Chevron operates two of the largest LNG facilities on earth — Gorgon at 15.6 MTPA and Wheatstone at 8.9 MTPA — giving the company a combined Australian equity liquefaction capacity of 24.5 MTPA and a chevron lng storage footprint that extends from Barrow Island to the US Gulf Coast. With $6 billion in active Australian expansion projects and 7 MTPA of US LNG offtake contracted, Chevron’s LNG infrastructure position in 2026 is larger and more complex than any single headline captures.
Gorgon LNG — 15.6 MTPA on Barrow Island
Gorgon LNG sits on Barrow Island, approximately 60km off the northwest coast of Western Australia. The three-train facility carries a nameplate capacity of 5.2 MTPA per train, totalling 15.6 MTPA. Chevron operates with a 47.3% stake; ExxonMobil and Shell each hold 25%, with Osaka Gas, JERA, and MidOcean holding the balance.
Feed gas comes from the Gorgon and Jansz-Io fields in the Carnarvon Basin. Onsite storage comprises two LNG tanks with a combined 360,000 m³ capacity and four condensate tanks totalling 38,000 m³, served by a 2,100-metre loading jetty. The facility also delivers up to 300 terajoules per day of domestic gas to the Western Australian market. First LNG export was March 2016; the design life extends beyond 2050.
Key long-term offtake agreements include SK LNG Trading at 4.15 MTPA, Osaka Gas at 1.375 MTPA, JERA at 1.44 MTPA, and Tokyo Gas at 1.1 MTPA — covering the bulk of train capacity under contracted supply.
Gorgon Stage 3 and Jansz-Io Compression: $6 Billion in Expansion
Chevron sanctioned the Gorgon Stage 3 backfill programme in December 2025, committing approximately $2 billion (A$3 billion). The project involves six new wells across two gas fields and is designed to sustain feed gas supply to existing trains — not to add liquefaction capacity. It is a reservoir management investment, not a capacity expansion.
Running in parallel, the Jansz-Io Compression Project represents a $4 billion commitment targeting completion in mid-2026. Subsea compression equipment is being installed at approximately 1,300 metres water depth to counteract natural reservoir pressure decline at the Jansz-Io field. Together, Stage 3 and Jansz-Io represent the most material near-term capital deployment in Chevron’s LNG portfolio.
Wheatstone LNG — 8.9 MTPA at Ashburton North
Wheatstone LNG operates at the Ashburton North Strategic Industrial Area, 12km west of Onslow in Western Australia’s Pilbara region. Two trains deliver a combined 8.9 MTPA. Chevron holds a 64.14% operating interest alongside Woodside (13%), KUFPEC (13.4%), Kyushu Electric (1.46%), and PE Wheatstone (8%, partly owned by JERA).
The plant processes gas from the Wheatstone, Iago, Julimar, and Brunello offshore fields via a platform located roughly 225km north of Onslow. Train 1 achieved first production in October 2017; Train 2 followed in mid-2018; domestic gas supply commenced March 2019. In 2024, Wheatstone delivered a daily average of 196,000 barrels of net oil-equivalent. Major offtakers include Tokyo Electric at 3.1 MTPA, KOGAS at 1.5 MTPA, and Chubu and Tohoku Electric at 1 MTPA each.
Combined, Gorgon and Wheatstone place more than 80% of Chevron Australia’s equity LNG under long-term sales and purchase agreements — a contracted revenue base that underpins the ongoing capital commitment to both sites. For context on how these facilities compare globally, see the Top 10 LNG Terminals in the World 2026.
Angola LNG — Equity Position in West Africa
Beyond Australia, Chevron holds an equity stake in Angola LNG (ALNG), located at Soyo in northern Angola. ALNG is one of Africa’s largest LNG facilities and exports to both Asian and European markets. Chevron’s position there is supported by its role as a major upstream operator across Angola’s offshore blocks, making it an integrated producer-to-export presence on the continent.
Gorgon CCS — 10 Million Tonnes Injected, Performance Questions Remain
The Gorgon Carbon Dioxide Injection Project is the world’s largest integrated CCS system at an LNG facility. CO2 occurs naturally in Gorgon reservoir gas at approximately 15% concentration and must be separated before liquefaction. Injection into the Dupuy Formation beneath Barrow Island began in August 2019 — three years behind the original schedule. As of November 2024, Chevron reported more than 10 million tonnes of CO2 injected to date.
The system was originally designed to capture 80% of reservoir CO2 on a five-year rolling average, equivalent to approximately 3.4–4 MTPA. Independent analysis by IEEFA found the actual capture rate fell to around 30% in FY2023–24 — the lowest recorded — with the cost per tonne rising to above $200/tCO2 against an original estimate of roughly $70. Chevron continues to operate and invest in the system. The performance gap between design specification and reported outcomes remains a substantive issue for the project’s claimed climate credentials.
CCUS Expansion — Bayou Bend, Pascagoula and Beyond
Chevron is developing several US carbon capture and storage projects alongside its LNG infrastructure. The Bayou Bend CCS project, operated by Chevron (50%) with Equinor and TotalEnergies as partners, covers approximately 140,000 acres onshore and offshore along the Texas Gulf Coast. In 2024, the project drilled stratigraphic test wells in both settings and received EPA notice of administrative completeness for its Class VI injection permit — a significant regulatory milestone for one of the first potential offshore CCS projects in the US.
At Pascagoula, Mississippi, Chevron is planning to capture CO2 from its largest US refinery, which processes around 330,000 barrels per day. A CO2 pipeline would run north from the refinery to a storage site in Jackson County. Additional US projects include the Eastridge CCS initiative in California’s San Joaquin Valley and the DOE-awarded Kern River Carbon Capture pilot. These sit within Chevron’s $10 billion lower-carbon investment programme running from 2022 to 2028.
Offshore Australia, Chevron holds GHG storage permits across four joint ventures covering more than 10 million acres evaluated for CO2 storage potential, with MoUs signed with ENEOS Xplora and Mitsui O.S.K. Lines for CO2 transport from Japan and Singapore respectively.
Hydrogen Storage — ACES Delta and the US West
Chevron holds a majority interest in the Advanced Clean Energy Storage (ACES) Delta project in Delta, Utah — an electrolytic hydrogen facility designed to store lower-carbon hydrogen in underground salt dome caverns. The project was targeting operational status by the end of 2025, with output directed toward western US markets. A partnership with Iwatani targets 30 hydrogen fuelling sites across California by 2026, positioning Chevron in the nascent US hydrogen distribution chain alongside its conventional LNG infrastructure.
Chevron LNG Storage Strategy in 2026
Chevron’s 2026 organic capex guidance of $18–19 billion reflects a company sustaining major capital commitments across its LNG portfolio. The Jansz-Io compression project and Gorgon Stage 3 FID are the most immediate milestones. The 7 MTPA of contracted US Gulf Coast LNG offtake adds merchant flexibility alongside the Australian equity base.
The full scope of chevron lng storage infrastructure — from Barrow Island tank farms to Utah salt caverns — reflects a portfolio that spans liquefaction, carbon injection, and emerging hydrogen storage technologies. The strategic question for 2026 is whether the CCS systems, particularly Gorgon, can close the performance gap that has drawn sustained scrutiny. On liquefaction, the trajectory is straightforward: sustain and extend existing trains rather than sanction new greenfield capacity. For a broader view of where Chevron’s assets sit in the global LNG landscape, the 2026 LNG Storage Tsunami analysis covers the infrastructure trends shaping the sector, while the Saudi Aramco Terminals profile offers a comparable look at how another major operator structures its export infrastructure.
What is Chevron’s total LNG storage and liquefaction capacity?
Chevron operates 15.6 MTPA of liquefaction capacity at Gorgon LNG on Barrow Island, Western Australia, and 8.9 MTPA at Wheatstone LNG near Onslow — a combined Australian equity total of 24.5 MTPA. Onsite LNG storage at Gorgon comprises two tanks with a combined 360,000 m³ capacity. Chevron also holds contracted offtake of 7 MTPA from US Gulf Coast LNG export terminals.
What is the Gorgon Stage 3 expansion and when was it sanctioned?
Gorgon Stage 3 is a backfill drilling programme involving six new wells across two gas fields, designed to sustain feed gas supply to the existing three LNG trains. It was sanctioned in December 2025 at a cost of approximately $2 billion (A$3 billion). It does not add new liquefaction capacity; its purpose is to offset natural reservoir decline.
How much CO2 has the Gorgon CCS project stored underground?
As of November 2024, Chevron reported more than 10 million tonnes of CO2 injected into the Dupuy Formation beneath Barrow Island since operations began in August 2019. The project is the world’s largest integrated CCS system at an LNG facility. Independent analysis has raised questions about capture rates, which reportedly fell to around 30% in FY2023–24 against an 80% design target.
What is the Bayou Bend CCS project and who are the partners?
Bayou Bend CCS is a carbon storage project covering approximately 140,000 acres on the Texas Gulf Coast, operated by Chevron (50%) with Equinor and TotalEnergies as partners. In 2024, the project drilled stratigraphic test wells onshore and offshore and received EPA administrative completeness notice for its Class VI injection permit. It is among the first potential offshore CCS projects in the United States.
What LNG offtake capacity does Chevron hold in the United States?
Chevron has entered long-term contracts for US Gulf Coast LNG export terminal offtake totalling 7 MTPA. This merchant capacity complements the company’s equity production from Gorgon and Wheatstone in Australia, providing additional flexibility in how Chevron supplies LNG to Asian and European buyers.