Discover 58 new and rewritten Reservoir Evaluation Reports from across the globe with C&C Reservoirs’ latest content release. This update includes a wide global spread of reports, including: 18 from Asia-Pacific, 11 from Africa, 10 from Latin America, 6 from North America, 5 from the Middle East, 4 from Europe, and 4 from Russia and the Caspian.
Highlights include:
Astrakhan (Russia/Kazakhstan) – Onstream since 1986, this supergiant field has in-place of 159 TCF and 7.0 BBC with EUR of 127 TCF (80% RF) and 3.6 BBC (52% RF), trapped in a large, basement-uplift anticline. The Lower Pennsylvanian Prikama-Severokeltmen-Krasnaya Polyana reservoir consists of fractured, shallow-platform carbonates with an average porosity of 9% and matrix permeability of 2 mD. The extremely sour gas is produced by gas-expansion and aquifer drives at constrained rates with wells routinely acidized.
Culzean Field (North Sea, UK) – New to DAKS, this HPHT field produces gas from the fluvial Joanne Sandstone (Skaggerak Formation). The field has an EUR of 1.6 TCF and 37 MMBC and came onstream in 2019. A gas column of 1733 ft is trapped in a steeply-dipping, salt-modified, tilted fault-block. Owing to compaction and stretching of reservoirs potentially causing damage to wellbores during production, as seen in other HPHT fields in the area, the platform is offset from the field crest and producers are deviated to reduce the strain on casing. Reservoir compaction is measured using GPS, DTS and DAS and monitored through geomechanical models calibrated to data from radioactive markers in the wells. Cumulative production as of end-2023 was 762 BCF and 22 MMBC.
Horn Mountain (USA) – Discovered in 1999, this field began production in 2002 from the main M reservoir of the Fleming Formation, which has a STOIIP of 370 MMBO with an EUR of 121 MMBO. The 250 ft-thick reservoir consists of confined and leveed submarine fan channel sandstones with average porosity and permeability of 24% and 251 mD. The field was initially developed with six producers and two water injectors reaching an initial peak of 51,785 BOPD in 2003. An output rejuvenation of 38,200 BOPD occurred in 2017-18 when three more producers were added. Afterwards decline resumed and the field was producing 20,700 BOPD by-end 2023 when cumulative stood at 186 MMBO.
Jambur Field (Iraq) – This field began production in 1959 and has a STOIIP of 2514 MMBO and GIIP of 4.83 TCF with EURs of 1192 MMBO and 4.35 TCF. Oil with gas caps occur in three stacked reservoirs – Aptian/Albian Qamchuqa fractured carbonates and Miocene Euphrates and Jeribe formation dolomitic limestones. The Euphrates-Jeribe reservoir came onstream first followed by the Qamchuqa in 1978. In 2005 the field was producing at ~75,000 BOPD which declined to ~36,000 BOPD in 2013, with 80% of production from the Qamchuqa. With a wet oil development/treatment project nearing completion as of 2023 production is expected to increase to ~100,000 BOPD by reducing water content in the oil.
Tupi Field (Offshore Brazil) – Formerly known as Lula, the Tupi Field began production in 2010 and has a STOIIP of 22,280 MMBO with an EUR of 6684 MMBO. Most of the reserves are held in the Aptian Barra Velha Formation, which is a highly unusual reservoir and consists of shallow-water lacustrine limestones of microbial origin. The field has been developed in phases through clusters of subsea wells tied back to FPSOs. Reservoir pressure maintenance and enhance recovery have been achieved by implementing CO2-WAG miscible flood concurrent with development drilling. By the end of 2023, the field remained in the plateau stage with an average production of 829,000 BOPD from 63 wells and cumulative production of 2630 MMBO.
Yurubchen-Tokhomo (Russia) – Onstream since 2017, the field has oil in-place of 3504 MMBO, 14.6 TCF and 172 MMBC with EUR of 1323 MMBO (38% RF), 6.9 TCF (47% RF) and 102 MMBC (59% RF). The main, Proterozoic Yurubchen-Yukten reservoir consists of karstified, fractured and silicified limestones that were deposited as stromatolitic bindstone on a shelf-margin shoal. Commercial production of the light 41 °API oil relies on pervasive fractures that connect cavernous and vuggy zones across the impermeable matrix through horizontal wells. Gas recycling has supplemented the gas-cap expansion drive for pressure maintenance.