Upstream major projects

A high-quality and material portfolio of projects, underpinning growth to 2020 and beyond

By 2020, we anticipate that our current suite of major projects will add 800 mboed of new production net to BP, which includes 500 mboed of new capacity planned to be on-line by end of 2017.
More than 90% of the 800 mboed is related to projects that have passed through the final investment decision and are complete or well under construction. The remainder of the 800 mboed is in the design stage and expected to progress into construction by early 2018. You can find out more information on our projects in the construction and design stages in the map below.
Looking beyond 2020, 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.

Quick links

Atoll Phase 1

Location
Egypt
Operator
BP
Partners
BP (100%)
Project type
Conventional gas
Start-up
2018
Gross production (peak)
~55 mboed (gross)
The Atoll field contains an estimated 1.5 trillion cubic feet of gas and 31 million barrels of condensates. The Atoll Phase 1 project is an early production scheme (EPS) involving the recompletion of an existing exploration well as a producing well, the drilling of two additional wells and the installation of the necessary tie-ins and facilities required to produce from the field. Onshore processing will be handled by the existing West Harbour gas processing facilities. Success of the Atoll Phase 1 project could lead to further investment in the Atoll Phase Two full field development.

Clair Ridge

Location
UK – North Sea
Operator
BP
Partners
BP (28.6%), Shell (28%), Conoco Phillips (24%), Chevron (19.4%)
Project type
Conventional oil
Start-up
2017
Gross production (peak)
~100 mboed (gross)
The Clair Ridge Project develops new resources from the giant Clair Field which is located approximately 40 miles west of Shetland and extends over an area of 85 square miles, in water depths of approximately 460 feet. The project scope includes provision of new production, accommodation and drilling facilities on two bridge-linked platforms. In addition, the project will deliver new development wells and brownfield modifications to the Clair Phase 1 and the Sullom Voe terminal. New subsea pipelines will be tied into the existing export systems. A LoSal unit will be provided to enhance oil recovery. Production capacity is expected to be 120,000 barrels per day, with provision for future subsea tiebacks.

Culzean

Location
UK – North Sea
Operator
Maersk
Partners
Maersk (50%), BP (32%), JX Nippon (18%)
Project type
High pressure gas
Start-up
2019
Gross production (peak)
~100 mboed (gross)
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 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 has been fabricated to drill six production wells and one produced water re-injection well.

In Amenas Compression

Location
Algeria
Operator
In Amenas joint venture
Partners
Sonatrach (8.2%), BP (45.9%), Statoil (45.9%)
Project type
Conventional gas
Start-up
2016
Gross production (peak)
~125 mboed (gross)
In Amenas is a wet-gas field, operated in partnership between Algerian state oil company Sonatrach, BP and Statoil. The field is approximately 810 miles from Algiers and about 40 miles west of the Libyan border. The project scope consists of two gas turbine compressor trains, a new slug-catcher, a produced water surge drum, associated utilities and control systems and tie-ins to the existing plant. It is expected to develop 216 million barrels of oil equivalent.

In Salah Southern Fields

Location
Algeria
Operator
In Salah joint venture
Partners
Sonatrach (35%), BP (33.15%), Statoil (31.85%)
Project type
Conventional gas
Start-up
Started February 2016
Gross production (peak)
~70 mboed (gross)
The In Salah Gas joint venture is located in central Algeria, approximately 690 miles from Algiers. The Southern Fields project involves the development of four dry gas fields: Gour Mahmoud, In Salah, Garet el Befinat and Hassi Moumene. The project scope consists of a new 500 million standard cubic feet per day gas dehydration central processing facility (CPF), 26 wells with gathering flow lines and export pipelines. Modifications to two existing CPFs in the Northern fields will add additional dehydration and compression capacity. Drilling of the 26 wells began in 2014 and is planned to continue until 2018.

Juniper

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
2017
Gross production (peak)
~95 mboed (gross)
The project includes the construction of a normally unmanned platform, together with corresponding subsea infrastructure. The Juniper facility will produce gas from the Corallita and Lantana fields located 50 miles off the south-east coast of Trinidad, in water depth of approximately 360 feet. The development is expected to include five subsea wells and to have a production capacity of approximately 590 million standard cubic feet per day. Gas from Juniper will flow to the Mahogany B hub via a new six mile flowline.

Oman Khazzan Phase 1

Location
Oman
Operator
BP
Partners
BP (60%), Oman Oil (40%)
Project type
Tight gas
Start-up
2017
Gross production (peak)
~200 mboed (gross)
This first phase of the onshore Khazzan field development plan involves drilling approximately 200 wells and constructing a two-train central processing facility. The project is expected to develop circa seven trillion standard cubic feet of gas and deliver plateau production of one billion standard cubic feet of gas per day and 25,000 barrels per day of gas condensate.

Persephone

Location
Australia
Operator
Woodside
Partners
BP (16.67%), BHP, Chevron, Shell, Woodside and Mitsubishi-Mitsui (16.67% each)
Project type
LNG
Start-up
2017
Gross production (peak)
~50 mboed (gross)
The Persephone gas field is located 85 miles north-west of Karratha, Western Australia, in a water depth of approximately 415 feet. The development concept is a two well subsea tieback to the existing North Rankin complex.

Point Thomson

Location
US - Alaska
Operator
ExxonMobil
Partners
ExxonMobil (62%), BP (32%), ConocoPhillips (5%), minors (1%)
Project type
Conventional gas
Start-up
Started April 2016
Gross production (peak)
~10 mboed (gross)
Point Thomson is a remote natural gas field located on Alaska’s North Slope, approximately 60 miles east of Prudhoe Bay. It is estimated to hold about 25% of known natural gas on the North Slope. The initial Production System (IPS) project is a reservoir cycling project where condensate will be removed from produced gas for export and the gas will be re-injected into the reservoir. Processing facilities include separation, compression and utilities plants, three new wells and gathering and condensate export lines. A pipeline is being installed with capacity of 70,000 barrels per day (for future field expansion) which will take condensate to the Trans-Alaska Pipeline.

Quad 204

Location
UK - North Sea
Operator
BP
Partners
BP (36.3%), Shell (54.0%), OMV UK Ltd (9.7%)
Project type
Conventional oil
Start-up
2017
Gross production (peak)
~120 mboed (gross)
The Quad 204 project will provide a new Floating Production, Storage and Offloading (FPSO) vessel, installed to the west of Shetland in water depths of approximately 1,300 feet, to extend and expand the recovery of oil from the Schiehallion field through to 2035. It includes an extension of the existing subsea system with 15 new flow lines, 21 new risers, 2 new dynamic controls umbilicals and 14 new wells. The project is designed to produce 130,000 barrels a day of oil and 220 million standard cubic feet of gas. The gas will be primarily used for artificial lift.

Shah Deniz Stage 2

Location
Azerbaijan
Operator
BP
Partners
BP (28.8%), SOCAR (16.7%), PETRONAS (15.5%), Lukoil (10%), NICO (10%), TPAO (19%)
Project type
Conventional gas
Start-up
2018
Gross production (peak)
~370 mboed (gross)
The Shah Deniz Stage 2 project entails several elements. These include drilling and completion of 26 subsea wells and construction of two bridge-linked offshore platforms. Onshore, new processing and compression facilities are being installed at the Sangachal terminal in Azerbaijan. An expansion of the existing South Caucasus Pipeline System and two new pipelines, the Trans Adriatic Pipeline (TAP, BP share 20%) and the Trans Anatolian Gas Pipeline (TANAP, BP Share 12%) will carry gas almost 2,200 miles - delivering energy to Georgia, Turkey, Bulgaria and Italy. Shah Deniz 2 plans to develop an additional 565 billion standard cubic feet per year of gas (at plateau) and has a designed condensate rate of 105,000 barrels per day.

Tangguh Expansion

Location
Indonesia
Operator
BP
Partners
BP (37.16%) 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%), Talisman Wiriagar Overseas Ltd (3.06%)
Project type
LNG
Start-up
2020
Gross production (peak)
~110 mboed (gross)
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.

Thunder Horse South Expansion

Location
US - Gulf of Mexico
Operator
BP
Partners
BP (75.0%), ExxonMobil (25.0%)
Project type
Deepwater oil
Start-up
2017
Gross production (peak)
~40 mboed (gross)
The Thunder Horse platform is located around 150 miles southeast of New Orleans in over 6,000 feet of water. The South Expansion Project comprises a new subsea drill centre located two miles from the Thunder Horse platform. Three new wells and an existing fourth well are expected to tie-into the new drill centre. Topsides scope is minimal as a result of maximising use of existing subsea infrastructure.

Thunder Horse Water Injection

Location
US - Gulf of Mexico
Operator
BP
Partners
BP (75.0%), ExxonMobil (25.0%)
Project type
Deepwater oil
Start-up
Started May 2016
Gross production (peak)
~25 mboed (gross)
The Thunder Horse platform is located around 150 miles southeast of New Orleans in over 6,000 feet of water. The water injection project is expected to develop an additional 65 million barrels of oil equivalent (gross). The project scope comprises refurbishment and replacement of existing topsides and subsea equipment, procurement and installation of new equipment and the drilling and completion of two water injection wells.  Water will be injected from the two new wells into the reservoir to increase pressure and enhance production.

Trinidad Onshore Compression

Location
Trinidad
Operator
Atlantic LNG
Partners
100% owned by BP Trinidad and Tobago which is owned by BP (70%) and Repsol (30%)
Project type
LNG
Start-up
2017
Gross production (peak)
~35 mboed (gross)
The Trinidad Onshore Compression project will increase production from low-pressure wells in BP Trinidad and Tobago LLC (bpTT)’s existing acreage in the Columbus Basin using an additional inlet compressor at the Point Fortin Atlantic LNG plant. Additional upgrades will be made to bpTT’s upstream facilities, as well as those of third parties to accommodate operations of the compressor.

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
Gross production (peak)
~75 mboed (gross)
The Western Flank B project will develop the Keast, Dockrell, Sculptor-Rankin, Lady Nora and Pemberton fields via a subsea tie-back to the Goodwyn A platform.

West Nile Delta - Taurus / Libra

Location
Egypt
Operator
BP
Partners
BP (82.75%), RWE Dea (17.25%)
Project type
Conventional gas
Start-up
2017
Gross production (peak)
~100 mboed (gross)
West Nile Delta includes two projects expected 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 Taurus / Libra project comprises a nine well subsea development tied-in offshore that will produce through BG’s Burullus facilities

West Nile Delta – Giza / Fayoum / Raven

Location
Egypt
Operator
BP
Partners
BP (82.75%), RWE Dea (17.25%)
Project type
Conventional gas
Start-up
2019
Gross production (peak)
~185 mboed (gross)
West Nile Delta includes two projects expected 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 Giza / Fayoum / Raven project includes 12 wells and will be developed as deepwater long distance tie backs to the shore, where the existing Rosetta plant will be modified for Giza / Fayoum and integrated with a new adjacent onshore plant for Raven.

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