A Utica completion in Jefferson County, Ohio, by Ascent Resources LLC was tested flowing 608,982 cu. m (21.506 MMcf) of gas with 212 bbl/d of water. The Nolan S CRC JF 2H well is on a 640-acre lease in Section 32-6n-2w and had a projected depth of 5,486 m (18,000 ft) in Gould Consolidated Field. It was drilled to the southeast to 5,648.5 m (18,532 ft), and production is from a fractured zone at 2,966 m to 5,540 m (9,731 ft to 18,176 ft).
Ecopetrol has reported a discovery on the Playon Block in Rio Negro (Santander) in the Middle Magdalena Basin in Colombia. The Boranda-2 ST well encountered crude in Eocene Basal Sands. The well was drilled from the same platform as discovery well Boranda-1 about 1,200 m (3,937 ft) to the southeast. The well initially produced 960 bbl/d with a water cut of less than 2%. It was drilled to 4,246 m (13,930 ft), and it confirmed the finding of 23-degree-gravity crude. Additional testing is planned.
Kosmos Energy has reported a discovery in the eastern anticline in the Greater Tortue, encountering about 30 m (98 ft) of net gas pay in the high-quality Albian reservoir. The GTA-1 well offshore Senegal was drilled to 4,884 m (16,024 ft) in 2,500 m (8,202 ft) of water. The Greater Tortue Ahmeyim Field Development is located in Block C-8 (Mauritania) and Saint-Louis Profond Block (Senegal). The drillship will be moved to drill appraisal well Yakaar-2 in the Senegal portion of the development area.
Aker BP is nearing completion at exploration well Liatarnet-1 in offshore Norway license 442 in the NOAKA area. The well has proved oil with a gross resource estimate of 80 MMboe to 200 MMboe. Further data acquisition and analysis will be undertaken to determine the drainage strategy and recovery factor for the discovery. A more detailed technical description of well results will be released by the Norwegian Petroleum Directorate when the operation has been completed.
Egdon Resources has confirmed the presence of hydrocarbons at exploration well Biscathorpe-2 in Lincolnshire, U.K. The well is in petroleum exploration and development license 253. According to the company, the well was drilled in the proven hydrocarbon fairway of the Humber Basin and was targeting a Carboniferous Westphalian Sandstone reservoir. Elevated gas readings were recorded in Westphalian over a 157-m (515-ft) Dinantian Limestone interval along with the presence of oil shows in both Westphalian and Dinantian cuttings samples. The well was suspended and a sidetrack well may be drilled after additional studies of existing 3-D seismic data and testing.
IGas Energy announced core analysis results from exploration well SR-01 at Springs Road in North Nottinghamshire, U.K. The vertical well is in petroleum exploration and development license 140 in the Gainsborough Trough Basin. Three zones were targeted: Bowland Shale, Millstone Grit and Arundian Shale with 429 m (1,407 ft) of hydrocarbon-bearing shale in Bowland. About 147 m (482 ft) of core was recovered, and testing indicates 2% to 7% total organic compound, 2% to 9% porosity, low clay content as well as 679,604 cu. m to 3.7 MMcm (24 MMcf to 131 MMcf) of potential gas pay. This is the second
well of an integrated exploration and appraisal program to define the Gainsborough Trough Basin.
Lundin Petroleum made two oil discoveries at exploration wells 16/1-31 S (Jorvik) and 16/1-31A (Tellus East). The discoveries are on the edge of the Edvard Grieg Field in the Norwegian sector of the North Sea in production license (PL) 338 on the Utsira High. The 16/1-31S (Jorvik) well encountered oil in 30 m (98 ft) of conglomerate reservoir of Triassic age with a thin, high-quality sandstone above. The well was tested at an anticipated flow rate of about 130 bbl/d in the conglomerate interval and pressure measurements show that the area is in communication with the Edvard Grieg Field. The 16/1-31A (Tellus East) well encountered a gross oil column of 60 m (197 ft) in porous, weathered basement reservoir. Tellus is on the northern edge of the field. The combined gross resources of Jorvik and Tellus East are estimated to be between 4 MMboe and 37 MMboe. The rig will stay in the Utsira High area to drill several shallow gas pilot wells. Afterward, it will move to drill the Goddo exploration well 16/5-8S in PL 815 to test the Rolvsnes weathered basement oil discovery into the adjacent license, where the combined area is estimated to contain gross potential resources of more than 250 MMboe.
OMV plans to drill two offshore wells in the shallow waters of the Istria Block XVIII in the Romanian sector of the Black Sea. The two wells have planned depths of about 2,000 m (6,562 ft) and area water depth is 50 m (164 ft). The ventures will target additional production from the oil and associated gas in the Lebada East Field, which was discovered in 1979.
A large gas field discovery offshore Sarawak, Malaysia, was announced by PTT Exploration & Production. The Lang Lebah-1RDR2 well is in the SK410B Block and hit 252 m (827 ft) of gas pay in the South China Sea. The well was drilled to 3,801 m (12,470 ft) and was targeting a Middle Miocene Cycle IV/V carbonate reservoir. It was tested at a completion-constrained rate flowing 1.1 MMcm (41.3 MMcf) of gas and 246 bbl/d of condensate during testing on a 40/64-in. choke. Although additional testing is planned, current estimates indicate the find at 56.6 Bcm (2 Tcf).
In Western Australia Block 469, Strike Energy has reported hydrocarbon shows in the Lesueur and Woodada formations at the West Erregulla-2 exploration well in the North Perth Basin. According to the company, good hydrocarbons have been observed, and both formations had fair-to-good visual porosity and appear better than offset well West Erregulla-1. The hydrocarbon-bearing formations will be further evaluated with openhole wireline logging. Strike plans to test the secondary conventional gas target of the well, the Basal Wagina Sandstone, and will be targeting analogous Permian gas sands of a similar nature as the Waitsia gas discovery. The well has a planned depth of 5,200 m (17,060 ft) and will penetrate two additional independent reservoir targets including a conventional gas target in Basal Wagina sandstones and the primary gas sand sequence in the Kingia High Cliff.
Three development wells in the Tui area of offshore New Zealand have been planned by Tamarind Resources in the offshore Taranaki Basin. The company expects to develop an additional 6 MMbbl to 8 MMbbl of oil. Three sidetrack wells are planned, and the company is considering a possible fourth sidetrack well, depending on the results from the initial three wells.
The Scoop and Stack plays are still in the money but only with improved well spacing and effective management of frac-driven interactions.
Positive results are emerging from fracturing field laboratories.
The dialing in of optimal completion designs by operators is keeping sand and water providers busy right-sizing their logistical response.