Gulf of Mexico

According to IHS Markit, Cobalt International Energy hit 198 m (650 ft) of net oil pay at its North Platte development on Garden Banks Block 959. The total depth was not disclosed, but the appraisal test was expected to reach 10,455.5 m (34,303 ft). Area water depth is 1,493.5 m (4,900 ft). A previously drilled appraisal, #3 (ST) OCS G30876, encountered 152 m (500 ft) of net oil pay.

Guyana

ExxonMobil Corp. announced a second oil discovery, #1-Payara, in the offshore Guyana Stabroek Block. The venture targeted similar aged reservoirs found at #1-Liza, which was discovered in 2015. The well encountered more than 29 m (95 ft) of high-quality oil-bearing sandstone reservoirs. It was drilled to 5,511 m (18,080 ft) and is in 2,030 m (6,660 ft) of water. Two sidetracks have been drilled, and additional testing and evaluation is underway.

UK

Cuadrilla Resources Ltd. is preparing to drill at a shale gas site in Lancashire, U.K. The company’s well, #1-Preston New Road, will be in PEDL 165 and will target the Bowland Shale. The vertical venture has a planned depth of 3,500 m (11,483 ft) and will be logged. Afterward, the depth and orientation of other horizontal wells will be determined. Up to four exploration wells could be drilled at the site, and laterals could extend to 2,000 m (6,562 ft).

UK

A new North Sea gas field discovery in Cleveland Basin Block 41/24 named Maxwell was announced by Arenite Petroleum Ltd. The new field is in offshore England’s Yorkshire coast at Scarborough. In the 1970s Total drilled and completed five wells in the field that produced about 424,753 cu. m/d (15 MMcf/d) of gas. Arenite is planning to drill a proof-of-concept horizontal well into the Permian carbonates with two major target horizons identified and to deepen this well to test the underlying Carboniferous strata.

Norway

Det Norske Oljeselskap ASA completed wildcat well #25/2-18 S and appraisal wells #25/2-18 A and #25/2-18 C in production license PL 442 in the Norwegian North Sea. The objective of #25/2-18 S was to prove petroleum in Middle Jurassic Hugin and Sleipner. It encountered a 30-m (98-ft) column and an 86-m (282-ft) column, both with moderate-to-good reservoir quality. Appraisal well #25/2-18 A was drilled 1 km (.62 mile) northeast of #25/2-18 S and hit a 27-m (88.5-ft) and a 34-m (111.5- ft) oil column in Hugin, both with moderate-to-good reservoir quality. Appraisal well #25/2-18 C, which was drilled 1 km west of #25/2-18 S, encountered a 27-m column, a 23-m (75-ft) column and a 55-m (180-ft) oil column in Hugin, all with moderate- to-good reservoir quality. A 7-m (23-ft) condensate column also was encountered, of which 3 m (10 ft) in sandstones was of moderate reservoir quality. At #25/2-18 A, a drillstem test flowed 600 cu. m/d (21 Mcf/d) of oil during testing on a 40⁄64-in. choke in the lowermost oil zone. The production rate in the uppermost oil zone was 210 cu. m/d (7.4 Mcf/d) of oil per flow day through a 24⁄64-in. choke. All of the wells were terminated in the Dunlin Group in the Lower Jurassic, and area water depth is 121 m (397 ft).

Italy

A rig is ready to drill a Sound Energy Plc exploration well at #1-Badile in northern Italy’s Po Valley Badile Block. The well has a planned depth of 4,600 m (15,092 ft), and it will test the hydrocarbon potential of Lower Jurassic Conchodon Dolomite. An independent study indicates an unrisked best-case estimate of 5 Bcm (178 Bcfe), an upside high case in excess of 18.9 Bcm (670 Bcfe) and low case of 1.3 Bcm (46 Bcfe).

Norway

Statoil announced an oil and gas discovery that is estimated to have between 20 MMboe and 80 MMboe. The Cape Vulture exploration well, #6608/10-1, is in License 12. Statoil plans to analyze the area to identify new exploration targets and also plans appraisal drilling. The discovery is northwest of Norne, and a tieback of the discovery to the FPSO unit at the Norne Field will be considered.

Kenya

Tullow Oil Plc announced results from #1-Erut in Kenya’s Block 13T. The company hit a gross oil interval of 55 m (180 ft) with 25 m (82 ft) of net oil pay at a depth of 700 m (2,296.5 ft). The overall oil column for the field is considered to be 100 m to 125 m (328 ft to 410 ft). The objective of the well was to test a structural trap at the northern limit of the South Lokichar Basin. Fluid samples taken and wireline logging all indicate the presence of recoverable oil. According to Tullow, oil has migrated to the northern limit of the South Lokichar Basin and has allowed the company to de-risk multiple prospects in this area. The well was drilled to 1,317 m (4,321 ft), and the rig is being moved to spud appraisal well #6-Amosing in the southern part of Block 10BB.

Pakistan

A gas discovery was completed by Jura Energy Corp. in the Zarghun South Development and Production Lease in Pakistan. The development well, #3-ZS, flowed 297,327 cu. m/d (10.5 MMcf/d) with production from Dunghan Limestone (Paleocene). The well was drilled to 1,820 m (5,971 ft). It was tested on a 32⁄64-in. choke with a wellhead pressure of 1,800 psi. According to the company, the gas is 920 Btu/scf, and it will be tied in to nearby gas processing facilities.

Australia

A gas and condensate discovery was announced by Empire Oil & Gas NL from the #1-Red Gully North well in Western Australia’s Perth Basin. The Perth Basin Block EP389 venture was tested flowing 419 bbl/d of condensate, 35,962 cu. m/d (1.27 MMcf/d) of gas and 684 bbl/d of water during an eighthour test of C Sand, with 24-hr testing planned soon. Testing was suspended so that additional surface facilities could be secured. Empire also planned to test Upper D Sand, but testing indicated a low-permeability reservoir, and no hydrocarbons flowed to the surface. Additional testing is planned to determine if both formations will produce in commercial quantities.

Australia

Quadrant Energy Pty Ltd. announced results from the offshore Western Australia venture #2-Phoenix South in the WA-435-P permit area on the North West Shelf. The well hit an estimated 39-m (128-ft) hydrocarbon- bearing zone between 5,176 m and 5,215 m (16,982 ft and 17,110 ft). A significant gas influx was reported with elevated reservoir pore pressures. Due to high pressure from the Caley reservoir below 5,215 m, the company was unable to assess as much as 185 m (607 ft) of potential. Additional testing is planned.

Papua New Guinea

Operator Oil Search Ltd. announced a new gas field discovery in Papua New Guinea’s northern Highlands about 21 km (13 miles) northwest of Hides Field. The #1-Muruk exploration well was drilled in PPL 402, and it encountered high-quality sandstone reservoirs similar to those found in Hides Field. The well was drilled to 3,130 m (10,269 ft). Additional drilling and testing is planned by the company.