Bretaña Norte (Peru) – New to DAKS™
Located in the Marañón Basin of Peru, Bretaña Norte has an EUR of 108 MMBO. Discovered in 1974, the field remained undeveloped until 2018 due to its remote location and a lack of infrastructure. Oil is produced from weakly-consolidated braided fluvial channel sands of the Vivian Formation, trapped in an inversion anticline. Development progressed gradually, with 1-4 producers added annually up to 2025. Early J-profile wells completed open-hole with standalone screens were ineffective at managing water influx, leadig to the adoption of open-hole horizontal wells equipped with autonomous inflow control devices and premium sand screens from 2020 onwards. These improvements increased productivity to ~18,000 BOPD in 2025, when cumulative production reached 30 MMBO from 24 wells.

Milne Point Field (USA) – New to DAKS™
Located on Alaska’s North Slope,Milne Point came onstream in 1985 and contains a STOIIP of 2.2 BBO and EUR of 1.04 BBO. The main reservoir consists of fluvio-deltaic sands of the Schrader Bluff Formation with oil trapped stratigraphically by updip depositional pinch-out on a homocline. The reservoir is highly compartmentalized, and the oil is heavy and viscous such that water injection and artificial lift were essential to production. A polymer flood pilot initiated in 2018 was later expanded fieldwide, leading to a rapid increase in production rates which reached ~41,000 BOPD by 2026.

Tizón Field (Mexico) – New to DAKS™
Situated within the Pilar-Reforma Basin along the coast of the Gulf of Mexico in shallow water, Tizón has an EUR of 908 BCF and 147 MMBC. Production began in 1991 from the Cretacico Medio reservoir and expanded in 2004 into the Jurassico Superior Kimmeridgian (JSK). A 180 m gas-condensate column is held within a compressional anticline in the JSK reservoir, which consists of fractured dolomites and tight limestones, with best productivity in oolitic grainstones. Average reservoir properties are 6% porosity and 35 mD permeability, the reservoir contains fracture swarms with the most prolific wells proximal to open fractures. The high-pressure, high-temperature reservoir produces via deviated J-profile wells drilled from two onshore pads and uses managed pressure-drilling. As of 2024, cumulative production had reached 638 BCF and 114 MMBC.

July Field (Egypt)
This field began production 1973 and has an EUR of ~700 MMBO. Developed from seven platforms, the field primarily produces from the Lower Rudeis, Matulla Formation, and the Nubia C sandstone reservoirs. Multiple oil columns up to 2400 ft are trapped in a complex of at least 46 tilted fault-blocks with steeply dipping beds up to 40° and sub-horizontal faults. Water injection which commenced in 1978 into Lower Rudeis shoreface, shelfal, and submarine channel, and fan sands,has significantly enhanced recovery. Infill and horizontal drilling targeting attic oil have further improved performance. By the end of 2014, more than 100 wells had been drilled, while cumulative production to 2000 was 615 MMBO.

Pirallahi Field (Azerbaijan) – New to DAKS™
Pirallahi, with an EUR of 211 MMBO, is one of Azerbaijan’s longest-producing oil fields, having been onstream since 1902. The field contains eight oil pools across five fault-blocks in a compressional anticline within lacustrine and deltaic reservoirs. The field straddles the coastline of the South Caspian Sea and is produced using offshore artificial islands. Water injection began in 1947, followed by in situ combustion from 1973-87, which had mixed results owing to variable reservoir quality. Water injection ceased in 1986 but was partially reinstated in 2012 following the introduction of microbial flooding in 2009. A 2013 infill drilling campaign successfully reversed production decline, increasing output to 2849 BOPD from 234 producing wells by 2019. By end-2023 the field was virtually depleted.

Prinos Field (Greece)
Located in the Prinos-Kavala Basin of the northern Aegean Sea, Prinos contains a STOIIP of 291 MMBO and an EUR of 131 MMBO. Oil is produced from deep marine sandstone reservoirs in a rollover anticline which is top-sealed by Messinian salt. Reservoir quality varies between good-quality amalgamated turbidite channel deposits and poorer quality inter-channel/lobe sandbodies. Porosities, which average 18%, diminish toward the OWC owing to dolomite cementation. The field produces by peripheral water injection with most injectors drilled updip of the OWC to avoid the cemented zone. Following a period of declining production, redevelopment commenced in 2015 using infill drilling, successfully rejuvenating the field through 2019.