Discover 65 new and updated Reservoir Evaluation Reports from across the globe in C&C Reservoirs’ latest content release. This update includes a wide spread of global oil and gas analogues, including: 19 from Asia-Pacific, 13 from the Middle East, 11 from North America, 9 from Africa, 6 from Latin America, 5 from Russia and the Caspian, and 2 from Europe.
Highlights include:
Alpine Field (Alaska, USA) – Situated in the North Slope Basin, this field has a STOIIP of 1225 MMBO and an EUR of 691 MMBO for a recovery factor of 56.4%. Production began in 2000 mainly from the Upper Jurassic Alpine Sandstone. Since the reservoir is relatively thin, with low permeability and good vertical continuity it has been developed exclusively with horizontal wells. Owing to the weak aquifer drive, water-alternating-gas (WAG) miscible injection began within a month of start-up. Production rose steeply to plateau at 121,746 BOPD during 2005-07. As of 2024 the field was producing 25,236 BOPD when cumulative stood at 632 MMBO.
Greater Rumaila (Southern Iraq) – This is one of the world’s largest fields with a 125 BBO and 17 TCF in place held in 10 reservoirs of Jurassic to Miocene age. Most production comes from Cretaceous Zubair sandstones and Mishrif limestones. Hydrocarbons are trapped in an elongate transpressional anticline with culminations at South Rumaila, North Rumaila and West Qurna. South Rumaila came onstream in 1954. Production was sporadic until the early 2000s when there was a massive programme of infill drilling, horizontal wells, workovers and zonal injection with fieldwide water injection from 2013 lifting rates in the Mishrif reservoir to 491,000 BOPD in 2020 from 237 producers. As of 2017 production rates for the Zubair sands were 988,000 BOPD in North and South Rumaila.
Kashagan (Kazakhstan) – Onstream since 2013, the Kashagan has a STOIIP of 36.6 BBO and an EUR of 13 BBO (35.5% RF), with a 925 m oil column trapped in a subsalt organic buildup, covering a large area of ~170,000 ac. The Carboniferous Unit 1 reservoir consists of platform interior and margin limestones that were karstified and fractured with average porosity of 5.3% and permeability of 3 mD. The light-volatile oil is produced by solution-gas drive, while oil rates depend largely on the success of reinjecting the produced raw, sour and toxic solution gas at high pressures.
Lancaster Field (UK) – Located in the Faeroe-Shetland Basin, and discovered in 2009, this field did not come onstream until 2019 owing to the complex nature of the fractured basement reservoir. A horizontal well drilled in 2014 tested up to 9800 BOPD suggesting a well-connected fracture network. Pre-production field best case STOIIP was 2326 MMBO with the majority held within the basement, however rapid water breakthrough and pressure decline occurred only five months after production began. Production and pressure data analysis led to a catastrophic 94% downgrade in volumes with most of the production coming from the Victory and Rona sandstones which onlap the basement high. Production is expected to end this year.
Velásquez Field (Colombia) – Located in the Middle Magdalena Basin, this field has a STOIIP of 647 MMBO and an EUR of 269 MMBO, for a 41.5% recovery factor. Several hydrocarbon pools are trapped in a homocline within Oligocene sandstones. The field has been developed with >300 vertical wells on a spacing of 40 ac. Production began in 1947. An intensive drilling campaign during 1955-58 led to a plateau at an average of 27,153 BOPD in 1959-60. The implementation of waterflooding in 2006 modestly rejuvenated output. By end-2023 the field was producing 2961 BOPD and cumulative reached 192 MMBO.
Zhetybay Field (Kazakhstan) – Onstream since 1965, the field has a STOIIP of 2578 MMBO and an EUR of 957 MMBO (37% RF), trapped in a low-relief, doubly plunging anticline. The 800 m-thick Middle Jurassic Units I-XIII reservoir comprises braided-fluvial to deltaic sandstones with an average porosity of 18% and permeability of 70 mD. The light oil is produced by aquifer, gas-cap expansion, and solution-gas drive, supported by rod pumps and cold/hot water injection. Hydraulic fracturing, renewed development drilling and horizontal wells have improved oil production and waterflood efficiency.