Projects in construction
Atlantis Phase 3
Atlantis Phase 3 included the construction of a new subsea production system from eight new wells that are tied into the current Atlantis platform, 150 miles south of New Orleans in water depth of over 7,000 feet.
Location
|
US – Gulf of Mexico
|
Operator |
BP |
Partners |
BP (56%), BHP Billiton
(44%)
|
Project type |
Deepwater oil |
Start-up |
July 2020 |
Status |
Operating |
Peak annual average production, gross |
~40 mboed |
Peak annual average production, net |
~20 mboed
|
Azeri Central East (ACE)
The ACE project is a development which includes a new 48-slot production, drilling and quarters platform located mid-way between the existing Central Azeri and East Azeri platforms in approximately 460 feet of water depth. New infield pipelines will transfer oil and gas from the ACE platform to the existing ACG Phase 2 oil and gas export pipelines for transportation to the onshore Sangachal terminal.
Location
|
Azerbaijan
|
Operator |
BP |
Partners |
BP (30.37%), SOCAR (25.00%), Chevron (9.57%), INPEX (9.31%), Equinor (7.27%), ExxonMobil (6.79%), TP (5.73%), ITOCHU (3.65%), OVL (2.31%) |
Project type |
Conventional oil |
Start-up |
2023 |
Peak annual average production, gross |
~ 80 mboed |
Peak annual average production, net |
~ 10 mboed |
Cassia Compression
The project will involve construction of a new platform with throughput capacity of 1.2 billion standard cubic feet of gas a day. Cassia C will be located ~35 miles off the south-east coast of Trinidad. Gas production from the Greater Cassia Area will be routed to Cassia C for compression before being exported via the adjacent existing Cassia B platform.
Location
|
Trinidad |
Operator |
BP |
Partners |
100% owned by BP Trinidad and Tobago which is owned by BP (70%) and Repsol (30%)
|
Project type |
LNG |
Start-up |
2022 |
Peak annual average production, gross |
~55 mboed |
Peak annual average production, net |
~55 mboed
|
Herschel
Herschel Development utilizes existing infrastructure to maximize value in the prolific Na Kika Catchment Area, offshore Gulf of Mexico in Mississippi Canyon block 520. Herschel is a three-well tie-in to Na Kika driven by the success of the H-5 ILX well, inclusive of H-5, Nebula, and Titania. Two M55 wells will tie-in to an extension of the Manuel high pressure flowline and one M60 well will tie-in to the existing South Oil Loop.
Location
|
US - Gulf of Mexico
|
Operator |
BP |
Partners |
Phase 1 BP (100%); Phase 2 BP (50%), Shell (50%) |
Project type |
Deepwater oil |
Start-up |
2022 |
Peak annual average production, gross |
~25 mboed |
Peak annual average production, net |
~10 mboed
|
KG D6 MJ
The MJ project is the third phase of Block KG D6 development off the east coast of India. Together three projects are expected to develop a total of about 3 trillion cubic feet of discovered gas resources. MJ field is located approximately 20 miles offshore and in 2,300-3,600 feet water depth. Seven subsea wells will tie-back to a new Floating Production Storage and Offloading (FPSO) vessel to process and separate liquids. Gas will be exported to the onshore terminal through an existing 24-inch pipeline.
Location
|
India |
Operator |
Reliance |
Partners |
Reliance (66.67%), BP (33.33%)
|
Project type |
Conventional gas |
Start-up |
2022 |
Peak annual average production, gross |
~90 mboed |
Peak annual average production, net |
~30 mboed |
KG D6 R Series
The R-Series project is the first of three projects in Block KG D6 off the east coast of India. The gas field is located approximately 45 miles offshore in water-depths of more than 6,500 feet. The R-Series project was developed as a six well subsea tie back to the existing control and riser platform off Block KG D6.
Location
|
India |
Operator |
Reliance |
Partners |
Reliance (66.67%), BP (33.33%) |
Project type |
Dry gas |
Start-up |
Operating
|
Peak annual average production, gross |
~90 mboed |
Peak annual average production, net |
~30 mboed
|
KG D6 Satellites
The Satellites project is the second of three projects in Block KG D6 off the east coast of India. It is a dry gas development and comprises four discoveries in 4,300 - 6,200 feet water depth. It will be developed as a five well subsea tie back to the existing control and riser platform off Block KG D6. KG D6 integrated development is aimed at delivering one billion standard cubic feet gross production a day by 2022 and supports country agenda by increasing domestic gas supply.
Location
|
India |
Operator |
Reliance |
Partners |
Reliance (66.67%), BP (33.33%) |
Project type |
Dry gas |
Start-up |
2021 |
Peak annual average production, gross |
~45 mboed |
Peak annual average production, net |
~15 mboed
|
Khazzan Phase 2 (Ghazeer)
The second phase of the onshore Khazzan field development included drilling approximately 100 wells, construction of a third train, a new export pipeline and tie-in to the existing Phase 1 facilities. The second phase (Ghazeer) is expected to deliver an additional 0.5bcf/d and over 35,000 barrels a day of condensate, bringing total Khazzan gas production to ~ 1.5bcf/d.
Location
|
Oman |
Operator |
BP |
Partners |
BP (60%), Oman Oil (30%), Petronas (10%)
|
Project type |
Tight gas |
Start-up |
October 2020 |
Peak annual average production, gross |
~115 mboed |
Peak annual average production, net |
~70 mboed
|
Mad Dog Phase 2
The Mad Dog Phase 2 project includes a new semi-submersible floating production platform with the capacity to produce up to 140,000 gross barrels of crude oil per day from 14 production wells and inject up to 140,000 barrels of water per day using a LoSal system to enhance oil recovery. The new platform will be moored approximately six miles southwest of the existing Mad Dog platform, which is located in 4,500 feet of water about 190 miles south of New Orleans.
Location
|
US - Gulf of Mexico |
Operator |
BP |
Partners |
BP (60.5%), BHP Billiton (23.9%), Chevron (15.6%) |
Project type |
Deepwater oil |
Start-up |
2022 |
Peak annual average production, gross |
~120 mboed |
Peak annual average production, net |
~65 mboed
|
Manuel
Manuel is an infrastructure-led (ILX) opportunity at Na Kika area. The development is a two well tie-back to Na Kika via a single riser and flowline.
Location
|
US - Gulf of Mexico |
Operator |
BP |
Partners |
BP (50%), Shell (50%)
|
Project type |
Deepwater oil |
Start-up |
2021 |
Peak annual average production, gross |
~15 mboed |
Peak annual average production, net |
~5 mboed
|
Matapal
The Matapal project will develop the gas resources discovered by BPTT in 2017 with the Savannah exploration well. The project will be a three-well subsea tie-back to the existing Juniper platform. The project production capacity will be 400 million standard cubic feet of gas a day.
Location
|
Trinidad |
Operator |
BP |
Partners |
100 % owned by BP Trinidad and Tobago which is owned by BP (70%) and Repsol (30%) |
Project type |
LNG |
Start-up |
2022 |
Peak annual average production, gross |
~70 mboed |
Peak annual average production, net |
~70 mboed
|
Platina
Platina is planned to be the first subsea tie-back to the existing Greater Plutonio floating production, storage and offloading vessel (FPSO) which started in 2007. Platina will be BP’s first new operated development in Angola since the PSVM project in Block 31 began production in 2013. The Platina field is in deepwater Block 18, discovered in 1999 and in water depths of approximately 1,300 metres.
Location
|
Angola |
Operator |
BP |
Partners |
BP (50%), Sonangol Sinopec International Limited (SSI) (50%) |
Project type |
Deepwater oil |
Start-up |
2022 |
Peak annual average production, gross |
~25 mboed |
Peak annual average production, net |
~10 mboed |
Project stage |
Construction |
Seagull
Seagull is a high pressure, high temperature development located in the Central North Sea approximately 10 miles south of the ETAP Central Processing Facility (CPF). Seagull will be tied back to the ETAP CPF partially utilising existing subsea infrastructure. Gas from the development will come onshore at the CATS processing terminal at Teesside, while oil will come onshore through the Forties Pipeline System to the Kinneil Terminal, Grangemouth.
Location
|
North Sea |
Operator |
Neptune Energy |
Partners |
BP (50%), Neptune Energy (35%), JAPEX (15%)
|
Project type |
Conventional oil |
Start up |
2023 |
Peak annual average production, gross |
~30 mboed |
Peak annual average production, net |
~15 mboed |
Tangguh Expansion
The Tangguh Expansion project, located in the Papua Barat Province of Indonesia, will add a third LNG process train (Train 3) and 3.8 million tons per annum (mtpa) of production capacity to the existing facility, bringing total plant capacity to 11.4 mtpa. The project also includes two offshore platforms, 13 new production wells, an expanded LNG loading facility, and supporting infrastructure.
Location
|
Indonesia |
Operator |
BP |
Partners |
BP (40.22%) MI Berau B.V. (16.30%), CNOOC Muturi Ltd (13.90%), Nippon Oil Exploration (Berau) Ltd (12.23%), KG Berau Petroleum Ltd (8.60%), KG Wiriagar Overseas Ltd (1.40%), Indonesia Natural Gas Resources Muturi Inc. (7.35%) |
Project type |
LNG |
Start-up |
2022 |
Peak annual average production, gross |
~115 mboed |
Peak annual average production, net |
~40 mboed
|
Thunder Horse South Expansion Phase 2
Thunder Horse South Expansion Phase 2 will further boost output of the existing Thunder Horse field, one of the largest oil fields in the Gulf of Mexico. This project will add two new subsea production units roughly two miles to the south of the existing Thunder Horse platform with two new production wells in the near term. Eventually eight wells will be drilled as part of the overall development.
Location
|
US - Gulf of Mexico |
Operator |
BP |
Partners |
BP (75%), ExxonMobil (25%)
|
Project type |
Deepwater oil |
Start-up |
2021 |
Peak annual average production, gross |
~50 mboed |
Peak annual average production, net |
~30 mboed |
Tortue Phase 1
Tortue Phase 1 is the first phase of the Greater Tortue Ahmeyim project which will produce gas from an ultra-deepwater subsea system and mid-water floating production, storage and offloading (FPSO) vessel. The gas will be transferred to a floating liquefied natural gas (FLNG) facility at an innovative nearshore hub located on the Mauritania and Senegal maritime border. The FLNG facility is designed to provide circa 2.5 million tonnes of LNG per annum of nameplate capacity, with the total gas resources in the field estimated to be around 15 trillion cubic feet.
Location
|
Mauritania and Senegal |
Operator |
BP |
Partners |
BP (56%), Kosmos (27%), PETROSEN (10%*), SMHPM (7%)
|
Project type |
LNG |
Start-up |
2023 |
Peak annual average production, gross |
~70 mboed |
Peak annual average production, net |
~35 mboed
|
Vorlich
Vorlich, a two-well development approximately 150 miles east of Aberdeen, is tied back to the Ithaca Energy-operated FPF-1 floating production facility, which lies at the centre of Greater Stella Area production hub. Through an innovative partnership, bp acted as operator during the development phase, drilling the wells and installing the wellheads. Ithaca Energy, whose FPF-1 floating production facility will process Vorlich's hydrocarbons, installed subsea infrastructure and executed the modifications on FPF-1. Shortly before production came online, Ithaca assumed operatorship of the field from bp.
Location
|
North Sea |
Operator |
Ithaca
|
Partners |
BP (66%), Ithaca (34%) |
Project type |
Conventional oil |
Start-up |
Operating |
Peak annual average production, gross |
~20 mboed |
Peak annual average production, net |
~15 mboed
|
West Nile Delta - Raven
Raven is the third stage of the West Nile Delta development (following Taurus / Libra and Giza / Fayoum) from two BP-operated offshore concession blocks, North Alexandria and West Mediterranean Deepwater. The Raven project includes eight wells and will be developed as a deepwater long distance tie back to shore, where the new Raven onshore plant is being built, immediately adjacent to the Giza / Fayoum facilities.
Location
|
Egypt |
Operator |
BP |
Partners |
BP (82.75%), Wintershall DEA (17.25%) |
Project type |
Conventional gas |
Start-up |
2020 |
Peak annual average production, gross |
~165 mboed |
Peak annual average production, net |
~140 mboed
|
Zinia Phase 2
Zinia 2 is the first of several possible short-cycle developments on Block 17 that will unlock its full potential by connecting satellite reservoirs to the existing floating storage, production and offloading (FPSO) units. Zinia 2 comprises nine wells in water depths ranging from 2,000 to 4,000 feet, tied back to the Pazflor FPSO.
Location |
Angola |
Operator |
Total |
Partners |
BP (15.84%), TOTAL (38%), Equinor (22.16%), ExxonMobil (19%), Sonangol (5%) |
Project type |
Deepwater oil |
Start-up |
2021 |
Peak annual average production, gross |
~35 mboed |
Peak annual average production, net |
~5 mboed
|
Projects in design
Location
|
UK - North Sea |
Operator |
BP |
Partners |
BP (45.1%), Shell (28%), Chrysaor (7.5%), Chevron (19.4%)
|
Project type |
Conventional oil |
Start-up |
Beyond 2021 |
Project stage |
Design |
Location
|
Trinidad |
Operator |
BP |
Partners |
100% owned by BP Trinidad and Tobago which is owned by BP (70%) and Repsol (30%)
|
Project type |
LNG |
Start-up |
Beyond 2021 |
Project stage |
Design |
Murlach (previously known as Skua)
Location
|
North Sea |
Operator |
BP |
Partners |
BP (80%), Zennor (20%)
|
Project type |
Conventional oil |
Start-up |
Beyond 2021 |
Project stage |
Design |
Location
|
Angola |
Operator |
BP |
Partners |
Sonagol (45%), BP (26.67%), Statoil (13.33%), SSI (15%) |
Project type |
Deepwater oil |
Start-up |
Beyond 2021 |
Project stage |
Design |
Location
|
Mauritania and Senegal |
Operator |
BP |
Partners |
BP (56%), Kosmos (27%), PETROSEN (10%*), SMHPM (7%)
|
Project type |
LNG |
Start-up |
Beyond 2021 |
Project stage |
Design |