The latest DAKS Content Release from C&C Reservoirs includes 70 new and updated Reservoir Evaluation Reports from across the globe includes a wide spread of global oil and gas analogues, including: 19 from North America, 11 from Europe, 10 from Asia-Pacific, 10 from Africa, 8 from the Middle East, 7 from Russia and the Caspian, and 5 from Latin America.

Highlights include:

Bhagyam Field (India) – Onstream since 2012, the field has a STOIIP of 500 MMBO and an EUR of 125 MMBO (25% RF). With a 208 m oil column trapped in a tilted fault-block below 440 m TVDML, the Upper Paleocene Fatehgarh reservoir consists of fluvial-channel sandstones with an average porosity of 25% and permeability of 5000 mD. Owing to its weak natural drive, the waxy oil is produced by hot waterflooding from startup, supported by PCPs. With a production peak well below expected, achieving only 29,000 BOPD in 2014 due to rapid water-cut increase. Polymer flood has been implemented since 2020 to mitigate water production and improve recovery.

Laslau Mare Field (Romania) – Onstream since 1975, the field has a GIIP of 1438 BCF and recovery factor of 91%. The Badenian Sarmatian reservoir contains multiple stacked turbidite sandstone pools occurring in a salt diapir-related anticline. Here, dry gas was produced from a poor-quality reservoir with 8% porosity and a permeability of 0.1-15 mD. Owing to salt precipitation and casing leaks, production rates have fluctuated. However, multiple techniques have been utilized to rejuvenate the field since, including infill drilling, sidetracking, recompletions, stimulation, and deepening of wells to target tight gas zones. As a result, production increased by 40% to 23 MMCF/day in 2005. In 2016 hydraulic fracturing was piloted and by end-2016 cumulative production stood at 1088 BCF.

Vatyogan Field (Russia) – Onstream since 1984, the field has a STOIIP of 6691 MMBO and an EUR of 2051 MMBO (31% RF), trapped in multiple, stacked reservoirs within a buried paleorelief compaction anticline. A 46 m oil column is contained in the main Upper Jurassic JuV1 reservoir (740 MMBO STOIIP with 33% RF), which consists of barrier-bar sandstones with an average porosity of 17% and permeability of 48 mD. The light oil is produced by solution-gas drive, supported by pumps and waterflooding. Recovery has been improved by step-out drilling from crestal areas and high water-cut well shut-ins.

Velebit Field (Serbia) – The field contains a STOIIP of 200 MMBL and EUR of 134 MMBO. The main Upper Miocene Lower Pontian Pt1-2 reservoir is very shallow and contains oil and gas trapped in a compressional anticline. The reservoir consists of weakly consolidated lacustrine delta-plain clastics with an average porosity of 30%, and permeabilities up to 6 D. Field development was hampered by a lack of infrastructure during the 1970s-80s, but production was boosted by increasing the operating bottom-hole pressure and replacing rod pumps with ESPs; leading to production rates of 6721 BOPD in 2012. A rapid drop in reservoir pressure followed, exacerbated by production of the gas cap. Intensive infill drilling was employed from 2013 and there are plans for ASP Flood EOR from 2028.

West Sak Field (USA) – Onstream since 1991, the field has a STOIIP of 16,000 MMBO. Located in the North Slope Basin, oil is trapped in a gently dipping homocline by up-dip lateral depositional pinch-out in unconsolidated sandstones of the Maastrichtian Upper Schrader Bluff Formation. Average porosity and permeability are 29% and 255 mD, respectively. The 16 °API oil has weak natural drive so waterflooding was required from start-up. The field is in the buildup phase, producing at ~94,700 BOPD using multilateral horizontal wells, artificial lift, and water-alternating-gas injection. A polymer injection EOR pilot was conducted 2018-22. Solids production from the unconsolidated sand units presents a major reservoir management issue. By end-2024, cumulative production had reached 468 MMBO.

Wellington Field (USA) – Onstream since 1929, the field has a STOIIP of 204 MMBO and an EUR of 22 MMBO (11% RF). The majority of production has come from the Upper Mississippian reservoir, which is part of a subcrop play, with oil trapped in a structural high preserved below a Pennsylvanian Unconformity. The 54 ft-thick reservoir comprises sucrosic dolomites interbedded with chert-rich bands with average porosity and permeability are 24% and 47 mD. The 30 °API oil was produced under aquifer drive until 1953, when water injection commenced. Infill drilling has had the greatest impact in supporting output rates, which led to three production peaks. In 2016-17, CO2 injection was piloted and by end-2024 cumulative production reached 21 MMBO.

Accounting for more than 70% of global conventional recoverable reserves, our Reservoir Evaluation Reports provide in-depth analysis and systematic documentation on fields and reservoirs around the world.

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