IHS Markit announced that Marathon Oil Co. has completed a Middle Bakken and a Three Forks well from a drill pad in Section 15-146n- 93w of Dunn County, N.D. The #31- 15H Chapman well flowed 5.072 Mbbl/d of 40-degree-gravity oil, 67.7 Mcm/d (2.391 MMcf/d) of gas and 6.422 Mbbl/d of water. Production is from a lateral extending 3,323 m (10,902 ft) southward to 6,366 m (20,886 ft), has a 3,226-m (10,584-ft) true vertical depth and bottomed in Section 22-146n-93w. It was tested on a 46/64-in. choke following 45-stage fracturing, and the flowing casing pressure was 1,500 psi. The #31- 15TFH French flowed 2.282 Mbbl/d of 41-degree-gravity oil, 28.3 Mcm/d (1 MMcf/d) of gas and 4.587 Mbbl/d of water. Production is from a horizontal Upper Three Forks interval at 3,325 m to 6,176 m (10,910 ft to 20,626 ft) after 45-stage fracturing. The lateral extends 3,303 m (10,837 ft) southward to 6,367 m (20,890 ft), and it bottomed in Section 22-146n- 93w with a true vertical depth of 3,246 m (10,651 ft). Gauged on a 64/64-in. choke, the casing pressure was 790 psi.


Canacol Energy Ltd. announced the results of appraisal well #2-Pandereta in the VIM 5 Block in Colombia’s Lower Magdalena Valley Basin. The #2-Pandereta well encountered 40 m (130 ft) of net gas pay in Cienaga de Oro and confirmed a previous completion on the block at #1-Pandereta. The #2-Pandereta had an absolute open flow rate of 3.9 MMcm/d (140 MMcf/d). The appraisal well was drilled to 2,939 m (9,641 ft) and had an average porosity of 23% within the Cienaga de Oro sandstone reservoir target. The upper part of Cienaga de Oro was perforated between 2,592 m and 2,625 m (8,505 ft and 8,612 ft) and flowed 991 Mcm/d (35 MMcf/d) during testing on a 57/64- in. choke. The flowing tubing head pressure was 1,438 psi. The lower part of Cienaga de Oro was perforated between 2,644 m and 2,647 m (8,674 ft and 8,684 ft) and was tested on a 32/64-in. choke with a flowing tubing head pressure of 2,446 psi.


GeoPark announced results from an exploration well in the Fell Block in Chile’s Magallanes Basin. The #1-Uaken well was drilled to 1,115 m (3,658 ft). A production test of El Salto flowed 22.66 Mcm/d (800 Mcf/d) of gas with a wellhead pressure of 158 psi. According to GeoPark, the Uaken gas field creates a new gas play in the Fell Block that can be tested in identified leads and prospects. In addition, there are multiple wells in already discovered oil and gas fields within the Fell Block that can be re-entered to test this formation.


Exxon Mobil completed its sixth discovery in offshore Guyana’s Stabroek Block. The #1-Ranger well hit a 70-m (230-ft) oil-bearing reservoir with high-quality oil. The well was drilled to 6,450 m (21,161 ft) and had an area water depth of 2,735 m (8,973 ft). According to Exxon Mobil, the recoverable resource estimate for the block is 3.2 Bboe. When #1-Ranger is complete, the drillship will be moved to the Pacora prospect.


SDX Energy announced results from a completion in Morocco’s Sebou permit area. The #16-KSR well was tested flowing at a restricted average rate of 238 Mcm/d (8.43 MMcf/d), and it has been placed on production. Additional completion information is not available.


According to Cuadrilla Resources Ltd., it has discovered gas in the Borough of Flyde in Lancashire, U.K. A horizontal shale well, the first in the country, is planned. Cuadrilla analyzed data from 114 m (375 ft) of core samples from a well at Preston New Road. The samples indicated excellent rock quality and high gas content in several of the shale zones. Up to four wells could be drilled at the site in second-quarter 2018.

Equatorial Guinea

An oil discovery was reported by Exxon Mobil offshore Equatorial Guinea in Block EG-06. The #1-Avestruz well is adjacent to the Zafiro Field. The company is assessing the commercial viability of the find. The government of Equatorial Guinea has partnered with Exxon Mobil in Block EG-06 through a 20% stake held by the national oil company.


An offshore Namibia test is planned by Africa Oil Corp. at the Cormorant Prospect in petroleum exploration license 37. The prospect is located in the Walvis Basin and area water depth is 550 m (1,804 ft). According to the company, the prospect is one in a series of extensive base-of-slope turbidite fan prospects with significant combined resource potential. The fans directly overlie a mature oil-prone source rock of Aptian age that was recently proven by nearby wells #1-Murombe and #1-Wingat.


A new gas field discovery in South Australia’s Otway Basin was announced by Beach Energy Ltd. The #3-Haselgrove ST1 was drilled as a deviated well to 4,331 m (14,209 ft) and intersected with an estimated gross gas column of 104 m (341 ft) in Sawpit Sandstone, with an estimated net pay of 25.6 m (84 ft). An estimated gross gas column of 11.6 m (38 ft) was also intersected in the shallower Pretty Hill Sandstone, with an estimated net pay of 8.5 m (28 ft). The well is in petroleum prospecting license 62 on state forestry land. The well initially produced 708 Mcm/d (25 MMcf/d) of gas from perforations at 4,023 m to 4,185 m (13,199 ft to 13,730 ft) and was tested on a 36/64-in. choke with a wellhead pressure of 2,700 psi. Flow rates were constrained due to the size of completion tubing. The well is shut-in and more testing is planned.

Papua New Guinea

The results from an appraisal well testing at Papua New Guinea’s Western Highlands Province were announced by Oil Search Ltd. The #2ST 1 P’nyang South is in petroleum retention license 3/application petroleum development license 13. According to the company, the objective was to migrate 2C (proven and probable) gas resource volumes to the 1C (proven) category as well as appraise 2C resource upside potential identifi ed in the southeastern part of the fi eld. The well was drilled to 2,275 m (7,464 ft) with 95⁄8- in. casing set at 1,981 m (6,499 ft). It was cored and then drilled through the objective Toro, Digimu and Emuk, and cores indicate saturated gas with good reservoir quality. Additional testing is planned.

New Zealand

TAG Oil Ltd.’s drilling is underway is underway at exploration well #1-Pukatea in onshore New Zealand’s North Island on the Puka Permit PEP51153. The primary objective of the #1-Pukatea well is the deep Tikorangi Limestone. The well will be drilled to 3,170 m (10,401 ft). The well site is adjacent to the Waihapa oil fi eld, which has produced more than 23 MMbbl from Tikorangi Limestone. According to the company, individual wells produced up to 5 Mbbl/d of oil. In addition to the drilling of Tikorangi Limestone, the venture will also test the shallower Mount Messenger.