We find oil and gas, move it, refine it and sell it, and we are building the low-carbon businesses that come next. Every stage runs to one standard for safety, reliability and emissions.
Upstream
We explore for and produce oil and natural gas in deepwater, on the continental shelf and onshore. In 2025 our fields delivered 842 kboe/d, 54% of it oil and 46% gas.
The portfolio pairs long-life offshore hubs, which produce for decades from a small number of high-rate wells, with short-cycle onshore plays where we can change the drilling pace within months. Every new development must be resilient at $45 Brent and meet our 2030 emissions targets before it reaches a final investment decision.
Net output is the Arkhos share of average 2025 production, with gas converted at 6,000 standard cubic feet per barrel of oil equivalent. The ten producing assets run our 14 hubs: Basalt Ridge has three central processing facilities, and Montney and Al Noor have two gas plants each. Scroll the table sideways to see every column.
| Asset | Location | Type | Arkhos interest | Net output 2025, kboe/d | Status |
|---|---|---|---|---|---|
| Americas387 kboe/d · 46% of production | |||||
| Halcyon FPSO24°52′S 42°41′W | Santos Basin, Brazil | Deepwater, pre-salt oil | 60%Operator | 104 | Producing |
| Basalt Ridge31°54′N 102°06′W | Permian Basin, USA | Onshore, unconventional oil | 88%Operator, average | 212 | Producing |
| Kauri Deepwater26°54′N 90°12′W | US Gulf, deepwater | Deepwater, subsea hub | 45%Operator | 30 | Producing |
| Montney Gas56°12′N 120°48′W | British Columbia, Canada | Onshore, liquids-rich gas | 35%Partner | 41 | Producing |
| Saramacca Block7°54′N 55°06′W | Offshore Suriname | Frontier exploration | 50%Operator | Pre-production | Appraisal |
| Europe152 kboe/d · 18% of production | |||||
| Tern Field61°06′N 1°24′E | Northern North Sea, UK | Shelf, subsea tieback | 75%Operator | 56 | Producing |
| Fenris Field65°54′N 7°36′E | Norwegian Sea | Offshore, gas-condensate | 52%Operator | 96 | Producing |
| Middle East and Africa202 kboe/d · 24% of production | |||||
| Al Noor Gas23°36′N 53°42′E | Abu Dhabi, UAE | Onshore, sour gas | 40%Partner | 66 | Producing |
| Heron Deepwater3°36′N 6°36′E | Offshore Nigeria | Deepwater, FPSO | 45%Operator | 50 | Producing |
| Sable Gas32°06′N 31°36′E | East Nile Delta, Egypt | Offshore gas | 50%Operator | 86 | Producing |
| Asia Pacific101 kboe/d · 12% of production | |||||
| Corvina Fields13°54′S 123°18′E | Browse Basin, Australia | Offshore gas for LNG | 65%Operator | 101 | Producing |
| Sulu Deep Block6°48′N 115°24′E | Offshore Sabah, Malaysia | Deepwater gas exploration | 60%Operator | Pre-production | Exploration |
| Total net production, 2025 | 842 | 54% oil · 46% gas | |||
Exploration
Our Houston imaging centre processed 1.6 petabytes of seismic data in 2025. Ocean-bottom node surveys and full-waveform inversion sharpen the picture beneath thick salt, where most of our deepwater targets sit.
We operate two frontier blocks: Saramacca offshore Suriname and Sulu Deep offshore Sabah, Malaysia. Both sit on trends where nearby wells have already proved a working petroleum system, which lowers the geological risk.
Saramacca delivered two discoveries in 2025. Appraisal wells and a drill-stem test in 2026 are measuring the size of the accumulations and how they flow, ahead of a development concept decision.
Midstream and LNG
Pipelines, tankers, gas plants and two LNG export plants connect our resources in South America, North America and Australia to buyers in Asia and Europe.
Our LNG portfolio reaches 14.5 mtpa when the second Corvina train starts in the first quarter of 2027. The third quarter of 2026 brought record LNG volumes, with Corvina running above nameplate capacity. We operate 6,800 km of oil and gas pipelines, and chartered tankers carry Halcyon crude from Brazil to our Bayshore refinery in Texas.
The LNG value chain
Subsea wells in the Corvina Fields produce gas and condensate. Condensate is separated offshore and sold as a light crude.
Gas · 380 m water depth
An 880 km trunkline on the seabed carries dry gas to the Pilbara coast at pressures up to 150 bar.
Gas · 880 km trunkline
The plant strips out CO₂, water and mercury, then refrigerant cycles cool the gas until it condenses to 1/600 of its volume.
Cooled to −162 °C
Membrane carriers of 174,000 m³ load about 75,000 tonnes each. The voyage from the Pilbara to Tokyo Bay takes around nine days.
Liquid · 0.1% boil-off a day
At the receiving terminal, seawater vaporisers warm the liquid back into gas and send it into the transmission grid.
Gas · sent out at 70 bar
Power stations, factories and city gas networks in Japan, Korea and Singapore buy the gas, mostly under long-term contracts.
Gas · power, industry, homes
Train bars share one scale, from 0 to 7.6 million tonnes a year, so the two plants can be compared directly.
Pilbara, Western Australia20°36′S 116°48′E
Train 2 commissioningGas from the Corvina Fields in the Browse Basin arrives through an 880 km trunkline. Train 2, powered partly by on-site solar, lifts capacity to 7.6 mtpa from the first quarter of 2027.
Louisiana, USA29°48′N 93°06′W
OperatingThree trains on the Louisiana Gulf Coast take pipeline gas from the Haynesville and Permian basins. Most cargoes sail to northwest Europe, including regular deliveries into Rotterdam.
Refining and marketing
Bayshore, Port Arden and Jurong turn 960 kbbl/d of crude into fuels, lubricants and petrochemical feedstocks for the Americas, Europe and Asia.
High conversion capacity lets us run heavier, lower-cost crudes and turn more of each barrel into diesel, jet fuel and gasoline. Our trading teams move crude and products between the three sites and our own retail network, so each barrel goes where it earns the most.
Our refineries
Bars show each refinery's share of total Arkhos crude distillation capacity.
Corpus Christi, Texas27°49′N 97°24′W
420kbbl/d
Our largest and most complex site runs heavy sour crude alongside Permian light oil, and exports products across the Americas from its own deepwater dock.
Rotterdam, Netherlands51°57′N 4°06′E
310kbbl/d
Supplies northwest Europe by pipeline, barge and ship. A 20 kbbl/d renewable diesel unit has run since 2021, and from 2028 the Baltic Wind JV will supply the site's power.
Jurong Island, Singapore1°16′N 103°41′E
230kbbl/d
Our Asian hub combines refining with 4.2 million barrels of tank storage, supplying jet fuel, low-sulphur marine fuel and aromatics to markets across the region.
Crude is heated to about 360 °C and fed near the bottom of the column. Vapour rises and cools, and each fraction condenses on the trays at its own boiling range. Hover over, focus or tap a cut to highlight it.
Typical yield from a medium sour crude, % of barrel by volume
Propane and butane leave the top of the column as vapour. At Bayshore, butanes feed the alkylation unit to make high-octane gasoline blendstock.
Light naphtha is isomerised and heavy naphtha reformed to raise octane for gasoline. At Jurong, heavy naphtha also feeds the paraxylene plant.
Hydrotreated to remove sulphur and tested for freezing point, this cut becomes Jet A-1 for airlines and kerosene for heating.
Hydrotreating brings sulphur below 10 ppm for road diesel. At Port Arden it is blended with renewable diesel made from waste fats and oils.
Too heavy to sell as it is, gasoil goes to the hydrocracker or the fluid catalytic cracker, which break it into diesel, jet and gasoline.
The bottom of the barrel goes to vacuum distillation and the delayed coker. Bayshore's coker is the main reason for its Nelson complexity of 12.1.
Retail and marketing
Our forecourts in the US Gulf Coast, the Benelux countries, Singapore and Malaysia sell fuel from Bayshore, Port Arden and Jurong. More of them now offer EV fast charging and renewable diesel blends, and commercial fleets buy fuel through Arkhos fuel cards.
2,300sites
Branded retail sites in four markets
Low-carbon solutions
Storing CO₂ uses our reservoir knowledge. Offshore wind uses our marine engineering. Renewable diesel uses our refineries. In 2025 we invested $1.6 billion in these businesses, 11% of our capital spending.
Read our transition plan
CO₂ captured at industrial sites in Scotland and northern England will be stored 2,600 m below the seabed in a depleted gas reservoir. We took the final investment decision on 14 October 2026.
Phase one 5 Mtpa CO₂Injection 2027Partners 3
A 400 MW solar plant paired with a 200 MWh battery supplies renewable power to Arkhos operations, replacing electricity that gas turbines would otherwise generate.
Solar 400 MWBattery 200 MWhOfftake Arkhos
We hold 30% of a 1.1 GW offshore wind farm now in construction. Its power is contracted to run our Port Arden refinery from 2028.
Capacity 1.1 GWTurbines 73Stake 30%
Since 2021 a dedicated unit has turned used cooking oil and animal fats into renewable diesel, with up to 80% lower lifecycle emissions than the fossil fuel it replaces.
Capacity 20 kbbl/dSince 2021Feed Waste oils
$1.6 billion in 2025, rising to 18% of the $38 billion 2026–2030 capital program.
Skerry Point phase one covers half of our 2035 storage target.
A new field can take ten years to go from a seismic anomaly to first oil, then produce for decades. These are the four stages, and the decisions that move a barrel from one to the next.
Stage 1 of 4 · Typically 3 to 7 years
Geoscientists combine seismic surveys, well data and basin models to rank prospects by risked volume and cost of supply. When an exploration well finds hydrocarbons, appraisal wells and flow tests measure how large the accumulation is and how it will produce.
Stage 2 of 4 · Typically 3 to 5 years
Engineers select a development concept and complete front-end engineering design (FEED). We take the final investment decision (FID) only when the project is resilient at $45 Brent and fits our emissions targets. Construction follows: wells, subsea systems, platforms or FPSOs, and the pipelines that connect them.
Stage 3 of 4 · Typically 20 to 40 years
Production teams manage reservoirs, wells and process plants to hold output steady and emissions low. Our integrated operations centre in Houston watches 31 assets around the clock, and digital twins flag equipment problems up to six weeks before they force a shutdown.
Stage 4 of 4 · Days to weeks per cargo
Oil travels by pipeline and tanker to our refineries or to other buyers. Gas goes into domestic grids or to our LNG plants for export. Trading teams in Houston and Singapore schedule cargoes and blend products to match what each market needs.
Our 2025 safety record is the best in our history. We measure it the same way at every site, for employees and contractors alike.
0.19TRIR
Total recordable injuries per 200,000 hours worked, 2025
Down from 0.41 in 2019
0.05LTIF
Lost-time injuries per million hours worked, 2025
Down from 0.11 in 2019
0fatalities
Across all Arkhos-operated sites in 2025
Employees and contractors
3.1million hours
Worked offshore at Halcyon without a lost-time incident
Since first oil in 2024
Eight rules cover the activities behind most serious incidents in our industry. They apply to every employee and contractor on every Arkhos site, and anyone can stop a job they believe is unsafe without fear of blame.
If a job cannot be done safely, we do not do it. Stopping work is never the wrong call.
Recordable injury rate, 2019–2025
−54%
From Corvina LNG Train 2 to Skerry Point CCS, follow what we are building, where, and when each project starts up. Talk to us about partnering, supplying or investing.