Energy — oil & gas in Algeria.

Energy — oil & gas

Algeria's proven oil reserves are roughly 13.2 billion barrels—a 27- to 30-year reserve life at current production. Gas reserves are 2.4 tcf, with Hassi R'Mel and In Salah/In Amenas being the legacy giants.

Current production (2026) is approximately 1.0 million barrels a day of oil and 8.8 bcf a day of gas. Both trajectories are declining. Hassi Messaoud, the flagship onshore field, delivers around 450,000 barrels a day with water cut rising to 35 percent. Gas production is also declining as Hassi R'Mel and other mature carbonate reservoirs water out.

Sonatrach outlined a 2025–2030 investment plan to drill nearly 1,450 oil wells, restarting programmes deferred during COVID. The stated goal is to stabilise oil output through 2027 via horizontal infill drilling and electric submersible pump upgrades—both adjacent to Saga's technology focus.

Sonatrach is the exclusive upstream operator. All exploration acreage, production licences, and development rights flow through Sonatrach-led consortia. The Ministry of Energy and Mines sets fiscal terms and production quotas. The fiscal regime is production-sharing contracts, with government take typically 50–60 percent depending on field maturity and crude quality.

Eni (Italy) operates In Amenas and In Salah—two of Algeria's largest gas fields—alongside Sonatrach and a Norwegian operator partner. In February 2023, Eni closed the acquisition of BP's 50 percent stake. In July 2025, a PSC for Zemoul El Kbar included a planned $1.35 billion investment. The Norwegian operator partner has held a continuous Algeria position for nearly three decades. BP (UK) exited operatorship in February 2023 when it sold operations to Eni, though it retains minority interests in historical JVs. CNPC (China) is building upstream presence with exploration focus.

Brownfield dominance is absolute: 90 percent or more of current production derives from fields more than twenty years old. Hassi Messaoud–Dahar province contains roughly 71 percent of Algeria's combined proved, probable, and possible reserves. These sandstone pays are mature, with water cut at 35–50 percent in main structures. Hassi R'Mel (gas) is in terminal decline. Sonatrach has explicitly identified shale and tight gas as essential to backfill the conventional decline.

The Grand Erg/Ahnet Basin holds roughly 80.1 tcf of technically recoverable shale gas according to USGS 2026 assessment. However, shale-gas development in Algeria remains pre-commercial. Drilling and completion costs run high relative to downstream gas prices. Sustained investment from Sonatrach remains uncertain.

ALNAFT (Algeria's independent regulator) is relaunching exploration licensing in early 2026 following a strategic pivot toward non-conventional resources. Frontier blocks in the Sahara onshore and offshore Mediterranean pre-Messinian areas are being shopped to majors, but subsurface risk is high.

Sonatrach's technical committees directly evaluate well-completion, stimulation, and artificial-lift technology through R&D partnerships and vendor workshops. Sonatrach is deploying artificial-lift upgrades and selective EOR pilots on Hassi Messaoud to maintain output. Eni (operator in In Salah and In Amenas) has significant deepwater and mature-field experience and is a steady buyer of third-party completion and intervention services. The Norwegian operator partner is held to high technology standards, but decisions flow by consensus with Eni and Sonatrach—a slow process.

The realistic near-term opportunities are: Hassi Messaoud horizontal infill and multilateral completion programmes (Sonatrach's well plan targets incremental barrels from brownfield assets; mechanical multilateral stimulation can address thin-pay, heterogeneous-carbonate geometry — entry requires a local Algerian partner or a proven European operator relationship); tight-gas exploration in Grand Erg/Ahnet basin if the early-2026 licensing round attracts an aggressive IOC; and consultancy on Sonatrach's 2030 brownfield-optimisation roadmap as a footing for future tech pilots.

Risks are material. Sonatrach requires in-country technical presence, local-content spending, and technology-transfer clauses in vendor contracts. Shale-gas economics remain unproven at scale.