Upstream major projects

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

By 2021, we anticipate that we will add 900 mboed of new production net to BP from our current suite of major projects 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 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.

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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
LNG
Start-up
2019
Peak annual average production, gross
~65 mboed
Peak annual average production, net
~65 mboed

The Angelin project features the construction of a new platform 40 miles off the southeast coast of Trinidad in water-depth of approximately 215 feet. The development will include four wells and will have a production capacity of approximately 600 million standard cubic feet of gas per day. 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
Maersk
Partners
Maersk (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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KGD6 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 KGD6 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 tieback to the existing control and riser platform off Block KGD6. The project is expected to produce up to 425 million standard cubic feet of gas a day.

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 Khazzan Phase 2 

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. Khazzan field total production is expected to rise to 1.5bcf/d when the second phase is fully onstream.

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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
~125 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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Thunder Horse Northwest Expansion

Location
US - Gulf of Mexico
Operator
BP
Partners
BP (75%), ExxonMobil (25%)
Project type
Deepwater oil
Start-up
2019
Peak annual average production, gross
~25 mboed
Peak annual average production, net
~15 mboed

The Thunder Horse platform is located around 150 miles southeast of New Orleans in over 6,000 feet of water. The Northwest Expansion Project comprises a new two-slot manifold, subsea controls and chemical distribution, and tie-in of two new development wells.

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Western Flank B

Location
Australia
Operator
Woodside
Partners
BP (16.67%), BHP, Chevron, Shell, Woodside and Mitsubishi-Mitsui (16.67% each)
Project type
LNG
Start-up
2019
Peak annual average production, gross
~75 mboed
Peak annual average production, net
~10 mboed

The Western Flank B project will develop the Keast, Dockrell, Sculptor-Rankin, Lady Nora and Pemberton fields via an eight subsea well tie-back to the Goodwyn A platform.

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