Kosmos Energy (KOS): GTA Spare Gas Capacity Gets 25-Year Buyers

On its FY2026 second-quarter earnings call on August 3, 2026, Kosmos Energy (KOS) said Mauritania and Senegal have turned their intent to use Greater Tortue Ahmeyim (GTA) gas into signed long-term contracts, and that the gas involved comes from spare capacity on the field's existing offshore facilities rather than from anything the partnership has to build [1].

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Why GTA's spare processing capacity had no buyer

Gas from GTA has to pass through two offshore steps before it can be sold. The field straddles the maritime border between Mauritania and Senegal, with BP as operator, Kosmos holding an interest, and both countries' national oil companies among the partners. Gas comes up from the seabed into a floating production, storage and offloading vessel (FPSO) that cleans and stores it, and part of that stream goes to a floating liquefied natural gas vessel (FLNG) alongside, which chills the gas into a liquid so it can be loaded onto tankers. Liquefaction is the most expensive step in that chain and the one with a hard capacity ceiling.

The FPSO can process more gas than the FLNG vessel takes, and until now that surplus had nowhere to go. Turning it into export volume would have required paying for additional liquefaction capacity, which is the expensive part. Management had already described the surplus in November 2025: the existing facilities and well stock could supply roughly another 200 million standard cubic feet a day with zero investment [2]. At that point it was a pricing concept with no counterparty. What changed this quarter sits on the demand side — both host states are piping the gas to power stations onshore, so the incremental volume reaches the market without passing through the liquefaction step at all.

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Long-term contracts, no incremental cost, and no price discount

Both host states have now put buyers under contract. Mauritania signed a 25-year agreement covering a 230 MW gas-fired power plant, with a Saudi power company responsible for development, financing, construction and operation and the fuel expected to come from GTA [1]. An independent report corroborates that plant: the agreements were signed on July 1, 2026, for a 230 MW combined-cycle unit fed by GTA gas [3]. In Senegal, land has been cleared for the onshore section of the pipeline connecting the field to the 250 MW Gandon power station, and the pipe is due to arrive after taking a longer route to avoid the Middle East [1].

Management also gave explicit terms on both the cost and the price of that volume. Above the throughput the FLNG vessel currently takes, the FPSO can add at least another 50% for domestic gas, and the company says that increment arrives with no additional cost, which is why it expects a marked effect on unit costs [1]. On price, domestic gas settles at the FOB equivalent less the LNG processing fee, on the reasoning that these molecules are delivered as pipeline gas rather than liquefied, and management's own summary is that the additional volume comes with the same economics as the LNG export [1]. Taken together, the two statements say the domestic route is not a discount channel. Both power plants are still under construction, and the volumes have yet to appear on anyone's books.

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What changes once the liquefaction step is bypassed

On the export route, both the toll and the capacity ceiling sit at liquefaction, and piping gas straight to shore skips that step entirely. Absolute operating cost at the field is broadly fixed, so raising throughput over that same cost base pushes unit operating cost down; revenue and per-unit margin rise at the same time with no matching capital expenditure line, which means cash flow from the project should grow faster than volume does.

One boundary belongs alongside that. The timing depends on onshore construction of the power stations and the pipeline, and the pipeline has already slipped once because of the rerouting. Two things are worth tracking: whether GTA's unit operating cost falls by roughly half in 2026 as the company targets and declines further in 2027, and whether the first domestic volumes show up as the plants and pipeline are commissioned [1]. The company places the full effect in 2028 to 2029.

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Companies exposed to the same mechanism

• BP p.l.c. (BP): The operator of GTA and the largest interest holder, so this incremental volume, which requires no additional investment, would accrue to it in proportion to that interest; on its February 10, 2026 earnings call, however, BP named GTA only as one of the major projects it had started up and made no reference to domestic gas anywhere in the call [4].
• Golar LNG (GLNG): The operator of the FLNG vessel at GTA, paid a fixed processing fee on liquefied volume. The domestic gas comes from FPSO capacity above what that vessel takes and travels ashore by pipe, so it never enters the liquefaction step and this expansion does not change the volume Golar is paid on; its own call describes the Mauritania and Senegal position as an LNG export business [5].

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Sources

[1] Drillr · Kosmos Energy (KOS) · 2026-08-03 · FY2026 Q2 earnings call

As we said in the past, you can add at least another 50% to the FPSO, the current throughput that's being supplied to the FLNG vessel for domestic gas. So that additional volume is going to have a significant impact on the unit cost because it comes with no additional cost.

[2] Drillr · Kosmos Energy (KOS) · 2025-11-03 · FY2025 Q3 earnings call

[3] Financial Afrik · Mauritania: First 230 MW Gas Power Plant entrusted to ACWA Power · 2026-07-04 · press report · https://www.financialafrik.com/en/2026/07/04/mauritania-first-230-mw-gas-power-plant-entrusted-to-acwa-power/

[4] Drillr · BP p.l.c. (BP) · 2026-02-10 · FY2025 Q4 earnings call

[5] Drillr · Golar LNG (GLNG) · 2026-05-20 · FY2026 Q1 earnings call

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