(Source: Larry Prado, Hart Energy)
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View more highlights at Hart Energy's Drilling Activity database.
1 Suriname
Total completed a new oil and gas discovery in offshore Suriname Block 58 at #1-Keskesi East. According to the company, the well hit a 63-m zone of net oil pay with 58 m (net) of black oil, volatile oil and gas pay in the Campano-Maastrichtian reservoirs, along with 5 m (net) of volatile oil pay in Santonian reservoirs. The well was drilled in approximately 725 m of water, and the rig is drilling ahead to deeper Neocomian-aged targets. Total assumed operatorship of Block 58 and #1-Keskesi East in 2020 with a 50% working interest, and Apache Corp. holds the remaining 50%.
2 Brazil
Exxon Mobil has scheduled its first offshore Brazil exploration well in almost 10 years. The presalt formation venture will be the #1-Opal wildcat in Block C-M-789 in the Campos Basin. The company also announced plans for a second wildcat at #1-Titan in the Tita presalt Santos Basin, which will be drilled after #1-Opal.
3 Turkey
Turkish Petroleum Corp. has reported that the #1-Tuna venture has been estimated to contain more than 405 Bcm of gas after identifying an additional 85 Bcm of gas. The deepwater exploration well is located in Block AR/TPO/KD/C26-C27-D26-D27 in the Black Sea. It was drilled in 2,115 m of water to a total well depth of 4,525 m. It encountered more than 100 m of gas-bearing reservoir in Pliocene and Miocene sands. The Ankara-based company had previously announced that the well data and geophysical studies at #1-Tuna showed a potential of 320 Bcm of lean gas. It is currently the largest discovery in the Black Sea.
4 Australia
Vintage Energy announced results from flow testing at #1 ST1 Vali in the Queensland, Australia, portion of the Cooper/Eromanga Basin. The well is in ATP 2021, and it flowed 3.77 MMcf of gas after six-stage fracture stimulation. It was tested on a 38/64-inch choke at a wellhead pressure of 800 psi. Additional testing is planned using different choke sizes. It was fractured in one stage in Tirrawarra and five stages in Patchawarra. A downhole production logging tool test is planned in each zone to determine the gas contribution of each of the stimulated zones. The well will then be cycled through equal periods of shut-in and flow at various flow rates. Gas composition samples will be tested in a laboratory. An independent certified study estimate indicates that the 2C gross contingent resource is 37.7 Bcf. Project partners include Metgasco (25%) and Bridgeport (25%).
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