Africa (Sub-Sahara)

  • ExxonMobil and its partners will invest more in Block 15 offshore Angola to increase production. As operator, ExxonMobil will complete a multiyear drilling program and install new infrastructure technology to increase capacity of existing subsea flowlines. The project is expected to add 40,000 B/D of oil. Under the agreement, Esso Angola will have 36% interest, BP Exploration 24%, Eni Angola Exploration 18%, and Equinor Angola 12%.

  • Anadarko and partners have taken the final investment decision (FID) to develop the Area 1 Mozambique LNG project. It will be Mozambique’s first onshore LNG development, initially consisting of two trains with total capacity of 12.88 MTPA to support the development of the Golfinho/Atum fields. At $20 billion, the FID is reportedly the largest sanction ever in sub-Saharan Africa oil and gas. Partners are Mitsui, ENH, PTT, ONGC, and Bharat Petroleum Resources and Oil.

  • Asia Pacific

  • Santos’ Dorado-2 appraisal well confirmed oil and gas in the Bedout Basin offshore Western Australia. The well, approximately 2 km from the Dorado-1 discovery, encountered 85 m of net reservoir in the primary Caley formation. An oil-water contact was intersected at 4003 m MD, with 40 m of net oil pay. An additional 11 m of pay was encountered in the Upper Caley sands, and 32 m of net pay was encountered in the underlying Baxter and Milne sandstones. Initial indications show compositions similar to the light oils and gases sampled in Dorado-1. High-quality reservoirs and fluids and the shallow-water setting should facilitate cost efficiency and add value. Santos is the operator of the permit with an 80% stake; Carnarvon Petroleum owns 20%.

  • Shell Australia’s Prelude floating LNG project, 475 km offshore Broome, Western Australia, shipped its first LNG cargo, loading the 173,400-cu m Valencia Knutsen for delivery to Asia.

  • Latin America-Caribbean

  • Arrow Exploration’s wholly owned subsidiary Carrao Energy announced that the 11-day production test of its Rio Cravo Este-1 (RCE-1) exploration well revealed average production of 613 B/D of 28.3 API oil at a 46.5% water cut. The well, located on the Tapir Block in the Llanos Basin of Colombia, reached total depth of 10,000 ft and encountered 103 ft of net oil pay.

  • Parex Resources and Ecopetrol discovered hydrocarbons in two formations in the Andina Norte-1 exploration well in Arauca, Colombia. The well was drilled to a total depth of 18,852 ft in the Capachos Block in the Llanos Basin near the Colombian border with Venezuela. It encountered oil-bearing reservoirs in the Guadalupe and Une formations, and produced a combined 3,406 B/D of light crude oil and 5.8 MM ft/D of natural gas over multiple days of testing. Parex and Ecopetrol each hold a 50% stake in the well.

  • Canacol Energy discovered gas with a flow rate of 33 scf/D its Acordeon 1 well located on its 100%-operated VIM 5 Block in Colombia’s Lower Magdalena Valley Basin. The well reached 8,500 ft total depth and encountered 420 ft of gross gas pay between 7,646 and 8,066 ft TVD. The well will be tied into the Jobo production facility via the Pandereta flowline and brought onto permanent production by the end of July 2019.

  • Petrobras is considering a budget plan for developing natural gas discovered over the last few years in six deepwater fields in the Sergipe Basin. Newspaper O Estado de Sao Paulo said the find was the largest since the sub-salt discoveries in 2006, and that Petrobras could extract up to 20 MM m3/d, equivalent to one-third of total Brazilian production.

  • Middle East-North Africa

  • SDX Energy encountered 134 ft of net heavy oil pay across the Lower Miocene Yusr and Bakr formations at the Rabul‑7 development well in the West Gharib concession in Egypt. The well was drilled to 5,323 ft TD, completed as a producer, connected to the central processing facilities at Meseda, and brought on line at an average stabilized rate over 5 days of 415 B/D gross. SDX and Dublin International Petroleum are joint operators and share equal working interest in the operation.

  • Northern Europe

  • Equinor and partners Ineos E&P and Faroe Petroleum discovered oil and gas in exploration well 6507/3-13 in production license 159B in the Norwegian Sea. The well had two different reservoir targets: an upper drilling target containing 2& to 12 million BOE of gas, and a lower target with an estimated volume of 1–48 million BOE of oil. A tieback to the Norne FPSO is a possibility.

  • Lundin Norway discovered oil in wells 16/1-31 S (Jorvik) and 16/1-31 A (Tellus East) on the eastern edge of the Edvard Grieg field on production license (PL) 338. Combined oil and natural gas gross resources were estimated from 4–37 million BOE. Reserves from both discoveries can be developed with wells from the Edvard Grieg platform. Lundin Norway operates PL338 with 65% working interest. Partners are OMV with 20% and Wintershall with 15%.

  • Reabold Resources said early estimates suggest that the West Newton discovery in northeast England could contain at least 189 Bcf of gas, making it potentially the largest hydrocarbon discovery onshore in the UK since Wytch Farm in 1973. Reabold holds an interest in the West Newton field through a 35% stake in Rathlin Energy, a subsidiary of Connaught Oil & Gas. Rathlin has a 66.67% interest in the project. Partner is Union Jack Oil.

  • USA

  • W&T Offshore (17.25%) and Kosmos Energy (20%) discovered oil at Gladden Deep in the deepwater Gulf of Mexico Mississippi Canyon Block 800. Gladden Deep is a subsea tieback that is expected to be brought on line through the existing Gladden pipeline to the Medusa spar in the fourth quarter of 2019. Based on preliminary analysis of drilling and wireline logging results, the recoverable resource is expected to be in line with the pre-drill estimate of 7 million BOE gross.