Upstream major projects

A diversified portfolio of projects, underpinning high-quality growth to 2021 and beyond

By 2021, we expect to add 900 mboed of new production net to BP from our major projects compared with our 2015 base portfolio, the majority of which have passed through the final investment decision and are complete or well under construction. You can find more information on our projects in the construction and design stages in the map below.

Looking beyond 2021, we have a deep and diverse hopper of projects that are currently under appraisal. Our focus here is to ensure we maximise the business opportunity and select the optimum project concept before we move it forward into design. We do not expect to progress all of the projects - only the best.

In addition to the map above we provide details of our construction phase projects below.  Also provided are links to pages detailing projects in operation or scheduled for start-up in 2018. 

Projects under construction

Completed

Alligin

Location
North Sea
Operator
BP
Partners
BP (50%), Shell (50%)
Project type
Conventional oil
Start-up
2020
Peak annual average production, gross
~10 mboed
Peak annual average production, net
~5 mboed

Alligin is located 87 miles west of Shetland in a water depth of approximately 1,600 feet. The Alligin development will consist of two wells, which will be tied-back into the existing Schiehallion and Loyal subsea infrastructure, utilizing the processing and export facilities of the Glenn Lyon FPSO.

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Angelin

Location
Trinidad
Operator
BP
Partners
100% owned by BP Trinidad and Tobago which is owned by BP (70%) and Repsol (30%)
Project type
Conventional gas
Start-up
2019
Peak annual average production, gross
~50 mboed
Peak annual average production, net
~50 mboed

The Angelin project develops four wells and features the construction of a new platform 40 miles off the southeast coast of Trinidad in water-depth of approximately 215 feet. Gas from Angelin will flow to the Serrette platform hub via a new 13-mile pipeline.

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Culzean

Location
UK – North Sea
Operator
Total
Partners
Total (50%), BP (32%), JX Nippon (18%)
Project type
High pressure gas
Start-up
2019
Peak annual average production, gross
~100 mboed
Peak annual average production, net
~30 mboed

Culzean is a 1.2 Tcf High Pressure High Temperature (HPHT) lean gas condensate field located approximately 140 miles east of Aberdeen in Block 22/25a of the Central North Sea in water depths of 300 feet. The project scope includes a stand-alone three bridge-linked platform development with dry gas export via the Central Area Transmission System (CATS) and liquids export via a new-build Floating Storage and Offloading tanker (FSO). A new Heavy Duty Jack Up (HDJU) rig, the Maersk Highlander, has commenced drilling of the six production wells and one produced water re-injection well.  

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KG D6 R-Series

Location
India
Operator
Reliance
Partners
Reliance (60%), BP (30%), Niko (10%)
Project type
Dry gas
Start-up
2020
Peak annual average production, gross
~90 mboed
Peak annual average production, net
~25 mboed

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 will be developed as a six well subsea tie back to the existing control and riser platform off Block KG D6.

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KG D6 Satellites

Location
India
Operator
Reliance
Partners
Reliance (60%), BP (30%), Niko (10%)
Project type
Dry gas
Start-up
2021
Peak annual average production, gross
~45 mboed
Peak annual average production, net
~15 mboed

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.

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 Khazzan Phase 2 (Ghazeer)

Location
Oman
Operator
BP
Partners
BP (60%), Oman Oil (40%)
Project type
Tight gas
Start-up
2021
Peak annual average production, gross
~115 mboed
Peak annual average production, net
~70 mboed

The second phase of the onshore Khazzan field development involves 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 15,000 barrels a day of condensate, bringing total Khazzan gas production to ~ 1.5bcf/d.  

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Mad Dog Phase 2 

Location
US - Gulf of Mexico
Operator
BP
Partners
BP (60.5%), BHP Billiton (23.9%), Chevron (15.6%)
Project type
Deepwater oil
Start-up
2021
Peak annual average production, gross
~120 mboed
Peak annual average production, net
~65 mboed

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.

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Tangguh Expansion

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
2020
Peak annual average production, gross
~115 mboed
Peak annual average production, net
~40 mboed

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.

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Vorlich

Location
North Sea
Operator
BP
Partners
BP (66%), Ithaca (34%)
Project type
Conventional oil
Start-up
2020
Peak annual average production, gross
~20 mboed
Peak annual average production, net
~15 mboed

Vorlich, a two-well development approximately 150 miles east of Aberdeen, will be tied back to the Ithaca Energy-operated FPF-1 floating production facility, which lies at the centre of Greater Stella Area production hub.

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West Nile Delta - Raven

Location
Egypt
Operator
BP
Partners
BP (82.75%), DEA Deutsche Erdoel AG (17.25%)
Project type
Conventional gas
Start-up
2019
Peak annual average production, gross
~160 mboed
Peak annual average production, net
~130 mboed

Raven is the third phase of the West Nile Delta development (following Taurus / Libra and Giza / Fayoum) to develop 5 trillion cubic feet of gas resources and 55 million barrels of condensates from two BP-operated offshore concession blocks, North Alexandria and West Mediterranean Deepwater. The Raven project includes 8 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.

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