BP has plugged and abandoned exploration well Uba Deep 1 in the Berau PSC, located in the Bintuni Basin, likely in early March 2019, with results unreported. The well was drilled to a TD of around 3,370 m. The drilling targets likely included Permian sandstones of the Ainim Formation and Triassic quartzose sandstones of the Tipuma Formation, to explore the deeper reservoirs in the Ubadari field area. PTD for the well was approximately 3,400 m.  According to local media reports, the well had reached a depth of 1,188 m (3,900 feet) as of mid-December 2018. The company planned to complete drilling operations in late Q1 2019.  Uba Deep 1 was spudded in late November 2018 using âENSCO 106â J/U. The rig reached the location on or around 22 November 2018, after conducting development drilling activities in the Vorwata field.  Reportedly, the drilling cost was planned to be around USD 56 million. The operator was targeting pre-drill resources of 1.2 Tcfg to be potentially added to the Tangguh LNG project.  Uba Deep 1 could be a commitment well that was due to be drilled in the Berau PSC before 2019. Other potential candidates for future drilling in the block include the Inos and Kepe-Kepe leads.  The last exploration activity in the block was a 730 sq km OBN 3D seismic survey over the Tangguh Unitized area, which was completed around March 2018. The survey commenced in early August 2017 with BGPâs cable-layer, Dong Fang Kan Tan No. 2 and SeaBirdâs "Voyager Explorer" S/V. Axxis Geo SolutionsâÂ âNeptune Naiadâ was also utilized as additional source to assist in the project.    Around 20 February 2017, BP commenced a geotechnical survey over the Ubadari area, using the âMarinerâ MV. The vessel was scheduled to continue the survey over the Ofaweri area.    The Tangguh project is covered by three PSCs, namely the Berau, Muturi and Wiriagar PSCs, with partnership for the LNG project comprising of BP (40.22, operator), CNOOC (13.9%), MI Berau (a Mitsubishi/Inpex JV) (16.30%), Nippon Oil (12.23%), KG (JOGMEC/Mitsui/MI Berau/JX) (10.00%) and LNG Japan (Soijtz/Sumitomo) (7.35%). Production in August 2018 was around 1.3 Bcfg/d plus 2,700 bc/d.    The Ubadari field was discovered in 1997 by ARCO, with the Ubadari 1 wildcat. The well tested 45 MMcfg/d from the Middle Jurassic Roabiba Sandstones. Appraisal well Ubadari 2, drilled in 1998, about 7 km southwest of the discovery well, was dry.  Typical objective in the area is the Middle Jurassic Roabiba Sandstone, which is producing for the Tangguh Gas Project. The Ainim Formation flowed gas in the Mogoi Deep 1 discovery by BP in 1996 (onshore Muturi PSC), however the Tipuma Formation has yet to be proven as a reservoir.  BP announced the Final Investment Decision for the Tangguh Expansion Project on 1 July 2016. The expansion will consist of one new LNG processing train (Train 3) with capacity of 3.8 MMtpa of LNG, equal to each of the first two trains. This will raise the overall processing capacity of the Tangguh plant to 11.4 MMtpa. The upstream developments related to the expansion will include two new offshore platforms, 13 production wells, expanded LNG loading facility and other infrastructure. Construction works are expected to take three and a half to four years, starting in late 2016. The new facility could be online in 2020. As of May 2018, development drilling was underway at the Vorwata field, using the âENSCO 106â J/U. Following the completion of Uba Deep 1, the rig has likely been mobilized to the Wiriagar Deep field.    Background Information    BP was reported to have 3D seismic data reprocessing in Q1 2015. The operator intended to enhance seismic imaging covering Permian sequence and obtain better understanding of the subsurface fault-style definition within the Berau Bay area. Aside from the seismic reprocessing project, the operator also intended to conduct a detailed biostratigraphy study.     Tangguh LNG Project    The Tangguh LNG Project is based on 14.4 Tcf of proven and certified gas reserves from the Vorwata, Wiriagar Deep, Roabiba, Ofaweri, Wos, and Ubadari fields. BP may conduct new exploration to further raise the amount of recoverable reserves.    BPMigas, Indonesia's former upstream industry regulator, approved the Plan of Development (POD) for the Tangguh LNG Project in late July 2007.    The Vorwata field, in the Berau PSC, was put onstream in June 2009 and the first LNG cargo from the Tangguh project has been lifted on 6 July 2009. The cargo went to POSCO's LNG regasification terminal in Gwangyang, South Korea. The Vorwata field, which has 2P recoverable reserves of 8.33 Tcfg, was the initial source of gas for the Tangguh LNG project. Around 15 development wells were drilled in the field prior to production. The development drilling campaign commenced in late June 2007 and was completed in March 2009. Preliminary facilities include two unmanned platforms, subsea pipelines, two LNG processing trains, storage tanks, and an LNG tanker loading terminal. By the end of 2010, over 100 LNG cargos had been exported.    Tangguh Expansion    The Plan of Further Development (POFD) for the third LNG train was submitted in September 2012, after the finalization of reserves certification. Once submitted, the POFD was expected to be fast-tracked and approved within one month.    Ministry approval of the POFD for the new facility had been initially reported in late November 2012, while in-principle approval had been granted by authorities earlier that month. Tangguh Train 3 is part of a USD 12 billion multi-year investment plan by BP in Indonesia. Tangguh produced approximately 1.3 Bscfg/d and 3,500 bc/d in March 2013.    BP received formal approval for the third LNG train on 15 May 2013, as Indonesian Minister of Energy and Mineral Resources Jero Wacik signed the Plan of Further Development (POFD) during the 37th Indonesian Petroleum Association (IPA) Conference in Jakarta. The POFD also includes the drilling of 11 development wells and the execution of a joint study for the supply of 180 MMscfg/d to the local fertilizer industry. At least 40% of LNG production from the third train will be allocated to the domestic market, to state electricity firm PT PLN. In addition, up to 15 MMscf/d of piped gas produced from Tangguh will be allocated for the generation of 50 MW to support local developments, commencing from Train 3 startup date. Finally, to address short term needs of the local communities, BP will supply PLN with gas sufficient to generate 8 MW of power (4 MW in January 2013 and 4 MW in the following years). A Supply and Offtake Agreement for 4 MW of power was signed by BP and PLN in early December 2013. With this agreement, gas will be used to supply energy to private users and businesses in the Teluk Bintuni regency.    The Environmental Impact Assessment for the Tangguh Expansion was approved in August 2014. BP previously expected to reach the FID on the USD 12 billion in 2015, after the reception of further regulatory and partner approvals.    BP announced on 22 October 2014 the award of onshore FEED contracts for Train 3. Two consortia, led by local firms PT Tripatra and PT Rekayasa respectively, have been awarded the works that will cover the new LNG train, LNG jetty and associated infrastructure. The FEED had a planned duration of 12 months.
Uba Deep 1 (BP op. 48%, MI Berau (Mitsubishi/Inpex) 22,86%, Nippon Oil 17,14%, KG Berau 12%) in Berau PSC, off W. Papua, P&A early Mar â19, results n/a, target assumed Permian Black shale Ainim + Tipuma Triassic red bed fmâs.