Explore 40 new and updated Reservoir Evaluation Reports from across the globe. Discover a wide spread of global oil and gas analogues, including: 12 from North America, 10 from Asia-Pacific, 5 from Europe, 4 from the Middle East, 4 from Latin America, 3 from Russia and the Caspian, and 2 from Africa.
Highlights include:
Tengiz Field (Kazakhstan) – A supergiant oil field with a STOIIP of 25 BBO and EUR of 10.2 BBO. Here, a highly-overpressured 1600 m oil column is trapped in a Devonian-Carboniferous carbonate buildup. Reservoir quality is locally reduced by pore-occluding bitumen, but the rim/upper slope facies are fractured and karstified. Miscible sour-gas injection was introduced in 2008, increasing production and improving sweep efficiency through choking-back or shutting-in high-GOR wells along with other conformance improvement methods. Production soared to ~850,000 BOPD in 2025 as new sour-gas injection capacity came online.
Natuna D-Alpha Field (Indonesia) – A huge field comprising 158 TCF CO2 and 62 TCF of hydrocarbon gas. The gas is trapped in a domal reef mound where reservoir quality is influenced by CO2 corrosion of carbonate grains and meteoric dissolution creating cavernous porosity. Currently the field has remained undeveloped owing to its remote setting, lack of long-term sales contract and difficulties disposing of the highly-corrosive, non-hydrocarbon gases containing 0.5% H2S and 0.5% N2. CO2 injection into a neighbouring aquifer is under consideration along with the possibility of recovering and monetizing the CO2.
Chester 16 Field (USA) – New to DAKS – This small oil field (6.9 MMBO STOIIP) is located in the northern Niagaran Pinnacle Reef Trend of the Michigan Basin. Here, oil is trapped in the reef core facies and A-1 Carbonates which drape over the reef. Primary recovery yielded very low results (only 2.16 MMBO by 1984) and a waterflood project in 1984-90 proved ineffective. The field was shut-in from 1990-2017, however a CO2 miscible flood project commenced in 2017 rejuvenated the field with rates of 289 BOPD achieved in 2025.
Surmont Project (Canada) – An in situ oil sands project located in the Athabasca Oil Sands area of onshore Alberta which began as a pilot in 1997 and started full production in 2007. The sands contain 21 BB of bitumen in-place trapped stratigraphically in fluvial-estuarine sandstones and extracted in situ using steam-assisted gravity drainage. The unconsolidated sandstones have excellent lateral connectivity. Extraction uses pad-drilled horizontal producer-injector well pairs allowing for continuous injection of steam. 4-D time-lapse seismic is used to track steam-chamber evolution and improve well recoveries.
Buffalo Field (Timor-Leste) – New to DAKS – This field had a STOIIP of 64 MMBO trapped in a horst-block within deltaic sandstones of the Elang Formation and was produced by strong aquifer drive. Production from 1999 ramped up to ~45,000 BOPD and then declined rapidly owing to premature water breakthrough along high-permeability streaks. Undrained attic oil was identified on reprocessed seismic and was targeted by two infill wells in 2002 which briefly reversed the decline. The field was shut-in from 2004.
Sahil Field (UAE) – New to DAKS – Located in the Rub’ Al Khali Basin, this field has a STOIIP of 2500 MMBO trapped mostly in the Thamama Zone B carbonates, deposited as cyclic successions of transgressive limestones. Production began under weak aquifer drive from 1975, with rapid pressure decline experienced from 1980. The field was shut-in until 1987 when production resumed from 22 wells. Peripheral water injection introduced from 1994 encountered difficulties with water flowing preferentially through high-permeability layers. Crestal gas injection was trialled in 1998 and restored the reservoir to initial pressure. WAG injection was introduced in 2013.