A Hess Corp. completion in McKenzie County, N.D., was tested flowing 10,626 bbl of oil, 27.6 MMcf of gas and 5,599 bbl of water per day. The An-Bohmbach 153-94-2734H-8 well is in Section 22-153n-94w. Production is from a horizontal Middle Bakken interval at 11,084 ft to 20,749 ft. The Antelope Field well was drilled to 20,749 ft (10,749 ft true vertical depth) to the south and bottomed in Section 34-153n-94w. Gauged on a 76/76-in. choke, the flowing casing pressure was 1,666 psi.
Tullow Oil has tested the Joe-1 exploration well and has opened a new Upper Tertiary oil play in the offshore Guyana Basin. The well was drilled to 2,175 m and is in 780 m of water. Evaluation of logging and sampling data has confirmed that the venture encountered 14 m of net oil pay in high-quality, oil-bearing sandstone reservoirs of Upper Tertiary age. The Joe-l well is the first oil discovery to be made in the Upper Tertiary and de-risks the petroleum system in the west of the Orinduik Block, where a number of Tertiary and Cretaceous age prospects have been identified. The data from Joe-1 will be evaluated with a previous discovery at Jethro-1. A follow-up well is planned at Carapa-1 on the Kanuku license.
Exxon Mobil reported an oil discovery on the Stabroek Block offshore Guyana at the Tripletail-1 well in the Turbot area. The discovery adds to the previously announced estimated recoverable resource of more than 6 Bboe on the Stabroek Block. The discovery hit about 108 ft of a high-quality, oil-bearing sandstone reservoir. The well was drilled in 6,572 ft of water. After completion operations, the drillship was moved to drill Uaru-1 to the east of the Liza Field. Exxon Mobil plans to have a total of four drillships operating in the area.
Hurricane Energy announced an oil discovery at the Lincoln Crestal 205/26b-14 exploration well in the Greater Warwick Area of the U.K. sector of Block 205/26b in the North Sea. The well was tested flowing 9,800 bbl/d of oil with the use of electric submersible pumps. The average rate was 4,682 bbl/d of 43-degree-gravity oil. No formation water was produced. The Lincoln Crestal is the second well in a three-well program in the Greater Warwick Area. It was drilled to 1,780 m and included a 720-m horizontal section of fractured basement reservoir. The well will be suspended, and the rig will move to drill the third well, Warwick West 204/30b-A, in the 2019 drilling program.
Eni announced a gas and condensate find in the deeper sequences of the Obiafu-Obrikom fields in the OML61 Block in Nigeria’s onshore Niger Delta. The Obiafu-41 Deep well was drilled to 4,374 m and encountered a gas and condensate accumulation within the deltaic sequence of Oligocene age of more than 130 m of high-quality, hydrocarbon-bearing sands. Initial estimates indicated that discovery holds 1 Tcf of gas and 60 MMbbl of associated condensate in
the deep drilled sequences. Additional testing and appraisal work is planned. Eni expects that the well can deliver in excess of 100 MMcf of gas and 3,000 bbl of associated condensates per day.
Croatian oil and gas company Industruja Nafte has reported the discovery of a gas ledge at the Severovci-1 well in the Drava-02 exploration block. According to the company, the well is capable of producing about 1.8 MMcf/d of gas. The venture was drilled to 3,410 m, and additional testing and exploration is planned.
Serbia’s national oil and gas company Naftna Industrija Srbije plans to drill two additional wells by the end of 2019 at its EX8 exploration block in western Romania. Partner East-West Petroleum drilled the first exploration well on the block, 1000-Bvs, in March and testing operations are underway. Seismic data processing (3-D) has been completed and interpretation
is ongoing, and another 3-D survey is planned on Block EXA-2 as well as experimental production at 1000-Ter in Block EX7.
Results from a flow test in the second stimulated zone at the Inanli-1 well in Turkey’s Thrace Basin were announced by Valeura Energy. The zone at 4,176 m to 4,217 m was targeted to test a shallower area of tighter and less fractured rock to determine gas flow potential and fluid characteristics. The well flowed 130,000 cf/d of gas along with a condensate-gas ratio of about 10 bbl/MMcf, with 4 bbl/d of water. According to the company, the results indicated that gas can be produced from the lower quality reservoir and also confirms the low water rates associated with the gas production at these depths. The current estimate of resource on the site is 10 Tcfe of unrisked gas, including 236 MMbbl of condensate. Valuera is preparing the well for the stimulation and expected to extend into late 2019.
An oilfield discovery has been announced by operator MOL in the TAL Block in Pakistan’s Khyber Pakhtunkhwa Province. New reserves were discovered in the TAL concession on the Kohat Plateau at the Makori-2 well. Well testing indicated that it is capable of producing about 1,844 bbl of oil with 18.25 MMcf/d of gas. The new discovery has de-risked exploration in deeper fault blocks in the TAL Block leading to new upside opportunities. Production from the TAL Block accounts for about 20% of Pakistan’s oil production (about 17,000 bbl/d). The most recent discovery was made in 2011.
Strike Energy has announced a new conventional gas discovery at the West Erregulla-2 well in Kingia Sandstones in Western Australia. The well is in EP 469, was drilled to 5,017 m and encountered a 97-m gas column with a net pay of 41 m and porosities of up to 19%. No gas-water contact has been observed. Drilling will continue through the High Cliff Formation. The West Erregulla-1 well flowed 23 bbl of 47-degree-gravity oil during a drillstem test. Total prospective P50 resources are estimated to be 1.16 Tcf of gas and 7 MMbbl of oil.
Cooper Energy Ltd. announced a new offshore gas field discovery at the Annie-1 exploration well in VIC/P44 in Victoria’s Otway Basin. The well was drilled to 2,442 m in 58 m of water and encountered productive Waarre C and Waarre A sandstones. The primary target, Waarre C, hit a gross gas column of 70 m with a net pay thickness of 62 m. Wireline logging operations to collect pressure and sample data have been completed and collected for resource volume estimates and to determine gas composition with additional testing planned. The well will be plugged and abandoned and will move to drill the second well in the program at the Elanora-
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.
The breakthrough follows months of talks between the two companies over what to charge for processing gas from the field through Woodside’s Pluto LNG plant.