Colombia

Canacol Energy Ltd. plans to drill four new gas development wells, #1-Trombon, #6-Nelson, #8-Nelson and #3-Clarinete, plus one new oil well in 2016. Canacol’s recent gas discoveries have added 8.5 Bcm (302 Bcf) in 2P reserves on the Esperanza and VIM 5 E&P blocks in Colombia’s Lower Magdalena Basin. A second rig has been added for drilling in two blocks. Canacol’s inventory of prospects holds an estimated 67.9 Bcm to 79.2 Bcm (2.4 Tcf to 2.8 Tcf) of unrisked mean estimate resource potential. Canacol is drilling #1-Trombon in the Esperanza Block in the Lower Magdalena Basin, which is estimated to contain 1.1 Bcm (40 Bcf) of potential recoverable resource. The #6 and #8 Nelson are in the same block and will target a Cienaga de Oro (CDO) reservoir. The #3-Clarinete will be drilled in the VIM-5 Block of the Lower Magdalena Basin and target CDO reservoir sandstones, which are productive in Clarinete and Nelson gas fields.

Colombia

GeoPark Ltd. announced that its Llanos Basin Block 34 development well, #4 Tigana, flowed 3.3 Mbbl/d of oil. The well was drilled to 3,398.5 m (11,150 ft) and produces from Guadalupe. It flowed 15.3-degree-gravity oil with a water cut of less than 1% during testing on an electric submersible pump. Tested on a 44⁄64-in. choke, the wellhead pressure was 100 psi. Additional production history will be required to determine stabilized flow rates. Tigana Field is along the same trend and fault line as Jacana Field. The company is drilling appraisal well #6 Jacana to test the southwest extension of the field.

Canada

Petrolia Inc. is drilling the lateral section in #1-Bourque, a wildcat on the Gaspe Peninsula in Quebec, Canada, to 1,700 m (5,577 ft). The planned true vertical depth is 1,505 m (4,938 ft) before the company sets intermediate casing. The projected depth is 3,450 m (11,319 ft), and the 1,750-m (5,741-ft) horizontal leg of the reservoir will be followed by logging and completion. Four cement plugs will be set between 1,780 m and 2,746 m (5,840 ft and 9,009 ft). The rig will be moved a few meters away toward the enlarged portion of #1-Bourque to drill #3-HZ Bourque, which will be vertically drilled to 1,006 m (3,300.5 ft). According to the company, the hole will then be progressively deviated to a total depth of 1,500 m (4,921 ft), 1,299 m (4,262 ft) true vertical depth. The planned depth of #3-HZ Borque is 3,150 m (10,335 ft). A production test of Forillion will be performed for both wells following drilling, logging and tubing installation.

Norway

Results from an offshore Norway appraisal well at the Skipper oil discovery in Block 9/21a in License P1609 were announced by Independent Oil & Gas Plc. The well was drilled to 1,700 m (5,578 ft) and hit 11-degree-gravity oil in the Skipper reservoir. The current estimate of oil in place is 142.6 MMbbl at the North Sea venture. Testing indicated the reservoir’s permeability is 10 darcies. The company plans additional testing and reservoir modeling.

Norway

Lundin Petroleum AB has completed drilling and testing of a reentry of appraisal well #7220/11-3 A on the eastern flank of the Alta discovery in PL609. According to the company, the Alta discovery has estimated gross contingent resources of between 125 MMboe and 400 MMboe. The reentry’s objective was to further assess the quality of the Permo-Carboniferous carbonate reservoir and to conduct injection and production tests. Two injection tests in the carbonate reservoir below the oil-water contact proved good to very good reservoir quality and injectivity in the Falk and Orn formations, according to the company. A production test on a 64⁄64-in. choke in the gas zone in the Lower Triassic reservoir section produced a maximum of 594,654 cu. m/d (21 MMcf/d) of gas. Pressure data from previous wells at #7220/11- 3, #7220/3A and #7220-3 AR indicate good communication with the two previously drilled wells on the Alta discovery. The original discovery well, #3-Alta, was completed in 2015 and hit a 120-m (394-ft) gas column.

Pakistan

Two new gas and condensate discoveries were announced by Petroleum Exploration Ltd. in the Ayesha-1 gas field in Pakistan’s Badin IV South Block, Sajjawal District, Sindh Province. The #1-Aminah was drilled to 2,297 m (7,536 ft) and completed in the Cretaceous Lower Goru A sands. It was tested in 14 m (46 ft) of perforations in Lower Goru A-Sand. During a 10-hr period it averaged 538,020 cu. m/d (19 MMcf) of gas on a 48⁄64- in. choke, with a wellhead flowing pressure of 1,607 psi. The average condensate-to-gas ratio at the 2,280-m (7,480-ft) well was about 3.8 bbl to 28,317 cu. m (1 MMcf) with 24.5 bbl/d of water. The #1-Ayesha North was completed in Cretaceous Lower Goru A sands. It was tested in an 18-m (59-ft) interval on 48⁄64-in. choke, flowing about 246,356.5 cu. m/d (8.7 MMcf/d) with an average wellhead flowing pressure of 771 psi. The condensate-to-gas ratio was about 8.17 bbl per 28,317 cu. m with 28 bbl/d of water.

India

Oilex Ltd. plans to drill a vertical well in the Cambay Block onshore Gujarat, India. Based on core analysis, the operator might fracture-stimulate the EP-IV zone reservoir. In addition, the venture will test the shallower OS-II zone to prepare an OS-II fi eld development plan for extension of the production-sharing contract that ends in 2019. Drilling is expected to begin in 2017, with EP-IV fracture stimulation to follow.

Indonesia

Saka Energi Indonesia discovered offshore oil in the Ujung Pangkah Block in East Java, Indonesia. According to the company, the discovery proved 300 MMbbl of oil at exploration well #4V-Sidayu. The discovery confi rms a fi eld extension after the 2015 discovery at #3ST1-Sidayu in Tuban, Kujung-1 and Ngimbang formations in the Sidayu structure. The company plans additional testing and fi eld development.

Australia

Results from the #2-Roc appraisal well by operator Quadrant Energy Australia Ltd. confi rm gas condensate at the offshore Western Australia site. In Block WA-437-P condensate-rich gas samples were extracted from the well at several locations. Wireline logging tests indicate a 30-m (98-ft) net reservoir and 60 m (197 ft) of gross gas- and condensate- charged sands. Downhole sampling rates indicate gas and condensate permeability of 100 to 350 millidarcies. A liner will be installed for testing, and perforations are planned in the uppermost 35-m (115-ft) sand interval.

Australia

Falcon Oil & Gas Ltd. released results from its #1H-NW Amungee well in Northern Territory, Australia. The Beetaloo Basin venture was drilled to 3,808 m (12,493 ft) and fl owed between 22,653 cu. m/d and 33,390 cu. m/d (800 Mcf/d and 1.2 MMcf/d) of gas after fracturing. The initial estimates indicate a dry gas composition with less than 4% CO2. Falcon hit a 30-m (98-ft) accumulation with 4% to 7.5% porosity, a gas saturation range of 50% to 75% and permeability between 50 and 500 nanodarcies. Additional testing and exploration is planned.

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