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OCT/NOV 2021 Woodside fires ahead Scarborough final investment decision locked in LEIGH CREEK ENERGY PROJECT DORADO PROJECT BAROSSA OFFSHORE PROJECT
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Mega-deals on the cards
create new avenues
With the announcement of four major players in the sector
combining to become two entities, the face of Australia’s oil
MOLLY HANCOCK and gas industry is set to be changed.
T
he motto within Australia’s oil and September, confirming they had entered diversified natural resources company
gas industry at present appears into a merger implementation deed, by market capitalisation with over 80,000
to be go big or go home. combining Santos’ carbon capture storage employees and contractors. With the
The sector first saw the capability with Oil Search’s ESG programs proposed mergers creating an opportunity
power-move from Woodside and BHP in Papua New Guinea (PNG) and Alaska. for long-life conventional portfolios of scale
when they announced in August that they Santos MD and CEO Kevin Gallagher said and diversity of geography, product and
had entered into a merger commitment the two companies would be stronger end markets, Woodside, BHP, Santos and
deed to combine their respective oil together and will have increased scale and Oil Search have opened up a new avenue
and gas portfolios to create a global capacity to drive a combined disciplined, for other companies to expand their growth
top 10 independent energy company low-cost operating model and unrivalled and capabilities.
by production. growth opportunities over the next decade.
The combined company is set to to Not only will the merger companies
have a high margin oil portfolio, long life create stronger balance sheets and strong
LNG assets and the financial resilience to cashflows for them, but it will also give Molly Hancock, Assistant Editor
help supply the energy needed for global Australia’s oil and gas industry a new look. molly.hancock@primecreative.com.au
growth and development over the energy As four large operators that boast a
transition. Woodside chief executive officer lot of projects in Australia and PNG, by
(CEO) and managing director (MD) Meg bringing all the assets together to create
O’Neill said merging the two company’s two companies, they will provide choice
oil and gas business would deliver a for shareholders, unlock synergies in
stronger balance sheet, increased cash how these assets are managed and allow
flow and enduring financial strength to fund capital to be deployed to the highest quality
planned developments in the near term opportunities. The merger companies will
and new energy sources into the future. also enable the skills, talent and technology
On November 22, Woodside confirmed of all four organisations to build a resilient
that that the two companies had signed a future as the industries’ needs evolve. With FRONT COVER
Scarborough and Pluto
binding share sales agreement, bringing BHP pioneering the development of the oil
Expansion Project.
the merger one step closer. Santos and Oil and gas industry in Australia in the 1960s, Image credit: Woodside.
Search followed suit at the beginning of it has grown to become the world’s largest
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3 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUVICTORIA
CRIB POINT TO PAKENHAM PIPELINE
ONSHORE | GAS PIPELINE | IN PLANNING | PROPONENT: AGL ENERGY
AGL Energy SCOPE
Level 22 Proposed by AGL Energy, the Crib Point to Pakenham Pipeline is intended to relieve gas supply
101 Miller Street pressure on the Victorian market by connecting interstate and international LNG ships to the local
North Sydney NSW 2060
P: (02) 9921 2999 market via the floating storage and regassification unit (FSRU) at the existing Crib Point jetty.
The high-pressure buried pipeline will transport gas from 12 to 40 LNG ships each year and will
PIPE STATS connect to the existing network via a link in Pakenham. The project consists of a bidirectional
Length: 55-60km pipeline, as well as some plant and equipment setup, including metering and odourisation.
Diameter: 600mm
UPDATE
March 2021: The Victorian Government has ruled out AGL Energy and APA Group’s proposed
gas import terminal at Crib Point and construction of a pipeline from the terminal to Pakenham.
Victorian Minister for Planning Richard Wynne said marine discharges from the proposed
project would have unacceptable effects on the environment in Western Port, which is listed as
a Ramsar wetland of international significance. The decision is based on an environment effects
statement (EES) produced by AGL and APA, around 6000 public submissions and a report into
the findings of the statement by an independent Inquiry and Advisory Committee (IAC).
PREVIOUS HISTORY
February 2021: The Liberal National opposition in Victoria has vowed to stop AGL’s Crib Point
development if elected to government in November next year. Outlined in EnergyQuest’s
OWNERSHIP monthly LNG report, Shadow Minister for Energy and Resources Ryan Smith said the opposition
APA Group 100%
was against an import terminal due to community backlash.
December 2020: EnergyQuest expects that additional gas supplies are urgently needed for the
southern states, particularly Victoria, where gas is predominantly used for manufacturing and
commercial purposes. A public inquiry into AGL’s proposed Crib Point project commenced in
September and is due to continue until December 17. The project has drawn a record number
of objections, notwithstanding the dire outlook for gas supply in the southern states. The inquiry
is due to report to the Victorian planning minister within 30 days of the final day of hearings, by
February 24, after which the minister has 20 days to make a decision.
August 2020: AGL Energy advised in its 2020 financial year results that the gas spot price
declined through financial year as excess market supply from the northern states continued
with lower domestic demand and liquefied natural gas (LNG) exports. AGL expects gas supply
constraints to hit in the early to mid-2020s. As a result the company continues to pursue both
the Crib Point import project and competitive re-contracting of gas supply, to ensure adequate,
flexible supply with trading exposure to international LNG pricing.
May 2020: AGL, presenting at the 2020 Macquarie Australia Conference, advised that its long-
term focus continued to be on building optionality and flexibility into its portfolio through diverse
contracting (both for supply and storage) and with projects like Crib Point.
February 2020: In the company’s half year report, AGL reported that it was continuing to
progress the Crib Point LNG import project. The company outlined that the project remained
compelling, subject to environmental approval and a final investment decision. AGL also
highlighted that the timing and cost of the project would likely be impacted by the increased
complexity of it.
December 2019: APA Group announced that it entered into a new gas transportation
agreement on December 18 on the East Coast Grid with AGL Energy, commencing January
1 2020. The new two-year multi-asset, multi-service agreement replaces an expiring contract
with AGL.
November 2019: Still battling approvals. AGL’s import terminal and subsequent pipeline are
now anticipated to be operational in 2022. AGL purchased 50 PJ of gas from Esso to keep its
supplies strong until it can import LNG using the proposed facilities, scheduled to be connected
to the project’s compression station from October 2019.
July 2019: According to media reports, approvals for AGL’s import terminal and the APA Group
Crib Point to Pakenham may not be received until the middle of 2020 and may require design
changes and extra costs.
4 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUVICTORIA
SOLE GAS PROJECT
ONSHORE AND OFFSHORE | PIPELINE | IN OPERATION | PROPONENT: COOPER ENERGY
Cooper Energy SCOPE
Level 10 Previous operator Santos first proposed the development of the Sole gas field off the
60 Waymouth Street coast of Victoria. Santos sold the Sole project to Cooper Energy in 2016. A 40km subsea
Adelaide SA 5000
P: (08) 8100 4900 pipeline connects the field to the Orbost gas plant on the Victorian coast, 10km from
Orbost. Operations at the Orbost gas processing plant involve separation, compression and
PIPE STATS dehydration of raw gas. Sales gas is then transported to the Eastern Gas Pipeline.
Capacity: 68 TJ/day
UPDATE
February 2021: Cooper Energy has reported record production and sales volumes in the
December 2020 half year as output has ramped up from the Sole gas field. Increased gas
production from Sole underpinned an 82 per cent increase in total production to 1.20 million
barrels of oil equivalent (MMboe).
PREVIOUS HISTORY
January 2021: Despite Cooper Energy’s half year production increasing to 1.16 million
barrels of oil equivalent (MMboe), quarterly production was down by 28 per cent to
0.49 MMboe. This was a result of lower Sole gas production during the reconfiguration
of the Orbost gas processing plant. “While works continue to establish a stable gas
OWNERSHIP production rate at the Orbost gas processing plant, we are seeing positive signs from the
Cooper Energy 100% reconfiguration of the plant’s absorbers and remain confident that the plant’s capacity rate
of 68 terajoules a day (TJ/d) can be achieved over time,” managing director David Max-well
PIPELINE
CONTRACTORS said.
Diamond Offshore: Drilling December 2020: Cooper Energy has confirmed that reconfiguration works at the Orbost
contractor gas pro-cessing plant in Victoria have been completed as planned. The plant, which is
Subsea 7: Subsea pipeline owned and operated by APA Group and processes gas from Cooper Energy’s Sole gas field,
and installation has also commenced its supply contract to industrial customers.
November 2020: Cooper Energy has mapped out a clear pathway and timeline for
the commence-ment of firm supply from Sole in the Gippsland Basin. Outlined in the
company’s annual general meeting report, Maxwell highlighted that it now means Cooper
Energy has a plan for higher produc-tion, prices and cash generation. “The first step is the
commencement of plant reconfiguration works at the Orbost gas processing plant next
week,” Maxwell said. “Production is expected to resume in early December, with the plant
reconfigured for more reliable and higher production than has been possible until now.”
August 2020: APA Group and Cooper Energy have executed an agreement to complete
the com-missioning of the Orbost gas processing plant (OGPP) in Victoria. The transition
agreement sup-plements the exisiting project documents, and sets aside potential claims
and entitlements available to either party, resulting in sharing of costs and revenue while
OGPP commissioning proceeds to-wards completion.
July 2020: Cooper Energy has hit a quarterly production record on the back of its first full
quarter since the Sole gas project commenced operations in the Gippsland Basin offshore
Victoria. In a quarterly update, Cooper reported that production increased by 118 per cent.
With commissioning of the plant ongoing, Cooper has recorded daily production from Sole
at 31 TJ and 48 TJ so far in July, with an average of 43 TJ. The plant performance is yet to
sustain gas supply of 68 TJ/day to complete the commission of the pant.
June 2020: The Orbost gas plant is progressively achieving a sustained increase in plant
output rates, including a a record of 55 terajoules a day during commissioning. APA
reported that output has averaged 34 TJ/day from May 20, with performance demonstrating
the plant’s capability to maintain production of 45 TJ to 40 TJ. The company found a
reoccurrence of fouling due to pro-longed foaming in the second absorber, which will require
a second shutdown for cleaning of the absorber vessel. APA has advised that a second
antifoam dosing pump has been installed since the previous shutdown at the beginning of
May to improve performance. The shutdown was scheduled for June 20-21, and was set to
take six days to complete.
5 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUQUEENSLAND
PROJECT ATLAS
ONSHORE | CSG | IN OPERATION | PROPONENT: SENEX ENERGY
Senex Energy SCOPE
Level 14 Project Atlas involves the delivery of natural gas from coal seams on acreage located
144 Edward Street near Wandoan and Miles in Queensland’s Surat Basin. The 56km2 acreage is estimated to
Brisbane QLD 4000
P: (07) 3335 9000 contain P50 recoverable gas volumes of 201 PJ, with investment of more than $200 million
to drill around 100 wells and construct associated infrastructure. First gas was achieved
at the project in November 2019.
UPDATE
AUGUST 2021: Senex Energy has announced the final investment decision (FID) has been
taken for the $40 million expansion of natural gas production at Atlas by 50 per cent to
18 petajoules (PJ/year). Managing director and CEO Ian Davies said the Atlas expansion
project is yet another example of the low-risk, high-return organic growth opportunities
available to Senex with its established hub-and-spoke infrastructure operating model.
PREVIOUS HISTORY
February 2021: Senex Energy outlined in its quarterly report that daily production at
OWNERSHIP Atlas reached 30 TJ/d subsequent to quarter end and continues to track towards initial
Senex Energy 100%
nameplate capacity of 32 TJ/d. In addition, activities at Atlas are progressing, including
PIPELINE work with Jemena on front-end engineering design (FEED) and long lead item planning
CONTRACTORS for the gas processing facility expansion, and FID targeted for the second half of the 2021
Pipeline: Jemena financial year.
Compressions Station
Construction: Valmec September 2020: Senex Energy has been awarded additional Atlas acreage as part of
the Queensland Government’s domestic gas acreage tender process. The Atlas acreage
is immediately adjacent to its existing development in the Bowen Basin, and on trend with
the Scotia and Meridian gas fields. As a result, this will enhance the company’s exisiting
development, with the contiguous block bounded by prolific has producing acreage, and
resource quality and reservoir performance expected to be high-quality.
July 2020: Senex Energy has reported a 21 per cent increase in Surat Basin 2P gas
reserves to 239 petajoules (PJ) following the execution of its natural gas developments in
Queensland. In an independently assessed estimate of reserves and contingent resources,
the company’s appraisal and development drilling results at Atlas have driven a 62 per cent
increase in 2P gas reserves, with a 90 PJ increase to 234 PJ.
June 2020: Senex Energy has reported that Atlas production was exceeding 15 TJ/day and
increasing steadily towards nameplate capacity of 32 TJ/day. The company stated that
initial water treatment facilities at Atlas had been commissioned, with final construction
to be completed in early 2021. Senex managing director and chief executive officer Ian
Davies said the Surat Basin natural gas development project was executed superbly, with
strong support from partners and stakeholders.
May 2020: Senex Energy has signed a one-year agreement with CleanCo Queensland for
2.55 petajoules of natural gas from Project Atlas in the Surat Basin, Queensland. As part
of the agreement, Senex will supply natural gas from January 1, 2021, with gas supplied at
the Wallumbilla gas hub at a fixed price in line with current market levels. Senex managing
director and chief executive officer Ian Davies said the company was proud to be helping
power homes and businesses throughout Queensland with cleaner energy. “The increase
in supply of Atlas gas to CleanCo is a great outcome for Queensland, enabled by the state
government’s policy to support the domestic market,” Davies said.
April 2020: Senex has reached a number of important milestones at Project Atlas in
2020, including the return of Easternwell Rig 27 in March following the completion of
the Roma North drilling campaign. Senex also reduced its planned 60-well campaign at
Project Atlas to 50 wells due to strong initial production performance from the first 23
wells and learnings from Roma North. Six wells have been spudded, with 32 of 50 wells
now drilled and completed.
6 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUQUEENSLAND
GLENARAS GAS PROJECT
ONSHORE | CSG | UNDER CONSTRUCTION | PROPONENT: GALILEE ENERGY
Galilee Energy SCOPE
Level 26 Galilee Energy’s Glenaras gas project is located in the ATP 2019 (formerly ATP 529) tenement
71 Eagle Street in the western section of the Galilee Basin. The project is designed to evaluate the quantity and
Brisbane QLD 4000
P: (07) 3177 9970 quality of CSG in the Betts Creek and Aramac Coal Beds. In 2015, Galilee resumed full ownership
of the project. In October 2017, Galilee announced the signing of a binding memorandum of
understanding with Jemena to work together to deliver the Glenaras gas project to the domestic
market.
UPDATES
May 2021: Galilee Energy has optimised production at its Glenaras multi well pilot program in
Queensland following the completion of the pump enhancement program (PEP). Natural gas is
now being recorded in five of the outer vertical wells and the PEP has succeeded in its objective of
increasing the water rate by over 30 per cent, with the current water rate now below 19,000 barrels
of water per day. The company also noted that the average natural gas rate from the pilot has
increased to approximately 70 Mscfd in aggregate.
April 2021: Galilee Energy has confirmed that its PEP at its Glenaras multi-well pilot program in
OWNERSHIP Queensland is tracking to schedule. The first facet of the program was the upgrade to the power
Galilee Energy 100%
generation system, with all the new larger horsepower pump now being completed. The company
has advised that the upgrading cabling to the vertical wells has also progressed. Workover activity
has been completed safely and within budget on the first three wells of the six well program –
Glenaras 19, 20 and 21. Galilee reported no sediment or fill was encountered and as a result there
was no need for further clean-out activities, meaning longer term pump reliability. The new larger
pumps at each of the above three wells have been commissioned and brought back online.
PREVIOUS HISTORY
January 2021: Galilee Energy has advised that each of the six new vertical wells as part of its
Glenaras multi-well pilot program are now in continuous production. The company also highlighted
that the total water rate from the full pilot is 14,500 barrels of water per day (BOPD).
December 2020: Galilee Energy has hit a key milestone at its Glenaras multi-well pilot program,
with all six new vertical wells now completed. The completions rig and camp have now been
demobilised from site, with the rig due back at the site in late January.
November 2020: Galilee Energy has officially completed the commissioning of Glenaras 19, 20 and
23 as part of its multi-well pilot program. The company previously announced that the Silver City rig
had completed the recent drilling campaign with the drilling of five additional vertical wells, with the
completions rig installing electrical submersible pumps (ESPs) to the wells.
October 2020: Galilee Energy has drilled the final well of the Glenaras multi-well pilot program,
with Glenaras 22 being drilled safely and on schedule. The Glenaras 22 vertical well was spudded
on October 11, reaching planned total depth and intersecting the full Betts Creek coal section, with
the rig released on October 16. The company also submitted two Potential Commercial Area (PCA)
applications to the Queensland Government to secure longterm tenure of the Glenaras gas project.
August 27, 2020: Galilee Energy has signed a drilling contract for the Glenaras multi-lateral pilot
program with Silver City, which will mobilise in the coming weeks. Galilee contracted Silver City’s
Rig 25 Schramm T200XD drill for drilling to commence in mid-September across five to six weeks.
Galilee will drill five new wells around the perimeter of the pilot, with Glenaras 17A to be used as
a prouder to achieve this objective. Meanwhile, Galilee Energy is confident in its Glenaras multi-
lateral pilot program in the Galilee Basin, Queensland after Schlumberger revealed significant
information from reservoir stimulation. As a result of the Schlumberger modelling, it has indicated
that, at Glenaras 17A well location, the entire Betts Creek coal sequence is being depleted almost
uniformly by the pilot.
June 2020: Galilee Energy has confirmed that the recently-drilled Glenaras 17A monitoring well
in Queensland has provided positive information on the reservoir characteristics and vertical
connectivity within the Betts Creek coal sequence. As part of the Glenaras multilateral pilot
program in the Galilee Basin (ATP2019), the company’s primary focus is converting the certified
contingent resources to reserves.
7 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUQUEENSLAND
ROMA EAST PROJECT
ONSHORE | CSG | IN OPERATION | PROPONENT: SANTOS
Santos SCOPE
60 Flinders Lane The Roma East project will involve bringing 480 wells online, including the drilling of around 430
Adelaide SA 5000 new wells, connecting existing appraisal wells, and drilling pre-developed wells in the Roma
P: (08) 8116 5000
region. The project will also include around 420km of water, gas gathering and other pipelines,
120 TJ per day of additional compression, 670km of power lines and around 25km of fibreoptic
cables. A water-handling facility for irrigation and more than 200 hectares of additional irrigation
in the Roma area will improve livestock carrying capacity. The project is expected to add
nearly 50 PJ a year to gas production in Queensland in 2020 – equivalent to about 8 per cent
of expected east coast domestic gas demand in 2018.
PREVIOUS HISTORY
July 2020: Santos outlined in its 2020 second quarter activities report in July that drilling was
complete in the Roma East project with 387 of 424 wells online to date and the last well is
expected online in the third quarter. Continued production growth from Roma resulted in gross
daily production increasing to 165 TJ/day at the end of the quarter, driven by new development
OWNERSHIP areas of the field and sustained high production in legacy areas.
Santos 100% April 2020: Drilling continues at the Roma East project with 368 wells drilled and 340 of 424
wells online to date, Santos reported in its March 2020 report. Continued steady production
growth from Roma resulted in gross daily production increasing to 155 TJ/day at the end of the
quarter, with production continuing to build.
January 2020: Drilling continues at the Roma East project with 327 wells drilled and 302
wells online to date, Santos reported in its December 2019 update. Continued steady
production from Roma resulted in gross daily production increasing to 137 TJ/day at the end of
the December quarter.
November 2019: Santos reported in its September quarter report it had drilled 274 wells and
brought 223 wells online at the Roma East project.
October 2019: Santos is continuing drilling operations towards its 480 wells targeted wells at
Roma East. In its 2019 half year results, the company reported that the project had maintained
an average cost of $0.83 million/well.
August 2019: Operations are continuing with 222 wells drilled and 181 wells online. Santos said
production from the project was building in line with expectation as dewatering continued.
May 2019: Drilling continues at the project with 158 wells drilled. There are now 109 wells online
and Santos achieved first gas sales from the development during the first quarter of 2019.
March 2019: Santos has now brought 86 wells online at the project, with a forecast of 380
wells to be online by the end of the year.
February 2019: Drilling continues at Roma East with 121 wells drilled with 80 wells now on
flare. At the end of December 2018, gross daily production had increased to 82 TJ/day.
November 2018: Drilling on the Roma East project continues, with 95 well sdrilled, 15 wells on
flare and early dewatering commenced as at October 18, 2018.
October 2018: Santos has awarded the Roma East Backbone Project to MPC Group. This
includes 34km of DN500 gas pipelines, 34km of DN400 water pipeline and 35km of 66kV
overhead powerline. MPC Group’s team has mobilised to a site near Roma and commenced
mainline operations.
August 2018: Drilling continues in the Roma East project with 51 wells drilled to date.
May 2018: The Roma East project has commenced, and two drilling rigs have drilled 15
wells to date.
April 2018: Santos and its GLNG partners will invest $900 million in upstream developments
in the Maranoa, Western Downs, Central Highlands and Banana regions this year. As well
as upstream developments around the Fairview, Scotia and Arcadia fields, this investment
includes the first year of funding for the new $750 million Roma East project, which will be
developed over the next three years. Santos executive vice president onshore upstream
Brett Woods was joined by Queensland Minister for Mines and Energy Dr Anthony Lynham to
launch the Roma East project, following the drilling of the first of 430 new wells in March.
8 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUQUEENSLAND
SURAT GAS PROJECT
ONSHORE | UNCONVENTIONAL | IN PLANNING | PROPONENT: ARROW ENERGY
Arrow Energy SCOPE
Level 39 Arrow Energy, a joint venture between Shell and PetroChina, is advancing the Surat gas
111 Eagle Street project with the aim of commercialising gas resources located in an area 160km west of
Brisbane QLD 400
P: (07) 3012 4000 Brisbane in Queensland’s Surat Basin. The project received its environmental approval from
the Australian Government on December 20, 2013, and by the Queensland Government on
October 25, 2013. In December 2017, the company signed a seven-year gas supply deal with
the Queensland Curtis LNG development to commercialise the majority of the company’s
gas reserves in the basin, which would reduce the amount of new infrastructure needed for
the project.
UPDATE
March 2021: Rey Resources has agreed with Southernpec Australia (SouthnA) to extend the
commencement date of the Surat gas project stage two, 75 per cent investment, until April 16.
SouthnA currently holds significant interests in seven conventional gas production licences in
the Surat gas project, located south of the Roma GLNG asset in the Surat Basin, Queensland.
The Surat gas project includes the Waldegrave joint venture where SouthnA is the operator
OWNERSHIP with its joint venture partner Armour Energy. In addition, stage three will see Rey invest or
Arrow Energy 100%
assist SouthnA to raise up to $5 million for additional 20 per cent interest in SouthnA before
the beginning of the third stage JV work program in October 2021.
PREVIOUS HISTORY
January 2021: Arrow submitted original plans to drill six wells last year. However, the
Queensland Department of Environment and Science has opened a public consultation for a
much larger campaign. Outlined in the document, the application will expand the proponent’s
existing coal seam gas activities and add an additional 280 wells, a 440km pipeline and
other associated activities. Arrow’s environmental authority (EA) has been assessed by the
department as a major amendment as it proposes to increase the surface area of the existing
activities by more than 10 per cent and involves a significant increase in scale.
November 2020: Valmec has secured early works on the first phase of Arrow Energy’s Surat
gas project. The company’s initial contract with Arrow is to deliver critical water treatment
facilities, valued at $16 million, and forms part of the first phase of works at the major gas
development. The turnkey project involves procurement, construction and commissioning
works at the Daandine facility.
April 2020: Joint venture partner Shell Australia has taken a final investment decision (FID)
to develop the first phase of Arrow Energy’s $10 billion Surat gas project in Queensland. The
project is expected to deliver up to 90 billion cubic feet per year of gas to market at peak
production, which will flow to the Shell-operated QGC liquefaction plant to be sold locally and
exported to international markets. Construction of the project will commence in 2020, with first
gas sales expected in 2021. The Surat gas project will bring an extra 5000 petajoules of gas to
market over 27 years, including about 270 terrajoules a day (TJ/day) during phase one’s peak
production, towards a whole-of-project peak of 700TJ/day. The project is expected to create
an initial 200 new construction jobs during its first phase and a further 800 operation and
construction jobs over its life.
August 2019: Despite aiming to begin development of the project later this year, Arrow has
expressed that this is not a forgone conclusion as political decisions are made regarding east
coast gas shortages. According to The Australian Financial Review, Shell said the project
needed consistent attention to keep it on track and the company was concerned about a 25
per cent increase in gas production royalties announced in Queensland.
June 2019: Arrow Energy has awarded a joint venture a contract for construction on two of
its major projects. Under the contract, a JV comprising China Petroleum Engineering and
Construction and Nacap (CNJV) will deliver off plot construction management services for
Arrow for construction works in the Surat and Bowen basins in Queensland. CNJV will include
construction of the surface well pad infrastructure, as well as Arrow’s gathering networks.
9 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUQUEENSLAND
WESTERN SURAT GAS PROJECT
ONSHORE | CSG | UNDER CONSTRUCTION | PROPONENT: SENEX ENERGY
Senex Energy SCOPE
Level 14 The Western Surat gas project will focus on the development of the Glenora and Eos blocks,
144 Edward Street and appraisal of the Mimas and Tethys blocks (collectively, Roma North) in its initial stages.
Brisbane QLD 4000
P: (07) 3335 9000 The primary objective is to reach minimum initial production of 16 TJ/day, with potential for
expansion to 24 TJ/day. Up to 425 wells and associated infrastructure are expected to be
constructed for the project.
UPDATES
June 2021: Heavy lifting has begun to boost production of natural gas from Senex Energy’s
Roma North operation in Queensland’s Surat Basin. Two compressors have been lifted into
position as part of its infrastructure partner, Jemena’s, $15 million expansion of the natural
gas processing facility. Senex advised that the construction contract, which was awarded to
Wasco, has created dozens of jobs.
May 2021: Jemena has started work on the $15 million expansion of the Roma North
gas processing facility in Queensland’s Surat Basin. The company advised that work
commenced following it awarding Queensland-based Waco Australia a construction
OWNERSHIP contract for the project. Jemena executive general manager of gas markets Antoon Boey
Senex Energy 100%
said Wasco Australia has a proven track record in completing complex projects at gas
processing facilities across the region and was well suited to partner with Jemena on
the expansion project.
PREVIOUS HISTORY
January 2021: Senex Energy’s Roma North expansion is on track to be online by the first
quarter of the 2022 financial year, with further production expansions at Roma North and
Atlas both within the front end engineering design (FEED) phase. Key activities at Roma North
are underway, including the execution of the gas processing facility expansion, well design
and gathering campaign, progressing land access and other approvals, and procurement
and fabrication of long lead items including compressors and well field equipment.
October 2020: Senex has made a final investment decision (FID) on a 50 per cent expansion
of natural gas production at Roma North in Queensland, with the increase expected to be
online in the first quarter of 2022. With an extensive Surat Basin gas resource position and an
established hub-and-spoke infrastructure operating model, the company confirmed it was
positioned to contribute to Australia’s recovery from COVID-19.
July 2020: Senex Energy has reported a 21 per cent increase in Surat Basin 2P gas reserves
to 239 petajoules (PJ) following the execution of its natural gas developments in Queensland.
Senex’s production outperformance at Roma North has also continued, driven by a
10 per cent increase in 2P gas reserves.
June 2020: Senex Energy has hit an important milestone with it completing the $400
million Surat Basin natural gas development project in Queensland. The company has now
completed an 80-well Surat Basin drilling campaign, a program it reduced from the110 wells
originally planned due to production outperformance. Alongside its infrastructure partner
Jemena, Senex has also built and commissioned natural gas facilities at Roma North and
Atlas, delivering greenfield gas processing infrastructure capacity of more than 20 petajoules
(PJ) a year. In addition, Senex outlined that Roma North has been consistently producing
above nameplate capacity at around 18 terajoules per day (TJ/day), with Atlas production
exceeding 15 TJ/day and increasing steadily towards nameplate capacity of 32 TJ/day.
April 2020: At Roma North, the initial 50-well drilling campaign was reduced to 35 wells
based on production outperformance. Senex has completed and drilled the final 15 wells
of the 35-well campaign, with the Easternwell Rig 27 demobilised and returned back to
Atlas. Senex also reached the plant’s nameplate capacity of 16 TJ/day during the quarter,
more than 12 months ahead of schedule. As a result, the company has entered the front-
end engineering design (FEED) phase on the low-cost 8 TJ/day expansion of the gas
processing facility to 24 TJ/day, which is expected to be finalised in the second half of 2020.
10 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUQUEENSLAND
MAHALO PROJECT
ONSHORE | CSG | UNDER CONSTRUCTION | PROPONENT: COMET RIDGE
Comet Ridge SCOPE
GPO Box 798 The Mahalo project is located in the ATP 337P permit in the Denison Trough. This area is
Brisbane QLD 4001 prospective for coal seam gas in Permian aged coals that are draped over a large north-
P: (07) 3221 3661
south trending structural high known as the Comet Ridge. These coals have proven to be
productive at the Origin Energy Spring Gully coal seam gas development project 150km to
the south on the same structural high. The Mahalo project has a range of potential volumes
of gas in place ranging from a minimum of 181 Bcf up to a maximum of 990 Bcf. The most
likely volume is estimated to be in excess of 400 Bcf.
UPDATE
October 2021: Comet Ridge commenced drilling operations at Mahalo North 1 vertical well
on October 16, 2021. Later in the month, the company also started drilling operations at the
Mahalo North 2 dual lateral well.
PREVIOUS HISTORY
OWNERSHIP May 2021: Comet Ridge and its joint venture partners have continued to assess the best
Comet Ridge 40% way to take the Mahalo gas project forward during the first quarter of 2021. The company
Santos 30%
APLNG 30% also had to consider the best way to maximise the three 100 per cent blocks that lie
immediately north of the Mahalo gas project. The three blocks have been marked as driving
down unit costs and increasing the total gas off take form the combined Mahalo hub
area when combined as a development concept. The Queensland Government has given
Comet Ridge the green light for a new Bowen Basin project, allowing the company to begin
exploration for new sources of gas. The state’s Resources Minister Scott Stewart said the
company has been granted an authority to prospect (ATP) over a 338 square kilometre
parcel of land located in the gas rich Bowen Basin. The new ATP will allow Comet to begin
exploration for new sources of gas while utilising its existing gas infrastructure in the region
to plug straight in and get gas to market faster.
October 2020: Comet Ridge has been awarded petroleum survey licence (PSL) 2048, an
area that covers part of the Mahalo gas hub in Queensland, for two years. The area, which
covers more than 1962km2, also includes the export route to the south where there are
two existing large diameter pipelines running into Gladstone – the Jemena Queensland gas
pipeline and Santos’ GLNG pipeline.
September 2020: Comet Ridge has been selected by the Queensland Government
as the preferred tender for two additional gas blocks in the Mahalo gas hub in Central
Queensland. The first block, PRL2020-1-1, will be named Mahalo East. Located west of
Gladstone, it covers 97km2 and sits east of Mahalo North. The second block, PRL2020-1-2,
is set to be called Mahalo Far East. It covers 338km2 and is slightly further east again.
July 2020: Comet Ridge has been granted petroleum leases 1082 and 1083 at the Mahalo
gas project for 30 years by the Queensland Government. Comet Ridge reported that the
petroleum lease awards are the final regulatory approval required to move the project into
production.
June 2020: The Queensland Government has granted Comet Ridge an environmental
approval for development of the Mahalo gas project (MGP). This milestone marks the
second of two environmental steps needed for the project to move into production,
following the Commonwealth Government Environment Protection and Biodiversity
Conservation act (EPBC) approval in May.
March 2020: Comet Ridge and LogiCamms have signed a memorandum of understanding
to work towards a 65km-plus pipeline connection option from Mahalo North in Queensland.
In a statement, Comet has reported it is continuing to work with Denison Gas and the
Mahalo joint venture on the transportation of Mahalo North gas to market. Comet Ridge has
entered into an agreement to consider an export solution by building a new pipeline which
would transport not only Mahalo North gas but accommodate its 40 per cent share in the
Mahalo JV gas.
11 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUQUEENSLAND
KINCORA GAS PROJECT
ONSHORE | CSG | IN OPERATION | PROPONENT: ARMOUR ENERGY
Armour Energy SCOPE
Level 27 Armour Energy completed the acquisition of petroleum resources, tenures, production and
111 Eagle Street transportation infrastructure assets on the Roma Shelf in the Bowen-Surat Basin, Queensland
Brisbane QLD 4000
P: (07) 3303 0620 from Origin Energy in September 2016. The project consists of gas, LPG condensate
processing and gas compression facilities at Kincora, a gas storage facility with a capacity of
7.5 PJ, over 3000km² acreage containing 15 production licences, four authorities to prospect
and four petroleum pipeline licences. These assets are all located near the Wallumbilla gas
hub on Australia’s east coast.
PREVIOUS HISTORY
January 2021: Armour Energy’s 2020 work program has established proof of concept in the
Basal Rewan formation, unlocking new potential throughout the Kincora gas project. The
company reported that the Basal Rewan results have established the potential for a significant
new pay zone across its existing well stock. Armour is encouraged by the sustained high
bottoms-hole pressures in the Basal Rewan and higher levels of permeability identified in the
Warroon #1 well, paving the way for a potential material reserves maturation plan to unload
OWNERSHIP across the company’s Surat acreage.
Armour Energy 100%
November 2020: Armour Energy has completed the multi-stage stimulation activities on the
Horseshoe #2 well as part of its Surat Basin 2020 work program at the Kincora gas project.
Armour will now install a production string and the Horseshoe #2 well will commence the
clean-up and blowback phase prior to returning to sales gas production. The company also
reported that it had completed the stimulation activities on the Horseshoe #4 well, with it
finishing a single-stage stimulation of the basal Rewan sandstone over a 4m interval from
1936m to 1940m.
October 2020: Armour Energy has completed pre-stimulation activities at the Kincora gas
project. The three-well stimulation program has been awarded to Condor Energy Services,
which will commence the Horseshoe#4 stimulation in due course. On completion of the
Horseshoe#4 stimulation program, Condor will mobilise its stimulation equipment for, firstly, a
two-stage program on the Horseshoe#2 well site to target both the Basal Rewan resource and
a deeper gas-saturated Intra Wallabella sandstone deposit.
September 2020: Armour has commenced work on its Surat 2020 work program at the
Kincora gas project. The work program consists of a three-well stimulation campaign,
which will be executed over the next three months at the Horseshoe 4, Horseshoe 2 and
Warroon 1 wells.
July 2020: Armour has reported in its 2020 quarterly activities report that the upcoming
2020/2021 work program will deliver further stimulation of wells and well optimisations over
a two-stage program across multiple wells. This program is set to target the accessing and
converting 2P reserves recognised in the Kincora Reserve increase.
June 2020: The company has announced its capital raising program of $3.36 million is
intended to be used for the purposes of progressing the Kincora project area well intervention
and work program. The funds will also be used for the payment of interest and scheduled
amortisation reductions in respect of the company’s Amortising Notes for the balance of 2020;
exploration expenditure; the costs of the raisings; and general working capital.
May 2020: Armour’s gas sales at Kincora for the March quarter averaged 7.6 terajoules a day
(TJ/day), representing a slight increase compared with the previous quarter of 7.5 TJ/day. The
company also revealed there was a new 2P oil reserve of 1.22 million barrels at its SuratBowen
Basin acreage. The adding of material oil reserves and resources to Armour’s portfolio
validates the long term and diverse potential of the wider Kincora project.
April 2020: Armour Energy is aiming to cut operating expenditure at Kincora by 20 per
cent, while maintaining reliable production in a safe and environmentally compliant manner.
This will include revised staff rostering and schedules but will unfortunately include some
redundancies. Armour planned to implement the site-related changes by the end of April.
12 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUQUEENSLAND
PROJECT VENUS
ONSHORE | CSG | IN DEVELOPMENT | PROPONENT: REAL ENERGY
Galilee Energy SCOPE
Level 6 Project Venus is a 50:50 joint venture between Real Energy and Strata-X Energy and is located
167 Eagle Street in permit ATP2051, Surat Basin, Queensland. The permit has displayed the attributes of a
Brisbane QLD 4000
P: (07) 3177 9970 highly prospective coal seam gas (CSG) acreage. The tenement is surrounded by major CSG
producing tenements and covers 153km2 approximately 9km west of Miles. It is within 6km of
a gas pipeline connected to east coast gas markets offering the potential for early cash flows
once the significant gas resources are progressively converted to reserves.
UPDATES
June 2021: Pure Hydrogen has recorded an initial gas breakout at its Venus-1 well, located on
Project Venus in Central Queensland, after only 50 barrels of water production. The early gas
breakout confirms the interpreted high gas saturation of the target Walloon coals. The company
reported that the breakout gas rate, estimated at 84,000 cod, is expected to continue to
increase as the controlled pressure draw down expands radially into multiple high gas saturated
coal reservoirs from the low-cost Venus-1 vertical production well. The results of the flow test
to data and current gas pressure build-up suggests a successful, more robust enhancement at
Venus-1 could substantially decrease the time to achieve commercial gas flows.
OWNERSHIP May 2021: Pure Hydrogen has increased its coal seam gas (CSG) resources at Project
Galilee Energy 100% Venus in Queensland, with the upgrade confirming a maiden 2C contingent re-sources of
130 petajoules. The independent review of its Surat Basin CSG resources was completed by
Sproule Inc, with the resource upgrading being a portion of the 694 PJ of prospective resources
in project Venus with the balance of 536 PJ remaining as prospective resource.
PREVIOUS HISTORY
November 2020: Strata-X Energy and Real Energy have reached a total depth of 715m at the
Ve-nus-1 well within the Surat Basin Walloon CSG fairway, Queensland. The JV advised that
good gas shows were recorded in the uppermost 3-5m thick coal seams, with fair to good gas
shows in the deeper thinner coal seams. Strata-X outlined that the Juandah coals would be
underreamed be-fore running a liner, with a wellhead then installed and the Silver City rig being
demobilised.
September 2020: Strata-X Energy and Real Energy, plan to commence ground operations
on the first coal seam gas well at the Surat Basin site in Queensland during October. Roma-
based drill-ing contractor Silver City has been selected to drill the Venus-1 well. It will be drilled
to 400m, cased, then drilled out to a total depth of 680m, leaving the highly gas saturated
Juandah coal seams open and uncased. The joint venture reported that after the Silver City
rig is demobilised, a Wellpro coil tubing unit will be mobilised and carry out a short-term initial
water influx test.
July 2020: Strata-X Energy and Real Energy have entered into an agreement to merge and be
re-named Pure Energy. The companies reported that it represents an opportunity to create a
materi-al gas business from the 100 per cent owned gas resources contained within projects
located in the Surat and Cooper Basins in Queensland. Pure Energy’s project Venus is located
within the Walloon CSG fairway and immediately adjacent to gas pipeline infrastructure in
the Surat Basin.
April 2020: Real Energy and Strata X Energy are preparing to commence operations
on Project Venus in the Surat Basin, Queensland. The joint venture reported that it was
looking to complete the re-entry of Connor 1 well, which was originally drilled in 2008. It
has showed that 34m of net Walloon coals were present and there was 100 per cent gas
saturation in the upper Walloon coals. The re-entry plan is to: drill out cement to 384m; mill the
bridge plug; undertake abrasive perforations of coals seams from 410 to 645m; flow test the
well using a water test rig; undertake a controlled draw-down to determine water influx and
induce gas breakout; and use storage tanks for water from flow testing. Real Energy stated
that preparations for the re-entry of Connor 1 were well-advanced and the field work was
expected to start towards the end of the current quarter, subject to finalising scheduling with
contractors and site permits.
13 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUQUEENSLAND
KUMBARILLA
ONSHORE | CSG | IN DEVELOPMENT | PROPONENT: GALILEE ENERGY
Galilee Energy SCOPE
Level 6 Galilee Energy was granted operatorship and a 100 per cent interest in ATP 2043, known as
167 Eagle Street Kumbarilla, in August 2019, as part of the Queensland Government’s 2019 release of new
Brisbane QLD 4000
P: (07) 3177 9970 petroleum resource areas. The acreage, which covers 384km2, overlaps the Bowen and
Surat basins and has a 2C contingent gas resource of 504 PJ. Galilee’s initial program at the
Kumbarilla project in the Surat Basin will include the drilling of three exploration coreholes
targeting coal seam gas resources in the Walloon subgroup. The Walloon coals will be cored
and a full suite of wireline logs will be obtained, giving Galilee a full assessment of the coal
seam gas resource and begin planning the future drilling and pilot program.
PREVIOUS HISTORY
June 2020: Galilee Energy advised in its quarterly report that the exploration program at
Kumbarilla is progressing well, targeting the conventional oil and gas potential in the permit.
The reprocessing of over 675km of 2D seismic in and around Kumbarilla has provided
high-quality imaging of the subsurface structural and stratigraphic architecture along the
regionally prominent Moonie-Goondiwindi Fault System, which traverses through a large
portion of the permit and hosts the nearby Moonie oil field.
OWNERSHIP May 2020: Galilee Energy has completed phase one of the Kumbarilla exploration program
Galilee Energy 100% after reaching total depth at the third and final well and drilling through the complete Walloon
subgroup. The company reached a total depth of 1073m at the KC3 well in late April, with the
complete Walloon Subgroup being intersected with wireline logs confirming 22m of net coal.
As a result, an extensive suite of new subsurface data has been acquired, confirming net
coal development of 22m to 25m across the area, exceeding pre-drill expectations.
April 2020: Galilee Energy has reached total depth on the second well of three at its
Kumbarilla drilling program in the Surat Basin, Queensland. The KC2 well reached total
depth of 1140m and successfully drilled through the complete Walloon Subgroup, coal
bearing section. Galilee reported that the Walloon Subgroup was intersected with wireline
logs confirming a net coal of 25m across the Upper Juandah, lower Juandah and Tarom
coal measures. The Savanna Rig 406 is now being prepared for mobilisation to the third well
location for Kumbarilla Central 3 (KC3). Galilee Energy continues to progress the Kumbarilla
Central 2 (KC2) prospect, announcing on April 17 that it was preparing to spud the well later
in the day. Galilee advised that the Savanna Rig 406 was being mobilised to the second well
location, which is targeted to be drilled to a total depth of 1050m for testing. Following the
drilling of KC1, 20 high-quality coal samples have been collected from the full hole core and
placed into gas desorption canisters.
March 2020: Galilee Energy has commenced drilling operations at its 100 per cent owned
and operated Kumbarilla project in the Surat Basin, Queensland. The company reported that
the Savanna Rig 406 spudded the well, with surface hole drilling commencing at a depth
of 248m measured depth and drilling ahead in the 8 1/2-inch hole. Galilee reported that
the initial program at the Kumbarilla project would include the drilling of three exploration
boreholes targeting coal seam gas resources in the Walloon Subgroup.
14 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUNEW SOUTH WALES
NARRABRI GAS PROJECT
ONSHORE | IN PLANNING | PROPONENT: SANTOS
Santos SCOPE
60 Flinders Street The Narrabri gas project (PEL 238) hosts large resources of coal seam gas in two distinct and
Adelaide widespread coal measure sequences. A number of wells have been drilled and completed in
South Australia 5000
P: (08) 8116 5000 the Bohena area, 25km southwest of Narrabri, with promising results. Early production results
supported a production model interpretation of a major CSG province, with the potential for high
(3-5 Bcf) recoverable reserves per well. ESG has signed a heads of agreement with APA Group
regarding a new gas pipeline that could be built and connected to the Central West Pipeline for
CSG delivery from the Narrabri area into the New South Wales gas market. Previously known as
the Gunnedah Basin CSG project.
PREVIOUS HISTORY
November 2020: The Australian Government has approved Santos’ proposal for the Narrabri
gas project in New South Wales, with the company now set to embark on a 12-18 month
appraisal program. Managing director and chief executive officer Kevin Gallagher said the
conditions of the approval were consistent with those already set by the New South Wales
Independent Planning Commission. Federal Environment Minister Sussan Ley said the
announcement that the project had passed all environmental approvals meant that jobs and
OWNERSHIP
Santos 100% gas would soon start flowing.
September 2020: The New South Wales Independent Planning Commission (IPC) has
approved Santos’ Narrabri gas project due to its potential to improve Australia’s east
coast gas security and boost the state economy by delivering social benefits and ongoing
employment opportunities. In making its determination, the IPC has relied on materials
including a whole-of-government assessment conducted by the Department of Planning,
Industry and Environment. However, the IPC has granted a phased approval that is subject to
stringent conditions that Santos must meet before the project can progress to the next phase
of development. The four phases include: phase one – appraisal; phase two – construction;
phase three – production; phase four – rehabilitation.
July 2020: The Narrabri gas project has reached another milestone with the New South Wales
Department of Planning, Industry and Environment endorsing the project and referring it to
the Independent Planning Commission (IPC) for final approval. The Department of Planning,
Industry and Environment concluded its assessment of the Narrabri gas project and referred
the project to the IPC for public hearing and determination, recommending approval with
strict conditions.
June 2020: Santos is set to decide on whether or not to develop the Narrabri gas project after
new regulations were introduced by the New South Wales Government. The regulations will
allow for the consideration of new projects to continue over the coming months and for the
Independent Planning Commission (IPC) to hold public hearings. As a result, the IPC will be
able to make a decision on whether or not to provide consent for the development of Narrabri
within 12 weeks of it receiving the Department of Planning’s assessment report.
April 2020: Santos is set to decide on whether or not to develop the Narrabri gas project after
new regulations were introduced by the New South Wales Government. The regulations will
allow for the consideration of new projects to continue over the coming months and for the
Independent Planning Commission (IPC) to hold public hearings. As a result, the IPC will be
able to make a decision on whether or not to provide consent for the development of Narrabri
within 12 weeks of it receiving the Department of Planning’s assessment report.
June 2019: According to The Australian Financial Review (AFR), AGL has shown an interest in
purchasing gas from the Narrabri CSG production project. AGL is one of several major energy
retailers with purchase potential for the project, and has already signed three agreements with
Perdaman, Brickworks and Weston Energy. The company is considering its options, although
upstream investment is not on the cards.
15 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUPETROLEUM
INFRASTRUCTURE
OF AUSTRALIA
Ichthys LNG Project Greater Sunrise Gas
Shell Prelude FLNG Project NT.1 INPEX, 8.4 MMt/a LNG; 1.6 MMt/a LPG; Fields Development
NT.3 Woodside Petroleum,
Shell Development Australia 100,000 bbl/d condensate, 2017
WA.2 4 MMt/a, TBA
3.6 MMt/a LNG; 0.4 MMt/a LPG; Bayu-Undan
Field NT5
1.3 MMt/a condensate, 2017 Darwin LNG Project
DARWIN NT.2 ConocoPhillips, 3.24 MMt/a, 2003
BONAPARTE BASIN
NT8 Blacktip
Gas Field
Bonaparte FLNG
NT.4
NT6 NT7
Ichthys
Gas Field GDF SUEZ, 2 MMt/a, 2018
BROWSE BASIN
BEETALOO BASIN
NT2
Abbot Point LNG
Q.1 Energy World Corporation,
2 MMt/a, TBA
Karumba
NT1
Browse Development Broome
WA.1 Woodside Energy, 25 MMt/a, TBA Q.2 GLNG Project
NORTHERN TERRITORY
Q11
Century Mine Santos, 7.8 MMt/a, 2016
Tennant Creek
WA.7 Pluto Gas Project
NT10
Gorgon Project
WA.4 Chevron Australia, 15.6 MMt/a, 2016 W11 Woodside Petroleum, 4.3 MMt/a, 2012
Tanami QUEENSLAND
Townsville
W13
W12
Q.3 QCLNG Project
W9 Mt Isa
W7
NWS LNG Plant NT11 Q1
Wheatstone Project WA.6 CANNING BASIN QGC, 8 MMt/a, 2015
WA.3 Chevron Australia, 8.9 MMt/a, 2017 W21
W10
W6 North West Shelf Australia LNG
Dampier Port Hedland 16.3 MMt/a, 1989 Q10 Mackay
W24 Telfer
W16 Cannington
W14 W8 GEORGINA BASIN BOWEN BASIN
Q29
W17
Moranbah
W23 NT3
W19
W20
Alice Springs Q9 Barcaldine
Mereenie
Scarborough Gas Field LNG W4 Palm Valley
NT4
ADAVALE BASIN Q28
Q4
WA.5 Development AMADEUS BASIN
NT9
Gladstone
Woodside Energy, 10 MMt/a, TBA Q3
WESTERN AUSTRALIA Gilmore Gas Field
Q12 Q25 Q23 Q24
Q2
Bundaberg
Q26
Tarbat Q15 Q21
Q22 Q5
Roma
CARNARVON BASIN COOPER-EROMANGA BASIN Ballera
Q19
Q16 S1 Cheepie Wallumbilla
Q18
Jackson Q20
W25 Moomba Q17
Q13 Q6
Q14
W18
COOPER BASIN Q7 BRISBANE
Mount Magnet Moonie
Q8
Toowoomba
W22 Q27
Geraldton W3 Windimurra SOUTH AUSTRALIA
S2
N4
SURAT BASIN APLNG Project
Kalgoorlie N5
N9
Q.4 Origin Energy, Sinopec and
ConocoPhillips, 9 MMt/a, 2016
PERTH BASIN S3
GUNNEDAH BASIN
Kambalda
W15
W1
NEW SOUTH WALES Tamworth
S7
Port Bonython N8
N10
W5
PERTH Whyalla Dubbo
N6
W2 Newcastle
Parkes N11
Port Pirie Orange
Bunbury Esperance Angaston N7
Forbes
SYDNEY
S4 Mildura Griffith
ADELAIDE
N3
Wollongong
S6
VICTORIA
Wagga Wagga
Tumut
ACT
CANBERRA
N2
Horsham
V1
V2 Carisbrook Wodonga
N1
S5
Wollert
SYDNEY BASIN
Mount Gambier
Mortlake MELBOURNE V6
S8 V7
Portland V3 Longford
Geelong Orbost
V12 V14 V16 V8 V15
V5
V4 V17
V13
V10
Casino Gas Field V9
Bass Strait Fields
V11
GIPPSLAND BASIN
OTWAY BASIN
BASS BASIN
T2
T1
0 100 200 300 400 500 TASMANIA
HOBART
0 100 200 300 400 500
LEGEND
Compressor Proposed
Pump Station
Project Name
LNG Project P.1 Proponent, Total planned capacity,
Commissioning Year
16 / OCT/NOV 2021 / PPO PROJECTS: WWW.PPO.COM.AUYou can also read
