US

A Niobrara discovery in the Powder River Basin was tested flowing 1.185 Mbbl of oil, 114 Mcm (4.048 MMcf) of gas and 925 bbl of water per day. Chesapeake Operating Inc.’s #6H Fetter NW 15-33-71 A is within the Northwest Fetter (Deep) Unit in Section 15-33n-71w in Converse County, Wyo. It was drilled to 5,408 m (17,746 ft), 3,414 m (11,200 ft) true vertical, and production is from a Niobrara interval at 3,509 m (11,513 ft) to 5,367 m (17,607 ft). The lateral extends from 2,727 m (8,946 ft) to the southeast and bottomed in Section 22-33n-71w. It was tested on a 32⁄64-in. choke after 48-stage fracturing.

Mexico

Eni has drilled and tested shallow-water well #3-Amoca in Mexico’s Campeche Bay. According to the company, there are multiple significant oil levels in Orca and Cinco Presidentes. The well is in Contractual Area 1 and was drilled to 4,330 m (14,206 ft). It hit 410 m (1,345 ft) of net oil pay in several high-quality Pliocene reservoir sandstones—300 m (984 ft) were found in the deeper sequence of Cinco Presidentes in various cluster levels of Pliocenic age with good reservoir characteristics. During a test of Cinco Presidentes, the well flowed 6 Mbbl of 25-degree-gravity crude per day. The #3-Amoca has been temporarily suspended; the drilling campaign will continue with the first appraisal of the Mizton discovery and additional appraisal wells are planned. With the results of #3-Amoca, Eni’s resource estimate of the field is 1 Bboe in place, and the Area 1 total estimated resource base is 1.3 Bbbl of oil in place (90% oil).

Brazil

Alvopetro Energy has spudded exploration well #177(A1) in onshore Brazil’s Reconcavo Basin in Block 177. The company’s well is targeting a shallow oil prospect in Agua Grande and Sergi as part of Cabure Field at wells #197(2) and #198(A1). According to Alvopetro, the area includes both of these wells but does not extend to the #197-1 discovery, a tight gas resource. Alvopetro is the operator of Block REC-T-177 with 100% interest.

Senegal

Testing results were announced by Cairn Energy from offshore Senegal well #1-FAN South in the South Fan prospect. The well hit a Lower Cretaceous hydrocarbon-bearing reservoir. Preliminary analysis indicates 31-degree-gravity oil. Additional testing is planned to establish the potential commerciality of the resource in the Sangomar Deep Block. It was drilled in 2,175 m (7,136 ft) of water to 5,343 m (17,529.5 ft) and was targeting an Upper Cretaceous stacked multilayer channelized turbidite fan prospect and a Lower Cretaceous base of slope turbidite fan prospect, similar to #1-FAN. The #1-FAN South is being plugged and abandoned, and the rig is moving to work at the SNE North exploration prospect, the most northerly location to be tested. The SNE North prospect is targeting a prospective volume of more than 80 MMbbl of total resource in multiple objectives.

Morocco

Sound Energy Plc completed testing at #1-Koba at Sidi Moktar in Morocco. The company reentered and completed the well in an Argovian reservoir. A 5-m (16-ft) interval was perforated at 1,406 m (4,613 ft) and confirmed gas accumulation. An extended well test is planned. The venture was drilled at the crest of the previous discovery at Kechoula. According to Sound Energy, the Sidi Moktar licenses also contain significant presalt potential, and a previous assessment indicated a potential of up to 254 Bcm (9 Tcf) of unrisked gas in Sidi Moktar licenses. Additional 2-D seismic testing and surveying is planned for the licenses.

Norway

Lundin Petroleum AB reported the drilling and production testing of Alta appraisal well #7220/11-4 (#4- Alta) located in PL609 in the southern Barents Sea. The appraisal well encountered a gross hydrocarbon column of 48 m (157 ft) comprising 4 m (13 ft) of gas and 44 m (144 ft) of oil in a sequence of Permian-Triassic clastic carbonate sediments. Pressure data show the same fluid contacts and gradients as observed in previous wells drilled on the Alta discovery, confirming good communication across the large Alta structure. A production test flowed 6.05 Mbbl/d of oil with lowpressure drawdown, which was constrained by rig testing facilities. A geological sidetrack will be drilled about 900 m (2,953 ft) north of #4-Alta.

India

Oil India Ltd. announced two hydrocarbon discoveries in the Moran Petroleum Mining Lease in India’s Upper Assam Basin. The #1-Borbhuibil encountered multiple sands in Barail, Lakadong and Therria. During testing the well encountered a 15-m (49-ft) Barail Sand interval at 3,322 m (10,899 ft), and it produced 27.9 Mcm/d (988 Mcf/d) of gas. A 10-m (33-ft) interval of Lakadong and Therria Sand was discovered at 4,300 m (14,108-ft), and it produced 3.531 Mbbl/d of oil. At #1- Lakwagaon, the company reported a gross column of 30 m (98 ft) of oil sand in Barail, which has produced 264 bbl/d of oil on initial testing. According to the company, the well is on production.

Indonesia

Operator of offshore Indonesia’s Duyung PSC block in the Natuna Basin Conrad Petroleum reported that the #1-Mako South well was tested on a 128⁄64-in. choke fl owing 308 Mcm/d (10.9 MMcf/d) of gas during a drillstem test. The fl owing pressure was 225 psi, and the gas is pure methane with no hydrogen sulfi de or CO2. It is shut in for buildup. According to the company, the planned total depth was 1,707 m (5,600 ft) and is producing from Intra Muda Sands in the Mako Field.

Australia

In Western Australia’s Perth Basin operator AWE Ltd. announced that wireline log and pressure data from appraisal well #3-Waitsia confi rmed the southern extension of the Waitsia Field by encountering gas shows across a 150-m (492-ft) gross interval including the Kingia and High Cliff sandstone reservoir targets. The well was drilled to 3,612 m (11,850 ft), and gas shows were encountered in Kingia and High Cliff Sandstone intervals as well as minor shows in the Irwin River Coal Measures. Three sections of core were cut in Kingia reservoir, and the well has been cased and suspended for future testing and production. The gross Kingia reservoir interval of 52 m (171 ft) contains 20 m (66 ft) of net gas pay with good reservoir quality. The partners in permit area L1/L2 are AWE and Origin Energy.

Australia

Santos Ltd. has announced results from the two-well appraisal drilling campaign in the Bonaparte Basin in Barossa Field. Logging and pressure data from the offshore Northern Territory, Australia, wells, #5-Barossa and #6-Barossa, confirm the primary Elang reservoir section is gas-saturated and in pressure communication with previous wells drilled in permit area NT/RL5. According to the company, the Elang reservoir interval in #6-Barossa is similar to the reservoir penetrated at offset #3-Barossa, which is about 4.3 km (2.6 miles) to the east. Gas and condensate fl ow at #6-Barossa was produced from an interval between 4,103 m and 4,144 m (13,461 ft and 13,595 ft), fl owing 1.8 MMcm/d (65 MMcf/d) during testing on a 68⁄64-in. choke. The fl ow-constrained condensate- gas ratio was 7 bbl/MMcf.

Comments