| Key Facts |
Employees: 2.286
Total Average Daily Production in 2007: 166 MBOE
- Oil: 48 MBD
- Gas: 673 MMCFD
- NGL: 6 MBD
Major Office Locations: Aberdeen, London, Warwick |
Exploration and Production ConocoPhillips’ upstream involvement in the U.K. began in discovered, and first gas was produced in 1972. Since then, the U.K. September 1964 when acreage was awarded to the company in the portfolio has grown to include additional operated assets, as well as first U.K. licensing round. In 1968, the Viking gas field was interests in nonoperated assets.
Greater Britannia
Britannia
Operator: Britannia Operator Limited, a 50/50 joint venture between ConocoPhillips and Chevron, ConocoPhillips (58.7%), Chevron (32.3%) Co-venturer: BP (9.0%)
Britannia is one of the largest natural gas and condensate fields in the North Sea. Commercial production began in August 1998. Condensate is delivered through the Forties Pipeline to the oil stabi¬lization and processing plant Kerse of Kinneil near the Grangemouth refinery in Scotland, and its gas is transported through Britannia’s own gas line to St. Fergus, Scotland. Net production in 2007 was 8 MBD of crude oil, 252 MMCFD of natural gas and 2 MBD of NGL.
Britannia Satellites (BritSats)
Brodgar
Operator: ConocoPhillips (75.0%) Co-venturer: Chevron (25.0%)
Callanish
Operator: ConocoPhillips (83.5%) Co-venturer: Chevron (16.5%)
Brodgar, discovered in 1985, is located in Block 21/3. Callanish, discovered in 1999, is located in Blocks 15/29b and 21/4a. Both fields were developed simultaneously as satellites of the already producing Britannia field. Production started in June 2008. The fields produce via subsea manifolds and two new pipelines linked to the Britannia platform.
Central North Sea
J-Block
Judy/Joanne
Operator: ConocoPhillips (36.5%) Co-venturers: ENI U.K. Limited (33.0%), BG (30.5%)
Jade
Operator: ConocoPhillips (32.5%)
Co-venturers: BG (35.0%), Chevron (19.9%), ENI U.K. Limited
(7.0%), OMV (5.6%)
Commercial oil production and gas sales from Judy/Joanne began in 1997. Gas processed on the Judy platform is transported through the CATS Pipeline, and liquids are transported to Teesside through the Norpipe system. The Jade field came on line in 2002 and consists of a normally unmanned platform tied back to Judy. Together, the J-Block fields’ net production in 2007 was 12 MBD of crude oil, 94 MMCFD of natural gas and 3 MBD of NGL.
MacCulloch
Operator: ConocoPhillips (40.0%) Field operations are subcontracted to North Sea Production Company (NSPC) Co-venturers: ENI U.K. Limited (40.0%), Talisman Energy (6.0%), Noble Energy (14.0%)
The MacCulloch field is located in Block 15/24b. It began production in August 1997. The wells are tied back to two subsea manifolds and then to the NSPC-owned floating production storage offtake. Oil and gas are delivered to the Piper B platform by pipeline, and from there oil travels to the Flotta terminal. Gas is transported via the Frigg Pipeline to the St. Fergus gas terminal. Net production in 2007 was 5 MBD of crude oil.
Southern North Sea
ConocoPhillips has various interests in producing gas fields in the Rotliegendes and Carboniferous areas of the Southern North Sea. Net production in 2007 averaged 1 MBD of crude oil and 276 MMCFD of natural gas.
Southern North Sea – Rotliegendes
LOGGS
Operator: ConocoPhillips (50.0%) Co-venturers: BP Exploration Beta Ltd. (20.0%), BP Exploration Alpha Ltd. (30.0%)
The Lincolnshire Offshore Gas Gathering System (LOGGS) complex started operating in 1988. It acts as a hub, receiving gas from the V-fields Vampire, Viscount, Valkyrie, Saturn area (Saturn, Mimas and Tethys); the Jupiter area gas fields (Ganymede, Sinope, Callisto, Europa and NW Bell); as well as the third-party fields Ann, Alison, Annabel, Audrey and Anglia. Gas is comingled at LOGGS and forwarded to the Theddlethorpe gas terminal in Lincolnshire, England, via a 36-inch pipeline.
V-fields
Operator: ConocoPhillips (50.0%-61.13%) Co-venturers: Various BP group companies
V-fields comprise four separate gas accumulations (North Valiant, South Valiant, Vanguard and Vulcan) and are produced via normally unmanned production platforms. All the V-fields’ gas is received and transported by LOGGS to the Theddlethorpe gas terminal.
Saturn Unit Area Saturn
Operator: ConocoPhillips (42.9%) Co-venturers: RWE Dea U.K. Exploration Limited (35.1%), Venture North Sea Gas Limited (22.0%)
Mimas
Operator: ConocoPhillips (35.0%) Co-venturers: RWE Dea U.K. Exploration Limited (50.0%), Venture North Sea Gas Limited (15.0%)
Tethys
Operator: ConocoPhillips (25.0%) Co-venturer: RWE Dea U.K. Exploration Limited (75.0%)
The Saturn Unit Area lies in Blocks 48/10a and 48/10b and consists of gas accumulations Atlas, Hyperion and Rhea. First production began in September 2005, and it is delivered into the LOGGS infra¬structure. Mimas in Block 48/09a and Tethys in Block 49/11b are satellite developments. Mimas and Tethys came on line in 2007.
Viking Transportation System (VTS)
Operator: ConocoPhillips (50%) Co-venturer: BP Exploration (50%)
The facilities comprising the VTS offtake system were installed in the early 1970s and include a 24-inch, 11 km infield pipeline, the Viking AR riser platform, and a 28-inch, 138 km export pipeline. The pipeline transports production from the Victor and Viking fields to the Theddlethorpe gas terminal. The pipeline will be replaced beginning in 2008 and operational in 2009. The scope of the VTS Pipeline Replacement Project includes the installation, platform tie-ins and commissioning of a new 16-inch diameter, 27.3 km gas export pipeline between the ConocoPhillips Operated Viking B and LOGGS offshore installations in the U.K. SNS.
Victor
Operator: ConocoPhillips (20.0%) Co-venturers: Various
Victor is an unmanned platform and subsea wellhead structure located in Blocks 49/17 and 49/2.
Viking
Operator: ConocoPhillips (50.0%) Co-venturers: BP Exploration (50.0%)
Viking is situated in Blocks 49/12, 49/16 and 49/17. First production from Viking began in 1972. Today, Viking consists of seven normally unmanned platforms, plus one manned main complex, Viking B, and the associated outlying Vixen subsea satellite.
Southern North Sea – Carboniferous
Caister Murdoch System
The Caister Murdoch System (CMS) is collectively the Murdoch complex, the Caister satellite platform plus the gas trunkline to the Theddlethorpe gas terminal. CMS acts as a hub for the Murdoch, Caister, Boulton, Munro, CMSIII (Hawksley, McAdam, Murdoch K, Boulton H and Watt) and Kelvin fields and also provides third-party transportation.
Murdoch Complex
Operator: ConocoPhillips (46.75%) Co-venturers: Gaz de France Britain Limited (16.25%); Tullow Oil SK Limited (17.0%), E.ON Ruhrgas U.K. North Sea Ltd. (20.0%)
The Murdoch platform complex consists of three bridge-linked plat¬forms located in Block 44/22 of the U.K. sector of the North Sea.
Murdoch field
Operator: ConocoPhillips (54.5%) Co-venturers: Gaz de France Britain Limited (11.5%), Tullow Oil SK Limited (34.0%)
The Murdoch field is produced via one of the Murdoch complex platforms.
Caister
Operator: ConocoPhillips (39.0%) Co-venturers: E.ON Ruhrgas U.K. North Sea Ltd. (40.0%), Gaz de France Britain Limited (21.0%)
The Caister unmanned wellhead platform is in Block 44/23a, which is connected by subsea flowline to Murdoch.
Boulton
Operator: ConocoPhillips (46.0%) Co-venturers: Gaz de France Britain Limited (44.5%), Tullow Oil SK Limited (9.5%)
The Boulton platform located in Block 44/21a is operated remotely from the Murdoch complex.
CMSIII
Operator: ConocoPhillips (59.5%) Co-venturers: Gaz de France Britain Limited (26.4%), Tullow Oil SK Limited (14.1%)
CMSIII consists of five subsea satellites (Hawksley, McAdam, Murdoch K, Boulton H and Watt).
Munro
Operator: ConocoPhillips (46.0%) Co-venturers: Gaz de France Britain Limited (39.0%), Tullow Oil SK Limited (15.0%)
Munro is located in Block 44/17b of the U.K. Southern North Sea. First production was achieved in 2005.
Kelvin
Operator: ConocoPhillips (50.0%) Co-venturers: Gaz de France Britain Limited (27.5%), Tullow Oil SK Limited (22.5%)
The Kelvin field lies in Blocks 44/18b and 44/23b eight miles north¬east of the Murdoch platform. First production was achieved in 2007.
Harrison
Operator: ConocoPhillips (50.0%) Co-venturers: Tullow Oil SK Limited (22.5%), Gaz de France Britain Limited (27.5%)
Successful discovery of the Harrison prospect was confirmed in 2007. Development plans are being considered.
Nonoperated Assets
Alba
Operator: Chevron (23.37%) Co-venturers: ConocoPhillips (23.43%), Statoil U.K. (17.0%), BP (13.3%), Others (22.9%)
Alba is located in Block 16/26. It consists of a platform with two subsea developments. Production is exported to a floating storage unit and then is offloaded to a shuttle tanker. Net production in 2007 was 10 MBD of crude oil.
Clair
Operator: BP (28.6%) Co-venturers: ConocoPhillips (24.0%), Chevron (19.4%),
Enterprise Oil (18.7%), Hess (9.3%)
The Clair field extends over 54,300 acres across five blocks in the west of Shetland area. Phase I development came onstream in February 2005 and is producing at a net peak rate of 15 MBOED. The phase I development includes a conventional platform with produc¬tion and process topsides supported by a fixed-steel jacket. Oil production is delivered through a dedicated trunk line to the Sullom Voe terminal, and natural gas is carried through a spur line into the Magnus enhanced oil recovery trunk line.
Nicol
Operator: Oilexco (70.0%) Co-venturers: ConocoPhillips (18.0%), ENI (12.0%)
First production was achieved from Nicol in 2007. Oil is produced through a subsea well tied back to a subsea multiport manifold and multiphase booster pump at the Brenda field. Oil then passes through the Balmoral floating production vessel where it is processed and transported through the Forties Pipeline system. Both ConocoPhillips and ENI will participate in the production up to a pre-defined cap before assigning their equity to Oilexco. During this period, Oilexco pays all operating costs and development capex. ConocoPhillips pays license fee and tariffs beyond Brenda.
East Irish Sea
ConocoPhillips’ interests in the East Irish Sea include the Rivers terminal at Barrow-in-Furness and five operated gas fields. Net production in 2007 averaged 36 MMCFD of natural gas.
Millom and Dalton
Operator: HRL Co-venturer: ConocoPhillips (100%)
Sweet natural gas is produced from the Millom and Dalton fields through a platform and two subsea manifolds. The gas is fed through to the Morecambe Bay North terminal where it is comingled with HRL’s gas, transported to the Barrow terminal and sold into the United Kingdom spot market.
Calder
Operator: HRL Co-venturer: ConocoPhillips (100%)
Calder has been developed with an unmanned platform and three development wells. The field produces sour gas. It feeds to a producing platform, then through a pipeline to the Rivers terminal, which provides compression, hydrogen sulphide removal and metering.
Darwen and Crossens
Operator: HRL Co-venturer: ConocoPhillips (100%)
The additional sour gas producers of Darwen and Crossens are currently being considered for development. If developed, they also will feed into the Rivers terminal.
United Kingdom FacilitiesRivers Gas Terminal
Operator: HRL Co-venturer: ConocoPhillips (100%)
The Rivers terminal, located in Barrow-in-Furness, is capable of handling 145 MMCFD of natural gas. Wet sour gas enters the terminal, liquids are separated and hydrogen sulphide is removed. Clean liquid and sweet gas are sent to the Morecambe Bay North terminal, H2S-rich solvent is regenerated and is converted to 96 percent pure sulphuric acid.
Teesside Oil Terminal
Operator: ConocoPhillips (29.3%) Co-venturers: Total Holdings Europe (32.9%), Statoil U.K. Limited (22.0%), ENI S.p.A. (10.3%), Norsk Hydro (U.K.) Limited (5.3%), Paris Orleans S.A. (0.2%)
Completed in 1975, this facility is a crude oil reception, processing, storage and transshipment installation. The terminal also fractionates natural gas liquids into ethane, propane and butane. Operations comprise both processing and tanker loading facilities covering a 307¬acre site at Seal Sands near Middlesbrough. Crude oil and NGLs from ConocoPhillips’ J-Block and Greater Ekofisk area fields are delivered to Teesside.
Theddlethorpe Gas Terminal
Operator: ConocoPhillips (50.0%) Co-venturer: BP (50.0%)
Located in Lincolnshire, the Theddlethorpe gas terminal receives and processes natural gas produced through LOGGS, CMS and VTS, as well as third-party volumes from the Pickerill field offshore and the Saltfleetby field onshore. The facility’s gross capacity is 1.6 BCFD of natural gas.
Interconnector Pipeline
Operator: Interconnector (U.K.) Ltd. Co-venturers: E.ON Ruhrgas (23.59%), ConocoPhillips (10.0%), Others (66.41%)
Up to 700 BCF per year of natural gas can be transported through this 145-mile, 40-inch-diameter subsea pipeline running from Bacton in the United Kingdom to a reception terminal at Zeebrugge in Belgium. The pipeline has the capability to reverse flow and has been fully operational since October 1998. ConocoPhillips’ equity share allows it to ship approximately 200 MMCFD of natural gas to markets in continental Europe, and the company’s reverse-flow rights provide 85 MMCFD of natural gas import capability to the United Kingdom.
Refining ConocoPhillips’ wholly owned Humber refinery is located in North Lincolnshire, United Kingdom, and has a crude oil processing capacity of 221 MBD. Crude oil processed at the refinery is supplied primarily from the North Sea and includes light, low-sulfur and acidic crude oils.
Humber is one of the most sophisticated refineries in Europe. It is a fully integrated refinery that produces a high proportion of trans¬portation fuels, such as gasoline and diesel fuel. Humber’s fluid catalytic cracking unit/thermal cracking/coking configuration means that substantial volumes of other feedstocks, such as low-sulfur fuel oil and vacuum gas oil, are processed alongside crude oil to fully utilize Humber’s cracking capability.
The refinery’s location on the east coast of England provides for cost-effective North Sea crude imports and product exports to European and U.S. markets.
The refinery also has two coking units with associated calcining plants that upgrade the heavy bottoms and imported feedstocks into light-oil products and high-value graphite and anode petroleum cokes.
Humber is the only coking refinery in the United Kingdom and is the world’s largest producer of specialty graphite cokes and the largest anode coke producer in Europe.
Approximately 70 percent of the light oils produced in the refinery are marketed in the United Kingdom, while the other products are exported to the rest of Europe and the United States.
MarketingConocoPhillips has marketing operations in select European countries through company-owned and dealer-owned JET® branded outlets. The company also has equity interest in a joint venture which markets products in Switzerland under the Coop® brand name. In addition, a portion of Irish refinery production is sold to inland Irish markets.
The company’s European marketing strategy is to sell primarily through owned, leased or joint-venture retail sites using a low-cost, high-volume strategy. ConocoPhillips also markets aviation fuels, liquid petroleum gases, heating oils, transportation fuels and marine bunker fuels to commercial customers and into the bulk or spot market.
As of Dec. 31, 2007, ConocoPhillips had approximately 1,600 marketing outlets in its European operations, of which approximately 1,150 were company owned, and 450 were dealer owned. Through our joint venture operations in Switzerland, we also have interests in 196 additional sites. The company’s largest branded site networks are in Germany and the United Kingdom, which account for approximately 75 percent of our total European branded units.
During 2007, ConocoPhillips sold 377 of its fueling stations in six European countries to LUKOIL and completely divested its marketing operations in Thailand and Malaysia. As of Dec. 31, 2007, agreements were signed for the sale of Norway, Sweden and Denmark marketing assets, and are under regulatory review.
Power GenerationThe focus of ConocoPhillips’ power business is on developing integrated projects to support the company’s E&P and R&M strategies and business objectives. Immingham CHP, 730-megawatt, gas-fired combined heat and power plant in North Lincolnshire, United Kingdom, was placed in commercial operation in October 2004. The facility provides steam and electricity to the Humber refinery and steam to a neighboring refinery, as well as merchant power into the U.K. market. A Phase expansion of the Immingham CHP was approved by the board of directors in October 2006. The Phase II project will produce an incremental 450 megawatts and is scheduled to begin commercial operations in 2009.
CommercialOne of the company’s four Commercial offices is housed in London, where employees manage worldwide commodity supply, marketing and trading needs.
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