[Editor's note: This article originally appeared in the January issue of E&P Plus. Subscribe to the digital publication here.] 

1. Colombia

GeoPark announced results from an appraisal test in Colombia’s Block CPO-5. The well, #2-Indico, was drilled to 10,925 ft and flowed 5,200 bbl of 35°API oil per day from Une (LS3). It was tested on a 40/64-inch choke, and the wellhead pressure was 330 psi. According to the company, the well bottomed within one-half mile to the north and 151 ft down-dip of a previous test, #1X-Indico, which hit a net pay zone of approximately 161 ft. Additional production testing is planned. The drilling rig is being moved to the nearby Aguila exploration prospect in the block to test several targets in Une (LS3). Up to six more wells are planned for the block by GeoPark.

2. Argentina

President Energy reported test results from exploration well #1-xEVN near Estancia Vieja Field in northern Rio Negro Province, Argentina. Two pay intervals in the previously untested Estancia Vieja North structure were confirmed by well logging, with an unreported amount of 36°API oil and gas flowing to the surface. The preliminary testing indicated that IP levels can be expected in line with P50 pre-drill expectations of more than 200 bbl/d of oil plus associated gas from this lower interval. The well is near the main Estancia Vieja pipelines and facilities. Additional exploratory drilling and testing are planned.

3. Canada

Equinor announced that it made two offshore Newfoundland oil discoveries. The two wells at the Cappahayden and Cambriol prospects in the Flemish Pass Basin have proven the presence of hydrocarbons; however, it is too early to provide specific information on volumes. The #1-Cappahayden well was drilled in about 1,000 m of water, and the #1-Cambriol well was drilled in a depth of 600 m.

SEE ALSO:

E&P Plus: January 2021 US Drilling Activity Highlights

4. Norway

ConocoPhillips announced a new gas condensate discovery in the Norwegian Sea in PL1009, Block 6507/4 near Victoria Field and northwest of Heidrun Field. The Warka discovery well, #6507/4-1, was drilled in 399 m of water to 4,985 m. Preliminary estimates indicate the discovery holds between 50 MMboe and 190 MMboe recoverable. The primary and secondary exploration targets for the well were to prove petroleum in reservoir rocks from the Albian and Aptian ages and in the early Intra Lange sandstones (Cretaceous). In the primary exploration target, the well hit a 27-m gas column in sandstone layers in Lange with moderate but uncertain reservoir quality. No gas/water contact or reservoir rocks were encountered in the secondary target. Additional appraisal work is planned. After completion, the rig will be moved to drill exploration well #6507/5-10S (Slagugle) in PL891, north-northeast of Heidrun Field.

5. South Africa

Total announced a gas condensate discovery on the Luiperd prospect offshore South Africa. The #1-Luiperd was drilled to about 3,400 m and encountered 73 m of net gas condensate pay in well-developed, good quality Lower Cretaceous reservoirs. Coring and wireline logging are planned to assess the dynamic reservoir characteristics and deliverability. The discovery is on Block 11B/12B in the Outeniqua Basin, and it follows the adjacent play opening Brulpadda discovery, which proved a significant new petroleum province in the region. Water depth at the site is 1,795 m.

6. India

Oil India Ltd. reported an oil and gas discovery at the #1-Dinjan exploration well in the Tinsukia District of India’s Assam state. The venture is in Tinsukia Petroleum Mining Lease in the Upper Assam Basin. It encountered multiple sands in Kopili, Narpuhand Lakadong, and Therria formations with a total net pay of about 10 m. It flowed approximately 4,061 cf/d of gas from perforations at 3,614 m with a flowing casing pressure of 3,750 psi.

7. Australia

bp is underway at the #1-Ironbarkl exploration well in exploration permit WA-359-P in the Carnarvon Basin. The offshore Western Australia venture will be drilled in about 300 m of water and will test the Ironbark gas prospect, which has a best estimate of 15 Tcf prospective recoverable gas resources. The primary target is the Deep Mungaroo at approximately 5,335 m. Several additional reservoir objectives within the same formation also will be tested. The operator is planning an extensive LWD program, and it will be plugged and abandoned following the completion of operations

8. Australia

Beach Energy announced a gas discovery in the Otway Basin at the #1-Enterprise exploration well in license VIC/P42(V). The well was drilled from an onshore location about 3.5 km north of Port Campbell, Victoria, and was directionally drilled using extended-reach techniques with a 3.2-km step-out. It was drilled to 4,974 m and hit the primary reservoir target, Upper Waarre. The well encountered a 146-m gas column, including 115 m of net gas pay with no gas-water contact identified. The well will be cased and suspended as a future producer.

For additional information on these projects and other E&P developments, visit the drilling activity database at hartenergy.com/activity-highlights.

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