Africa (Sub-Sahara)

  • Eni finished a production test on its Minsala Marine 1 NFW well, located in Marine XII block, 35 km offshore The Republic of the Congo. During the test, the well delivered natural flow in excess of 5,000 B/D of 41 °API crude and 14 MMcf/D of natural gas from a 37-m opened section of the discovery’s 420-m column. Eni (65%) is operator, with state-owned partner SNPC (25%), and New Age (African Global Energy) Limited (10%).

  • Asia Pacific

  • CNOOC started natural gas production from the Panyu 34-1/35-1/35-2 project at the Pearl River Mouth basin in the South China Sea. Main production facilities for the three gas fields include one comprehensive platform, two sets of underwater production systems, and 13 producing wells. Two wells are producing a total of 21 MMcf/D of gas. The project is expected to reach peak production of 150 MMcf/D. CNOOC is operator and holds 100% interest.

  • OMV started producing oil from the Maari Growth Project at Maari field, 80 km offshore south New Zealand. The campaign includes drilling of five wells into producing and new reservoirs and will represent a USD-205-million investment by the time it reaches its conclusion in the first half of 2015. The first well, MR-8A was sidetracked out of an abandoned injection well and drilled horizontally into the Moki formation. It is estimated that MR-8A will achieve a 4,500-B/D peak flow rate. OMV (69%) operates the project with partners Todd Maari (16%), Horizontal Oil (10%), and Cue Taranaki (5%).

  • Logging data acquired during the drilling of Origin Energy’s Speculant-1 exploration well—located 3 km offshore southern Victoria, in permit VIC/L1 of the Otway basin—indicated gas within sands in the Waarre formation. Wireline formation-pressure data confirmed the presence of a gas column of approximately 145 m within the Waarre C formation. Further evaluation of secondary targets is under way. Origin is operator of the permit and holds 100% interest.

  • Santos discovered wet gas at its Varanus South-1 well on PEL 513 of Australia’s Cooper basin. The well was drilled to a total depth of 3154 m, and after preliminary interpretation of wireline logs was found to contain an aggregate best estimate of 18 m of net gas pay over a gross interval of 365 m in the Patchawarra formation. An additional net 9 m of hydrocarbon pay was detected in the Tirrawarra formation over a gross interval of 37 m. Santos (60%) is the operator with partner Drillsearch (40%).

  • TAG Oil’s Cheal-E-JV-6 well, located in New Zealand’s Taranaki basin, intersected a net 9 m of hydrocarbon-bearing sands in the Mt. Messenger formation. The well was drilled to a total depth of 1939 m and is being cased and suspended for future testing and possible production, pending results. TAG (70%) is operator with partner East West Petroleum (30%).

  • Latin America-Caribbean

  • Ecopetrol discovered the presence of oil at its Nueva Esperanza-1 exploratory well in block CPO-9, Meta, Colombia. After being drilled to a total depth of 12,056 ft, an eight-day flow test was conducted using an electrical submersible pump. The result was a stabilized daily 910 B/D of 8 °API crude with less than 2% water cut. Nueva Esperanza-1 is the second oil discovery by Talisman and Ecopetrol in block CPO-9, following the discovery of hydrocarbons in the Akacia structure. Ecopetrol (55%) is operator with partner Talisman Energy (45%).

  • Karoon Gas Australia detected five separate oil-bearing zones at its Kangaroo-2 well, offshore Brazil in the Santos basin. Pay zones were encountered in Paleocene- and Maastrichtian-aged formations, each with a separate oil/water contact. The gross oil column totals 250 m with no gas cap. Karoon will conduct wireline logging and drill a possible sidetrack for coring, depending on log results. Karoon (65%) is operator of block S-M-1165 with partner Pacific Rubiales (35%).

  • Middle East-North Africa

  • Marathon Oil KDV—a wholly owned subsidiary of Marathon Oil—discovered multiple stacked oil- and gas-producing zones at its Jisk-1 exploration well in the Harir block of Iraq’s Kurdistan region. The well reached a total depth of 15,000 ft and encountered Jurassic and Triassic reservoirs. Drillstem testing yielded 6,100 B/D of oil and nonassociated gas flowing at a rate of 10–15 MMcf/D. The well was cased and suspended as a potential producer. Marathon (45%) operates the block with partners Total (35%) and the Kurdistan Regional Government (20%).

  • South, Central and East Europe

  • Palomar Natural Resources spudded the Rawciz-12 appraisal well in Poland’s southern Permian basin, in the Rawciz concession. The well is targeting a natural gas accumulation in the Permian Rotliegendes sandstones and will be drilled to a total depth of 1900 m. Palomar (65%) operates the concession with partner San Leon Energy (35%).

  • USA

  • Chevron started producing oil and natural gas from the Jack/St. Malo project in the US Gulf of Mexico, which is estimated to promise peak production of 94,000 B/D and 21 MMcf/D. Oil and gas from the Jack and St. Malo fields, which lie approximately 25 miles from each other, are transported to an export pipeline and then to the Green Canyon 19 Platform which connects with refineries on the coast. Chevron operates the two fields and the host facility. Statoil, Maersk Oil, Petrobras, Eni, and ExxonMobil each participate at different levels within some or all of the three joint ventures.

  • Cuttings from Linc Energy’s Pata 1 exploration well—located in Alaska’s Arckaringa basin—showed evidence of oil in the Stuart Range formation, starting below 1039 m. Fluorescence was found in a siliceous siltstone with minor fine-grained sandstone and increased with depth from approximately 10% at the top of the unit to 90% at the base of unit. The cuttings were sent to a laboratory in Brisbane, Australia—where the company is based—for more testing. Linc is operator and holds 100% interest in PEL 121.