Sahara Group discovered hydrocarbons in three wells drilled in Block OPL 274, located onshore in Nigeria’s Edo State. Olugei-1 was drilled to a measured depth of 4537 m and encountered five hydrocarbon zones, with 33 m of net pay. Oki-Oziengbe South 4 was drilled to a measured depth of 3816 m and encountered 64.3 m of net pay in 13 hydrocarbon-bearing zones. Oki-Oziengbe South 5 was drilled to a measured depth of 3923 m and encountered 91 m of net pay in 19 reservoirs. Sahara Group (100%) is the operator.
Sino Gas & Energy Holdings (SGE) flowed gas (coalbed methane) from its first horizontal well in the Linxing production sharing contract (PSC) in China’s Shanxi province. Following a nine-stage fracture stimulation treatment, flow testing was conducted over 80 hours in two stages, resulting in a gas flow rate of 4.93 MMcf/D, with a tubing head pressure of 2,008 psi. SGE (64.75%) is the operator, with partners CUCBM (30%) and CBM Energy (5.25%).
Salamander Energy spudded the North Kendang-2 (NK-2) exploration well—a re-drill of North Kendang-1—in Indonesia’s South East Sangatta PSC. A serious kick incident led to North Kendang-1 being plugged and abandoned before operations could be completed. NK-2 is being drilled by semisubmersible Ocean General to 2878 m total vertical depth subsea in order to evaluate the Upper Miocene formation. Salamander (75%) is operator, with partner Kutai Timur Resources (25%).
In the WA-430-P permit of Western Australia’s Exmouth sub-basin, Woodside Petroleum’s Toro-1 exploration well intersected approximately 150 m of gross gas pay (65 m of net gas pay) in the target Mungaroo formation. The well was drilled to a total depth of 3724 m and is 22 km from Woodside’s existing Ragnar-1A discovery. It will be plugged and abandoned. Woodside (70%) is operator, with partner Mitsui E&P Australia (30%).
Beach Energy spudded the Elliston-2 development well in PPL 249, on the western flank of the Cooper basin in South Australia. The well will be drilled to a total depth of approximately 1655 m, which is expected to take 1 week. Beach intends to use the well to accelerate production from the Namur sandstone reservoir. Beach (75%) is operator, with partner Cooper Energy (25%).
According to wireline logs, ConocoPhillips discovered gas in well Pharos-1 in the WA-298-P Browse basin permit, off the coast of Western Australia. Pharos-1, located around 9 km northeast of the Proteus-1 well, was drilled to a total depth of 5220 m. Pharos-1 was targeting an extension of the discovery made by Proteus-1, which established excellent reservoir quality and condensate-bearing gas in the Montara formation. ConocoPhillips (60%) is operator, with partner Karoon Gas (40%).
Egdon Resources spudded the Wressle-1 onshore exploration well in PEDL 180, Lincolnshire, UK. Egdon plans to drill Wressle-1 as a deviated well to a total measured depth of approximately 2300 m. Egdon estimates the well has mean gross un-risked recoverable resources of 2.1 million bbl of oil. Egdon (25%) is operator, with partners Europa Oil & Gas (33.3%), Celtique Energie Petroleum (33.3%), and Union Jack Oil (8.3%).
ExxonMobil Exploration and Production Romania started drilling the Domino-2 well in a deepwater section of the Neptun prospect, in the Black Sea, approximately 200 km off the coast of Romania. Domino-2 sits at a water depth of 800 m. ExxonMobil (50%) is operator, with partner OMV Petrom (50%).
Centrica Energy has commenced drilling the Pegasus West well (43/13b- 7) in Block P1724 of the UK’s southern North Sea. The well is being drilled by jackup rig Noble Julie Robertson at a water depth of approximately 95 ft and is targeting a Carboniferous gas interval. Centrica (55%) is operator, with partners Third Energy Offshore (35%) and Atlantic Petroleum (10%).
Oryx Petroleum finished testing the Demir Dagh-6 appraisal well, located in the Demir Dagh field, Hawler license area, in the Kurdistan Region of Iraq. It was drilled to a total measured depth of 2029 m. Oryx conducted two cased-hole drillstem tests. The first was conducted over a 20-m interval in the Kometan formation, and 19°API to 21°API oil flowed naturally at a sustained rate of 500 B/D over a 10-hour period through a 32/63-in. choke. The second was performed over a 25-m interval in the Shiranish formation. Using a 16/64‑in. choke over a 6-hour period, a sustained flow rate of 700 B/D of 23°API oil, with no free gas, was achieved. Oryx (65%) is operator, with partners KRG (20%) and KNOC (15%).
TransGlobe Energy’s NWG-1 exploration well—located in the North West Gharib concession in Egypt—has encountered approximately 33 ft of net oil pay, according to well logs. The well was cased for completion as a future producer. TransGlobe (100%) is the operator.
Shell announced its third major discovery in the Gulf of Mexico’s Norphlet play—the Rydberg exploration well, located 120 km offshore Louisiana in Mississippi Canyon Block 525. The well was drilled in a water depth of 2280 m by drillship Noble Globetrotter I to a total depth of 8038 m and encountered more than 120 m of net oil pay. Shell is still evaluating the well, but expects the resource base to be approximately 100 million BOE. Shell (57.2%) is operator, with partners Ecopetrol America (28.5%) and Nexen (14.3%).
GeoPark discovered oil at the Tigana Norte-1 well in Block LLA-34 of Colombia’s Llanos basin. The well was drilled to a total depth of 12,141 ft; a test was conducted with an electrical submersible pump in the Guadalupe formation at 11,557 ft. The test achieved a production rate of approximately 1,061 B/D of 14.6°API crude through a 24/64-in. choke, with a wellhead pressure of 235 psi. GeoPark is operator (45%), with partner Parex Resources (55%).