Explore 69 new and updated Reservoir Evaluation Reports from across the globe includes a wide spread of global oil and gas analogues, including: 15 from Asia-Pacific, 14 from North America, 11 from Europe, 10 from the Middle East, 8 from Latin America, 6 from Russia and the Caspian, and 5 from Africa.

Highlights include:

El Morgan Field (Eygpt) – Lying in the Gulf of Suez, this field contains a STOIIP of 3.2 BBO with an EUR of 1.78 BBO, giving a recovery factor of 56%. ~90% of the resources are held in the Miocene Kareem Formation which has a 950 ft oil column trapped in a tilted fault-block structure with two culminations. The Kareem Formation consists of turbidite fan lobes >1000 ft thick in proximal fan areas where N:G ratio reaches 0.7-1.0. Production has focussed on the larger South Morgan culmination which produces under water injection. As of 2024 the field was producing at 15,476 BOPD with cumulative of 1.74 BBO. A combined polymer injection and low-salinity waterflood project is planned for South Morgan and may achieve incremental recovery of 10%.

Gullfaks Field (Norway) – Located in the Norwegian Northern North Sea, this field has a STOIIP of 4.9 BBO, EUR of 2.46 BBO, giving a recovery factor of 50%. It produces from the Middle Jurassic Brent deltaic sandstones (73% of STOIIP) with minor production from the Lower Jurassic Cook, Triassic-Lower Jurassic Statfjord and Triassic Lunde formations. Multiple oil pools are trapped in >30 tilted fault-blocks. Oil production peaked at 528,953 BOPD in 1994 but declined rapidly thereafter. From start-up, water injection has been the primary driver of the high recovery factor. Infill wells including horizontals were located using 4-D seismic. Water-alternating-gas injection and individual well cyclic gas injection, sand control, selective perforation and zonal isolation all helped to stabilize production and by mid-2025 the field had produced 2.39 BBO.

Guntong Field (Malaysia) – Located offshore Peninsular Malaysia, the Gunton Field came onstream in 1985. It has a STOIIP of 1258 MMBO and EUR of 819 MMBO, for an anomalously high RF of 65%. ~70 hydrocarbon pools with 50-230 m-thick columns are trapped in a faulted, transpressional anticline below 1280 m TVDSS. The Lower-Middle Miocene Groups J and I reservoirs in the Tapis and Bekok formations consist of fluvial/tide-dominated deltaic sandstones, with an average porosity of 20% and permeability of 200 mD. The volatile oil is produced by gas-cap expansion and solution-gas drives using highly deviated, dual completion wells, aided by early water and crestal gas injection. Production plateaued at ~104,000 BOPD in 1995-99, supported by infill drilling, well workover and conformance improvement. By end-2024, cumulative production reached 778 MMBO.

Ku Field (Mexico) – Lying in the Campeche Shelf, this field contains a STOIIP of 5884 MMBO and an EUR of 3089 MMBO, for a 52.5% recovery factor. An 864 m oil column is trapped within an arcuate, four-way dipping, NW-trending fold-thrust structure. The reservoir is a 370 m-thick interval of Upper Cretaceous dolomitic breccias of the Cantarell Formation. It has a N:G ratio of 0.85 and high vertical transmissibility imparted by fracturing. Porosities range from 5-25% and permeabilities are 800-9000 mD. Production is driven by the aquifer, solution-gas, gravity drainage, and secondary gas-cap expansion. The field reached peak production of 363,994 BOPD from 28 wells in 2008. By end-2023, cumulative production had reached 2923.8 MMBO and in 2024 the field was producing 13,151 BOPD despite the onset of nitrogen gas injection from 2009.

Sacha Field (Ecuador) – Located in the Oriente Basin, this field has a STOIIP of 5134 MMBO and an EUR of 1181 MMBO, giving a 23% recovery factor. Oil columns of 190-290 ft, in five pools, are trapped in a low-relief overthrust anticline with tilted OWCs related to meteoric recharge of the aquifers. Hydrocarbons occur in the Aptian-Albian Hollín, Albian-Campanian Napo and Maastrichtian-Paleocene Tena formations. The clastic reservoirs were deposited in tide-dominated estuaries, low-sinuosity rivers and shoreface shelves. Average porosity ranges from 12-18% while permeabilities are from 130-350 mD. The field has been developed on a 70-ac spacing with a total of 476 wells. Production peaked in 1973 at 88,345 BOPD with a water-cut of 17%. Recovery has been aided by acidization, hydraulic fracturing and artificial lift. By end-2024, the field had produced 1118 MMBO and was producing ~75,000 BOPD.

Shah Deniz (Azerbaijan) – Located offshore in the South Caspian Basin, the Shah Deniz Field came onstream in 2006. It has in-place resources of 42.4 TCF and 2 BBC and EUR of 25.4 TCF and 1.1 BCF, for gas and condensate RFs of 60% and 56%. Five stacked gas-condensate pools with column heights of up to 1500 m are trapped from 4400 m TVDSS in a compressional anticline, supplemented by a hydrodynamic component. The Pliocene Fasila and Balakhany suites of the Productive Series consists of lacustrine river-delta sandstones, with an average porosity of 12% and permeability of 35 mD. Production soared before leveling off at ~86,000 BCPD in 2021 and ~2700 MMCF/day in 2024, with a cumulative 8.9 TCF and 386 MMBC produced by mid-2025.

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