Alaska

According to Armstrong Energy Corp., the company has made a large conventional find in Alaska’s North Slope. The contingent resources in the Nanushuk play could amount to about 1.2 Bbbl of recoverable light oil. Two wells were drilled in Section 15-8n-4e of Umiat Meridian, #1-Horseshoe and #1A-Horseshoe, and extend 32 km (20 miles) into the Pikka area. The Pikka Unit covers about 101,879 km (63,304.47 miles) in 31 State of Alaska and Arctic Slope Regional Corp. oil and gas leases. The #1-Horseshoe was drilled to 1,829 m (6,000 ft) and hit more than 46 m (150 ft) of net oil pay in several reservoir zones in the Nanushuk. The sidetrack, #1A-Horseshoe, was drilled to 2,504 m (8,215 ft) and hit more than 30 m (100 ft) of net oil pay in Nanushuk. The company plans to directionally drill another wildcat, which will bottom to the northwest in Section 16-8n-4e.

Colombia

Anadarko Petroleum Corp. announced results from the #1-Purple Angel well in the Caribbean Sea. The offshore Colombia well was drilled to 4,795 m (15,732 ft) and encountered a 21-m to 34-m (69-ft to 111.5-ft) zone of production. Based on the information obtained from the two wells it is estimated that the Kronos Field has a gas column of at least 520 m (1,706 ft). Area water depth is 1,584 m (5,197 ft).

Colombia

Geopark completed appraisal well #11-Jacana in the Jacana oil field in Colombia’s Llanos 34 Block. It was drilled to 3,541 m (11,618 ft) and tested on an electric submersible pump in Guadalupe flowing 2.1 Mbbl/d of 18.7 degree-gravity oil with less than 1% water cut. It was tested on a 33⁄64-mm choke, and the wellhead pressure was 98 psi. After cleanup additional production history is planned to determine stabilized well flow rates. Surface facilities are in place, and the well is already in production. The venture was drilled to the southwest to 2,500 m (8,202 ft) and is southwest of appraisal well #6-Jacana, which did not encounter the oil-water contact. The discovery indicates that #11-Jacana extends the Tigana/ Jacana oil play toward the southwest limits of the Llanos 34 Block. After completion the rig will be moved to drill #2-Jacana South to test the northwest extension of the field.

Guyana

ExxonMobil Corp. is planning to drill another offshore Guyana exploration well in the Stabroek Block. The #1-Snoek is about 10 km (6 miles) south of the #1-Liza discovery, which hit more than 90 m (295 ft) of high-quality oil-bearing sandstone reservoirs. It was drilled to 5,433 m (17,825 ft) in 1,743 m (5,719 ft) of water. Nearby drilling was at #1-Payara, which encountered more than 29 m (95 ft) of good quality oil-bearing sandstone reservoirs.

Brazil

According to Alvopetro Energy, the company has completed testing an interval at #198(A1) in Reconcavo Basin Block REC-T-198 in Bahia, Brazil. The well was drilled to 1,480 m (4,856 ft), and openhole logging indicated 31 m (102 ft) of potential net gas pay in the Main Caruacu Member, with 26 m (85 ft) of potential net hydrocarbon pay in a series of thinner up-hole Pojuca sands. During a 24-hr test it flowed an average of 7 Mcm (250 Mcf) of gas without stimulation from the Caruacu Member of Maracangalha with 12 bbl of 45-degree-gravity condensate and 92 bbl of water. It was tested on a 32⁄64-in. choke, and the shut-in casing pressure was 615 psi. Additional reservoir pressure tests are planned, and the first interval will be suspended temporarily with a bridge plug while the test proceeds uphole to test the second interval within the primary target.

Senegal

Appraisal results from Cairn Energy Ltd.’s #5-SNE in offshore Senegal’s SNE Field were completed in the upper reservoirs, where two principal units are located within the oil leg. During wireline logging and drillstem testing multiple samples of oil and gas were recovered, and analysis indicated oil of similar quality to previous wells. Two drillstem tests were conducted within the upper reservoir units over gross intervals of 18 m (59 ft) and 8.5 m (28 ft). In the 18-m interval the well produced 4.5 Mbbl/d of oil during testing on a 40⁄64-in. choke. In the 8.5-m interval it produced 3 Mbbl/d of oil during testing on a 56⁄64-in. choke. The drillship is moving to drill #1 Vega- Regulus to test Aptian Carbonates, which is under the SNE Field and has potential gross mean consolidated prospective resource of more than 100 Mbbl.

Saudi Arabia

Gas production from an Aramco shale gas project is set to begin in 2017. The company completed shale gas wells in 2011 in the Jawf and Northern Borders Provinces as well as in areas near Midyan Field and Jalamid Field. One of the wells, #3-Jalamid, produced 597 Mcm/d (12.1 MMcf/d) of gas during preliminary tests. According to Aramco, Midyan alone could produce 2.1 MMcm/d (75 MMcf/d) of nonassociated gas and 4.5 Mbbl/d of oil with condensates. Aramco expects the Jalamid Field will furnish about 5.6 MMcm/d (197.8 MMcf/d) to the Wa’ad Al-Shamal phosphate complex in Tareef Province by 2018.

Pakistan

A gas and condensate discovery by Oil & Gas Development Co. Ltd. was tested flowing 245 Mcm (8.66 MMcf) of gas and 285 bbl/d of condensate. The #1-Chhutto is in the Nim Block in the Sindh Province’s Hyderabad District. The 3,820-m (12,533-ft) well was tested on a 32⁄64-in. choke at a wellhead flowing pressure of 2,100 psi from A sands of Lower Goru.

Australia

Empire Oil & Gas NL announced more results from its #1 Red Gully North well in the Perth Basin in Western Australia. The C Sand discovery produced 1.055 Mbbl/d of light volatile oil from the Upper Cattamara C Sand. The venture is in EP 389 and PL 18/Pl19. Previous testing of the Cattamara C interval flowed 1.8 Mcm (67 Mcf) of gas and 15 bbl of condensate with 895 bbl of water during a 20-hr period. Log analysis on the well indicates a P90 net of oil pay with greater than 9% porosity.

New Zealand

An analysis of the offshore Barque prospect for New Zealand Oil & Gas in offshore New Zealand’s Canterbury Basin indicates that the unrisked petroleum in place (100%) in the three horizons total 311 Bcm (11 Tcf) of gas and 1.5 Bbbl of liquid (oil or gas condensate). The primary reservoir target was estimated to contain 155 Bcm (5.5 Tcf) of gas (best estimate, unrisked and in place) and 785 Mbbl of associated condensate. Analysis of the prospect in the Clipper permit, PEP 52717, showed up to three horizons in the structure. According to the company, if all three horizons were developed simultaneously, a gas-to-shore LNG project is considered the most likely model. It could yield 232 Bcm (8.2 Tcf) of gas, of which 135 Bcm (4.8 Tcf) could be available for conversion to LNG. Area water depth for the prospect is 800 m (2,625 ft).

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