalaris spp. Canary Grass x x x x x x x x x x 

* Pinus radiata Radiata Pine x x x 

# Pittosporum undulatum Sweet Pittosporum x x 

* Plantago coronopus Buck's-horn Plantain x x 

* Plantago lanceolata Ribwort x x x X x 

Poa labillardierei Common Tussock-grass x 

Poa sieberiana Grey Tussock-grass x 

Poa sp. Tussock-grass x 

* Polygonum aviculare Prostrate Knot-weed x x 

* Polypogon monspeliensis Annual Beard-grass x 

Pomaderris aspera Hazel Pomaderris x x 

* Populus sp. Poplar x 


Appendix 1 

Status 




D & 

F 

G 

L & 

H 


Origin 

* Prunella vulgaris Self-heal x x x x 

Pteridium esculentum Austral Bracken x x x x x 

Pultenaea daphnoides Large-leaf Bush-pea x 

Ranunculus sp. Buttercup x x 

* Rorippa nasturtium-aquaticum Watercress x 

* Rosa rubigonosa Sweet Briar x 

* Rubus fruticosus spp. agg. Blackberry x x x x x x x x 

Rubus parvifolius Small-leaf Bramble x 

* Rubus sp. ? laciniatus Blackberry x 

* Rumex crispus Curled Dock x x x x 

* Salix sp. Willow x x x 

Sedge sp x 

Senecio minimus Shrubby Fireweed x x x x x x 

Senecio spp. Groundsel x x 

* Sisyrinchium iridifolium Blue Pigroot x x 

Solanum laciniatum Large Kangaroo Apple x x x x x 

* Solanum nigrum sensu Willis (1972) Black Nightshade x x x x 

* Sonchus oleraceus Common Sow-thistle x 

* Sporobolus africanus Rat-tail Grass x x x 

* Stenotaphrum secundatum Buffalo Grass x 

* Taraxacum officinale spp. agg. Garden Dandelion x 

Tetragonia implexicoma Bower Spinach x 

Tetrarrhena distichophylla Hairy Rice-grass x x x 

Tetrarrhena juncea Forest Wire-grass x x x x 

Themeda triandra Kangaroo Grass x 

* Trifolium spp. Clover x x x x x x x x x x 

Triglochin procerum s.l. Water Ribbons x 

Typha domingensis Norrow-leaf Cumbungi x 

* Urtica urens Small Nettle x 

* Vicia sativa Common Vetch x 

Viola hederacea sensu Entwisle (1996) Ivy-leaf Violet x 

* Watsonia meriana var. bulbillifera Bulbil Watsonia x 

Xanthorrhoea minor ssp. lutea Small Grass-tree x x 


Appendix 1 

Fauna Species List 

The study area has been substantially modified from its pre-European condition through clearing of vegetation for agricultural land 

use. Native vegetation within the study area is now largely confined to the Port Campbell National Park, roadsides and scattered 

patches on private land. The following list of fauna species are records from within the study area taken from the DSE Atlas of 

Victoria Wildlife (AVW). 

Status of species is designated as follows: 

DSE 

Status from DSE (2003b) 

EPBC 

Status under EPBC Act 

FFG 

Listed under FFG Act 

X (national) 

Extinct 

E (national) 

Endangered 

e (state) 

Endangered 

V (national) 

Vulnerable 

v (state) 

Vulnerable 

R (national) 

Rare 

r (state) 

Rare 

K (national) 

Poorly Known 

k (state) 

Poorly Known 

LR 

Lower risk near threatened 

Cmp 

Comprising several taxa 

L Listed as threatened under Flora & Fauna Guarantee Act 1988 

T Listed as threatening proces under Flora & Fauna Guarantee Act 1988 

Notes: 

* species. 

X = confirmed to occur during field survey. 


Appendix 1 

List of fauna species that occur or are likely to occur in the study area 

Common Name Scientific Name Recorded EPBC DSE FFG 

Stubble Quail 

Coturnix pectoralis 

Common Bronzewing 

Phaps chalcoptera 

Brush Bronzewing 

Phaps elegans 

Whiskered Tern Chlidonias hybridus LR 

Silver Gull 

Larus novaehollandiae 

Masked Lapwing 

Vanellus miles 

Black-fronted Dotterel 

Elseyornis melanops 

Australian White Ibis 

Threskiornis molucca 

Straw-necked Ibis 

Threskiornis spinicollis 

Yellow-billed Spoonbill 

Platalea flavipes 

Great Egret Ardea alba Vul L 

White-faced Heron 

Egretta novaehollandiae 

White-necked Heron 

Ardea pacifica 

Australian Wood Duck 

Chenonetta jubata 

Black Swan 

Cygnus atratus 

Australian Shelduck 

Tadorna tadornoides 

Pacific Black Duck 

Anas superciliosa 

Chestnut Teal 

Anas castanea 

Grey Teal 

Anas gracilis 

Australasian Shoveler Anas rhynchotis Vul 

Hardhead Aythya australis Vul 

Swamp Harrier 

Circus approximans 

Grey Goshawk Accipiter novaehollandiae Vul 

Brown Goshawk 

Accipiter fasciatus 

Wedge-tailed Eagle 

Aquila audax 

Little Eagle 

Hieraaetus morphnoides 

Whistling Kite 

Haliastur sphenurus 

Black-shouldered Kite 

Elanus axillaris 

Australian Hobby 

Falco longipennis 

Peregrine Falcon 

Falco peregrinus 

Brown Falcon 

Falco berigora 

Nankeen Kestrel 

Falco cenchroides 

Southern Boobook Ninox novaeseelandiae X 

Purple-crowned Lorikeet 

Glossopsitta porphyrocephala 

Yellow-tailed Black-Cockatoo Calyptorhynchus funereus X 

Gang-gang Cockatoo 

Callocephalon fimbriatum 

Sulphur-crested Cockatoo 

Cacatua galerita 

Long-billed Corella 

Cacatua tenuirostris 

Galah 

Cacatua roseicapilla 

Crimson Rosella Platycercus elegans X 

Eastern Rosella 

Platycercus eximius 

Blue-winged Parrot 

Neophema chrysostoma 

Laughing Kookaburra 

Dacelo novaeguineae 

White-throated Needletail Hirundapus caudacutus X 

Fork-tailed Swift 

Apus pacificus 

Pallid Cuckoo 

Cuculus pallidus 

Fan-tailed Cuckoo 

Cacomantis flabelliformis 


Appendix 1 

List of fauna species that occur or are likely to occur in the study area (cont’d) 


Horsfield's Bronze-Cuckoo 

Chrysococcyx basalis 

Shining Bronze-Cuckoo 

Chrysococcyx lucidus 

Welcome Swallow Hirundo neoxena X 

Fairy Martin 

Hirundo ariel 

Grey Fantail Rhipidura fuliginosa X 

Willie Wagtail Rhipidura leucophrys X 

Satin Flycatcher 

Myiagra cyanoleuca 

Flame Robin 

Petroica phoenicea 

Eastern Yellow Robin 

Eopsaltria australis 

Golden Whistler 

Pachycephala pectoralis 

Grey Shrike-thrush Colluricincla harmonica X 

Magpie-lark Grallina cyanoleuca X 

Crested Shrike-tit 

Falcunculus frontatus 

Black-faced Cuckoo-shrike 

Coracina novaehollandiae 

White-fronted Chat 

Epthianura albifrons 

Striated Thornbill 

Acanthiza lineata 

Brown Thornbill Acanthiza pusilla X 

Buff-rumped Thornbill 

Acanthiza reguloides 

Yellow-rumped Thornbill 

Acanthiza chrysorrhoa 

White-browed Scrubwren Sericornis frontalis X 

Chestnut-rumped Heathwren Hylacola pyrrhopygia Vul 

Striated Fieldwren 

Calamanthus fuliginosus 

Rufous Bristlebird Dasyornis broadbenti LR L 

Golden-headed Cisticola 

Cisticola exilis 

Southern Emu-wren 

Stipiturus malachurus 

Superb Fairy-wren Malurus cyaneus X 

Varied Sittella 

Daphoenositta chrysoptera 

White-throated Treecreeper 

Cormobates leucophaeus 

Spotted Pardalote 

Pardalotus punctatus 

Silvereye Zosterops lateralis X 

White-naped Honeyeater Melithreptus lunatus X 

Brown-headed Honeyeater 

Melithreptus brevirostris 

Eastern Spinebill 

Acanthorhynchus tenuirostris 

Tawny-crowned Honeyeater Phylidonyris melanops 

Singing Honeyeater 

Lichenostomus virescens 

Yellow-faced Honeyeater Lichenostomus chrysops X 

White-eared Honeyeater Lichenostomus leucotis X 

White-plumed Honeyeater 

Lichenostomus penicillatus 

Crescent Honeyeater 

Phylidonyris pyrrhoptera 

New Holland Honeyeater Phylidonyris novaehollandiae X 

Noisy Miner 

Manorina melanocephala 

Little Wattlebird 

Anthochaera chrysoptera 

Red Wattlebird Anthochaera carunculata X 

Richard's Pipit 

Anthus novaeseelandiae 

Beautiful Firetail 

Stagonopleura bella 


Appendix 1 



Red-browed Finch Neochmia temporalis X 

Pied Currawong 

Strepera graculina 

Grey Currawong Strepera versicolor X 

Grey Butcherbird 

Cracticus torquatus 

Australian Magpie Gymnorhina tibicen X 

Forest Raven 

Corvus tasmanicus 

Australian Raven Corvus coronoides X 

Little Raven 

Corvus mellori 

* Rock Dove Columba livia 

Striated Pardalote 

Pardalotus striatus 

Cattle Egret 

Ardea ibis 

* Common Blackbird Turdus merula X 

* Skylark Alauda arvensis 

* House Sparrow Passer domesticus X 

* European Goldfinch Carduelis carduelis X 

* European Greenfinch Carduelis chloris 

* Common Starling Sturnus vulgaris X 

Short-beaked Echidna 

Tachyglossus aculeatus 

Agile Antechinus 

Antechinus agilis 

Dusky Antechinus 

Antechinus swainsonii 

White-footed Dunnart Sminthopsis leucopus Vul 

Southern Brown Bandicoot Isoodon obesulus obesulus End LR 

Common Ringtail Possum Pseudocheirus peregrinus X 

Sugar Glider 

Petaurus breviceps 

Koala 

Phascolarctos cinereus 

Common Wombat 

Vombatus ursinus 

Black Wallaby 

Wallabia bicolor 

Eastern Grey Kangaroo Macropus giganteus X 

Gould's Wattled Bat 

Chalinolobus gouldii 

Eastern False Pipistrelle 

Falsistrellus tasmaniensis 

Southern Forest Bat 

Vespadelus regulus 

Large Forest Bat 

Vespadelus darlingtoni 

Bush Rat 

Rattus fuscipes 

Swamp Rat 

Rattus lutreolus 

* House Mouse Mus musculus 

* European Rabbit Oryctolagus cuniculus X 

* Brown Hare Lepus capensis 

Dingo/Dog (feral) Canis familiaris Cmp 

* Red Fox Canis vulpes X T 

* Cat (feral) Felis catus 

White's Skink Egernia whitii Cmp 

Garden Skink 

Lampropholis guichenoti 

Blotched Blue-tongued Lizard Tiliqua nigrolutea 

Common Blue-tongued Lizard Tiliqua scincoides X 

White-lipped Snake 

Drysdalia coronoides 


Appendix 1 



Eastern Three-lined Skink 

Bassiana duperreyi 

Southern Water Skink 

Eulamprus tympanum tympanum 

Lowland Copperhead 

Austrelaps superbus 

Southern Grass Skink 

Pseudemoia entrecasteauxii 

Southern Smooth Froglet 

Geocrinia laevis 

Striped Marsh Frog 

Limnodynastes peronii 

Spotted Marsh Frog 

Limnodynastes tasmaniensis 

Common Spadefoot Toad 

Neobatrachus sudelli 

Southern Toadlet Pseudophryne semimarmorata Vul 

Common Froglet 

Crinia signifera 

Southern Brown Tree Frog 

Litoria ewingii 

Hybrid Geocrinia Geocrinia laevis X victoriana Cmp 


Appendix 2 

Santos Environment, Health and 

Safety Management System

Environment, 

Health and Safety 

Management System Santos 

Version 1.0 October 2003

INTRODUCTION 

Introduction 

Message from the Managing Director 

Santos continually strives to be among the world’s best exploration and production companies. 

As a best practice organisation, we are committed to conducting our business activities in a 

manner that ensures we lighten the environmental footprint and that all employees and 

contractors go home from work without injury or illness. 

The Santos Environment, Health and Safety Management System (EHSMS) outlines the structured 

approach necessary to ensure our worldwide operations are conducted in a consistent and 

systematic manner. The Santos EHSMS is the backbone of our EHS approach that will enable us 

to achieve our EHS objectives in our continual drive for excellence. 

I encourage all employees and contractors working with Santos operations to continually strive 

to improve our company’s EHS performance. 

Cover photograph: 

Paul Appleby, OH&S Advisor, monitoring safety activity during maintenance shutdown, Big Lake Satellite, Cooper Basin. 

Inside photographs: 

Left panel: John Kidman, Consulting Geologist, liaising with contractor during offshore drilling operations, Exeter oil field, 

Carnarvon Basin, Western Australia. Right panel: Landscape at Challum 7, South-West Queensland. 

Santos Ltd ABN 80 007 550 923 

EHSMS Introduction

EHSMS Introduction 

About this document 

What is the Santos EHSMS? 

The Environment, Health and Safety Management System 

(EHSMS) is a company-wide system that describes the 

requirements for effective environmental and safety practice 

across all of Santos’ activities and operations. 

The EHSMS can be broken down into three simple areas: 

management standards, hazard standards and assessment/audit. 

The standards provide a common framework and describe 

requirements such as organisation structure, planning 

activities, responsibilities, resources, practices, procedures and 

processes for meeting the objectives of Santos’ Environment 

and Health and Safety policies. 

Why do we have it? 

To provide a clear set of environment, health and safety (EHS) 

expectations so that there is a consistent, efficient approach 

across all business units. 

What should I do? 

All Santos employee and contractors are responsible for 

contributing to a safe and environmentally responsible 

workplace. This means conducting our day-to-day activities 

according to the standards and procedures specified in the 

EHSMS and by continually identifying hazards and implementing 

effective management strategies. 

Everyone is encouraged to suggest ways Santos can improve its 

safety and environmental performance via toolbox meetings and 

EHS Committee Meetings or by contacting their Supervisor, 

their Health and Safety Representative or Santos’ Corporate EHS 

Department (see back cover). 

What’s inside? 

EHSMS Framework > p2 

Overview of the multiple layers 

that make up the EHSMS. 


Minimum expectations that Santos applies across 

its entire operations in the management of EHS. 

Summary > p3 

Listing > p4 

Hazard Standards > p22 

Specific processes to manage hazards that 

underpin the EHS Management Standards. 

Glossary > p23 

Definitions of key terms and abbreviations 

used throughout this document. 

> INTRODUCTION 1

2 

> FRAMEWORK 

EHSMS Framework 

The Santos Environment, Health and Safety Management System applies to all Santos operations. 

The framework has been developed to ensure that Santos’ system is compliant with Australian Standard 4801 2000 Occupational health and 

safety management systems – Specification with guidance for use, and AS/NZS ISO 14001:1996 Environmental management systems – 

Specification with guidance for use. 

The EHSMS framework consists of multiple layers, the key components being management and hazard standards as shown below in Figure 1. 

Policy 

EHS 

Standards 

Management & Hazard Standards 

Assessment 

Common 

Group Processes 

Incident Management System (IMS) & Incident Reporting 

Emergency Response Plans 

Safety Leadership Training 

Business Unit & Department 

Processes & Procedures 

Developed to address unique features 

relating to the Business Unit or Department 

Environment & Safety Tools & Programs 

(common where possible) 

Figure 1: EHSMS framework. 

EHSMS Framework

EHSMS Standards 


> go to > go to 

EHSMS 01 Environment, Health and Safety Policies > p4 

Plan 

EHSMS 02 Legal and Other Obligations > p4 

EHSMS 03 Objectives and Targets > p5 

EHSMS 04 Environment, Health and Safety > p5 

Improvement Plans 

Implement 

EHSMS 05 Responsibility and Accountability > p6 

EHSMS 06 Training and Competency > p7 

EHSMS 07 Consultation and Communication > p7 

11.2 Design and Handover of Operating 

Facilities and Decommissioning 

and Abandonment 

11.3 Pipeline Management 

EHSMS 12 Management of Change > p14 

12.1 Piping and Instrument Diagram (P&ID) 

and Control System Change 

12.2 Change Management for Operating and 

Maintenance Procedures 

12.3 Disablement of Protective Devices 

(Bridging) 

12.4 Substitution of Materials and Equipment 

Components 

EHSMS 08 Document and Records Management > p9 

12.5 Acquisition and Divestment of Assets 

EHSMS 09 Hazard Identification, Risk Assessment > p9 

and Control 

09.1 Job Hazard Analysis (JHA) and 

Stepback 

09.2 Hazard Studies 

09.3 Workplace Inspections 

09.4 Behavioural Improvement 

09.5 Environmental Impact Assessment 

and Approvals 

EHSMS 10 Contractor and Supplier Management > p12 

EHSMS 11 Santos Operations > p13 

11.1 Operated by Others 

EHSMS 13 Emergency Preparedness > p17 

13.1 First-Aid and Medical Facilities 

Monitor and Evaluate 

EHSMS 14 Monitoring, Measurement and Reporting > p18 

EHSMS 15 Incident and Non-Conformance > p19 

Investigation, Corrective and 

Preventative Action 

15.1 Injury Management 

EHSMS 16 Management System Audit and Assessment > p20 

Review 

EHSMS 17 Management Review > p21 

> MANAGEMENT STANDARDS 3

4 

> MANAGEMENT STANDARDS 

EHSMS 01 | EHSMS 02 


EHSMS 01 

Environment, Health and Safety Policies 

Purpose 

The EHS policies outline overall Environment, Health and Safety 

(EHS) objectives and demonstrates Santos’ commitment to 

improving EHS performance. 

Implementation Requirements 

> Santos shall develop EHS policies in accordance with industry 

best practice. 

> All activities conducted by Santos shall conform with the EHS 

policies. 

> All activities conducted by contractors or by other companies 

on Santos’ behalf are to be carried out in accordance with 

policies that are equivalent in intent to the EHS policies and 

the EHSMS. 

> EHS policies shall be communicated to all employees and all 

contractors. 

> A review of the EHS policies shall be conducted on an annual 

basis. 

EHSMS 02 

Legal and Other Obligations 

Purpose 

Understanding legal and other obligations allows management to 

ensure the activities of Santos and contractors comply with EHS 

legal requirements. 


> EHS Compliance Manual/s summarising EHS laws relevant to 

Santos’ operations shall be developed and maintained at 

Corporate level: 

>> contain references to EHS licenses/permits and other 

obligations 

>> contain references to EHS industry codes, commitments 

and other obligations 

>> be readily available to all employees. 

> Legislative compliance audits shall be conducted in 

accordance with requirements outlined in EHSMS14 

Monitoring, Measurement and Reporting. 

> The Executive Committee (Excom) and the Board shall be 

informed of any material change in EHS legal requirements 

and of any significant non-compliances within the business. 

> Company EHS standards shall take into consideration 

legislative requirements, relevant industry codes, practices 

and agreements. 

EHSMS Standards

5EHSMS Standards 


EHSMS 03 


Objectives and Targets 

Purpose 

Objectives and targets help achieve the requirements of the 

Santos EHS Policies. 


> Corporate EHS objectives and targets shall be set in July for 

the following calendar year by Group EHS in consultation 

with the Business Units. 

> Department or site objectives and targets shall be 

established to measure performance and drive improvement 

in line with the Corporate objectives and targets. 

> Objectives and targets should be: 

>> Specific: Set at an appropriate level and not too 

broad or too detailed 

>> Measurable: Assessable either quantitatively or 

qualitatively 

>> Achievable: Realistic based on resources and 

competencies 

>> Relevant: Effectively achieves desired result 

>> Timely: Realistic time to achieve the change. 

> Targets shall be set for a number of EHS measures including 

both proactive (lead) and reactive (lag) measures. 

EHSMS 04 


Improvement Plans 

Purpose 

EHS plans set out the specific initiatives, actions and milestones 

for achieving the EHS performance objectives and targets. 


> A Strategic EHS Improvement Plan endorsed by the Business 

Units shall be developed, issued and maintained by the 

Corporate EHS Department. 

> The EHS Strategic Plan shall include the critical EHS issues 

(eg plant integrity, implementation of EHSMS Standards, 

leadership and behaviour) and provide a broad framework for 

achievement of the corporate EHS objectives and targets. The 

plan shall detail the following: 

>> a statement of the current status and desired long-term 

objective 

>> annual major milestones to be achieved 

>> responsibility for the completion of each milestone. 

> EHS Improvement Plans shall be developed annually on 

a calendar year basis for functional areas as determined by 

the Business Units. 

> Improvement Plans shall detail the actions that will be 

undertaken to achieve the EHS Strategic Plan and Business 

Unit EHS objectives and targets. 


EHSMS 03 | EHSMS 04

6 


EHSMS 05 


> The Improvement Plan shall detail the key actions, 

responsibilities and timeframes to meet the Strategic EHS 

Improvement Plan and Business Unit/Shared Business 

Services/Department EHS objectives, targets and actions 

arising from assessments, audits and incidents. 

> EHS Improvement Plans shall be monitored by line 

management at least every two months to ensure that 

appropriate progress is being achieved and variances are 

addressed. 

EHSMS 05 

Responsibility and Accountability 

Purpose 

Assignment of roles, responsibility and accountability ensures 

resources, including human, technical and financial, are 

appropriately used to implement, maintain and improve the 

EHSMS. 


> EHS outcomes are a line management responsibility 

supported by EHS personnel and EHS committees. 

> Organisational structures and position descriptions shall be 

documented to outline the hierarchy of EHS responsibilities, 

accountabilities and reporting channels. 

> Personal EHS objectives shall be set as a component of the 

performance review process. 

> EHS committees shall be established within each Business 

Unit to help management oversee the implementation, 

monitoring and review of the Santos EHSMS. 

> Sufficient resources shall be provided by management to: 

>> implement EHS improvement plans to achieve EHS 

objectives and targets 

>> develop, implement and maintain the operation’s EHSMS 

>> ensure compliance with EHS legal and other 

commitments. 

Tony Dean, Instrument/Electrical Technician, and Peter ODowd, 

Production Operator, installing solar powered air compressor, 

Tirrawarra, South Australia. 

EHSMS 

Standards

7EHSMS Standards 


EHSMS 06 

Training and Competency 

Purpose 

Focused training ensures that everyone with responsibilities 

allocated under the EHSMS understands how to fulfil the 

responsibilities and has the necessary skills. 


> Training programs shall be established, maintained and 

periodically reviewed for employees and contractors. 

> Systems shall be developed, maintained and reviewed to 

identify, prioritise and deliver training. 

> Employees have an obligation to pursue the attainment of 

competencies identified for their position. 

> Training programs shall be designed and delivered to ensure 

that employees and contractors are made aware of the 

relevant: 

>> requirements of the EHSMS and their roles and 

responsibilities 

>> potential EHS impacts associated with their activities, 

including consequences of not complying with the EHSMS. 

> Employees and contractors shall attend an induction program 

that covers relevant EHS risks and their required 

management, followed by refresher sessions where appropriate. 

> Managers and Supervisors shall undergo leadership training. 

> Line management shall ensure appropriate training sessions 

are conducted for their workgroup on the relevant EHSMS 

Standards. 

> Line managers shall ensure that EHS awareness sessions are 

conducted for personnel under their responsibility for specific 

hazards relating to the workgroup’s needs. 

> Personnel training records of internal and external training 

shall be kept for 30 years. 

EHSMS 07 

Consultation and Communication 

Purpose 

Appropriate communication and consultation mechanisms to 

ensure that Santos employees and contractors understand, have 

ownership of and are willing to comply with the EHSMS. 


> Consultative arrangements shall be in place to provide 

employees, contractors and external stakeholders with an 

opportunity to contribute to EHS decision-making. 

> Consultation with employees shall be via Environment 

Committees, Health and Safety Committees and Health and 

Safety Representatives. 

> Operations that have a significant impact on the local 

community shall establish consultation mechanisms for 

affected groups. 

> Consultation with government agencies, authorities and 


EHSMS 06 | EHSMS 07

8 


EHSMS 07 


other organisations shall be maintained in order to 

contribute to the development of public policy, relevant 

legislation, improved industry performance and educational 

initiatives. 

Santos worked in close consultation with more than 700 landowners in 

Victoria’s Otway Basin community. 

> The Santos EHS Policies, EHSMS Standards, and relevant EHS 

issues and performance shall be communicated to employees 

and contractors. Where required, EHS information shall be 

provided in appropriate languages for non-English speaking 

personnel. Methods of communication include: 

>> Environment Committees and Health and Safety Committees 

>> toolbox meetings 

>> Santos Incident Management System (IMS) 

>> presentation of EHS KPIs (eg on the intranet, ”The Well”) 

>> EHS training 

>> EHS notice boards, bulletins and alerts 

>> management visits 

>> awareness programs and initiatives. 

> Monthly workgroup meetings shall be held including 

communication and discussion of EHS matters at all Santos 

sites. 

> Santos sites shall have Environment and Health and Safety 

Committees to monitor the implementation of the 

Environment and Health and Safety Management, discuss 

EHS matters and recommend to management the means to 

resolve issues. 

> Business Units shall hold regular EHS Management meetings 

to monitor the implementation of the EHS Management 

System. The purpose of the EHS Management Committee is to 

provide a linkage between the sites and the Corporate EHS 

objectives and targets. 

> Meetings, where appropriate, should start with a discussion 

of relevant EHS issues. 

> Daily toolbox meetings shall be held for workgroups 

including the relevant Supervisor, employees and relevant 

contract personnel. 

> Communication with external stakeholders on EHS matters 

shall be maintained, both proactively and upon request. 

EHSMS 

Standards

9EHSMS 

Standards 


> Regular reporting and notification of EHS incidents, where 

required by statute, shall be reported to the appropriate 

government agency. 

> EHS reporting shall be included in the Santos Annual Report 

and the Santos internet site, www.santos.com. 

EHSMS 08 

Document and Record Management 

Purpose 

Personnel need easy access at all times to current, up-to-date 

versions of all EHSMS documents to perform their work. Records 

also demonstrate compliance with EHS Policy, Standards and 

attainment of objectives. 


> All EHSMS documents shall have an individual nominated 

custodian responsible for the management of the document. 

> All EHSMS documents shall be entered in the electronic 

document management system located in “The Well”. 

> Paper based versions of EHSMS documents shall be marked as 

“uncontrolled copy” and the user of a printed document is 

responsible to ensure that it is the latest version. 

> Documents shall be issued in appropriate languages to ensure 

personnel who require access to the information are able to 

read them. 

> Where applicable, work instructions and signs should be in 

the form of pictures, drawings, colours and other visual 

means, rather than text. 

> Documents shall be reviewed by the custodian at a minimum 

of every three years or when triggers for change occur. 

> Custodians shall ensure that links to external documents eg 

acts, regulations, industry codes, standards and guidelines, 

referenced in EHSMS documents are current. 

> Line managers shall ensure that EHSMS documents are 

readily accessible. 

> Records shall be kept to demonstrate conformance with 

requirements of the EHSMS. 

> The person responsible for the operating site shall ensure a 

Plant Dossier is prepared and maintained. Plant Dossier 

documentation shall be accessible to potential users. 

EHSMS 09 

Hazard Identification, Risk Assessment and 

Control 

Purpose 

Processes are necessary to systematically identify hazards, assess 

their risk and adopt control strategies to reduce risk to as low as 

reasonably practicable (ALARP). 


> The overall risk management approach used by Santos shall, 


EHSMS 08 | EHSMS 09

unless otherwise stated, be based on Australian Standard 

AS4360 “Risk Management”. 

> EHS hazards shall be managed using the risk management 

process outlined in Figure 2. 

> The Santos Incident Management System (IMS) shall be used 

to record and manage EHS hazards. 

Establish the Content 

Identify Risks 

Analyse Risks 

Evaluate Risks 

Treat Risks 

Figure 2: Risk management process. 

> Major Hazards (as defined) shall be managed in accordance 

with the requirements of relevant Major Hazard Facility 

(MHF) legislation for onshore facilities and with the relevant 

“Safety Case” legislative requirements for offshore activities. 

> Competent personnel at all organisational levels should be 

appropriately involved in the identification of hazards and 

their effects. 

> Processes shall be put in place to identify pre-existing 

hazards using one or more of the following tools: 

>> Job Hazard Analysis (JHA) and Stepback 

>> inspections and audits 

>> incident, near miss, hazard and non-conformance 

investigation and follow up activities 

>> communication sessions, eg toolbox meetings 

>> systematic hazard identification processes 

>> work permits. 

> Hazards introduced by projects or changes to operations 

facilities shall be identified through an appropriate Hazard 

Study. 

> Risk assessment techniques that should be used for the 

stated applications in Santos are as follows: 

Communicate and Consult 

Monitor and Review 

10 


EHSMS 09 


Assess Risks 

EHSMS 

Standards

EHSMS 

Standards 


Application Risk Assessment Technique 

Assessment of major hazards Semi-quantitative or 

quantitative 

Assessment of EHS hazards, Qualitative – Risk Score 

near misses and incidents Calculator 

Assessment of Qualitative – Santos Risk 

contractors’ scope of work Assessment Tool (AS4360) 

for prequalification 

Assessment of project or Qualitative – Santos Risk 

technical EHS hazards Assessment Tool (AS4360) 

> In assessing risk controls, consideration shall be given to 

both preventive controls (to prevent a breakdown event 

occurring) and mitigation controls (to minimise the 

consequences should the breakdown event occur). 

> Risk control measures shall be assessed using the “Hierarchy 

of Control” approach. Elimination shall be the first (and 

preferred) control method to be considered. A number of 

control options may be considered and applied either 

individually or in combination. 

> A plan for the implementation of risk controls (including any 

risk control studies or interim controls) shall be prepared 

within a defined period of time. Actions shall be recorded 

and managed using IMS. 

> Risk controls implemented shall be reviewed to ensure that 

that they have been effective, they have not introduced any 

new unintended hazards, and that the risk has been reduced 

to an acceptable level. 

> An EHS Hazard Register shall be developed and maintained 

at each Santos-defined site and shall include all hazards with 

an initial risk score of moderate or higher. 

> All hazards in the Site Hazard Register shall be reviewed on a 

periodic basis to ensure that the risk controls have achieved, 

and are continuing to achieve, the intended risk reduction. 

> The Hazard Register shall be used in the induction of new 

employees and contractors to make them aware of the 

hazards and controls that are in place to manage their risk. 

> A generic Office Hazard Register has been developed and is 

available on “The Well” (Office Hazard Register). 

> EHSMS 09.1 

Job Hazard Analysis (JHA) and Stepback 

Purpose 

To define the requirements for identifying, assessing and 

controlling personal risks associated with work activities. 

> EHSMS 09.2 

Hazard Studies 

Purpose 

To detail the requirements for the identification and risk 

management of EHS hazards during project development. 


EHSMS 09 

11

12 


EHSMS 10 


> EHSMS 09.3 

Workplace Inspections 

Purpose 

To ensure that all workplaces are inspected on a regular basis 

to ensure hazards are identified and controls are implemented 

to manage their risk. 

> EHSMS 09.4 

Behavioural Improvement 

Purpose 

To define the requirements for managing the behavioural 

aspects of EHS performance improvement. 

> EHSMS 09.5 

Environmental Impact Assessment and Approvals 

Purpose 

To ensure that processes are in place to systematically identify 

and manage potential environmental and social impacts 

associated with development activities and to obtain all 

relevant statutory approvals. 

EHSMS 10 

Contractor and Supplier Management 

Purpose 

Third parties doing work on Santos’ behalf are required to have 

appropriate systems in place to ensure their activities are 

consistent with Santos’ policies and business objectives. 


> An approved catalogue of equipment and material suppliers 

and offsite service providers that have a potential for 

significant business risk shall be maintained to ensure that 

appropriate, quality equipment, materials and services are 

purchased. 

> An inspection regime shall be specified for each item on the 

approved catalogue. 

Wellhead platform construction, Bayu-Undan liquids project, Timor Sea. 

Photograph courtesy of ConocoPhillips Australia Pty Ltd. 

EHSMS Standards



> Equipment or materials found to be non-conforming with 

specified requirements shall be managed as a nonconformance 

in the Santos Incident Management System. 

> Contractors shall be assessed before being offered or invited 

to tender for Santos work. Prequalification shall be 

conducted for potential contractors of major contracts. 

Capability Assurance shall be conducted for potential 

contractors for minor contracts. 

> Prior to work being awarded to a contractor, the Santos 

Representative shall assess the potential EHS risk associated 

with the work. Where the service involves work that has a 

moderate or higher risk to environment, health or safety, an 

EHS Management Plan shall be provided by the contractor. 

> Prior to commencement of work, the contractor shall undergo 

the appropriate Santos induction (Level 1 Generic and Level 

2 Site Specific). The contractor shall provide to their 

employees and subcontractors a task-specific induction 

(Level 3) relevant to the scope of work including a review of 

the contractor's EHS Management or Work Plan. 

> It is the contractor’s responsibility to ensure that all 

equipment to be used on a Santos site meets relevant 

standards, is maintained and tested in accordance with the 

manufacturers’ and applicable statutory requirements. The 

contractor shall ensure all equipment is inspected prior to 

use and be able to demonstrate that the equipment is fit for 

purpose (including the status of safety and emergency 

equipment). 

> Where required, work permits must be obtained by 

contractors and sub-contractors before commencing work. 

> Contractors shall report and investigate environment, health 

and safety incidents and near misses. 

> Contractors shall ensure that the requirements of EHS 

Management or Work Plans are complied with. 

> Regular review shall be conducted with contractors to review 

their EHS performance. 

> On completion of major contracts, an evaluation of the 

contractor’s performance shall be completed and included on 

the contractor's file. 

> Opportunities for improvement arising from the evaluation 

shall be communicated for action. 

EHSMS 11 

Santos Operations 

Purpose 

Operations are to be conducted within established parameters 

and regulations. This requires effective procedures, inspection 

and maintenance systems, reliable safety and control facilities 

and qualified personnel who consistently execute these 

procedures and practices. 


> Processes shall be in place to plan and discuss operational 


EHSMS 11 

13

14 


EHSMS 12 


activities to ensure EHS risks are managed (eg Job Hazard 

Analysis, toolbox meetings and Stepback). 

> Procedures shall be developed, implemented and maintained 

by a nominated custodian for routine tasks. 

> Procedures are classified as critical, standard or work aid, 

determined by the risk and complexity of the task. 

> Critical procedures shall undergo a relevant technical and 

management review before being approved. 

> Personnel shall be trained in the procedures and follow the 

requirements of the procedure. 

> A handover process shall be in place to enable the effective 

handover of ongoing operations. 

> A Work Permit System shall be developed and maintained for 

the planning, coordination, authorisation and control of 

specified work activity to ensure that the work is conducted 

safely and efficiently and that personnel, the environment 

and facilities are protected. 

> A system shall be developed and maintained to manage the 

integrity of critical protection systems. Critical protection 

systems include alarms, trips, interlocks, shutdown systems, 

electric power protection and standby control systems. They 

may use electric, electronic, programmable electronic, 

pneumatic, hydraulic, mechanical or other equipment. 

> A system shall be developed and maintained to ensure the 

integrity of pressure equipment. 

> EHSMS 11.1 

Operated by Others 

Purpose 

To outline the Santos requirements for stewarding EHS 

performance of Joint Venture activities operated by others. 

> EHSMS 11.2 

Design and Handover of Operating Facilities and 

Decommissioning and Abandonment 

Purpose 

To ensure that EHS risks associated with the design, 

commissioning and handover of operating facilities and the 

decommissioning and abandonment of plant and equipment 

are effectively managed. 

> EHSMS 11.3 

Pipeline Management 

Purpose 

Pipelines are consistently designed, operated and maintained 

in a manner which reduces EHS risks to as low as reasonably 

practicable. 

EHSMS 12 

Management of Change 

Purpose 

Processes are required to ensure that changes in organisational 

structure, operations, procedures, standards, facilities or 

personnel, are evaluated and managed so that EHS risks arising 

from these changes remain at an acceptable level. 

EHSMS Standards




> A structured process using Change Request (CR) forms shall 

be used to make changes to: 

>> control systems 

>> piping and instrumentation diagrams 

>> operating and maintenance procedures 

>> temporarily disable protective devices 

>> materials or equipment components. 

Construction activities, Phase 3 Ballera Gas Plant development, South- 

West Queensland. 

> The initiator of a CR form shall provide sufficient details to 

enable the change to be assessed. 

> Proposed changes shall be assessed by the relevant 

Supervisor or Superintendent to ensure that the proposal is 

merited, funds are allocated and an appropriate response is 

developed. 

> An appropriate technical review of detailed aspects of the 

proposal shall be undertaken. 

> The developer of the change shall undertake the required 

definition and design to allow implementation of the 

proposed change, including cost estimation, and coordinate 

the appropriate hazard and technical reviews eg Hazard 

Studies. 

> Endorsed and developed CRs shall be forwarded to the 

change coordinator, who will: 

>> check the completeness of the change documentation 

provided 

>> allocate a unique CR Number 

>> register the CR in the Change Register 

>> complete the distribution section of the CR and circulate 

>> file a copy of the endorsed CR for reference. 

> Approval levels shall relate to the classification of the CR 

and the residual risk of the change, taking into account the 

controls to be implemented. 

> The change shall be implemented and documentation 

updates completed by a nominated implementer. 


EHSMS 12 

15

16 


EHSMS 12 


> The implementer shall conduct pre-commissioning checks of 

the change and ensure that the change has been completed 

and is safe to bring into service. 

> A review of the change (Completion Review) shall be 

completed by the completion auditor within 3 months of 

implementation. The objective of the Completion Review 

is to: 

>> check and record if the intentions of the change have 

been achieved after a period of operation 

>> confirm that all planned actions/changes have been 

completed 

>> confirm that no unplanned action/changes have been 

made that would warrant a new CR number 

>> ensure that all affected documentation has been updated 

to “as built”. 

> EHSMS 12.1 

Piping and Instrument Diagram (P&ID) 

and Control System Change 

Purpose 

To describe the requirement for the control and authorisation 

of changes to existing P&IDs and control systems. 

> EHSMS 12.2 

Change Management for Operating and 

Maintenance Procedures 

Purpose 

To ensure there is a process to adequately address any risks 

associated with changes to operating and maintenance 

procedures. 

> EHSMS 12.3 

Disablement of Protective Devices (Bridging) 

Purpose 

To ensure the risks associated with temporarily disabling 

protective devices (bridging) are adequately managed such as 

the ongoing safety of personnel, environmental impact and 

the integrity of plant and equipment. 

> EHSMS 12.4 

Substitution of Materials and Equipment 

Components 

Purpose 

To ensure the risks associated with the substitution of 

materials or components in plant and equipment are 

adequately managed and the changes meet or exceed the 

performance criteria of the original plant and equipment. 

> EHSMS 12.5 

Acquisition and Divestment of Assets 

Purpose 

To ensure that EHS aspects of proposed acquisitions and 

divestments are fully understood before making a decision to 

acquire or divest land or assets being companies or other 

entities. 

EHSMS Standards



EHSMS 13 

Emergency Preparedness 

Purpose 

Process are required to ensure any foreseeable emergencies and 

are able to managed, so as to minimise any adverse impact on 

the safety or health of people or the environment. 


> A document-controlled Santos Incident Management Plan 

(SIMP) shall be prepared, distributed and maintained by 

Manager EHS that shall detail the requirements for site/field/ 

area based Emergency Response Plans (ERPs) and Emergency 

Scenario procedures. 

> ERPs shall be developed and maintained in accordance with 

SIMP requirements for all sites/fields/areas. 

> All Business Units and relevant Corporate departments shall 

prepare and maintain documents and facilities in accordance 

with SIMP requirements. 

> At sites which are classified as a Major Hazard Facility, the 

ERP shall incorporate, in addition to the SIMP requirements, 

all the specific requirements as defined in Section 9 of the 

National Standard Emergency Equipment Locations. 

> A hazard identification process shall be conducted to identify 

locations where emergency equipment may be required. 

> Emergency equipment shall be located in easily accessible 

locations and within a reasonable distance from the hazard. 

> Such locations shall be sign-posted, including directions from 

areas where the emergency equipment cannot be seen. 

> Warning devices such as lights, sirens and bells shall be 

installed in all locations where personnel need to be warned 

of a hazard or an emergency (eg over pressure, release of 

toxic gasses, etc). 

> Emergency evacuation lighting shall be installed and 

regularly inspected and maintained. 

Joanne Bay, Graduate Engineer, Moomba 

> Emergency power supply (independent of the normal mains 

supply) shall be provided for all plant and equipment which 


EHSMS 13 

17

18 


EHSMS 14 


may present a significant EHS risk in the event of an 

interruption to normal power supply. 

> Emergency equipment shall be regularly inspected and 

maintained to ensure it is in proper working order and a 

state of readiness. 

> Site management shall conduct a review at least once a year 

to ensure emergency equipment is of sufficient quantities 

and of the correct type for foreseeable emergencies. 

> Workplaces shall have appropriate first aid facilities readily 

available for use. The choice of first aid facilities at a 

workplace shall be based on a risk assessment taking 

into consideration: 

>> nature of the work 

>> size and layout of the workplace 

>> location of the workplace 

>> number and distribution of workers. 

> Relevant staff shall be trained and competent to use 

emergency equipment at their site/field/area. Training shall 

be refreshed annually. 

> Emergency and Incident Management Plans shall be regularly 

tested using a simulated approach. 

> Records of the emergency exercises conducted shall be kept. 

> EHSMS 13.1 

First-Aid and Medical Facilities 

Purpose 

To define the requirements for first aid, the provision of first 

aid facilities and the availability of qualified first aid 

personnel to ensure effective treatment to employees, visitors 

and contractors. 

EHSMS 14 

Monitoring, Measurement and Reporting 

Purpose 

Collection, analysis and reporting of EHS performance data is 

necessary to establish whether risks associated with Santos’ 

operations are being managed, minimised and, where reasonably 

practicable, eliminated. 


> EHS monitoring programs shall be established and 

maintained to regularly measure key aspects of Santos’ 

activities that can have a significant EHS impact. 

> Monitoring programs shall include both direct monitoring of 

EHS impacts from business activity and monitoring of the 

EHS management system. 

> Personal health monitoring shall be conducted and records 

kept where appropriate (eg when identified by a risk 

assessment or when required by legislation). 

EHSMS Standards



> EHS monitoring equipment shall be regularly calibrated and 

maintained to manufacturer’s specifications and records 

retained for five years. 

> Each month EHS data relating to key performance indicators 

shall be collected and collated for each business unit/area/ 

work activity and consolidated for the whole Company. 

Seismic acquisition, onshore Otway Basin, Victoria. 

> To ensure appropriate stakeholders are adequately informed 

of relevant EHS performance a range of EHS reports shall be 

prepared including: 

>> Board reports 

>> management reports 

>> industry (eg APPEA) reports 

>> statutory reports 

>> annual public report. 

> EHS data shall be analysed at least annually to identify 

issues and areas requiring improvement. 

> The Manager EHS shall ensure that EHS reports are readily 

accessible on “The Well”. 

EHSMS 15 

Incident and Non-Conformance Investigation, 

Corrective and Preventative Action 

Purpose 

Reporting, investigation and management of corrective actions 

associated with incidents is required to identify the underlying 

system failures and implement appropriate corrective actions to 

prevent a recurrence. 


> EHS incidents, hazards, near misses, property damage, 

significant process incidents, non-conformance events and 

third party complaints shall be managed by using the Santos 

Incident Management System (IMS). 

> The normal sequence of events following an incident shall be 

as follows: 

>> immediate control of any hazards and impacts (eg 

injuries) 


EHSMS 15 

19

20 


EHSMS 16 


On-site training and inspection. 

>> report the incident to line management 

>> report the incident to authorities (where required) 

>> notify other personnel using an IMS notification 

>> conduct a risk assessment of the incident 

>> conduct an investigation (for significant incidents a 

TapRooT® investigation or equivalent shall be conducted) 

>> assign recommended actions using IMS 

>> ensure agreed actions are completed and update IMS 

>> ensure the risk has been reduced to an acceptable level 

>> share relevant learnings arising from the incident with 

others. 

> Employees shall be trained in the use of IMS. 

> EHSMS 15.1 

Injury Management 

Purpose 

To ensure that there is an effective and equitable injury 

management system in place for employees who sustain a 

work related injury or illness. 

EHSMS 16 

Management System Audit and Assessment 

Purpose 

Audit and assessment ensures that EHSMS Standards have been 

effectively implemented and are being complied with and that 

the system meets legislative requirements and defined EHS 



> Santos Business Units shall participate in the EHS 

audit/assessment program which includes: 

>> Assessments of EHSMS implementation. 

>>> An annual assessment shall be conducted at defined 

Santos sites to determine the implementation status 

of EHSMS Standards. 

>>> An assessment report shall be prepared and provided 

to each site and the responsible line manager. 

EHSMS Standards



>>> The site assessment reports shall be used when 

developing the following year’s EHS Improvement 

Plan. 

>> Internal EHSMS audits. 

>>> An internal EHSMS audit plan prioritised on risk shall 

be developed and administered by Corporate EHS to 

provide verification of conformance with the EHSMS 

Standards. 

>>> Audits should be conducted by independent internal 

auditors. 

>> Statutory compliance audits. 

>> EHSMS self-audits. 

>>> Business Units are encouraged to self audit their 

conformance with the EHSMS using a risk-based 

approach. 

>> EHSMS audits of contractors and non-operated joint 

ventures. 

>> Other specialised audits eg issue-specific audits. 

>>> In the event of a serious incident, non-compliance or 

other valid reason an unscheduled audit may be 

initiated. 

> All audits and assessments shall be scheduled, recorded and 

managed using the Santos Audit and Inspection Manager 

(AIM). 

> Appropriate personnel shall be trained in the use of AIM. 

EHSMS 17 

Management Review 

Purpose 

Periodic reviews of the overall effectiveness of the EHSMS by 

senior management ensure continual improvement, suitability 

and effectiveness. 


> Personnel shall advise the Manager EHS, either directly or 

through their Supervisor, of any suggestions to improve the 

system. Feedback shall be provided to personnel making 

suggestions. 

> An informal review of the effectiveness of the EHSMS shall be 

conducted at Management Safety or Environment Committee 

meetings. 

> A formal review of the EHSMS shall be conducted annually by 

the Santos EHSMS Management Review Group. 

> The formal annual review shall be documented including 

observations, conclusions, recommendations, actions and 

follow-up requirements. An action register shall be used to 

manage the effective close-out of actions. 


EHSMS 17 

21

22 

> HAZARD STANDARDS 

Hazard Standards 

Hazard Standards that have been completed are available on the Santos intranet,“The Well”, 

at Home > Support Services > Health & Safety > EHSMS. 

HSHS 01 Fire Control Management 

HSHS 16 Lifting Equipment 

HSHS 02 Land Transportation 

HSHS 17 Personal Protective Equipment 

HSHS 03 Air Transportation 

HSHS 18 Working in Confined Space 

HSHS 04 Fitness for Work 

HSHS 19 Excavations 

HSHS 05 Working in Hot Environments 

HSHS 06 Electrical Safety 

EHS 01 Land Disturbance 

HSHS 07 Working at Heights 

01.1 Earthworks 

HSHS 08 Chemical Management and Dangerous Goods 

01.2 Biodiversity 

08.1 Asbestos 

01.3 Land Disturbance Inventory 

08.2 Synthetic Mineral Fibre 

EHS 02 Management of Onshore Hydrocarbon Storage 

08.3 Carcinogenic Substances 

EHS 03 Produced Water Management 

08.4 Mercury 

EHS 04 Waste Management 

08.5 Vanadium 

EHS 05 Air Emissions 

08.6 Nitrogen 

EHS 06 Greenhouse Gas Management 

08.7 Hydrogen Sulphide 

EHS 07 Energy Conservation 

HSHS 09 Radiation 

EHS 08 Contaminated Land Management 

HSHS 10 Food Safety 

EHS 09 Weed and Pest Animal Control 

HSHS 11 Manual Handling and Ergonomics 

EHS 10 Water Resource Management 

HSHS 12 Occupational Noise 

EHS 11 Cultural Heritage 

HSHS 13 Working in Remote Locations 

EHS 12 Noise Emissions 

HSHS 14 Occupational Health 

12.1 Marine Noise Emissions 

HSHS 15 Personal Security 

EHSMS Standards

EHSMS Glossary 

Glossary 

This glossary defines the key terms and abbreviations used throughout this summary of the Santos 

Environment, Health and Safety Management System. 

Accountability Answerable for the outcomes and therefore takes the credit or consequences. Accountability cannot be delegated. 

Assessment Process of collecting evidence and making judgements on whether competency has been achieved. 

Competency Demonstration and reliable application of knowledge and skills to the standard required in the workplace. 

Contractor An individual, company or other legal entity contracted to carry out work for, and on behalf of, Santos including 

self-employed persons and sub-contractors. 

Control Measures Actions taken to reduce the chance of a hazard occurring or to reduce the effect of the hazard if it does occur. 

EHS Environment, health and safety. 

EHS Improvement A document used to detail and monitor actions required to achieve defined EHS objectives and targets. 

Plan 

EHS Objective Overall environment, health and safety goal, arising from the environment, health and safety policy, that an organisation 

sets itself to achieve and which is quantified where practicable. 

EHS Policies Written statements by the organisation of its commitment, intentions and principles in relation to its overall EHS 

performance which provide a framework for the setting and execution of its EHS objectives. 

EHS Targets A quantified EHS outcome. 

EHSMS Environment, Health and Safety Management System. 

EHSMS Audit A systematic and documented verification process of objectively obtaining and evaluating evidence to determine whether 

an organisation’s EHSMS conforms to the EHSMS audit criteria set by the organisation, and for communication of the 

results of this process to management. 

EHSMS Management A senior management review group with representation drawn from all Santos Business Units with responsibility for 

Review Group detailed review of EHSMS management and hazard standards. Membership of the group includes operational managers from 

Business Units. 

> GLOSSARY 23

24 

> GLOSSARY 

Glossary 

EHSMS Performance Measurable results of the EHSMS, related to an organisation’s control of its EHS aspects, based on its EHS policy and 


Emergency Response Actions taken at the site of a major incident to preserve lives, the environment and property. 

Hazard A source of potential harm or a situation with a potential to cause loss. 

Health Monitoring The monitoring (including biological monitoring and health assessment) of a person to identify changes in the 

person’s health because of exposure to a hazard. 

Incident Any unplanned event resulting in or having a potential for injury, ill-health, environmental damage or other form of loss. 

Interested Parties Individual or group concerned with or affected by the safety or environmental performance of Santos operations. 

Job Hazard Analysis A process used to identify hazards and control their workplace risks during task planning, execution and review of work 

(JHA) activities. It involves the workgroup who will be doing the work, breaking the job down into steps, identifying the hazards 

associated with each step and deciding what actions are necessary to mitigate the hazards. The workgroup may choose 

to use the risk score calculator to help them assess and quantify the level of risk associated with each hazard. 

Legal Requirements All laws, regulations, conditions of permits, licences, approvals and rules of conduct established by national, state or local 

government authorities. 

Line Management Management with direct responsibility and accountability for all aspects of activities, operations, products and services, 

including Environment, Health and Safety. 

Lost Time Injury Work-related injury resulting in one or more complete shift away from work. 

Major Hazard A source of potential harm or a situation with a potential to cause two or more fatalities. 

Medical Treatment Work-related injury requiring specified treatment from a medical practitioner. 

Injury 

Near Miss An unplanned event that did not result in injury or property damage but which, when formally assessed, had the 

potential to have done so. 

EHSMS Glossary

EHSMS Glossary 

Glossary 

Property Damage The actual damage or loss of property or other resources during the normal activities associated with the operation of a 

Santos site, including damage/loss sustained to property owned or operated by third parties such as contractors, subcontractors 

or visitors, etc. 

Record A health and safety record is a record of “evidence”, that cannot be changed or up-dated and does not need to be held 

under a document control system. 

Responsibility An undertaking to see that activities are carried out. Responsibilities can be delegated. 

Risk The chance of something happening that will have an impact upon Environment, Health and Safety. It is measured in 

terms of consequences and likelihood. 

Risk Assessment The process used to determine risk management priorities by evaluating and comparing the level of risk against 

predetermined standards, target risk levels or other criteria. 

Risk Management The systematic application of management policies, procedures and practices to the tasks of identifying, analysing, 

assessing, treating and monitoring risk. 

Shall A mandatory (compulsory) instruction. 

Should A recommended instruction. 

Stepback An informal (non-documented) process of thinking about and mentally planning the steps involved and managing the 

hazards that may be faced in doing a job by “engaging the mind before the hands”. 

Strategic EHS A strategic document used to detail critical EHS issues that Santos is planning to achieve within a three to five year 

Improvement Plan period. 

Target Detailed performance requirement, quantified where practicable, applicable to the organisation, that arises from the 

EHS objectives and that needs to be set and met in order to achieve those objectives. 

Work Permit Sets out the work to be done, the precautions to be taken, and specifies all work conditions. 

Workplace Assessor Person holding a current recognised certificate of competency to conduct workplace competency assessments. 

> GLOSSARY 25


Head Office 

Santos House 

91 King William Street 

Adelaide South Australia 5000 

Telephone 08 8218 5111 

Facsimile 08 8218 5274 

www.santos.com 

Further Information 

Contact the EHS department. 

Telephone 08 8218 5557 or 08 8224 7956 

Facsimile 08 8218 5549 

Visit the EHSMS section of The Well. 

Home > Support Services > Health & Safety > EHSMS 

ENVHS P001 


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Environment Report - Santos

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