BP Increases Replacement Cost Profits by 135% in 1Q

BP released its first quarter 2010 results for its exploration and production.

  • BP's first-quarter replacement cost profit was $5,598 million, compared with $2,387 million a year ago, an increase of 135%.
  • Non-operating items and fair value accounting effects for the first quarter had a net $49 million unfavorable impact compared with a net $194 million unfavorable impact in the first quarter of 2009.
  • Finance costs and net finance income or expense relating to pensions and other post-retirement benefits were $228 million for the first quarter, compared with $368 million for the same period last year.
  • The effective tax rate on replacement cost profit for the first quarter was 34%, compared with 37.5% a year ago.
  • Net cash provided by operating activities for the first quarter was $7.7 billion, compared with $5.6 billion a year ago.
  • Net debt at the end of the first quarter was $25.2 billion. The ratio of net debt to net debt plus equity was 19% compared with 23% a year ago.
  • Cash costs(b) for the first quarter were slightly lower than a year ago despite adverse foreign exchange and fuel cost effects.
  • Total capital expenditure, including acquisitions and asset exchanges, for the first quarter was $4.7 billion. Organic capital expenditure(c) in the first quarter was $3.8 billion. Disposal proceeds were $0.1 billion for the first quarter. For 2010 as a whole, we continue to expect organic capital expenditure of around $20 billion and disposal proceeds of $2-3 billion.
  • The quarterly dividend, to be paid on June 21, 2010, is 14 cents per share ($0.84 per ADS), the same as a year ago. The corresponding amount in sterling will be announced on 8 June 2010. A scrip dividend alternative is available, allowing shareholders to elect to receive their dividend in the form of new ordinary shares and ADS holders in the form of new ADSs.

The replacement cost profit before interest and tax for the first quarter was $8,292 million, an increase of 92% compared with the first quarter of 2009. This increase was primarily due to higher realizations and higher earnings from equity-accounted entities (mainly TNK-BP), partly offset by a lower contribution from the gas marketing and trading business, higher production taxes and higher depreciation. After adjusting for restructuring costs, unit production costs were 3% lower than a year ago.

The net non-operating gain of $41 million in the first quarter primarily relates to fair value gains on embedded derivatives, partly offset by restructuring costs. The corresponding quarter in 2009 included a net non–operating gain of $311 million. Additionally, in the first quarter, fair value accounting effects had a favorable impact of $63 million compared with a favorable impact of $158 million a year ago.

Production for the quarter was 4,010mboe/d, broadly flat with the first quarter of 2009 reflecting continued strong operational performance. After adjusting for entitlement impacts in our production-sharing agreements (PSAs) production was 1% higher. As previously indicated, we expect production in 2010 to be slightly lower than in 2009.

The actual outcome will depend on a number of factors including the oil price and its impact on PSAs and OPEC quota restrictions. In the second quarter, we expect a normal seasonal turnaround effect of around 100mboe/d. These turnaround activities are planned for some of our higher-margin areas including the North Sea and the Gulf of Mexico, where activity is currently under way at Thunder Horse. This will impact costs and margins as well as volumes.

Two major projects started up during the first quarter. In the ultra-deepwater Gulf of Mexico, first oil was achieved from the Great White field (BP 33.3%). In Canada, the Noel major project commenced exporting and selling gas.

During the quarter, we announced that BP will pay Devon Energy $7.0 billion for assets in Brazil, Azerbaijan and the US deepwater Gulf of Mexico. These include ten exploration blocks in Brazil; a major portfolio of deepwater exploration acreage and prospects in the US Gulf of Mexico; and an interest in the ACG development in the Caspian Sea. Completion of certain of these transfers is subject to regulatory approvals and other third-party consents. In addition, BP will sell to Devon Energy a 50% stake in our Kirby oil sands interests in Alberta, Canada, for $500 million. The parties have agreed to form a 50:50 joint venture, operated by Devon, to pursue the development of Kirby. Devon will commit to fund an additional $150 million of capital costs on BP's behalf.

Also during the quarter, BP and Value Creation Inc. (VCI) of Calgary agreed to form a partnership to explore and develop the Terre de Grace oil sands acreage, in the Athabasca region of Alberta, Canada, using in-situ techniques. BP will hold a 75% interest and VCI a 25% interest in a newly formed partnership. BP has agreed to pay $900 million for the interest with $500 million paid in cash at closing.

Furthermore, on behalf of our partners, BP announced the first major contracts to support the expansion of production from the Rumaila field in southern Iraq (BP has a 38% working interest).

After the end of the quarter, BP agreed with Total to acquire its 15.7% interest in Valhall and its 25% interest in Hod, both fields located in the southern part of the Norwegian continental shelf, for the sum of $991 million to be paid in cash. The agreement will deepen BP's position as operator by giving BP a 43.8% interest in Valhall and 50% in Hod, subject to third-party consents and government approval. The deal has an effective date of 1 January 2010.

On April 20, 2010, the semisubmersible drilling rig Deepwater Horizon owned and operated by Transocean Limited caught fire in the US Gulf of Mexico and subsequently sank. The rig was drilling an exploration well on a BP deepwater lease. BP is committed to doing everything in its power to contain the environmental consequences of the incident.

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