PRODUCTION 

BP achieves first gas offshore Trinidad & Tobago

BP Trinidad and Tobago (BPTT) said that its Angelin development has reached first gas, on time and under budget. The development is approximately 37 mi off Trinidad’s southeastern coast, in about 213 ft of water. The project’s newest platform, which is BPTT’s 15th installation in the region, is flowing to the existing Serrette hub, via a new 13-mi pipeline. The platform reportedly has a production capacity of 600 MMscfd. According to BPTT, Angelin is the company’s first major project supported by the application of ocean bottom cable seismic acquisition with advanced processing, which allows enhanced imaging of its reservoirs in the Columbus basin. BPTT Regional President Claire Fitzpatrick said Angelin “is the next step” in fulfilling the company’s long-term development plan in Trinidad. Following the successful startup of Angelin, BPTT has announced the sanction of another two developments—Cassia Compression and Matapal—which are expected to go onstream in 2021 and 2022, respectively.

U.S. production reaches record 12.0 MMbopd

The U.S. Energy Information Administration (EIA) reported that U.S. crude oil production hit an all-time high in January, averaging 12.0 MMbpd. This is up from the previous record of 11.91 MMbpd that was set in December. The record was reached significantly earlier than expected, as EIA previously predicted that 12.0 MMbpd would not be reached until fourth-quarter 2019. The EIA has adjusted its 2019 forecast accordingly. The agency now anticipates that U.S. crude oil production will average 12.4 MMbpd this year, and 13.2 MMbpd in 2020. Most of the production growth is expected to come from the Permian basin in Texas and New Mexico. EIA is forecasting that Permian production will average 4.2 MMbopd in 2019, a 750,000-bopd increase from 2018, and 4.7 MMbopd in 2020, a 530,000-bopd gain over 2019’s level. Permian producers reportedly were able to increase output, despite major regional price discounts “because of operational efficiencies in trucking and rail, and higher overall WTI-Cushing prices.” The agency explained that “favorable geology, combined with technological improvements, has contributed to the Permian region becoming one of the more economic regions for crude oil production in the United States.” EIA also said that it expects production in all other major regions to remain stagnant, or to slightly decline, through 2020. 

DEVELOPMENTS

Woodside secures FPSO for SNE field development, in deep waters offshore Senegal

Woodside, operator of the Rufisque Offshore, Sangomar Offshore and Sangomar Deep Offshore (RSSD) JV, has awarded a FEED contract to MODEC International, Inc., for the SNE Field Development Phase One FPSO. According to the company, Phase One of the development is a stand-alone FPSO facility, with 23 subsea wells and supporting subsea infrastructure. It is expected to have a capacity of approximately 100,000 bpd, with first oil anticipated for 2022. Also, it reportedly will allow subsequent SNE development phases, including options for potential gas export to shore, as well as future subsea tie-backs from other reservoirs and fields. This award comes just a few months after the development plan for SNE field was submitted to the Government of Senegal in October. “Securing an FPSO facility is a significant step for the joint venture and will allow the project team to complete the technical and commercial activities required to support a final investment decision, targeted for mid-2019,” Woodside CEO Peter Coleman said in a release.

Neptune Energy moves forward with plans for Duva, Gjøa

Neptune Energy has submitted development plans for the Duva and Gjøa P1 projects, in the Norwegian sector of the North Sea. The fields reportedly will be developed as subsea tie-backs that will connect two templates to the nearby Gjøa platform (pictured). The PDO of Duva field, formerly known as Cara, includes a four-slot subsea template. The field, which is estimated to contain recoverable resources of 88 MMboe, will have three production wells, two oil producers and one gas producer. Likewise, an application for exemption from PDO for the Gjøa P1 Segment Redevelopment Project was submitted, as the P1 segment reportedly is already covered by the development plan for Gjøa field. According to Neptune, Gjøa P1 is a further extension of the field, which will focus on increased exploitation. P1’s recoverable resources are estimated at about 32 MMboe. It reportedly is expected to yield about 24,000 boed at maximum production. 

SDX expands presence in “key growth region”

SDX Energy has increased its acreage in Morocco, with two new eight-year licenses—Moulay Bouchta Ouest and Lalla Mimouna Sud. Paul Welch, president and CEO of SDX Energy, said that Morocco remains “a key growth region for SDX going forward.” Accordingly, the company will serve as operator (75%) of the Moulay Bouchta Ouest exploration license, where it has agreed to reprocess more than 150 km of 2D seismic data, acquire 100 km² of new 3D seismic, and drill one exploration well. SDX will continue to serve as operator (75%) of the Lalla Mimouna Sud license, as well. The company has committed to acquiring 50 km² of 3D seismic and to drilling an exploration well.

BHP approves Atlantis Phase 3 project

BHP has approved funding for the Atlantis Phase 3 development project, in the deep waters of the U.S. Gulf of Mexico. The approval follows BP’s sanction of the project in January. Situated approximately 130 mi off the coast of Louisiana, the $1.3-billion project is a subsea tie-back of eight new production wells that will be drilled and completed to access infill resource opportunities. It reportedly will utilize existing infrastructure and could increase production by an estimated ~38,000 boed, gross, at its peak. BHP holds a 44% interest in Atlantis field, while BP holds 56%. Steve Pastor, BHP’s president of operations, petroleum, said, “The Atlantis Phase 3 project provides a competitive opportunity to deliver on our strategy to grow resources in Tier 1 conventional deepwater assets. The project will further expand the Atlantis field and will provide cost-efficient, near-term volumes.”