EnQuest Beats Production Guidance, Boosts Dividend as Strategy Delivers Growth

EnQuest’s 2025 scorecard: guidance beat, dividend up, and South East Asia firing

EnQuest has wrapped up 2025 with production ahead of guidance, costs under control and a bigger dividend on the way. The company also reset its balance sheet with a fresh lending facility and a smart deal at Magnus that removes a chunky liability and frees up future cash flow. The strategy to diversify into South East Asia is already paying off, with Malaysian gas and the new Vietnam business adding reliable volumes.

Operational delivery that beat expectations

Reported production averaged 42,945 Boepd in 2025 (barrels of oil equivalent per day), up 5.4% year-on-year. On a pro forma basis including Vietnam for the full year, output came in at 45,606 Boepd – above the top end of the 40,000 to 45,000 Boepd guidance range. Asset uptime was around 90%, which is top-tier performance for late-life North Sea assets.

• Magnus delivered 15,335 Boepd, up 8%, despite a five-week third-party outage. Production efficiency excluding that outage was 93%.
• Kraken’s FPSO ran at 95% efficiency and averaged 10,948 Boepd. Enhanced oil recovery and a Bressay gas import project are being matured to cut emissions and support future output.
• Malaysia’s PM8/Seligi grew 12.9% to 9,201 Boepd. The Seligi 1b gas project started up nine months early – full production of c.70 mmscf/d (about 6.0 Kboepd net) began in January 2026, and March gross rates have regularly reached c.100 mmscf/d to meet strong Peninsular Malaysia demand.
• Vietnam was integrated smoothly post the July acquisition, with three well workovers lifting net Q4 production to c.5.5 Kboed.

The diversification push kept momentum: EnQuest picked up operatorship in Brunei (Block C PSC, aiming for c.15 Kboed of gas by 2029) and exploration PSCs in Indonesia (Gaea and Gaea II, with bp Tangguh a 40% partner and prospectivity of more than 100 Tcf across multiple prospects).

Cash discipline in a weaker oil price year

Brent averaged $68.2/bbl in 2025, down 15.3%. EnQuest held the line on unit costs while hedging cushioned the blow. Adjusted EBITDA landed at $503.8 million, with average unit operating costs trimmed to $25.1/Boe (from $25.6/Boe). Reported profit after tax was $1.6 million, heavily distorted by the non-cash impact of the UK Energy Profits Levy (EPL) extension; excluding that, profit after tax would have been $125.5 million.

Key numbers (FY 2025)
Production	42,945 Boepd
Revenue and other income	$1,118.3 million
Adjusted EBITDA	$503.8 million
Average unit operating cost	$25.1/Boe
Adjusted free cash flow	$8.7 million
EnQuest net debt	$433.9 million
Cash and undrawn facilities	$678.6 million
Proposed final dividend	0.8 pence per share (c.$20 million)

Balance sheet reset: fresh RBL and Magnus deal

EnQuest refinanced its Reserve Based Lending (RBL) facility in Q4: a six-year, $800 million package split between a $400 million loan tranche and a $400 million letter of credit tranche, both with a potential $400 million accordion. The RBL was fully undrawn at year end, giving the group $678.6 million of cash and available facilities.

In February 2026, EnQuest paid $60.0 million to settle the Magnus contingent consideration with bp. This removes a discounted $432.9 million balance sheet liability and unlocks c.$777 million of additional undiscounted forward Magnus cash flow for EnQuest. Management cites a net $238.9 million gain from the settlement. Strategically, this simplifies decision-making at a core asset and enhances credit capacity under the RBL.

2026 outlook: steady guidance, strong start, firm hedging

The company guided 2026 production at 41,000 to 45,000 Boepd. The year started slowly because of that third-party Magnus outage, with 32,429 Boepd to end-February and c.650 kbbls deferred. Since 22 February, production has rebounded; in March, the Group has consistently exceeded 50,000 Boepd.

• Opex c.$450 million; capital investment c.$160 million; decommissioning spend c.$60 million.
• A six-well Magnus infill campaign starts in Q2 2026; further well interventions planned across the portfolio.
• From 1 April 2026, 5.1 MMbbls are hedged over the next 12 months at an average floor of $71.3/bbl, and a further 3.5 MMbbls at $64.4/bbl for the subsequent 12 months, predominantly via swaps.

Reserves, resources and the longer game

2P reserves stood at 162.5 MMboe at year-end (78% 1P – proven), reflecting production and routine revisions. Contingent resources (2C) totalled 452.1 MMboe, offering multiple routes to future conversion through drilling, workovers and near-field developments in both the UK and South East Asia.

Dividend and returns: small but growing

After paying a maiden c.$15 million dividend in June 2025, the Board proposes a 2025 final dividend of 0.8 pence per share (c.$20 million), payable in June 2026 following AGM approval. The signal is clear: management is intent on sustainable, growing returns, underpinned by operational delivery and a more robust balance sheet.

What’s great, what’s not

Positives I like

• Operational outperformance: production above guidance with c.90% uptime across the fleet; Kraken at 95% is best-in-class.
• Seligi 1b delivered nine months early and already running above contracted volumes – high-quality, lower-carbon gas barrels.
• Magnus settlement removes uncertainty and materially improves future cash capture from a core asset.
• RBL refinance provides long-dated, flexible liquidity with the loan tranche undrawn at year end.
• Costs contained despite a weaker USD; unit opex edged down to $25.1/Boe.

Watch-outs

• Commodity leverage: 2025 EBITDA fell with Brent at $68.2/bbl; EPS was dampened by UK EPL impacts.
• Reserves ticked down to 162.5 MMboe; drilling and project delivery will be key to offset declines.
• North Sea fiscal risk remains: while the Oil and Gas Pricing Mechanism is encouraging, timing and details matter for investment appetite.
• Bond maturities cluster in 2027; management intends to refinance opportunistically, but market conditions will dictate pricing.

Strategy check: diversified growth with a lower-carbon tilt

EnQuest’s operating sweet spot is extracting value from mature, underinvested assets, and the results show that playbook still works. The pivot to gas-weighted South East Asia strengthens cash flow resilience and lowers intensity. At the same time, the company is progressing decarbonisation at the Sullom Voe Terminal, with projects expected to cut terminal emissions by around 90%, and it continues to lead in North Sea decommissioning.

My take

This is a solid year in a softer price environment: production beat, unit costs nudged lower, liquidity strengthened and a messy Magnus overhang removed. The Seligi gas ramp and Vietnam integration add a helpful second engine outside the UK. 2026 guidance looks sensible, and the March run-rate above 50 Kboepd gives confidence. The dividend is still modest, but rising – and that matters.

Net debt of $433.9 million against $503.8 million of adjusted EBITDA (0.9x) is manageable, especially with an undrawn RBL and increased hedging coverage from April. Keep an eye on delivery of the Magnus six-well programme, the pace of South East Asia growth and any progress on a “material UK North Sea transaction” flagged by management. Continued successful execution could be genuinely transformative for cash flow and returns.

Glossary

• Boepd – barrels of oil equivalent per day.
• 2P reserves – proven plus probable reserves that are commercially recoverable.
• 2C resources – contingent resources that are potentially recoverable but not yet commercial.
• RBL – Reserve Based Lending facility secured against producing reserves.
• EPL – UK Energy Profits Levy, an additional tax on UK upstream profits.