Africa (Sub-Sahara)

  • Eni is starting commercial oil and gas production at the Sankofa field offshore Ghana 3 months ahead of schedule, the company confirmed. Production was set to begin in July with output eventually to reach 45,000 B/D. The development represents phase one of the USD 7.9-billion Offshore Cape Three Points (OCTP) project, which will produce up to 180 MMscf/D of gas from the neighboring Gye Nyame field by the end of 2018. Eni, the operator, holds a 44.44% interest in OCTP with Vitol (35.56%) and Ghana National Petroleum Corp. (20%) holding the remaining stakes.

  • Asia Pacific

  • Senex Energy has begun drilling in phase two of its flagship Western Surat Gas Project in the Surat Basin in Queensland, Australia. The latest phase involves the drilling of 30 coal-seam gas wells on the Glenora and Eos blocks, which are in the southeastern section of the project acreage and directly north of GLNG’s producing Roma field. Drilling at Western Surat will proceed through the rest of the year with first production expected in the first quarter of 2018. The project, in which Senex holds a 100% interest, is expected to support up to 425 wells.

  • ExxonMobil provided an update on its positive results at the Muruk project in the Papua New Guinea (PNG) North Highlands. The Muruk-1 sidetrack 3 well flowed natural gas at a rate of 16 MMscf/D, which was constrained by production test facilities that limited tests to short flow and buildup periods. The test confirms Muruk as a potentially significant discovery close to the company’s existing PNG LNG (liquefied natural gas) development. Oil Search is the operator of the Muruk wells with a 37.5% interest. ExxonMobil (42.5%) and Santos (20%) are the other interest holders.

  • Latin America-Caribbean

  • ExxonMobil has made a final investment decision to proceed with first-phase development of the Liza field 118 miles offshore Guyana. Situated in 4,921 ft to 6,234 ft of water, Liza is one of the largest oil discoveries of the past decade. The company also said that the Liza-4 well has encountered more than 197 ft of high‑quality, oil-bearing sandstone reservoirs that could underpin a potential Liza phase two development. Gross recoverable resources for the Stabroek block are estimated at 2 billion to 2.5 billion BOE, which includes Liza and other successful exploration wells on Liza Deep, Payara, and Snoek. Liza phase one will include a subsea production system and a floating production, storage, and offloading vessel designed to produce up to 120,000 B/D of oil. Production is expected to begin by 2020, less than 5 years after field discovery. The company is the operator with a 45% interest in the block. Hess (30%) and CNOOC Nexen Petroleum Guyana (25%) hold the remaining stakes.

  • BP, through its BP Trinidad & Tobago (BPTT) joint venture, has made two significant gas discoveries with the Savannah and Macadamia exploration wells offshore Trinidad. Together they represent the discovery of 2 Tcf of gas in place. The Savannah well, which was drilled into an untested fault block east of the Juniper field in more than 500 ft of water, encountered approximately 650 ft of net pay in two main intervals. BPTT expects to develop these reservoirs through a future tieback to the Juniper platform that is due to come on line in mid‑2017. The Macadamia well encountered approximately 600 ft of net pay in seven intervals. The discovery is expected to support a new platform development sometime after 2020. BPTT is 70% owned by BP with the remaining interest held by Repsol.

  • Also in Trinidad, BP’s BPTT joint venture has sanctioned the development of the Angelin gas field 37 miles offshore in 213 ft of water. The project calls for the construction of a platform that will be BPTT’s 15th offshore production facility. The development will include four wells and have a production capacity of approximately 600 MMscf/D. Gas from Angelin will flow to the Serrette platform hub through a new 13-mile pipeline. Drilling is slated to start in the third quarter of 2018 with first gas expected in the first quarter of the following year. Angelin was discovered by the El Diablo well in 1995 and appraised by the La Novia well in 2006.

  • Northern Europe

  • Faroe Petroleum’s Brasse 31/7-2 S appraisal well has found oil in a sand-rich reservoir of good quality in the Norwegian North Sea. Drilled to a total depth of 8,038 ft, the well targeted a seismic anomaly approximately 1.2 miles southeast of the main discovery well, 31/7-1, which was announced in July 2016. Preliminary analysis confirms the same oil/water contact as in the 31/7‑1 well and its sidetrack, and indicates good pressure communication within the reservoir. The company had made plans for a drillstem test of the latest well and was considering drilling a sidetrack well. Faroe and Point Resources each hold a 50% interest in the wells with Faroe as the operator.