ENVIRONMENTAL IMPACT REPORT Petroleum Exploration Activities in the Simpson and Pedirka Regions

DRAFT

May 2020

Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Prepared by:

Tri-Star Energy Company Level 35 Riverside Centre 123 Eagle Street Brisbane, Q 4000 T: (07) 3236 9800 F: (07) 3221 2146 E: [email protected] W: http://www.tri-starpetroleum.com.au

and

JBS&G Australia Pty Ltd ABN 62 100 220 479 100 Hutt St Adelaide SA 5000 T: +61 8 8431 7113 F: +61 8 8431 7115 W: http://www.jbsg.com.au

Document Status

Review Release Version Purpose of Document Original Review QA Review Issue Date Date Approval

A Draft for Tri-Star review / discussion RS/AM/AC AC/SM 6/4/2019 SM SM 16/4/2019

Updated draft following Tri-Star B input. Issued for preliminary DC AC/SM 9/8/2019 SM SM 9/8/2019 government agency consultation Updated based on DEW, DPTI and 0 AC DC/AC 8/3/2020 CB/RU/SH JB 28/5/2020 SAAL NRM Board initial comments

Tristar Drilling EIR Rev0 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Contents

1 Introduction ...... 1 1.1 About this Document ...... 1 1.2 Tri-Star Energy Company Profile ...... 1 1.3 Location and Exploration Rationale ...... 1 1.4 Scope ...... 2 2 Legislative Framework ...... 6 2.1 Petroleum and Geothermal Energy Act 2000 ...... 6 2.1.1 Environmental Significance Assessment and SEO Consultation Requirements ...... 7 2.1.2 Activity Notification / Approval Process ...... 8 2.2 Other Legislation ...... 8 3 Proposed Activities ...... 11 3.1 Grouping of Operations ...... 11 3.2 Drilling Operations ...... 12 3.2.1 Construction Activities ...... 12 3.2.2 Well Drilling Activities ...... 21 3.2.3 Well Completion and Workover Activities ...... 21 3.2.4 Well Production Testing ...... 22 3.2.5 Well Decommissioning ...... 22 3.3 Fracture Stimulation Operations ...... 23 3.3.1 Well Design and Construction ...... 24 3.3.2 Fracture Stimulation Design ...... 25 3.3.3 Fracture Stimulation Monitoring ...... 27 3.3.4 Fracture Stimulation Stages ...... 28 3.3.5 Fracture Stimulation Fluids ...... 29 3.3.6 Post Stimulation Flowback ...... 30 3.3.7 Equipment and Materials ...... 31 3.3.8 Water Use and Management ...... 31 3.4 Associated Activities ...... 32 3.4.1 Water Supply ...... 32 3.4.2 Waste Management ...... 33 3.4.3 Fuel and Chemical Storage ...... 35 3.5 Restoration and Rehabilitation ...... 36 3.5.1 Initial Restoration ...... 36 3.5.2 Partial Restoration ...... 36 3.5.3 Final Restoration ...... 37 4 Existing Environment ...... 38 4.1 Climate ...... 38 4.2 Bioregions, Landforms and Land Systems ...... 38 4.3 Flora and Fauna ...... 43 4.3.1 Flora ...... 43 4.3.2 Fauna ...... 45

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4.3.3 Threatened Species and Communities ...... 46 4.3.4 Listed Migratory Species ...... 48 4.3.5 Weeds and Pests ...... 49 4.3.6 Recognised Biodiversity Values ...... 50 4.4 Surface Water ...... 50 4.5 Geology ...... 54 4.5.1 Geological Setting / Background ...... 54 4.5.2 Structural Setting ...... 55 4.5.3 Stratigraphy ...... 57 4.5.4 Hydrocarbon Targets ...... 61 4.6 Hydrogeology ...... 65 4.6.1 Aquifer Use ...... 71 4.6.2 Great Artesian Basin Springs ...... 75 4.7 Cultural Heritage ...... 75 4.7.1 Aboriginal Cultural Heritage ...... 75 4.7.2 Non-Aboriginal Heritage ...... 76 4.8 Land Use ...... 76 4.8.1 Pastoralism ...... 76 4.8.2 Mining and Petroleum ...... 78 4.8.3 Conservation ...... 80 4.8.4 Tourism ...... 81 4.8.5 Native Title ...... 81 4.9 Socio-Economic ...... 81 4.9.1 Population Centres ...... 81 4.9.2 Infrastructure ...... 82 5 Environmental Impact Assessment ...... 84 5.1 Overview of Risk Assessment Process ...... 84 5.2 Drilling Operations ...... 87 5.2.1 Soil and Shallow Groundwater ...... 87 5.2.2 Surface Water ...... 90 5.2.3 Groundwater ...... 91 5.2.4 Vegetation and Fauna ...... 93 5.2.5 Pastoral Operations...... 96 5.2.6 Munga-Thirri–Simpson Desert Regional Reserve ...... 98 5.2.7 Public Safety and Amenity ...... 99 5.2.8 Cultural Heritage ...... 101 5.2.9 Economic Impact ...... 102 5.2.10 Environmental Risk Assessment Summary ...... 102 5.3 Fracture Stimulation Operations ...... 118 5.3.1 Leakage into Aquifers Due to Loss of Well Integrity ...... 118 5.3.2 Fracture Propagation into GAB Aquifers ...... 119 5.3.3 Leakage into GAB Aquifers Through Geological Material ...... 122 5.3.4 Lateral Migration of Injected Fluids ...... 122 5.3.5 Groundwater Impacts from Water Use ...... 122 5.3.6 Soil and Shallow Groundwater ...... 122

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5.3.7 Surface Water ...... 123 5.3.8 Native Vegetation and Fauna ...... 124 5.3.9 Radioactivity ...... 125 5.3.10 Seismicity ...... 125 5.3.11 Public Safety and Amenity ...... 126 5.3.12 Environmental Risk Assessment Summary ...... 127 6 Consultation ...... 135 6.1 Key Stakeholder Consultation ...... 135 7 Environmental Management System ...... 138 7.1.1 Environmental Training ...... 138 7.1.2 Emergency Response and Contingency Planning ...... 138 7.1.3 Environmental Monitoring and Audits ...... 138 7.1.4 Incident Management, Recording and Corrective Actions .... 139 7.1.5 Reporting ...... 139 8 References ...... 140 9 Abbreviations and Glossary ...... 145

Appendix 1: Listing of Fracturing Additives and Constituents Appendix 2: Agency Consultation Comments and Responses

Tables

Table 1-1: Licence Area Work Program Commitments ...... 2 Table 2.1: Additional environmental legislation and approvals ...... 8 Table 3.1: Access track construction methods for landforms in the licence area ...... 13 Table 3.2: Well lease construction methods for landforms in the licence area ...... 18 Table 3.3: Key components and typical dimensions for an ALA ...... 20 Table 3.4: Additives typically used in fracture stimulation fluids ...... 29 Table 3.5: Typical drilling, completions and fracture stimulation wastes and disposal methods ...... 34 Table 4.1: Climate data for Oodnadatta Airport ...... 38 Table 4.2: Typical landforms and characteristics in the licence area...... 41 Table 4.3: Mapped vegetation associations in the licence area ...... 43 Table 4.4: Threatened species recorded or predicted to occur in the licence area ...... 46 Table 4.5: Weeds recorded in the licence area ...... 49 Table 4.6: Summary of potential unconventional targets ...... 66 Table 4.7: Summary of salinity, pressure and permeability characteristics ...... 67 Table 4.8: Water bores (or other drill holes converted to water bores) drilled within the licence area ...... 72 Table 4.9: Exploration wells previously drilled in the licence area ...... 78 Table 5.1: Severity of consequences ...... 85 Table 5.2: Assessment of likelihood ...... 86 Table 5.3: Risk matrix ...... 86 Table 5.4: Impacts associated with earthworks in the various land systems ...... 88 Table 5.5: Environmental risk assessment for drilling, completion and initial production testing in the Simpson, Eromanga and Pedirka Basins, South Australia ...... 103 Table 5.6: Environmental risk assessment for fracture stimulation in the Simpson Pedirka Regions, South Australia ...... 128 Table 6.1: Stakeholder consultation list ...... 135 Table 6.2: Summary of issues raised during stakeholder consultation...... 136

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Figures

Figure 1-1: Location of Tri-Star Petroleum Exploration Licences (PELs) 160, 288, 289 and 290 and the Simpson, Eromanga and Pedirka Basins ...... 4 Figure 1-2: Location of Goyder Lagoon and Kallakoopah Creek ...... 5 Figure 3-1: Existing access tracks in the licence area and surrounding region ...... 14 Figure 3-2: Typical oil exploration well lease layout (Source: Santos 2003) ...... 16 Figure 3-3: Typical gas well lease layout (Source: Santos, 2015) ...... 16 Figure 3-4: Well lease layout with fracture stimulation equipment (Source: Senex, 2015) ...... 17 Figure 3-5: Large above-ground water storage tank (Source: Senex, 2015)...... 17 Figure 3-6: Typical fracture stimulation fluid tank for small-scale operations (Source: Senex, 2015) ...... 17 Figure 3-7: Cross-section of ALA showing cleared runway strip and flyover area and adjacent lateral transitional slopes...... 20 Figure 3-8: Fracture Stimulation (Source: DEM, 2018) ...... 24 Figure 3-9: Example of model output for fracture stimulation treatment. (Source: Santos 2015) ...... 26 Figure 3-10: Example of fracture stimulation workflow for exploration and appraisal ... 26 Figure 3-11: Example of real-time monitoring of fracture stimulation (Source: Santos 2015)...... 27 Figure 4-1: Land systems mapped in the licence area (Source: DEW, 2010) ...... 42 Figure 4-2: Surface water features in the vicinity of the licence area ...... 53 Figure 4-3: Illustration of different types of hydrocarbon reservoirs (after Schenk and Pollastro 2002)...... 54 Figure 4-4: Structural Elements and relationships between Pedirka, Simpson and Eromanga Basins (from Ambrose et al., 2007)...... 55 Figure 4-5: Regional structural features expressed in the structural depth of the Cretaceous ‘C’ seismic horizon (Cadna-Owie Formation) (Source: Radke, 2009)...... 56 Figure 4-6: Structural cross-section across the Pooloowanna Trough including vitrinite reflectance profiles (Ambrose et al. 2007) ...... 57 Figure 4-7: Basin stratigraphy ...... 58 Figure 4-8: Schematic section across the Eromanga. Pedirka and Simpson basins ...... 60 Figure 4-9: Stratigraphic cross-section for South Australia and Queensland wells. Datum is base Algebuckina Sandstone (Ambrose et al. 2007) ...... 61 Figure 4-10: Gas chromatogram of oil and condensate samples recovered from the Poolowanna 1 well. (Source: Ambrose et al., 2007)...... 62 Figure 4-11: The early Jurassic and Triassic formations from the Poolowanna 1 well log (Source: Ambrose et al., 2007)...... 63 Figure 4-12: Pedirka, Simpson and Eromanga Basins play types and proposed migration pathways (schematic) (Source: Ambrose et al., 2002)...... 64 Figure 4-13: Regional geological cross section of the area ...... 69 Figure 4-14: Regional geological cross section of the area ...... 70 Figure 4-15: Existing water bores in the licence area ...... 74 Figure 4-16: Pastoral leases surrounding the licence area ...... 77 Figure 4-17: Historic exploration wells and seismic lines in the licence area ...... 79 Figure 4-18: Existing roads and tracks in the Munga-Thirri–Simpson Desert RR and CP (Source: DEW, 2019a) ...... 83 Figure 5-1: Indicative Fracture Stimulation schematic showing stratigraphy, fracture extent and geological control provided by adjacent formations ...... 121

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1 Introduction

Tri-Star Energy Company (Tri-Star) holds several Petroleum Exploration Licences (PELs) in the South Australian Simpson and Pedirka Regions (see Figure 1-1). Tri-Star plans to undertake exploration drilling activities in these PELs to identify and delineate potential petroleum prospects. This Environmental Impact Report (EIR) has been prepared as a requirement of the South Australian Petroleum and Geothermal Energy Act 2000 to provide information on the proposed activities, the potential environmental impacts and their management.

This document has been prepared to satisfy the requirements of an EIR under the Petroleum and Geothermal Energy Act 2000 (the Act). It has been prepared in accordance with current legislative requirements, in particular Section 97 of the Act and Regulation 10 of the Petroleum and Geothermal Energy Regulations 2013 (the Regulations).

This document relates to petroleum exploration activities carried out in Tri-Star’s licence area (PELs 160, 288, 289 and 290) in the Simpson and Pedirka Regions, South Australia (see Figure 1-1). This EIR has been developed to use as the basis for preparation of a Statement of Environmental Objectives (SEO). The SEO outlines environmental objectives that Tri-Star is required to achieve and the criteria on which the objectives are to be assessed.

Tri-Star was founded in Texas, USA, in 1979 to explore and develop its Permian Basin oil reserves, Tri- Star began its Australian exploration activities in 1988. After 30+ years of exploration and development in Queensland, Tri-Star’s Australian tenures form the bulk of its reserves.

In Australia, Tri-Star operates both coal and gas interests, and is participating as non-operator in exploration and development joint ventures with members of coal seam gas (CSG) to liquefied natural gas (LNG) projects, including Gladstone LNG (GLNG) and Australia Pacific LNG (APLNG).

The Queensland CSG tenures which Tri-Star discovered and developed at Durham Ranch, Spring Gully and Fairview CSG fields are not only the best in Australia, but some of the best in the world. Well productivity, production life, and proximity to major infrastructure and ports, compare favourably with other CSG fields in Australia and elsewhere. Tri-Star has an enviable track record of environmental stewardship, operating for 30+ years with zero Environmental Infringement Notices.

Tri-Star maintains a large portfolio of both coal and petroleum tenure within South Australia covering the Arckaringa, Pedirka and Simpson basins. Tri-Star also operates in the Northern Territory and Queensland.

The Simpson and Pedrika Regions are located in central Australia at the border of South Australia, the Northern Territory and Queensland (see Figure 1-1). Tri-Star’s PELs 160, 288, 289 and 290 (henceforth referred to as the licence area) cover a continuous area of approximately 33,150 km2 that is largely located in the Munga-Thirri–Simpson Desert Regional Reserve (RR) and smaller areas of several pastoral leases.

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The licence area has been subject to intermittent petroleum exploration since the 1950s. Exploration activities have included numerous seismic surveys and the drilling of several exploration and stratigraphic wells. The Simpson and Pedrika Regions contain several prospective hydrocarbon formations. Oil was originally discovered in the Poolowanna Trough following the drilling of Poolawanna-1 in 1977. Drill stem tests of Poolawanna-1 returned a waxy, paraffinic crude oil along with mud and water. A light oil condensate was also recovered from the upper Peera Peera Formation. Numerous wells were drilled following the Poolowanna-1 discovery with oil shows recorded in multiple intersections, however no commercial hydrocarbon discovery has yet to be made.

Tri-Star plans to implement new technology (as described in this EIR) to unlock the potential of the Simpson, Eromanga and Pedirka Basins. Tri-Star will be focusing its efforts on both conventional and unconventional petroleum opportunities in multiple formations. Tri-Star’s plans involve drilling one or two exploration wells initially, with further drilling activities contingent on initial results. Exploration activity is expected to involve the drilling of 2 wells (as detailed in Table 1-1), with further activities contingent on initial findings.

Table 1-1: Licence Area Work Program Commitments

Year PEL 160 PELs 288, 289, 290 & 331 2021 G&G Studies G&G 2022 G&G Studies 300 km 2D Seismic 2023 G&G Studies 100 km 3D Seismic 2024 40 km 2D Seismic Drill 1 Well 2025 Drill 1 Well Work commitments current as at December 2019

This EIR addresses potential environmental risks and consequences associated with Tri-Star’s exploration drilling activities in the South Australian Simpson and Pedrika Regions(PELs 160, 288, 289 and 290) rather than relating to a specific site or sites, or to specific projects. This all encompassing approach has been applied in several EIRs and SEOs that have been developed and approved under the Act.

Tri-Star proposes to exclude drilling exploratory wells in Goyder Lagoon1 and the area within 500 m of the main channel of Kallakoopah Creek2 from the scope of this EIR. However, activities reasonably necessary for, or incidental to, exploratory well drilling operations are not excluded from being undertaken in these areas (e.g. access construction and maintenance). (see Figure 1-2).

The southern boundary of PEL 288 overlaps the Kalamurina pastoral lease (see Figure 1-2). Kalamurina is held by the Australian Wildlife Conservancy (AWC) and is operated as a private sanctuary. The overlapping area represents approximately 60 km2. Tri-Star proposes to exclude undertaking petroleum activities in Kalamurina from the scope of this EIR.

Petroleum operations covered by this EIR include: ▪ well site and access track construction, maintenance and restoration

1 Goyder Lagoon, as defined by the Wetlands of National Importance 3rd Edition (Spatial GIS Layer) (DEEH, 2001). 2 Kallakoopah Creek, as defined by the DEW Watercourses in South Australia dataset (GDA94) (DEW, 2019).

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▪ aircraft landing area construction, maintenance and restoration (if required) ▪ well operations (drilling, completions and workovers) ▪ fracture stimulation ▪ well production testing (drill stem tests and initial production testing); and ▪ well and zonal decommissioning.

This EIR and accompanying SEO do not apply to petroleum operations such as: ▪ seismic exploration activities ▪ production and processing operations beyond initial well production testing ▪ permanent field production and processing equipment installation, operation, decommissioning and rehabilitation; and ▪ pipeline construction, operation and decommissioning.

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Figure 1-1: Location of Tri-Star Petroleum Exploration Licences (PELs) 160, 288, 289 and 290 and the Simpson and Pedirka Regions

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Figure 1-2: Location of Goyder Lagoon and Kallakoopah Creek

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2 Legislative Framework

This section briefly describes the legislative framework that currently applies to petroleum licensing in South Australia.

Petroleum activities in South Australia are governed by the Petroleum and Geothermal Energy Act 2000 (the Act) and the Petroleum and Geothermal Energy Regulations 2013 (the Regulations). This legislation is administered by the Department for Energy and Mining (DEM).

Key objectives of the legislation include: ▪ to create an effective, efficient and flexible regulatory system for exploration and recovery or commercial utilisation of petroleum and other regulated resources ▪ to minimise environmental damage from the activities involved in exploration and recovery or commercial utilisation of petroleum and other regulated resources ▪ to establish appropriate consultative processes involving people directly affected by regulated activities and the public generally; and ▪ to protect the public from risks inherent in regulated activities.

Regulated activities, as defined in Section 10 of the Act, are: ▪ exploration for petroleum or another regulated resource ▪ operations to establish the nature and extent of a discovery of petroleum or another regulated resource, and to establish the commercial feasibility of production and the appropriate production techniques ▪ production of petroleum or another regulated substance ▪ utilisation of a natural reservoir to store petroleum or another regulated substance ▪ production of geothermal energy ▪ construction of a transmission pipeline for carrying petroleum or another regulated substance; and ▪ operation of a transmission pipeline for carrying petroleum or another regulated substance.

Statement of Environmental Objectives

As a requirement of Part 12 of the Act, a regulated activity can only be conducted if an approved SEO has been developed. The SEO outlines the environmental objectives that the regulated activity is required to achieve and the criteria upon which the objectives are to be assessed.

Under Regulation 14 of the Petroleum and Geothermal Energy Regulations, an approved SEO must be reviewed at least once in every five years.

Environmental Impact Report

In accordance with Section 97 of the Act, an EIR must: ▪ take into account cultural, amenity and other values of Aboriginal and other Australians insofar as those values are relevant to the assessment ▪ take into account risks to the health and safety of the public inherent in the regulated activities; and ▪ contain sufficient information to make possible an informed assessment of the likely impact of the activities on the environment.

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As per Regulation 10 of the Petroleum and Geothermal Energy Regulations, the EIR must include: ▪ a description of the regulated activities to be carried out under the licence (including their location) ▪ a description of the specific features of the environment that can reasonably be expected to be affected by the activities, with particular reference to the physical and biological aspects of the environment and existing land uses ▪ an assessment of the cultural values of Aboriginal and other Australians which could reasonably be foreseen to be affected by the activities in the area of the licence, and the public health and safety risks inherent in those activities (insofar as these matters are relevant in the particular circumstances) ▪ if required by the Minister – a prudential assessment of the security of natural gas supply ▪ a description of the reasonably foreseeable events associated with the activity that could pose a threat to the relevant environment (including events during the construction, operational and abandonment stages, atypical events, estimated frequency of events and the basis of predictions) ▪ an assessment of the potential consequences of these events on the environment (including size and scope, duration, cumulative effects (if any), the extent to which these consequences can be managed or addressed and proposed management actions) ▪ an explanation of the basis on which these consequences have been predicted ▪ a list of all owners of the relevant land; and ▪ information on consultation undertaken during preparation of the EIR.

The EIR is submitted to DEM and an Environmental Significance Assessment is undertaken to determine whether the activities described in the EIR are to be classified as ‘low’, ‘medium’ or ‘high’ impact (refer to DEM (2019) for further detail on assessment criteria). A corresponding SEO is prepared, reflecting the impacts and measures identified in the EIR or other assessments that may be required as determined by the classification.

The classification also determines the level of consultation DEM will be required to undertake prior to final approval of the SEO as follows:

▪ Low impact activities do not require public consultation and are subjected to a process of internal government consultation and comment on the EIR and SEO prior to approval ▪ Medium impact activities require a public consultation process for the EIR and proposed SEO, with comment sought for a period of at least 30 business days; and ▪ High impact activities are required to undergo an environmental impact assessment under the provisions of the Development Act 1993.

The level of impact of a particular activity is assessed on the basis of the predictability and manageability of the impacts on the environment. Where the environmental impacts are predictable and readily managed, the impact of the activity is considered low. Where the environmental impacts are less predictable and are difficult to manage, the impact of the activity is potentially high.

Once the approval process is complete, all documentation, including this EIR and its associated SEO, must be entered on an environmental register. This public Environmental Register is accessible to the community from the DEM website.

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Prior to commencing a regulated activity, Section 74(3) of the Petroleum and Geothermal Energy Act provides that: ▪ the Minister’s prior written approval is required for activities requiring high level supervision (as per Regulation 19); and ▪ notice of activities requiring low level supervision is to be given at least 21 days in advance (as per Regulation 18).

In order to obtain written approval for activities requiring high level supervision, an application and notification of activities (in accordance with Regulation 20) must be submitted to the Minister at least 35 days prior to the commencement of activities.

The notification of activities must provide specific technical and environmental information on the proposed activity and include an assessment to demonstrate that it is covered by an existing SEO.

Consequently, the activity notification process provides an additional opportunity for DEM to ensure that the proposed activities and their impacts can be effectively managed and are consistent with the approvals obtained in the EIR and SEO approval process. This is particularly relevant for activities that are conducted under an SEO that applies to a broad geographical area, as it provides site-specific detail that is not usually contained in the generic documents.

A number of additional environmental approvals may be required under Commonwealth and South Australian legislation. These are outlined in Table 2.1. (Note that this is not a comprehensive list of all applicable legislation).

It must be noted that not all subsequent approvals are mandatory at the development (or construction) stage, as approvals may be required as circumstances arise (for example cultural artefact finds during construction or operation).

Table 2.1: Additional environmental legislation and approvals

Agency Legislation Issue

Commonwealth Department of Environment Protection and Assessment and approval required if activities will Agriculture, Water Biodiversity Conservation Act significantly impact matters of national environmental and the Environment 1999 (EPBC Act) significance, including: (DAWE) ▪ National Heritage Places ▪ wetlands of international importance (Ramsar wetlands) ▪ listed threatened species and communities ▪ listed migratory species (for example JAMBA and CAMBA); and ▪ a water resource in relation to coal seam gas and large coal mining developments. Commonwealth Native Title Act 1993 Intersection of registered Native Title claims. South Australia Department for Heritage Places Act 1993 Permission required if listed heritage places or related Environment and objects are to be destroyed / disturbed. Water (DEW)

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Agency Legislation Issue

DEW National Parks and Wildlife Act ‘Taking’ of protected plant and animal species. 1972 Undertaking regulated activities in Regional Reserves. DEW Native Vegetation Act 1991 Removal of native vegetation and achievement of significant environmental benefit (SEB). DEW Crown Land Management Act Provision for the disposal, management and conservation of 2009 Crown Land in South Australia. DEW Natural Resources Management Management of pest plants and animals. SAAL NRM Board Act 2004 Water sourcing (e.g. from new bores) and licensing of water extraction. Water affecting activities. Department of the Aboriginal Heritage Act 1988 Authorisation required if Aboriginal sites, objects or remains Premier and Cabinet are to be damaged, disturbed or interfered with. (Aboriginal Affairs and Reconciliation) Environment Environment Protection Act 1993 General environmental duty to avoid causing environmental Protection Authority (including all Environment harm (EPA) Protection Policies (EPP) e.g. Protection of water quality Environment Protection (Water Quality) Policy 2015) EPA Radiation Protection and Control Control of activities related to radioactive substances and Act 1982 radiation apparatus, and for protecting the environment and the health and safety of people against the harmful effects of radiation. Primary Industries Pastoral Land Management and Provides for the management and conservation of pastoral and Regions South Conservation Act 1989 land to ensure that all pastoral land in SA is well managed Australia (PIRSA) and utilised to maintain renewable resources and yields sustained. Attorney General’s Native Title (South Australia) Act Matters relating to traditional land rights in South Australia. Department 1994 The Act provides for the registration of native title rights, investigations on native title rights, claims and determinations of native title rights and compensation for acts affecting native title rights. Safework SA Explosives Act (South Australia) Regulates the manufacture, carriage, storage, import and 1936 purchase or explosives. Safework SA Work Health and Safety Act 2012 Identifies control measures to be applied to specific work activities and hazards.

Other legislation of particular relevance to the proposed activities include: ▪ Fire and Emergency Services Regulations 2005 – in relation to fire bans and hot work permits; and ▪ South Australian Public Health (Wastewater) Regulations 2013 – in relation to waste water (sewage) disposal and the operation of septic tank systems with respect to the Department of Health’s requirements / approval.

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EPBC Act

Approval under the Commonwealth Environment Protection and Biodiversity Conservation Act 1999 (EPBC Act) is required for activities that have a significant impact on matters of national environmental significance including World Heritage properties, National Heritage places, Ramsar wetlands of international importance, nationally threatened species and ecological communities, migratory species and water resources in relation to coal seam gas and large coal mining developments.

In regard to petroleum activities in the Cooper Basin, issues that potentially require approval under the EPBC Act are relatively limited and can generally be avoided by site selection and implementation of field procedures (e.g. avoiding impacts to populations of threatened species, surface drainage and significant wetland areas).

Tri-Star will review proposed activities against the EPBC Act triggers and submit a referral under the Act for specific activities if necessary.

Native Vegetation Act and Regulations

Exploration activities that are approved under the Petroleum and Geothermal Energy Act do not require approval under the Native Vegetation Act 1991 for clearance of native vegetation, provided that the activities are undertaken in accordance with industry standards endorsed by the Native Vegetation Council (NVC) that are directed towards minimising impact and encouraging regrowth of any native vegetation that is cleared (see Regulation 15 of the Native Vegetation Regulations 2017).

If there are no applicable industry standards, or if it is not possible to undertake the operations in accordance with applicable industry standards, the clearance is permitted if the clearance is undertaken in accordance with a management plan, approved by the NVC, that results in a significant environmental benefit, or if the person undertaking the operations makes a payment into the Fund of an amount considered by the Council to be sufficient to achieve a significant environmental benefit.

Guidelines have been developed to provide a framework for determining the significant environmental benefit (SEB) requirement or the amount for payment into the Native Vegetation Fund, where it is required. These guidelines are administered by DEM, which has the delegated authority to approve SEBs.

Environment Protection Act

The Environment Protection Act 1993 imposes a general environmental duty not to undertake an activity that pollutes, or might pollute, the environment unless all reasonable and practicable measures have been taken to prevent or minimise any resulting environmental harm.

Environmental authorisations are required to undertake activities prescribed under the Act. The Environment Protection Act also imposes an obligation to report incidents causing or threatening serious or material harm to the EPA, where applicable, in accordance with Sections 83 and 83A of the Act. The Environment Protection Act does not apply to petroleum exploration activities undertaken under the Petroleum and Geothermal Energy Act or to wastes produced in the course of an activity (not being a prescribed activity of environmental significance) authorised by a licence under the Petroleum and Geothermal Energy Act when produced and disposed of to land and contained within the area of the licence.

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3 Proposed Activities

The following section provides an overview of petroleum drilling and fracture stimulation activities including activities related to well production testing.

The operations considered in this EIR include surface and subsurface activities such as well lease and access track construction, drilling and fracture stimulation operations, and ongoing well maintenance through to decommissioning. To assess the environmental impact of exploration drilling and fracture stimulation operations on the environment, the activities have been grouped and considered as follows:

Drilling Operations ▪ Construction Activities (Section 3.2.1) ▪ Well Drilling Activities (Section 3.2.2) ▪ Well Completion and Workover Activities (Section 3.2.3) ▪ Well Production Testing (Section 3.2.4); and ▪ Well Decommissioning (Section 3.2.5).

Fracture Stimulation Operations ▪ Well Design and Construction (Section 3.3.1) ▪ Fracture Stimulation Design (Section 3.3.2) ▪ Fracture Stimulation Monitoring (Section 3.3.3) ▪ Fracture Stimulation Stages (Section 3.3.4) ▪ Fracture Stimulation Fluids (Section 3.3.5) ▪ Post Stimulation Flowback (Section 3.3.6) ▪ Equipment and Materials (Section 3.3.7); and ▪ Water Use and Management (Section 3.3.8).

Associated Activities ▪ Water Supply (Section 3.4.1) ▪ Waste Management (Section 3.4.2); and ▪ Fuel and Chemical Storage (Section 3.4.3).

Restoration and Rehabilitation ▪ Initial Restoration (Section 3.5.1) ▪ Partial Restoration (Section 3.5.2); and ▪ Final Restoration (Section 3.5.3).

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Access Tracks

Well leases generally require the construction of purpose-built access tracks to connect the site to an existing track or road. Tri-Star will use existing roads and tracks where possible and appropriate. The licence area to which this EIR refers has very limited road infrastructure. The Birdsville Track crosses the south-eastern corner of PEL 290, and several tracks and public access tracks cross the licence area. Pastoral leases in PELs 289 and 290 (Alton Downs and Clifton Hills) contain a sparse network of pastoral roads and tracks (see Figure 3-1).

Tri-Star will liaise with DEM, the Department for Environment and Water (DEW), the Wangkangurru / Yarluyandi People, and relevant landholders to develop appropriate and mutually beneficial access to the licence area.

The construction method used for access track construction is dependent upon the terrain in which it is being built, and the expected level of use or traffic. Safety requirements are also taken into consideration and define the minimum design standards for access tracks.

In most cases the access track is cleared and graded, or rolled, and capped with clay where required. Erosion controls are implemented during and after access track construction, with particular attention given to areas prone to surface water movements or flooding. Culverts or other structures may be installed where required to ensure that surface water flows are not impeded by the road. Alternatively, the access track can be constructed at ground level with no windrows, so the road does not impede natural surface water flows.

In some circumstances, structures such as raised roads may be installed to support petroleum activities. Where relevant, a detailed hydrological assessment is undertaken for these structures to ensure no significant impacts on surface water flows or aquatic fauna. Table 3.1 provides information on the general road construction methods that would be applied to landforms in the licence area. These landforms are discussed in Section 4.2.

Access tracks in gibber terrain

In sensitive gibber environments the stone cover layer should be maintained wherever possible to control erosion. The following methods are considered to minimise disturbance and control erosion risk: ▪ roll gibber where surface is naturally smooth, stable and trafficable ▪ remove gibber mantle to windrows, grade underlying surface smooth, replace gibber mantle, water and roll ▪ leave existing natural surface, over-cap large rocks and wearing areas with borrow material that contains clay and stone ▪ construct erosion control berms, banks and drains where required; and ▪ undertake ongoing maintenance to prevent wheel rutting and water channelling.

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Table 3.1: Access track construction methods for landforms in the licence area

Landform Construction Method Gibber Salt Dunefields / Sand Plains Floodplains Wetlands plains lakes Avoid construction on land system ✓ ✓ Utilise naturally cleared areas ✓ ✓ ✓ ✓ Avoid steep slopes Susceptible to erosion. Ensure controls are in ✓ place Weave road between trees and large ✓ ✓ ✓ ✓ shrubs

Clear and grade ✓ ✓ * ✓ Roll ✓ Cap road surface with clay or similar ✓ ✓ ✓ ✓ borrow material Culverts or floodways installed on ✓ ✓ ✓ ✓ drainage line crossings as required * In Gibber environments the surface stone layer cover should be maintained wherever possible to control erosion. Clear and grade of gibber is non-standard practice, which may be undertaken in some circumstances, with adequate erosion controls in place. Detailed site-specific assessment, planning, management, monitoring and rehabilitation would be required.

Traffic

The number of vehicle movements involved in drilling operations varies greatly depending on the type of drilling being undertaken. A drill rig typically requires 30-40 semi-trailer loads to move the rig and camp to the well lease, with a further 10-20 loads required to deliver supplies, operator equipment and well casing. During drilling, a water truck may be required to cart water from a water source to the well site if a water well is not available at the site. Other vehicle movements during drilling typically include daily movements of four-wheel drive vehicles (e.g. contractors or crew changes) and supply runs by a truck (typically 15 tons) every 1-2 days.

Fracture stimulation activities (following well drilling activities) require additional equipment to be transported to the well lease. Fracture stimulation activities outlined in this EIR will generally require approximately 5-10 semi-trailer loads of equipment to be delivered to the well lease, but this can vary greatly depending on fracture stimulation design and operational requirements. Additional trucks carrying water from a source point (e.g. water bore) to the well lease are also likely to be required. Trucks equipped with specialist apparatus will also be required during fracture stimulation operations e.g. a wireline perforation truck to conduct perforations prior to each fracture stimulation stage (see Section 3.3 for more detail).

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Figure 3-1: Existing access tracks in the licence area and surrounding region

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Borrow Pits

Borrow pits will be required to source material (generally in the form of clay rich soil) to cap and stabilise access tracks, camp sites, laydown areas and well leases. The volume of borrow material required depends on site substrates. Borrow pits are typically located on plains or interdune swales near roadsides and well leases. Borrow pits vary considerably in dimension depending upon the quality and quantity of material contained within them.

Poorly sited or constructed borrow pits can result in soil erosion or adverse visual impact. Wildlife or stock (where present) may also become trapped in waterlogged or muddy borrow pits. Borrow pits in some locations may provide an alternative water source for stock and wildlife, which may result in changes to grazing pressure. Additional watering points also attract scavenging wildlife, which may impact domestic stock and native fauna.

Borrow pits will be managed in accordance with current Goal Attainment Scale (GAS) criteria for the construction, maintenance and rehabilitation of borrow pits (DEM, 2014).

Well Leases

Drilling operations require a flat and stable working platform to safely locate the drill rig and undertake drilling, completions, fracture stimulation and other well management activities. The well lease must be large enough to allow for the placement of the drill rig, associated equipment and facilities e.g. ponds and tanks, generators, fuel and chemical storage, casing and pipe storage, and portable offices and accommodation. In addition, the lease should provide a defined (and where possible, low permeability) surface that provides temporary containment for minor releases.

A well lease for petroleum drilling (with amenities for fracture stimulation) generally requires the following features: ▪ a compacted and stable pad (“hard stand area”) for stabilisation of the drill rig and placement of associated infrastructure ▪ a mud sump for the disposal of drill cuttings and the recirculation of water into the mud system ▪ a flare pit or tank for well control and testing operations may be required (flare pits may be lined with a synthetic liner (HDPE or equivalent)) ▪ earthen ponds or above-ground tanks for the storage of clean water required for drilling activities (ponds may be lined with a synthetic liner e.g. HDPE or equivalent) ▪ earthen ponds or above-ground tanks to hold water and flowback fluid for fracture stimulation activities (ponds will be lined with a synthetic liner e.g. HDPE or equivalent). In some cases ponds may be located adjacent to the lease depending on pond size requirements) ▪ areas for fuel and hazardous material storage ▪ mobile wastewater treatment systems for the disposal of ablutions waste from well site offices and accommodation; and ▪ an access road with clear entry and exit points for vehicles, which could include a loop road or turnaround.

The size and layout of the well lease will vary depending on several factors such as the size and type of drill rig, the well completion program, whether fracture stimulation will be required, and the nature of the surrounding environment. Smaller drilling rigs with no requirement for fracture stimulation operations typically require a well lease in the order of 100m by 100m in size. Wells drilled by larger rigs, or that require additional space on the well lease for storage or equipment laydown (e.g. water storage tanks or ponds for fracture stimulation activities) may require a lease of approximately 200m by 200m.

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Water storage requirements for stimulation activities or other well completion operations may necessitate the installation of above-ground tanks or lined earthen ponds, such as those shown in Figure 3-4 to Figure 3-6. However, water storage requirements are dependent on the fracture stimulation design, and in some cases additional water storage capacity is not required. Examples of typical well lease layouts are provided in Figure 3-2 to Figure 3-3.

Figure 3-2: Typical oil exploration well lease layout (Source: Santos 2003)

Figure 3-3: Typical gas well lease layout (Source: Santos, 2015)

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Figure 3-4: Well lease layout with fracture stimulation equipment (Source: Senex, 2015)

Figure 3-5: Large above-ground water storage tank (Source: Senex, 2015)

Figure 3-6: Typical fracture stimulation fluid tank for small-scale operations (Source: Senex, 2015)

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Well lease construction methods are dependent upon the landform and terrain in which the lease is located. In most locations, with the exception of areas with a stony pavement (e.g. gibber plains, stony plains), topsoil and vegetation are cleared and stockpiled separately for use in restoration. Material sourced from borrow pits is imported (where required) to construct the lease pad, access roads and associated infrastructure. Borrow material consisting of preferentially clayey soils is watered and rolled to achieve adequate compaction and provide a stable and trafficable surface. The selection of well sites without steep slopes (especially in the more sensitive environments such as gibber areas) is very important in order to avoid the use of large quantities of borrow material.

Well lease construction methods specific to key landforms present are outlined in Table 3.2, and key considerations for siting and constructing well leases and associated infrastructure is outlined below: ▪ where possible, locate well leases in naturally flat terrain, avoid sloping well leases, and orientate the lease to avoid disturbance to surrounding obstructive landforms and perennial vegetation. This approach leads to the following key outcomes: ▪ mitigates the requirement for cut and fill earthworks techniques ▪ reduces the volume of borrow material required to level the site ▪ greatly reduces future erosion risk; and ▪ contributes to simpler and more efficient restoration and leads to faster natural rehabilitation of the lease area. ▪ construct erosion control measures where appropriate (i.e. diversion banks or berms) ▪ roll and cap gibber terrain wherever practicable ▪ avoid environmentally sensitive and restricted areas where possible e.g. gibber, wetlands and watercourses; and ▪ avoid disturbance of important native vegetation and fauna habitat where possible.

Table 3.2: Well lease construction methods for landforms in the licence area (adapted from Santos, 2015)

Landform Construction Method Gibber Salt Dunefields / Sand Plains Floodplains Wetlands plains lakes Avoid construction on land system ✓ ✓ Utilise naturally cleared areas ✓ ✓ ✓ ✓ Avoid steep slopes Susceptible to erosion. Ensure controls are in ✓ place Avoid trees and large shrubs ✓ ✓ ✓ ✓ Roll lease where possible ✓ ✓ Clear and grade ✓ ✓ * ✓ Stockpile topsoil and cleared ✓ ✓ ✓ vegetation Cap lease surface with clay or similar ✓ ✓ ✓ ✓ borrow material Build up lease surface ✓ ✓ ✓ ✓ Cut and fill (steep slopes) ✓ ✓ * ✓ * In sensitive gibber environments the surface stone layer cover should be maintained to control erosion. Clear and grade of gibber is non-standard practice, which may be undertaken in some circumstances, with adequate erosion controls in place. Detailed site-specific assessment, planning, management, monitoring and rehabilitation would be required.

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Campsites and Laydown Areas

Due to the extended and often remote nature of exploration drilling, completions and well operations, temporary campsites are usually required to provide accommodation for drilling, completions and associated personnel. Campsites are typically located in close proximity to well leases to minimise travel related risks. Campsites for petroleum exploration drilling are usually designed to accommodate approximately 30-40 people. In some circumstances (e.g. multi-well drilling campaigns) additional areas (‘laydown areas’) may be required to store equipment or supplies.

Laydown areas and campsites are usually constructed on either previously disturbed areas, or naturally clear, flat areas, where disturbance of vegetation and surface drainage, and the importation of borrow material, can be avoided or minimised. Where new sites are required, construction methods are generally limited to minimal vegetation clearance and site levelling to construct a stable, flat and relatively clear area to locate transportable buildings and equipment. Site location also takes into consideration landholder requirements, noise and dust generation, and other operational hazards such as interaction with stock (where present), the general public (e.g. tourists), traffic, flooding, and fire risks.

Aircraft Landing Area

Given the remote location of the licence area, Tri-Star is likely to require access to a nearby aircraft landing area (ALA) to efficiently transport operational personnel, and for access in emergency situations e.g. Royal Flying Doctor Service (RFDS) aircraft access. Tri-Star considers access to a local ALA is necessary to meet occupational health and safety (OHS) and emergency response requirements. Parts of the licence area are located more than 200 km drive (on unformed access tracks) to the nearest ALA (e.g. Witjira National Park, Clifton Hills Pastoral Station).

Tri-Star’s preference would be to utilise, maintain or upgrade an existing ALA. Tri-Star will evaluate the feasibility of using existing ALAs in the region prior to constructing a new ALA. A new ALA would be designed to meet the minimum requirements of the Civil Aviation Safety Authority (CASA) Guidelines for aeroplane landing areas (CASA, 1992), and relevant standards published by the RFDS3.

Aircraft landing areas are primarily used in the daytime but may be designed to be suitable for night- time use in case of emergencies. Permanent aircraft landing areas are typically fenced to exclude large fauna, and gates and signage are also typically installed to restrict vehicle and personnel movement through the landing strip area. An ALA is unlikely to be designed as an all-weather strip i.e. borrow capping material is unlikely to be required, and the ALA surface will only be graded.

An ALA (if required) would be located and designed to minimise impacts on a range of environmental and community sensitivities e.g. landforms, vegetation, noise and dust nuisance. The compacted runway surface of the ALA will be in the order of 1200 m long and 20m wide with the approach, take- off and adjacent flyover areas (which must be clear of vegetation) totalling approximately 1,800 m by 90 m.

CASA requirements stipulate that objects located within the approach, take-off and lateral transitional areas are not allowed to protrude above prescribed surface slopes. A typical ALA cross section is shown in Figure 3-7, and key components and typical dimensions of an ALA are summarised in Table 3.3.

3 https://www.flyingdoctor.org.au/preparing-airstrip/

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Vegetation and topsoil cleared from an ALA area (if required) would be stockpiled parallel to the edge of the cleared area, at some distance from the runway strip and below the height of the transitional clearance envelope. Once the ALA is no longer in use, the surface would be reprofiled to match original surface contours and stockpiled topsoil and vegetation respread.

Table 3.3: Key components and typical dimensions for an ALA

Width ▪ Runway: 20m wide with a 25m x 25m turning node at each end – must be smooth enough to provide a comfortable ride in a stiffly sprung vehicle travelling at a speed of at least 75 km/h ▪ Runway strip (contains runway): 45m wide – must be trafficable but can be to a lesser standard than the runway surface ▪ Flyover area: 90m wide (including runway strip) – need not be trafficable but must be clear of all above ground level objects including trees, shrubs, fences, mounds and rock outcrops ▪ Lateral transitional surface: 45m either side of flyover area, clear of obstacles on a 20% transitional slope (i.e. no 9m tall trees allowed within 45m of the edge of the flyover area).

Length ▪ Runway strip and flyover area: 1200m ▪ Approach and take-off areas: 900m long, clear of objects above slope 3.3% for night time use (i.e. no 10m tall trees allowed within 300m) ▪ Width of approach and take-off area increases to 180m at 900m from end of strip.

Apron (parking area) ▪ At least 50 x 30m.

Taxiway to apron ▪ 12 m width. Other infrastructure likely required as part of a new ALA includes: ▪ Access track ▪ Water storage ponds or tanks ▪ Markers and windsock.

20% (1:5) transitional slope

9m

45m 90m 45m

Clear of obstacles on Runway, runway strip and flyover Clear of obstacles on 20% slope area (cleared) 20% slope

Figure 3-7: Cross-section of ALA showing cleared runway strip and flyover area and adjacent lateral transitional slopes

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Drilling operations will be typical of standard petroleum exploration activities and are summarised below. Detailed descriptions of drilling operations are provided in Santos (2015). Additional details on the drilling parameters for an individual well will be provided in activity notification documentation (as discussed in Section 2.1.2).

The following drilling operations will be carried out: ▪ drilling to a projected total depth (typically 2200m to 3000m depending on targets) ▪ drilling muds used will be water-based and non-toxic or low toxicity and the sump will not be lined unless the well site is in an area where very shallow aquifers are present ▪ side-wall coring, which may be used to obtain samples to provide information on the formations present ▪ running and cementing surface casing and any intermediate casing required ▪ drill stem testing, which may be used to evaluate pressures and production from any potential hydrocarbon producing formation(s). Drill stem tools would be set to cover the zone of interest, and if the well has potential to flow, it will produce to the surface where it is measured. The production would flow through a separator tank or to a flare pit for flaring ▪ any small quantities of formation water produced would be disposed of in the drilling sump and allowed to evaporate; and ▪ open-hole logging to evaluate formations of interest.

If commercial quantities of hydrocarbons are discovered the following will be carried out: ▪ Installation and cementing of production casing ▪ installation of well head; and ▪ completion, which involves cleaning out the casing, perforating the zones of interest, running tubulars, setting packers, running production logging tools and static gradients.

Artificial lift systems (e.g. jet pump or electronic submersible pumps) may be installed if there is not sufficient pressure in the formation to push petroleum to the surface. (Note: The operation of these artificial lift systems for production is outside the scope of this EIR).

In the event that a well fails to discover commercial quantities of petroleum it will be decommissioned, as discussed in Section 3.2.5.

The typical duration of drilling for a single well (mobilisation to demobilisation) is in the order of 30 to 35 days, however this may be extended in some circumstances given the remote nature of the licence area.

Workover operations may also be carried out on wells. Typically, workover operations occur later in a well’s life span, but may be required soon after drilling. They may include cleaning sand out of the well, replacing liners, plugging the well, repairing casing, drilling deeper, drilling around any obstructions in the well, and re-perforating existing zones in production. Some workovers require only wireline equipment to lower tools into the hole to conduct operations, but others require a specialist workover rig to be moved to the location. Pumps and storage tanks are required to be located on the well lease for operations that need to circulate workover fluids in the well. Well completions and workovers are usually carried out by smaller rigs than those used in the initial drilling of the well.

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If petroleum is discovered, initial production testing may be performed prior to the construction and installation of permanent production facilities. These tests are typically required to assist in the evaluation of the well’s productivity in order to justify and/or assist in the design of permanent production facilities. The test duration, and the type and volume of fluids produced are dependent on the characteristics of the well. Tests may range in duration from a few days to up to 6 months.

Installations for initial production testing are typically small-scale, mobile and temporary in nature. They are normally confined to the drilling pad and may consist of one or more separator and storage tanks, with inter-connecting pipework and valving. Testing equipment and personnel may be provided by either a contractor or by Tri-Star in-house, depending on requirements. Over-pressure shutdowns, spill protection and other risk mitigation measures are incorporated in a fit-for-purpose manner. The testing activities may be manned or unmanned, subject to testing requirements and risk assessment.

In the case of a potentially producing gas discovery, a single / multi-rate flow and build-up operation would be undertaken, with produced gas flared off. Details will necessarily depend on the outcome of drilling, but an IPT test for gas, while “producing” under the meaning of the Petroleum and Geothermal Energy Act, will not require additional surface infrastructure.

Produced oil is loaded into tankers and trucked off-site. Produced water may be disposed to either tanks, drilling sumps or local ponds for evaporation or may be trucked off-site. Produced petroleum and any co-produced water typically flow to a separator tank and then one or more stock tanks for measurement, and the small volume of water that may be produced is separated and disposed of to a tank or pond where it evaporates. If IPT were successful, regulatory approvals would be sought for upgrading to production rather than exploration facilities.

Establishment of permanent or semi-permanent surface infrastructure for longer term production operations such as large hydrocarbon storage tanks or water disposal ponds is not covered by this EIR.

Decommissioning4 Following Drilling

Following completion of well drilling (and fracture stimulation and/or production testing), a decision is made to install cement production casing or plug and decommission the well.

The primary objective of well decommissioning is to isolate hydrocarbon and water bearing formations. Wells are decommissioned to avoid crossflow that could result in environmental harm to aquifer systems and/or flow between hydrocarbon reservoirs or another aquifer system.

If a decision is made to abandon the well the following steps are undertaken: ▪ plugs are set to isolate all formations that have hydrocarbons ▪ plugs are set across separate aquifers ▪ plugs are set across the surface casing shoe and intermediate casing shoe (if present) ▪ a plug (typically 15 m) is set at the surface prior to cutting off the surface casing bowl; and ▪ A decommissioning plaque is posted.

4 Decommissioning of wells is equivalent to ‘abandonment’, which is the technical term used in the Petroleum and Geothermal Energy Regulations 2013.

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The well lease is then cleaned-up and reinstated as described in Section 3.5 below. Decommissioning programs are submitted to DEM for prior approval.

Decommissioning Following Production

Once a well has reached the end of its productive life a decision is made on whether to decommission the cased well bore or leave it in a suspended state until it can be decommissioned. Each well is evaluated individually to design the decommissioning program. Decommissioning programs are submitted to DEM for prior approval.

The decommissioning program usually involves the following: ▪ all perforated petroleum zones are isolated from other perforated zones with cement plugs and/or bridge plugs ▪ the bond logs are evaluated to ensure that the cement behind the production casing is adequate to avoid crossflow of aquifers with other aquifers or hydrocarbon producing zones ▪ a decision may be made to perforate and squeeze off the aquifer to ensure there is no crossflow ▪ an additional cement plug is placed in the surface casing prior to cutting off the well head below ground level; and ▪ a decommissioning plaque is posted.

The well lease is then cleaned up and reinstated as described in Section 3.5 below. Decommissioning programs are submitted to DEM for prior approval.

Fracture stimulation is a process used in to enhance deliverability from the well. It involves the injection of fluid into the target formation at pressures sufficient to split the rock and create high conductivity flow paths to the well. These highly conductive flow paths will enable increased production rates and, in some cases, can add reserves.

The injected water is slightly modified with a gelling agent to enable proppant material (sand or ceramic material similar to sand particles) to be pumped into the rock to hold the induced fractures open. Further additives are used to control corrosion, friction, remove bacteria and assist with recovering the stimulation fluids from the interval when the well is flowed back to production.

Fracture stimulation has been used for over forty years in the nearby Cooper Basin and has been used in several hundred conventional and unconventional gas wells to improve deliverability and commerciality of these wells. The industry has also had extensive experience successfully and safely fracture stimulating oil-bearing reservoirs to improve oil recovery and has carried out over 140 fracture stimulation treatments in target oil reservoirs within the Great Artesian Basin.

This section describes the application of fracture stimulation to the exploration of target formations in the Simpson and Pedrika Regions as described in Section 4.5. It outlines the principles of well design and construction and goes on to describe the fracture stimulation process, the fluids used, monitoring of stimulation, completions, flow back and production testing, water use and other associated issues. Implementation of the items discussed in this section will be assessed after well completion in consultation with DEM during the activity notification process for any proposed fracture stimulation activities (see Section 2.1.2).

A simplified diagram of a fracture stimulation treatment is provided in Figure 3-8.

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Figure 3-8: Fracture Stimulation (Source: DEM, 2018)

Well design and construction is important in ensuring well integrity under all the operating conditions that the well is expected to experience, and is particularly important during the fracture stimulation treatment and subsequent testing operations.

The wellhead, steel casing, cement and production tubing are designed to be suitable for: ▪ the temperatures and pressures expected down-hole ▪ the pressures required to initiate fracture stimulation treatments deep underground ▪ the stresses induced when large volumes of cool fluids are pumped, at pressure, into the well during stimulation ▪ the flow back of reservoir fluids or the flow back of sour gases.

When wells are drilled, a series of steel casing strings are installed and cemented into the ground at various depths to provide mechanical stability and isolation of the wellbore from the formations and aquifers that are penetrated during drilling. The strength of the casing and the depth at which it is set is determined through understanding of the geological environment and the pressures that are anticipated in the formations that are drilled through. The size, strength, coupling and material of the casing string must satisfy the identified operational conditions and industry standard design safety factors.

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The surface wellhead is also important for petroleum containment. This equipment provides control measures (or barriers) that can be closed to shut-in the well and isolate production.

Wells are pressure tested prior to commencing fracture stimulation, to confirm the integrity of the wellhead, casing and cement. Routine well integrity checks are also undertaken.

The fracture stimulation design process uses data collected during drilling and logging to design the treatment for each individual well. Data on reservoir parameters, lithology variations and stress contrast between layers is processed using stimulation software to develop a design which optimises fracture length, fracture conductivity and fracture height within the target reservoir formation. Information from well logs is used to detect water bearing zones which need to be considered in the fracture stimulation design.

Detailed considerations that influence the fracture modelling investigation and final design of the fracture stimulation include: ▪ depth, thickness, rock strength and lithology of the target zone and bounding layers ▪ thickness of the seals (aquitard layers) above and below the target reservoir formation ▪ minimum horizontal stress across all layers (target and bounding) ▪ stress field analysis to determine the maximum principal stress direction and the minimum principal stress direction ▪ bulk density, elastic properties, compressibility ▪ bedding planes, jointing and mineralisation ▪ porosity and permeability ▪ pore fluid saturations and properties (e.g. density, water salinity) ▪ well performance data, including flow rates, formation pressure and produced fluid properties.

The stress field within the reservoir determines fracture growth and orientation during fracture stimulation. Changes in the stresses (e.g. at formation boundaries) also play an important role in containing fractures.

Prior to a fracture stimulation treatment, a fracture model is constructed to investigate, predict and optimise the fracture geometry. A complete layer description is input into the simulator. Various pumping schedules are input into the model to evaluate the simulated fracture geometry and provide optimal geometry within the formation of interest. The treatment design models can predict the fracture geometry including fracture length and height based on the geomechanical rock properties. An example of a model output for a fracture stimulation treatment is shown in Figure 3-9.

Fracture growth into a water bearing zone is undesired on a fracture stimulation, as it would result in the flow being dominated by water rather than hydrocarbons. The fracture stimulation treatment is therefore designed very carefully and the operation itself is closely managed and monitored in real time to ensure the treatment is executed as designed and the fracture growth stays within the target units and does not extend into non-target formations.

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Figure 3-9: Example of model output for fracture stimulation treatment. (Source: Santos 2015) There are a number of methods that can be deployed during the drilling and formation evaluation process to acquire relevant data to inform stimulation design. This may include direct well bore measurements such as a diagnostic fracture injection test (DFIT), rock mechanic measurements from core data and logging tools such as image and dipole sonic. Tri-Star will assess the evaluation requirements for each stimulation program based on the target interval and relevant receptors. A typical workflow is provided in Figure 3-10.

Figure 3-10: Example of fracture stimulation workflow for exploration and appraisal

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During the fracture stimulation operation itself, parameters are monitored in real time (e.g. surface pressure, bottom-hole pressure, net pressure, injection rate and proppant concentration) to ensure that the treatment is proceeding as designed. The expected pressures generated by the modelling discussed above are compared with the measured pressures and the overall pressure response can provide useful information in evaluating the overall fracture growth and containment achieved.

During the operation, if an unexpected response is seen, one or more variables may be altered. If a significantly different response is observed which could indicate height growth beyond design parameters (e.g. a slight dip in net pressure or large decrease in treatment pressure) the stimulation is typically stopped. Figure 3-11 shows a typical example of real-time monitoring output.

Figure 3-11: Example of real-time monitoring of fracture stimulation (Source: Santos 2015). Post-treatment parameters are also monitored and are entered into the model following the treatment to achieve a history match and predict the actual fracture geometry. This calibration process is used to refine and improve subsequent designs.

Other monitoring techniques can also be useful in evaluating fracture geometry and orientation and providing data for calibrating fracture stimulation model predictions. These include micro seismic monitoring, surface tiltmeters, proppant tracers, chemical tracers, sonic anisotropy logging and temperature logging and are discussed below. Implementation of such techniques will be assessed on a case by case basis depending on the location of the well and its objectives.

Micro seismic monitoring involves placing sensitive listening devices (geophones) in an adjacent well during stimulation of the target well. During stimulation, small movements of rocks are detected at the monitoring well and the location of those movements is determined by triangulation. This information is used to understand the location and height of fracture growth. The economic feasibility of micro seismic monitoring is dependent on the presence of a suitable offset well, which typically needs to be within 200 to 300 m of the well that is being stimulated for smaller scale fracture stimulation treatments, and within 500 to 800 m for large scale treatments.

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Surface tiltmeters measure surface deformation during a fracture treatment. In an environment where complex fracture geometries are possible, surface tiltmeters can provide valuable information on fracture orientation.

Chemical or radioactive tracers can be used to provide information on fracture growth and / or which fractures are contributing to petroleum production. Non-hazardous chemical tracers may be added in very low concentration to each of the fracture stimulation stages to assist with understanding which zones are contributing to flow back after the treatments. Radioactive bead tracers can also be used during treatments to estimate fracture height, near wellbore proppant concentrations and associated propped widths post-treatment using spectral, gamma-ray logging tools. A variety of isotopes (scandium, iridium, and antimony) can be used to identify movement of different fluids. These radioactive isotopes have a short half-life and rapidly decay in the environment to safe levels.

Sonic anisotropy logging typically involves running pre and post fracture treatment dipole sonic logs and then comparing them to identify changes in sonic amplitude or stress anisotropy caused by the induced near well bore fracture.

Production logging tools can be used to identify flow contribution from individual zones using an array that records information such as fluid density, pressure, temperature and spinners to detect fluid movement. The temperature response may be used to identify where fluids are entering the wellbore or moving within the casing. Temperature logging can also be used to detect fluid movement behind casing. Depending upon the well, a temperature log may also be used to determine fracture height and identify perforations contributing to production.

A typical fracture stimulation treatment involves pumping of several discrete stages.

Pad stages: Small volumes of friction reduced water are injected. The initial pad volume, injected at high pressure, is used to split the rock and propagate the fracture.

Proppant stages: Once the fracture has initiated, proppant is introduced. In order to carry the proppant in suspension to the rock the fluid is viscosified with a gelling agent. Typically, the higher the injection rate of fluid the less gel is required to carry the proppant, and finer grained proppants require less gel to carry them. Gel breakers or surfactants are added during the stage to aid in later recovery of injected fluids from the fracture.

Flush / Displace: A final volume of water is injected to push the sand from the well bore into the rock to clean the well bore. In some cases, sand may not be completely displaced from the well bore to create a temporary “sand plug” to isolate the treated zone. This temporary sand plug is used to enable perforation and stimulation of the next interval higher in the well bore and removed from the casing at the conclusion of the stimulation treatments.

Plug / Perforate: Once the stimulation treatment is placed (and a temporary sand plug is not used for isolation as described above), a wireline unit is rigged-up to run a plug that will isolate the zone that was stimulated from the next interval to be stimulated (if multiple zones are to be stimulated). The wireline will also perforate the casing ready for the next stimulation treatment.

The process described above outlines the activities associated with stimulating a single zone in the well. Where multiple targets are identified within a vertical or horizontal wellbore, this process is repeated several times within a single wellbore.

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Water is the main component of fracture stimulation treatments and forms the vast majority of the fluid injected during fracturing operations, typically around 97%. The proppant is the next largest constituent. Proppant is a granular material, typically sand or small ceramic beads which is mixed in with the fracturing fluids to prop open the fractures and allow hydrocarbons to flow to the well.

In addition to water and proppant, a range of other additives (approximately 0.5%) are necessary to ensure successful fracture stimulation. Chemical additives include acid, buffers, biocides, surfactants, iron control agents, corrosion and scale inhibitors, crosslinkers, friction reducers, gelling agents and gel breakers. Several of these ingredients are essential to maintaining well integrity.

To ensure a safe and successful operation, other components are added to fracturing fluid, including biocides, buffers, friction reducers, guar gelling agents, crosslinkers and breakers (see Table 3.4).

Table 3.4: Additives typically used in fracture stimulation fluids

Additive Purpose

Acid/Solvent Removes scale and cleans wellbore prior to fracturing treatment Buffer/Acid Additive Used to adjust the pH of the based fluid for protection of wellbore components and treatment equipment from corrosive action of acid Biocide Prevents or limits growth of bacteria that can cause formation of hydrogen sulphide and can physically plug flow of oil and gas into the well. Limits gel destruction due to bacterial action Breaker/Deviscosifier Reduces fluid viscosity after the treatment to aid quick clean up in flowback Chemical tracer Compound used to chemically mark individual stage fracturing fluids in a multi-zone completed well Clay control Prevents clays from swelling which can stop fluid flow post treatment Cross linker Increases fluid viscosity to help activate and carry proppant Foamer Used to transport and place proppant into fractures Friction Reducer Allows fracture fluid to move down the wellbore with the least amount of resistance Gelling agent Adds viscosity to the fluid to help carry proppant Iron Chelating Agent Helps prevent the precipitation of hydrated iron oxides from spent acid following an acidising treatment Neutralising agent Counteracts the corrosive effect of acids or acidic treatment fluids on equipment Non-emulsifier Prevents emulsions forming and keeps oil separate from the fracturing / formation fluids during flowback pH Buffer Used to adjust the pH of the fluid and promotes hydration of gel Proppant Typically comprised of sand or small ceramic beads which prop open the fracture allowing oil, gas and water to flow to the wellbore Scale Inhibitor Prevents build-up of certain materials (i.e. scale) on sides of well casing and surface equipment Surfactant Assists in recovery of fluid from the well Surfactant / Penetrating Agent Allows for increased matrix penetration of the acid resulting in lower breakdown pressures

Fracturing fluids are a carefully formulated product and each task performed during the operation will use fluid with additives specifically designed for the task. For example, the fluid designed to propagate

Tristar Drilling EIR Rev0 29 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions the fractures is initially injected without proppant, and then proppant is added to the fluid to enter the fractures and hold them open. Gelling agents, or viscosifiers, are used during these phases to increase the viscosity of the fluid and help carry the proppant. Gel breakers and surfactants are added to aid in recovery of the injected fluids from the formation.

The design of the fluids is customised for each well, taking into account source water chemistry, depth, temperatures, pressures, reservoir geology and chemistry, scale build-up, bacteria growth, proppant transport, iron content and fluid stability and breakdown requirements. During the fracture stimulation treatment, regular quality control and monitoring of source water quality is undertaken to adjust the formulation as required.

Appendix 1 provides further information on fracturing additives and their chemical constituents, based on typical formulations. Fracture stimulation service providers may have their own proprietary stimulation compounds, which are generally from the same group of chemicals but with different amounts of, or slightly different, active ingredients. It is expected that the additives used by different providers in the future are likely to be similar to those outlined in this document. Detail of additives proposed for use in fracture stimulation operations is provided to DEM as part of the activity notification process (see Section 2.1.2).

Most of the chemicals used in fracture fluids are found within products that are commonly used in the home or in industry. While many of the additives used in the fracturing process are hazardous when in their concentrated product form, they are diluted by the water and are present in fracturing fluids in relatively low concentrations. However, even in low concentrations some of these additives need to be handled with care to avoid any potential for impacts on human health or the environment.

Fracturing fluid additives containing the volatile aromatic compounds benzene, toluene, ethylbenzene and xylene (collectively referred to as BTEX), have been identified as a potential concern in some areas where fracture stimulation operations are carried out much closer to water supply aquifers. Although the level of risk posed by additives containing BTEX is relatively low (e.g. the target petroleum reservoirs can naturally contain BTEX), it is not proposed to use additives where BTEX is present in significant quantities. Some additives in the acid blend (e.g. hydrochloric acid, corrosion inhibitor and acid penetrating agent) can contain trace levels of BTEX, however the dilution of the acid blend by subsequent stages of the fracture stimulation would result in very low levels, which would be below drinking water guidelines. Suppliers and fracturing contractors have been working to ensure that levels of BTEX in fracturing fluids are reduced as far as practicable and are not at significant levels.

Tri-Star aims to keep utilisation of chemicals to the lowest level possible and will safely manage the use of chemicals and fuels and contain recovered stimulation fluids to minimise the environmental footprint of stimulation activities. Tri-Star will investigate methods to further reduce chemical utilisation and incorporate findings during the monitoring of flow back fluids as part of Tri-Star’s commitment to continuous improvement.

Following completion of fracture stimulation operations, the well is flowed back to the surface to recover the injected fluids. The initial flow will be predominantly recovered stimulation fluid and will be directed to a tank. Water that is flowed back to the surface is metered and sampled on a regular basis to evaluate the composition of the recovered fluid.

After the initial well clean-up phase, the produced fluids are typically diverted to a separator to separate the various phases and capture any liquid hydrocarbons into tanks. Gas from wells undergoing production testing that are not close to gas gathering networks will be flared after separation and metering.

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Published data on recovery of fracture fluid during flowback, which relates almost exclusively to shale gas wells, shows that the volume recovered can range from approximately 5 – 50%. Flowback volume depends on reservoir properties, fracture stimulation design and fracture fluid used. Smaller scale fracture stimulation can have a higher percentage of flowback as opposed to the large slickwater fracture stimulations utilised for unconventional shale targets.

Chemicals returning from a well after a fracturing treatment are usually a fraction (e.g. 20% or less for chemicals and about 40% for polymers) of what was pumped down the well (Friedmann 1986, Howard et al. 2009, King 2012) and fluid disposal plans are tailored accordingly. Polymers decompose quickly at reservoir temperature; biocides degrade as they are spent on organic demand and surfactants are adsorbed on rock surfaces (King 2012). Consequently, many of the compounds that are identified as potentially hazardous on their Safety Data Sheets, such as buffers or biocides, are effectively neutralised or present at significantly reduced concentrations in the flowback fluid. The flowback fluid may also contain salts that were dissolved from the geological strata underground. Monitoring of ion concentrations in the flowback fluids is undertaken to understand the extent to which this is occurring.

The fracture stimulation process requires equipment for pumping, proppant loading, blending, pipework and valves, tanks, chemical additives and monitoring. Monitoring equipment is used to track the volume of fluids, the concentration of proppant being pumped, and most importantly the injection pressure. As with the well design process, stimulation equipment is designed to meet the pressures expected during the treatment process with secondary protection to shut down equipment before design pressures are reached.

The fracture stimulation equipment for activities outlined in this EIR will require approximately 10 - 20 truckloads. For a full 15 stage fracture stimulation, for example, an additional 40 trailers of proppant and 4 trailers of additives may be required. In addition, all activities will require a wireline perforation truck to conduct perforations prior to each fracture, and a coiled tubing unit consisting of a reel of tubing mounted on a truck and the associated wellhead equipment to run the tubing into the wellbore.

Each stimulation treatment will require up to 16,000L of fuel (diesel) to operate equipment and machinery on the surface, which will be stored on site. Additives required for the fracture stimulation operation will also be stored on site. All chemicals are stored and handled in accordance with relevant guidelines and legislation.

Personnel will typically be accommodated at established camps (see section 3.2.1).

Following the completion of fracture stimulation activities, all infrastructure, equipment and waste materials not required for production operations are removed off site and are either re-used or disposed at a licensed facility.

The amount of water used in fracture stimulation operations varies depending on the target formation and well objectives. Operational experience in the Cooper Basin demonstrates consumption can range from approximately 0.4 - 1.6 megalitres (ML) per zone. Within the Simpson and Pedirka Regions, it is anticipated that one to five zones may be fracture stimulated in a vertical well. In a horizontal well, with a length of 2,500 m (noting that length may range from 1,000 – 3,000 m), stimulation treatments are likely to be placed every 100 m, requiring 25 treatments in the well. Consequently, fracture stimulation of a vertical well would require in the order of 0.4 – 8 ML of water, and a horizontal well may require up to 40 ML.

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Where possible, water for fracture stimulation uses recycled water sources. Alternatively, water may be obtained from shallow water wells which are generally drilled within the lease area of each petroleum well. Water well productivity and water quality uncertainties may also make it necessary for Tri-Star to seek landholder permission to obtain water from existing bores. Appropriate authorisations are obtained for water well drilling and extraction of groundwater (and Tri-Star will liaise with DEW where required). Tri-Star will consult with relevant stakeholders regarding any proposed water extraction, and use, to ensure use does not impact adversely on existing users of groundwater.

Water Management

Water for use in fracture stimulation is stored on site in tanks or lined ponds. As discussed above, flowback from the well after fracture stimulation is completed is directed to a tank or a lined pond. All flowback water is handled and stored in accordance with relevant legislation and guidelines.

All ponds that are to receive water for stimulation and recovered flowback fluids will be lined and fenced. The construction will utilise both excavation and bunding to raise the sides of the ponds above ground level to prevent surface water runoff into the ponds. The temporary water holding ponds will typically be constructed and start filling approximately one to two months in advance of the planned stimulation date.

Tri-Star will construct a number of ponds (approximately 50 m by 30 m and 2 – 3 m deep) at each well site for water storage, with regard to EPA Guideline 509/19 Wastewater Lagoon Construction. Any temporary pond that has the potential to be used for stimulation fluid flowback will be constructed with the following considerations:

▪ all ponds are to be lined with a suitable UV stabilised polyethylene material. All liners must be constructed to the manufactures recommend installation method and be welded and checked for joint adherence and leak tested prior to being placed in operation, and ▪ regular water balance calculations and visual inspections are made to ensure any loss of significant volumes from recovered fluid ponds is detected.

If necessary, for operational requirements or potential issues with pond integrity, fluids may be transferred between ponds, or removed from one location and transferred to another well site for further evaporation. Ponds will be progressively rehabilitated as operations progress. Where necessary, some ponds will be retained for longer term use, as flow back may be required for approximately three to six months to understand longer-term well performance.

Water will be required for both domestic and industrial purposes for drilling and fracture stimulation operations. The quality of water required is dependent upon the intended use.

Domestic water supply: Potable water will be required to supply kitchen and ablutions facilities on the drill site and at the camp. The source of potable water will depend on the well location, but it may be sourced from the water supply of a nearby town or settlement and transported to site in a bulk water tanker. Alternatively, a portable reverse osmosis (RO) water treatment plant may be utilised.

Drilling water supply: The amount of water required for drilling operations depends principally upon the depth of the well that is being drilled and stimulated. Water use for drilling of a 3000 m deep petroleum exploration well for example typically range from 0.8 to 1 ML depending on casing diameter.

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Water will either be sourced from a water bore drilled on or near the well lease or transported by road tankers and stored in a turkey’s nest or above ground tanks.

Fracture stimulation water supply: Refer to Section 3.3.8 for information on water usage during fracture stimulation operations.

Water for drilling and fracture stimulation operations may be sourced from existing artesian and sub- artesian bores. The drilling of new water bores and extraction of groundwater in the region (which is located in the Far North Prescribed Wells Area) is regulated under the Natural Resources Management Act 2004 (NRM Act). Tri-Star will liaise with DEW to ensure appropriate authorisations are in place for drilling and extraction of groundwater. Relevant stakeholders will be consulted regarding water well locations and water use, and proposed water supply wells will be reviewed to ensure that their use does not impact adversely on existing users of groundwater. As discussed in Section 4.6.1, there are relatively few water supply bores in the area, and shallow aquifers are often unsuitable for stock or domestic use. Water use for fracture stimulation will be in accordance with the Far North Prescribed Wells Area Water Allocation Plan (SAAL NRM, 2009), and applicable guidelines such as APPEA and API guidelines (APPEA, 2011; API, 2010). Tri-Star will undertake detailed investigation and consultation to ensure that significant impacts to water resources and other users are avoided.

A water licence issued by DEW under the NRM Act is generally required to extract groundwater from existing water bores, however groundwater extracted for use during exploratory drilling operations is exempt from this requirement5.

Water bores to supply a drill site will be chosen on the basis of minimising transport distances and impacts on other users of the bores. However, the quality / character of the water is also considered. Water well productivity and water quality uncertainties may also make it necessary for Tri-Star to seek a relevant stakeholders’ permission to obtain water from existing bores.

A range of wastes are generated during drilling and fracture stimulation operations. Waste management practices will be guided by the principles of the waste hierarchy (i.e. avoid, reduce, reuse, recycle, recover, treat, dispose). The following sections and Table 3.5 provide a summary of the typical waste streams associated with the operations and the requirements and strategies employed to manage them.

Domestic waste

Domestic wastes generated at campsites require storage prior to transportation for recycling or disposal to a licensed waste management facility. The presence of waste can attract wildlife (e.g. crows, black kites and dingoes) and litter may also be scattered by the wind. However, domestic wastes (e.g. food waste, paper, plastics, cans and glass) will be stored on site in secure bins or skips. Recyclable materials will be segregated for transport to a recycling facility where practicable. Other materials will be transported to a licensed waste disposal facility.

5 Pursuant to s.11 of the Water Resources Act 1997 and s.128 of the Natural Resources Management Act 2004 (see clause 54(3) of Schedule 4) a water licence is not required to extract groundwater from a prescribed wells area for the purpose of using it in the course of any operation or activity reasonably necessary for, or incidental to the drilling, construction or testing of a hydrocarbon well. However, the drilling of a new water bore still requires a well construction permit issued by the DEW.

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Solid waste

Solid wastes created during drilling and fracture stimulation operations are collected in designated skips or bins for recycling or disposal to an appropriately licensed facility. Other wastes associated with operations, including drilling fluids, muds and drill cuttings are generally managed in the excavated drilling sump.

The contents of the drill sump is left to dry before being covered with at least one metre of fill cover. In some circumstances (e.g. where there is a risk of flooding) the sump contents may be pumped out and removed off-site for disposal. Topsoil is respread over restored surfaces at final restoration to encourage natural rehabilitation processes.

Sewage Wastewater / Grey Water Management

Sewage wastes at campsites and offices are required to be disposed of via on-site systems that are approved and managed under the South Australian Public Health (Wastewater) Regulations 2013 and in compliance with the South Australian Health On-site Wastewater Systems Code, or to the satisfaction of the Department of Health. Wastewater effluent is typically disposed to evaporation ponds or irrigated to land in a location where it will not enter surface waters, consistent with Clause 17 of the Environment Protection (Water Quality) Policy 2015.

Contaminated Soil Management

Any escape of petroleum, processed substance, chemical or fuel to soil is either immediately contained and removed or assessed in accordance with National Environment Protection (Assessment of Site Contamination) Measure (NEPM) guidelines and remediated in a timely manner. Minor spills in lined bunded areas are treated in accordance with EPA / NEPM guidelines. The main method of treatment and disposal of hydrocarbon contaminated soil resulting from spills outside bunded areas is removal for temporary storage in a designated bunded area. The contaminated soil is may be treated on site in accordance with EPA guidelines or transported by a licensed regulated waste contractor to a suitable EPA licensed facility for treatment or disposal.

Fracture Stimulation Flowback Solids

Fracture stimulation flowback solids (e.g. proppant) remaining in ponds may be disposed on site during pond rehabilitation if testing demonstrates solids meet appropriate criteria (e.g. waste fill guidelines) or are disposed of at an appropriately licensed facility (e.g. licensed waste disposal facility).

Table 3.5: Typical drilling, completions and fracture stimulation wastes and disposal methods (adapted from Santos, 2015)

Waste Disposal Method

Domestic Waste Sewage and grey water, and Treated onsite in septic tank or approved aerobic system in accordance with SA Public storm water runoff (camp) Health (Wastewater) Regulations 2013. Sludge and residue collected by a licensed contractor as required and disposed of at an appropriately licensed facility. Storm water runoff (camp) to vegetation. General wastes – food waste, Securely stored in covered bins (to prevent wildlife access) for regular removal to general food wrappers, plastic bags, (approved) landfill. Rubbish contained and controlled to minimise odours and maintain packaging hygiene. Comingled recyclable Segregated and placed in bins or skips for recycling. material – paper and

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Waste Disposal Method cardboard, timber pallets, plastics and aluminium cans Grease trap wastes Collected for transport off-site by a licensed regulated waste contractor to a licensed regulated waste facility for treatment, recycling or disposal. Industrial Waste Contaminated soil Soils contaminated with chemicals are to be managed as specified in the Safety Data Sheet (SDS) for the spilt chemical. Soils contaminated with hydrocarbons treated on site where appropriate in accordance with EPA guidelines or collected and stored in a designated soil containment area located at the drill pad. If not treated on site, collected for transport off-site by a licensed regulated waste contractor to a licensed regulated waste facility for disposal. Ultimate reuse or disposal of treated soil consistent with the principles of the National Environment Protection Measure for contaminated sites and relevant EPA guidelines. Drilling muds and cuttings Disposed in drilling sump and covered with at least 1 m of fill cover. Completions / fracture Collected in lined ponds or tanks for disposal via evaporation or transported to an stimulation fluids appropriate licensed facility. Completions / fracture Disposal at an appropriately licensed facility or disposal on site during pond rehabilitation stimulation flowback solids if testing demonstrates that appropriate criteria (e.g. waste fill guidelines) are met. Metals – empty steel drums, Segregate (stored separately from other waste) metals from other wastes and store for bulk scrap steel, pipe, bolts, recycling. wire / cables, mini rings Empty drums – plastic fuel, Drums to be transported off-site by waste contractor for reuse, recycling or disposal. lubricant and chemical containers Plastic pond liner (e.g. HDPE) Transported to a licensed recycling facility (where possible) or sent for disposal at an appropriately licensed facility. Batteries Collected for transport off-site by a licensed regulated waste contractor to a licensed regulated waste facility for treatment, recycling or disposal. Chemical wastes Stored in accordance with Australian Standards and EPA guidelines in bunded areas for transport off-site by a licensed regulated waste contractor to a licensed regulated waste facility for recycling or disposal. Timber pallets (skids) Recycled where possible. Vehicle tyres Collected for transport off-site by a licensed regulated waste contractor to a licensed regulated waste facility for treatment, recycling or disposal. Workshop waste – filters, Recycle where possible and remainder for disposal to EPA licensed landfill. rags, grease and lubricants Oil and lubricants to be collected and stored in bunded areas awaiting transport off-site by a licensed regulated waste contractor to a licensed regulated waste facility for treatment, recycling or disposal.

A variety of fuels and chemicals are required for drilling and fracture stimulation operations. These include fuel, lubes, oils, solvents, and drilling mud and fracture stimulation fluid additives (see Section 3.3.5 for a list of stimulation fluid additives). The volumes and types of chemicals used will be dependent upon the type of operation. Refer to Santos (2015) for a detailed list of chemicals that may be used during drilling and completion operations.

All fuel, oil and chemical storage, handling and secondary containment will be undertaken in accordance with appropriate standards and guidelines e.g. Australian Standard AS 1940, EPA guideline

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080/16 Bunding and Spill Management, the Australian Dangerous Goods Code (ADG) and product Safety Data Sheets (SDSs). Typically fuel and chemicals are stored in approved containers in appropriately lined bunded areas or on bunded pallets, and well leases are constructed to provide a suitable working platform and containment for minor spills.

Diesel storage volumes will vary depending upon the operation. Diesel storage volumes are usually greatest for drilling operations, but fracture stimulation operations also require considerable volumes of diesel (refer to Section 3.3.5).

The restoration of well sites and associated infrastructure is normally undertaken in stages following the completion of drilling operations.

Irrespective of the outcome of the drilling operation, initial well lease clean-up involves: ▪ fence the drilling mud sump immediately following the completion of drilling to prevent or discourage animal access ▪ backfilling treated wastewater pits (if any) at both the well site and campsite; and ▪ pumping any additional water from the turkey’s nest into the mud sump and removing the turkey’s nest liner.

The drilling mud sump will remain fenced until the contents have dried sufficiently to allow the sump to be backfilled without displacing fluids to the natural soil surface. The time required for the sump contents to dry is dependent upon the size of the sump and seasonal weather conditions, but for a petroleum well usually takes between 6 and 12 months. In some circumstances (e.g. where there is a risk of flooding) the sump contents may be pumped out and removed off-site for disposal.

When the drilling sump has dried, full or partial restoration of the well site will be undertaken depending upon the outcome of the drilling operations. Partial restoration will be undertaken at well sites that have been successful in discovering commercial quantities of hydrocarbons as subsequent operations, such as workover and completion activities, require less space than that which was required for drilling operations. Partial restoration typically involves:

▪ backfilling the drilling sump to achieve at least 1m cover over mud contents (following drilling operations sufficient freeboard is left to allow for this without creating a raised surface upon restoration) ▪ partial ripping (where appropriate) and respreading of topsoil and cleared vegetation on excess lease areas to promote natural revegetation and stabilisation of the lease edges ▪ backfilling the turkey’s nest ▪ backfilling any additional pits or voids (flare pits may be left open for subsequent operations) ▪ removal of pond liners (where no longer required) ▪ ripping (where appropriate) excess loop roads used for vehicle turnarounds; and ▪ remove clay capping and windrows, and rip campsite, laydown areas, and associated access tracks (unless required for future operations).

Note: in some circumstances (e.g. high clay content soils on floodplains or interdune swales), ripping of the site surface may be inappropriate and cause unnecessary soil disturbance. Natural rehabilitation processes may progress more efficiently if the site is instead lightly shaped and soil blended to match the surrounding terrain. Ripping will not be undertaken on unsuitable soils such as gibber pavement.

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Complete well site, access track, borrow pit and associated infrastructure restoration will be undertaken if the well is plugged and abandoned and there is no requirement to access any services at the site e.g. an access track may be retained to access a water bore at the site.

Final surface restoration of well sites and associated infrastructure will involve: ▪ backfilling all pits including the drilling mud sump, turkey’s nest and flare pit ▪ removing any windrows to ensure natural water flows are not impeded ▪ removing all capping material from prepared surfaces (e.g. well leases, access tracks) where appropriate and return material to borrow pits where practicable. Some capped surfaces (e.g. access tracks) may not be rehabilitated if requested by the relevant stakeholder; and ▪ ripping (on the contour) and reshaping of all disturbed sites where appropriate (i.e. well sites, campsites, laydown areas, access tracks) to represent as near as practicable the original landform and respread stockpiled topsoil and cleared vegetation (where available) to promote natural rehabilitation processes.

Final restoration of borrow pits will be undertaken in accordance with industry-wide standards for borrow pit management developed by DEM (2014) in consultation with relevant stakeholders.

Final restoration of borrow pits typically involves: ▪ battering slopes to prevent collapse ▪ constructing erosion control measures where appropriate ▪ returning overburden to the pit ▪ the floor and sides of the pit; and ▪ spreading stockpiled topsoil and vegetation (where available).

Note: in some circumstances (e.g. high clay content soils on floodplains or interdune swales), ripping of the site surface may be inappropriate and cause unnecessary soil disturbance. Natural rehabilitation processes may progress more efficiently if the site is instead lightly shaped and soil blended to match the surrounding terrain. Ripping will not be undertaken on unsuitable soils such as gibber pavement.

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4 Existing Environment

The licence area covers approximately 33,150 km2 of far northern South Australia. This region can generally be described as arid with a uniform climate. It contains a wide diversity of land systems that are defined by geological, geomorphological and hydrological influences. This section provides an overview of the environment of the licence area.

The climate in the region is arid, with warm to extremely hot summers and mild to warm winters. Rainfall is low and highly erratic with some years receiving no rainfall at all. The annual median rainfall at nearby Oodnadatta (approximately 100 km south-west of PEL 160) is 150 mm (BoM, 2018). During summer, the climate is weakly influenced by the north-west monsoon, where moist tropical air can bring thunderstorms and intense, but relatively short-lived rainfall. For the rest of the year, the main source of rain is from north-west cloud bands that originate over the Indian Ocean, though these rarely bring prolonged rains to the area. Evaporation rates are high with annual evaporation in excess of 3500 mm (BoM, 2018; Maree SCB, 2004). A summary of climate records for Oodnadatta Airport is provided in Table 4.1 (BoM, 2018). The licence area is located in the north east pastoral fire ban district.

Table 4.1: Climate data for Oodnadatta Airport

J F M A M J J A S O N D Annual Mean Daily Max (oC) 37.9 36.7 33.8 28.6 23.3 19.9 19.7 22.2 26.7 30.5 33.8 36.4 29.1 Mean Daily Min (oC) 23.1 22.4 19.3 14.4 9.9 6.5 5.8 7.5 11.5 15.2 18.7 21.3 14.6 Mean Rainfall (mm) 23.9 30.4 14.0 10.9 12.5 11.9 9.4 7.9 10.5 13.1 12.7 17.4 177.1 Median Rainfall (mm) 8.3 9.0 2.8 1.4 4.2 3.6 1.6 1.4 3.9 4.8 6.8 11.2 150.2 (Source: BoM, 2018 – Oodnadatta Airport Station 017043. Location: 135.45°E, 27.55°S. Data from 1939-2018)

The licence area is located within the Simpson Strzelecki Dunefields, Channel Country, and Stony Plains biogeographic regions6. Several named land systems7 have been described across the licence area as part of broader land system mapping in the pastoral areas of South Australia (Marree SCB, 2004). The location of each land system with respect to the licence area is displayed in Figure 4-1.

The Simpson, Tirrari and Jeljendi dunefields are the predominate land systems in the licence area. These land systems are characterised by extensive linear dunefields and interdune flats (see Figure 4-1) (DENR, 2011). PEL 290 is the most diverse landscape of the licence area. PEL 290 is located over a unique interface of dunefield systems (Jeljendi and Simpson land systems), wetlands and drainage lines of the Diamantina River Wetland System and Goyder Lagoon (Diamantina and Mulligan land systems), and stony / gibber plains (Koonchera and Sturts land systems) to the south-east (Marree SCB, 2004;

6 Biogeographic regions (bioregions) are broad landscape units based on major geomorphic features and are defined by the Interim Biogeographic Regionalisation for Australia (IBRA) Version 7.0. 7 Land systems subdivide the IBRA bioregions and are areas throughout which there is a recurring pattern of geology, topography, soils and vegetation (DEH 2005).

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DEW, 2010). The following section provides a summary description of land systems and typical landforms present in the licence area.

Simpson

The Simpson land system occurs in the north-west section of the licence area and is characterised by extensive linear dunefields and sandy interdune flats. Dominant vegetation is Sandhill wattle (Acacia ligulata) shrublands over Sandhill canegrass (Zygochloa paradoxa) tall hummock grassland. Dunes are soft red sand with mobile crests and interdunes are firmer red sands to reddish sandy clays (Marree SCB, 2004; DEW, 2010).

Tirari

The Tirrari land system occurs in the central section of the licence area and is characterised by linear north trending sand dunes of between 10m to 20m high with spacing of 150m to 1 km. Dominant vegetation is Sandhill canegrass open hummock grassland with sparse Sandhill wattle and Needlewood (Hakea leucoptera). Dunes are pale red to brown sands with clay at lower profiles (Marree SCB, 2004; DEW, 2010).

Jeljendi

The Jeljendi land system dominates the north-eastern section of the licence area and is characterised by long, widely spaced north-north-westerly trending dunes, which overlay the ancient Lake Eyre / Kati Thanda floodplain. Dominant vegetation is Sandhill canegrass hummock grassland and Lobed spinifex (Triodia basedowii). Dunes are red siliceous sands, deep, with mobile crests (Marree SCB, 2004; DEW, 2010).

Diamantina

The Diamantina land system occurs in the central area of PEL 290 and is characterised by the floodplains and channels of the Diamantina River and channelled swampland of Goyder's Lagoon. Dominant vegetation is low open Coolibah (Eucalyptus coolabah) woodland with mixed Lignum (Duma florulenta) and Queensland bluebush (Chenopodium auricomum) low open shrubland. Trees reduce away from channels, with the shrubs remaining relatively dense on grey clays. Floodplains have grey self-mulching cracking clay soils with gilgai development, but the channels and terraces (levees) within Goyder Lagoon are red firm siliceous sands (Marree SCB, 2004; DEW, 2010).

Mulligan

The Mulligan land system occurs in the north-central area of PEL 290 and is characterised by the floodplains and channels of Eyre Creek (which receives flows from the Mulligan River to the north). Dominant vegetation is low Coolibah and mixed Wattle (Acacia stenophylla; A. salicina) low woodland over Lignum open shrubland. Soils on flood-outs and floodplains are grey self-mulching cracking clays, with alluvium on channel floors and loamy soils on banks (Marree SCB, 2004; DEW, 2010).

Koonchera

The Koonchera land system occurs in the south-east corner of PEL 290 and is characterised by gently undulating gibber plains, crossed by major drainage with run-on depressions and swamps, and limited occurrences of large isolated sand dunes. Dominant vegetation is Barley Mitchell grass (Astrebla pectinata) and Katoora grass (Sporobolus actinocladus) mixed low open tussock grassland. Soils are duplex soils, a shallow friable loam over red clays, with a dense cover of gibber, and dunes are generally soft red sands (Marree SCB, 2004; DEW, 2010).

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Sturts

A minor area of the Sturts land system is present in the south-east corner of PEL 290. The land system is characterised by gibber downs with gilgais, internally draining lakes, claypans and swamps, and scattered red dunes. Dominant vegetation is Neverfail (eragrostis setifolia) and Mitchell grass and Cottonbush (Maireana apylla) on gibber plains, scattered Lignum and Swamp canegrass (Eragrostis australasica) in swamps; sand plains with Bladder saltbush (Atriplex vesicaria) and Mitchell grass; mesas with Dead finish (Acacia tetragonopylla); Dunes with Sandhill wattle over Lobed spinifex and Sandhill canegrass. Soils have gilgai development; gilgais are red cracking self-mulching clays with little or no stone, while surrounds are duplex soils, a shallow friable loam over red clays, with a dense cover of gibber and higher salinity than the gilgais (Marree SCB, 2004; DEW, 2010).

Macumba

A very minor area of the Macumba land system occurs in the south-western corner of PEL 288. The land system is characterised by wide braided watercourses with grey clay soils, floodout plains with sandy-clay soils, and fresh-water swamps. Dominant vegetation is Coolibah bordering channels and floodplains with scattered Gidgee (Acacia cambagei), Old-man saltbush (Atriplex nummularia) and Queensland bluebush, Dead finish, Cotton bush over grasses (Marree SCB, 2004; DEW, 2010).

Warburton

A minor area of the Warburton landsystem occurs in the south-east corner of PEL 289. The landsystem is characterised by channels, floodplains and sand dunes associated with the Warburton Creek. Dominant vegetation is Coolibah, Broughton willow (Acacia salicina), River cooba (Acacia stenophylla) and Lignum bordering channels, Lignum and Queensland bluebush in swamps, and sand dunes with Sandhill canegrass, Native pear (Cynanchum floribundum) and Sandhill wattle (Marree SCB, 2004; DEW, 2010).

Five general landforms occur in the licence area. Table 4.2 describes these landforms and indicates the land systems in which they occur. The sensitivity of each landform to disturbance depends upon its basic characteristics of geology, topography, soils, hydrology, flora and fauna.

Tristar Drilling EIR Rev0 40 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Table 4.2: Typical landforms and characteristics in the licence area

Landform Land System Summary Description

Dunefields and Jeljendi, Koonchera, Dunes vary greatly in their size, direction and spacing across the licence area. Sand Plains Macumba, Mulligan, Interdune swales are generally flat or gently undulating, with clayey soils and Simpson, Sturts, occasional claypans and salt lakes. Tirari, Warburton Dunes associated with the Simpson land system are generally extensive and active longitudinal dunes, running in a generally north-south direction and ranging in height with deep red sands. Dunes associated with the Tirari land system are generally large, 10-15m high increasing to 20m in the northern part of the land system. Dunes are pale reddish or brownish quartz sands with carbonate nodules at depth, and some clay in their lower profiles, resulting in lower clayey flanks, which appear to be "hard" sand. Dunes associated with the Jeljendi land system are long and high and tend to travel in a north-west direction. The dunes are deep with mobile crests comprised of red siliceous sands. The ancient floodplain of Eyre Creek is at least partially exposed between most dunes. Soils vary, but they are generally red-yellow-siliceous sands on dunes and red massive earths or grey self-mulching clays in interdune swales. Gibber plains Koonchera, Sturts Gently undulating stony plains, crossed by major drainage with run-on depressions and swamps, and limited occurrences of widely spaced large sand dunes. Highly polished stones or gibbers are usually embedded in a clayey crust, thereby protecting the underlying soil from erosion. Soils have some gilgai development; gilgais are red cracking self-mulching clays with little or no stone, while surrounds are duplex soils, a shallow friable loam over red clays, with a dense cover of gibber and higher salinity than the gilgais. Floodplains Diamantina, Jeljendi, Extensive flood-out areas adjacent to the Diamantina and Mulligan Rivers Macumba, Mulligan, and Warburton Creek. Floodplains are periodically inundated when creeks Tirari, Warburton and rivers overflow their banks. Characterised by grey sediments which are deposited on plains by floodwaters. In places, dunes are either co-dominant or occasionally present. Floodplains have grey self-mulching cracking clay soils with gilgai development and pale sandy clays. Drainage Diamantina, The main waterways in the vicinity of the PELs include Eyre Creek, Goyder channels and Macumba, Mulligan, Lagoon, Warburton Creek and Kallakoopah Creek, which drain into Lake Eyre wetlands Warburton North / Kati Thanda. The Diamantina River flows into Goyder Lagoon to the east of PEL 290. The braided Diamantina River and Eyre Creek bring flood waters from higher rainfall areas in Queensland and channel water out over the plains. Low gradients in the region mean the movement of the water is very slow as the flood waters move south. Goyder Lagoon is a wide, low-relief area of lignum swamps and vertic soil plains. Some waterholes may contain water for extended periods, but channels, swamps, and lakes are frequently dry. The channels are generally made up of red firm siliceous sands. Floodplains have grey self-mulching cracking clay soils with gilgai development. Cracks and voids in the clay allow penetration of water deep into the clays when they are dry. Claypans and Diamantina, Jeljendi, Claypans and salt lakes located between sand dunes. Claypans are non- Salt Lakes Macumba, Mulligan, cracking clays which are vary in size are not self-mulching and form a seal Simpson, Tirari, when wet. The water storage capacity of claypans soils is subsequently low Warburton and there is little to no plant growth. Terminal salt lakes or pans of varying sizes where evaporation has resulted in concentration of soluble salts as a surface crust. Are periodically inundated but are usually dry. Salt lakes soils are salty overlying grey self-mulching cracking clays. (Sources: DEW, 2010; Marree SCB, 2004, Marla-Oodnadatta SCB, 2002).

Tristar Drilling EIR Rev0 41 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Figure 4-1: Land systems mapped in the licence area (Source: DEW, 2010)

Tristar Drilling EIR Rev0 42 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Vegetation in the licence area is almost entirely native. Approximately 500 plant species from 50 families have been recorded in the Simson Desert region (DEW, 2018). The majority of species recorded are ephemeral species, or short-lived perennials responding to the boom and bust nature of the region. Such species are often underrepresented in survey data as they are generally absent during dry periods.

Vegetation in the licence area is largely dominated by Sandhill wattle (Acacia ligulata) shrublands over Sandhill canegrass (Zygochloa paradoxa) tall hummock grassland on sand dunes. This vegetation community covers approximately 70% of the licence area. Minor areas of Coolibah (Eucalyptus coolabah) open woodland over Queensland bluebush (Chenopodium auricomum) and Lignum (Duma florulenta) shrubland dominate wetter areas e.g. swamps, floodplains and adjacent to stream channels. Low open shrublands of Grey samphire (Tecticornia halocnemoides) and Nitrebush (Nitraria billardierei) dominate interdune swales and saline areas e.g. edges of salt lakes. Sea health (Frankenia sp.) low shrublands occur near other depressions e.g. near lakes and claypans.

Vegetation associations (based on vegetation mapping (DEW, 2010)) and their percentage cover of the licence area are detailed in Table 4.3.

Table 4.3: Mapped vegetation associations in the licence area

% Cover of Landform / Environment Veg ID Vegetation Association Description Licence Description Area

CG0018 Chenopod shrubland. Emergent Coolibah Eucalyptus coolabah Closed depressions, Swamps, 8.07 % low open woodland over Golden Goosefoot Chenopodium Floodplains; Adj. stream auricomum, Lignum Duma florulenta mid open shrubland channel on periphery of over Tangled Bindyi Sclerolaena intricata, Rough Raspwort floodplains; Clay; Grey Haloragis aspera, and chenopod Atriplex crassipes var. cracking clays; Subject to crassipes low open shrubland. periodic water logging CG0022 Eucalyptus forest woodland. Coolibah Eucalyptus coolabah, Stream Channel (banks), 1.66 % River Cooba Acacia stenophylla, +/- Willow Wattle Acacia Levees and Floodplains; salicina, +/-River Red Gum Eucalyptus camaldulensis var. Sandy loam; Over cracking obtusa low woodland over Lignum Duma florulenta tall open clays; Watercourses/ shrubland over Inland Shrubby Groundsel Senecio billabongs/ waterholes/ lanibracteus, +/- Tall nut-heads Ethuliopsis cunninghamii low floodplains sparse shrubland over Bluerod Stemodia florulenta. SD0006 Acacia shrubland. Umbrella Bush Acacia ligulata, Elegant Stream channels and Flood 0.03 % Wattle Acacia victoriae ssp., Gidgee Acacia cambagei, +/- outs; Minor water courses Narrow-leaf Hop-bush Dodonaea viscosa ssp. angustissima, and Flood outs +/- Mulga Acacia aneura var. tall open shrubland over Cotton- bush Maireana aphylla, Bladder Saltbush Atriplex vesicaria ssp., Black Bluebush Maireana pyramidata, Spiny Saltbush Rhagodia spinescens SD0007 Chenopod shrubland. Cotton-bush Maireana aphylla, +/- Old- Stream channel, Flood outs 0.38 % man Saltbush Atriplex nummularia ssp. nummularia, +/- and Run-on areas; Flood outs Bladder Saltbush Atriplex vesicaria ssp. low open shrubland over Bristly Love-grass Eragrostis setifolia, Barley Mitchell Grass Astrebla pectinata, Goat-head Bindyi Sclerolaena bicornis, Tangled Bindyi Sclerolaena intricate. SD0008 Chenopod shrubland. Pop Saltbush Atriplex spongiosa, Bindyi Stream channel and Flood 0.01 % Sclerolaena cuneata, Woolly Soft-horns Malacocera outs; Little surface strew;

Tristar Drilling EIR Rev0 43 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

% Cover of Landform / Environment Veg ID Vegetation Association Description Licence Description Area albolanata, Pop Saltbush Atriplex holocarpa, Western Clay; Cracking; Major water Copperburr Sclerolaena parallelicuspis low open shrubland. courses and Flood outs SD0009 Hummock grassland. Emergent Umbrella Bush Acacia ligulata Dunes and Plains; Sand 0.05 % tall sparse shrubland over Sandhill Cane-grass Zygochloa paradoxa, Loose-flowered Rattle-pod Crotalaria eremaea ssp., +/-Spiny Saltbush Rhagodia spinescens, +/- Hard Spinifex Triodia basedowii, +/- Desert Cyanchum Cynanchum floribundum, +/- Spiny Saltbush Rhagodia spinescens tall open hummock grassland over Camel Bush Trichodesma zeylanicum. SD0012 Tussock grassland. Barley Mitchell Grass Astrebla pectinata, Stony plains; Gibber 0.98 % Ray Grass Sporobolus actinocladus, Silky Bindyi Sclerolaena eriacantha, Bonefruit Osteocarpum acropterum var., Salt Bindyi Sclerolaena ventricosa low open tussock grassland. SD0013 Chenopod shrubland. Bladder Saltbush Atriplex vesicaria ssp., Stony plains and Tablelands 0.03 % Old-man Saltbush Atriplex nummularia ssp. omissa, Low Bluebush Maireana astrotricha, Black Bluebush Maireana pyramidata, Soiny Saltbush Rhagodia spinescens low open shrubland over Poverty bush Sclerolaena intricata, Bristly Lovegrass Eragrostis setifolia, Tangled Bindyi Sclerolaena divaricata, Lantern-bush Abutilon halophilum, Samphire Tecticornia medullosa. SI0001 Samphire shrubland. Grey Samphire Tecticornia Salt lakes and claypans 7.16 % halocnemoides ssp., Nitre -bush Nitraria billardierei mid shrubland over Buckbush Salsola australis, Brown-head Samphire Tecticornia indica ssp. leiostachya, Purple Plume Grass Triraphis mollis, Curly Wire-grass Aristida contorta, Caustic Weed Chamaesyce drummondii low forbs. SI0003 Low shrubland of Sea-heath Frankenia spp. and Tecticornia Near lakes and claypans 4.11 % spp. SI0004 Chenopod shrubland. Atriplex vesicaria ssp., +/-Maireana interdune corridors and 0.07 % aphylla, +/-Maireana astrotricha, +/-Astrebla pectinata, +/- paleo-drainage systems Chenopodiaceae spp. mid shrubland. SI0010 Chenopod shrubland. Maireana aphylla low shrubland. Sandplains and interdune 0.34 % corridors SI0011 Acacia shrubland. Acacia ligulata, Acacia murrayana, +/- Sandplains and dunefields 1.36 % Acacia dictyophleba, +/-Acacia ramulosa var., +/-Hakea leucoptera ssp. leucoptera, +/-Grevillea juncifolia ssp. juncifolia, +/-Dodonaea viscosa ssp. angustissima, +/- Eremophila macdonnellii tall shrubland over Atriplex spp. SI0012 Tall hummock grassland. Emergent Acacia ligulata, +/-Acacia Dune crests and dune foot 9.73 % murrayana, +/-Dodonaea viscosa ssp., +/-Hakea leucoptera slopes ssp. leucoptera mid shrubland over Zygochloa paradoxa, Triodia basedowii tall hummock grassland over Salsola tragus, Polycalymma stuartii, Aristida holathera var holathera. SI0013 Tall hummock grassland. Emergent Acacia ligulata mid shrubs Dune slopes, swales and 1.81 % over Triodia basedowii, Zygochloa paradoxa tall hummock interdune corridors grassland over Goodenia cycloptera, Polycalymma stuartii, Salsola tragus, Senecio gregorii, Sida ammophila, Aristida spp. SI0014 Acacia georginae mid open woodland Interdune corridors, lake 0.05 % fringes, and drainage systems

Tristar Drilling EIR Rev0 44 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

% Cover of Landform / Environment Veg ID Vegetation Association Description Licence Description Area

SI0015 Nitraria billardierei low open shrubland over +/-Atriplex spp., Swales and near salt lakes 5.01 % +/-Frankenia spp., +/-Goodenia spp. SI0018 Acacai shrubland. Acacia ramulosa var. mid open shrubland Sand dunes 0.003 % over +/-Aristida spp., +/-Eragrostis spp. low tussock grasses SI0020 Chenopod shrubland. Atriplex limbata, +/-Atriplex vesicaria Interdune corridors 0.42 % ssp., +/-Maireana pyramidata low open shrubland SI0021 Tall hummock grassland. Emergent +/-Acacia ligulata mid Dunes 58.61 % shrubs over Zygochloa paradoxa tall hummock grassland over Salsola tragus, Aristida spp., Sclerolaena spp., Polycalymma stuartii, Trichodesma zeylanicum (Source: DEW, 2010)

Grasslands such as those of the Simpson Desert do not usually support a great abundance or diversity of vertebrate species. After rains, however, resources are abundant and populations boom. As a result, the distributions of local and regional species are continuously fluctuating. A complete picture of the fauna is therefore only possible through repeated observations over long periods. The remoteness and scale of the reserves has limited the number of surveys in the region and, as a consequence, desert fauna is not as well-understood as desert flora (DEW, 2019a).

Mammals

Up to 22 native species of mammals and 9 introduced species have been previously recorded in the licence area (DEW, 2018). Commonly recorded native mammal species in the licence area include the Fat-tailed dunnart (Sminthopsis crassicaudata) and the Sandy inland mouse (Pseudomys hermannsburgensis). Common and widespread introduced species include the One-humped Camel (Camelus dromedarius), Rabbit (Oryctolagus cuniculus), Feral Cat (Felis catus), House mouse (Mus musculus) and Red Fox (Vulpes vulpes). Management of these pest species is a priority for the Simpson Desert RR (DEW, 2019).

Birds

148 bird species have been recorded across the licence area (DEW, 2018). Commonly recorded bird species include the Banded whiteface (Aphelocephala nigricincta), Budgerigar (Melopsittacus undulates), Crested Pigeon (Ocyphaps lophotes), White-winged Fairywren (Malurus leucopterus), and Zebra Finch (Taeniopygia guttata).

Migratory birds visit the region in wetter years, further detail is provided in Section 4.3.4.

Reptiles and Amphibians

The Simpson Desert and surrounding areas support high reptile diversity. 54 species of reptile and 2 frog species have been recorded in the licence area (DEW, 2018). Commonly recorded reptile species include Painted Dragon (Ctenotus pictus), Eastern Desert Ctenotus (Ctenotus regius), Eyrean Ctenotus (Ctenotus taeniatus), Ghost skink (Eremiascincus phantasmus), Robust tree Dtella (Gehyra purpurascens), Desert Skink (Liopholis inornata), and the Beaded Gecko (Lucasium damaeum).

Tristar Drilling EIR Rev0 45 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

No threatened ecological communities (TECs) occur within the licence area (DEE, 2018).

Natural heritage sites in the region include the ecologically significant Diamantina River Wetland System which occurs in parts of PEL 289 and PEL 290 (refer to Section 4.4).

Several species listed under the Commonwealth Environment Protection and Biodiversity Conservation Act 1999 (EPBC Act) and South Australian National Parks and Wildlife Act 1972 (NPW Act) legislation are recorded or predicted by databases to occur in the region. Threatened species recorded (DEW, 2018; DEE, 2018) or predicted to occur in the licence area are detailed in Table 4.4.

Table 4.4: Threatened species recorded or predicted to occur in the licence area

Status* Species Location / Comment Cwlth SA Plants Acacia peuce V - EPBC database predicts presence. No records identified for the licence Waddy area (DEW, 2018). May occur on stony flats or gibber plains areas between longitudinal dunes or on alluvial flats between ephemeral watercourses. No South Australian records, previously recorded in south-west Queensland and south-east Northern Territory (Orchard & Wilson, 2001). Acacia pickardii V R EPBC database predicts presence. Birds Nest wattle / Pickards Wattle 1 record located in the SE corner of PEL 290, and a further 30+ records located 10-20 km south of PEL 290 (DEW, 2018). Species known from far north-eastern SA and south-eastern NT, with the SA population in the Mt Gason Bore / Pandie Pandie area, 150 km south of Birdsville, SA. Grows on gibber-covered sandplains and in stony sand over clay on low mesas and flats (Orchard & Wilson, 2001). The species forms a low woodland or low open woodland. Frankenia plicata E V 7 records located in the central and northern areas of PEL 288, and 1 Sea Heath record in the Simpson Desert CP (DEW, 2018). Grows in a range of habitats, including on small hillside channels, which take first run-off after rain (DEE, 2019a). In the Simpson Desert, species predominantly found from swales of loamy sands to clay (Neagle, 2003). Species is found in a wide range of vegetation communities that have good drainage (Neagle, 2003). Plantago multiscapa - V 1 record located in PEL 160 approximately 56 km NNE of Morice Hill Many Stem Plaintain (summit), and 2 records west in Witjira NP (DEW, 2018). Tecticornia cupuliformis - V No records identified for the licence area (DEW, 2018). 1 record located approximately 12 km south-east of PEL 289 southern boundary (DEW, 2018). Small shrub around 25 cm high. Found on freshwater claypans and on white clay soil. Birds Amytornis modestus V - EPBC database predicts presence. No records identified for the licence Thick-billed Grasswren area (DEW, 2018). Closest records (3) located approximately 20 km south-east of PEL 289 SE boundary (DEW, 2018). Inhabits chenopod shrublands dominated by Atriplex spp. and Maireana spp. Ardeotis australis - V 7 records located in PELs 160 and 289, and several records in the Australian Bustard region surrounding the licence area (DEW, 2018). Occurs in open grassy woodland, grassland including pastoral land and crops.

Tristar Drilling EIR Rev0 46 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Status* Species Location / Comment Cwlth SA Formerly found throughout inland Australia, extending to coastal areas north of the Tropic of Capricorn. Calidris ferruginea CE - EPBC database predicts presence. No records identified for the licence Curlew Sandpiper area (DEW, 2018). Closest records approximately 40 km east of PEL 290 eastern boundary, and 40 km south of PEL 288 southern boundary (DEW, 2018). Migratory shorebird, mainly occurring on intertidal mudflats or coastal lakes and lagoons. Recorded less frequently inland around ephemeral and permanent lakes, dams, waterholes and bore drains, usually with bare edges of mud or sand. Charadrius mongolus E R EPBC database does not predict presence. Lesser Sand plover 2 records located in the south-east corner of PEL 290 (DEW, 2018). Small to medium-sized grey-brown and white plover widespread in coastal regions, occasionally occurring inland (DEE, 2018a). Cladorhynchus leucocephalus - V 1 record located in PEL 288 to the east of Lake Griselda, bordered on Banded Stilt PEL 289 (DEW, 2018). Coturnix ypsilophora - V No records identified for the licence area (DEW, 2018). Brown Quail Closest record located 35 km east of PEL 290 eastern boundary. Grus rubicunda - V 1 record located in central PEL 289 (DEW, 2018). Brolga Neophema chrysostoma - V 5 records located in PELs 288 and 289, and multiple records within the Blue-winged Parrot Simpson Desert CP. Pedionomus torquatus CE E EPBC database predicts presence. No records identified for the licence Plains Wanderer area (DEW, 2018). Closest records located 40-50 km south-east of PEL 289 and 290 (DEW, 2018). Inhabits sparse, treeless, lowland native grasslands with around 50% bare ground and occasionally in chenopod shrublands (DEE, 2019a). Pezoporus occidentalis E E EPBC database predicts presence. No records identified for the licence Night Parrot area (DEW, 2018). Closest record located 85 km south-east of PEL 290 southern boundary (DEW, 2018). Discovery of signs (calls and feather) in samphire habitat at Kalamurina near Lake Eyre North / Kati Thanda reported in 2017 have since been retracted. Thought to inhabit Triodia grasslands and samphire and chenopod shrublands in arid and semi-arid Australia. Current distribution is possibly limited to western Queensland and the Pilbara, but is poorly understood due to difficulty in detection and very limited numbers of sightings (DEE, 2019a). Rostratula australis E V EPBC database predicts presence. No records identified for the licence Australian Painted Snipe area (DEW, 2018). Closest record located approximately 40 km east of PEL 290 eastern boundary (DEW, 2018). Wading bird which inhabits shallow terrestrial wetlands including temporary and permanent lakes, swamps and claypans as well as dams, sewage farms and bore drains (DEE, 2018a).

Mammals Dasycercus cristicauda V - EPBC database predicts presence. Crest-tailed Mulgara (Ampurta) 80+ records located across the licence area (DEW, 2018). Records occur in all PELs. Inhabits crests of low dunes and sandy rises. Dasyuroides byrnei V V EPBC database predicts presence. No records identified for the licence Kowari area (DEW, 2018).

Tristar Drilling EIR Rev0 47 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Status* Species Location / Comment Cwlth SA Closest records (2) located 7-20 km south of PEL 290 southern boundary (DEW, 2018). Known (well-studied) populations occur in gibber habitats on Clifton Hills pastoral Station located approximately 50 km east of PEL 290. Macrotis lagotis V V EPBC database predicts presence. No records identified for the licence Greater Bilby area (DEW, 2018). Closest records (2) located 50 km east of PEL 290 eastern boundary (DEW, 2018). Medium-sized burrowing marsupial that occurs at various locations between south-west Queensland and the Pilbara (DEE, 2019a). Species thought to be extinct in the wild in mainland SA. Notomys cervinus - V 2 records located in the SE corner of PEL 290 near Goyder Lagoon Fawn Hopping-mouse (DEW, 2018). Most commonly inhabits gibber plains with low chenopods and ephemeral plants, and sometimes found on adjacent claypans. Populations fluctuate in response to environmental conditions (SAAL NRM, 2011) Notomys fuscus V V EPBC database predicts presence. No records identified for the licence Dusky Hopping-mouse area (DEW, 2018). 1 record located approximately 15 km south of PEL 289 southern boundary at Lake Warrandirinna. Patchy and fluctuating distribution in the arid areas of south-west Queensland, north-east SA (Strzelecki dunefields) and western NSW (DEE, 2019a). Notoryctes typhlops - V 16 records located in PELs 160 (15 records) and 288 (1 record), and 1 Southern Marsupial Mole record in Simpson Desert CP (DEW, 2018). A blind marsupial mole that (Itjaritjara) lives underground in sand dunes and adjacent swales where there is suitable deep, loose sand (DEE, 2018a). Pseudomys australis V V EPBC database predicts presence. Plains Rat 2 records located in the north-west corner of PEL 289. Small nocturnal rodent which inhabits low-lying patches of deep cracking clay common on gibber plains and gentle slopes supporting sparse chenopod shrublands and other ephemeral vegetation. Widespread in western Lake Eyre Basin from NT border to Lake Eyre South / Kati Thanda. Increases in numbers during good conditions and becomes extremely scarce between periods of peak abundance. It is considered likely that no populations of the Plains Rat are permanently associated with a particular habitat patch or ‘refugia’. Rather, Plains Rat populations consist of a number of dynamic regional populations utilising a network of primary core areas, with rare widespread dispersal between regions (DEE, 2019a). *Conservation Status under the Commonwealth Environment Protection and Biodiversity Conservation Act 1999 and the SA National Parks and Wildlife Act 1972: CE – Critically Endangered, E – Endangered, V – Vulnerable, R – Rare

The EPBC Act Protected Matters Search Tool (PMST) report (DoEE 2018b) identified eight (8) migratory species listed under the EPBC Act as potentially occurring within the licence area, species identified include: (Fork-tailed Swift (Apus pacificus), Grey Wagtail (Motacilla cinerea), Yellow Wagtail (Motacilla flava), Common Sandpiper (Actitis hypoleucos), Sharp-tailed Sandpiper (Calidris acuminata), Curlew Sandpiper (Calidris ferruginea), Pectoral Sandpiper (Calidris melanotos) and Oriental Plover, Oriental Dotterel (Charadrius veredus). The Curlew Sandpiper (Calidris ferruginea) is also listed as Critically Endangered under the EPBC Act. No records for Curlew Sandpiper occur in, or within approximately 40 km of, the licence area (DEW, 2018).

Tristar Drilling EIR Rev0 48 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

As discussed in Section 4.3.1, vegetation in the licence area is almost entirely native, and records of introduced species are limited (DEW, 2018). Weeds recorded in the licence area are predominantly naturalised or widespread weed species of generally limited concern to the environmental or pastoral values of the broader region e.g. Caltrop.

However, Buffel grass (Cenchrus ciliaris), which is a declared weed under the South Australian Natural Resources Management Act 2004 (NRM Act), has been recorded in the Munga-Thirri–Simpson Desert RR. The Munga-Thirri–Simpson Desert CP and RR Management Plan (DEW, 2019a) recommend that containment of Buffel grass spread should be a priority for the area given its ease of establishment, fast maturation and spread. Buffel grass can form dense monocultures, out-competing native grasses and reducing food supply for native fauna. The broader landscape is also compromised as Buffel grass produces more combustible material than native grasses resulting in hotter and more intense fires.

Other weeds recorded for the licence area identified as a management priority by DEW (2019a) include Caltrop (Tribulus terrestris) (Declared, NRM Act) and Neurada procumbens. Caltrop is a rapidly growing summer herb that causes problems with its sharp-spined burrs. The species is a complex found throughout the tropics and subtropics of the world, and populations in inland SA are likely to include native forms that have been present in northern Australia for many thousands of years. Active management of the species in the SAAL NRM region is limited (PIRSA, 2014). Neurada was first observed in Australia at the north-west corner of the Munga-Thirri–Simpson Desert RR in 2000. It is only otherwise known to occur at a number of sites in the Northern Territory (DEW, 2019a).

Introduced plant species recorded in databases (DEW, 2018) to occur in the licence area are listed in Table 4.5.

Table 4.5: Weeds recorded in the licence area

Species Common Name Status* Brassica tournefortii Wild Turnip Cenchrus ciliaris Buffel Grass Declared Citrullus colocynthis Colocynth Citrullus lanatus Bitter Melon Heliotropium curassavicum Smooth Heliotrope Indigofera linnaei Birdsville Indigo Pseudognaphalium luteoalbum Jersey Cudweed Sonchus oleraceus Common Sow-thistle Tribulus terrestris Caltrop Declared Diplachne fusca ssp. Erodium aureum Neurada procumbens *as per the South Australian Natural Resources Management Act 2004

Pest animals recorded in the licence area include feral cattle, rabbits, cats and foxes, donkeys, horses and camels. The ongoing maintenance of low feral herbivore (camels, donkeys, horses and cattle) densities is identified as a management priority for the Munga-Thirri–Simpson Desert CP and RR (DEW, 2019a).

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The Diamantina River Wetland System is located in PELs 290 and 289. The wetland system is listed as a nationally important wetland by the Directory of Important Wetlands in Australia. The Diamantina’s multiple intertwining small stream channels and flood courses spread to form the ephemeral Goyder Lagoon before recombining into the narrow flood courses and channels of the Warburton and Kallakoopah Creeks that eventually feed into Lake Eyre (DEH, 2008). The system includes the lower reaches of the Diamantina River and Goyder Lagoon, which intersects PELs 290 and 289 as Goyder Lagoon and Warburton Creek. The Kallakoopah Creek travels west through PELs 289 and 290. The Diamantaina system is an example of a major unregulated arid zone wetland system, and is one of the major wetland systems in Australia, which remains substantially unmodified. The wetland system is also highly unusual in being a major arid zone river system with a catchment in the semi-arid rather than in a humid zone.

Goyder Lagoon and the Warburton and Kallakoopah Creeks provide aquatic, wetland and riparian habitat for a wide range of flora and fauna including a range of fish, birds and mammals (Mancini, 2017; Schmarr et al., 2017). Goyder Lagoon in particular provides habitat for a wide range of waterbirds and shorebirds including Little Black Cormorant, Straw-necked Ibis, Nankeen Night Heron, Little Pied, Pied and Great Cormorants, Great and Intermediate Egrets, Australian White Ibis, Australasian Darter, Australian Pelican and White-necked Heron, Sandpipers and Little Curlew. The area also supports a population of Yellow chat near Koonchera Waterhole. The Australian Painted Snipe has also been recorded near Koonchera Waterhole. Goyder Lagoon also supports a population of Grey Grasswren (Amytornis barbatus diamantina) (Birdlife International, 2019). The gibber plains adjacent to the eastern side of the lagoon support a diverse mammal assemblage, including the stronghold of the South Australian population of Kowari (Dasycercus byrnei) (NPW Act and EPBC Act listed Vulnerable).

As discussed in Section 1.4, Tri-Star proposes to exclude drilling exploratory wells in Goyder Lagoon8 and the area within 500 m of the main channel of Kallakoopah Creek9 from the scope of this EIR.

No wetlands of international importance (Ramsar wetlands) occur in the licence area. The closest Ramsar wetland (Coongie Lakes) is located approximately 54 km south-east of the PEL 290 boundary.

Other areas of value not formally listed include: waterholes of the Diamantina system (Mancini, 2017).

Surface water in the region is generally ephemeral and the environmental, cultural, social and economic aspects interact and response to the episodic, irregular, extreme boom and bust periods that are a feature of the SAAL NRM region. A distinct feature of the region is periodic temporary flooding in some areas, caused by rainfall outside the region that flows into the river systems.

The main waterways in the region are ephemeral, and include the Diamantina River, Eyre Creek, Goyder Lagoon, Warburton Creek and Kallakoopah Creek, which ultimately drain into Lake Eyre North / Kati Thanda. The Diamantina River flows into Goyder Lagoon. These features are shown in Figure 4-2.

The Diamantina River is a braided channel which originates north-west of Longreach in Queensland (Wainwright et al. 2006). The river travels approximately 1000 km from Queensland to Lake Eyre North

8 Goyder Lagoon, as defined by the Wetlands of National Importance 3rd Edition (Spatial GIS Layer) (DEEH, 2001). 9 Kallakoopah Creek, as defined by the DEW topographical watercourse mapping dataset (GDA94) (DEW, 2019).

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/ Kati Thanda in South Australia (SA). The total catchment area of the Diamantina is 365,000 km2 (Kotwicki, 1986). The Diamantina initially flows into Goyder Lagoon, which lies 80 km south of the SA border, and ultimately terminates at Lake Eyre North / Kati Thanda via the Warburton and Kallakoopah Creeks. Goyder Lagoon is an extensive ephemeral wetland covering 1300 km2. The south-western corner of PEL 290 intersects Goyder Lagoon. At the south-western edge of this large basin, Eyre Creek (known as the Georgina upstream) joins from the west.

Eyre Creek (from the South Australian border to Goyder Lagoon) is the down-valley termination of the Georgina River. It consists of multiple semi-parallel interlinked flow paths in which water flows down Simpson Desert interdunes. The flow is essentially unconfined (except in local topographic pinch points) and extremely low energy, without sediment transport. Consequently, there are few channels and no permanent water, and no aquatic refugia (Wakelin-King, 2017). Eyre Creek runs along the western boundary of PEL 290.

Goyder Lagoon is a broad shallow valley where flows are unconfined with no significant sediment transport. Goyder Lagoon has a few permanent and semi-permanent waterholes, mostly at the lagoon margins. The width and low gradient of Goyder Lagoon coupled with numerous dispersed water entry points drives the unconfined nature of the flow (Wakelin-King, 2017). Goyder Lagoon typically receives inflows from the Eyre Creek and Warburton / Diamantina Rivers during summer months when monsoonal troughs push south into the Diamantina catchment. These monsoonal systems can bring heavy rainfall to the lower reaches of the catchment, whereas rainfall is more commonly confined to the upper catchment area during moderate flood events (Osti, 2004; Costelloe et al., 2003).

During larger flood events, floodwaters can flow southwards from Goyder Lagoon to Lake Eyre North / Kati Thanda via the Warburton River and Kallakoopah Creek. The Kallakoopah Creek runs through permits 289 and 288. Warburton and Kallakoopah Creeks flow from the south-western end of Goyder Lagoon to Lake Eyre North / Kati Thanda. The channels are particularly wide (in the order of 50 m) and flows, although highly variable, are generally more confined than the rest of the Diamantina system. Warburton Creek lies to the south-east of PEL 289, while Kallakoopah Creek intersects the southern parts of PEL 288 and 289, flowing in a north-westerly direction through PEL 289 turning in a generally southerly direction through PEL 290 (see Figure 4-2).

The Diamantina system is the major contributor of floodwaters to Lake Eyre North / Kati Thanda (Kotwicki, 1986). The Diamantina River has an average annual inflow volume to Lake Eyre North / Kati Thanda of 2.4 km3 (65% of the total flow) compared to the Cooper Creek with an average contribution of only 0.63 km3 (16%) (Nanson et al. 1998). Satellite observations of Diamantina flood events between 1991 to 2013 identified 11 flood events reached Lake Eyre North / Kati Thanda, 4 terminated in Goyder Lagoon, and 2 terminated downstream of the lagoon, but upstream of Lake Eyre North / Kati Thanda (Osti, 2004). During flood events the Goyder Lagoon and its connected tributaries and floodplains can occupy 30-50% of PEL 290 depending on flood magnitude. Large flood events in the region generally coincide with rainfall over a significant portion of the catchment, but the self-draining nature of the surrounding country means that very little of the rainfall reaches the system as runoff. The only area in the catchment that noticeably contributes runoff via organised drainage is the Sturt Stony Desert (Koonchera / Sturt land systems), with runoff flowing into Goyder Lagoon via small incised flood channels (Osti, 2004).

Other surface water features of note in the licence area include the chain of playa lakes (ephemeral lakes) in the central part of the Munga-Thirri–Simpson Desert RR (predominantly in PELs 288 and 289). Smaller playa lakes have a smooth and hard clay surface, while the larger lakes have a bright white salt crust sitting over a layer of mud which remains damp even during drought (DEW, 2019a). Larger lakes include Lake Griselda, Peera Peera Poolanna Lake, Poolowanna Lake, Lake Umaroona, Poolyeruninna Lake, Lake Willawilaninna, Lake Pialpotingoona and Lake Pantoowarinna.

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Plate 4.1: Stained waters of the Kallakoopah Creek – high evaporation rates cause leaching of saline water and dissolved iron from shallow groundwater sources (Source: Wakelin-King, 2017)

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Figure 4-2: Surface water features in the vicinity of the licence area

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This subsection provides background on conventional and unconventional hydrocarbon reservoirs. Specific detail on the conventional and unconventional targets in the Simpson Basin is then provided.

Conventional and Unconventional Gas

Natural gas is found in a number of geological settings and within various rock types (see Figure 4-3). All natural gas is composed predominantly of methane (CH4), with varying, usually minor, quantities of other hydrocarbons and inert compounds (e.g. N2, CO2). The descriptor of conventional as opposed to unconventional does not refer to the gas itself; rather it refers to the rocks or formations that the gas is trapped in and the methods required to extract it commercially.

Conventional Oil

Conventional oil is typically found in sandstone formations in sedimentary basins. The oil resources are usually from another formation but move into the sandstone and are trapped by an impermeable ‘cap’ rock. Conventional oil resources are extracted using traditional methods of drilling down through the ‘cap’ rock and allowing oil to flow (or pumping it) up the well (see Figure 4-3). In some formations where the permeability is lower, fracture stimulation techniques are required to recover the oil.

Figure 4-3: Illustration of different types of hydrocarbon reservoirs (after Schenk and Pollastro 2002).

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The most recent summary of the areas structural history is described by Radke (2009). The region can be divided into three sub-basins or preserved depocenters enclosed by the Arunta Platform to the northeast, the Amadeus Basin to the north west, the Musgrave Block to the west-south west, Muloorinna Ridge which demarcates the Officer and Arckaringa Basins to the southwest, and the Birdsville Track Ridge to the east (see Figure 4-4 to Figure 4-5). In this region and west of the Dalhousie – McDills – Mayhew (DMM) Ridge lies the north-northeast-south – southwest orientated Eringa Trough. Immediately east of the DMM Ridge and contained further east by paralleling Border Trend is the Madigan Trough that is developed only in the Northern Territory. East of the Border Trend lies the much larger Poolowanna Trough, bounded on its eastern flank by the Birdsville Track Ridge. This high separates the trough from the much deeper Cooper Basin.

Figure 4-4: Structural Elements and relationships between Pedirka, Simpson and Eromanga Basins (from Ambrose et al., 2007).

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Figure 4-5: Regional structural features expressed in the structural depth of the Cretaceous ‘C’ seismic horizon (Cadna-Owie Formation) (Source: Radke, 2009). Ambrose et al. (2007) describes pronounced Palaeozoic tectonism related to compression during the latter part of the Alice Springs Orogeny (Late Devonian to Mid-Carboniferous) folded Neoproterozoic/Palaeozoic sediments of the Warburton Basin. This section was truncated by erosion resulting in a moderately undulating topography which was infilled by Permo-Carboniferous sediments. During the period, epeirogenic downwarp accommodated glaciogenic (Crown Point Formation) and floodplain-swamp deposits (Purni Formation), but subsequent depositional terrains became progressively more subdued through time. Mild tectonism at the end of the Early Permian was accompanied by regional easterly tilt with local basin sag occurring in the Eringa, Madigan and Poolowanna Troughs, the latter being the major focus of Mesozoic sedimentation. This period saw the installation of a structural regime differentiating the Pedirka Basin from the younger, closely allied Simpson and Eromanga Basins.

The oldest Simpson Basin sediments, the Walkandi Formation red-bed sequence, were deposited on a gently undulating Permian surface, under the influence of mild regional subsidence. It is proposed that minor uplift in the Middle Triassic triggered an abrupt change to fluvial-alluvial sedimentation at the base of the Peera Peera Formation. Minor uplift and erosion (peneplantation) at the end of the Triassic resulted from mild rejuvenation of pre-existing faults. The overlying Early Jurassic sedimentary cycles are sheet-like in extent, with sedimentation of both this unit and the overlying Jurassic/Cretaceous sequence increasingly focussed in the Poolowanna Trough. This resulted in the vertical juxtaposition of the thickest development of Peera Peera and Poolowanna Formation source rocks beneath the most substantial Cretaceous sedimentary load (see Figure 4-6).

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Figure 4-6: Structural cross-section across the Pooloowanna Trough including vitrinite reflectance profiles (Ambrose et al. 2007) Structuring during the Jurassic was subtle and largely a function of drape and compaction over older Palaeozoic highs, but structural closures formed at this time are believed to be prime targets. Relatively rapid burial of the Eromanga section occurred during the Cretaceous prior to at least some uplift and erosion at the end of the Winton Formation time, although this interpretation relies heavily on evidence from the Cooper Basin to the south. During Miocene, intense east-west compression and local wrenching resulted in severe structural rejuvenation resulting in severe structural rejuvenation, and in some cases structural inversion, along most major fault lines. This structural phase linked to the collision of the Australian and Timor continental plates during the Miocene (Ambrose et al., 2007).

Ambrose et al. (2007) provides an excellent summary of basin stratigraphy and is provided below.

Three stacked sedimentary basins deposited on folded Neoproterozoic/Palaeozoic sediments of the Warburton Basin are present in the target area with the stratigraphy summarised in Figure 4-7 and Figure 4-8. The lowermost of the three basins is the Permo-Carboniferous Pedirka Basin, whose main depo-centres occur in the west (Madigan and Eringa troughs, see Figure 4-4 and Figure 4-5). The Triassic Simpson Basin and Jurassic-Cretaceous Eromanga Basin variably overlap the Pedirka Basin and are the primary subject of this paper.

The regional distribution of geological formations is summarised on a west to east structural cross- section (see Figure 4-5) and two stratigraphic cross-sections (see Figure 4-6 and Figure 4-7).

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Figure 4-7: Basin stratigraphy

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Permian Stratigraphy (Pedirka Basin)

The Pedirka Basin and its associated depocenters including the Eringa, Madigan and Poolowanna Troughs originated during the Alice Springs Orogeny. The Permo-Carboniferous record is dominated by widespread glaciation and basal diamictites (Crown Point Formation), which were previously thought to be disconformably overlain by intracratonic sediments of the early Permian Purni Formation. Ambrose et al. (2002) describes the Purni Formation as being the lateral equivalent of the highly productive lower Patchawarra Formation/Tirrawarra Sandstone petroleum system of the Cooper Basin.

Triassic stratigraphy (Simpson Basin)

In the Simpson Basin a major unconformity separates the Early Permian Purni Formation and the overlying Early–Middle Triassic Walkandi Formation. A period of Late Permian structuring, accompanied by imposition of a regional easterly tilt, is indicated by erosion of Permian sequences in structurally high positions (Moore, 1986). The structural configuration of the Simpson Basin, which was a precursor to the later Eromanga Basin, originated at this time.

The Walkandi Formation in the Simpson Basin is interpreted to correlate with the lower part of the Nappamerri Group (Arrabury Formation) in the Cooper Basin, on the basis of lithological criteria, wireline log signature and sparse palaeontological control. The two basins are separated at this stratigraphic level by a zone, 150–200 km wide, of non-deposition and erosion across the Birdsville Track Ridge (Moore,1986; see Figure 4-5). The Walkandi Formation is defined in Moore (1986) who describes a regional red-bed sequence of fine sandstone, siltstone and shale deposited in a shallow, ephemeral, lacustrine environment under stable tectonic conditions. This setting was coeval with the worldwide lowering of sea level that created major Early Triassic continental red-bed deposits across much of central/eastern Australia and much of the Northern Hemisphere.

The Walkandi/Peera Peera Formation contact is probably marked by a very low angle disconformity commonly denoted by fluvial /alluvial sandstone deposition probably responding to an abrupt, regional fall in base level of erosion (fall in sea level to the northeast). The proposed disconformity corresponds to an important unconformity in the Cooper Basin separating the Arrabury and Tinchoo formations defined by Powis (1989).

Sparse drilling on and near the Birdsville Track Ridge shows thinning of the Peera Peera Formation south-eastward onto this high; however, the occurrence of typical Peera Peera alluvial-lacustrine facies (Tinchoo Formation) in numerous northern Cooper Basin wells (e.g. Cook–1, MacKillop–1, Mt Howitt– 2) suggests there was probably some connection between this depocentre and the Simpson Basin at this time (see Figure 4-9). Tectonic stability resulted in marked lateral continuity of the Peera Peera Formation across a very wide area beyond the Poolowanna Trough (see Figure 4-9). Gradually rising sea levels during deposition of the Peera Peera Formation, caused ponding of drainage lines resulting in an upward gradation to fine-grained delta plain/delta front clastics, which in turn grade upwards into ubiquitous, fine-grained lacustrine siltstone and shale providing regional source and seal. Ambrose et al. 2007.

Jurassic-Cretaceous stratigraphy (Eromanga Basin)

At the end of the Triassic in the Simpson Basin there was subtle movement on major faults with associated peneplanation prior to deposition of the Early Jurassic Poolowanna Formation. A very thin section of Late Triassic Cuddapan Formation occasionally intervenes between the Peera Peera and Poolowanna formations, signifying little erosion at this unconformity (see Figure 4-9).

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The Poolowanna Formation, which forms the base of the Eromanga Basin sequence, can be subdivided into two transgressive, fluvial-lacustrine cycles that formed on a regional scale, both probably controlled by distal sea level fall/slow-rise cycles although there may have been some regional climatic/tectonic controls in place. This two-fold subdivision (Cycles 1 and 2) is based primarily on wireline log response (see Figure 4-9) and sparse palynology, and is supported by the partitioning of aquifer salinities and hydrocarbon occurrences/shows at a sealing shale capping Cycle 1.

Cycle 1 is broadly contained in palynological zones J1 to J3–4 and in its thickest development (120 m in Poolowanna–1) comprises a basal, sheet-like braided fluvial channel sand 20–30 m thick, overlain by interspersed floodplain / crevasse splay and distributary mouth bar sandstones about 70 m thick. There follows a gradation, through fine-grained splay and meandering channel sandstones, to lower delta plain/lacustrine coaly shales and siltstones. The latter are good source rocks and provide regional seal.

Cycle 2 is broadly contained in palynological zones J5–6 and is a similar facies to Cycle 1 but is relatively thin (50–100 m thick). Braided fluvial channel sands at the base are often strongly cemented by calcite and are in sharp contact with the underlying regional seal, probably marking a hiatus related to a distal fall in sea level. Silty-coaly shales cap the cycle and are interpreted to be locally eroded by massive braided fluvial sandstones of the lower Algebuckina Sandstone, hence linking Cycle 2 reservoirs to the main Eromanga Basin aquifer system.

A return to marine sedimentation occurred during deposition of the Early Cretaceous Cadna-owie Formation.

Figure 4-8: Schematic section across the Eromanga. Pedirka and Simpson basins

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Figure 4-9: Stratigraphic cross-section for South Australia and Queensland wells. Datum is base Algebuckina Sandstone (Ambrose et al. 2007)

Background

Oil was originally discovered in the Poolowanna Trough at the Poolowanna 1 well drilled by Delhi in 1977. Several drill stem tests were conducted in this well with the Pooloowana Formation producing on test a waxy, paraffinic crude oil along with mud and water. A light oil/condensate was also recovered from the upper Peera Peera Formation which supports the presence of multiple petroleum systems. (Ambrose et al., 2007) (see Figure 4-10 and Figure 4-11). Numerous wells were drilled following the Poolowanna discovery with oil shows recorded in multiple intersections however a commercial discovery is yet to be made (see Figure 4-4). Poolowanna 3 was the most recent well drilled in 1989.

Tri-Star Petroleum plans to implement modern technology to unlock the potential of the Simpson Basin focusing its efforts on both conventional and unconventional opportunities.

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Figure 4-10: Gas chromatogram of oil and condensate samples recovered from the Poolowanna 1 well. (Source: Ambrose et al., 2007).

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Figure 4-11: The early Jurassic and Triassic formations from the Poolowanna 1 well log (Source: Ambrose et al., 2007).

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Prospective Targets – Conventional Oil and Gas

Prospective conventional petroleum reservoirs identified in the Simpson Basin licence area are associated with sandstone formations of the Eromanga, Simpson and Pedirka Basins (see Figure 4-12). Mapped reservoirs typically comprise structural targets in the Triassic Peera Peera and Jurassic Poolowanna Formation sealed by intra-formational seals consisting of mudstone, siltstone and coal. Stratigraphic plays may also exist within the Purni Formation where reservoir sands pinch out and the Walkandi Formation provides a regional seal.

The Algebuckinga Sandstone provides excellent reservoir characteristics and is regionally sealed by the overlying Cadna-Owie Formation within the Simpson Basin area. The Birkhead Formation has been intersected in a number of wells including Kuncherina 1, Miandana 1 and Walkandi 1, in the Cooper Basin the Birkhead Formation provides a regional Intraformational seal.

Where sedimentation is thickest within the Poolowanna Trough, sandstone reservoirs often have low permeabilities such that hydraulic stimulation may be deployed to test flow-rates and production volumes.

Prospective Targets – Unconventional Oil and Gas

Unconventional plays in the Eromanga, Simpson and Pedirka Basin are comprised of shales, deep coals or tight sandstones which are largely characterised as self-contained systems (providing the full petroleum system of source, seal, reservoir and trap), with the presence of petroleum not influenced by any such structural (anticlinal) setting. It is important to note that because the unconventional reservoirs lie within the same stratigraphy as that of the conventional reservoirs, the hydrocarbon produced is the same as that of a conventional well. A distinguishing feature of unconventional resources is their very low permeabilities, ranging from ultra-tight sub-micro (10-6 D) to nanodarcy (10- 9 D) permeability. Unconventional plays often exist as large, continuous and predictable accumulations within basin depocenters such as the Poolowanna Trough and maybe either normally-pressured or over-pressured. The key enabler for the commercialisation of unconventional plays is hydraulic stimulation.

Figure 4-12: Pedirka, Simpson and Eromanga Basins play types and proposed migration pathways (schematic) (Source: Ambrose et al., 2002).

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The Eromanga, Simpson and Pedirka Basins can be broadly subdivided into aquifers and confining beds (aquitards and seals). Aquifers are porous and permeable units that are able to store and transmit water and are generally analogous to the petroleum reservoirs in that they have storage capacity for fluids as well as permeability which enables the passage of fluids through them. In several instances, porous-permeable units are both aquifers and petroleum reservoirs.

Confining beds (aquitards) are units that impede the movement of water, and in general have low hydraulic conductivities or permeability. In some aquitards, the conductivity is so low that no fluid permeates them under natural pressure conditions.

The pressure of an aquifer can be described as a pressure or hydraulic head. In general, the hydraulic head drives the flow of water from one part of an aquifer to another, (i.e. from high to low). The head distribution can be used to create a potentiometric surface map that links locations of equal head potential by the construction of equipotential contours. Flow paths are constructed perpendicular to these contours to show the direction of lateral groundwater flow. Differences in head potential between aquifers occur when a confining layer is present and flow in each aquifer occurs independent of the other. In this situation, the head difference will drive water through the confining bed until equilibrium is established. The volume of water moving through a confining bed is generally very small compared with the lateral flow in the aquifers. The rate of movement through the confining bed depends on its thickness, its vertical hydraulic conductivity (related to lithology) and the head difference. Flow through confining beds can also occur along faults.

Under normal conditions, fluid flows from high hydraulic head to low hydraulic head. If the hydraulic head is the same in two aquifers separated by a confining bed, the mixing of fluids between aquifers will not occur even if the aquitard is breached by a fault or well bore. Where the hydraulic head is different and there is a breach in the confining bed, fluid will flow from the aquifer with the higher hydraulic head to the aquifer with the lower head. To minimise the potential for mixing during drilling activities, weighted muds are used to offset pressure differences. Once the well is drilled to its target depth and the casing strings have been installed, cement is pumped into the annulus between the casing and the formation providing a seal between the different formations.

In general, aquifers and aquitards are assigned in relation to geological formations, which is the basic rock unit used to describe a stratigraphic succession. A geological formation can contain both aquifers and aquitards. For example, the Cadna-owie Formation has been described as one of the main aquifers of the Great Artesian Basin (GAB). However, the bottom three quarters of the Cadna-owie Formation is siltstone and shale and acts as an aquitard while the upper quarter of the unit is a sandstone that may act as an aquifer where it is not cemented or too silty. Large parts of the Poolowanna formation, and most of the Wallumbilla, Toolebuc, Allaru, Mackunda and Winton formations, are aquitards within the Eromanga Basin. Within the Simpson and Pedirka Basin, large parts of the Peera Peera, Walkandi and Purni Formations form aquitards. The hydraulic conductivities of these beds have been estimated to be low based on lithology given the lack of regional data, numerical model calibration in same formation in the Cooper Basin region estimate flow to be about 10−4 m/day (Audibert, 1976). Recent research on the Bulldog Shale near Lake Eyre in the Western Eromanga Basin indicated a range of vertical hydraulic conductivity values of 9 x 10-4 to 9 x 10-9 m/day (Love et al. 2013) with the higher vertical hydraulic conductivity values reflecting the effects of preferential pathways (faults) in this area of thinner Bulldog Shale. Despite the low hydraulic conductivities, over geological time, the aquitards have allowed hydraulic communication between aquifers such that most are in hydraulic equilibrium and have the same hydraulic head. In addition, many aquitards have been breached naturally, either by erosion or by faulting. Where this occurs, large scale mixing of the aquifers has taken place and hydraulic equilibrium has or is being reached.

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Aquifers include the Eyre Formation of the Lake Eyre Basin, some parts of the Winton, Cadna-owie, Birkhead formations, and large parts of the Algebuckina, Poolowanna formations in the Eromanga Basin. In the Simpson Basin, parts of the Peera Peera Formation may act as aquifers. In the Pedirka, parts of the Purni and Crown Point Formation act as aquifers. Hydraulic conductivities measured in the Eromanga and Pedirka aquifers range between 0.2 and 25 m/day (DEWNR, 2015), these data points are located further west of the licence area where Permian sediments sub-crop into the Eromanga. Hydraulic conductivities measured to the east of the licence area in the Cooper Basin region range between 0.1 and 10 m/day (Audibert, 1976). Table 4.7 provides a summary of the pressure, permeability and salinity characteristics of these aquifers and regional geological cross sections are shown in Figure 4-13 and Figure 4-14.

A semi regional shale aquiclude at the top of Cycle 1 sediments in the Poolowanna Formation has been interpreted at Poeppels Corner 1 and Thomas 1. Formation water produced from both the Algebuckinga Sandstone and the Poolowanna Formation during production testing returned marked changes in reservoir salinities across the seal (Ambrose et al 2002). At Poppels Corner 1, Algebuckina Sandstones reservoir water salinity ranged between 1,800 – 2,000ppm. Pooloowanna Formation reservoir water salinity beneath Cycle 1 shale seal had a salinity of 6,000ppm. A similar change in salinity was seen at Colson 1 between the Cycle 2 reservoirs and the Algebuckina Formation indicating an important shale caps Cycle 2 sediments (Ambrose et al 2002).

Tight rocks (including some of the aquitards listed above) of the Eromanga, Simpson and Pedirka Basins can be further characterised into unconventional reservoirs (summarised in Table 4.6). These are rocks that may contain oil or gas which is stored either in micro porosity or adsorbed onto the surface of organic matter that makes up part of the rock framework. Rocks that form unconventional reservoirs can include shales, siltstones, mudstones (commonly grouped as shales), coals and very tight sandstones. Shales and coals are known to be the source of hydrocarbons in the Eromanga and Simpson basin. Low concentrations of organic matter in the shales, and high concentrations in the coals are partially converted to hydrocarbon fluids by heating associated with burial. In conventional reservoirs, the hydrocarbon moves away from the source rock (migrates) through a permeable conduit to collect in a porous and permeable reservoir rock. In some situations, particularly where the rocks have been deeply buried, hydrocarbon is unable to migrate and remains in or close to where it was generated, often with an increase in pressure. The gas phase can become continuous through the rock, as it is immobile. Water can still be present in the rock, but the combination of a gas and fluid phase reduces the permeability of both phases; the water blocks gas movement and gas blocks water movement. Sandstones that behave as conventional reservoirs in the shallower parts of the Eromanga, Simpson and Pedirka Basin, move into the unconventional tight category as they become more deeply buried, where compaction and heat act to close up the pores, thereby limiting fluid conductivity.

In the proposed exploration area, oil & gas is the main unconventional target. Under “normal” conditions, the gas stored in these rocks is immobile and the rocks can be considered as aquitards or seals. Gas flow and recovery from unconventional wells is achieved by stimulating the rock to create a network of fractures through which the gas can flow.

Table 4.6: Summary of potential unconventional targets

Basin Formation Unconventional Target Toolebuc Shale Eromanga Poolowanna Coal/Shale/Tight Sand Peera Peera Coal/Shale/Tight Sand Simpson Walkandi Shale/Tight Sands Pedirka Purni Coal/Shale

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Table 4.7: Summary of salinity, pressure and permeability characteristics

Formation Use Extent Salinity Pressure System Permeability Phreatic Limited to stock Basin wide, except Highly variable, 2000 – Fully unconfined High aquifer watering and where older, underlying 122,350 ppm petroleum units are exposed exploration Eyre Limited use Basin wide, except Unclear, probably variable Uppermost aquifer, unknown but less then GAB High Formation where eroded on like the phreatic aquifer topographic highs above, 1000 – 20000 ppm or more Winton Basin wide, but sands As above As above High Formation may be of limited extent Mackunda Potential reservoir Basin wide Unclear, probably high Uppermost GAB or k aquifer. Known to be less than GAB High Formation (>9000 ppm) J aquifer Cadna-Owie Known aquifer in Basin wide Limited data – possible 2000 Part of main GAB j aquifer, on a common water pressure Often low, locally high Formation uppermost part of – 5000 ppm system formation Algebuckina Known aquifer and Basin wide 300 – 4000 ppm Part of main GAB J aquifer High Formation reservoir Birkhead Known reservoir Restricted to southern 300 – 4000 ppm Part of main GAB J Aquifer High Formation marginal areas Hutton Known aquifer and Basin wide 300 – 4000 ppm Part of main GAB J aquifer High Sandstone reservoir Poolowanna Potential reservoir Basin wide 3000 – 15000 ppm Part of main GAB J on the western margin. Potentially Highly variable – likely Formation isolated within the Poolowanna Trough due to semi tight in centre of regional shales capping Cycle 1 Poolowanna reservoir Poolowanna Trough Peera Peera Potential reservoir Basin Wide 14000 – 35000 ppm Potential for very high pressure in centre of basin. May Highly variable – likely Formation be same or greater or less than GAB. May have local tight in centre of depleted zones. Poolowanna Trough Walkandi Potential reservoir Basin Wide Unknown As above Highly variable Formation

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Formation Use Extent Salinity Pressure System Permeability Purni Potential reservoir Restricted to western 13500ppm Potential for very high pressure in centre of basin. May Highly variable Formation marginal areas be same or greater or less than GAB. May have local depleted zones. Can prove connection with the GAB west of the Simpson Basin. Crown Point Potential reservoir Restricted to western Limited data in working area. As above Highly variable Formation marginal areas 93 – 7910ppm where formation subcrops into GAB Pre-Permian Potential reservoir Basin Wide Unknown Potential for very high pressure in centre of basin. May Highly variable – may Basement be same or greater or less than GAB. include natural fractures

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Figure 4-13: Regional geological cross section of the area

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Figure 4-14: Regional geological cross section of the area

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The licence area is located in the Far North Prescribed Wells Area (Far North PWA). Groundwater in the Far North PWA is predominately sourced from deep Great Artesian Basin (GAB) aquifers. There are other sources of groundwater in the region, but few are useable and are minor by comparison with the GAB (Maree SCB, 2004; Love et al., 2013). GAB water extraction in the region permits permanent pastoralism and supplies industry. The salinity of GAB groundwater in the region is quite good, being generally less than 2,000 mg/L over most of the area, although increasing on the margins of the basin (Maree SCB, 2004).

Groundwater is predominantly sourced from the GAB Cadna-owie Formation and Algebuckina Sandstone (and equivalents), which as a single aquifer unit is described as the Jurassic-Cretaceous (J- K) aquifer. The depth to the GAB (J-K) aquifer is as much as 2400 m below ground level in the north- east of SA, but this decreases towards the edge of the basin, with the aquifer cropping out along the western and southern margins. The GAB (J-K) aquifer ranges from less than 50 m in thickness around the basin’s western margin to greater than 500 m near the Poolowanna Trough (DEW, 2018b). Recent research has shown that much of the groundwater contained in the GAB (J-K) aquifer in SA was recharged more than 10 000 years ago under different climatic conditions to those that are observed today. Present-day recharge along the western margin of the GAB (J-K) aquifer in SA is low, and although active recharge occurs to the GAB (J-K) aquifer from the occasional flooding of ephemeral rivers in the Northern Territory, the rates of recharge are relatively low compared to rates of discharge. Upward leakage from the underlying Cooper Basin is also thought to contribute recharge to the GAB (J-K) aquifer, but the magnitude of this flow is yet to be determined (DEW, 2018b).

The Water Allocation Plan for the Far North PWA (SAAL NRM, 2009) estimates groundwater extraction from the GAB is in the order of 33.5 ML/d for stock and domestic use and 4 ML/d for town water supply. Total groundwater discharge from springs has been estimated at 66 ML/d. Petroleum operations have a current allocation volume of 60 ML/d for co-produced water. Mining operations have a current allocation volume of 44.6 ML/d. In addition to this volume, BHP Billiton’s Olympic Dam has been granted a special water licence to extract water (up to 42 ML/d) from the GAB aquifer.

Groundwater sourced from shallow unconfined aquifers in the region is generally of poor quality and are highly variable e.g. salinity can be in the range of 2,000 – 122,350 ppm. Pleistocene sediments occur beneath river valleys and the dunefields in the region. Most of these sediments are permeable sands, and they host the local unconfined aquifer (Wakelin-King, 2017). However, good quality groundwater can be found at shallow depths adjacent to the major watercourses and water bodies due to bank recharge processes during flow events (e.g. Diamantina River and Goyder Lagoon). Shallow groundwater sources in the region are important contributors to the persistence of the waterholes and associated biodiversity, except for an approximate 9-12-month period following large flood events (Costelloe, 2017). Very minor shallow groundwater sources, with a rainfall recharge only, exist in parts of the Simpson Desert – these areas were tapped by Aboriginal wells (Maree SCB, 2004).

Existing groundwater bores in the licence area and surrounding region are detailed in Table 4.8 and displayed on Figure 4-15. All water bores within PELs 160, 288 and 289 were completed for petroleum exploration purposes. There are several shallow bores in PEL 290 completed for stock purposes. Several artesian bores, such as New Goyders Lagoon bore (6643-11), were completed in the GAB.

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Table 4.8: Water bores (or other drill holes converted to water bores) drilled within the licence area

Name Bore # Status Purpose pH TDS (mg/l) Yield (L/sec) SWL (m) Drill Date Depth (m) Max Depth (m) EC (µS/cm) Aquifer

ALTON DOWNS 6645-1 Backfilled 10.67 1/01/1958 37.49 37.49 H.S.

ALTON DOWNS 6645-3 Backfilled 0.82 0 15.54 WELL

BMR 6644-2

PANDIE PANDIE 3 6644-1 Backfilled 1/10/1970 0 70.1 BROWNS BORE / 6245-1 Backfilled Stock 7.8 26654 0.1515 28 28/02/1977 154 156 24533 TQ MACUMBA

ERABENA 1 6345-3 Dry Exploration 18/12/1981 2584.7 2584.7

ERABENA NO 2 6345-2 Unequipped 3.788 32 6/11/1981 125 125 TQ ERABENA NO 3 6345-1 Unequipped 7.3 11446 4.419 27 8/11/1981 125.5 125.5 19396 TQ

GEORGES BORE 6644-3 Controlled Stock 626 -48.65 5/08/2002 1603 1603 1136 JK1 Flowing

GLEN JOYCE 1 6245-4 Abandoned Exploration 16/08/1985 0 2289.05 GLEN JOYCE NO.1 6245-5 7.9 2292 15.15 38 21/07/1985 120 120 4114 TQ

GNARROWIE 6645-4 Abandoned 1.89 1/01/1958 0 14.33 WELL

GOYDERS 6643-1 Controlled Observation/Stock 7.78 669 25.26 -108.12 1/01/1905 1478.28 1215 JK-a LAGOON Flowing

KILLUMI 1 6244-1 Abandoned Exploration 26/07/1985 2312.21 2312.21

KILLUMI NO.1 6244-2 11.36 27 1/01/1985 136 136 Taee

KUNCHERINNA 1 6544-2 Abandoned Exploration 2/02/1982 2866.34 2866.34 KUNCHERINNA 6544-1 Operational Industrial 7.1 122350 3.92 8 30/11/1981 154 154 143941 Taee NO1

MACUMBA 1 6245-2 Abandoned Exploration 16/11/1977 0 2617.01

MIANDANA 1 6343-1 Abandoned Exploration 15/09/1985 0 2672.49

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Name Bore # Status Purpose pH TDS (mg/l) Yield (L/sec) SWL (m) Drill Date Depth (m) Max Depth (m) EC (µS/cm) Aquifer

MIANDANNA A 6343-2 2.24 7/08/1985 105 105 Topn

MIANDANNA B 6343-3 2.21 14/08/1985 105 105 Topn

MOKARI 1 6145-2 Abandoned Exploration 10761 26/06/1966 2385.67 2385.67 18334 NEW GOYDERS 6643-11 Stock 7.34 611 58 -104.54 20/11/2012 1520 1520 1110 JK1 LAGOON

NEW GOYDERS 6643-12 Decommissioned 19/11/2012 0 774 LAGOON SITE A

OOLARINNA 1 6245-3 Abandoned Exploration 19/06/1985 0 2674.93

OOLARINNA NO.1 6245-6 16651 8.66 30 22/05/1985 96 96 27434 TQ

Unnamed 6643-7 Industrial 10448 2.5 16 24/05/2000 60 60.5 17800

Unnamed 6645-2 Abandoned 10.06 1/01/1958 26.82 26.82

Unnamed 6645-5 Abandoned 7853 0 13602

WALKANDI 1 6344-3 Abandoned Exploration 8/11/1981 0 3125.11

WALKANDI NO1 6344-1 2.525 20 2/09/1981 79.9 79.9 TQ

WALKANDI NO2 6344-2 7.576 20 4/09/1981 79.5 79.5 TQ (Source: Waterconnect, 2019)

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Figure 4-15: Existing water bores in the licence area

Tristar Drilling EIR Rev0 74 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Vertical leakage from the GAB occurs via a series of springs (generally referred to as GAB springs or mound springs). The closest GAB springs to the licence area are the Dalhousie Mound Springs complex, which are located in Witjira National Park (NP) approximately 65 km west of the PEL 160 western boundary. More southerly occurring GAB springs and mounds are located over 80 km south-west of the PEL 288 south-western boundary.

The Dalhousie Springs are the most northerly group of GAB springs in South Australia. It is a complex of ‘mound’ springs i.e. the groundwater flow deposits calcium and other salts from the mineral-rich waters. These deposits, combined with wind-blown sand, mud and accumulated plant debris, settle around the spring outflow forming mounds that resemble small volcanos (DEE, 2018b).

GAB groundwater movement rates are slow, between one to five metres per year. As a result, some water in the centre of the basin is more than one million years old. Dating techniques that measure groundwater flow reveal that Dalhousie Springs appear to be recharged by thousands of years old water that has percolated down through the beds of Finke River, and adjacent arid zone rivers, where they overlie outcrops of the GAB aquifer. As a geological feature the Dalhousie Springs complex is unique in Australia. It illustrates on a huge scale an artesian spring’s system, with faults, impermeable confining beds, aquifer outcrops, mound spring deposits, and the large pools and rivulets of artesian water (DEE, 2018b).

The Munga-Thirri–Simpson Desert RR and CP form part of an area of great significance to the Wangkangurru / Yarluyandi People. The Wangkangurru / Yarluyandi People have lived on this country for tens of thousands of years (DEW, 2019a). Pastoral expansion in the desert regions from 1860-1900 displaced Aboriginal groups and at this time, the Wangkangurru / Yarluyandi began leaving the desert. The last remaining Wangkangurru / Yarluyandi People vacated the desert in the summer of 1899-1900 (DEW, 2019a).

There are culturally significant areas and sites throughout the Munga-Thirri–Simpson Desert CP and RR that are important to the Wangkangurru / Yarluyandi People. All sites are protected under the Aboriginal Heritage Act 1988, whether registered, recorded or unrecorded. Culturally significant areas and sites may include (but are not limited to) the following: ▪ cultural campsites ▪ stone implements and workings ▪ stone arrangements ▪ burial sites ▪ tree scars; and ▪ Approdinna Attora Knolls (rare gypsum outcrops) – the Knolls are the home of the Rain Ancestor ‘Kuntili’.

While some sites and places are documented in the Register of Aboriginal Sites and Objects under the Aboriginal Heritage Act 1988, there has not been a comprehensive survey of the Munga-Thirri– Simpson Desert CP and RR, and there are highly likely to be many undocumented sites (DEW, 2019a).

Witjira NP is located adjacent to, and shares its eastern boundary with, the Munga-Thirri–Simpson Desert RR and PEL 160 (Note: PEL 160 does not cover any area of Witjira NP). Witjira NP is of great significance to the Wangkangurru and Lower Southern Arrernte people, whose Altyerre (traditional law and customs) is strongly linked to the land. The significance of the national park to Aboriginal

Tristar Drilling EIR Rev0 75 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions people is reflected through the many creation stories that weave through the Country. The mound springs complex is of particular significance to traditional owners, as many stories are associated with, or pass through, the springs (DEWNR, 2017).

There are no National or State Heritage listed places located within the licence area.

The Dalhousie Mound Springs complex is a listed Heritage Place on the National Heritage List. Places listed in the National Heritage List are protected under the EPBC Act. The springs are located in Witjira NP, approximately 65 km west of the PEL 160 western boundary.

The historic “French Line” is also located between Witjira NP, PEL 160 and the Munga-Thirri–Simpson Desert CP. The French line, along with other tracks in the area (e.g. Rig road, QAA line), was created during seismic surveys of the area during the 1960’s and 1970’s.

The major land use within the region is conservation, tourism and beef cattle production. Other land uses in the broader region include petroleum and resource exploration.

Pastoral leases intersected by the licence area include (see Figure 4-16):

• Cowarie (PEL 289) • Kalamurina (PEL 288) • Clifton Hills (PELs 289, 290) • Alton Downs (PEL 290); and • Macumba (PEL 160)*.

*Note: The Macumba pastoral lease intersects the south-west corner of PEL 160 as defined by the SA pastoral boundaries GIS layer (which is derived from pastoral fence lines) (DEW, 2018a). However, the PEL 160 boundary is actually aligned with the gazetted boundary of the Munga-Thirri–Simpson Desert RR and is understood to be within the Munga-Thirri–Simpson Desert RR land parcel (see Figure 4-16). For the purposes of this document Macumba pastoral lease is considered to be located outside the licence area.

The Kalamurina pastoral lease is held by the Australian Wildlife Conservancy (AWC) and is operated as a private sanctuary. Kalamurina intersects a small section of the PEL 288 southern boundary (approximate area is 60 km2). As discussed in Section 1.4, the southern portion of PEL 288 that overlaps Kalamurina pastoral lease is excluded from the scope of this EIR.

Alton Downs, Cowrie and Clifton Hills Pastoral Stations are Certified Organic Livestock operations under the National Association for Sustainable Agriculture, Australia (NASAA).

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Figure 4-16: Pastoral leases surrounding the licence area

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No mining tenements (i.e. exploration or production licences) are located within the licence area or its immediate region.

Active mineral licences and applications are generally located to the far west and south of the licence area. Numerous non-active mineral exploration licences (ELs) are located immediately south-west of PELs 160 and 288, and 2 non-active ELs (5278 and 5279) are located on Cowarie pastoral station directly south of the PEL 289 south-eastern boundary.

The licence area has been subject to intermittent petroleum exploration since the 1950’s, and the Simpson and Pedrika Regions contain several prospective hydrocarbon formations. Extensive seismic survey and exploratory and stratigraphic well drilling activities were undertaken in the licence area (10 drill holes) and the 70’s and 80’s, and some of the early seismic lines and well access tracks are still used as access routes through the Simpson Desert region (see Section 4.7.2). Approximately 7250 km of seismic survey lines have been recorded in the licence area.

Several exploration wells were also drilled in the region surrounding the licence area, including within the Munga-Thirri–Simpson Desert CP (e.g. Poolowanna 1, 2 and 3) and oil and condensate was originally discovered in the Poolowanna Trough following the drilling of Poolawanna-1 in 1977. Drill stem tests of Poolawanna-1 returned a waxy, paraffinic crude oil along with mud and water. A light oil condensate was also recovered from the upper Peera Peera Formation. Numerous wells were drilled following the Poolowanna discovery with oil shows recorded in multiple intersections, however no commercial hydrocarbon discovery has yet to be made.

Exploration wells previously drilled in the licence are detailed in Table 4.9, and the locations of historic seismic lines and wells are displayed on Figure 4-17.

Table 4.9: Exploration wells previously drilled in the licence area

Spud Well Name Basin Operator Class Result Status Long (dec) Lat (dec) Year Erabena 1 Simpson Delhi 1981 Exploration Oil Shows Abandoned 137.22904 -26.019362 Glen Joyce 1 Pedirka Delhi 1985 Exploration Dry Abandoned 136.520803 -26.303217 Killumi 1 Pedirka Delhi 1985 Exploration Dry Abandoned 136.753048 -26.521537 Kuncherinna 1 Simpson Delhi 1981 Exploration Oil Shows Abandoned 138.267917 -26.709475 Macumba 1 Pedirka Delhi 1977 Exploration Dry Abandoned 136.85621 -26.442578 Miandana 1 Simpson Delhi 1985 Exploration Oil Shows Abandoned 137.396116 -27.052197 French Mokari 1 Pedirka 1966 Exploration Dry Abandoned 136.441485 -26.318495 Petroleum Oolarinna 1 Pedirka Delhi 1985 Exploration Dry Abandoned 136.857707 -26.222038 Walkandi 1 Simpson Delhi 1981 Exploration Oil Shows Abandoned 137.468977 -26.560001 Bureau of Pandie Warburton Mineral 1970 Stratigraphic Dry Hole P&A 138.98457 -26.93434 Pandie 3 Resources (Source: DEM, 2019b)

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Figure 4-17: Historic exploration wells and seismic lines in the licence area

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The region contains some of South Australia’s largest areas dedicated under the National Parks and Wildlife Act 1972. The licence area is located in its entirely over the Munga-Thirri–Simpson Desert Regional Reserve (RR), and shares boundaries with Witjira National Park (NP) and the Munga-Thirri– Simpson Desert Conservation Park (CP) (see Figure 1-1).

Regional Reserves are areas proclaimed for the purpose of conserving wildlife, natural or historical features while allowing responsible use of the area’s natural resources (including oil and gas exploration and production activities). Oil and gas exploration and production is an anticipated activity within Regional Reserves; a significant proportion of the Cooper Basin (Australia’s largest onshore oil and gas province) is located within the Innamincka Regional Reserve and Strzelecki Regional Reserve.

The Simpson Desert is the world’s largest sand dune desert, with the world’s longest parallel dunes. Munga-Thirri–Simpson Desert CP and RR cover a combined area of approximately (3,607,265 ha), and they share their borders with south-western Queensland and south-eastern Northern Territory (see Figure 1-1). The Conservation Park was originally proclaimed as a National Park in 1967, but its classification was changed to a Conservation Park in 1972. The Regional Reserve was established in 1988, linking the CP with Witjira NP. The large size of the parks allows for a wide cross-section of diverse flora, fauna and sand ridge formations to be protected.

Witjira NP was proclaimed under the NPW Act in 1985. The park covers an area of approximately 768,853 ha, and shares its northern boundary with the Northern Territory, and its eastern boundary with the Munga-Thirri–Simpson Desert RR (see Figure 1-1).

As discussed in Section 4.8.5, the Wangkangurru / Yarluyandi People are the native title holders of the Munga-Thirri–Simpson Desert CP and RR area. As traditional owners they set directions for management in partnership with the South Australian Government (DEW, 2019a).

The Munga-Thirri–Simpson Desert CP and RR help protect (DEW, 2019a): ▪ culturally significant sites and landscapes, including rare gypsum outcrops, known as Knolls ▪ ancient song lines that reflect the creation of desert landforms and provide a geographical reference, enabling Wangkangurru Yaryulandi people to navigate their way across the desert ▪ bush tucker foods and culturally significant animals ▪ the world’s largest system of parallel sand dunes ▪ one of the largest areas of high-quality wilderness left in Australia ▪ fossil sites of extinct megafauna that once roamed these deserts, providing opportunities for scientific research ▪ a variety of plants including ten that are listed as vulnerable or rare in South Australia and one (Sea Heath Frankenia plicata) listed as endangered under the EPBC Act ▪ important fauna including 16 species listed as rare or vulnerable in South Australia and two nationally vulnerable species; and ▪ one of the greatest 4WD challenges in the world and a true Australian outback experience.

The Munga-Thirri–Simpson Desert CP and RR Management Plan (DEW, 2019a) outlines the current management objectives and strategies for the area. The Plan notes strategies for managing the impacts of petroleum exploration include:

▪ In the event of future mineral and petroleum exploration or production activities within the regional reserve, ensure that the regional reserve’s remote and natural qualities are maintained, precautions are taken to minimise the spread of weeds, tracks are rehabilitated, and visitor experience and aboriginal cultural heritage is not impacted.

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As discussed in Section 4.8.1, the Kalamurina pastoral lease intersects a small section of PEL 288 and is held by the Australian Wildlife Conservancy (AWC), who operate the area as a private sanctuary. Kalamurina covers an area of approximately 679,666 ha located between the Munga-Thirri-Simpson Desert RR and Kati-Thanda/Lake Eyre NP. The Kallakoopah Creek, Warburton Creek and Macumba River converge in Kalamurina before entering Kati-Thanda/Lake Eyre. Over 65% of the water that enters Kati Thanda-Lake Eyre travels through Kalamurina. Kalamurina contains a diversity of ecosystems – vast dunefields, a network of freshwater and saline lakes, desert woodlands, gibber plains, and riparian and floodplain habitats (AWC, 2019). As discussed in Section 1.4, Kalamurina pastoral lease is excluded from the scope of this EIR.

The Munga-Thirri–Simpson Desert CP and RR have been recognised as having wilderness value (DENR, 2011), however no formal wilderness protection exists over the area. Several non-government organisations have proposed that the Munga-Thirri–Simpson Desert RR and CP, particularly the Kallakoopah Creek area, should be formally protected as wilderness. As acknowledged in DENR (2011), the Munga-Thirri–Simpson Desert RR is subject to existing rights of entry for petroleum and mining activities.

The Birdsville Track (which crosses the south-eastern corner of PEL 290) and the Simpson Desert crossing are iconic outback routes. It is estimated that approximately 9,000 visitors cross the desert each year. The unsealed Birdsville Track can carry large numbers of tourists, particularly during the period from July to September when the Big Red Bash and Birdsville Races are held. Annual average daily traffic on this section of the Birdsville Track (2015 data) is 55 vehicles per day (DPTI, 2019).

Visitor use across the Munga-Thirri–Simpson Desert RR is largely limited to well-equipped and self- sustaining groups possessing suitable four-wheel drive vehicles, with a crossing of the Simpson Desert typically taking several days (DEW, 2019a). DEW close the Munga-Thirri-Simpson Desert CP and RR to public access between 1 December to 15 March each year due to extreme summer temperatures that can reach over 50 degrees Celsius. Peak tourism season is between May and September (DEW, 2019a).

The licence area is entirely covered by the Wangkangurru / Yarluyandi Native Title Claim (NNTT Number: SCD2014/005), which was determined 3rd October 2014, and is registered to the Wangkangurru / Yarluyandi Aboriginal Corporation Registered Native Title Body Corporate.

Native title agreements with the Wangkangurru / Yarluyandi were signed by the Minister on the 3rd March 2011 (PELs 288, 289, 290 and 331) and 25th May 2017 (PEL 160). The agreements are conjunctive and cover activities from exploration through to development and production. Under the requirements of these agreements, heritage clearances (typically termed Work Area Clearance (WAC) surveys) for any field work will be undertaken prior to the commencement of field activities.

The Marree-Innamincka district has a permanent population of approximately 200 people, with a further 300 transient workers servicing the petroleum industry and 45,000 tourists visiting the region annually (SAAL NRM, 2013). Townships include Innamincka (population approx. 44), Marree (population approx. 101), Lyndhurst (population approx. 24) and Moomba (no permanent residents, FIFO only) (ABS 2016).

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The licence area and surrounding region have very limited road infrastructure. The Birdsville Track crosses the south-eastern corner of PEL 290, and a number of tracks and public access tracks cross the Munga-Thirri–Simpson Desert RR and CP which predominantly utilise seismic lines and roads developed for historic petroleum exploration activities (see Figure 4-18).

The pastoral leases in PEL 290 contain a sparse network of pastoral roads and tracks as well as pastoral infrastructure such as fences, dams, tanks and yards.

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Figure 4-18: Existing roads and tracks in the Munga-Thirri–Simpson Desert RR and CP (Source: DEW, 2019a)

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5 Environmental Impact Assessment

This section identifies and assesses the potential and perceived environmental impacts related to Tri- Star’s petroleum exploration activities (drilling and fracture stimulation operations) in the Simpson, Eromanga and Pedirka Basins.

Environmental impact assessment of drilling and fracture stimulation operations has been covered in Section 5.2 and Section 5.3, respectively. For each activity, detailed discussion of potential environmental impacts is supported by an environmental risk assessment. The risk assessment outlines key hazards, management measures and the resulting level of risk. Risk assessments for drilling and fracture stimulation operations are presented in Table 5.5 and Table 5.6, respectively.

Reference is made to the results of the risk assessments where relevant throughout the impact assessment discussions.

Environmental risk is a measure of the likelihood and consequences of environmental harm occurring from an activity. The risk assessment process involves:

▪ identifying the potential hazards or threats posed by the project ▪ categorising the potential consequences and their likelihood of occurring; and ▪ using a risk matrix to characterise the level of risk10.

The level of risk for Tri-Star’s petroleum exploration activities (drilling and fracture stimulation operations) in the Simpson and Pedrika Regions has been assessed based on the assumption that management measures discussed in this EIR will be in place. The risk assessment was carried out by JBS&G and Tri-Star personnel, based on knowledge of the existing environment, and experience with operations in the Cooper Basin undertaken by other companies (e.g. Senex Energy, Santos, Beach Energy).

The risk assessment process was based on procedures outlined in Australian and New Zealand Standard AS/NZS ISO 31000:2009 (Risk Management) and HB 203:2012 (Managing environment- related risk).

The risk assessments capture existing or proposed risk controls and assign a consequence and likelihood rating to the residual risk. Consequence and likelihood categories and the risk matrix adopted for use in this document are consistent with those used previously for assessment of similar projects in South Australia, and are described below.

The objective of the risk assessment process is to separate the minor acceptable risks from the major risks and to provide data to assist in the evaluation and management of risks.

10 The risk assessment process is iterative for many hazards. For example, the risk assessment may initially indicate that risks are unacceptably high, based on minimum or familiar management practices. In such cases, management practices are reviewed to identify additional management options to lower risk and/or improve environmental outcomes (e.g. elimination, substitution, reduction, engineering controls and management controls). The risk is then re-assessed based on these additional management options. This EIR details the final or residual risk after management options have been applied.

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Risks are generally considered acceptable if they fall into the low category without any further mitigation measures, and ‘tolerable’ if they fall into the medium risk category and are managed to reduce the risk to a level ‘as low as reasonably practicable’. Risk reduction measures must be applied to reduce high risks to tolerable levels.

To describe the severity, scale and duration of potential impacts, the five categories of consequence listed in Table 5.1 are used. These consequences are adapted from the definitions in AS/NZS 31000:2009, but have been expanded to incorporate impacts to environmental values such as flora, fauna and biomass and the socio-economic environment.

A summary of the risk levels for drilling operations is provided in Table 5.5, and those for fracture stimulation operations in Table 5.6. These risk assessments take into account the mitigation methods and practices outlined in the tables.

Table 5.1: Severity of consequences

Category of Qualitative Description of Environmental Effects Effect Natural environment Socio-economic environment Negligible Possible incidental impacts to flora & fauna in a locally affected Community is aware of operations land system but no ecological consequence. Possible incidental and concerns have been addressed impacts to aquifers associated with the oil and gas formation without ecological consequence. Minor Changes to the abundance or biomass of biota, and existing soil Temporary disturbance to the and/or water quality in the affected land system, but no changes community. to biodiversity or ecological function. Aquifers have a small amount of exposure from other sources of fluids, negligible volume movement in or out of formations or aquifers. No measurable change to aquifer water quality or pressure in local area. Moderate Changes to the abundance or biomass of biota, and existing soil Longer term disturbance able to be and/or water quality in the affected land system, with local managed with communication to changes to biodiversity but no loss of ecological function. affected community Detectable change to aquifer water quality and pressure in the local area. Major Substantial changes to the abundance or biomass of biota, Significant effect which can be existing soil and/or water quality in the affected land system mitigated by extensive with significant change to biodiversity and change of ecological rehabilitation and negotiation with function. Eventual recovery of ecosystem possible, but not community necessarily to the same pre-incident conditions. Substantial changes to aquifer water quality and pressure in the local area (i.e. local drawdown adjacent to the oil and gas well or field). Catastrophic Irreversible and irrecoverable changes to abundance/biomass or Significant and long lasting negative aquifers in the affected area. Loss of biodiversity on a regional economic and social effects. scale. Loss of ecological functioning with little prospect of recovery to pre-incident conditions. Widespread effect of reduction in aquifer pressure (i.e. reduced flow from bores in locations remote from operations). Contamination of aquifers remote from operations.

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Likelihood of occurrence

The likelihood of potential environmental consequences occurring was qualitatively assessed and categorised according to the criteria outlined in Table 5.2.

Table 5.2: Assessment of likelihood

Likelihood Description Almost certain is the event is expected to occur in most circumstances Likely Will probably occur in most circumstances Possible Could occur Unlikely Could occur but not expected Rare Occurs only in exceptional circumstances

Risk Assessment

The level of risk has been determined by combining the likelihood and the severity of consequences using a risk matrix. Table 5.3 shows the risk matrix that has been used in this risk assessment.

Table 5.3: Risk matrix

SEVERITY OF CONSEQUENCE Negligible Minor Effect Moderate Major Effect Catastrophic Effect Effect Effect Almost certain MEDIUM HIGH HIGH VERY HIGH VERY HIGH

Likely LOW MEDIUM HIGH VERY HIGH VERY HIGH

Possible LOW MEDIUM HIGH HIGH VERY HIGH

LIKELIHOOD Unlikely LOW LOW MEDIUM HIGH HIGH

Rare LOW LOW MEDIUM MEDIUM HIGH

Tristar Drilling EIR Rev0 86 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

This section discusses potential environmental impacts related to drilling operations. The discussion is supported by the environmental risk assessment that is summarised in Table 5.5 (in Section 5.2.10), which outlines the key hazards, management measures and residual risk level. Reference is made to the results of the risk assessment where relevant throughout the discussion.

Potential impacts to soil and shallow groundwater arise mainly from:

▪ earthworks for well lease, access track, borrow pits, camp site, and aircraft landing area construction and rehabilitation (e.g. erosion, inversion, compaction) ▪ presence of borrow pits ▪ spills or leaks associated with storage and handling of fuel, oil and chemicals, drilling procedures and initial production testing / flaring ▪ well control incidents or loss of well integrity and explosion or fire at well sites; and ▪ storage, handling and disposal of waste.

Earthworks

The major hazards associated with road construction are earthworks, vegetation clearance, chemical and fuel storage and waste disposal. Earthworks and vegetation clearance can potentially result in soil erosion, interruption of natural drainage patterns, disturbance to cultural heritage sites, introduction and spread of weeds and loss of vegetation. Waste disposal and chemical and fuel storage associated with road construction activities and mobile earthworks camps can lead to localised soil or water contamination.

In order to minimise surface impacts and facilitate rehabilitation, well leases will be placed in accordance with key impact mitigation measures outlined in Section 3.2.1. Furthermore, the preferred location of well leases is determined by the sub-surface targets, however leases can generally be moved or orientated within allowable tolerances to minimise surface disturbance.

Topsoil will typically be removed at the well lease and stockpiled alongside the lease for use in rehabilitation. In most cases the access track is cleared and graded or rolled. Final surface restoration of well leases and associated infrastructure will be undertaken in accordance with measures outlined in Section 3.2.1 and Section 3.5.

The type and severity of potential impacts as a result of access track and well lease construction is dependent, to a certain extent, on the landform in which the activities are carried out. Table 5.4 summarises potential impacts associated with earthworks in the typical landforms present in the licence area. Hazards associated with construction activities include earthworks (i.e. grading, compacting), road watering and the introduction of construction material (e.g. borrow material).

Introduction of borrow material can also result in alteration of drainage patterns and possibly introduction and / or spread of weeds. The presence of roads can also increase the ease of access by third-parties to previously inaccessible sites (as discussed in Section 5.2.6), which has been observed to increase impacts from grazing and tourism visitation (Gillen and Reid, 2013).

Public roads will be utilised and maintained in consultation with relevant stakeholders (e.g. DEW, DPTI) to minimise consequences on other public road users. There are few hazards associated with road abandonment. Hazards include earthworks (i.e. ripping) and removal of road construction material (e.g. clay). Ripping can lead to soil erosion and alteration of drainage patterns. Disposal of road

Tristar Drilling EIR Rev0 87 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions construction material may potentially spread weeds or alter drainage patterns and vegetation cover at the disposal site.

The principal hazards associated with construction of an aircraft landing area are earthworks, vegetation clearance, chemical and fuel storage and waste disposal, as discussed for road construction in Section 3.2.1. The major hazards associated with operation of an aircraft landing area are the storage of fuels and the potential disruption or injury to stock (if present) or wildlife, particularly birds. Permanent airstrips may be fenced to exclude stock or large fauna species.

Borrow Pits

Earthworks, including the construction of borrow pits, can potentially disturb natural drainage patterns, introduce or spread weeds, lead to soil erosion and result in the alteration of drainage lines or lead to the capture of water which in turn may attract animals and lead to an alteration in grazing patterns. A recent review of borrow pits in the Cooper Basin (Jacobs SKM, 2014) highlighted water retention in borrow pits and the associated indirect impacts of increased grazing and predator pressure as an issue of particular concern. The Native Vegetation Act 1991 and Pastoral Land Management and Conservation Act 1989 place some approval requirements on pastoral landholders regarding approval of new waterpoints which may be relevant for borrow pits that retain water for long periods.

Borrow pits are required for the excavation of material for use in the stabilisation of access tracks, campsites and well sites, depending upon the nature of the substrates at each location. Movement to and from a well site to a borrow pit can lead to generation of dust and/or compaction of soil. Borrow material is generally not moved over large distances. Borrow pit locations will have adequate clearance from infrastructure (e.g. facilities, fences, homesteads, roads) to minimise risk associated with safety concerns, erosion, and visual impacts. Erosion is controlled by appropriate placement, batter slopes and construction of water flow diversion banks. contained in them. Site selection, environmental management and restoration of borrow pits will be undertaken in accordance with industry-wide standards for borrow pit management developed by DEM (2014).

Table 5.4: Impacts associated with earthworks in the various land systems

Land System Preparation of well site / access tracks (grading) Excavation & Stockpiling

Dunefields and Sand ▪ Vegetation clearance ▪ Vegetation clearance Plains ▪ Soil erosion (wind and water erosion) ▪ Soil erosion (wind and water erosion) ▪ Disturbance to cultural heritage sites (dune ▪ Disturbance to cultural heritage sites fields near waterholes are typically of high (dunefields near waterholes are typically of cultural significance) high cultural significance) ▪ Impeded fauna movement ▪ Inversion of the soil profile ▪ Impeded fauna movement

Gibber Plains ▪ Not applicable on gibber plains (grading ▪ Vegetation clearance should not occur on these terrain types) ▪ Soil erosion (particularly susceptible to water erosion e.g. severe gullying) ▪ Disturbance of natural drainage systems (e.g. siltation) ▪ Impeded fauna movement ▪ Inversion of the soil profile ▪ Disturbance to cultural heritage sites

Tristar Drilling EIR Rev0 88 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Land System Preparation of well site / access tracks (grading) Excavation & Stockpiling

Drainage Lines, ▪ Vegetation clearance ▪ Vegetation clearance Wetlands & ▪ Soil erosion (wind and water) ▪ Soil erosion (wind and water) Floodplains ▪ Soil compaction ▪ Disturbance of natural drainage systems (Note: Wetlands are generally avoided) ▪ Disturbance of natural drainage systems ▪ Impeded fauna movement ▪ Impeded fauna movement ▪ Disturbance to cultural heritage sites (generally low density of sites in floodplains) ▪ Disturbance to cultural heritage sites (generally low density of sites in floodplains)

Claypans and Salt ▪ Not applicable on salt lakes (drilling will not ▪ Not applicable on salt lakes (drilling will not lakes occur on salt lakes) occur on salt lakes) ▪ Disturbance to cultural heritage sites on ▪ Disturbance to cultural heritage sites on claypans claypans ▪ Impeded fauna movement ▪ Disturbance of natural drainage systems ▪ Soil erosion (particularly susceptible to water erosion) ▪ Impeded fauna movement

Spills or leaks

Improper storage and handling of fuel, oil and chemicals has the potential to result in localised contamination of soil and shallow groundwater. Chemicals and fuel on site will be stored and handled in accordance with relevant standards and guidelines. Any spills will be immediately cleaned up and contaminated material treated on site in accordance with EPA guidelines or removed off-site for appropriate treatment or disposal. Fuel, oil and chemicals will be stored in their product containers with appropriate secondary containment (e.g. lined, bunded areas or on self-bunded pallets). Storage and handling of fuel and chemicals is restricted to designated areas on the well pad. Runoff from higher risk areas (e.g. drill rig, generators) is directed into the sump to minimise the risk of movement of contaminants off-site.

Drilling sumps are used to contain drilling fluids and cuttings and may collect surface runoff from the well lease. They have the potential to result in localised contamination of soil and shallow groundwater. Drilling muds will be water-based, and non-toxic to low toxicity additives will be used.

In terms of potential impacts to shallow groundwater, the water table in much of the region, where present, is generally not close to the surface, and is predominantly brackish to saline (see Section 4.6.1). There is very low to nil population density and very limited use of shallow groundwater in the region. The rate of transport of any spilt contaminants to shallow groundwater (if present) is also likely to be limited by the low rainfall and high evaporation rates in the region, and the relatively low permeability of the clay soils that are present at many locations. Consequently, minor spills and leak, if they occurred, would be expected to have a low level, localised impact. A large release (e.g. due to pond failure) could affect a larger surface area and result in a moderate level consequence, but this is considered unlikely.

Storage of waste and transport to licensed disposal facilities will be undertaken in accordance with relevant legislation and guidelines. Waste generation will be minimised where practicable, waste will be stored securely, and appropriately licensed contractors will be used for waste transport.

Spills or leaks during initial production testing activities could also result in localised contamination of soil or shallow groundwater. Initial production testing will be carried out on the well lease in accordance with industry standards. Production tanks would be located in lined, bunded areas. All tanks and production lines would be inspected and tested for leaks prior to use. If water is produced

Tristar Drilling EIR Rev0 89 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions during initial production testing, it would be in small quantities which would be directed to a tank or pond for disposal via evaporation. Personnel would remain on site during any production testing activities and fluid levels in tanks and ponds would be continually monitored to avoid overfilling.

Assessment and remediation of uncontained spills with larger scale impact (e.g. release of fluid to land outside fenced areas, or any volume to water) will be consistent with the National Environment Protection (Assessment of Site Contamination) Measure and relevant SA EPA guidelines. Any escape of petroleum, processed substance, chemical or fuel to soil is either immediately contained and removed or assessed in accordance with NEPM guidelines and remediated in a timely manner.

If not managed appropriately, spills or leaks can lead to impacts on vegetation, fauna, wildlife and people. The loss and subsequent ignition of some hazardous substances may also lead to an explosion or fire.

Well control and well integrity

Well control and well integrity risks are managed by a range of measures that are discussed in Section 5.2.3.

Waste management

Inappropriately managed waste has the potential to result in localised disturbance or contamination of soil and shallow groundwater. Storage of waste and transport to licensed disposal or recycling facilities will be undertaken in accordance with relevant legislation and guidelines. Waste generation will be minimised where practicable, waste will be stored securely, and licensed waste contractors will be used for waste transport. Waste will be managed in accordance with measures outlined in Section 3.4.2.

Risk Assessment

The level of residual risk was assessed to be either low or medium (see Table 5.5).

Potential impacts to surface water arise mainly from:

▪ earthworks for well site, access track, borrow pit, camp site and aircraft landing area construction and rehabilitation (e.g. disturbance to natural drainage patterns, increased erosion / sedimentation) ▪ presence of borrow pits ▪ spills or leaks associated with storage and handling of fuel, oil and chemicals, drilling procedures and production testing / flaring ▪ well control incidents or loss of well integrity and explosion or fire at the well site; and ▪ storage, handling and disposal of waste.

Earthworks

Earthworks for the well site, access track, borrow pits and camp site and aircraft land area construction and rehabilitation have the potential to alter natural drainage patterns or result in increased sedimentation of surface water features. This can potentially affect native vegetation and fauna.

Well sites, access tracks, borrow pits, camp sites and an aircraft landing area will be located and constructed to avoid significantly impacting surface drainage patterns or surface water features. Sites will be rehabilitated to restore natural surface profiles and original drainage patterns. Sensitive land

Tristar Drilling EIR Rev0 90 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions systems will be avoided wherever possible. Where activities are undertaken in or near these areas, appropriate review, assessment and mitigation measures will be in place to ensure that surface water flows are maintained, and contamination of surface water and groundwater is avoided. Where necessary, temporary culverts will be installed to ensure surface drainage is maintained.

Borrow pits

Erosion is controlled by appropriate placement, batter slopes and construction of water flow diversion banks. Borrow pits are restored to minimise water holding capacity. Site selection, environmental management and restoration of borrow pits will be undertaken in accordance with industry-wide standards for borrow pit management developed by DEM (2014).

Spills or leaks

The principal risk to surface water results from the potential transport off-site of material from spills or leaks. The measures discussed above in Section 5.2.1 will be implemented to ensure safe storage and handling of fuel and chemicals and appropriate management of initial production testing fluids. Spill containment and clean-up equipment would be present on site and any spills immediately cleaned up. Runoff from higher risk areas would be directed into the sump. Runoff from bunded fuel or chemical storage areas would be similarly contained and would not be allowed to drain off-site. The risk of flooding is considered in the location and construction of well leases, and if required, additional measures such as a small berm around the sump to prevent floodwater entering the sump may be implemented.

Well control and well integrity

Well control and well integrity risks are managed by a range of measures that are discussed in Section 5.2.3.

Waste management

Measures to ensure secure storage and handling of waste will be implemented as outlined in Section 5.2.1 and Section 3.4.2.

Risk assessment

The level of residual risk was assessed to be either low or medium (see Table 5.5).

Potential impacts to groundwater arise mainly from:

▪ drilling through aquifers ▪ well control incidents ▪ loss of well integrity (e.g. casing or cement failure); and ▪ depletion of GAB and sub-artesian water supplies.

Potential impacts to shallow groundwater arising from surface activities including fuel and chemical storage and handling and waste management and are discussed in Section 5.2.1. Well control issues associated with drilling operations have the potential to result in loss of containment of oil, gas, condensate, produced water, drilling fluids, possible crossflow between formations and depletion of pressure in aquifers and hydrocarbon reservoirs.

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Drilling through aquifers

Drilling fluids in the down hole environment have the potential to invade freshwater aquifers and cause contamination. Constituents of drilling muds are generally non-toxic or have a low effective chronic toxicity at the concentrations present in the drilling mud. A study on the impacts of drilling fluids in the down hole environment found that fluid loss is most likely to occur in the upper sections of the well, where unconsolidated sands and swelling clays are most common (Santos 2015). While there is a potential risk to freshwater aquifers from drilling fluids, contemporary mud systems with low weight are specifically designed to control losses in unconsolidated formations and minimise the potential for aquifer impact (Santos, 2015). Following drilling of the top hole, surface casing is installed and cemented into place, which isolates these freshwater aquifers from drilling fluids used to drill the deeper sections of the hole.

Well control incidents

A well control incident or blowout during drilling could result in a loss of containment of hydrocarbons and drilling fluids, possible crossflow between aquifers or loss of aquifer pressure and possibly an explosion or fire. There are considerable safety measures to avoid a blowout and they are rare particularly in areas such as the Pedirka, Cooper and Eromanga Basins where reservoir pressures are well understood in South Australia. All drilling operations will be carried out in accordance with regulatory requirements and approved well construction standards. The drilling rig will be equipped with fully functional and regularly tested blowout preventers. Guidelines, procedures, safety practices, design considerations, certification of trained individuals and an emergency response plan will be in place.

Well integrity

A loss of well integrity (through failure of the cement or casing in the well) could result in crossflow between aquifers, contamination of aquifers, reduction of pressure in aquifers and possibly the release of water, hydrocarbon and other reservoir gases if present (e.g. carbon dioxide, hydrogen sulphide) to the surface. The risk is restricted to as low as possible in the well design and construction process and managed through monitoring, during both drilling and the throughout the well’s life.

Measures undertaken to ensure well integrity include: ▪ design of the casing and well head to meet pressure, temperature, operational stresses and loads ▪ isolation of shallow aquifers behind casing strings that are cemented to the surface ▪ centring of casing with centralisers to assist full radial cement coverage ▪ monitoring of cementing operations to ensure that volumes returned to surface match calculations ▪ running of cement bond logs on production casing where applicable to confirm the quality of cement ▪ undertaking of remedial action where there is evidence of insufficient isolation; and ▪ ongoing well integrity monitoring.

Following a decision to abandon a well a specific well decommissioning program is developed and implemented, as discussed in Section 3.2.5. Cement plugs are installed in the well to isolate all aquifers and prevent cross flow, contamination or pressure reduction.

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Other downhole issues

Other hazards associated with down hole operations predominantly include issues that can affect drilling progress but generally have very limited environmental consequences, such as lost circulation, sloughing shales, stuck pipe or drill pipe failure.

A loss of a radioactive source down hole can also potentially occur. When the well is open hole logged after drilling, the neutron and gamma ray logging tools emit radiation into the formation and a receiver picks up the signal which is interpreted to relate the characteristics of the formation. If the tool is lost down hole, it is retrieved immediately in most cases. However, if it is not possible to retrieve the tool it is cemented in the hole to isolate it from adjacent formations.

Depletion of the GAB and sub artesian water supplies

Mining, petroleum and pastoral industries rely on GAB bores in the broader region for operational activities, particularly within the Simpson-Strzelecki Dunefields system to the east, with ongoing monitoring and maintenance of bore infrastructure and licensing of water supply key to maintaining a sustainable supply. Installation of any new water bores will be in accordance with all government regulations and licensing conditions as discussed in Section 3.4.1. Compliance with water licence and allocations will be adhered to where applicable. Impact assessments will be undertaken where proposed groundwater bore(s) are in the vicinity of surface water systems that may be baseflow dependent.

Risk Assessment

The level of residual risk was assessed to be either low or medium (see Table 5.5).

Potential impacts to vegetation and fauna arise from:

▪ earthworks for well lease, access track, borrow pits, camp site, and aircraft landing area construction and rehabilitation (e.g. vegetation clearance and soil excavation) ▪ disturbance from site activities (e.g. light, noise, presence of the drill rig, camp, aircraft landing area and personnel) ▪ introduction and spread of weeds and feral animals ▪ introduction of water sources and redistribution of gazing pressure ▪ presence of borrow pits ▪ use of roads and movement of heavy vehicles and machinery, and Increased accessibility to remote areas ▪ access to contaminants (e.g. from well control incidents, the drilling sump or spills and leaks) and waste; and ▪ fire.

Earthworks

Earthworks and clearing activities have the potential to damage vegetation and fauna habitats, and disturb, trap or injure fauna. Vegetation clearance may also impede the movement of fauna, particularly small mammals or reptiles across cleared areas. The clearance of narrow corridors for access tracks may also increase access for feral animals, including predators such as cats and foxes.

The clearance of vegetation during infrastructure construction activities cannot be avoided, but it can be minimised through locating infrastructure in naturally or previously cleared or disturbed areas where practicable. During the preparation of infrastructure sites (e.g. well leases, access tracks and an

Tristar Drilling EIR Rev0 93 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions aircraft landing area), particular care will be taken to minimise the clearance of vegetation in heavily wooded areas. Campsites and laydown areas will be located as far as possible in naturally sparse or clear areas in which site establishment does not require significant disturbance to vegetation. Large trees, high quality native vegetation and significant wetland areas will be avoided.

Well sites are subject to environmental assessment (see Section 2.1.2) in the planning process to ensure that any issues such as native vegetation, presence of listed species or risk of introduction of weeds are identified and appropriate avoidance or mitigation strategies are developed. As discussed in Section 5.2.2, activities will also be carried out to ensure surface drainage patterns and water quality are maintained, which will avoid potential indirect impacts to vegetation and fauna.

Disturbance from site activities

Potential disturbance to native fauna from site activities (e.g. light, noise, presence of the drill rig, camp and personnel) is short term, localised. The environmental assessment (see Section 2.1.2) undertaken during the planning process will identify whether there are specific issues at an individual well site (e.g. presence of listed species) and develop measures to avoid or mitigate potential impacts. Relevant agencies (e.g. DEW) will be consulted where required.

The presence of excavations and ponds on site (e.g. the drilling sump, turkey’s nest) also has the potential for localised impacts (e.g. entrapment) to fauna. The presence of site personnel and the fencing of ponds and the drilling sump following drilling will generally preclude impacts to larger species. Well sites are likely to be located in areas where there is limited habitat value for smaller species and their presence on the well lease is unlikely, however excavations will be regularly checked for trapped fauna to minimise potential impacts. Fauna proof fencing and egress ramps will be built into the sumps and storage ponds to limit accessibility by fauna. Large feral herbivores (e.g. camels) in the region may require the installation of sturdy fencing around ponds to mitigate access to water sources.

Introduction and spread of weeds and feral animals

The introduction of weeds and feral animals (particularly by earthmoving equipment) is a potentially significant impact to native flora and fauna and land use. A range of measures will be undertaken to manage the potential for the introduction or spread of weeds and feral animals, including:

▪ all reasonable and practical endeavours taken to minimise the risks of introducing weeds and pest fauna into the licence area ▪ environmental assessment (see Section 2.1.2) undertaken during the planning process will identify specific issues at an individual well site e.g. infrastructure locations (e.g. access tracks, well sites) are subject to site inspection by a suitably qualified person to identify the potential presence of weeds, and appropriate avoidance or mitigation strategies are implemented ▪ consultation with stakeholders and DEW where appropriate to identify any potential issues or specific management requirements ▪ ensuring that vehicles and equipment entering the licence area are clean and free of soil and plant material ▪ assessment of vehicles and equipment entering the region or moving between sites (especially from weed infested areas into non-infested areas) for the risk of transporting weeds and cleaning them down where appropriate ▪ monitoring sites and access tracks for new weed infestations, with treatment undertaken as necessary in consultation with landholders and DEW; and ▪ no domestic pets will be allowed at camps or worksites.

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Introduction of water source and redistribution of grazing pressure

The introduction of man-made water sources such as turkey’s nests and borrow pits may lead to a redistribution of grazing pressure as livestock (feral and domestic), native fauna and feral animals become attracted to the water source in the arid environment. This may also lead to trampling and grazing pressure on sensitive habitat. A range of measures will be undertaken to manage the potential for redistribution of grazing pressure, including:

▪ fencing to prevent or discourage feral animal and wildlife access to turkey nests and sumps ▪ large feral herbivores (e.g. camels) in the region may require the installation of sturdier fencing to mitigate access to water sources ▪ maintaining minimum pond freeboard ▪ fauna egress ramps are built into the sumps and storage ponds ▪ regular inspection of pit walls and repairs undertaken when and where required.

Borrow pits

Borrow pits may present a bogging hazard to wildlife. Borrow pits in some locations also provide an alternative water source which may result in a redistribution or increase in abundance of feral animals such as camels. Borrow material is generally not moved over large distances. However, there is the potential for weed species to be moved along with the construction material. Site selection, environmental management and restoration of borrow pits will be undertaken in accordance with industry-wide standards for borrow pit management developed by DEM (2014).

Use of roads and movement of heavy vehicles and machinery and increased accessibility to remote areas

The movement of vehicles and machinery along existing roads and access tracks has the potential to impact fauna, principally through collisions. This is likely to be relatively insignificant due to the level of existing traffic and the short-term nature of the activities. Transport procedures (e.g. speed restrictions, limitation of movements at night) will also reduce the potential level of impact. Movement to and from a well site can lead to damage of vegetation, generation of dust and/or compaction of soil.

The presence of roads can also increase the ease of access by third-parties to previously inaccessible sites (as discussed in Section 5.2.7), which has been observed to increase impacts from grazing and tourism visitation (Gillen and Reid, 2013).

Access to contaminants (e.g. from well control incidents, drilling sump, spills or leaks) and waste

The potential for fauna to access contaminants and waste is limited. The well site and sump will be fenced, as discussed above, and any contaminants from spills or leaks are likely to be confined to the area of the well lease and will be immediately cleaned up. Waste will be stored in covered bins before being transported off-site for disposal.

Fire

Fire initiated by site activities (e.g. flaring, sparks from vehicles or equipment) has the potential to impact large areas of vegetation. Measures will be in place to prevent fires including firebreaks, restriction of vehicles to tracks and cleared areas (unless involved in scouting activities), maintenance of suitable fire-fighting equipment on site and liaison with relevant stakeholders regarding fire conditions and management in the region e.g. DEW. Flare pits (if required) will be located to avoid radiant heat impacting or burning vegetation.

Risk Assessment

Tristar Drilling EIR Rev0 95 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

The level of residual risk was assessed to be either low or medium (see Table 5.5).

Pastoral operations are restricted to the bordering areas of the licence area. Potential impacts to operations on pastoral properties arise from:

▪ earthworks for well lease, access track, borrow pits, camp site, and aircraft landing area construction and rehabilitation (e.g. disturbance to soil, groundwater, surface water and vegetation) ▪ stock disturbance from site activities (e.g. light, noise, presence of the drill rig, camp and personnel) ▪ access to contaminants by stock (e.g. from well control incidents, the drilling sump, spills or leaks, waste) ▪ fire ▪ visual impact from disturbance of soil ▪ introduction and spread of weeds and feral animals; and ▪ presence of borrow pits.

Earthworks

Construction, use and rehabilitation of the well site, access track and camp site have the potential to impact land use through disturbance to soil, groundwater, surface water and vegetation within the footprint of the activity (as discussed in Sections 3.2 and 3.5). The measures discussed in these previous sections will be implemented to ensure that impacts are minimised and appropriate rehabilitation is undertaken.

Poor planning and execution of construction and rehabilitation activities also has the potential to impact land use beyond the activities’ direct footprint e.g. if well leases and access tracks are not sited to minimise disruption to overall property access and management.

Landholders will be consulted regarding the location, management and timing of proposed activities, with the aim of minimising disturbance. Ongoing liaison with landholders is carried out following drilling (and throughout the well’s life if it is successful). Any deterioration of property tracks or infrastructure as a result of drilling-related traffic will be rectified.

Disturbance from site activities (e.g. light, noise, presence of the drill rig, camp and personnel)

Drilling activities and transport moves have the potential to disturb and possibly injure stock. Consultation with landholders is undertaken to ensure that the location and timing of activities minimise the potential for impact. Measures in place to minimise impacts include speed limits, fencing of access tracks if required, positioning lighting to minimise light emanating from the site during drilling operations, avoidance of night transport moves as far as possible, and prompt removal of drill rigs and camps from site following the completion of operations.

Access to contaminants by stock (e.g. from well control incidents, drilling sump, spills or leaks, waste)

The potential for stock to access contaminants and waste is limited. The well site and sump will be fenced, as discussed previously, and any contaminants from spills or leaks are likely to be confined to the area of the well lease, and will be immediately cleaned up. Waste will be stored in covered bins before being transported off-site for disposal.

The loss of organic beef certification could occur on those properties that are certified for organic production if stock are allowed access to chemicals or contaminated areas (and if this is detected

Tristar Drilling EIR Rev0 96 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions during tissue tests or inspections by the certifying body). However, the petroleum industry has been working on organic certified properties in the wider region for many years without adversely affecting their organic status. Practices have been developed to protect the organic status such as fencing off any areas that may contain hydrocarbons (e.g. spills, drilling sumps), secure storage of hydrocarbons and chemicals and use of appropriate fencing materials (e.g. CCA-free treated pine). Similar practices will be developed in the Simpson and Pedirka Region, in consultation with landholders.

Fire

Fire initiated by site activities (e.g. flaring, sparks from vehicles or equipment) has the potential to significantly impact land use (e.g. via damage to pasture and infrastructure). Measures will be in place to prevent fires as discussed in Section 5.2.4.

Visual impact from disturbance of soil

Soil disturbance may lead to dust mobilisation and view scape modification leading to a perceived visual impact on the landscape. Measures will be in place to reduce potential visual impacts from soil disturbance, include:

▪ use existing tracks and disturbed areas where practicable in consultation with landholders ▪ well sites will be located to avoid significant cut and fill ▪ rehabilitation of construction areas as soon as possible ▪ restoration of borrow pits ▪ dust suppression measures carried out where required to minimise visual impact of activity; and ▪ systems are in place for logging landholder complaints to ensure that issues are addressed as appropriate.

Introduction and spread of weeds and feral animals

The introduction of weeds and feral animals by vehicles and equipment (particularly earthmoving equipment) is a potentially significant impact to pastoral properties and their use of the land. The measures discussed in Section 5.2.4 will be implemented to ensure these potential impacts are minimised.

Borrow Pits

The presence of borrow pits may lead to injury or loss of stock from poorly constructed and / or poorly maintained pits. Site selection, environmental management and restoration of borrow pits will be undertaken in accordance with industry-wide standards for borrow pit management developed by DEM (2014). Measures to reduce potential impacts to stock, include:

▪ ensuring pit locations have adequate clearance from infrastructure ▪ locations are not established in locations which pose an unacceptable hazard to stock ▪ erosion is controlled by appropriate placement, batter slopes and construction of water flow diversion banks ▪ borrow pits are restored to minimise water holding capacity, where arrangements are not in place with relevant stakeholders; and ▪ should a pastoral lessee request that a specific borrow pit be left unrestored, appropriate procedures will be followed.

Risk Assessment

The level of residual risk was assessed to be low (see Table 5.5).

Tristar Drilling EIR Rev0 97 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Petroleum exploration activities within the Regional Reserve have the potential to impact the remote and natural qualities of the area leading to potential impacts to visitor experience and Aboriginal cultural heritage values. Potential impacts to the values of the Munga-Thirri–Simpson Desert Regional Reserve may arise from:

▪ earthworks for well lease, access track, borrow pits, camp site, and aircraft landing area construction and rehabilitation (visual disturbance to soil and landforms) ▪ disturbance from site activities (e.g. light, noise, presence of the drill rig, camp, aircraft landing area and personnel) ▪ public safety risks due use of roads and movement of heavy vehicles and machinery ▪ potential for increased accessibility to remote areas due to creation of new roads ▪ potential for introduction and spread of weeds and feral animals ▪ introduction of water source and redistribution of gazing pressure ▪ presence of borrow pits ▪ potential impacts to culturally significant sites; and ▪ fire.

Earthworks

Construction, use and rehabilitation of petroleum infrastructure (e.g. well leases, access tracks and an aircraft landing area) has the potential to impact the aesthetic and wilderness values of the Region Reserve through disturbance to soil, groundwater, surface water and vegetation within the footprint of the activity (as discussed in Sections 3.2 and 3.5). Vegetation clearance may also impede the movement of fauna, or increase access for feral animals as discussed in Section 5.2.4.

The clearance of vegetation during infrastructure construction activities cannot be avoided, but it can be minimised through implementing measures discussed in Section 5.2.4. Wherever practicable, infrastructure will be located away from areas that are heavily used by visitors to the Regional Reserve. Well sites are subject to environmental assessment (see Section 2.1.2) in the planning process to ensure that any issues are identified and appropriate avoidance or mitigation strategies are developed

Ongoing liaison with relevant stakeholders (e.g. DEW and Wangkangurru / Yarluyandi People) will be carried out before, during and after petroleum activities to minimise potential impacts to the values of the Regional Reserve.

Disturbance from site activities (e.g. light, noise, presence of the drill rig, camp and personnel)

Drilling activities and transport moves have the potential to disturb tourists and DEW operations and personnel. Consultation with DEW will be undertaken to minimise the potential for these impacts. Measures in place to minimise impacts include speed limits, road signage, fencing of access tracks if required, positioning lighting to minimise light emanating from the site during drilling operations, avoidance of night transport moves as far as possible, and prompt removal of drill rigs and camps from site following the completion of operations.

Public safety risks due use of roads and movement of heavy vehicles and machinery

The use of roads for drilling operations has the potential to increase road hazards to other road users (e.g. DEW personnel and visitors to the Regional Reserve), and unauthorised or uncontrolled access to a well site, particularly during drilling, could expose members of the public to potential harm. Management measures detailed in Section 5.2.7 will be implemented to minimise potential hazards to other road users.

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Increased accessibility to remote areas due to creation of new roads

Signage to indicate public versus private roads and access tracks to discourage third-party access to infrastructure will be undertaken in consultation with DEW, and unauthorised off-road or off-lease driving, or creation of shortcuts will be avoided. Access tracks will be rehabilitated when no longer required to prevent unauthorised use by the public in consultation with DEW. Furthermore, measures detailed in Section 5.2.7 will be implemented to minimise hazards and third-party access of petroleum infrastructure.

Introduction and spread of weeds and feral animals

The introduction of weeds and feral animals by vehicles and equipment (particularly earthmoving equipment) poses a potentially significant impact to the values of the Regional Reserve. Measures discussed in Section 5.2.4 will be implemented to ensure potential for impacts are minimised.

Introduction of water source and redistribution of gazing pressure

The introduction of man-made water sources such as turkey’s nests may lead to a redistribution of grazing pressure as native fauna and feral animals become attracted to the water source in the arid environment. This may also lead to trampling and grazing pressure on sensitive habitat. Measures detailed in Section 5.2.4 will be undertaken to manage the potential for redistribution of grazing pressure.

Borrow Pits

The presence of borrow pits may lead to impacts to the values of the Regional Reserve e.g. aesthetic impacts, erosion and water source redistribution. Site selection, environmental management and restoration of borrow pits will be undertaken in accordance with industry-wide standards for borrow pit management developed by DEM (2014).

Potential impacts to culturally significant sites

Potential impacts to culturally significant sites, animals, bush tucker foods and landscapes mainly arise from earthworks during construction and rehabilitation activities. Management measures, including site cultural heritage field inspections with the Wangkangurru / Yarluyandi People, detailed in Section 5.2.8 will be implemented to minimise potential impacts.

Fire

Fire initiated by site activities (e.g. flaring, sparks from vehicles or equipment) has the potential to significantly impact the values of the Regional Reserve (e.g. via damage to vegetation and infrastructure). Measures will be in place to prevent fires as discussed in Section 5.2.4.

Risk Assessment

The level of residual risk was assessed to be either low or medium (see Table 5.5).

Potential impacts to public safety and amenity arise principally from: ▪ use of roads and movement of vehicles and heavy machinery and unauthorised site access ▪ disturbance from site activities (e.g. light, noise, presence of the drill rig, aircraft landing area, camp and personnel) ▪ generation of dust and air emissions; and

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▪ fire.

Use of roads and movement of vehicles and heavy machinery and authorised site access

The use of roads for drilling operations has the potential to increase noise disturbance to the community and can result in an increased road hazard to local road users. Use of roads and tracks for drilling operations, particularly unsealed roads or farm tracks can also cause damage or degradation.

Impacts of road use are generally short term, with peak traffic movements occurring during rig moves. Stakeholders will be informed of significant activities such as rig mobilisation and demobilisation. Warning signs and traffic management measures will be installed where appropriate near well sites. All necessary permits will be obtained for trucks transporting drilling and other equipment. Any deterioration of property tracks or infrastructure as a result of drilling-related traffic will be rectified.

Vehicles, especially trucks, also have the potential to cause a hazard to other road users. Rig moves for an oil and gas drilling rig typically involve 30-40 trailer loads for the rig and camp plus additional loads for supplies and equipment, as discussed in Section 3.2. However, these moves are infrequent and are usually staged over several days. Additional traffic on major roads due to petroleum exploration is not likely to be significant. Use of minor roads and tracks requires careful management (e.g. planning of routes, setting and observance of appropriate speed limits, use of signage where appropriate) in order to minimise the risk and potential disturbance to other road users and landholders.

Measures to mitigate the risks to the public will be put into place including signage, fencing, gates, access restrictions, speed restrictions, monitoring of speeds in industry vehicles, education programs and ongoing maintenance of roads and tracks.

Unauthorised or uncontrolled access to the well site, particularly during drilling, could expose members of the public to potential harm. Access to the site will be restricted during operations, the site will be fenced and “No entry” signage warning of dangers associated with drilling operations will be placed at the entry to the site access track. Following drilling, the well site will be fenced until rehabilitation is completed. Fencing and signage will be installed to prevent unauthorised access to the well head at any well that is successful.

The population density in the area is very low and most sites are likely to be relatively remote from public roads or accessed from roads and tracks with no public access. As discussed in Section 4.8.4, visitor use across the Munga-Thirri–Simpson Desert RR largely consists of well-equipped and self- sustaining groups possessing suitable four-wheel drive vehicles, with a crossing of the Simpson Desert typically taking several days (DEW, 2019a). Ongoing liaison with relevant stakeholders (e.g. DEW and Wangkangurru / Yarluyandi People) will be carried out before, during and after petroleum activities to minimise potential impacts to visitors of the Regional Reserve.

Disturbance from site activities

Disturbance from site activities (e.g. light, noise, presence of the drill rig, aircraft landing area, camp and personnel) can result in short term aesthetic impacts and disturbance to visitors of the region. A range of measures will be implemented to manage these potential impacts. Ongoing liaison with relevant stakeholders (e.g. DEW and Wangkangurru / Yarluyandi People) will be carried out before, during and after petroleum activities to minimise potential impacts to visitors of the Regional Reserve.

Furthermore, DEW will be consulted regarding the proposed activities, with the aim of identifying potential issues and minimising disturbance. Well site and access track construction will be restricted to daylight hours. Noise limitation during drilling (particularly at night) will be included as part of induction procedures (e.g. noisy tubular / pipe handling, unnecessary use of horns, reversing of

Tristar Drilling EIR Rev0 100 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions forklifts). Systems will be in place for logging stakeholder complaints to ensure that issues are addressed as appropriate.

Lighting will be positioned to minimise light emanating from the site during drilling operations. Flaring during production testing will be kept to the minimum length of time necessary. Drill rigs and camps will be promptly removed from site following the completion of operations, particularly in visible locations.

Generation of dust and air emissions

Generation of dust during site construction and use of unsealed roads and tracks can result in temporary and localised impacts to air quality. Dust generation will be minimised by restriction of speeds on unsealed roads and spraying of unsealed roads with water where required.

Emissions from fuel burning equipment, flaring and fugitive emissions from well operations have the potential to cause localised impacts to air quality and contribute to greenhouse gas emissions. Equipment will be operated and maintained appropriately in order to minimise emissions, and flaring during production testing will be kept to the minimum length of time necessary to establish resource parameters. Fugitive emissions will be minimised by maintenance of well integrity as discussed in Section 5.2.3.

Fire

Fire initiated by site activities (e.g. flaring, sparks from vehicles or equipment) has the potential to significantly impact landholders and the community through damage to property or possibly loss of life. Measures discussed in Sections 5.2.3 and 5.2.4 above will be implemented to manage fire risk.

Risk Assessment

The level of residual risk was assessed to be either low or medium (see Table 5.5).

As discussed in Section 4.7.1, while some sites and places are documented in the Register of Aboriginal Sites and Objects, there has not been a comprehensive survey of the Munga-Thirri–Simpson Desert CP and RR, and there are highly likely to be many undocumented sites present (DEW, 2019a).

Potential impacts to Aboriginal cultural heritage arise predominantly from earthworks during construction and rehabilitation activities. Detailed cultural heritage field inspections (typically termed Work Area Clearance (WAC) surveys) will be carried out with the Wangkangurru / Yarluyandi People, and any identified sites will be recorded, avoided and flagged or fenced where appropriate to prevent disturbance. Petroleum activities following these field inspections will be confined to surveyed areas. Cultural heritage issues will also be covered during inductions, and procedures will be in place to respond in the event that any sites are discovered or disturbed during activities.

There are no anticipated impacts to non-Aboriginal heritage, as no State or Nationally listed heritage sites exist within the licence area.

Risk Assessment

The level of risk to cultural heritage has been assessed as medium (see Table 5.5).

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Petroleum activities in the licence area have potential to cause both positive and negative economic impacts on landholders and other stakeholders e.g. DEW, tourists. Application of the measures discussed above to minimise environmental risk will minimise the potential for negative economic impacts.

Potential economic benefits for landholders, DEW, the community and the State, may include:

▪ well access tracks and ongoing maintenance of existing roads and tracks (where appropriate) are often of use to landholders as all-weather access tracks and may save construction costs to the landholder and enhance pastoral management ▪ potential for engagement of local contractors for activities such as earthworks and fencing ▪ potential for royalties to be paid if exploration and appraisal are successful and project economics are favourable, which benefits the State; and ▪ potential enhancements or increased maintenance to existing infrastructure such as roads and water bores (where appropriate in liaison with relevant stakeholders), dependent on success and ongoing activity.

As discussed above, Tri-Star has undertaken an environmental risk assessment of drilling operations in the Pedirka and Simpson Basins. This section outlines the process and results of the assessment.

The assessment of the level of environmental risk for drilling operations is provided in Table 5.5 below. The level of risk has been assessed based on the assumption that management measures discussed in this EIR will be in place.

The results of the risk assessment indicate that the majority of the risk levels for drilling operations are classified as either ‘low’ or ‘medium’ and no ‘high’ or ‘very high’ risks were identified.

This indicates that with appropriate planning and management environmental risks are not at an unacceptable level.

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Table 5.5: Environmental risk assessment for drilling, completion and initial production testing in the Simpson and Pedirka Regions, South Australia

Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk

Well lease, Impacts to soil (e.g. 2, 4, Consider alternate routes, locations and construction methods during planning and scouting Minor Unlikely Low access track, erosion, inversion, 8, 9, phase to minimise environmental impacts. borrow pit, compaction) 11 Use existing tracks and disturbed areas where practicable in consultation with stakeholders and camp site, and Vegetation clearance DEW. aircraft and excavation Liaise with DEM, DEW, the Wangkangurru / Yarluyandi People, and relevant stakeholders to landing area Visual impact from develop appropriate access to the licence area. construction disturbance of soil and and Ongoing liaison with relevant stakeholders (e.g. DEW and Wangkangurru / Yarluyandi People) to landforms rehabilitation minimise potential impacts to the values of the Regional Reserve. Impacts to Regional Construction activities are not carried out on salt lakes. Reserve remote and Well sites will be located and orientated so as to take into account natural drainage patterns and natural qualities / to minimise soil and vegetation removal, avoid significant cut and fill and consider accessibility to visitor experience the public. If well sites are in close proximity to the boundaries of Witjira NP or Munga-Thirri–Simpson Desert CP and indirect impacts are likely, consultation is undertaken with DEW to determine appropriate mitigation measures. Wherever practicable, infrastructure will be located away from areas that are heavily used by visitors to the Regional Reserve. Well sites are rehabilitated following drilling, or the lease area reduced to the minimum size necessary if the well is successful. Sensitive gibber terrain is protected through appropriate construction and maintenance practices wherever practicable. Rehabilitate construction areas as soon as possible. Manage borrow pits in accordance with industry-wide standards for borrow pit management developed by DEM (2014). Utilise existing borrow pits where practicable and appropriate. Dust suppression measures carried out where required. Landholders are consulted as required where activities may affect pastoral operations and notified prior to survey, construction and undertaking of operations (pursuant to Regulations). Induction of employee and contractor personnel with respect to pastoral and Regional Reserve operations including issues such as use of gates and infrastructure and restricted areas and activities.

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk Systems are in place for logging stakeholder complaints to ensure that issues are addressed as appropriate. Well lease, Disturbance to natural 6, Well leases, camp sites and access tracks are located and constructed to maintain pre-existing Minor Unlikely Low access track, drainage patterns, 11 water flows (e.g. channel contours are maintained on floodplains and at creek crossings). borrow pit, increased erosion and Sensitive land systems avoided wherever possible. Where activities are undertaken in or near camp site, and sedimentation of these areas, appropriate review, assessment and mitigation measures are in place to ensure that aircraft surface waters natural surface water flows are maintained, and contamination of surface water and groundwater landing area is avoided. construction Sediment and erosion control measures installed where necessary. and rehabilitation Any soil removed during the construction of the well lease will be respread over the disturbed area during restoration. Topsoil and subsoil will be stored separately. Restoration of natural contours to minimise impacts to natural drainage patterns. Manage borrow pits in accordance with industry-wide standards for borrow pit management developed by DEM (2014). Well lease, Introduction and 3 All reasonable and practical endeavours taken to minimise the risks of introducing weeds and Major Rare Medium access track, spread of weeds and exotic pest fauna into the tenement areas. borrow pit, feral animals Appropriate consultation regarding weeds carried out with landholders and DEW/SAAL NRM camp site, and Board. aircraft Environmental assessment undertaken during the planning process to identify specific issues at landing area infrastructure locations e.g. infrastructure locations will be subject to site inspection and construction assessment by a suitably qualified person to identify the potential presence of weeds, and and appropriate avoidance or mitigation strategies are implemented. rehabilitation Consultation with landholders and DEW where appropriate to identify any potential issues or specific management requirements. Weed identification training for grader operators and other relevant personnel to facilitate identification of track-side weeds and prevent spread along access routes. Vehicles and equipment entering the licence area must be clean and free of soil and plant material. Vehicles and equipment entering the region or moving between sites (especially from weed infested areas into non-infested areas) will be assessed for the risk of transporting weeds and cleaned down where appropriate. All records of vehicle or equipment inspections and cleaning will be kept for auditing.

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk Sites and access tracks will be monitored for new weed species / infestations and treated as necessary in accordance with requirements of the landholder, and if appropriate DEW/the SAAL NRM Board. Records of detection, monitoring or eradication of weeds introduced by activities are kept and available for review. No domestic pets allowed at camps or worksites. Feeding of wildlife is prohibited by employees/contractors. Well lease, Loss of native 2, 8 Minimise environmental impact by appropriate site selection to avoid sensitive land systems and Minor Unlikely Low access track, vegetation and fauna vegetation. borrow pit, habitats Suitably qualified people have inspected and assessed infrastructure locations to identify and flag camp site, and Disturbance to stock significant (or rare, vulnerable or endangered) species and communities. aircraft native fauna Native vegetation clearance minimised by locating well sites and access tracks appropriately. landing area Impacts to Regional construction Removal of large trees (including dead trees with hollows) is avoided except in exceptional Reserve remote, and circumstances (e.g. if unavoidable for airstrip construction). conservation and rehabilitation Where possible trim vegetation rather than clearing. natural qualities / visitor experience If threatened species are likely to be impacted, specialist advice is sought regarding measures to mitigate potential impacts. Undertake detailed assessments and EPBC Act referral where Disturbance to necessary. landholders Borrow pits are located in areas which are naturally devoid of vegetation as far as possible.

Clearance of vegetation, especially the removal of trees and larger shrubs, will be avoided wherever possible or minimised. Manage borrow pits in accordance with industry-wide standards for borrow pit management developed by DEM (2014). Utilise existing borrow pits where practicable and appropriate. Well sites will be located and orientated so as to take into account natural drainage patterns and vegetation and to avoid significant cut and fill. Facilities (e.g. well cellars) are designed and constructed as far as practicable to minimise impacts to fauna. Well sites are appropriately fenced to minimise fauna and stock access. Excavations (e.g. well cellar, flare pit) checked regularly for trapped fauna. Well cellar covers installed as soon as practicable following completion of drilling operations. Fauna egress ramps are built into the sumps and storage ponds.

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk Reinstate temporary construction areas (e.g. laydown) as soon as possible. Driving on designated areas only (i.e. lease and access tracks). Unauthorised off-road or off-lease driving, or creation of shortcuts is avoided. Signage to indicate public versus private roads and access tracks to discourage third party access to infrastructure. Airstrip located to minimise disturbance to landholders and the public. Protocols implemented to ensure landing area is clear of stock or wildlife (e.g. pre-landing inspection). Wherever practicable, infrastructure will be located away from areas that are heavily used by visitors to the Regional Reserve. Ongoing liaison with relevant stakeholders (e.g. DEW and Wangkangurru / Yarluyandi People) to minimise potential impacts to the values of the Regional Reserve. Well lease, Damage to existing 8 Landholders consulted regarding the location management and timing of proposed activities. Minor Unlikely Low access track, infrastructure Ongoing landholder liaison during and following operations. borrow pit, Disturbance to stock Activities are restricted to agreed / defined areas. camp site, and Disturbance to land use All gates left in the condition in which they were found (open / closed). aircraft landing area Dust generation Systems in place for logging stakeholder complaints to ensure that issues are addressed as construction Noise generation appropriate. and Compliance with Part 10 of the Petroleum and Geothermal Energy Act (Notice of Entry rehabilitation requirements). Well lease, Damage to cultural 1 Cultural heritage inspections and / or clearance will be undertaken with the Wangkangurru / Moderate Unlikely Medium access track, heritage sites Yarluyandi People. borrow pit, Consultation with stakeholders (i.e. native title groups, government agencies, landholders etc.) in camp site, and relation to the possible existence of heritage sites. aircraft Known sites identified and protected from operations (e.g. using temporary flagging). landing area construction Cultural heritage issues covered in inductions. Key personnel (e.g. supervisors, machinery and operators) receive appropriate cultural heritage training. rehabilitation Procedure in place for the appropriate response to any sites discovered during activities. Records of sites forwarded to the Aboriginal Heritage Branch in compliance with the Aboriginal Heritage Act. Records relating to sites of cultural heritage significance kept and available for audit.

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk

Well lease, Disturbance to fossils of 1 Assessment undertaken during the planning and WAC processes to identify potential presence of Minor Unlikely Low access track, significance fossils of significance and appropriate avoidance and / or mitigation measures are implemented. borrow pit, Infrastructure is placed appropriately to minimise the impact to known fossil sites. camp site, and aircraft landing area construction and rehabilitation Presence of Erosion 2, 4, Manage borrow pits in accordance with industry-wide standards for borrow pit management Minor Unlikely Low borrow pits Loss of visual amenity 9, 11 developed by DEM (2014). Injury / loss of stock Utilise existing borrow pits where practicable and appropriate. and native fauna Borrow pit locations have adequate clearance from infrastructure (e.g. facilities, fences, Introduction of water homesteads, roads) to minimise risk associated with livestock, safety concerns, erosion, and visual source and impacts. redistribution of grazing Borrow pits are not established in locations which pose an unacceptable hazard to stock or fauna. pressure. Erosion is controlled by appropriate placement, batter slopes and construction of water flow Attraction of feral diversion banks. animals Borrow pits are restored as soon as practicable after material extraction is complete, to a standard consistent with the surrounding land use. Where infrastructure (e.g. well leases) is being restored, borrow capping material returned to borrow pits where practicable. Borrow pits are restored to minimise water holding capacity, where arrangements are not in place with relevant stakeholders. Presence of Attraction of feral 2 Water stored in designated pits (e.g. turkey’s nest or sump). Minor Unlikely Low operational animals Quality control of pit construction including above ground earthen bunds where required to water sources Introduction of water prevent surface water ingress. (turkey nest source and Fencing turkey nests and sumps to prevent or discourage feral animal and wildlife access. and sump) redistribution of grazing Sturdy fencing installed around ponds where large feral herbivores are present. pressure. Fauna egress ramps are built into the sumps and storage ponds. Regular inspection of pit walls and repairs undertaken when and where required.

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk Turkey nests and sumps are restored to minimise water holding capacity, where arrangements are not in place with relevant stakeholders. Physical Visual impact 2, 8, Landholders consulted regarding notification, location and management of works and site issues Minor Unlikely Low presence of Disturbance to native 9 including livestock management. drill rig, camp fauna Training and induction of all personnel and visitors includes information on restricted areas and and personnel Disturbance to stock activities including Light Any lighting required is positioned to minimise light emanating from the well site. emissions (rig Disturbance to land use lighting, Impacts to Regional Flaring during production testing kept to minimum length of time necessary. flaring) Reserve remote and See Well site, access track and camp site construction and rehabilitation above. natural qualities / Appropriate site selection to reduce potential impacts to wildlife, pastoral residences or tourist visitor experience sites. Maintain a high standard of ‘housekeeping’ to minimise visual impact. Signage to indicate public versus private roads and access tracks to discourage third party access to infrastructure. Wherever practicable, infrastructure will be located away from areas that are heavily used by visitors to the Regional Reserve. Ongoing liaison with relevant stakeholders (e.g. DEW and Wangkangurru / Yarluyandi People) to minimise potential impacts to the values of the Regional Reserve. Air emissions Reduction in local air 7, 8 Equipment operated and maintained in accordance with manufacturer specifications. Minor Unlikely Low quality Flaring during production testing kept to minimum length of time necessary. Generation of Dust control measures implemented where appropriate e.g. road watering. greenhouse gas Note: Greenhouse gas emissions recorded and reported in accordance with NGER requirements. emissions Noise Disturbance to native 2, 7, Appropriate site selection to reduce potential impacts to wildlife, pastoral residences or tourist Minor Unlikely Low emissions fauna 8 sites Disturbance to stock Equipment operated and maintained in accordance with manufacturer specifications. Disturbance to third- Landholders are consulted as required where activities may affect pastoral operations. parties Systems in place for logging stakeholder complaints to ensure that issues are addressed as Impacts to Regional appropriate. Reserve remote and Wherever practicable, infrastructure will be located away from areas that are heavily used by natural qualities / visitors to the Regional Reserve. visitor experience

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk Ongoing liaison with relevant stakeholders (e.g. DEW and Wangkangurru / Yarluyandi People) to minimise potential impacts to the values of the Regional Reserve. Use of roads Injury or death of stock 2, 4, Transport trucks to be restricted to daylight hours as far as possible. Minor Unlikely Low and tracks; or fauna 8 Dust suppression measures carried out where required. movement of Dust generation Compliance with relevant speed restrictions on access roads and tracks. vehicles and Soil compaction heavy Warning signage and traffic management measures installed where appropriate indicate public machinery Noise generation versus private roads and access tracks to discourage third party access to infrastructure. Damage to third party Induction of employees and contractor personnel with respect to road use and driver behaviour, infrastructure conservation and tourism. Disturbance to third- Driver awareness training for all company and contractor personnel. parties Any required authorisations (e.g. DPTI, police) obtained where required for movement of rig Impacts to Regional along public roads. Reserve remote and Any deterioration of property tracks or infrastructure as a result of drilling-related traffic is natural qualities / rectified. visitor experience Driving on designated areas only (i.e. lease and access tracks). Unauthorised off-road or off-lease Road hazard / 7 driving, or creation of shortcuts is avoided. Major Rare Medium disturbance to local Landholders and other relevant stakeholders (e.g. DEW) will be informed of significant activities road users such as rig mobilisation and demobilisation. Systems in place for logging stakeholder complaints to ensure that issues are addressed as appropriate. Traffic management plan developed in consultation with DEW for activities in Regional Reserve. A traffic management plan will be provided to DPTI (as part of the Stage 3 approval process) for review prior to commencement of drilling activities. Appropriate traffic safety measures (e.g. pilot vehicles during rig moves) implemented. Reporting systems in place for recording injuries and accidents. Increased Introduction and 1, 2, See measures under Well lease, access track, borrow pit, camp site, and aircraft landing area Moderate Unlikely Medium accessibility to spread of weeds and 3, 11 construction and rehabilitation above. remote areas feral animals Liaise with DEM, DEW, the Wangkangurru / Yarluyandi People, and relevant landholders to by the public Damage to native develop and manage appropriate access to the licence area. vegetation and wildlife Signage to indicate public versus private roads and access tracks to discourage third party access habitats to infrastructure.

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk Damage to cultural Rehabilitate access tracks when no longer required to prevent unauthorised use by the public, in heritage sites consultation with DEM, DEW, the Wangkangurru / Yarluyandi People, and relevant landholders. Presence of Impacts to Regional 8, 11 Wherever practicable, infrastructure will be located away from areas that are heavily used by Minor Unlikely Low roads and well Reserve remote and visitors to the Regional Reserve. leases natural qualities / Ongoing liaison with relevant stakeholders (e.g. DEW and Wangkangurru / Yarluyandi People) to visitor experience minimise potential impacts to the values of the Regional Reserve. Rehabilitate roads and well leases where no longer required. Routine Crossflow, aquifer 5 Well integrity management: Minor Unlikely Low drilling contamination or Aquifers isolated behind casing string(s) cemented in place. reduction in pressure in Effective barriers exist to maintain well control and prevent crossflow between separate aquifer aquifers systems or hydrocarbon reservoirs. Operational reports verify that barriers have been set and/or remedial cement work carried out in accordance with the work program. Water based drilling muds are used. Chemical selection process demonstrates preferential selection of low toxicity chemical alternatives where appropriate. Well design in accordance with leading practice. Use of ‘fit for purpose’ equipment. Detailed engineering/drilling program. Regular inspections. Competent site personnel and contractors on site at all times. Continued competency assessment, education and training of individuals responsible for activities associated with drilling and workovers. Well control Contamination of soil, 4, 5, Drill rig, ancillary and any testing equipment to comply with Regulations, meet relevant industry Moderate Rare Medium incidents (e.g. groundwater and 6, 7 standards and be ‘Fit for Purpose’. blowout, kick) surface water Blow out prevention precautions in place in accordance with defined procedures and appropriate Crossflow, aquifer to the expected downhole conditions. contamination or Regular BOP drills, testing, certification, and maintenance. reduction in pressure in Well control equipment used during coiled tubing, wireline and workover activities where aquifers necessary. Uncontrolled release of Satisfactory kick tolerance in casing program design. water and

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk hydrocarbons to Work is performed as set out in the Drilling Program. surface Appropriate emergency response procedures in place. Injury / danger to Ready access to suitable fire-fighting equipment. health and safety of Restricted access to site. employees, contractors and possibly the public Continuous observation and procedures in place to detect problems while testing. Conduct regular inspections of pits, tanks, separators and sumps while testing. Consult with landholders to ensure appropriate practices are developed and implemented to mitigate risks and impacts to properties that are organic certified e.g. fencing off areas that may contain hydrocarbons or chemicals Damage to native 2, 7, Minor Unlikely Low vegetation and wildlife 8 habitats Access to contaminants by stock and wildlife Damage to property organic status Atmospheric pollution Impacts to Regional Reserve remote and natural qualities / visitor experience Other Contamination of soil, 2, 4, See measures above for Well control incidents. Minor Unlikely Low downhole groundwater and 5, 6, Preventative maintenance (i.e. inspections, pressure testing of equipment, repairs). drilling issues surface water 8 Competent site personnel and contractors on site at all times. (e.g. lost Crossflow, aquifer Continued competency assessment, education and training of individuals responsible for activities circulation, contamination or associated with drilling and workovers. sloughing reduction in pressure in shales, stuck aquifers Continual observation of circulating system during operations. pipe or drill Uncontrolled release of Appropriate emergency response plans in place. pipe failure) water and Appropriate emergency spill response equipment on site. hydrocarbons to Minimise fluid volumes on surface. surface

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk

Damage to native Leases are built to provide appropriate working platform. Negligible Rare Low vegetation and wildlife Water based fluid with minimum chemicals. habitats Impacts to Regional Reserve remote and natural qualities / visitor experience Loss of well Contamination or over- 2, 4, Well integrity management: Moderate Rare Medium integrity (e.g. pressurisation of 5, 6, Aquifers isolated behind casing string(s) cemented in place. casing or aquifers (resulting from 7, 8, Effective barriers exist to maintain well control and prevent crossflow between separate aquifer cement cross-flow) 11 systems or hydrocarbon reservoirs. failure) Contamination of soil, Operational reports verify that barriers have been set and/or remedial cement work carried out in groundwater and accordance with the work program. surface water Cement slurry and pumping schedule designed by qualified and competent engineers and Emissions to the confirmed by senior engineers. atmosphere Casing and well head designed to meet pressure, temperature, operational stresses and loads. Injury / danger to health and safety of Observed volumes of cement return to surface match calculations. employees, contractors Casing will be centred with centralisers to assist full radial cement coverage, mud cake will be and possibly the public removed to maximise cement bond to formation and excess cement volumes will be pumped to Damage to native cater for unforeseen cavities and over-gauge hole; and vegetation and wildlife Casing seating depths will be designed to cover formations at risk and the cementing programme habitats will allow for sufficient cement returns at surface to ensure bond to the formation. Access to contaminants Casing set in accordance with design parameters. by stock and wildlife Cement bond logs will be run as required. Remedial cementing will be undertaken where Damage to property required. organic status Appropriate emergency response plan in place and drills conducted. Impacts to Regional Well Decommissioning: Reserve remote and natural qualities / Well decommissioning program to be submitted to DEM with wireline logs for prior approval. visitor experience Downhole decommissioning is carried out to meet worst case expected loads and downhole environmental conditions. Isolation barriers to be set in place to ensure that crossflow, contamination or pressure reduction does not occur.

Tristar Drilling EIR Rev0 112 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk Effective isolation maintained between any potential aquifers to prevent crossflow. Abandonment plugs must be set to ensure long term isolation of any potential aquifers intersected to avoid shallow zones becoming over-pressurised. Records of plug depths and intervals are kept. Consult with landholders to ensure appropriate practices are developed and implemented to mitigate risks and impacts to properties that are organic certified e.g. fencing off areas that may contain hydrocarbons or chemicals Spills or leaks Localised 2, 6 Drilling: Moderate Unlikely Medium associated contamination of soil, Overflow of drill cuttings, muds and other drilling fluids from mud sumps, pits or tanks avoided with: surface water and (e.g. by adequate sizing, maintenance of freeboard and management of runoff / drainage from drilling groundwater the well lease). procedures Damage to native 4 Camp and drill rig generators to be appropriately located to contain any spills (e.g. in bunded Minor Unlikely Low and storage of vegetation and wildlife areas or with suitable alternative spill containment). drilling muds habitats Any escape of petroleum, processed substance, chemical or fuel to soil is either immediately and cuttings in Access to contaminants contained and removed or assessed in accordance with NEPM guidelines and remediated in a sump by stock and wildlife timely manner. storage of Conduct regular inspections of pits and sumps. fuel, oil and Damage to property chemicals organic status Flooding risk is considered in well lease location and construction and additional measures implemented if required (e.g. a small berm around the sump to prevent floodwater entering the aircraft sump). landing area operations Tank level sensors with continuous monitoring to detect small changes in fluid volumes. refuelling In the event of a spill or leak follow appropriate emergency response procedures. operations Competent site personnel and contractors on site at all times. and high- Continued competency assessment, education and training of individuals responsible for activities pressure associated with drilling and workovers. hydraulic systems Fluid losses will be controlled during drilling. initial Information on muds and chemicals to be readily available on the rig. production Fuel and chemical transport, storage and handling: testing / Transportation of chemicals, fuels and oils in accordance with ADG Code and AS1940-2017. flaring Construction and operation of filling systems, storage tanks and the tankers in accordance with AS 1940.

Tristar Drilling EIR Rev0 113 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk Continued competency assessment, review and monitor chemical and fuel transportation, including signage / labelling, storage, proper packing and tie downs. Appropriate areas (e.g. storage tanks, fuel and chemical storage) bunded and lined to contain spills in accordance with relevant standards and guidelines including AS 1940, EPA guideline 080/16 Bunding and Spill Management. Hazardous materials stored, used and disposed of in accordance with relevant legislation on dangerous substances. All hazardous materials including fuels, oils and chemicals are to be stored in approved containers in polythene lined bunded areas or on bunded pallets. No refuelling outside designated refuelling or servicing areas. Appropriate drip capture / spill capture methods implemented in refuelling areas (e.g. use of drip trays or liners). Appropriate spill response equipment is available on site. Personnel have received training in the use of spill response equipment. Immediate clean-up and remediation to minimise contamination to soil / water. Any escape of petroleum, processed substance, chemical or fuel to soil is either immediately contained and removed or assessed in accordance with NEPM guidelines and remediated in a timely manner. Spills or leaks are immediately reported to HSE manager. Fencing of affected areas if threat is posed to stock or wildlife, and consult with landholders to ensure appropriate practices are developed and implemented to mitigate risks and impacts to properties that are organic certified. Maintain a register of spills and / or leaks and implement corrective actions based on analysis of spill events. Logged incidents are reviewed and areas for improvement are identified for inclusion in future improvement plans. All contaminated soil treated on site in accordance with EPA guidelines or removed for treatment / disposal at an EPA approved facility. Assessment and remediation of uncontained spills with larger scale impact (e.g. release of fluid to land outside fenced areas, or any volume to water) is consistent with the NEPM and relevant SA EPA guidelines. Production testing / flaring: Production tanks to be located in lined bunded areas.

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk Production lines and tanks to be inspected prior to use. No fluids are disposed to the flare pit. Flare pit is only used for emergency well control situations while drilling and operated to avoid carry-over of unburnt hydrocarbons; immediate clean up implemented if it occurs. Unauthorised Danger to health and 7, 8 Access to sites restricted during operations. Moderate Rare Medium access by third safety of employees, “No Entry” signs warning of dangers associated with drilling operations placed at the entry to the parties contractors and site access track. possibly the public Drilling Supervisor and Drilling Contractor Manager given authority to refuse access by Damage to unauthorised third parties. infrastructure All minor excavations to be backfilled soon after rig release. Necessary measures (e.g. fencing, signage, gates) taken to prevent the public accessing the well head equipment or waste relating to the well. Necessary measures (e.g. fencing, signage, gates) taken to prevent the public and stock or fauna accessing the aircraft landing area where appropriate (see Well lease, access track, borrow pit, camp site, and aircraft landing area construction and rehabilitation above). Effective rehabilitation of the well site includes removal of infrastructure extruding above ground level. Fire (resulting Loss of vegetation and 2, 7, Fire and Emergency Services Act requirements will be complied with, (e.g. permits for ‘hot work’ Moderate Rare Medium from habitat 8 on total fire ban days). activities) Disturbance, injury or Safety, testing, maintenance and inspection procedures are implemented. death of fauna Ready access to suitable fire-fighting equipment. Atmospheric pollution Where necessary fire break constructed around well lease. Damage to Flare pits (if required) will be located to avoid radiant heat impacting or burning vegetation. infrastructure Response to fire included in Emergency Response Plan. Disruption to land use Ensure fire risk is included in the induction and all personnel are fully informed on the fire danger Danger to health and season and associated restrictions. safety of employees, Personnel are trained to supervise and instruct individuals entering lease to conduct work. contractors and possibly the public Continued competency assessment, education and training of individuals responsible for activities associated with drilling and workovers. Impacts to Regional Reserve remote and Hazardous area management / equipment spacing criteria is followed. No smoking or safe smoking areas away from equipment or well.

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk natural qualities / Ongoing liaison with relevant stakeholders regarding fire conditions and management in the visitor experience region e.g. DEW. Storage, Localised 2, 4, Application of the waste hierarchy (avoid, minimise, reuse, recycle, recover, treat, dispose). Minor Unlikely Low handling and contamination of soil, 6, 8, Remove waste to minimise visual impact. disposal of surface water and 9, 10 Covered bins are provided for the collection and storage of wastes. All loads of rubbish are waste groundwater covered during transport to an approved waste facility. Damage to vegetation Waste streams are segregated on site and transported to appropriate facilities to maximise waste and habitat recovery, reuse and recycling. Attraction of Hazardous wastes handled in accordance with relevant legislation and standards. scavenging animals (native / pest species) Appropriately licensed contractors used for waste transport. and access to All wastewater disposed in accordance with the South Australian Public Health (Wastewater) contaminants by stock Regulations 2013 or to the satisfaction of the Department of Health) and consistent with the and wildlife Environment Protection (Water Quality) Policy 2015. Impacts to property Fencing installed where required around irrigation areas. organic status Approved transportable wastewater treatment plants used for rigs / camps. Litter / loss of visual Appropriate controls for management of sewage effluent (developed in consultation with amenity Department of Health) implemented for situations where excursions outside effluent quality Impacts to Regional guidelines may occur. Reserve remote and Any escape of petroleum, processed substance, chemical or fuel to soil is either immediately natural qualities / contained and removed or assessed in accordance with NEPM guidelines and remediated in a visitor experience timely manner. Consult with landholders to ensure appropriate practices are developed and implemented to mitigate risks and impacts to properties that are organic certified e.g. fencing off areas that may contain hydrocarbons or chemicals. High Standards of ‘housekeeping’ implemented. Groundwater Depletion of GAB and 2, 5, Minimisation of groundwater use during drilling and workover operations by minimising sump Moderate Rare Medium use sub-artesian water 8 sizes and recirculating water. supplies Compliance with water licence and allocations where applicable. Impacts to other users Lining of all temporary storage ponds to reduce the potential for loss of water to seepage. Installation of any new water bores will be in accordance with NRM Act requirements. Consultation with other groundwater users/bore owners.

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Activity / Potential SEO Management Strategy Consequence Likelihood Residual Event Environmental Impacts Obj Risk Impact assessment where proposed groundwater bore(s) are in the vicinity of surface water systems that may be baseflow dependent.

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This section discusses potential environmental impacts (or perceived impacts) related to fracture stimulation activities in the PELs.

The discussion is supported by an environmental risk assessment. The risk assessment is summarised in Table 5.6 (in Section 5.3.12), which outlines the key hazards, management measures and resulting level of risk.

The following discussion summarises the management measures that will be implemented, with the detail provided in Table 5.6. Sections 5.3.1 to 5.3.5 address aquifers and sections 5.3.6 to 5.3.11 address hazards at the surface. Reference is made to the results of the risk assessment where relevant throughout the discussion.

A loss of well integrity could result in the leakage of fracturing fluids or hydrocarbons to aquifers or production of water from the aquifer when the well is flowed. The risk is reduced to as low as possible in the well design process and construction process and managed through operational monitoring.

In particular: ▪ the well design and construction provides the mechanical integrity that reduces this risk to as low as possible ▪ pressure testing demonstrates production casing integrity ▪ cement bond logs are run where required to review quality of the production casing cementing operation that is pumped into the production casing-wellbore annular space ▪ pressure safety trip out systems during the fracture stimulation prevent pressure limits of the surface pipework and downhole casing equipment being exceeded ▪ continuous pressure monitoring during the fracture stimulation treatment enables precautionary equipment shut down if abnormal pressure responses are recorded.

The well design and construction process considers stresses and loads associated with temperatures, pressures and fluids that may be pumped into and produced throughout the life of the well. The casing, production and well head equipment is purchased from established API certified suppliers that have demonstrated their ability to supply the materials that meet or exceed the design specification with appropriate supporting certification documents.

During construction of the well, casing strings are cemented into the bore hole. In addition to anchoring the casing string into the bore, the function of the cement is to provide a barrier to fluid migration between the casing and borehole isolating aquifers and hydrocarbon bearing intervals. Cement design, casing centralisation in the well bore and correct cement pumping procedures are important for achieving good quality cementing and isolation of the formations. This maximises the potential for technical success of the well to mitigate migration of fluids behind casing. Experienced petroleum industry personnel supervise the on-site well construction operations, including installation and cementing of casing strings, well head equipment is correctly undertaken as per the program.

At completion of the production casing cement displacement, the wellbore is pressure tested to confirm the pressure integrity of the casing and cement at the base of the well. Prior to stimulation, additional pressure testing of the wellbore may be conducted to maximum designed pumping pressure (using water).

A cement bond log (CBL) may be run after a well is cased and suspended to provide an indication of the production casing cement quality. The log may assist with understanding production results in the

Tristar Drilling EIR Rev0 118 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions event that unexpected production characteristics develop. If anomalous CBL results are recorded and pending further testing and evaluation, remedial work may be performed on the production casing to reduce the risk of communication with aquifers.

Pressure controls are fitted to the pumping equipment that limit the maximum pumping pressure and will automatically shut down the pumps when a pre-set operational maximum pressure is reached. This limit is set below the design rating of the casing and wellhead equipment to avoid over pressure of the system.

Continual monitoring of wellhead pressures is carried out during fracture stimulation to understand how the injection is progressing. If a significant pressure anomaly is observed at surface during the stimulation treatment, this may indicate that well integrity has been compromised. This may arise due to faulty casing material or errors during making up the casing connections while running the casing. As discussed in the well design section, the choice of casing size, weight and connection type, the use of new casing from a reputable supplier and adequate supervision while running the casing reduces the risk of this type of breach.

In the event that the injection pressure does not appear to be correct for the zone being stimulated, the stimulation treatment will be suspended and the data reviewed to assess the implications. If it is determined that a breach has occurred and depending on the location of the breach, the well may be repaired with a casing patch or other isolation method if required. Alternatively, if the zone is below other intervals proposed for stimulation, the stimulation may progress in the upper zones foregoing the intervals deeper in the well. If the zone is significantly higher in the well and there is no suitable way to isolate the interval and successfully stimulate the lower intervals, the well may be decommissioned with appropriate plugs set to isolate intervals as required by the regulations.

Growth of fractures out of the target zone and into an adjacent or overlying aquifer could result in leakage of fracture fluids, formation water and hydrocarbons into the aquifer (although it is noted that aquifers or water-bearing units proximal to oil reservoirs typically contain hydrocarbons and are not suitable for domestic or agricultural use). It could also result in flow from the aquifer into the reservoir when the well is flowed to the surface.

Fracture growth into a water bearing zone is undesired during fracture stimulation, as it would result in the well flow being dominated by water and thus uneconomic. Potential fracture stimulation targets are excluded if there is an identified water risk apparent due to underlying or overlying aquifers that cannot be mitigated (e.g. by alteration of the stimulation design).

Operator experience stimulating oil bearing formations in the Eromanga Basin indicates treatments typically only require smaller volumes of proppant and lower pump rates which limits fracture network complexity. As discussed in Section 3.3, prior to operations each stage is modelled using specialist software to provide confidence that the treatment will be confined to the target zone. In most cases Eromanga Basin stimulation treatments are not expected to grow out of the target reservoir as the Eromanga sands are often confined by underlying and overlying siltstones, shales and coals which act as natural barriers and limit the potential for fracture propagation outside of the target formation. However, where modelling indicates that propagation outside of the target zone poses an unacceptable environmental risk, the target will be excluded from the program.

During stimulation operations, treatment volumes and pressures are monitored in real time. A drop- in surface treating pressure could indicate out of zone fracture growth which would trigger immediate shut down. As noted, prior to stimulation operations, treatments are modelled to ensure that fracture growth does not extend into adjacent formations where adverse impacts to aquifers may be a risk.

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Validation of treatment modelling is achieved by comparing model results with field treatment monitoring results. Field monitoring methods are discussed in in Section 3.3.3.

Stimulation treatments in deeper formations (within the Simpson and Pedirka Basin) may be designed to treat a thicker package of reservoir. As discussed in Section 4.5, both the Simpson and Pedirka Formations have numerous barriers to fracture height growth out of formation, multiple shales, coals and siltstones between that isolate these basins from the overlying Great Artesian Basin. Where modelling indicates that propagation outside of the target zone poses an unacceptable environmental risk, the target will be excluded from the program.

Figure 5-1 is a schematic showing stratigraphy, fracture extent and geological controls provided by adjacent formations

Mackunda Formation

Cement

Steel Casing

Allaru Mudstone Casing Shoe Up to 500m Up to thick

Casing Shoe

Toolebuc Formation

50m Perforations

Wallumbilla Formation

EromangaBasin

thick Up to 250m Up to

Cadna-Owie Formation

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Algebuckina Sandstone

Cement

Steel Casing

Poolowanna Formation Up to 1,000m Up to thick EromangaBasin Perforations

Coal Seams act as stress barrier to fracture propogation

Peera Peera Formation

Perforations

Walkandi Formation

Up to 300m Up to thick SimpsonBasin

Purni Formation

Perforations

Crown Point Formation

Up to 300m Up to thick PedirkaBasin

Warburton Pre-Permian Basement Basin Figure 5-1: Indicative Fracture Stimulation schematic showing stratigraphy, fracture extent and geological control provided by adjacent formations

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Leakage of stimulation fluids to aquifers through the overlying strata (via transmission through aquitards or faults) is not considered a significant hazard for fracture stimulation.

The rate of flow through a low permeability aquitard overlying the fracture stimulation treatment would be very slow and result in negligible net movement away from the treatment. Pressure gradients to potentially drive such leakage would typically exist only during the stimulation operation, and once flowback commences, the pressure gradient underground will result in fluids moving towards the well rather than away from the fracture stimulation.

Fault structures can be identified with seismic surveys, and stimulation treatments can be avoided in proximity to faults. Suitable pressure and permeability conditions would also be necessary for fluids to flow along any faults. Given the pressure gradients resulting from hydrocarbon production, it is unlikely that sufficiently high upwards pressures required for fluids to flow along any faults would develop and/or be sustained.

Lateral migration of any significant quantities of injected fluids away from the fracture treatment zone is considered highly unlikely, as once the fracture stimulation treatment has been completed, the well is flowed back, creating a pressure differential and a flow path from the end of the fracture treatment to the well. This pressure differential increases into the production phase of the well as production of reservoir fluids continues. Consequently, injected fluids would flow back to the well. A pressure gradient to drive lateral migration would likely not exist.

Where possible, fracture stimulation will use recycled water (e.g. recovered fracture stimulation fluids).

Where groundwater extraction for fracture stimulation is required, it will be undertaken within the regulatory framework of the Natural Resources Management Act. Appropriate authorisations will be in place for drilling and extraction of groundwater. Landholders will be consulted regarding water well locations and water use, and proposed water supply wells will be assessed to ensure that their use does not impact adversely on existing users of groundwater. Where potential impacts are identified, further assessment, consultation with the well owner and monitoring would be carried out to ensure that significant drawdown or impacts are avoided or mitigated.

Extraction of large volumes of water from aquifers that provide baseflow to nearby waterholes (e.g. aquifers in sandy sequences underlying and adjacent to the Kallakoopah Creek) will be avoided.

Water use for fracture stimulation will be in accordance with the Far North Prescribed Wells Area Water Allocation Plan, and broadly applicable guidelines such as APPEA and API guidelines (e.g. APPEA 2011, API 2010).

Potential impacts to soil and shallow groundwater during fracture stimulation activities include: ▪ spills or leaks from the storage and handling of fuel or chemicals ▪ spills or leaks from the sourcing and storage of water in preparation for stimulation ▪ spills or leaks from handling and storage of flowback fluids at the surface ▪ storage and transport of waste.

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Chemicals and fuel on site will be stored and handled in accordance with relevant standards and guidelines. Any spills will be immediately cleaned up and contaminated material removed off-site for appropriate treatment or disposal.

As discussed in Section 3.2.9, temporary storage tanks or lined ponds will be used to contain fluid associated with fracture stimulation events depending on the volume used (i.e. shallow, small fluid volume programs will use mobile tanks, and deep, unconventional programs with high water volumes will adopt temporary above-ground, lined storage ponds). Quality control during construction of ponds for water / flowback storage will minimise the risk of liner breaches. Fencing will be installed to prevent large fauna and livestock from entering the ponds and damaging the liners. Regular monitoring of the pond and fence condition, operating the ponds with adequate freeboard and construction with above- ground walls that prevent surface runoff into the ponds all minimise the risk of seepage or release from the pond.

The water used for fracture stimulation can be fresh, brackish or saline. Chemicals are generally not added to stored bore water, however low levels of hydrocarbons or other chemicals (e.g. biocides) may be present if recycled water from evaporation ponds is being used. Should a spill or leak of pre- stimulation water occur, the short-term nature of utilisation, the general absence of added chemicals and the remoteness from sensitive receptors or sensitive land uses indicate that there will be negligible to minor impacts on the soil and shallow groundwater.

If a spill or leak from a pond occurs while it contains flowback fluids, containment and clean-up measures would be implemented. Where necessary and possible, escaped fluid may be recovered, (e.g. using a drainage channel to collect the fluid). In the event of a major spill or leak, affected areas would be fenced off and assessed, rehabilitated and monitored, in consultation with DEM and EPA where appropriate.

In terms of potential impacts to shallow groundwater, the water table in much of the region, where present, is generally not close to the surface, and is predominantly brackish to saline. There is very low population density and very limited use of shallow groundwater. Many of the fracturing fluid additives are biodegradable. The rate of transport of any spilt contaminants to shallow groundwater (if present) is also likely to be limited by the low rainfall and high evaporation in the region and the relatively low permeability of the clay soils that are present at many locations. Consequently, minor seepage from a pond, if it occurred, would be expected to have a low level, localised impact. A large release (e.g. due to pond failure) could affect a larger surface area and result in a moderate level consequence but is considered unlikely.

An equipment failure or leak during stimulation could result in fracturing fluid being released to the lease area. Equipment design, pressure testing and shut down systems reduce the risk of leaks to a very low level. In the unlikely event of a failure, the equipment is quickly shut down from the control van, reducing the volume of the spill to minor amounts.

Storage of waste and transport to licensed disposal facilities will be undertaken in accordance with relevant legislation and guidelines. Waste generation will be minimised where practicable, waste will be stored securely, and appropriately licensed waste contractors will be used for waste transport.

Potential impacts to surface water arise mainly from: ▪ spills or leaks from the storage and handling of fuel or chemicals ▪ storage and transport of waste ▪ spills or leaks from handling and storage of flowback fluids at the surface ▪ spills or leaks from the sourcing of and storage of water in preparation for stimulation

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▪ flooding of well leases during fracture stimulation operations.

Prior to undertaking fracture stimulation operations, site-specific assessments against the SEO will be submitted to DEM to demonstrate that the environmental objectives can be met, including the SEO requirement to avoid contamination of surface waters. The site-specific assessments will indicate risks identified at individual well locations and management strategies required to mitigate these risks to meet the objectives.

Measures to ensure safe handling and storage of fuel, chemicals, flowback fluids and waste will be implemented, as discussed in Section 5.3.6.

Several fluid additives (e.g. biocides) have relatively high toxicity to aquatic organisms. Although many of these additives are biodegradable and would be either degraded in the formation or break down further over time, a large release or spill to surface waters would require significant dilution to reduce contaminants to below harmful levels and could result in impacts beyond the immediate area of operations. Such an escape of large volumes could result from structural failure of flowback ponds or significant flooding such that a pond is inundated.

Pond design, location, construction, operation and monitoring would reduce the risk of structural failure such that it is a very unlikely event. If well leases are located in areas where infrequent minor flooding may occur, measures will be undertaken to ensure that any ponds are not vulnerable to flooding (e.g. location of ponds on higher ground).

To mitigate the risk of fluid release due to flood inundation, well leases will not be located in areas where frequent flooding is likely. If well leases are to be located in areas where infrequent minor flooding may occur, measures will be undertaken to ensure that ponds are not vulnerable to flooding (e.g. ponds may be located on higher ground and/or pond walls constructed higher above grade at these locations).

Flooding of the well lease while fracture stimulation is being carried out could result in localised contamination from fuel and chemicals held on site. Short term (1-2 weeks), shallow and localised flooding due to localised high rainfall events is unlikely to result in significant risk as the stimulation activity is ceased in advance of storm weather and materials would be appropriately secured.

The mitigation measures discussed above, particularly in regard to the location of ponds and well sites, indicate that the likelihood of release of flowback fluid to surface water can be reduced to a very low level.

Potential impacts to native vegetation and fauna arise from: ▪ spills or leaks from the storage and handling of fuel or chemicals ▪ spills or leaks of flowback fluids ▪ interaction with fluid storage ponds ▪ use of roads and movement of vehicles and heavy machinery ▪ activity outside designated / approved areas storage and transport of waste.

Safe handling and storage of fuel, chemicals, flowback fluids and waste will be implemented, as discussed in Section 5.3.6.

Measures including fencing of ponds, manning of sites during stimulation operations and immediate clean-up and containment of spills will minimise stock and native fauna access to flowback fluids. Based

Tristar Drilling EIR Rev0 124 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions on experience with similar ponds used for holding raw water for drilling or fracturing or for treatment of produced formation water, entrapment of fauna in ponds in the neighbouring Cooper Basin is a very rare occurrence. However, the presence of potentially high numbers of feral herbivores (e.g. camels) in the region may require the installation of sturdier fencing to mitigate access to water sources.

Due to the nature of the ponds (relatively steep sided and lined with plastic, with no ‘beaches’, vegetation or food sources) visitation by birds is expected to be restricted to relatively small numbers for relatively short periods of time. Concentration of additives of highest concern for fauna (e.g. biocides) is expected to be below levels that pose a significant risk for birds coming into short term contact with flowback fluids. The pH of flowback fluids is expected to be relatively neutral, as acids are neutralised in the fracturing process. If necessary, additional measures to discourage bird use can be implemented, which may include installation of flagging or other devices to discourage bird presence.

A spill of flowback fluid associated with a pond breach may affect vegetation (should it extend beyond the lease area) and indirectly stock and fauna that may enter to feed. As discussed previously, the construction, operation and monitoring of ponds reduces the likelihood of a breach occurring to a very low level. Containment, clean-up and fencing of the spill area would be implemented to prevent stock and fauna access to contaminants.

Fracture stimulation operations will likely result in a short term and localised increase in traffic volumes, which could increase the risk of collisions with stock and native fauna. Measures to mitigate the risks are part of standard operating procedures for Tri-Star and include speed restrictions, monitoring of speeds in industry vehicles, driver education programs and restriction of transport movements to daylight hours as far as practicable.

The potential for radioactivity resulting from Naturally Occurring Radioactive Materials (NORM) that are brought to the surface is perceived as a potential issue for fracture stimulation activities. Based on previous experience with Cooper Basin petroleum operations, levels of radioactivity associated with NORM in flowback of fracture stimulation fluids are not expected to be significant and are expected to be well below any levels of concern. NORM are usually only a potential issue when they are concentrated (e.g. by the formation of mineral scales or sludges over time in tanks, piping and facilities).

Radioactive tracers (proppant beads impregnated with isotopes), if used, are generally retained in formation along with the remainder of the proppant. They have a short half-life and rapidly degrade. Very little is returned to surface and would be at very low concentration and settle out into the lined pond. Appropriate protocols (e.g. risk assessment, monitoring where required) will be implemented where radioactive tracers are used to confirm that radiation levels are well below any levels of concern. All radioactive materials will be handled in accordance with relevant legislation and guidelines (e.g. Radiation Protection and Control Act 1982).

Chemical tracers, if used, are non-hazardous and used in very low concentrations. In flowback they are expected to be less than 250 parts per billion in total within the flowback fluid.

The induction of seismic events (i.e. micro-earthquakes) as a result of petroleum exploration and fracture stimulation is sometimes perceived as a potential issue. It is not considered that a credible risk is presented by these activities being undertaken in the Simpson and Pedirka Regions.

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Fracture stimulation has been carried out in the Cooper Basin for over 40 years without any issues related to seismicity. Fracture stimulation of the Holdfast-1 well in PEL218 in 2011 did not register on the seismic monitoring equipment at Geodynamics’ nearby Habanero site. Micro-seismic monitoring may be used at some well locations as part of the resource assessment and will be available to delineate seismic response.

Drummond (2016) concluded issues of concern flagged by the public can be mitigated through the use of leading industry practice. Key points relating to seismicity summarised by Drummond (2016) include: ▪ The water volumes used during hydrofracturing11 are typically small compared to other uses in rural and regional areas. The volumes injected during hydrofracturing are insufficient to cause significant earthquakes; indeed the science underpinning hydrofracturing indicates that the earthquakes should be very small, consistent with observations. ▪ Environmental issues associated with the surface footprint of hydrofracturing activities are not linked with induced seismicity. ▪ Seismicity induced by deliberate hydrofracturing usually has zero or negative magnitudes. It will not be felt and will not be damaging. Larger earthquakes can occur through the reactivation of faults by reinjecting large volumes of waste water. This can be mitigated through management of formation pressures.

Drummond (2016) provides a table that captures parameters for induced seismicity using numerous references and case studies to form conclusions. Based on available data, in the unlikely event fracturing of intact rock caused an earthquake, maximum magnitudes are usually ≤ 0 and occur within a few hundreds of meters of the well spreading radially with time. In the unlikely event a fracture stimulation causes fault reactivation, maximum magnitudes are usually M ≤ 0 in shales and typically occur at the edges of the fractured volume. Such events occur in linear patterns hundreds of metres long aligned with existing faults that are usually optimally or near optimally aligned with stress fields.

In both occasions, it is highly unlikely the seismic event will be felt at surface.

The level of risk has been assessed as low (refer to Table 5.6).

Measures to mitigate the risks to the public include signage, fencing, access restrictions, speed restrictions, monitoring of speeds in industry vehicles, education programs and ongoing maintenance of roads and tracks, as discussed in Section 5.2.7.

The population density in the area is very low to nil and most sites are likely to be relatively remote from public roads and accessed from roads with no public access.

Noise and air emissions from the well sites during fracture stimulation will be localised and short term and are not likely to have a significant noise or air quality impact. There are no homesteads within the tenure area.

11 For the purposes of this report, hydrofracturing and fracture stimulation are equivalent terms.

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As discussed above, Tri-Star has undertaken an environmental risk assessment of fracture stimulation activities in the Pedirka and Simpson Basins. This section summarises the process and results of the assessment.

A summary of the level of environmental risk for fracture stimulation activities is provided in Table 5.6 below. The level of risk has been assessed based on the assumption that the management measures outlined in this EIR will be in place.

The results of the risk assessment indicate that the majority of the risk levels for drilling activities are classified as either ‘low’ or ‘medium’. This indicates that with appropriate planning and management environmental risks are not at an unacceptable level.

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Table 5.6: Environmental risk assessment for fracture stimulation in the Simpson Pedirka Regions, South Australia

Activity / Event Potential Environmental SEO Management Strategy Consequence Likelihood Residual Impacts Obj Risk

Loss of well Leakage from / to aquifers 4, 5, 6 Aquifers isolated behind casing string(s), cemented in place. New casing and Moderate Rare Low integrity Loss of aquifer pressure and wellhead installed on new wells contamination of aquifers Casing and wellhead and cement slurry designed to meet pressure, temperature, Contamination of soil, operational stresses and loads groundwater and surface Cement bond logs run where applicable to check quality of cement water Well pressure tested prior to stimulation Emissions to the High pressure stimulation equipment has valid certifications, is properly secured atmosphere and is pressure tested once set-up, prior to commencement of stimulation Injury / danger to health 7 Stimulation pumping pressures do not exceed design safety factors Major Rare Medium and safety of employees, Trip systems to shut off pumping units during stimulation contractors and possibly the Injection pressures are monitored and compared to expected fracture initiation public pressure. If significantly lower initiation pressure, stop job and assess for potential casing integrity failure Emergency response plan in place and drills conducted Fracture Loss of aquifer pressure and 5 Fracture design (including pressures, injectate rate, fluid makeup and proppant Moderate Rare Low propagation contamination of aquifers concentration) undertaken to provide confidence that the fracture treatment from Eromanga Adverse impacts to remains within the hydrocarbon target Basin targets groundwater users and Fracture stimulation treatments will be modelled prior to treatment into adjacent groundwater resources Fracture stimulation candidates are excluded where water risk is apparent due to GAB aquifers close proximity to overlying aquifers Real time pressure monitoring during treatment Where pressure monitoring suggests loss of zonal containment, operation will be shut down Fracture Contamination of aquifers 5 Physical separation between targets and overlying GAB aquifers Minor Rare Low propagation Indirect adverse impacts to Minimal connecting faulting noted on seismic acquired throughout the basin from Simpson, groundwater users and Pressure differential between GAB aquifers and target reservoirs indicates no Eromanga or groundwater resources communication Pedrika Basin targets into Modelled stimulation treatments demonstrate containment of height growth overlying GAB within acceptable limits between hydrocarbon targets and any GAB aquifers aquifers Real time pressure monitoring during treatment to identify containment

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Activity / Event Potential Environmental SEO Management Strategy Consequence Likelihood Residual Impacts Obj Risk Geological risk assessment undertaken as necessary Leakage of Contamination of aquifers 5 Target intervals separated from overlying GAB aquifers by interbedded sandstones Minor Unlikely Low injected fluids Indirect adverse impacts to and low permeability shales, siltstones and coals to GAB aquifers groundwater users and Pressure differential between the GAB and the target formations indicates that the through groundwater resources intervals are not currently connected by faults overlying strata Any localised fault structures identified with seismic survey and stimulation or faults treatment is avoided in proximity to faults Lateral Contamination of aquifers 5 In low permeability formations, fracture stimulation fluid highly unlikely to migrate Minor Unlikely Low migration of any significant distance beyond the stimulation treatment injected fluids Stimulation treatments are flowed back as soon as practicable and/or the well is put on line to recover treatment fluids Once on production, pressure gradient underground will result in fluids moving towards the well rather than migrating either upwards or laterally away from the fracture stimulation Water supply / Excessive drawdown of 5 Options for alternative water supplies investigated / used where possible (e.g. Minor Possible Medium use artesian and sub-artesian produced formation water, recycling, reuse) aquifers Water supply wells reviewed to ensure that their use does not impact adversely on Adverse impact on existing users of groundwater groundwater users and Monitoring of water extraction volumes groundwater resources

Adverse impact on groundwater dependent ecosystems

Leak of brackish Localised salinisation of soil, 2, 4, 6 Tanks used for storage of pre-stimulation water where small volumes are required. Minor Unlikely Low or saline pre- surface water and Larger above-ground tanks or lined ponds used where necessary to hold larger stimulation groundwater volumes water from Adverse impacts to flora Quality control on pond construction and liner installation to minimise risk of holding ponds and vegetation compromised liner integrity Adequate freeboard maintained (to allow for rain events and wave effects) and above-ground walls / bunds to prevent entry of surface runoff

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Activity / Event Potential Environmental SEO Management Strategy Consequence Likelihood Residual Impacts Obj Risk Pond operation monitored (e.g. pond wall integrity) and repair undertaken if required Testing, maintenance and inspection procedures are implemented. Maintain register of spills / leaks. Minor spill / Localised contamination of 2, 4, 6 See Fuel and chemical transport, storage and handling in Table 5.5 for general Minor Unlikely Low leak from soil, surface water and controls related to spills or leaks. hazardous groundwater material Access to contaminants by storage and stock and wildlife handling (e.g. Adverse impacts to flora several litres) and vegetation Major spill / Contamination of soil, 2, 4, 6 Moderate Unlikely Medium leak from surface water and hazardous groundwater material Access to contaminants by storage and stock and wildlife handling (e.g. Adverse impacts to flora entire contents and vegetation of refuelling tank) Minor leak or Localised contamination of 2, 4, 6 Routine inspections of flowback storage area and pipelines Minor Unlikely Low spill to ground soil and/or groundwater High pressure stimulation equipment has valid certifications, is pressure tested from surface Access to spilt contaminants once set-up (prior to commencement of stimulation) and trip systems prevent handling / by stock and wildlife operation above design pressure limits storage of Adverse impacts to flora Flowback lines from the wellhead rated and pressure tested to appropriate flowback fluids and vegetation pressure Major leak or Contamination of soil 2, 4, 6 Emergency shut-down system installed on well-head Moderate Unlikely Medium spill to ground and/or groundwater Quality control during construction to minimise risk of compromise to integrity of from surface Access to spilt contaminants liner handling / by stock and wildlife Maximum pond fill level not exceeded (allow for rain events and wave effects) storage of Adverse impacts to flora Ponds with above-ground walls that prevent surface runoff into ponds flowback fluids and vegetation Pond operation monitored (e.g. pond wall integrity, visual inspections, regular water balance calculations) and repair / remediation / decommissioning undertaken

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Activity / Event Potential Environmental SEO Management Strategy Consequence Likelihood Residual Impacts Obj Risk (e.g. pond wall where appropriate (e.g. if leak evident, create drainage channel, recover fluid, failure) repair or decommission pond) Spills / leaks cleaned up and remediated Additional fencing installed where necessary to prevent stock access Chemical utilisation during stimulation kept to the lowest possible to achieve necessary stimulation outcome Lower toxicity chemical additives used where practicable and suited to the stimulation design required Note: Water table, where present, is generally not close to the surface and is expected to be predominantly saline, with very limited use of shallow unconfined groundwater. This further mitigates the level of risk Minor leak or Localised contamination of 2, 6 Chemical utilisation during stimulation kept to the lowest possible to achieve Minor Unlikely Low spill of flowback surface water necessary stimulation outcome fluids to surface Localised death or injury to Lower toxicity chemical additives used where practicable and suited to the water aquatic fauna stimulation design required Major leak or Contamination of surface 2, 6 Flowback fluid securely contained in lined ponds, as discussed above: Major Unlikely Medium spill of flowback water Ponds lined with UV stabilised HDPE or equivalent fluids to surface Death or injury to aquatic Quality control during construction to minimise risk of compromise to integrity of water fauna liner (e.g. if pond Monitoring of pond operation (freeboard) to maintain pond integrity fails and Spills / leaks cleaned up and remediated contents reach surface water Ponds with above-ground walls / bunds to prevent surface runoff into ponds or flood Well sites and pond locations selected to ensure that the consequences of a overtops ponds) potential pond failure are minimised (e.g. ponds would not be located in close proximity to significant watercourses such that failure would result in direct release to these watercourses) Where well leases have potential for infrequent flooding, measures will be undertaken to ensure ponds are not vulnerable to flooding (e.g. ponds on higher ground, construction of higher pond walls, removal of flowback fluids off-site either during testing or at completion of operations) Implementation of additional management measures as identified by site-specific assessments against the stated environmental objective to avoid surface water impacts

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Activity / Event Potential Environmental SEO Management Strategy Consequence Likelihood Residual Impacts Obj Risk

Flooding of well Contamination of surface 2, 6 Well leases located on higher ground as far as practicable in areas where there is Moderate Unlikely Medium leases during water potential for flooding fracture Death or injury to fauna Handling and storage in accordance with relevant International Standards stimulation Organisation standards, relevant SDS and State regulatory requirements operations Emergency/spill response procedures in place with immediate clean up and remediation of spills Measures discussed above implemented to ensure ponds are secure from flooding Flowback fluids will be monitored closely where ponds are located in areas where there is any potential of flooding Interaction of Death or injury of fauna or 2 Ponds securely fenced to exclude stock and large native fauna Minor Unlikely Low stock or native stock Pond construction to minimise attractiveness to birds i.e. relatively steep sides and fauna with lined with suitable polyethylene material, with no ‘beaches’ or vegetation storage ponds Many of the fracturing fluid additives are biodegradable Routine surveillance monitoring will be undertaken to detect incursions Measures to facilitate escape of smaller fauna from ponds provided where feasible (e.g. geofabric or textile matting ‘ladders’) Ongoing inspection and monitoring of ponds would detect fauna mortality (if it occurred) and implement appropriate preventative measures if required Bird deterrent measures will be introduced if bird mortality incidents are observed Ponds will be temporary and will be rehabilitated following removal of liner Note: Historically there are very few reports of fauna (small or large) entrapment in similar ponds in the Cooper Basin. Personnel and Danger to health and safety 7 Ponds securely fenced Moderate Rare Low third party of personnel, contractors Signage in place to warn of access restrictions access to and possibly the public Access to sites restricted during operations storage ponds Sites will be attended by an operator during and after fracturing operations General site Disturbance to landholders 1, 2, 8 Activities confined to existing cleared areas (e.g. access roads, prepared well lease) Minor Unlikely Low activities, and other third parties within area subject to environmental assessment and Work Area Clearance for presence of Disturbance to stock and cultural heritage personnel and wildlife Approved work areas and restricted areas clearly delineated on site noise emissions

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Activity / Event Potential Environmental SEO Management Strategy Consequence Likelihood Residual Impacts Obj Risk Disturbance to cultural Training and induction for all personnel to educate them on the importance of heritage sites remaining within designated / approved areas If flora with significant conservation value is present in the vicinity it will be flagged and / or fenced off where necessary to prevent disturbance Cultural heritage sites or exclusion zones in the vicinity of the well site will be flagged and / or fenced off to prevent disturbance where necessary Equipment operated and maintained in accordance with manufacturer specifications Remote location of well sites Stakeholders notified of location of operations and appropriate consultation and mitigation measures implemented, if required, to ensure that no reasonable complaints are received Minimise lighting where possible Flaring or Localised reduction in local 8 Equipment operated and maintained in accordance with manufacturer Minor Unlikely Low combustion of air quality specifications hydrocarbons Release of greenhouse If possible, well flowback diverted to separator to minimise gas not being captured Fugitive gases and sent to flare emissions of Flaring during production testing kept to minimum length of time necessary to methane and establish resource and production parameters organic carbon Remote location of well sites

Monitoring of well parameters during testing operations to check for potential for fugitive emissions at the wellbore Note: Greenhouse gas emissions recorded and reported in accordance with NGER requirements Bushfire Loss of vegetation and 2, 7, 8 Activities undertaken on cleared well lease Moderate Rare Low (resulting from fauna habitat Combustible materials cleared from area surrounding flowback equipment activities) Disturbance, injury or death Fire fighting equipment available as appropriate for location and use of fauna Fire and Emergency Services Act requirements will be complied with (e.g. permits Atmospheric pollution for ‘hot work’ on total fire ban days) Damage to infrastructure Disruption to land use

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Activity / Event Potential Environmental SEO Management Strategy Consequence Likelihood Residual Impacts Obj Risk Danger to health and safety of personnel, contractors and possibly the public Seismicity Ground disturbance 8 Low background seismic hazard Negligible Rare Low Lack of major faulting in most operational areas Historical stimulation work in the Cooper Basin indicates low risk of induced seismicity Micro seismic monitoring may be used at some well locations as part of the resource assessment and will be available to delineate seismic response Radioactivity Danger to health and safety 4, 6, 7 Appropriate protocols (e.g. risk assessment, monitoring where required) Minor Unlikely Low from Naturally of employees, contractors implemented where radioactive tracers are used to confirm that radiation levels are Occurring and possibly the public well below any levels of concern Radioactive Contamination of soil If NORM above the natural background levels were to occur, appropriate measures Materials and/or groundwater for handling and disposal of pond liners and contents remaining after evaporation (NORM) in would be implemented flowback fluids

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6 Consultation

Effective consultation allows for an exchange of information and provides an opportunity to promote understanding and reconciliation of competing interests.

The licence area and surrounding area is a sparsely populated and remote arid region. Stakeholders in the region generally include pastoral leaseholders and the local community, Native Title groups, regulatory agencies, DEW and AWC personnel, tourists and tourism operators, petroleum explorers and associated contractors, and environmental organisations.

It is a requirement under the Petroleum and Geothermal Energy Regulations 2013 that information on consultation with relevant landholders, Aboriginal groups or representatives, government departments/agencies, or any other interested person or parties be outlined in an EIR.

Preliminary consultation with government agencies (principally DEM, DEW, DPTI, SA Arid Lands NRM Board and the EPA) was undertaken on selected issues during the development of the EIR and SEO. A preliminary consultation meeting was held by Tri-Star on 26th September 2019 with representatives from DEM, DEW, DPTI and EPA invited to attend. The draft EIR and SEO were subsequently emailed to relevant agencies for their initial review and comment. Initial comments on the draft documents have been addressed in this EIR and the accompanying SEO. Refer to Appendix 2 for a summary of comments received from relevant agencies and associated Tri-Star responses. Tri-Star also met with the Wangkangurru / Yarluyandi Aboriginal Corporation RNTBC Board on 6th December 2019 and discussed a range of matters in relation to the proposed activities. Refer to Table 6.2 for a summary of issues raised and associated Tri-Star responses. Tri-Star also engaged with pastoralists whose lease overlaps the area the SEO applies, refer to Table 6.2 for a summary of issues raised and associated Tri-Star responses. Initial comments on the draft documents have been addressed in this EIR and the accompanying SEO.

The EIR and SEO were formally submitted to DEM after being updated to address the comments raised, and the documents underwent a formal period of consultation under the Petroleum and Geothermal Energy Act.

Tri-Star has undertaken and will continue to undertake stakeholder consultation regarding its petroleum exploration activities in the region. Tri-Star aims to continue to engage stakeholders for the duration of its activities in the region to ensure that all potential concerns are identified and appropriately addressed.

A list of stakeholders engaged during the formal consultation process is provided in Table 6.1, and a summary of the issues raised by stakeholders and government agencies, along with Tri-Star responses, is provided in Table 6.2. The EIR and the accompanying SEO have been updated where relevant.

The following stakeholders have been identified as having a direct interest in petroleum exploration activities in the licence area: [Note: This section currently outlines planned consultation – it will be completed following public consultation]

Table 6.1: Stakeholder consultation list

Government Environment Protection Authority (EPA)

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Department of Environment and Water (DEW) Department for Energy and Mining (DEM). SA Arid Lands Natural Resources Management Board SA Arid Lands Water Projects Aboriginal Affairs and Reconciliation Department of Planning, Transport and Infrastructure (DPTI) Department of Health and Aging Non-Government Wangkangurru / Yarluyandi Aboriginal Corporation RNTBC South Australian Chamber of Mines & Energy (SACOME) Australian Petroleum Production and Exploration Association (APPEA) Conservation Council of SA Wilderness Society Australian Wildlife Conservancy (AWC) Friends of Simpson Desert Parks Landholders Cowarie Kalamurina (AWC) Clifton Hills Alton Downs Macumba

Table 6.2: Summary of issues raised during stakeholder consultation

Stakeholder / Date Issue / Comment Tri-Star Response Tri-Star meeting with Concerns about potential presence of There is potential that unmapped springs may be the Wangkangurru / unmapped springs within the Simpson present within the licence area. However, Yarluyandi Aboriginal Desert. desktop studies and field inspections (e.g. field Corporation RNTBC cultural heritage and environmental surveys) of Board all proposed project areas will assess and inspect 6th December 2019 for the potential presence of unmapped springs and a range of other potential sensitivities. As per Objectives 5, 6, 7 in the SEO. Concerns raised with fracking activities and Addressed in the EIR at Sections 3.3, 5.2.3 and effects on groundwater. 5.3. Also note there are a range of criteria and requirements listed in the SEO at Objective 5 to mitigate against potential impacts to groundwater and associated groundwater dependent systems and users. Concerns around the chemicals used in Addressed in the EIR at Sections 3.3.5, 5.3 and fracturing fluids. Appendix 1. Concerns about water sources and Addressed in the EIR at Sections 3.3.8, 4.6, 5.2.3 quantity of water consumed during and 5.3.5. As mentioned above, there are a proposed activities. range of criteria and requirements listed in the SEO at Objective 5 to mitigate against potential impacts to groundwater and associated groundwater dependent systems and users. Concerns about the potential impacts on As per comments above regarding potential groundwater, and the importance of impacts to groundwater and springs. Tri-Star will groundwater and springs to WY dreamtime liaise with the Wangkangurru / Yarluyandi

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Stakeholder / Date Issue / Comment Tri-Star Response stories associated with a serpent that lives Aboriginal Corporation in an ongoing basis to in the ground water and originally caused ensure their concerns are heard and addressed the springs to occur. where appropriate. Pastoralists Concerns about organic accreditation. Addressed in Section 4.8.1. The section specifically notes that Alton Downs, Cowrie and Clifton Hills are Certified Organic Livestock operations under NASAA. Section 5.2.5 address’s risks and mitigation measures associated with stock accessing contaminants. Concerns raised associated with fracking Addressed in the EIR at Sections 3.3, 5.2.3 and and water contamination/damage to GAB. 5.3. Also note there are a range of criteria and requirements listed in the SEO at Objective 5 to mitigate against potential impacts to groundwater and associated groundwater dependent systems and users. To be completed following public consultation

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7 Environmental Management System

Drilling and fracture stimulation operations in the licence area will be undertaken in accordance with the principles of an Environmental Management System (EMS). An EMS is a key tool in the management of the proponent and associated contractors’ environmental responsibilities, issues and risks. An EMS also provides a framework for the coordinated and consistent management of environmental issues by ensuring the. ▪ establishment of environmental policy ▪ identification of environmental risks and legal and other requirements relevant to drilling operations ▪ setting of appropriate environmental objectives and targets ▪ delineation of responsibilities ▪ establishment of a structure and program to implement environmental policy and achieve objectives and targets, including the development of procedures or guidelines for specific activities and education and induction programs ▪ facilitation of planning, control monitoring, corrective action, auditing and review of activities to ensure that the requirements and aspirations of the environmental policy are achieved. ▪ Tri-Star and its contractors’ operating standards will follow industry-accepted standards.

Key components of an EMS are discussed in the following sections.

Prior to the start of field operations all field personnel will be required to undertake an environmental induction to ensure they understand their role in protecting the environment. This induction will be part of a general induction process also including safety procedures. The induction will include notification of environmental objectives, environmental requirements and obligations under land access agreements, and will include the distribution and explanation of any site-specific environmental material.

A record of induction and attendees will be maintained.

In the course of normal operations, there is always the potential for environmental incidents and accidents to occur. To manage these incidents, emergency response plans will be developed to guide actions to be taken to minimise the impacts of accidents and incidents. Emergency response plans will be reviewed and updated on a regular basis to incorporate new information arising from any incidents, near misses and hazards and emergency response simulation training sessions. These plans will also include the facilitation of fire danger season restrictions and requirements.

Emergency response drills will also be undertaken at regular intervals to ensure that personnel are familiar with the plans and the types of emergencies to which it applies, and that there will be a rapid and effective response in the event of a real emergency occurring.

Ongoing monitoring and auditing of drilling and fracture stimulation operations will be undertaken to determine whether significant environmental risks are being managed, minimised and where reasonably possible, eliminated.

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Monitoring programs will be designed to assess: ▪ compliance with regulatory requirements ▪ visual impact of the operations ▪ impact upon flora and fauna and general biodiversity ▪ site contamination ▪ site revegetation following program completion and any restoration activity ▪ potential future problems.

Tri-Star and its contractors will have a system in place to record environmental incidents, near misses and hazards, track the implementation and close out of corrective actions, and allow analysis of such incidents to identify areas requiring improvement. The system will also provide a mechanism for recording ‘reportable’ incidents, as defined under the Petroleum and Geothermal Energy Act 2000 and associated regulations.

Internal and external reporting procedures will be implemented to ensure that environmental issues and/or incidents are appropriately responded to. A key component of the internal reporting will be contractors’ progress and incident reports to Tri-Star.

External reporting (e.g. incidents, annual reports) will be carried out in accordance with Petroleum and Geothermal Energy Act requirements and the SEO.

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8 References

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Friedmann, F. (1986). Surfactant and Polymer Losses During Flow Through Porous Media. SPE 11779, SPE Reservoir Engineering, Vol. 1, No. 3, May 1986, p261-271. Geoscience Australia (2012). The 2012 Australian Earthquake Hazard Map. Accessed September 2018 at http://www.ga.gov.au/interactive-maps/#/theme/hazards/map/earthquakehazards Gibson, G. and Sandiford, M. (2013). Seismicity & induced earthquakes. Background Paper to the Office of the NSW Chief Scientist and Engineer (OCSE), Melbourne Energy Institute, University of Melbourne. Gillen, J.S. and Reid, J.R.W. (2013). Vegetation and soil assessment of selected waterholes of the main and northwest channels of Cooper Creek, South Australia, April-May 2012. A report by the Australian National University to the South Australian Arid Lands Natural Resources Management Board, Port Augusta.

Hale, J. (2010). Lake Eyre Basin high conservation value aquatic ecosystem pilot project. Draft report to the Australian Government Department of Environment, Water, Heritage and the Arts from the Aquatic Ecosystems Task Group. Howard, P.R., Mukhopadhyay, S., Moniaga, N., Schafer, L., Penny, G and Dismuke, K. (2009). Comparison of Flowback Aids: Understanding Their Capillary Pressure and Wetting Properties. Paper SPE 122307, 8th European Formation Damage Control Conference, 27-29 May 2009, Scheveningen, The Netherlands. Jacobs SKM (2014). Review of current Goal Attainment Scaling (GAS) criteria for borrow pit construction, use and rehabilitation within the Cooper Basin. Jacobs SKM, South Australia, Adelaide. Report 06 March 2014. King, G.E. (2012). Estimating Frac Risk and Improving Frac Performance in Unconventional Gas and Oil Wells. Paper SPE 152596 at the Hydraulic Fracturing Conference, The Woodlands, TX. February 2012. Love A.J., Shand P., Crossey L., Harrington G.A. and Rousseau-Guetin, P. (2013). Allocating Water and Maintaining Springs in the Great Artesian Basin, Volume III: Groundwater Discharge of the Western Great Artesian Basin. National Water Commission, Canberra, March 2013. Mancini, H. (ed) (2017). Summary of technical findings: Improving habitat condition and connectivity in South Australia’s channel country – the Diamantina and Warburton river system in South Australia. Report by Natural Resources SA Arid Lands DEWNR, to the South Australian Arid Lands Natural Resources Management Board, Pt Augusta. Maree SCB (2004). Marree Soil Conservation Board District Plan Revised 2004. Government of South Australia. Marla-Oodnadatta SCB (2002). Marla-Oodnadatta Soil Conservation Board District Plan. Government of South Australia. Moore, P.S. (1986). Jurassic and Triassic Stratigraphy and Hydrocarbon Potential of the Poolowanna Trough (Simpson Desert Region) Northern South Australia. GSA Special Publication, 12, 39 – 51. Neagle, N. (2003). An Inventory of the Biological Resources of the Rangelands of South Australia. Department for Environment and Heritage, South Australia, Adelaide. Orchard, A.E. & A.J.G. Wilson (eds) (2001). Flora of Australia, Volume 11A, Mimosaceae, Acacia Part 1. Osti, A. (2014). Hydrological modelling of the Diamantina-Warburton River System. Technical note 2014/15. Department of Environment, Water and Natural Resources, South Australia, Adelaide.

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Palmer, I.D. and Luiskutty, C.T. 1985. A Model of the Hydraulic Fracturing Process for Elongated Vertical Fractures and Comparison of Results with Other Models. Paper SPE 13864 presented at the SPE/DOE Low Permeability Gas Reservoirs Symposium. Denver, Colorado Perkins, T. K., and Kern, L. R. 1961. Width of Hydraulic Fractures. J. Pet. Eng. J.13:937 – 949 PIRSA (2014). Declared Plant Policy: Caltrop (Tribulus terrestris). Primary Industries and Regions SA (PIRSA), South Australia, Adelaide. Powis, G.D. (1989). Revision of Triassic Stratigraphy at the Cooper Basin to Eromanga Basin Transition. Presented at the Cooper and Eromanga Basins Conference, Adelaide, 1989. PESA, SPE and ASEG (SA branches), 265 – 77. Radke, B., (2009). Hydrocarbon & Geothermal Prospectivity of Sedimentary Basin in Central Australia (Warburton, Cooper, Pedirka, Galilee, Simpson & Eromanga Basins). Geoscience Australia Record 2009/25. Ransley, T.R., Radke, B.M., Feitz, A.J., Kellett, J.R., Owens, R., Bell, J., Stewart, G. and Carey, H. (2015). Hydrogeological Atlas of the Great Artesian Basin. Geoscience Australia, Canberra. Accessed at: http://dx.doi.org/10.11636/9781925124668 SAAL NRM (2009). Water allocation Plan for the Far North Prescribed Wells Area, South Australian Arid Lands Natural Resources Management Board, Government of South Australia. SAAL NRM (2011). Wilkinti or Dusky Hopping Mouse, Notomys fuscus, and Ooarri or Fawn Hopping Mouse, Notmys cervinus. Biodiversity Fact Sheet. South Australian Arid Lands Natural Resources Management Board, Government of South Australia, Updated July 2011. SAAL NRM (2013). Marree-Innamincka District Profile. Accessed July 2018 at: http://www.naturalresources.sa.gov.au/files/1491417e-dd18-4cec-bd1f-a37200975118/marree- innamincka-district-profile-fact.pdf. SA Arid Lands Natural Resources Management Board, South Australian Government. SAAL NRM Board (2017). It’s your place. A roadmap for managing natural resources in the SA Arid Lands NRM Region 2017-2017. Regional NRM Plan (Volume 1). SA Arid Lands Natural Resources Management Board. Santos (2015). South Australia Cooper Basin Environmental Impact Report: Drilling, Completions and Well Operations. November 2015. Santos Ltd, Adelaide. Schmarr, D.W., Mathwin, R. and Cheshire, D.L. (2017). Aquatic Ecology Assessment and Analysis of the Diamantina River Catchment: Lake Eyre Basin, South Australia. Report by South Australian Research and Development Institute to the South Australian Arid Lands Natural Resources Management Board, Pt Augusta. Senex (2015). Environmental Impact Report: Fracture Stimulation of Oil Targets in Eromanga Basin Formations. July 2015. Senex Energy Limited, Brisbane. Simonson, E.R., Abou – Sayed, A. S., and Clfton, R. J. 1978. Containment of Massive Hydraulic Fractures. Soc. Pet. Engrs. J. 18:27-32. Voegele, M.D., Abou-Sayed, A.S. and Jones, A.H. 1983. Optimization of Stimulation Design through the use of In-Situ Stress Determination. JPT 35: 1071 – 1081. DENR (2011). Simpson Desert Conservation Park and Regional Reserve Wilderness Assessment Report, Wilderness Advisory Committee, Department of Environment and Natural Resources, South Australia, Adelaide. Wainwright, P., Tunn, Y., Gibson, D. and Cameron, J. (2006). Wetland mapping, Channel Country bioregion, South Australia. Department for Environment and Heritage, South Australia, Adelaide.

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Wakelin-King, G.A. (2017). Geomorphology of the Diamantina River Catchment (SA). Report by Wakelin Associates to the South Australian Arid Lands Natural Resources Management Board, Government of South Australia, Pt Augusta. Warpinski, N.R., Schmidt, R.A., and Northrop, D.A. 1982. In Situ Stresses: The Predominant Influence on Hydraulic Fracture Containment. JPT. 34:653 – 664. Warpinski,N.R., Fnley, S.J., Vollendorf, W.C., O’Brien, M., and Eshom, E. 1982. The Interface Test Series: An In Situ Study of Factors Affecting the Containment of Hydraulic Fractures. Sandia National Laboratories Report SAND81-2408 WaterConnect (2019). Groundwater Bore Data “Drill holes” GIS dataset obtained from WaterConnect, Government of South Australia. Accessed: February 2019 at https://www.waterconnect.sa.gov.au/Systems/GD/Pages/Default.aspx Government of South Australia. White, M., D. Albrecht, A. Duguid, P. Latz & M. Hamilton (2000). Plant species and sites of botanical significance in the Southern Bioregions of the Northern Territory. Volume 1: Significant Vascular Plants. Arid Lands Environment Centre. Alice Springs, NT

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9 Abbreviations and Glossary

ADG Code Australian Dangerous Goods Code ANZECC Australia and New Zealand Environment and Conservation Council (in reference to the Australian and New Zealand Guidelines for Fresh and Marine Water Quality 2000) aquitard A bed of low permeability adjacent to an aquifer AS Australian Standard AS 1940 Australian Standard AS 1940 Storage and Handling of Flammable and Combustible Liquids bbls barrels (1 barrel = 159 litres) BDBSA Biological Databases of South Australia biocide Chemical compound that can kill living organisms (typically targeted at microorganisms) BoM Bureau of Meteorology BOP blowout preventer BTEX Benzene, toluene, ethylbenzene, xylene CAMBA China-Australia Migratory Bird Agreement CASA Civil Aviation Safety Authority casing annulus Space between the casing and any piping, tubing or casing surrounding it casing string A long section of connected oilfield pipe that is lowered into a wellbore and cemented into place cement bond log The output from an acoustic tool that is lowered down an oil or gas well to evaluate the integrity of the bond of the cement to the casing and formation

CO2 carbon dioxide coiled tubing A long, continuous length of pipe wound on a spool. The pipe is straightened prior to pushing into a wellbore and rewound to coil the pipe back onto the transport and storage spool contamination As defined by the Environment Protection Act 1993 and the National Environment Protection (Assessment of Site Contamination) Measure (1999) amended in 2013 conventional gas Natural gas trapped in underground structures in highly permeable sandstones coring The process of cutting out a long cylindrical section of rock, known as a core sample or core, from a geological formation by core drilling Culvert A structure that allows water to flow under a road. D Darcy DAWE Department of Agriculture, Water and Environment DEE Department of the Environment and Energy (Commonwealth) (now DAWE) DEH Department for Environment and Heritage (now DEW) DEM Department for Energy and Mining (regulator of the Petroleum and Geothermal Energy Act) DEW Department for Environment and Water DEWNR Department of Environment, Water and Natural Resources (now DEW) DMITRE Department of Manufacturing, Innovation, Trade, Resources and Energy (now DEM) DPC Department of Premier and Cabinet – Energy Resources Division (now DEM) DPTI Department of Planning, Transport and Infrastructure DSD Department of State Development (now DEM)

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EIR Environmental Impact Report prepared in accordance with Section 97 of the Petroleum and Geothermal Energy Act 2000 and Regulation 10 EMS Environmental Management System EPA Environment Protection Authority (South Australia) EPBC Act Environment Protection and Biodiversity Conservation Act 1999 EPT Extended production testing ERP Emergency Response Plan flowback Fluids that are injected during fracture stimulation and flow back up the well from the reservoir to the surface after the pressure is released fracturing fluids The mixture of water and additives injected into a well during fracture stimulation GAB Great Artesian Basin GAS Goal Attainment Scaling Gibber Small to medium weathered rounded stones that form a relatively flat, extensive pavements on plains and gentle slopes. The narrow spaces between stones have soil infill. The stones are concentrated on the surface by their gradual downward movement as the soil that once separated them in the vertical dimension has been removed by wind and gentle water erosion. ha hectare HDPE high density polyethylene HDPE high density polyethylene HSEMS Health, Safety and Environment Management System ISO International Standards Organisation JAMBA Japan-Australia Migratory Bird Agreement km kilometre km2 square kilometres lithology Description of the physical characteristics of a rock such as colour, texture, grain size or composition mD millidarcy mg/L milligrams per litre microseismic monitoring The passive observation of very small-scale seismic events which occur in the ground as a result of human activities or industrial processes such as mining, oil and gas production, enhanced geothermal operations or underground gas storage minimise To reduce as far as reasonable practical, considering all other factors e.g. requirements for safe operations and accessibility NEPM National Environment Protection (Assessment of Site Contamination) Measure (1999) amended in 2013 NGER National Greenhouse and Energy Reporting Act 2007 (Cth) NORM Naturally Occurring Radioactive Materials NPI National Pollutant Inventory NPWS National Parks and Wildlife Service NRM Natural Resources Management PAH polycyclic aromatic hydrocarbon PEL Petroleum Exploration Licence

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perforating The process of punching holes in the casing or liner of an oil or gas well to connect it to the reservoir permeability A measure of the ease of flow of fluids through a rock PFW produced formation water PFW Produced Formation Water PGE Act Petroleum and Geothermal Energy Act 2000 PIRSA Primary Industries and Regions South Australia PPL Petroleum Production Licence PRL Petroleum Retention Licence proppant Particles (e.g. sand grains, resin-coated sand or high-strength ceramic material) mixed with fracturing fluid to hold fractures open after a fracture stimulation treatment psi pounds per square inch (a unit of pressure) PTW Permit to Work QA/QC Quality Assurance / Quality Control Ramsar wetland A Wetland of International Importance listed under the Ramsar Convention (held in Ramsar, Iran 1971). RFDS Royal Flying Doctor Service ripping The use of machinery to rake or plough soil to relieve compaction and aerate soil. SDS Safety Data Sheet SEO Statement of Environmental Objectives prepared in accordance with the Petroleum and Geothermal Energy Act 2000 SEO Statement of Environmental Objectives prepared in accordance with Section 99 and 100 of the Petroleum and Geothermal Energy Act 2000 and Regulations 12 and 13 SFL Special Facilities Licence SMS Safety Management Study Sour Gas Sour gas is natural gas or any other gas containing significant amounts of hydrogen sulfide. stimulation Fracture stimulation of a well, which involves pumping fluid, largely water, at high pressure to create or enhance fractures in the rock and increase permeability in the reservoir. stratigraphy The study of rock layers and layering (stratification) tectonic Relating to, causing, or resulting from structural deformation of the earth's crust THPS TetrakisHydroxymethylPhosphonium Sulfate (a biocide) tight gas Natural gas which is difficult to access because of the low permeability of the rock containing the gas tiltmeter An instrument used to measure slight changes in the inclination of the earth's surface TPH total petroleum hydrocarbons unconventional gas Natural gas that is trapped in lower permeability reservoirs, rather than on underground structures such as anticlines and highly permeable sandstones viscosifiers An additive that increases the viscosity of a fluid. Viscosity of a fluid is its resistance to flow, or in everyday terms, its “thickness” WAC Work Area Clearance wellhead The part of an oil or gas well which terminates at the surface, where oil or gas can be withdrawn.

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wireline unit The equipment used to lower a wire or cable into an oil or gas well to conduct operations in the well zone An interval or unit of rock differentiated from surrounding rocks on the basis of its fossil content or other features, such as faults or fractures. Often used to describe a layer of reservoir rock that contains oil or gas

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Appendix 1: Listing of Fracturing Additives and Constituents

The following table lists chemicals which may be used in a fracture stimulation.

Table A1: Fracturing fluid additives (source Santos (2015))

Chemical Name CAS RN Common Use Organic 2-Bromo-2-notro-1,3- Preservative agent, antibacterial soap, skin cleansing wipes, hand wash 52-51-7 propanediol and body shampoo and microbial; treatment in water systems Additive in food industry, processed fruit, cheese, meat and poultry, Acetic Acid 64-19-7 descaling agent Food Red 10 3734-67-6 Food dye Red No. 2 915-67-3 Dye Violet 12 6625-46-3 Air freshener, commercial pH indicator solution Food agent for sour taste, fruit juice, dishwasher cleaner, all-purpose Citric Acid 77-92-9 cleaner, hand soap Ethylene Glycol Monobutyl Cleaning products, cosmetics, liquid soaps, paint removal gel, citrus 111-76-2 Ether household cleaner, sterilizing wipes, commercial lubricating oil Solvent, sweetener, filler in food, laundry stain remover, antimicrobial Glycerine 56-81-5 soap, toothpaste, lipstick Glyoxal 107-22-2 Cross linker in paper and textile industries Solvent, medical grade disinfectant, tape head cleaner, hops extract Isopropanol 67-63-0 used for beer, air freshener Windscreen washer fluid, wastewater treatment, alternative fuel blends, Methanol 67-56-1 liquid hand soap, furniture finisher, windscreen washer concentrate, hops extract Xanthan Gum 11138-66-2 Thickening agent in salad dressings, sauces, ice-creams Disinfectants, surfactants, fabric softeners, antistatic agents, and wood Quaternary Amine -* preservation Laundry detergents, surface cleaners, cosmetics and for use in Alcohols, C12-16, ethoxylated 68551-12-2 agriculture, textiles and paint, car wash liquid, air freshener Absorbent material in nappies, laundry detergent glass cleaning Polyacrylate -* solution, dishwashing detergent, children’s bath water additive Disinfectants, surfactants, fabric softeners, anti-static agents, wood Quaternary Amine -* preservation, industrial and commercial water acidity neutralizing solution Alcohol (1) -* Scouring agent for textiles, commercial defoamer Disinfectants, surfactants, fabric softeners, anti-static agents, wood Amine -* preservation, commercial bathroom cleaner, medical rinsing solution, photography print ink Soil conditioner in the horticulture and agriculture industries, Polyacrylamide copolymer -* flocculator in potable water treatment, mulch binder, dust control agent Natural agricultural pesticides, laundry soap, furniture oil, grease Terpene -* stripper, paint, ink, gum removal Chemical Name CAS RN Common Use Ether Compound -* Air freshener, food flavouring agents

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Chemical Name CAS RN Common Use Oxyalkylated polymer -* Demulsifiers, flotation agents Phenolic compound -* Plastic and textile generation, detergents Foods, cosmetics, and oral hygiene products as solvent, preservative Glycol compound -* and moisture retaining agent Thickener is cosmetics, baked goods, ice cream, toothpaste, sauces, Hydroxypropyl guar 39421-75-5 fabric softener, hair straightening aid, shampoo, body lotion, shaving cream Benzaldehyde 100-52-7 Almond flavouring in food Cinnamaldehyde 104-55-2 Food flavour, herbicide, cancer treatment, antimicrobial Moisture retainer in tobacco, cork, ink glue, cosmetics. Used in brake Diethylene glycol 111-46-6 fluids Alkyl phenol alkoxylates -* Metal soldering flux, commercial and industrial cleaners and degreasers Pharmaceuticals, sunscreens, cosmetics, inks, dyes, water based paints, Glycol ether -* degreasers, cleaners, aerosol paints and adhesives Choline chloride 67-48-1 Feed additive for chickens Ethylene glycol 107-21-1 Antifreeze, household cleaners, deicing, caulk Acrylonitrile 107-13-1 Plastic manufacture Alcohols, C6-C12, Ethoxylated Household and industrial and institutional cleaners, paints and coatings, 68937-66-6 propxylated pulp and paper, textile processing Alcohols, C10-C16, Household and industrial and institutional cleaners, paints and coatings, 69227-22-1 Ethoxylated propxylated pulp and paper, textile processing Polyethylene glycol 25322-68-3 Laxatives, medications Inorganic Ammonium Sulfate 7783-20-2 Soil fertiliser Chlorous Acid, Sodium Salt 7758-19-2 Bleaching and stripping of textiles, pulp, and paper Crystalline Silica, Quartz 14808-60-7 Sand and gravel, cat litter, tile mortar, arts and crafts, ceramic glaze Disodium Octaborate 12008-41-2 Antiseptic, insecticide, flame retardant Tetrahydrate Hydrochloric Acid 7647-01-0 Leather processing, purification of common salt, household cleaning Potassium Carbonate 584-08-7 Soap, glass, china, food additive Silica Gel 112926-00-8 Mouthwash, toothpaste, powdered sugars Chemical Name CAS RN Common Use Sodium Carbonate 497-19-8 Laundry detergent, dishwashing liquid, toothpaste, pool pH additive Sodium Chloride 7647-14-5 Food grade salt, laundry detergent, aquarium fish medication, ice melting product Sodium Hydroxide 1310-73-2 Laundry detergent, toothpaste, cocoa, milk products, chocolate Sodium Hypochlorite 7681-52-9 Household bleach, disinfectant, water treatment, endodontics, eczema treatment Sodium Iodide 7681-82-5 Light bulbs, infant food Sodium Persulfate 7775-27-1 Bleach, metal etching, soil conditioner, detergent Sodium Sulfate 7757-82-6 Dishwasher detergent, laundry detergent, liquid hand soap, toothpaste Aluminum oxide 1344-28-1 Paint, pigment, plastic filler, water/gas purification Aluminum silicate 1302-76-7 Blanket felt, paper or boards

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Chemical Name CAS RN Common Use Crystalline Silica, cristobalite 14464-46-1 Glass, optical fibers for telecommunications Iron oxide 112926-00-8 Pigments in paint coatings, coloured concretes Silica Dioxide 112926-00-8 Cement, glass, optical fibers for telecommunications, porcelain, earthenware Titanium Dioxide 13463-67-7 Sunscreen, food colouring, paint pigments Borate salts -* Agricultural plant food, fertilizer, industrial glass manufacturing additive Almandite and pyrope garnet 1302-62-1 Gemstone, grit blasting EDTA / Copper chelate -* Fertiliser, water softeners, shampoos, food preservatives Sodium bisulfite 7631-90-5 Food preservative, swimming pool chemical Note:” -* ” = chemical not disclosed for reasons of confidentiality

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Indicative Overall Percentage of Additives

The indicative overall percentages of additives in a typical fracturing operation on a well in the Cooper Basin is shown below.

Figure A1: Indicative overall percentages of Additives from a fracture operation in the Cooper Basin

Safety Data Sheets

Safety Data Sheets for the fracturing fluid additives listed above are available at the following websites:

Halliburton: http://www.halliburton.com/en-US/tools-resources/safety/material-safety-data-sheet- search.page

Schlumberger: http://www.slb.com/resources/msds-sheets.aspx

Further Information

Additional information on fracture stimulation additives is available from the following sources:

Table A2: Fracture Stimulation Additives information sources

Government web sites:

DEM (SA) http://www.petroleum.statedevelopment.sa.gov.au/ Fracture stimulation providers:

http://www.halliburton.com/public/projects/pubsdata/Hydraulic_Fracturing/fluids_ Halliburton disclosure.html http://www.slb.com/services/completions/stimulation/unconventional_gas_stimula Schlumberger tion/openfrac_hydraulic_fracturing_fluids.aspx https://www.bakerhughes.com/products-and-services/pressure- pumping/hydraulic- Baker Hughes fracturing/environmental-solutions-and-chemical-disclosure Industry bodies:

APPEA http://www.appea.com.au

API http://www.api.org

Frac Focus (USA) https://fracfocus.org/hydraulic-fracturing-process

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Appendix 2: Agency Consultation Comments and Responses

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Summary of Agency Consultation Comments and Responses Comments received during preliminary consultation with government agencies, and associated Tri-Star responses, are summarised in Table A 1.

Note: Comments received from DEW (comments received 22nd November 2019) and SAAL NRM Board (comments received 4th March 2020) were consistent / verbatim. Where appropriate, these agency comments and the Tri-Star response have been grouped into a single row for both agencies in Table A 1.

Table A 1: Preliminary Government Agency Consultation Comments and Responses

No. Agency General Comment Comment / Issue Raised Tri-Star Response or EIR / SEO 1 DEW / General Comment ▪ DEW: Thank you for the opportunity to provide comment on ▪ Noted SAAL NRM these documents. This is a relatively unexplored and remote part of South Australia consequently the activities will need to Board be carefully planned as it shouldn’t be assumed that what works in the Cooper Basin can be directly applied to the Munga Thirri - Simpson Desert Regional Reserve. Methods used in the Cooper Basin may have relevance but may need to be adapted to the landscapes of the reserve. Reconnaissance to pick up any differences between the Cooper Basin and Simpson Desert will be critical to achieving your stated objectives. You have identified the need to talk to DEW and WY people; we strongly support this and recommend that this is done as early as possible. ▪ SAAL NRM Board: Thank you for the opportunity to provide comment on the Environmental Impact Report and Statement of Environmental Objectives in relation to petroleum exploration activities in the Simpson and Pedirka Basins. The SA Arid Lands NRM Board has worked closely with DEW Flinders & Outback in reviewing the proposal and supports their requests and recommendations.

2 DEW / General Comment ▪ Overall, impacts to groundwater resources from drilling and ▪ Noted SAAL NRM fracture stimulation are expected to be negligible, based on the preventative measures adopted during well construction (i.e. Board casing / cementing to isolate key aquifers), post drilling testing (i.e. integrity testing), operational monitoring and management controls. Tri-Star to provide validation pressure data (page 32) to DEM to demonstrate containment and compliance with objective 5 (page 127).

3 DEW / General Comment ▪ The South Australian Government is currently developing a ▪ Noted SAAL NRM groundwater model for the Far North Region, with the intent of reviewing current and future cumulative drawdown impacts Board resulting from groundwater extraction. There is very little structural and groundwater data in the Simpson/Pedirka region. DEW request the provision of data from petroleum exploration to support development of the groundwater

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No. Agency General Comment Comment / Issue Raised Tri-Star Response or EIR / SEO model. Key data would include stratigraphy, well construction, baseline formation pressure, groundwater temperature and quality (if available).

4 DEW / General Comment ▪ Title of documents to also include Eromanga Basin, which is ▪ Noted and Amended, updated to Regions rather than Basins. SAAL NRM also a target for hydraulic fracturing. An alternative is to rename as Simpson and Pedirka Regions, rather than Basins. Board 5 DEW / General Comment ▪ To assist the review process, revised versions of EIR/SEO ▪ Noted, track changes have been used to make changes (excluding SAAL NRM documents are to include tracked changes or an appendix formatting changes and this summary of agency consultation and summarising changes. responses) Board 6 DEW EIR ▪ Page 8 – DEW no longer administers the Pastoral Land ▪ Noted and Amended Management and Conservation Act 1989. That is now PIRSA.

2 DEW EIR ▪ Page 11 – first paragraph mentions ‘Public Access ▪ Noted and Amended Routes’. Incorrect terminology as Public Access Routes traverse pastoral stations to a point of interest under the Pastoral Land Management and Conservation Act. One leads from the Birdsville Track over the Warburton Crossing to the Munga-Thirri – Simpson Desert Regional Reserve. The tracks in the Regional Reserve and Conservation Park are ‘public access tracks’. 3 DEW EIR ▪ Page 14 – borrow pits. Use existing borrow pits where possible ▪ Noted, Tri-Star will liaise with DEW on this matter, and existing as some exist along the Rig Road where previous companies borrow pits will be used where practicable. clay capped dunes for large rigs to get over. If some dunes ▪ The following text has also been included in the SEO and EIR “Utilise need to be recapped in consultation with DEW, then these old existing borrow pits where practicable and appropriate.” (included in borrow pits may be of some use. If it is possible to avoid SEO at Objective 2 - Minimise disturbance to native vegetation and native fauna, Guide to How Objectives can be Achieved, and included capping and creating borrow pits then this would be in the EIR Environmental Risk Assessment (Table 5.5) under relevant preferable. headings).

4 DEW EIR ▪ Page 18 – aircraft Landing Areas. Can DEW access these for ▪ Noted, Tri-Star will liaise with DEW and other stakeholders on this emergency situations or park maintenance in consultation with matter Tri-Star? Can Graham Scott from Mt Dare use these in consultation with Tri-Star to drop of parts for broken down vehicles as he is now the only person recovering vehicles out of the desert? Can RFDS use these in consultation with Tri-Star to extract injured visitors from the desert? In negotiation between Tri-Star and DEW, can these be left after Tri-Star has departed for use by DEW/RFDS?

5 DEW / EIR ▪ Page 33 – sewage waste. Even though they mention the EPA ▪ Noted, storage ponds, including evaporation ponds, will be securely SAAL NRM Act, waste sites need to be fenced off to keep animals out of fenced to exclude stock and large native fauna as is standard practice the evaporation ponds. Board

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No. Agency General Comment Comment / Issue Raised Tri-Star Response or EIR / SEO 6 DEW EIR ▪ Page 34 – waste pipe from drilling, etc. In consultation with ▪ Noted, Tri-Star will liaise with DEW on this matter DEW, an opportunity for Tri-Star to truck waste bore casing and drill pipe to Port Augusta and donate to DEW to be recycled into fencing to protect National Parks in our region from stray and feral animals. 7 DEW / EIR ▪ DEW: Page 35 and 36 – bore heads and turkey nests. Stored ▪ Noted SAAL NRM surface water will be a big issue with camels. The only Board appropriate fencing around these ponds is to use pipe. Any form of wire is a waste of time. See image below to see the most effective way to keep camels away from water sources. ▪ SAAL NRM Board: Page 35 and 36 - bore heads and turkey nests. Stored surface water will be a big issue with camels. The only appropriate fencing around these ponds is to use pipe as camels can destroy wire fences.

8 DEW EIR ▪ Page 66, Table 4.6. This table does not concur with Figure 5.1 ▪ Noted, Figure 5-1 updated to illustrate geological formations (page 120). Clarify whether the Toolebuc fm is also a potential surrounding the Toolebuc Shale target. If yes, the risk of fracture propagation to the underlying Cadna-owie/Algebuckina formations (GAB aquifers) would need to be considered. 9 DEW EIR ▪ Page 94 –how do they propose to implement vehicle hygiene? ▪ All reasonable and practical endeavours will be taken to minimise the In the vineyards further south and in some abattoirs vehicles risks of introducing weeds, pathogens and pests into the licence area. must drive through a disinfectant bath. Having drivers just check for seeds won’t do very much at all which does not even ▪ Vehicles and equipment entering the licence area will be clean and work in vineyards. Maybe there is a wash down area where free of soil and plant material. vehicles need to drive through? ▪ Environmental assessments will be undertaken during the planning stage to identify specific issues / weed presence within survey area.

Tristar Drilling EIR Rev0 156 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

No. Agency General Comment Comment / Issue Raised Tri-Star Response or EIR / SEO 10 DEW EIR ▪ Page 100 – Use of roads and movements of vehicles and heavy ▪ Noted, Tri-Star will liaise with DEW on this matter machinery and authorised sites – If there is a need for any track closures due to exploration/extraction activities such as moving large rigs, DEW must be notified a month in advance in an attempt for DEW to get information out to people that are heading to the desert. Tri-Star will need install temporary signs at the appropriate track junctions to notify visitors and having signs at junctions will enable visitors to change their travel route without adding extra time and using extra fuel (if a sign was say 40km away from a junction), with fuel being critical out in the desert.

11 DEW / EIR ▪ Page 127 event 'Fracture propagation from Eromanga Basin ▪ a) Noted and amended targets into adjacent GAB aquifers'. SAAL NRM ▪ b) Aquifer proximity to fracture stimulation targets is dependent on a Board ▪ a) Potential environmental impact should read 'Adverse number of geological factors including lithology, structure, rock stress impacts to groundwater users and groundwater resources'. and rock strain. These parameters will be incorporated into the design process as discussed in Section 3.3.2. Where the stimulation ▪ b) Management strategy 'Fracture stimulation candidates model demonstrates potential risk to an overlying or underlying are excluded where water risk is apparent due to close aquifer, the stimulation program will be adjusted until these risks can proximity to overlying aquifers'. Define close proximity. This be mitigated. In the event the risk cannot be mitigated, the stage will could be supported by data from previous fracturing be aborted. activities, e.g. total number of fracture stimulations, type (horizontal / vertical), basin, formation, depth and modelled ▪ c) Noted v observed dimensions. Strat logs near/within PELs suggest the Poolowanna fm underlying GAB aquifers is between 40 - 230 metres thick in this region. ▪ c) Tri-Star to provide validation pressure data (page 32) to DEM to demonstrate containment and compliance with this objective.

12 DEW / EIR ▪ DEW: Page 128 states no adverse impact to GDEs. How will ▪ Noted. The location, potential risk of impacts to GDEs and SAAL NRM compliance with this objective be assessed? How will the compliance processes will be assessed by the DEM Stage 3 approval process for proposed activities e.g. environmental assessments will Board location of GDEs be determined? Suggest consulting BOMs GDE be undertaken for proposed activities. DEW mapping project noted, Atlas in the first instance, which shows moderate potential for and Tr-Star will utilise available GDE mapping from State and aquatic and terrestrial GDEs on all PELs: National mapping where available. http://www.bom.gov.au/water/groundwater/gde/map.shtml. Would be useful to provide a map in the EIR. This text also appears as a management strategy on page 116. ▪ SAAL NRM Board: Page 128 states no adverse impact to GDEs. How will compliance with this objective be assessed? How will the location of GDEs be determined? DEW Science Information staff are working on a mapping project to define shallow GDEs throughout SA. This should be sourced to complement the national GDE mapping (Technical contact: Trevor Hobbs).

Tristar Drilling EIR Rev0 157 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

No. Agency General Comment Comment / Issue Raised Tri-Star Response or EIR / SEO 13 DEW / EIR ▪ Sections 3.2.1, 5.2.2 and 5.3.7 - works which require ▪ Noted SAAL NRM modifications to watercourses may require a water affecting Board activity permit. 14 DEW / EIR ▪ Existing groundwater users are referenced throughout the ▪ Specific identification of existing groundwater users will be SAAL NRM document. Provide a map showing where these are in relation undertaken following liaison with potentially affected parties e.g. landholders (this will depend on the location of proposed activities, Board to PELs. which are yet to be decided / identified). The location of existing groundwater bores in the licence area and surrounding region are detailed in Table 4.8 and displayed on Figure 4-15 in the EIR.

15 DEW / EIR ▪ Editorial: figures are occasionally of poor quality and difficult to ▪ Noted SAAL NRM read (e.g. Figure 3-9), suggest revision. Board 1 DEW / SEO ▪ Page 1 – works which require modifications to watercourses ▪ Noted SAAL NRM may require a water affecting activity permit. Please talk to Board DEW as soon as you have more information about your work program. 2 DEW / SEO ▪ Page 12 – re-use old borrow pits where possible in consultation ▪ Noted, please refer to Tri-Star comments on borrow pits above SAAL NRM with DEW. (Question 3, DEW, EIR) Board 3 DEW / SEO ▪ Page 15 – reference in pond decommissioning to also remove ▪ Requirement to remove the turkey’s nest liner is noted in Section SAAL NRM lining from all ponds. 3.5.1 (Initial Restoration). Board ▪ Section 3.5.1 (Partial Restoration) has been updated to include a general reference to the removal of pond liners where ponds are no longer required.

4 DEW / SEO ▪ Page 20 – fire breaks. After seasons of above average rains ▪ Noted. Appropriate fuel reduction activities around infrastructure SAAL NRM where grass/forb fuel loads build up quickly, slash fire breaks would be undertaken (where appropriate and permitted) following above average rainfall seasons. Board around infrastructure. 5 DEW / SEO ▪ Appendix C is missing from the document. ▪ Noted, will be included in final document. Can be accessed on the SAAL NRM DEM website in the interim. Board 6 DEW / SEO ▪ Ensure comments on the EIR are carried through to the SEO ▪ Noted, revisions have been carried across where required. SAAL NRM Board 1 DPTI EIR: Section 3 This comment / issue has been summarised based on a range of emails ▪ Tri-Star expects road use will be similar to existing activities in the SEO: Appendix A: between DPTI, DEM and Tri-Star regarding traffic management. The Cooper Basin, albeit at much less frequency given the exploratory Environmental comments were raised in regard to preliminary review of both the nature of the proposed activities.

Tristar Drilling EIR Rev0 158 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

No. Agency General Comment Comment / Issue Raised Tri-Star Response or EIR / SEO Objectives and draft Tri-Star Geophysical Operations in the Simpson and Pedrika ▪ The requirement for road upgrades to DPTI roads to facilitate access Assessment Regions SEO/EIR, and draft Petroleum Exploration Activities in the is not expected to be required. Criteria, Simpson and Pedrika Regions SEO/EIR. ▪ The majority of road maintenance or upgrade works (if required) are Objectives 7 and 8 Issue Summary: expected to occur within the Simpson Desert Regional Reserve. ▪ DPTI raised concerns regarding use of DPTI roads and potential ▪ The need to close any DPTI roads is also not expected. traffic volumes in the licence area region. ▪ Tri-Star expects to access the licence area from the eastern side, and ▪ DPTI and Tri-Star acknowledged that the majority of daily vehicle movements associated with seismic/drilling campaigns the likely route would be via the Birdsville Track – Yelpawaralina would more than likely occur within the PEL boundaries and Track – Warburton Track - Rig Road. movements to/from DPTI roads would occur infrequently. ▪ Tri-Star will provide a Traffic Management Plan to DPTI for review ▪ DPTI and Tri-Star both acknowledged there is difficulty to prior to the commencement of each stage of the proposed activities confirm equipment requirements for an exploration program as part of the DEM Stage 3 approval process. prior to confirming an exploration program’s objectives. ▪ The Traffic Management Plan will address the criteria requested by ▪ DPTI stated that potential impacts to the DPTI road network DPTI (where relevant). relates to the following two stages: ▪ The SEO, Appendix A: Environmental Objectives and Assessment - Seismic survey and potential drilling e.g. seismic trucks, Criteria has been updated to include the following: recording vehicles and support convoy ▪ Objective 8, Assessment Criteria: - Well construction e.g. small rig approx. 50 trailers or large rig approx. 100 trailers, construction/earthmoving - “A traffic management plan will be provided to DPTI (as part of vehicles, on-site concrete batching (material delivery?), the Stage 3 approval process) for review prior to employee compounds, water/refuse vehicles etc. commencement of drilling activities^ - As noted in the stakeholder meeting large wells typically ^the traffic management plan will address the headings listed in the need Road Train access and small rigs may have OS/OD Guide to How Objectives Can Be Achieved” components. ▪ ▪ DPTI requested a Traffic Management Plan is provided to DPTI Objective 8, Guide to How Objectives Can be Achieved: prior to undertaking each stage of proposed activities, and that - “DPTI traffic management plan developed to address the the plan address the following criteria: following criteria (where relevant): - Type and volume of vehicles for each stage of the proposed Tri-Start activities, including seismic and drilling; - Type and volume of vehicles for each stage of the proposed drilling activities; - The final access route used during seismic and drilling campaigns; - The final access route used during drilling campaigns; - Details of any DPTI road upgrades or routine inspections - Details of any DPTI road upgrades or routine inspections and and maintenance required to facilitate the ongoing maintenance required to facilitate the ongoing activities; activities; - Details of delivery times i.e. survey schedule (if known); - Details of delivery times i.e. campaigns and well construction (if known); - Details of proposed road closures (i.e. exclusion periods) and their management; - Details of proposed road closures (i.e. exclusion periods 1/12 till 15/3 for NPWS) and their management; - Details of any permits required; - Details of any permits required; - Details of all required road signs and advisory signs;

Tristar Drilling EIR Rev0 159 Tri-Star Energy Company Environmental Impact Report – Petroleum Exploration Activities in the Simpson and Pedirka Regions

No. Agency General Comment Comment / Issue Raised Tri-Star Response or EIR / SEO - Details of all required road signs and advisory signs; - Where required, details of any approvals/permits (from the - In the event that Restricted Access Vehicles (including National Heavy Vehicle Regulator) for Restricted Access Vehicles oversize and overmass components) are proposed to be (including oversize and over mass components); utilised, the applicant must ensure that all necessary approvals/permits are obtained from the National Heavy - Where required, a route risk assessment for roads intended for Vehicle Regulator; and any oversize/over mass vehicles (as per the requirements of the - A route risk assessment for roads intended for any National Heavy Vehicle Regulator).” oversize/overmass vehicles as per the National Heavy The EIR risk assessment Table 5.5 (Activity “Use of roads and tracks; Vehicle Regulator (refer link: https://www.nhvr.gov.au). movement of vehicles and heavy machinery”) has also been updated to reflect the requirement for a traffic management plan to be provided to DPTI as part of the Stage 3 approval process.

Tristar Drilling EIR Rev0 160