IHS Markit announced that Talos Energy LLC has logged 72 m (235 ft) of pay in a Pliocene objective at the Bulleit exploratory test on Green Canyon Block 21. The company was last reported drilling below 3,235 m (10,615 ft). Area water depth is 396 m (1,300 ft). Additional completion information is not currently available. Other Talos wells on Block 18 yield oil and gas from a Pleistocene reservoir at 2,861 m to 5,403 m (9,386 ft to 17,728 ft).
Results from the Lower Magdalena Basin exploratory project were announced by Canacol Energy. The Acordeon 1 well is in the VIM 5 Block in Colombia. It was drilled to 2,591 m (8,500 ft) and encountered more than 128 m (420 net ft) of gross pay between 2,330.5 m and 2,458.5 m (7,646 ft and 8,066 ft) with an average porosity of 18% in the Cienaga de Oro Sandstone. The well flowed 934,456 cu. m/d (33 MMcf/d) of gas during testing on a 60/64-in. choke with a flowing tubing head pressure of 1,476 psi.
An oil discovery was announced by Arrow Exploration Corp. in the Llanos Basin in Colombia. The Rio Cravo Este-1 well is in the Tapir Block and was drilled to 3,048 m (10,000 ft) and hit 31 m (103 ft) of net oil pay (true vertical depth). It was perforated and tested over a 3.6-m (12-ft) interval depth in C7 A Sand. The well averaged 613 bbl of 28-degree-gravity oil per day with a water cut of 46.5%. A peak oil rate of 1,172 bbl/d was recorded, and the well did not produce any gas
during the test. Additional pressure testing is planned.
Rathlin Energy announced preliminary results from the West Newton A-2 appraisal well in petroleum exploration and development license 183. It was drilled to 2,061 m (6,762 ft), and 28 m (92 ft) of core has been extracted from the primary target, Kirkham Abbey, with a net 65-m (213-ft) hydrocarbon-saturated sample including a significant liquids component, which correlates with results from the West Newton A-1 discovery well. The well also encountered hydrocarbon shows within the deeper secondary target, Cadeby, which have proven to be consistent with West Newton A-1. Prior to the drilling of West Newton A-2, a best estimate contingent resource indicated 5.3 Bcm (189 Bcf) of gas equivalent. An extended well test is planned to establish flow rates.
Equinor announced an oil and gas discovery at an exploration well in Snadd Outer Outer/Black Vulture offshore Norway in production license 159B. According to the company, the well had two different reservoir targets—an upper drilling target containing 2 MMboe to 12 MMboe of gas and a lower target with an estimated volume of 1 MMboe to 48 MMboe recoverable. The 6507/3-13 Snadd Outer Outer/Black Vulture well was drilled to 2,800 m (9,186 ft) to the first target, Snadd Outer Outer, where gas was proven. The well was then drilled to 3,200 m (10,499 ft) and hit oil on the second target, Black Vulture. Well volume totals 3 MMboe to 60 MMboe before further delineation tests.
Another discovery was announced by Eni offshore Angola in Block 15/06. An exploratory well, Agidigbo-1 NFW, was drilled to 3,800 m (12,467 ft) and hit a single hydrocarbon column composed with a gas cap of about 60 m (197 ft) and 100 m (328 ft) of light oil. The hydrocarbons are contained in Lower Miocene Sandstones with good petrophysical properties. Based on current testing, there is an estimated 300 MMbbl to 400 MMbbl of oil in place. The five commercial discoveries on the block are estimated to contain up to 1.8 Bbbl of light oil in place with possible upside.
Aspect Energy announced an oilfield discovery in Hungary. According to the company and partners Horizon Energy and TDE Services, they estimate that the new field will be able to produce 11,000 bbl/d to 14,200 bbl/d of oil. The company intends to drill 30 production wells in the new field and build transport pipelines.
Results from an onshore Albania appraisal well were announced by Shell Oil Co. The Shpirag 4 venture is in Block 4, and it was reported flowing light oil. A production test is planned, and commercially recoverable volumes of oil are still to be determined through further appraisal activity. The well was drilled to 6,101 m (20,016 ft) and another appraisal well is planned at Shpirag 3. A previous test at Shpirag 2 hit a light oil column of 800 m (2,625 ft). According to the
company, it is producing from a fractured carbonate reservoir in an equivalent geological setting to the Val D’Agri and Tempa Rossa fields in Italy.
An exploration well is planned in the Bainet West Prospect in the EIV-1 Suceava Concession in Romania. Raffles Energy SRL has analyzed 2-D seismic data for the Bainet West Prospect where a previous exploratory well, Bainet-1, was drilled to 600 m (1,968.5 ft) and hit a 9-m (29.5-ft) reservoir with 8 m (26-ft) of net gas pay in a Sarmatian Sandstone reservoir. The two intervals tested within the main gas pay zone were perforated at 513.3 m to 514.8 m (1,684 ft to 1,689 ft) and 516.3 m to 517.3 m (1,694 ft to 1,697 ft). The well produced 934 cu. m/d (33,000 cf/d) of gas during testing on an 8-mm choke.
Jordan National Petroleum Co. has reported a gas discovery at a new well in the Risha Gas Field in Jordan. According to the country’s Energy Minister, the results in early assessment indicate that the well produced about 198,218 cu. m/d (7 MMcf/d) of gas. The venture will increase the production capacity of the field to 453,069.5 cu. m/d (16 MMcf/d) of gas, a 5% increase in Jordan’s daily output.
Santos Ltd. announced results from the Dorado-2 appraisal well in the Bedout Basin offshore Western Australia. The well was drilled downdip approximately 2 km (1.24 miles) from Dorado-1 and hit 85 m (279 ft) of net reservoir in Caley. The oil-water contact was intersected at 4,003 m (13,133 ft) with 40 m (131 ft) of net oil pay encountered. An additional 11 m (36 ft) of pay was found in Upper Caley Sands. Preliminary analysis indicates this upper zone is oil-bearing, and additional testing is planned. An additional 32 m (105 ft) of net pay was found in the underlying Baxter and Milne sandstones, and there was no fluid contact. Wireline pressure testing has confirmed that all the reservoirs are in pressure communication with the equivalent intervals in Dorado-1. Hydrocarbon and fluid compositions are similar to the light oils and gases that were sampled in Dorado-1. The appraisal well was drilled to 4,573 m (15,003 ft) and is in 91 m (298.5 ft) of water in permit area WA-437-P.
For additional information on these projects and other global developments, visit the activity highlights database at https://www.hartenergy.com/activity-highlights.
Success in those projects would result in its reserve base reaching 3.7 billion barrels over the next seven years and help Woodside expand production by 6% a year over the next decade, the company said.
Output at the largest formation, the Permian Basin of Texas and New Mexico, is expected to rise 57,000 bbl/d to 4.73 MMbbl/d.
Plans are for the well, which was drilled into two untested fault blocks east of the Cashima Field, to be completed by the end of November, the company said.