Transcript

Gorgon Project

Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0

Revision Date: 20 October 2017 Next Revision Due: Information Sensitivity: Company Confidential

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page iii Information Sensitivity: Company Confidential Uncontrolled when Printed

Contents

1.0 Introduction ................................................................................................. 5 1.1 Purpose .................................................................................................... 5 1.2 Licencing Strategy ...................................................................................... 5 1.3 Document Scope ........................................................................................ 6

2.0 Project Location and Tenure ........................................................................... 8 2.1 Project Location ......................................................................................... 8 2.2 Tenure ...................................................................................................... 8 2.3 Proof of Occupier Status .............................................................................. 8

3.0 Premise Categories and Boundary ................................................................... 9 3.1 Prescribed Premises Boundary .................................................................... 11 3.2 Existing Licensed Facilities ......................................................................... 11

3.2.1 LNG Train 1 Licence L8952/2016/1 ...................................................... 11 3.2.2 LWF L8894/2015/1 ........................................................................... 11 3.2.3 BWWTP Licence L8479/2010/2 ............................................................ 12 3.2.4 Waste Transfer Station L8751/2013/1 .................................................. 12 3.2.5 Temporary Power Station L8794/2013/1 .............................................. 12

4.0 Facility Description and Plant Process ............................................................ 14 4.1 Introduction ............................................................................................ 14 4.2 Pre-treatment .......................................................................................... 14

4.2.1 Jansz and Gorgon Inlet Processing, MEG Regeneration, and Condensate Stabilisation ................................................................................................. 14 4.2.2 Acid Gas Removal Unit – Trains 1, 2, and 3 .......................................... 15

4.3 LNG Production ........................................................................................ 15 4.3.1 Dehydration and Mercury Removal in LNG Trains ................................... 15 4.3.2 Liquefaction, Fractionation, and Refrigerant Make-up in LNG Trains .......... 15 4.3.3 Nitrogen Removal and End Flash Gas Compression in LNG Trains ............. 16

4.4 Associated Facilities .................................................................................. 16 4.4.1 LNG and Condensate Storage ............................................................. 16 4.4.2 Fuel Gas System and Recycle Gas System ............................................ 16 4.4.3 Power Generation System .................................................................. 16 4.4.4 Heating Medium Heaters .................................................................... 17 4.4.5 Flare Systems .................................................................................. 17 4.4.6 Chemical Storage .............................................................................. 17 4.4.7 Domestic Gas Export ......................................................................... 17

5.0 Other Approvals and Consultation ................................................................. 18 5.1 Part IV of the EP Act ................................................................................. 18

5.1.1 Long-term Marine Turtle Management Plan ........................................... 18 5.1.2 Solid and Liquid Waste Management Plan ............................................. 19 5.1.3 Terrestrial and Subterranean Environment Monitoring Program ................ 19 5.1.4 Best Practice Pollution Control Design Report ........................................ 19 5.1.5 Air Quality Management Plan .............................................................. 19

5.2 Department of Mines, Industry Regulation, and Safety ................................... 20 5.3 Radiation Approvals from the Department of Health ...................................... 20 5.4 Local Government Planning and Building Approvals ....................................... 21 5.5 Stakeholder and Community Consultation .................................................... 21

6.0 Inputs, Outputs, Emissions and Discharges .................................................... 22 6.1 Inputs to Gas Treatment Plant ................................................................... 22 6.2 Outputs from Gas Treatment Plant .............................................................. 22

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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6.2.1 Products .......................................................................................... 22 6.2.2 Liquid Wastes ................................................................................... 22 6.2.3 Solid Wastes .................................................................................... 22 6.2.4 Atmospheric Emissions ...................................................................... 23

6.3 Proposed Monitoring ................................................................................. 23 6.3.1 Stack Emission Monitoring Program ..................................................... 24 6.3.2 Ambient Air Quality Monitoring ............................................................ 25

7.0 Other Relevant Information .......................................................................... 26 8.0 Licence Application Fee Calculation ................................................................ 28 9.0 Acronyms and Abbreviations ........................................................................ 29 10.0 References ................................................................................................ 32

Tables

Table 1-1: Supporting Information .............................................................................. 6 Table 3-1: Applicable Schedule 1 Prescribed Premises Category Criteria ......................... 10 Table 6-1: GTP Atmospheric Pollutants and Air Toxics Emissions and Sources ................. 23 Table 6-2: Stack Emission Monitoring Program during LNG Train 1, 2, and 3 Operations ... 24 Table 8-1: Licence Fee Calculation ............................................................................ 28 Table 9-1: Acronyms and Abbreviations ..................................................................... 29 Table 10-1: References ........................................................................................... 32

Figures

Figure 4-1: LNG Production Process and Associated Facilities ........................................ 14

Appendices

Appendix A Proof of Occupier Status ......................................................................... 34 Appendix B Prescribed Premises Boundary ................................................................. 35 Appendix C GPS Coordinates of Prescribed Premises Boundary ..................................... 36 Appendix D Emission and Discharge Points ................................................................ 37 Appendix E Pollution Control Equipment .................................................................... 38 Appendix F Monitoring Equipment ............................................................................. 39 Appendix G 3-Train Licence Fee Data .........................................................................40

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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1.0 Introduction Chevron Australia Pty Ltd (Chevron Australia) is the proponent and the person taking the action for the Gorgon Project on behalf of the following companies (collectively known as the Gorgon Joint Venturers):

• Chevron (TAPL) Pty Ltd

• Chevron Australia Pty Ltd

• Shell Australia Pty Ltd

• Mobil Australia Resources Company Pty Limited

• Osaka Gas Gorgon Pty Ltd

• Tokyo Gas Gorgon Pty Ltd

• JERA Gorgon Pty Ltd.

1.1 Purpose This document provides information to support the application for a licence to operate the three-train (3-Train) Gorgon Liquefied Natural Gas (LNG) Gas Treatment Plant and associated infrastructure (GTP) on Barrow Island. Specifically, this document provides information required for Attachment 2, 3A, 4, 6A, 6B and 9 of the Western Australian (WA) Department of Water and Environmental Regulation (DWER) Application Form: Works Approval, Licence, Renewal, Amendment or Registration (July 2017 V7) (the Application Form; Ref. 1). Note that the Department of Environment Regulation changed its name as of 1 July 2017. The current name DWER will be used throughout this application.

1.2 Licencing Strategy The intention is to secure a single licence that includes

• LNG Trains 1, 2, and 3, including the Low Pressure Mixed Refrigerant (LP MR) andHigh Pressure Mixed Refrigerant and Propane Refrigerant (HP MR/PR) compressors;Jansz and Gorgon Inlet Facilities; plus, Jansz and Gorgon Monoethylene Glycol(MEG) regeneration plants and MEG tanks; Acid Gas Removal Unit (AGRU) Trains 1,2, and 3; and all flares

• Condensate processing facilities

• Domestic Gas (DomGas) plant

• Ancillary support facilities including:

• product storage, including LNG and Condensate Tanks

• power generation Gas Turbine Generator (GTG) 1, 2, 3, 4, and 5

• permanent diesel storage facilities

• waste management facilities including:

Waste Transfer Station (WTS)

mercury-contaminated waste storage

waste concrete storage

Bridging Wastewater Treatment Plant (BWWTP)

Liquid Waste Facility (LWF), including Permanent Waste Disposal (PWD)wells and temporary wastewater disposal facilities (such as the TemporaryWastewater Injection Plant [TWIP]).

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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Several of these facilities are already licensed, pursuant to the requirements of Part V of the Environmental Protection Act 1986 (WA) (EP Act), such as

• LNG Train 1 (L8952/2016/1; Ref. 2)

• LWF (L8894/2015/1; Ref. 3)

• BWWTP (L8479/2010/2; Ref. 4)

• WTS (L8751/2013/1; Ref. 5).

To avoid regulatory duplication, when the 3-Train licence (including these facilities) is granted, Chevron Australia will request the concurrent surrender of these licences: LNG Train 1 L8952/2016/1 (L8952), LWF L8894/2015/1 (L8894), BWWTP L8479/2010/2 (L8479), and WTS L8751/2013/1 (L8751). Applications for the surrender—using the prescribed forms—will be prepared and submitted before the grant of the 3-Train licence.

Commissioning of the Permanent Wastewater Treatment Plant (PWWTP) has been delayed and the facility cannot be included in this licence application. It is intended that the 3-Train licence will be amended in due course to include the PWWTP.

1.3 Document Scope This application proposes to licence the GTP as defined in Section 1-2, using feed gas delivered from the Jansz and Gorgon gas fields. In accordance with the DWER Application Form, Table 1-1 provides a summary of the supporting information provided in this document.

Table 1-1: Supporting Information

Application Form Attachment and Information Required

Section of Document

Attachment 1A as required by Part 1.8 of Application Form

• Proof of Occupier Status

Section 2.0 and Appendix A

Attachment 2 as required by Part 2.4 and 3.9 of Application Form

• Premises Boundary and coordinates,• Licence Categories• Existing Licenced Facilities

Section 3.0 and Appendix B & C.

Attachment 3A a required by Part 3.10 of the Application Form

• Proposed Activities and Description

Section 4.0

Attachment 4 as required by Part 4.9 of Application Form

• Other Approvals

Section 5.0

Attachment 6A as required by Part 6 of Application Form

• Inputs and Outputs• Emissions and Discharges• Proposed Monitoring

Section 6.0

Attachment 8 as required by Part 8.1 of the Application Form – Other relevant information

• EP Act Part IV and Part V Commitments

Section 7

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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Attachment 9 as required by Part 9.4 and 9.8 of Application Form

• Fee Calculation and Data

Section 8.0 and Appendix G

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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2.0 Project Location and Tenure

2.1 Project Location The Greater Gorgon Area, which includes the Gorgon and Jansz–Io (Jansz) gas fields, is located approximately 130 km off the north-west coast of WA. Barrow Island is located off the Pilbara coast, 85 km north-north-east of Onslow and 140 km west of Karratha. Barrow Island is the largest of a group of islands, which includes the Montebello, Varanus and Lowendal Islands.

2.2 Tenure Barrow Island is reserved under the Conservation and Land Management Act 1984 (WA) as a Class A nature reserve for the purposes of ‘Conservation of Flora and Fauna’. As such Barrow Island is a “specified Ecosystem” for the purposes of Environmental Guidance Statement: Siting (Ref. 6). Since 1967 Barrow Island has also supported a producing oilfield, also operated by Chevron Australia on behalf of the WA Oil Joint Venture. Petroleum extraction and associated activities are carried out under the L1H R1 petroleum retention lease granted pursuant to the Petroleum Act 1936 (WA). Areas of land on Barrow Island required for the Gorgon Gas Development and supporting infrastructure works were excised from the existing L1H R1 lease and transferred to the Gorgon Joint Venture.

The Barrow Island Act 2003 (WA) is the primary legislative instrument that enables establishment of the Gorgon Gas Development. Under this Act and subject to approved Gorgon Gas Development Proposals and ministerial approvals, the Gorgon Joint Venture has permission to seek tenure for uncleared land on Barrow Island for the Gorgon Gas Development. Land access for the works was granted in accordance with the provisions of the Land Administration Act 1997 (WA).

2.3 Proof of Occupier Status Details of certificate of title, lease, or other instruments evidencing proof of occupier status including the expiry date (or confirmation that there is no expiry date) have been provided in Appendix A as required by Part 1.8 of the Application Form.

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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3.0 Premise Categories and Boundary This application proposes to licence the three LNG trains and their associated infrastructure, which includes, but is not limited to:

• Jansz and Gorgon Inlet facilities and slugcatchers

• GTGs 1 to 5

• AGRU Trains 1 to 3

• Refrigeration and compression facilities, including the Gas Turbines (GTs) and WasteHeat Recovery Units (WHRUs)

• DomGas plant

• LWF

• Class 1, 2, 3, and 4 drainage systems

• MEG regeneration facilities for both the Jansz and Gorgon systems

• Heating Medium Heaters (HMHs)

• LNG and Condensate Storage Tanks

• WTS

• Wet, dry, and Boil-off Gas (BOG) flare systems

• Bridging Wastewater treatment plant.

Note that the CO2 Injection system is not ready to be operated due to technical issues and is not included in this licence application. Please refer to Part 6.1 of the Application Form for more information.

Pursuant to Sections 56 and 57 of the EP Act, and Parts 1 and 2 of Schedule 1 of the Environmental Protection Regulations 1987 (WA), this licence application is for Prescribed Premises Categories:

• 10 (oil and gas production)

• 34 (oil and gas refining)

• 52 (electrical power generation)

• 54 (sewage facility)

• 62 (solid waste depot)

• 73 (bulk storage of chemicals).

Table 3-1 lists the proposed throughput criteria for each Prescribed Premises Category.

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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Table 3-1: Applicable Schedule 1 Prescribed Premises Category Criteria

Prescribed Premises Category

Description

Design or Production Throughput

Classification

Design (or Production) Throughput1

10 Oil and gas production from wells: premises, whether on land or offshore, on which crude oil, natural gas, or condensate is extracted from below the surface of the land or the seabed, as the case requires, and is treated or separated to produce stabilised crude oil, purified natural gas, or liquefied hydrocarbon gases

5000 tonnes or more per year

• 15,600,000nameplate design(18,000,000production) tonnesper year LNG

• 300 TJ/d DomGas• (1,000,000

production) tonnesper year Condensate

34 Oil and gas refining: premises on which crude oil, condensate, or gas is refined or processed

(N/A) • 15,600,000(18,000, 000production) per yearLNG

• 300 TJ/d DomGas• (1,000,000

production) tonnesper year Condensate

52 Electric power generation: premises (other than premises within Category 53 or an emergency or standby power generating plant) on which electrical power is generated using a fuel

• 20 megawatts(MW) or morein aggregate(using naturalgas)

• 10 MW ormore inaggregate(using fuelother thannatural gas)

584.5 MW

54 Sewage facility: premises on which sewage is treated (excluding septic tanks); or from which treated sewage is discharged onto land or into waters

100 m3 or more per day

1,385 m3 per day

62 Solid waste depot: premises on which waste is stored, or sorted, pending final disposal or re-use

500 tonnes or more per year

• 240,000 tonnes ofstored concrete waste

• 52,050 tonnes ofother solid waste peryear

73 Bulk storage of chemicals etc.: premises on which are stored acids, alkalis, or chemicals that: • contain at least one carbon bond; and• are liquid at standard temperature and

pressure

1000 m3 in aggregate

1,090 m3

1 Note: Production throughputs may exceed the original design throughputs as specified in works approvals. Where indicated, the nameplate design throughput is shown. The production throughput figure, where included, is an estimated potential maximum annual production throughput based on maximum daily rates experienced during the commissioning and start-up phases and assumes plant operation for 342 days each year.

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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3.1 Prescribed Premises Boundary The proposed Prescribed Premises boundary is shown on an aerial photograph and is included in Appendix B.

The boundary details are also provided electronically in GIS coordinate file in Appendix C as required by Section 2.3 of the Application Form.

3.2 Existing Licensed Facilities As advised in Section 1.1, several existing licensed facilities will be included in the 3-Train licence.

3.2.1 LNG Train 1 Licence L8952/2016/1 LNG Train 1 was constructed under Work Approvals W4818/2010/1 (W4818) and W5178/2012/1 (W5178). Construction of the facilities under W4818 included the LNG and Condensate Storage Tanks, the Class 1 to Class 4 Drainage System and the LWF. W5178 allowed for construction of LNG Trains 1, 2, and 3, and associated facilities including the chemical storage tanks, the Gorgon and Jansz MEG regeneration facilities, the Gorgon and Jansz slugcatchers, and the AGRUs.

Staged compliance reports were prepared and submitted to DWER to allow LNG Train 1 to be commissioned and produce LNG. The compliance reports covered the GTGs, GTs, Jansz Inlet facility, the LNG and Condensate Tanks, Jansz MEG tanks and Regeneration plant, AGRU Train 1, the dry, wet, and BOG flares, MRUs, and the Dehydration, Liquefaction, Fractionation, and Refrigerant Make-up systems for LNG Train 1. A Partial Emissions Verification Report for LNG Train 1 was submitted to DWER in April 2016.

L8952 was amended in February 2017 to allow for a solid waste depot to be located within the prescribed premise. This amendment allows for up to 240 000 tonnes of waste concrete (produced by removing temporary project buildings) to be stored within the LNG Train 1 prescribed premise.

An Emissions Verification Report covering LNG Trains 1, 2, and 3 and associated facilities was prepared and submitted to DWER pursuant to the requirements of condition 5 of W5178 on 14 August 2017. The LNG Train 1 licence will be merged with the 3-Train licence when it is issued and the existing licence surrendered.

3.2.2 LWF L8894/2015/1 The LWF was constructed under W4818; it comprises two disposal water tanks, pumping facilities, and steel pipelines running from the GTP site to the two PWD wells. A compliance report was submitted to DWER on 17 April 2015 allowing the facility to be commissioned and L8894 to be issued on 19 October 2015.

Category 61 covers - “liquid waste facility: premises on which liquid waste produced on other premises (other than sewage waste) is stored and, reprocessed, treated or irrigated.”

Category 61 for the LWF was triggered historically by the produced water from the Category 10 oil and gas production Gorgon and Jansz fields being produced on “other premises” and being considered as separate non-contigous premises to the LWF.

The single 3-Train licence will remove the non-contigous aspect. In addition, the produced water is another by-product (similar to natural gas, CO2 and condensate) from Category 10 and 34 Oil and Gas activities. It is therefore proposed that Category 61 is removed from the 3-Train licence similar to condensate storage not being licenced under Category 73.

A request to revoke the LWF licence upon issue of the 3-Train licence will be submitted to DWER.

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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3.2.3 BWWTP Licence L8479/2010/2 The BWWTP was constructed under Works Approval W4685/2010/1; it allows for two-train wastewater treatment with a combined capacity to process 840 m3 of treated effluent per day. A compliance report was submitted to DWER on 28 June 2011; L8479 was subsequently granted on 18 August 2011.

A second Works Approval, W5152/2012/1, was issued to allow an expansion of the BWWTP by building a third train and expanding total capacity to 1385 m3 of treated effluent per day. A compliance report for the expansion was submitted on 30 June 2012 allowing for the third train to begin commissioning on 21 July 2012. The licence amendment was subsequently issued on 21 August 2012.

The BWWTP has operated consistently in compliance with its licence, which is due to expire on 21 August 2019. Due to reduced manning levels on Barrow Island, only two of the three BWWTP trains have been operating, with average treated effluent production in June 2017 of only 482 m3/day.

Treated effluent produced by the BWWTP is licensed to be disposed of by deep well injection to the TWIP or the PWD wells. A recent amendment to the BWWTP removed the requirement to monitor treated effluent disposed of downwell. Once the Permanent Wastewater Treatment Plant is operational, the BWWTP will be used as a backup plant for high-demand periods. The BWWTP will be merged with the 3-Train licence when it is issued and the existing licence surrendered.

3.2.4 Waste Transfer Station L8751/2013/1 The Waste Transfer Station was constructed in stages under Works Approval W4827/2010/1, which was issued on 7 March 2013. The WTS is licensed under Category 61: Liquid Waste Facility and Category 62: Solid Waste Depot. The WTS was built and commissioned in stages, with the Stage 2 Compliance Report submitted to DWER on 20 October 2014.

L8751 was issued on 16 April 2014 and licensed the facility to process liquid and solid waste. The facility is licensed for Inert Waste Type 1 and 2, putrescible waste, and hazardous waste. The current waste quantities allowed are 11 400 tonnes of liquid waste and 51 400 tonnes of solid waste per year. Oily water collected at the WTS is conveyed to other licenced facilities for disposal down well.

Consistent with the LWF in Section 3.2.2, Category 61 for the WTS’s LWF was triggered historically by the wastewater being produced on “other premises” and being considered as separate non-contigous premises to the WTS. The 3-Train licence incorporating the WTS will remove the non-contigous aspect. Category 61 for the WTS will therefore no longer be triggered.

The WTS licence will be merged with the 3-Train licence when it is issued and the existing licence surrendered.

3.2.5 Temporary Power Station L8794/2013/1 The Temporary Power Station (TPS) and diesel tank farm located within the General Utilities Area were approved for construction under W5037/2011/1. A compliance report was submitted to DWER and L8794 issued on 7 May 2015. The TPS is licensed under Category 52: Electric Power Generation and Category 73: Bulk Storage of Chemicals. Capacity of the power plant is 24 MW. The total diesel storage capacity of 1970 m3. The diesel tanks comprise 15 × 110 kL temporary double-skinned tanks and two 160 kL permanent tanks.

The power generation plant was put under care and maintenance in August 2016. The 8 × 110 kL diesel tanks used to supply diesel to the generators were put under care and maintenance in February 2017.

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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This leaves the combined diesel storage capacity of 1090 kL (the two 160 kL permanent tanks and 7 × 110 kL temporary tanks) still operable and triggers Category 73 of the EP Regulations. The diesel storage tanks will be merged with the 3-Train licence when it is issued and the existing licence surrendered. The TPS power generators will not be merged with the 3-Train licence.

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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4.0 Facility Description and Plant Process

4.1 Introduction This Section describes the facilities subject to this licence application. Figure 4-1 shows elements of the LNG production process and associated facilities, as described in the following subsections.

Figure 4-1: LNG Production Process and Associated Facilities

4.2 Pre-treatment

4.2.1 Jansz and Gorgon Inlet Processing, MEG Regeneration, and Condensate Stabilisation

The Jansz and Gorgon feed gas arrives separately at dedicated Jansz and Gorgon inlet processing facilities (slugcatchers) that segregate incoming fluids into three streams:

• gas

• condensate

• aqueous MEG solution.

The inlet facilities provide steady flow rates to the downstream units. A portion of the gas is sent to the DomGas plant for processing. The gas streams are sent to the AGRU Trains 1, 2, and 3. The condensate stream is sent to the Condensate Stabilisation Units, where further stripping of the light hydrocarbon components occurs to produce a stabilised condensate stream, which is combined with the condensate from the Fractionation Unit before storage and export.

The aqueous MEG solutions are sent to the separate Jansz and Gorgon MEG Regeneration Units, to regenerate the rich (water-saturated) MEG by removing water and salts to meet lean (water removed) MEG specifications. The lean MEG is then re-used and recycled to the Jansz and Gorgon production wellheads. There it is injected into the feed gas stream to inhibit hydrate formation in the subsea pipelines. Various chemicals, such as hydrochloric acid and sodium hydroxide, are used in the MEG

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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regeneration process. Water separated from the hydrocarbon streams is then sent to the LWF for disposal.

4.2.2 Acid Gas Removal Unit – Trains 1, 2, and 3 The Jansz and Gorgon gas stream from the slugcatchers and the Condensate Stabilisation Units are then routed to the AGRU Trains 1, 2, and 3. Jansz and Gorgon gas can either be blended together or processed separately in the AGRU trains. The blend of feed gas entering each AGRU is flexible, ranging from 0% to 100% of Gorgon or Jansz gas, with the balance from the alternative source.

A Mercury Removal Unit (MRU) removes mercury (Hg) from the gas stream before entering each AGRU. Carbon dioxide (CO2) and hydrogen sulfide (H2S) and minor residual amounts of volatile organic compounds (VOCs) (collectively termed ‘acid gas’), are removed from the gas stream using proprietary activated methyldiethanolamine (aMDEA) or amine technology. Acid gas is removed from the natural gas to prevent it from freezing at low temperatures in the cryogenic sections of the GTP and to meet the LNG product specifications.

Each AGRU comprises three subsystems:

• an MRU to remove mercury

• an Absorber System designed to remove acid gas from the feed gas by absorption to an aMDEA solvent

• a Regeneration System to treat the aMDEA solvent for re-use in the AGRU by separating it from the acid gas components that were removed from the natural gas in the Absorber System.

Currently, all acid gas recovered from Jansz and Gorgon reservoirs by the AGRUs is vented through Vent 1 in each AGRU train. Treated feed gas passes to the Dehydration Units. Once the CO2 Injection System is commissioned and operating it will allow all acid gas to be disposed of down hole.

4.3 LNG Production

4.3.1 Dehydration and Mercury Removal in LNG Trains The Dehydration Unit in LNG Trains 1, 2, and 3 removes water from the feed gas leaving the AGRUs. The treated gas is then dried in a molecular sieve to remove the final traces of water and to prevent hydrate formation in the Liquefaction Unit; hydrate formation could cause blockages of lines and equipment. The MRUs in each LNG train removes any remaining mercury from the main gas stream entering the train that could otherwise cause erosion and corrosion of aluminium tubing in the Liquefaction Units.

4.3.2 Liquefaction, Fractionation, and Refrigerant Make-up in LNG Trains

Heavy hydrocarbons, which can freeze in the LNG, need to be removed before the dry treated gas can be liquefied. The dry treated gas is pre-cooled and fed to the Scrub Columns in each LNG train to remove heavy hydrocarbons and aromatics to comply with LNG product specifications and to prevent freezing in the Main Cryogenic Heat Exchanger. The liquids from the Scrub Columns are directed to the Fractionation Unit, which uses heat and pressure to separate the liquids into various components; lighter components (methane, ethane, propane, and butane) exceeding those required for refrigerant make-up are returned to the LNG process. The remaining stable liquid is directed to the Condensate Tanks.

Liquefaction is the main component of the LNG trains; using large GT-driven compressors and a series of cryogenic heat exchangers, liquefaction chills the natural

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

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gas to a temperature at which LNG can be produced. The LNG train refrigeration compressors are each driven by Frame 7 Process GTs supplemented with power from electric helper motors. Mixed Refrigerant (a mixture of nitrogen, methane, ethane, and propane) and Propane Refrigerant are used to liquefy the natural gas into LNG.

4.3.3 Nitrogen Removal and End Flash Gas Compression in LNG Trains

LNG is further cooled in the Nitrogen Column Reboiler and subsequently flashed off in the top of the Nitrogen Rejection Column to remove sufficient nitrogen from the LNG to comply with the LNG product specification. The LNG product is pumped to the LNG Storage Tanks. End flash gas is routed to a multistage End Flash Gas Compressor, which compresses it to the pressure required for the High-pressure Fuel Gas System.

4.4 Associated Facilities

4.4.1 LNG and Condensate Storage Two cryogenic LNG Storage Tanks store the LNG received from each LNG train’s Nitrogen Rejection Column. BOG from the LNG Storage Tanks is collected, compressed, and returned to the High-pressure Fuel Gas System (see Section 4.4.2) for the LNG trains or flared.

Condensate Storage Tanks store the stabilised condensate product received from the Fractionation and Condensate Stabilisation Units. The GTP includes four Condensate Storage Tanks.

All storage tanks operate at atmospheric pressure.

4.4.2 Fuel Gas System and Recycle Gas System The Fuel Gas and Recycle Gas Systems provide fuel gas to users throughout the GTP, and return low-pressure gas—unsuitable for use as fuel—to the process for treatment. The system comprises multiple subsystems:

• High-pressure Fuel Gas System in the LNG trains to supply fuel to the refrigerant GTs and seal gas for the End Flash Compressor

• High-pressure Fuel Gas System in the Utilities Area to supply fuel to the GTGs for power generation

• High-pressure Fuel Gas Letdown System to separate low-pressure fuel gas headers to supply the HMHs and the pilots/purging gas for the flare systems

• Recycle Gas System to compress flash gas from the AGRU back to the AGRU inlet for further treatment.

4.4.3 Power Generation System The power generation system generates power for electrical consumers in the GTP and other areas (e.g. Permanent Operations Facility, Butler Park).

Electrical power is provided by Frame 9 GTGs running continuously and sharing the load under normal operating conditions. The GTP includes five Frame 9 GTGs each with a generation capacity of 116.9 MW and therefore a total combined capacity of up to 584.5 MW.

Essential Diesel Generators (EDGs) supply essential power. They are situated next to the power generation systems and are expected to be used infrequently and for short periods when the Frame 9 GTGs are unavailable, e.g. during shutdowns and maintenance.

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4.4.4 Heating Medium Heaters The Heating Medium System is a pressurised, closed-loop, hot demineralised water recirculating system. Make-up water is provided by the Demineralised Water System, which distributes demineralised water to multiple areas in the GTP. Heat is recovered from the available waste heat from GT exhausts in the WHRUs and sent to various heat consumers around the GTP, including inlet gas heating, AGRU reboilers, and the MEG regeneration package. The HMHs are expected to be used only occasionally, when duty heat from the WHRUs is not sufficient to meet demand.

4.4.5 Flare Systems These flare systems safely dispose of hydrocarbons by combustion:

• ground flare, comprising wet and dry flare systems

• BOG flares.

The ground flare segregates wet (containing water or water vapour), heavy hydrocarbons, and light, dry (water-free), potentially cold hydrocarbons to restrict hydrate formation, freezing, or condensation. The wet and dry ground flare systems each comprise a collection header system for vapours and a collection header system for liquids, a knockout drum, and a staged ground flare.

The BOG flare system comprises two 100% low-pressure flares. The BOG flare system was originally set up to allow one flare to be operational and one spare; however, it has now been modified to allow both flares to operate simultaneously if required.

The BOG flare system collects emergency and operational releases during LNG storage and loading. BOG should usually be sent to the BOG Compressor and the BOG Recycle Compressor and recycled back through the GTP.

4.4.6 Chemical Storage In addition to LNG and condensate, numerous chemicals are required to be used and stored throughout the Prescribed Premises boundary to support the operation of LNG trains and associated facilities. Chemicals are stored in areas designed to prevent loss of containment to the environment.

4.4.7 Domestic Gas Export The DomGas Unit processes feed gas to meet the pipeline moisture and hydrocarbon dewpoint specifications required for export to the Dampier to Bunbury Natural Gas Pipeline.

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5.0 Other Approvals and Consultation This section provides information required by Attachment 4: Other Approvals and Consultation.

The operation of the GTP is subject to various State and Commonwealth regulatory frameworks. The existing regulatory frameworks that manage the emissions, wastes, and discharges from the GTP are described below.

5.1 Part IV of the EP Act The Gorgon Gas Development was approved under Part IV of the EP Act by Ministerial Statement (MS) 800. The conditions of MS 800 require a suite of Ministerial Deliverables to be in place during the construction and operation of the Gorgon Gas Development. Where Ministerial Deliverables required by MS 800 provide sufficient control for managing emissions from the operation of the GTP, this application refers to those existing controls to avoid regulatory duplication under Part V of the EP Act.

The Part IV Ministerial Deliverables that specifically manage relevant environmental risks throughout this application are:

• Long-term Marine Turtle Management Plan (LTMTMP; Ref. 6)

• Solid and Liquid Waste Management Plan (SLWMP; Ref. 7)

• Terrestrial and Subterranean Environment Monitoring Program (TSEMP; Ref. 8)

• Best Practice Pollution Control Design Report (BPPCDR; Ref. 9)

• Air Quality Management Plan (AQMP; Ref. 10).

5.1.1 Long-term Marine Turtle Management Plan The LTMTMP (Ref. 6) was developed and approved by the State under the requirements of Condition 16 of MS 800. Commonwealth Condition 12 of the Environmental Protection Biodiversity Conservation Act 1999 (EPBC Act) approval References 2003/1294 and 2008/4178 also covers the LTMTMP. One of the objectives of the LTMTMP is to:

Specify design features, management measures, and operating controls to manage and where practicable, avoid adverse impacts to marine turtles, with specific reference to reducing light and noise emissions as far as practicable.

The LTMTMP includes lighting design features that address, but are not limited to:

• light direction (e.g. downward-facing)

• light reduction measures (e.g. shielding, unnecessary lighting not used)

• the type of luminaires that should be used

• when lighting is to be turned on or off.

Through the LTMTMP (Ref. 6), an extensive Flatback Turtle monitoring program operates on Barrow Island to measure and detect changes to the Flatback Turtle population. The Marine Turtle Expert Panel established under Condition 15 of MS 800 reviews the reports generated from the LTMTMP audit/review. The LTMTMP also satisfies the Environmental Performance Reporting required under Condition 5 of MS 800 and Condition 4 of EPBC 2003/1294 and EPBC 2008/4178.

A Light Monitoring Program is implemented under the LTMTMP, which includes monitoring of ambient night-time light emissions during operation of the GTP.

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5.1.2 Solid and Liquid Waste Management Plan The SLWMP (Ref. 7) is required by Condition 30 of MS 800. The objectives of this plan are set out in Condition 30.2, which states:

Ensure all Proposal-related solid and liquid wastes are either removed from Barrow Island or, if not, that all practicable means are used to ensure that waste disposal does not cause Material or Serious Environmental Harm to Barrow Island and its surrounding waters.

The SLWMP (Ref. 7) contains management measures that are implemented to ensure that waste disposal meets the objectives set out in Condition 30.2. Therefore, where this licence application identifies waste, relevant controls in the SLWMP are applied.

5.1.3 Terrestrial and Subterranean Environment Monitoring Program Chevron Australia monitors groundwater characteristics of the near-surface aquifer in accordance with The Terrestrial and Subterranean and Environment Monitoring Program (TSEMP, Ref. 8) as required by Condition 8 of MS 800. The objective of the Program is to:

Establish a statistically valid ecological monitoring program to detect any Material or Serious Environmental Harm to the ecological elements outside the Terrestrial Disturbance Footprint.

Where ecological monitoring relates to emissions from the operation of GTP, the TSEMP (Ref. 8) is referenced.

5.1.4 Best Practice Pollution Control Design Report Condition 28 of MS 800 requires the BPPCDR (Ref. 9) to be submitted to DWER as part of its Works Approval application for the GTP. The BPPCDR:

i. Demonstrates that the proposed works adopt best practice pollution controlmeasures to minimise emissions from the GTP

ii. Sets out the base emission rates for the major sources for the GTP and thedesign emission targets

iii. Addresses normal operations, shut down, start-up, and equipment failureconditions.

The BPPCDR (Ref. 9) outlines pollution control equipment for the operation of LNG Trains 1 to 3 and their associated facilities.

Verification of emission predictions from the BPPCDR were included in the EVR (Ref. 12) submitted under Condition 5 of W5178 on 14 August 2017.

5.1.5 Air Quality Management Plan Condition 29.1 of MS 800 required the AQMP (Ref. 10) to be submitted to DWER as part of Chevron Australia’s Works Approval application for the GTP. In 2016 the Office of the Environmental Protection Authority (now part of DWER) approved the amended revision to the AQMP (Revision 2 Amendment 1). This revision is now implemented across the Gorgon Project.

The objectives of the AQMP are to:

i. Ensure air quality meets appropriate standards for human health in theworkplace; and

ii. Ensure air emissions from the Gas Treatment Plant operations do not pose arisk of Material or Serious Environmental Harm to the flora, vegetationcommunities, fauna, and subterranean fauna of Barrow Island

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The Plan also includes:

i. A list of chemicals to be monitored, the location of air quality sampling points and the frequency of air quality monitoring;

ii. Emission targets for these chemicals; and

iii. Performance Standards against which achievement of the objectives of this condition [Condition 29] can be determined.

Chevron Australia has conducted several air quality modelling studies to assess potential impacts from atmospheric pollutants and air toxic emissions on local and regional air quality from the operation of the three LNG train GTP. These studies include the operation of the GTP, and the atmospheric pollutants and air toxic emissions subject to this licence application. The AQMP outlines these studies and summarises their results.

The AQMP (Ref. 10) formed part of the application of W5178/2012/1 and was implemented under Condition 1 of that works approval. The AQMP (Revision 2 Amendment 1) will be implemented under Part V of the EP Act during the operation of the GTP.

Verification of emission predictions from the AQMP were included in the EVR (Ref. 12) submitted under Condition 5 of W5178 on 14 August 2017.

5.2 Department of Mines, Industry Regulation, and Safety The GTP, including the three LNG trains and their associated facilities, is a Major Hazard Facility (MHF) under the Dangerous Goods Safety Act 2004 (WA) administered by the Department of Mines, Industry Regulation, and Safety (DMIRS). Note that the Department of Mines and Petroleum changed its name as of 1 July 2017. The current name DMIRS will be used throughout this application.

When a site is classified as a MHF, the site operator must prepare a safety report for submission to, and approval by DMIRS. The operator must demonstrate that it has taken measures to identify all foreseeable major incidents, their likelihood, and consequences. The operator must also justify the adequacy of the control measures used to minimise the risk of major incidents. This includes preventing loss of containment. Chevron Australia has prepared and submitted to DMIRS the Gorgon Major Hazard Facility Safety Report (Ref. 11), which fulfils the requirements of the Dangerous Goods Safety Act 2004 (WA) in relation to the operation of the GTP as a MHF.

Therefore, where relevant, this licence application references controls that are described in the MHF report for the handling and storage of environmentally hazardous material, as well as the controls that are in place to prevent loss of containment.

5.3 Radiation Approvals from the Department of Health The Radiological Council is an independent statutory authority appointed under the Radiation Safety Act 1975 (WA) and the Radiation Safety (General) Regulations 1983 (WA) to maintain safe practices in radiation use. The Radiological Council is relevant to this licence application because radiation-emitting equipment and radioactive substances are used for activities in the GTP and its associated facilities.

The entire GTP site is certified as a Registered Premises by the Radiological Council (Reg No. RS26/2015 25769). All radiation equipment is registered. Details including equipment manufacturer, model, type, and serial numbers, location, radioactive material, and radiation quantities are provided to the Radiological Council. Licensed Radiation Safety Officers who manage the health, safety, security, and environmental aspects of the registered equipment (Reg No. LS 1054/2014 25512). Registration is required if the radiation quantity exceeds the limits set by the Radiological Council; due to the size of the GTP site, the required certified registrations have been obtained. As

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part of the registration process, Chevron Australia seeks approval from the Radiological Council to use radiation equipment and substances in the GTP.

5.4 Local Government Planning and Building Approvals The Shire of Ashburton is the ‘responsible authority’ appointed under the Planning and Development Act 2005 (WA) and the ‘permit authority’ appointed under the Building Act 2011 (WA). The Shire of Ashburton is relevant to this licence application as it has granted 24 town planning approvals (including four by the Pilbara Joint Development Assessment Panel) for the Gorgon Gas Development.

Since 2005, the Shire has also granted more than 130 building approvals for buildings and structures at various sites assisting the construction, commissioning, and now operation of the GTP. In 2012, under the new Building Act 2011, the Shire granted a Part 5 Building Permit exemption for buildings associated with the GTP, but still required Building and Occupancy Permits for buildings used for, or assisting, accommodation on Barrow Island. The Shire requires all buildings on the island to comply with the Building Code of Australia and applicable Australian Standards, which ensures energy efficiency, fire safety, structural integrity for a Class D Cyclone Region, and general safety of the occupants.

The Shire of Ashburton and the WA Department of Health regulate the installation of sewage treatment facilities and disposal/re-use of effluent through the Health Act 1911 (WA) and Health (Treatment of Sewage and Disposal of Effluent and Liquid Waste) Regulations 1974 (WA). All applicable approvals have been obtained for the operation of the BWWTP.

5.5 Stakeholder and Community Consultation Public comments were considered when preparing this licence application. Comments received during the Part IV assessment of the Gorgon Gas Development, and Chevron Australia’s response to the comments, are available from Chevron Australia’s website: https://www.chevronaustralia.com/our-businesses/gorgon/environmental-approvals

An extensive program of community consultation was undertaken with a broad range of stakeholders. This consultation began during preparation of the Environmental Impact Statement/Environmental Review and Management Programme (Ref. 13) and continues as part of the ongoing stakeholder engagement process. Stakeholders consulted included community groups, government departments, business representatives, Aboriginal groups, and individuals.

Consultation with DWER is ongoing, with meetings and other interactions regularly occurring between Chevron Australia personnel and the DWER Licensing Branch (located in Perth and in the Karratha Regional Office) to ensure that licensing requirements are known and met.

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6.0 Inputs, Outputs, Emissions and Discharges

6.1 Inputs to Gas Treatment Plant Inputs to the GTP predominantly comprise the Gorgon and Jansz feed gas streams delivered from the offshore gas fields via the Gorgon and Jansz feed gas pipelines. Gorgon and Jansz feed gas contains MEG, condensate and water. MEG is separated from the feed gas and re-used by pumping it back to the wells by a separate pipeline running parallel with the feed gas pipeline.

There are no other significant fuel inputs to support the GTP during routine operations. Diesel is used in relatively small quantities for the firewater pumps, essential diesel generators and for general fuel use. Diesel is expected to be stored at the General Utilities Area and licenced under Category 73.

Numerous process chemicals are used within the prescribed premises at various stages throughout the gas treatment process. Process chemicals are delivered to the GTP through permanent import lines located on the Materials Offloading Facility or via appropriate containers such as Intermediate Bulk Containers and ISOtainers which are shipped to the site.

6.2 Outputs from Gas Treatment Plant

6.2.1 Products The GTP has an anticipated average stream day design capacity of up to 45,800 tonnes of LNG production from the three LNG trains. This equates to a nominal annual average LNG production of 15.6 MTPA based on 340 stream days per year.

The GTP is expected to produce condensate at the nominal rate of approximately 3461 tonnes per day of condensate. This equates to an annual production of one million tonnes. Nominal DomGas production is 300 TJ per day exported to the mainland.

Operating performance of the GTP is improving. Recent annualised production of LNG in August 2017, from the three LNG Trains, exceeded the design capacity of 15.6 MTPA.

6.2.2 Liquid Wastes Various contaminated liquid wastes are generated from the operation of the GTP. These include, but are not limited to:

• produced water

• treated effluent

• contaminated stormwater

• process liquid wastes intermittently produced during maintenance, shutdown, and turnaround operations.

Uncontaminated stormwater is discharged to the environment.

6.2.3 Solid Wastes Solid wastes are generated throughout the operation of the GTP and can be broadly classified under the categories of general waste putrescible waste, recyclable waste, hazardous waste and quarantine-risk material.

Up to 240,000 tonnes of concrete waste generated from demolition of surplus construction facilities is stored pending reuse or final disposal.

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6.2.4 Atmospheric Emissions The primary sources of identified atmospheric pollutants and air toxics associated with the operation of GTP are identified in the AQMP (Ref. 10), as shown in Table 6-1.

Table 6-1: GTP Atmospheric Pollutants and Air Toxics Emissions and Sources

GTP Emission Sources Associated Atmospheric Pollutants and Air Toxics

Frame 9 GTGs NOx, PM10, SO2, NMVOCs1, CO, Hg4

Frame 7 LP MR and HP MR/PR GTs NOx, PM10, SO2, NMVOCs1, CO, Hg4

HMH A and B NOx, PM10, SO2, NMVOCs1, CO, Hg4

EDGs NOx, PM10, SO2, NMVOCs2, CO, Hg4

Wet and Dry Flares NOx, PM10, SO2, NMVOCs1, CO

BOG Flares A and B NOx, PM10, SO2, NMVOCs1, CO

AGRUs 1 to 3 Vents NMVOCs3, H2S, Hg4

Condensate Storage Tanks (fugitive emissions) NMVOCs, Hg4

Notes:

1. Non-methane volatile organic compounds (NMVOCs) associated with combustion of clean fuel gas in GTs, heaters (boilers), and flares mainly comprise the unburnt portion of the aliphatic hydrocarbons present in the fuel gas.

2. NMVOCs present in the exhaust gases from the EDGs also include minor (trace) quantities of polycyclic aromatic hydrocarbons and formaldehyde.

3. NMVOCs in the vented acid gas stream include up to 30% benzene, toluene, ethylbenzene, and xylene compounds (BTEX) (on a molar basis).

4. Although Hg is present in the emission stream, it is at very low levels. EVR: LNG Trains 1,2 and 3 and Associated Facilities (Ref. 13).

In addition to Table 6-1, note:

• EDGs are expected to be used infrequently and for short periods when the Frame 9 GTGs are unavailable, e.g. during shutdowns and maintenance; hence, they are not considered major emission sources due to both the limited frequency of use and limited overall volume of associated emissions.

• Fugitive emissions, which may occur from Condensate Storage Tanks, diesel storage tanks, and other equipment such as valves, flanges, connectors, pump seals and compressor seals in hydrocarbon service, flow lines, and connections, are considered minor.

• To prevent the formation of dry ice, which can cause blockages in the cryogenic processing trains to create LNG, CO2, which occurs naturally in the feed gas, is extracted in the AGRUs. The CO2 with other pollutants (H2S and BTEX) will be vented until the CO2 Injection system is commissioned and operational.

6.3 Proposed Monitoring Inputs Monitoring: Chevron Australia does not propose any monitoring of inputs into the GTP and prescribed premises.

Process Monitoring: Chevron Australia does not propose any process monitoring for the three LNG trains and associated facilities.

Outputs Monitoring: Chevron Australia proposes to monitor atmospheric emissions from the prescribed premises via stack emission and ambient air quality monitoring programs. Monitoring of the discharge of wastewater to land via discharge to the

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Class 3 drainage system or injection down well is to be consistent with the existing LNG Train 1 licence conditions.

6.3.1 Stack Emission Monitoring Program Table 6-2 sets out the monitoring of point source emissions to air and process monitoring as specified in Tables 3.2.1 and 3.4.1 of L8952 (Ref. 2) and expanded to include the additional facilities associated with GTGs 4 and 5, LNG Trains 2 and 3, and AGRUs 2 and 3.

Table 6-2: Stack Emission Monitoring Program during LNG Train 1, 2, and 3 Operations

Atmospheric Emission

Point Source Parameters Units Monitoring Method Averaging

Period

Frequency (if operational at the time of monitoring)

Frame 9 GTG 1 to 5

Exhaust flow rate

m3/s United States Environmental Protection Agency (USEPA) Method 2 (Ref. 14) or 2F (Ref. 15) or other suitable method.

N/A Proposed change from Quarterly to Annual1

NOx, SO2, CO, NMVOCs

mg/m3 NOx: USEPA Method 7D (Ref. 16) or 7E (Ref. 17) or other suitable method. SO2: USEPA Method 6C (Ref. 18), 8 (Ref. 19), or ISO11632:1998(E) (Ref. 20) or other suitable method. CO: USEPA Method 10 (Ref. 21) NMVOCs: USEPA Method 18 (Ref. 22) or other suitable method.

As required by testing technology

Proposed change from Quarterly to Annual1

Fuel Consumption

m3/month Process monitoring N/A Continuous

Frame 7 LP MR Compressor GT Driver Trains 1 to 3 Frame 7 HP MR/PR Compressor GT Driver Trains 1 to 3

Exhaust flow rate

m3/s USEPA) Method 2 (Ref. 14) or 2F (Ref. 15) or other suitable method

N/A Proposed change from Quarterly to Annual1

NOx, SO2, CO, NMVOCs

mg/m3 NOx: USEPA Method 7D (Ref. 16) or 7E (Ref. 17) or other suitable method. SO2: USEPA Method 6C (Ref. 18), 8 (Ref. 19), or ISO11632:1998(E) (Ref. 20)1, or other suitable method. CO: USEPA Method 10 (Ref. 21) or other suitable method.

As required by testing technology

Proposed change from Quarterly to Annual1

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Atmospheric Emission

Point Source Parameters Units Monitoring Method Averaging

Period

Frequency (if operational at the time of monitoring)

NMVOCs: USEPA Method 18 (Ref. 22), or other suitable method.

Fuel Consumption

m3/month Process monitoring N/A Continuous

Wet and Dry Ground Flares

Volume of process hydrocarbon gas burnt

m3/month Flare flow meter Monthly Continuous

BOG Flare (two in total – A and B)

Volume of burn-off gas burnt

m3/month Flare flow meter Monthly Continuous

Amine Regenerator reflux drum Vent 1 in each AGRU (AGRU Trains 1 to 3)

Volume of acid gas vented

m3/month Vent flow meter Monthly During each venting event

Note 1. Stack testing has been carried out on a quarterly basis on the GTGs and GTs in operation since early 2016. Recent stack test results in the EVR (Ref.12) carried out have demonstrated that when the DLN Burners are operating effectively that the stack test emissions are below the emission targets. Chevron therefore proposes (from the grant of the licence) to reduce the frequency of the stack testing from quarterly to annual.

Part 6.1 of the Application Form requires that for electromagnetic radiation, copies/details of other relevant approvals (such as from DMIRS or the Radiological Council) must be provided where applicable. Relevant details are included in Sections 5.2 and 5.3.

6.3.2 Ambient Air Quality Monitoring As indicated in Appendix 2 of the AQMP (Ref. 10), ambient air quality monitoring is to be undertaken and reported during the operation phase according to the program and methodology outlined in Table 9-1 in the AQMP approved under Part IV of the EP Act.

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7.0 Other Relevant Information

Table 7-1 below provides a summary of the Part IV and Part V commitments in relation to this licence application.

Table 7-1Environmental Commitments

Section Action

Part IV BPPCDR BPPCDR equipment installed and operated to control the major emission sources of atmospheric emissions at the GTP to As Low As

Reasonably Practicable.

Part IV LTMTMP Lighting on the GTP to be managed in accordance

with the LTMTMP.

Light monitoring programs implemented including monitoring of ambient night-time light emissions

Part IV Solid and Liquid Waste Management Plan

Solid and liquid waste managed by applying waste management hierarchy

Spill response procedures and equipment in place for hazardous liquid waste storage

Hazardous wastes to be stored and handled as per the respective MSDS

Part IV Air Quality Management Plan Ambient Air Quality Monitoring program as outlined in Table 9-1 of the AQMP will continue

through the commissioning, start-up and operation phrases of the GTP

Management measures can include:

• Dry Low NOx burners in the GTs and GTGs

• Low NOx burners in HMHs

• MRUs

• Flare pilot and purge gas only during routine

operations

• WHRUs on GTs exhaust stacks

• Using BOG Flares and BOG Recycle

Compressors

• Internal floating roof on Condensate Tanks

• Implementing preventive maintenance

programs where appropriate

• Using ultra-low sulfur content diesel

• Using area gas leak detection whereappropriate.

Part IV Terrestrial and Subterranean

Environment Monitoring Program

Groundwater Monitoring

Environmental noise monitoring carried out in relation to terrestrial receptors

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Part V The Air Quality Management Plan will continue to

be implemented under Part V of the EP Act during the operation of the GTP.

Part V Pollution control equipment maintained.

Part V Flow Meters at, but not limited to, Wet and Dry ground flares, BOG Flares, TWIP, PWDs will be

maintained.

Part V Water and Stormwater

Management

The water quality is assessed and then disposed

of via the appropriate system.

Contaminated and uncontaminated water is kept separate.

Uncontaminated water is discharged into Class 3 drainage system as appropriate to mitigate soil erosion

Contaminated water is disposed of by deepwell

injection

Part V Deepwell Injection During normal operations, wastewater is

commingled with other liquid wastes received by the LWF and discharged via deep well injection. Deep-well injection is either through the PWD

wells or the TWIP.

Monthly monitoring for TSS, TPH and pH for

operational purposes

Operational monitoring instruments and programs

are in place to include but are not limited to:

• Individual well gauges and meters(each well) to monitor:

• Wellhead pressure

• Downstream choke pressure andtemperature

• A and B annulus pressure

• Liquid flow rate.

Part V Air Emissions LNG Train 1 licence L8952/2016/1 requires stack

testing for the (operating) GTGs and GT7s to be carried out in each calendar quarter. It is proposed to reduce the frequency to annual (refer to Table 6-2)

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8.0 Licence Application Fee Calculation The fee calculation for this licence application was calculated using DER’s online Industry Licencing System.

Table 8-1: Licence Fee Calculation

Fee Component Parameters Fee ($)

Premises Component Category 10 for more than 2,000,000 tonnes per year

Category 34 for more than 2,000,000 tonnes per year

Category 52 for more than 200 MW per year

Category 54 for more than 200 m3/day but not more than 2,000 m3/day per year

Category 62 for more than 5,000 tonnes per year

Category 73 for more than 1,000 m3 per year

Discharge to Air Carbon Dioxide

Benzene

Particulates

Hydrogen Sulphide 0

Oxides of Nitrogen

Volatile Organic Compounds

Sulphur Oxide

Other Wastes

Discharge to Land Total Suspended Solids

Total Nitrogen

Phosphorus

Total Residual Chlorine

TOTAL LICENCE FEE

1 The proponent only pays the premises component that is the most expensive, not the sum of all components; therefore, the premises component is $21,360.

Appendix G provides more detailed information and data for the fee calculation as required by Part 9.8 of the Application Form.

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9.0 Acronyms and Abbreviations Table 9-1 defines the acronyms and abbreviations used in this document.

Table 9-1: Acronyms and Abbreviations

Acronym/Abbreviation Definition

AGRU Acid Gas Removal Unit

Ambient Air As described in the National Environment Protection (Ambient Air Quality) Measure (Ref. 23) is considered the external air environment, and does not include the air environment inside buildings or structures.

a-MDEA Activated Methyldiethanolamine

AQMP Air Quality Management Plan

Atmospheric Emissions Any emission to air, for any period of time, of solid, liquid, or gaseous matter. Examples include, but are not limited to, dust and greenhouse gases.

Atmospheric Pollutants As described in the National Environment Protection (Ambient Air Quality) Measure (Ref. 23) includes carbon monoxide (CO), nitrogen dioxide (NO2), photochemical oxidants (such as ozone [O3]), sulfur dioxide (SO2), lead, and particles (such as PM10). In principle, this includes gaseous, aerosol, or particulate pollutants that are present in the air in low concentrations with characteristics such as toxicity or persistence so as to be a hazard to human, plant, or animal life.

Base Emission Rate The rate at which atmospheric pollutants are emitted from a source with pollution control in place.

BOG Boil-off gas

BPPCDR Best Practice Pollution Control Design Report

BTEX Benzene, toluene, ethylbenzene, and xylene compounds

BWWTP Bridging Wastewater Treatment Plant

CH4 Methane

Chevron Australia Chevron Australia Pty Ltd

Class 1 Class 1 Stormwater Drainage – Contaminated Run-off

Class 2 Class 2 Stormwater Drainage – Potentially Contaminated Run-off

Class 3 Class 3 Stormwater Drainage – On-site Uncontaminated Run-off

Class 4 Class 4 Stormwater Drainage – Intercepted Off-site Uncontaminated Run-off

CO Carbon monoxide

CO2 Carbon dioxide

DMIRS Western Australian Department of Mines, Industry Regulation, and Safety (from 1 July 2017; formerly Department of Mines and Petroleum and Department of Commerce)

DomGas Domestic Gas Plant

DWER Western Australian Department of Water and Environmental Regulation (from 1 July 2017; formerly Department of Environment Regulation)

EDG Essential Diesel Generator

EP Act Western Australian Environmental Protection Act 1986

EPBC 2003/1294 Commonwealth Ministerial Approval (for the Gorgon Gas Development) as amended or replaced from time to time.

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Acronym/Abbreviation Definition

EPBC 2008/4178 Commonwealth Ministerial Approval (for the Revised Gorgon Gas Development) as amended or replaced from time to time.

EPBC Act Commonwealth Environment Protection and Biodiversity Conservation Act 1999

Gorgon Gas Development The Gorgon Gas Development as approved under MS 800 and 965, and EPBC 2003/1294 and 2008/4178 (as varied by the Commonwealth Environment Minister), as amended or replaced from time to time.

GPS Global Positioning System

Greenhouse Gases Components of the atmosphere that contribute to the greenhouse effect. These include carbon dioxide (CO2), methane (CH4), sulfur hexafluoride, and nitrous oxide (NO).

GT Gas Turbine

GTG Gas Turbine Generator

GTP Gas Treatment Plant

H2S Hydrogen sulphide

Hg Mercury

HMH Heating Medium Heater

HP High Pressure

ISO International Organization for Standardization

Kl Kilolitre

LNG Liquefied Natural Gas

LP Low Pressure

LTMTMP Long-term Marine Turtle Management Plan

Luminaire A complete lighting unit that produces and distributes light, including the fixture, ballast, mounting, and lamps

LWF Liquid Waste Facility

m3 Cubic metre

MEG Monoethylene glycol

Mg Milligram

MHF Major Hazard Facility

MR Mixed Refrigerant

MRU Mercury Removal Unit

MS Western Australian Ministerial Statement

MS 800 Western Australian Ministerial Statement 800 (for the Gorgon Gas Development) as amended from time to time.

MTPA Million tonnes per annum

MW Megawatt

N/A Not Applicable

Name Plate Design Capacity The intended full-load sustained output of a facility

NEPM National Environment Protection Measure for Ambient Air Quality

NMVOC Non-Methane Volatile Organic Compound

NO Nitric oxide

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page 31 Information Sensitivity: Company Confidential Uncontrolled when Printed

Acronym/Abbreviation Definition

NO2 Nitrogen dioxide

NOx Nitrogen oxides (NO and NO2)

O3 Ozone

Ph Measure of acidity or basicity of a solution

PM Particulate Matter

PM10 Suspended particulate matter comprising particles having an equivalent aerodynamic diameter of less than 10 μm, as defined in Australian Standard 3580.9.8 (Standards Australia 2008)

PR Propane Refrigerant

Practicable Defined in section 3 of the EP Act as ‘means reasonably practicable having regard to, amongst other things, local conditions and circumstances (including cost) and to the current state of technical knowledge’

PWD Permanent Wastewater Disposal (wells)

SLWMP Solid and Liquid Waste Management Plan

SO2 Sulphur dioxide

TAPL Texaco Australia Pty Ltd

TJ/d Terajoules per day

TPS Temporary Power Station

TSEMP Terrestrial and Subterranean Environment Monitoring Program

TWIP Temporary Wastewater Injection Plant

USEPA United Stated Environmental Protection Agency

VOC Volatile Organic Compound

WA Western Australia

WHRU Waste Heat Recovery Unit

WTS Waste Transfer Station

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page 32 Information Sensitivity: Company Confidential Uncontrolled when Printed

10.0 References The following documentation is either directly referenced in this document or is a recommended source of background information.

Table 10-1: References

Ref. No. Description Document ID

Department of Water and Environmental Regulation 2017. Application Form: Works approval/licence. (Revision 7, July 2017) Perth, Western Australia.

-

Department of Environment Regulation. 2016. Western Australian Environmental Protection Act 1986 Part V Licence to operate for LNG Train 1 L8952/2016/1. Department of Environment Regulation, Perth, Western Australia.

L8952/2016/1

Department of Environment Regulation. 2015. Western Australian Environmental Protection Act 1986 Part V Licence to operate for Liquid Waste Facility L8894/2015/1. Department of Environment Regulation, Perth, Western Australia.

L8894/2015/1

Department of Environment Regulation. 2010. Western Australian Environmental Protection Act 1986 Part V Licence to operate for the Bridging Wastewater Treatment Plant L8479/2010/2. Department of Environment Regulation, Perth, Western Australia.

L8479/2010/2

Department of Environment Regulation. 2013. Western Australian Environmental Protection Act 1986 Part V Licence to operate for the Waste Transfer Station L8751/2013/1 Department of Environment Regulation, Perth, Western Australia.

L8751/2013/1

Chevron Australia. 2014. Gorgon Gas Development and Jansz Feed Gas Pipeline: Long-Term Marine Turtle Management Plant. Chevron Australia, Perth, Western Australia.

G1-NT-PLNX0000296

Chevron Australia. 2016. Gorgon Gas Development and Jansz Feed Gas Pipeline: Solid and Liquid Waste Management Plan. Chevron Australia, Perth, Western Australia.

G1-NT-PLNX0000302

Chevron Australia. 2016. Gorgon Gas Development and Jansz Feed Gas Pipeline: Terrestrial and Subterranean Environment Monitoring Program. Chevron Australia, Perth, Western Australia.

G1-NT-PLNX0000309

Chevron Australia. 2015. Gorgon Gas Development: Best Practice Pollution Control Design Report. Chevron Australia, Perth, Western Australia.

G1-NT-REPX0001730

Chevron Australia. 2015. Gorgon Gas Development and Jansz Feed Gas Pipeline: Air Quality Management Plan. Chevron Australia, Perth, Western Australia.

G1-NT-PLNX0000301

Chevron Australia. 2014. Gorgon: Major Hazard Facility Safety Report, Chevron Australia, Perth, Western Australia.

G1-NT-REPX0004799

Chevron Australia. 2017. Gorgon Project, Emissions Verification Report: LNG Trains 1,2 and 3 and Associated facilities (W5178/2012/1. Chevron Australia, Perth, Western Australia.

ABU170800448

Environmental Impact Statement/Environmental Review and Management Programme for the Proposed Gorgon Gas Development. Chevron Australia, Perth, Western Australia.

-

United States Environmental Protection Agency. 2011. Method 2 – Determination of Stack Gas Velocity and Volumetric Flow Rate (Type S Pitot Tube). Technology Transfer Network, Emission Measurement Center, Washington DC, USA.

Method 2

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page 33 Information Sensitivity: Company Confidential Uncontrolled when Printed

Ref. No. Description Document ID

United States Environmental Protection Agency. 2011. Method 2F – Determination of Stack Gas Velocity And Volumetric Flow Rate With Three-Dimensional Probes. Technology Transfer Network, Emission Measurement Center, Washington DC, USA.

Method 2F

United States Environmental Protection Agency. 2000. Method 7D – Determination of Nitrogen Oxide Emissions from Stationary Sources (Alkaline-Permanganate/Ion Chromatographic Method). Technology Transfer Network, Emission Measurement Center, Washington DC, USA.

Method 7D

United States Environmental Protection Agency. 2009. Method 7E – Determination of Nitrogen Oxides Emissions from Stationary Sources (Instrumental Analyser Procedure). Technology Transfer Network, Emission Measurement Center, Washington DC, USA.

Method 7E

United States Environmental Protection Agency. 2006. Method 6C – Determination of Sulfur Dioxide Emissions from Stationary Sources (Instrumental Analyzer Procedure). Technology Transfer Network, Emission Measurement Center, Washington DC, USA.

Method 6C

United States Environmental Protection Agency. 2000. Method 8 – Determination of Sulfuric Acid and Sulfur Dioxide Emissions from Stationary Sources. Technology Transfer Network, Emission Measurement Center, Washington DC, USA.

Method 8

International Organization for Standardization. 1998. ISO11632:1998(E) – Stationary source emissions – Determination of mass concentration of sulfur dioxide – Ion chromatography method. International Organization for Standardization, Geneva, Switzerland.

ISO11632:1998(E)

United States Environmental Protection Agency. 2006. Method 10 – Determination of Carbon Monoxide Emissions from Stationary Sources (Instrumental Analyzer Procedure). Technology Transfer Network, Emission Measurement Center, Washington DC, USA.

Method 10

United States Environmental Protection Agency. 2000. Method 18 – Measurement of Gaseous Organic Compound Emissions by Gas Chromatography. Technology Transfer Network, Emission Measurement Center, Washington DC, USA.

Method 18

National Environment Protection Council. 2015. Variation to the National Environment Protection (Ambient Air Quality) Measure. National Environment Protection Council, Canberra, ACT.

-

Standards Australia. 2008. AS 3580.9.8. Methods for sampling and analysis of ambient air – Determination of suspended particulate matter – PM10 continuous direct mass method using a tapered element oscillating microbalance analyser, AS3580.9.87-2008, Standards Australia, Sydney

AS 3580.9.8

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page 34 Information Sensitivity: Company Confidential Uncontrolled when Printed

Appendix A Proof of Occupier Status

Area Relevant Tenure Title Title Number Expiry date

GTP; BWWTP Gas Treatment Plant Lease

L077431

Volume 3158; Folio 477

14 Sept 2069

WTS Support Infrastructure Licence (Old Airport East) Licence

00333-2016_A6042022 1 Nov 2021

PWD Permanent Water Disposal Wells Licence

L00016_2012/1_A1991085 14 Sept 2069

TWIP Temporary Wastewater Injection Facilities Licence

LIC 00554/2009_1_43 12 Nov 2020

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page 35 Information Sensitivity: Company Confidential Uncontrolled when Printed

Appendix B Prescribed Premises Boundary

2

7 8 9 1011 12 13 14

15 16

1819202324

28

29303132

3839

4041

51

5556

57

5859

6061

626364656676

808486

8890

92

94

9597

99 100 101 102

104105

109110

117

120

124

125

128

129131

146147

148

140141

142

143144

145

2122

2526

153

154

139

138 137115°27'30"E

115°27'30"E

115°27'0"E

115°27'0"E

115°26'30"E

115°26'30"E

115°26'0"E

115°26'0"E

20°4

7'0"S

20°4

7'0"S

20°4

7'30"S

20°4

7'30"S

20°4

8'0"S

20°4

8'0"S

336500

336500

337000

337000

337500

337500

338000

338000

338500

338500

339000

339000

339500

339500

340000

340000

7699

500

7699

500

7700

000

7700

000

7700

500

7700

500

7701

000

7701

000

7701

500

7701

500

PROPOSED PRESCRIBED PREMISES BOUNDARY

LEGENDProposed Prescribed Premises Boundary

Barrow Is

Date: 19 Sep 2017 CAI: DSZC

±0 100 200 300 400

MetresCoordinate System: GDA 1994 MGA Zone 50

COMPANY CONFIDENTIAL

DISCLAIMERAll information within this map is current as of 19/09/2017. Beforerelying on this information users should obtain appropriate advice andevaluate the metadata to determine data accuracy, currency,completeness and relevance for the intended purpose.For the production of detailed maps, transfer and conversion of data,review of detailed metadata and other queries relating to this mapplease contact the Australasian Business Unit GIS team at [email protected]

Ref: GOR_062A_Rev10

171

168

161162

163

164165166

167169

170

Temporary Waste Injection Plant (TWIP)

TWIPInset

GTP

Gorgon ProjectBridging WastewaterTreatment Plant

Gorgon GasTemporary Power Station

Gas Treatment Plant & Associated Infrastructure

Construction Village(Bultler Park)

Waste TransferStation

115°30'0"E

115°25'0"E

115°25'0"E

20°4

5'0"S

20°4

5'0"S

20°5

0'0"S

20°5

0'0"S

332000

332000

334000

334000

336000

336000

338000

338000

340000

340000

342000

342000

7692

000

7692

000

7694

000

7694

000

7696

000

7696

000

7698

000

7698

000

7700

000

7700

000

7702

000

7702

000

7704

000

7704

000

7706

000

7706

000

7708

000

7708

000

PROPOSED PRESCRIBED PREMISE BOUNDARY LOCATION MAP

LEGENDProposed Prescribed Premises Boundary

!(

!(

!(

Onslow

Dampier

Exmouth

DISCLAIMERAll information within this map is current as of 19/09/2017. Beforerelying on this information users should obtain appropriate advice andevaluate the metadata to determine data accuracy, currency,completeness and relevance for the intended purpose.For the production of detailed maps, transfer and conversion of data,review of detailed metadata and other queries relating to this mapplease contact the Australian Business Unit GIS team [email protected].

0 625 1,250 1,875 2,500

Meters

COMPANY CONFIDENTIAL

File Ref: GOR_061A_Rev6

±Coordinate System: GDA 1994 MGA Zone 50

Date: 19 Sep 2017 CAI: DSZC

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page 36 Information Sensitivity: Company Confidential Uncontrolled when Printed

Appendix C GPS Coordinates of Prescribed Premises Boundary

Description MGA50_X MGA50_Y

Waste Transfer Station 337050.85 7699480.48

Waste Transfer Station 337062.00 7699472.00

Waste Transfer Station 337081.94 7699454.93

Waste Transfer Station 337088.66 7699448.42

Waste Transfer Station 337099.57 7699437.35

Waste Transfer Station 337108.68 7699422.59

Waste Transfer Station 337126.78 7699398.28

Waste Transfer Station 337127.00 7699398.00

Waste Transfer Station 337126.99 7699397.99

Waste Transfer Station 337127.05 7699397.91

Waste Transfer Station 337123.11 7699392.16

Waste Transfer Station 337123.00 7699392.00

Waste Transfer Station 337123.00 7699392.00

Waste Transfer Station 337122.55 7699391.35

Waste Transfer Station 337107.27 7699395.57

Waste Transfer Station 337101.00 7699394.00

Waste Transfer Station 337097.00 7699395.00

Waste Transfer Station 337072.00 7699411.00

Waste Transfer Station 337028.10 7699439.93

Waste Transfer Station 336979.31 7699388.86

Waste Transfer Station 336958.24 7699397.47

Waste Transfer Station 336939.87 7699409.28

Waste Transfer Station 336930.31 7699414.10

Waste Transfer Station 336977.69 7699486.26

Waste Transfer Station 336988.07 7699477.11

Waste Transfer Station 337011.00 7699511.00

Waste Transfer Station 337016.28 7699506.80

Waste Transfer Station 337050.85 7699480.48

Plant Site 339322.26 7700255.11

Plant Site 339322.26 7700241.70

Plant Site 339292.04 7700241.70

Plant Site 339292.04 7700285.52

Plant Site 339251.68 7700285.52

Plant Site 339251.68 7700225.40

Plant Site 339251.68 7700136.53

Plant Site 339229.51 7700114.65

Plant Site 339210.62 7700114.65

Plant Site 339295.34 7700005.06

Plant Site 339268.27 7699986.93

Plant Site 339190.35 7700087.74

Plant Site 339117.13 7700036.74

Plant Site 339145.13 7699996.56

Plant Site 339141.97 7699989.28

Plant Site 339136.38 7699976.41

Plant Site 339009.97 7699644.19

Plant Site 339006.03 7699633.58

Plant Site 338869.79 7699276.98

3 -Train Licence Boundary Coordinates

1

Description MGA50_X MGA50_Y

3 -Train Licence Boundary Coordinates

Plant Site 338867.69 7699277.70

Plant Site 338836.50 7699195.96

Plant Site 338728.13 7699235.89

Plant Site 338762.01 7699322.70

Plant Site 338869.56 7699282.60

Plant Site 338868.05 7699278.64

Plant Site 338869.20 7699278.24

Plant Site 339004.97 7699633.62

Plant Site 339004.67 7699634.61

Plant Site 339008.46 7699644.51

Plant Site 339009.17 7699644.89

Plant Site 339134.82 7699975.13

Plant Site 339140.72 7699991.06

Plant Site 339108.43 7700037.41

Plant Site 339197.17 7700099.64

Plant Site 339197.17 7700121.38

Plant Site 339226.72 7700121.38

Plant Site 339245.30 7700139.61

Plant Site 339245.30 7700225.40

Plant Site 339216.45 7700225.40

Plant Site 339216.47 7700237.22

Plant Site 339135.36 7700237.55

Plant Site 339134.71 7700348.19

Plant Site 338975.78 7700346.34

Plant Site 338975.78 7700245.80

Plant Site 338420.15 7700245.80

Plant Site 338421.54 7699779.25

Plant Site 338342.79 7699779.35

Plant Site 338264.72 7699779.44

Plant Site 338202.26 7699779.51

Plant Site 337769.18 7699779.51

Plant Site 337764.60 7699782.12

Plant Site 337760.62 7699785.82

Plant Site 337760.07 7699786.33

Plant Site 337756.61 7699790.92

Plant Site 337754.84 7699796.18

Plant Site 337755.15 7699820.89

Plant Site 337755.37 7699838.95

Plant Site 337753.77 7699843.62

Plant Site 337751.87 7699849.17

Plant Site 337741.32 7699860.54

Plant Site 337740.25 7699861.70

Plant Site 337737.93 7699863.00

Plant Site 337714.69 7699875.97

Plant Site 337710.45 7699878.34

Plant Site 337706.05 7699880.79

Plant Site 337702.72 7699882.75

2

Description MGA50_X MGA50_Y

3 -Train Licence Boundary Coordinates

Plant Site 337700.18 7699884.25

Plant Site 337694.30 7699887.71

Plant Site 337687.43 7699899.14

Plant Site 337684.72 7699936.68

Plant Site 337685.34 7700017.49

Plant Site 337685.35 7700018.99

Plant Site 337685.54 7700042.59

Plant Site 337685.72 7700066.92

Plant Site 337676.95 7700171.43

Plant Site 337676.82 7700171.80

Plant Site 337676.18 7700180.58

Plant Site 337672.43 7700453.52

Plant Site 337680.05 7700540.61

Plant Site 337680.85 7700589.10

Plant Site 337682.02 7700604.59

Plant Site 337687.92 7700608.87

Plant Site 337740.26 7700614.13

Plant Site 337788.49 7700610.08

Plant Site 337886.11 7700591.22

Plant Site 338084.49 7700591.22

Plant Site 338084.49 7700756.29

Plant Site 338075.83 7700756.42

Plant Site 338076.68 7700794.87

Plant Site 338086.17 7700794.86

Plant Site 338085.81 7700848.30

Plant Site 338089.50 7700887.81

Plant Site 338080.66 7700887.83

Plant Site 338082.99 7700916.29

Plant Site 338091.33 7700916.28

Plant Site 338094.51 7700954.37

Plant Site 338093.95 7700954.37

Plant Site 338089.19 7700954.37

Plant Site 338088.49 7700966.96

Plant Site 338088.25 7700971.17

Plant Site 338064.82 7700990.64

Plant Site 338060.55 7700985.61

Plant Site 338033.86 7701011.38

Plant Site 338039.03 7701017.47

Plant Site 337880.50 7701179.30

Plant Site 337751.12 7701294.10

Plant Site 337721.24 7701326.62

Plant Site 337637.63 7701423.87

Plant Site 337561.42 7701493.78

Plant Site 337465.91 7701593.04

Plant Site 337560.10 7701691.61

Plant Site 337641.97 7701606.77

Plant Site 337707.03 7701547.30

3

Description MGA50_X MGA50_Y

3 -Train Licence Boundary Coordinates

Plant Site 337870.49 7701378.64

Plant Site 338147.06 7701105.49

Plant Site 338105.20 7701065.74

Plant Site 338121.31 7701049.75

Plant Site 338104.25 7701033.47

Plant Site 338087.97 7701017.94

Plant Site 338103.51 7701001.79

Plant Site 338111.03 7700993.98

Plant Site 338119.83 7700984.84

Plant Site 338118.82 7700954.37

Plant Site 338118.88 7700952.55

Plant Site 338122.27 7700859.37

Plant Site 338123.81 7700799.37

Plant Site 338123.81 7700699.75

Plant Site 338177.47 7700699.75

Plant Site 338200.29 7700722.56

Plant Site 338237.47 7700722.56

Plant Site 338237.47 7700678.40

Plant Site 338973.52 7700678.40

Plant Site 338973.52 7700669.41

Plant Site 339237.72 7700669.41

Plant Site 339237.72 7700528.90

Plant Site 339489.07 7700531.52

Plant Site 339489.07 7700458.34

Plant Site 339489.07 7700301.95

Plant Site 339437.73 7700273.24

Plant Site 339349.03 7700273.24

Plant Site 339349.03 7700255.11

Plant Site 339322.26 7700255.11

4

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page 37 Information Sensitivity: Company Confidential Uncontrolled when Printed

Appendix D Emission and Discharge Points

Ground Flaremonitoring point

BOG Flare monitoring point

A1

A2

A3

A4

A5

A6

A7

A8

A9

A10

A11

A14

A15

A16 A17 A18

A19

A12A13

337500

337500

338000

338000

338500

338500

339000

339000

339500

339500

340000

340000

770

00

00

770

00

00

770

05

00

770

05

00

770

100

0

770

100

0

770

150

0

770

150

0

EMISSION POINTS TO AIR

Barrow Is

Date: 19 Sep 2017 CAI: DSZC

±0 100 200 300 400

Metres

Coordinate System: GDA 1994 MGA Zone 50

COMPANY CONFIDENTIAL

Ref: GORG_137A_Rev3

Stormwater Holding Pond (SHP)(339182mE, 7700428mN)

Bridging WWTP - Flowmetermonitoring point(339279mE, 7699996mN)

Z-WI2 Discharge Point338801.4mE, 7699263.3mN

Z-WI1 Discharge Point338782.3mE, 7699270.6mN

Discharge Point(339753mE, 7700645mN)

ZWI2 Flow Meter and Sampling Points338810mE, 7699290mN

ZWI1 Flow Meter and Sampling Points338790mE, 7699293mN

!(M1

!(L1

338000

338000

338500

338500

339000

339000

339500

339500

340000

340000

340500

340500

769

95

00

769

95

00

770

00

00

770

00

00

770

05

00

770

05

00

EMISSION POINTS TO LAND

Barrow Is

Date: 12 Sep 2017 CAI: DSZC

±0 75 150 225 300

Metres

Coordinate System: GDA 1994 MGA Zone 50

COMPANY CONFIDENTIAL

Ref: GORG_137B_Rev2

WDW1332731.2 mE,

7700842.5 mN

WDW2332824.0 mE

7700644.7 mN

TWIP Inset

TWIP Main Map

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page 38 Information Sensitivity: Company Confidential Uncontrolled when Printed

Appendix E Pollution Control Equipment

The primary function of pollution control equipment is to eliminate or mitigate the discharge of environmentally hazardous material into the environment. The main pollution control equipment relating to this licence application comprises

Pollution Control Equipment

Bunding around environmentally hazardous liquid inventories namely Condensate Tanks, MEG Tanks, Diesel Tanks, HCL etc

Automatic shut-down devices (where the automatic shut-down device’s prime function is to prevent pollution)

Dry Low NOx burners – GTs and GTGs operating once sufficient electrical load is available

Low NOx burners (Heating Medium Heaters)

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page 39 Information Sensitivity: Company Confidential Uncontrolled when Printed

Appendix F Monitoring Equipment

Monitoring

Air Quality Monitoring Stations

Portable field equipment required for air quality monitoring

Flow Meters at Wet and Dry ground flares, BOG Flares, PWDs.

Flow meters above to be maintained and calibrated for the duration of the Gorgon Gas Development

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page 40 Information Sensitivity: Company Confidential Uncontrolled when Printed

Appendix G 3-Train Licence Fee Data

Gorgon Project Application for a Licence to Operate LNG Trains 1 to 3 and their Associated Facilities

Document ID: ABU170900173 Revision ID: 0 Revision Date: 20 October 2017 Page 41 Information Sensitivity: Company Confidential Uncontrolled when Printed

Data for Three Train Licence Fee Calculation

Table 1: GTGs

Pollutant E-Suite Pollutant Name3GTG E-Suite Emission

Rates [kg/hr]

3GTG E-Suite Emission

Rates [g/m]TOTALS g/m

NOx Nitrogen Oxides (NOX) 377.507 6291.782 NOx 16483.018

CO Carbon Monoxide 96.593 1609.887 CO 25681.591

NMVOC Volatile Organic Compound (VOC) 2.478 41.297 VOCs (total) 39333.671

NMVOC (minus benzene) 2.464 41.061 VOCs (no benzene) 39174.348

Benzene Benzene 0.014 0.236 Benzene 159.323SOx Sulfur Dioxide 3.24

# 54.000 Toluene 1.198

PM10 PM10 2.240 37.331 Ethylbenzene 0.095

#Data based on stack sampling conducted in Feb 2017 Xylene 0.284SOx 115.652

H2s 0.0006

Table 2: Frame 7 GTs (Train 1) PM10 74.967

Pollutant E-Suite Pollutant Name

1 Train GTs E-Suite

Average Emission Rates

[kg/hr]

1 Train GTs E-Suite

Average Emission Rates

[g/m]NOx Nitrogen Oxides (NOX) 379.1845791 6319.742985

CO Carbon Monoxide 97.02250664 1617.041777

NMVOC Volatile Organic Compound (VOC) 2.488838214 41.4806369

NMVOC (minus benzene) 2.474636369 41.244

Benzene Benzene 0.014201845 0.236697421

SOx Sulfur Dioxide 3.6# 60

PM10 PM10 2.249797255 37.49662092

#Data based on stack sampling conducted in Feb 2017

Table 3: EDGs

Pollutant E-Suite Pollutant Name3EDG E-Suite Emission

Rates [kg/hr]

3EDG E-Suite Emission

Rates [g/m]NOx Nitrogen Oxides (NOX) 0.159 2.656

CO Carbon Monoxide 0.072 1.192

NMVOC Volatile Organic Compound (VOC) 0.007 0.112

NMVOC (minus benzene) 0.007 0.111

Benzene Benzene 0.000 0.001

SOx Sulfur Dioxide 0.000 0.001

PM10 PM10 0.008 0.140

Table 4: Flaring

Pollutant E-Suite Pollutant NameFlares E-Suite Emission

Rates [kg/hr]

Flares E-Suite Emission

Rates [g/m]

NOx Nitrogen Oxides (NOX) 232.290 3871.493

CO Carbon Monoxide 1347.280 22454.662

NMVOC Volatile Organic Compound (VOC) 2322.896 38714.934

NMVOC (minus benzene) 2313.496 38558.260

Benzene Benzene 9.400 156.674

SOx Sulfur Dioxide 0.099 1.650

PM10 PM10 0.000 0.000

Table 5: Venting

Pollutant E-Suite Pollutant NameVent Emission Rates

[kg/hr]

Vent Emission Rates

[g/m]

H2S Hydrogen Sulfide 0.0000 0.0006

Benzene Benzene 0.1305 2.175

Toluene Toluene 0.0719 1.198

Ethylbenzene Ethylbenzene 0.0057 0.095

Xylene Xylene (mixed isomers) 0.0170 0.284

- Volatile Organic Compound (VOC) 32.1508 535.846Total VOC (minus benzene) - 32.0203 533.671

Table 4a: BOG Flaring For Application Table 6.1

Pollutant E-Suite Pollutant NameBOG Flares E-Suite

Emission Rates [kg/hr]

BOG Flares E-Suite

Emission Rates [g/m]

BOG Flares

E-Suite

Emission

Rates [g/s]

NOx Nitrogen Oxides (NOX) 40.478 674.631 11CO Carbon Monoxide 234.772 3912.859 65NMVOC Volatile Organic Compound (VOC) 404.779 6746.309 112NMVOC (minus benzene) 403.140 6719.008 112Benzene Benzene 1.638 27.301 0SOx Sulfur Dioxide 0.017 0.288 0PM10 PM10 0.000 0.000 0

Table 4b: Wet & Dry Flaring For Application Table 6.1

Pollutant E-Suite Pollutant NameWet & Dry Flares E-Suite

Emission Rates [kg/hr]

Wet & Dry Flares E-Suite

Emission Rates [g/m]

BOG Flares

E-Suite

Emission

NOx Nitrogen Oxides (NOX) 191.812 3196.863 53

CO Carbon Monoxide 1112.508 18541.803 309

NMVOC Volatile Organic Compound (VOC) 1918.118 31968.625 533

NMVOC (minus benzene) 1910.355 31839.252 531

Benzene Benzene 7.762 129.373 2

SOx Sulfur Dioxide 0.082 1.363 0

PM10 PM10 0.000 0.000 0

2016/2017

2016/2017

2016/2017

2016/20172016/2017

2016/2017

2016/2017

2016/2017


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