Africa (Sub-Sahara)

  • Equatorial Guinea’s Ministry of Mines and Hydrocarbons has notified Ophir Energy that it will not gain an extension for the offshore Block R license. The block contains the deepwater Fortuna gas discovery. Ophir had been seeking to develop the gas using a Golar-converted floating liquefied-natural-gas (LNG) vessel, but failed to secure sufficient financial backing for the project. Front-end engineering design had begun in July 2015. Targeted production was approximately 330 MMcf/D, with a plateau of 30 years. Located approximately 140 km west of Bioko Island, the Fortuna project was to see development of six commercial discoveries in a phased manner. In November 2016, the British oil and gas company created a joint operating company with OneLNG to develop the floating LNG project at the Fortuna gas discovery.

  • Asia Pacific

  • Thailand’s Department of Mineral Fuels (DMF) has awarded state oil company PTTEP production-sharing contracts for both the offshore G1/61 (Erawan) and G2/61 (Bongkot) projects. PTTEP will replace Chevron as operator of the former in 2022. This development follows an international auction for long-term renewals of the production-sharing contracts for the giant offshore gas fields. The state-owned company won bidding for new concessions covering both fields. The current Bongkot license will expire in 2023. PTTEP bid with 40% partner Mubadala Petroleum for the Erawan license and alone for the Bongkot license. Chevron, with Mitsui Oil Exploration, submitted bids for both licenses. PTTEP has proposed investment plans aimed at committed production of at least 700 MMscf/D from Bongkot and 800 MMscf/D from Erawan.

  • Latin America-Caribbean

  • Hess Corporation announced that drilling has begun on the Haimara-1 exploration well offshore Guyana, the first of two planned exploration wells in January. The Stena Carron drillship is drilling the Haimara-1 well, located 31 km east of the Pluma-1 discovery in the southeastern part of the Stabroek Block. The Noble Tom Madden drillship will drill the second well, Tilapia-1, located 5 km west of the Longtail-1 discovery. The Tilapia-1 well is located in the Turbot area. The resource base on the Stabroek Block underpins the potential for at least five floating, production, storage, and offloading (FPSO) vessels producing more than 750,000 B/D by 2025. ExxonMobil plans to deploy a seismic vessel operated by Petroleum Geo-Services to the Turbot area to acquire 4D seismic data, similar to a 4D campaign conducted in the Liza area in 2017.

  • Middle East-North Africa

  • Saipem and Petrobel have negotiated a contract addendum worth more than $1.2 billion for engineering, procurement, construction, and installation (EPCI) activities in relation to the ramp-up-to-plateau phase of the Zohr field in the Egyptian sector of the Mediterranean Sea. Petrobel is a 50-50 joint venture between Egyptian General Petroleum Corporation and IEOC (an Eni subsidiary in Egypt) and is in charge of the development of Zohr on behalf of PetroShorouk, a joint venture between EGAS (Egyptian Natural Gas Holding Company), IEOC, Rosneft, BP, and Mubadala Petroleum. The current addendum to the work includes the installation of a second 30-in.-diameter gas-export pipeline, infield clad lines, umbilicals, and electrical/fiber-optic cable, as well as EPCI work for the field development in deep water (up to 1700 m) of 10 wells.

  • Northern Europe

  • Spirit Energy has clearance from both the Norwegian Petroleum Directorate (NPD) and Norway’s Petroleum Safety Authority to start operations at the Oda field in the southern Norwegian North Sea. These operations could begin in February or March. Oda was discovered in 2011 at a water depth of 65 m. Development includes two production wells tied back to the Aker BP-operated Ula complex, 10 km to the west, and one injection well for pressure support. Produced gas will be sold to the Ula licensees for use as injection gas for alternating water and gas injection. Oil will be exported through Ula’s existing export pipeline by the Ekofisk field to the Teesside terminal in northeast England.

  • South, Central and East Europe

  • Valeura, an upstream natural gas producer focused on developing an unconventional gas accumulation in the Thrace Basin of Turkey, has provided an update on appraisal drilling operations, which the Company is undertaking with its joint venture partner Equinor. The Inanli-1 appraisal well is drilling ahead at 4145 m with positive interim results. The well encountered the top of the high net-to-gross objective section at approximately 3270 m and has drilled through 875 m of prospective gross reservoir to date. Preliminary interpretation suggests the net-to-gross of the drilled section is at least as good as the approximately 40% net-to-gross encountered in the Yamalik-1 discovery well. After operations are complete, the rig will be moved to the next appraisal well location, Devepinar-1, approximately 20 km to the west.

  • USA

  • Eni has entered into an agreement with Caelus Natural Resources Alaska to acquire 70% and operatorship of the Oooguruk oil field off Alaska. Eni already owns the remaining 30% working interest. The agreement is subject to the approval of the authorities and to certain closing conditions. Located in the Beaufort Sea approximately 5 km off Alaska’s North Slope, the Oooguruk field has been in production since 2008. Current gross production is approximately 10,000 B/D of oil from 25 producing wells and 15 gas/water injector wells. The Oooguruk unit includes a six-acre gravel island in the nearshore waters of Harrison Bay and a subsea flowline bundle connecting with an onshore tie-in pad, which delivers production to the Kuparuk River Unit for processing and delivery.

  • BP has awarded Subsea 7 the subsea umbilicals, risers, and flowlines (SURF) contract for the Manuel project in the US Gulf of Mexico. Project execution will be delivered by a partnership between Subsea 7 and OneSubsea, a Schlumberger company, to provide BP with a fully integrated solution. The Manuel project comprises a two-well development tieback to the Na Kika semisubmersible production platform, working at water depths of up to 1900 m. The project’s SURF work scope includes engineering, procurement, construction, and installation of an electrically heat-traced flowline and a steel catenary riser and all associated subsea structures as well as front-end engineering and design. Offshore operations are scheduled to start in Q4 of 2019.