Africa (Sub-Sahara)

  • Eni, through its affiliate Nigerian Agip Oil Co. (NAOC), discovered natural gas and condensate in the Obiafu and Obrikom fields, in OML61, onshore Niger Delta. The Obiafu-41 Deep well reached 4374 m TD and encountered more than 130 m of high-quality, hydrocarbon-bearing sands. The find amounts to approximately 1 tcf of gas and 60 million bbl of associated condensate. Eni has a 20% stake in NAOC. NNPC has 60% and Oando, 20%.

  • The BP-operated Yakaar-2 appraisal well off Senegal encountered 30 m of net gas pay and proved the southern extension of the Yakkar field. BP has a 60% stake in the Cayar Offshore Profond block and the Yakaar-Teranga gas project. Kosmos and Petrosen have 30% and 10%, respectively.

  • Asia Pacific

  • Beijing Haohua Energy Resource discovered natural gas at the Ketan-1 well in Xinjiang’s Aksu area, part of the oil-and-gas-rich Tarim basin. The well yielded daily natural gas output of 60,000 cu m in test production, according to China National Petroleum Corp.

  • Cooper Energy discovered gas at the Annie prospect in the VIC/P44 permit in the Otway basin approximately 9 km offshore Victoria. The Annie-1 exploration well was drilled to 2442 m TD in 58 m of water. The Waarre C primary target was encountered at 2241 m MDRT with a gross gas column of 70 m. Net pay thickness was 62 m. The deeper Waarre A sandstone was encountered at 2341 m and was water wet. Cooper is the operator of VIC/P44 and holds 50% interest. Mitsui E&P Australia holds the other 50%.

  • Canada

  • Advantage Oil & Gas discovered a significant pool of light oil on its 47 net section block of 100%-owned lands in Alberta. The 16-36 well was drilled to 5268 m MD and demonstrated average production test rates of more than 2,100 BOE/D.

  • Latin America-Caribbean

  • GeoPark discovered the new Guaco oil field in the Llanos 34 block in Colombia. The Guaco 1 exploration well was drilled to 11,936 ft TD, and production tests indicated potential for hydrocarbons in the Guadalupe and Mirador formations. The well is expected to produce approximately 960 BOE/D.

  • ExxonMobil discovered oil with the Tripletail-1 well in the Turbot area on the 6.6-million-acre Stabroek block offshore Guyana. The well, drilled in 6,572 ft of water 3 miles northeast of the Longtail discovery, encountered 108 ft of high-quality oil-bearing sandstone. Esso Exploration & Production Guyana Ltd. is operator with 45% interest. Hess Guyana Exploration Ltd. holds 30%, and CNOOC Petroleum Guyana Ltd. holds 25%.

  • Tullow Oil PLC’s Joe-1 exploration well opened a new Upper Tertiary oil play in the Guyana basin. The well was drilled to 2175 m TD in 780 m of water and encountered 14 m of net oil pay. Tullow Guyana BV operates the Orinduik block with 60%. Total E&P Guyana BV holds 25%. Eco (Atlantic) Guyana holds the remaining 15%. Africa Oil holds 18.8% equity interest in Eco.

  • Middle East-North Africa

  • Eni began production from the Baltim South West gas field offshore Egypt. Initial production rate is 100 MMscf/d. Eni, through its subsidiary Ieoc, has a 50% interest. BP holds the remaining 50%. The project is executed by Petrobel, the operating company jointly held by Eni and the state Egyptian General Petroleum Corp. (EGPC) on behalf of Medgas, jointly held by contractor (Eni and BP) and EGPC.

  • Northern Europe

  • Rathlin Energy discovered oil at West Newton, England, in what was originally thought to be a pure gas discovery. An appraisal well identified an estimated gross hydrocarbon column of approximately 65 m with a gross oil column of 45 m and a gross gas column of 20 m. Rathlin operates the well with a working interest of 66.67%. Its partners are Union Jack Oil and Humber Oil and Gas, each with 16.665%.

  • Equinor started production from the Snefrid Nord natural gas field, the first discovery tied back to the Aasta Hansteen field, and—in 1309 m of water—the deepest field development on the Norwegian Continental Shelf. Recoverable reserves are estimated at 4.4 billion cu m. Equinor Energy serves as operator with 51%. Partners are Wintershall Dea (24%), OMV (Norge) (15%), and ConocoPhillips Skandinavia (10%).

  • Equinor and partners Aker BP and Wellesley Petroleum discovered natural gas with the Ørn 6507/2-5 S exploration well in the Norwegian Sea. The well was drilled to a vertical depth of 4147 m subsea, in 332 m of water. It encountered a total gas column of 40 m in the Garn and Not formations. Equinor estimates recoverable resources at 50–88 MM BOE.

  • Equinor began production from the Utgard gas and condensate field, which spans the Norwegian-UK border in the North Sea. The field consists of two wells from a subsea template tied back to the Sleipner field. Recoverable resources are estimated at 40 million BOE, and daily production on plateau will be approximately 43,000 BOE. Water depth is 110 m, and the reservoir is located at a depth of approximately 3700 m. Utgard will be remotely operated from the Norwegian Sleipner field, and will also use Sleipner’s facility for CO2 purification and storage. License owners are Equinor Energy (38.44%), Equinor UK (38%), LOTOS Exploration & Production Norge (17.36%), and KUFPEC Norway (6.2%).

  • Equinor and partners JX Nippon, Siccar Point, and ONE-Dyas began oil production from the Mariner field, which is estimated to have a total of 3 billion bbl of oil in place and which took more than $7.7 billion to develop. Production is expected to average around 55,000 B/D and up to 70,000 B/D at peak production. Mariner is Equinor’s first operated oil field on the UK Continental Shelf.

  • South, Central and East Europe

  • Valeura Energy and Equinor flowed natural gas from the second stimulated zone in the Inanli-1 appraisal well in Turkey’s Thrace Basin. The interval, at 4176–4217 m, flowed at an average of 185 Mcf/D.