Friday, April 19, 2013

BP Expects Some US Gulf Oil Spill Claims To Be Higher Than Anticipated

Deepwater Horizon Gulf of Mexico Oil Spill

LONDON - BP PLC now expects to pay more than previously anticipated in compensation for private economic and property damage stemming from the Deepwater Horizon disaster in the Gulf of Mexico, according to the company's annual report.

This is because average payments for business economic loss claims so far have been higher than anticipated, the company said. BP said this means it can no longer give a reliable estimate for the total cost of the settlement it agreed last year with the plaintiffs' steering committee--a group representing individuals with economic, property or medical damage claims--other than to say it will be significantly higher than $7.7 billion.

In a speech earlier this week BP Chief Executive Bob Dudley said the company has spent over $24 billion in response, including clean-up and restoration costs and in payments on claims made by individuals, businesses and governments for the 2010 disaster. This latest escalation in the cost of the disaster, which killed 11 men and triggered the worst offshore oil spill in U.S. history, comes as the company is embroiled in a civil trial to determine environmental fines that could total as much as $17.6 billion.

BP has spent or provisioned more than $40 billion for the Deepwater Horizon disaster, Mr. Dudley added.

BP said the final cost of the PSC settlement is likely to be higher than $7.7 billion, which is the company's current estimate of total payments under the deal, excluding future claims for business economic loss whose size cannot now be determined.

In February BP revised up the cost of the PSC settlement to $8.5 billion--already an increase from the original estimated cost of $7.8 billion last year--but it has now withdrawn that guidance. The company said it would issue fresh guidance for the higher costs when it is able to calculate a reliable new estimate.

BP said it can't give an estimate for the final total of compensation payments to individuals and businesses. "Management has concluded that no reliable estimate can be made of any business economic loss claims not yet received or processed," BP said.

BP said costs were higher because the administrator of the compensation fund was using a more generous interpretation of the payout agreement, resulting in higher number and value of awards than BP had assumed in their initial estimate.

This week a U.S. federal court affirmed the administrator's interpretation of the economic and property damages settlement agreement. BP said it disagrees with the ruling and will challenge it.

However, the U.K.-listed oil giant said that even if it is successful in appealing the court's ruling, the total cost of the settlement agreement will still exceed $7.7 billion. "If BP is not successful in its challenge to the court's ruling, a further signi?cant increase to the total estimated cost of the settlement will be required," BP said.

The company is now in the second week of a civil trial in New Orleans to apportion blame for the 2010 accident. A second trial, scheduled for the fall, will determine how much oil leaked into the Gulf of Mexico. The two trials will determine the size of the fines BP could face under the U.S. Clean Water Act, which could total as much as $17.6 billion

BP has said these fines should be a maximum of $3.4 billion.

Copyright (c) 2012 Dow Jones & Company, Inc.

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UK Oilfield Services Firms Plan Workforce Increase of 10%

UK Oilfield Services Firms Plan Workforce Increase of 10%

UK oilfield services companies plan to increase their workforces by an average of 10 percent over the next two years, according to a new report from corporate accountants Ernst & Young.

Ernst & Young said that more than 75 percent of businesses surveyed in conjunction with Oil & Gas UK expect to expand their staff, with 90-percent expecting an increasing in revenues. But 53 percent of respondents identified sourcing suitably-qualified personnel as the main factor limiting growth in their organizations.

Nearly two-thirds of firms stated that any surprise changes to the fiscal terms for the oil and gas sector would negatively affect their plans.

"The oilfield services segment continues to outperform most other UK industrial sectors, despite the recession. The UK, particularly the north east of Scotland, is recognized as a global leader and has the potential to deliver even more skilled jobs and greater export opportunities," commented Ernst & Young partner Ally Rule, the report's author, in a statement.

"There is evidence of record order books and rising revenues, but this is dependent on a stable fiscal environment. Changes made to the tax regime following the increase in the supplementary charge in 2011, alongside the introduction of an agreed framework for assurances on decommissioning tax relief, are redressing the balance and increasing confidence in the sector."

Ernst & Young's report follows a report by Lloyds Banking Group earlier this week that stated that the UK oil and gas sector could create more than 34,000 new jobs within the next two years. Lloyds also said that a skills shortage remains the sector's biggest challenge.

A former engineer, Jon is an award-winning editor who has covered the technology, engineering and energy sectors since the mid-1990s. Email Jon at jmainwaring@rigzone.com.

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Apache Could Earn $3B on Rumored Deepwater US Gulf Sale

Apache Corp. could realize up to $3 billion in a rumored sale of its deep water Gulf of Mexico oil and natural-gas assets, analysts said Thursday.

Apache was said to be considering an exit from the Gulf to concentrate on its onshore North America drilling assets, an unnamed person told Bloomberg Wednesday. Apache declined to comment on the rumors, only noting that it announced in its fourth-quarter earnings release that it planned to sell $2 billion in assets.

"When we have something concrete to share, we will do so," Apache spokesman Bill Mintz said.

A sale would undo Apache's relatively recent investment in the Gulf of Mexico, when it acquired Mariner Energy in 2010 for about $2.4 billion in debt and cash.

Operating costs in the Gulf of Mexico have risen since the deadly 2010 Deepwater Horizon accident due to new safety requirements.

Michael Yeager, CEO of BHP Billiton Petroleum said during a talk at the IHS CERAWeek conference in Houston this week that his company's Gulf of Mexico wells now cost about $170 million to drill, up from $120 million before the Deepwater Horizon accident.

Many U.S. oil and natural-gas producers are trimming their exposure to the deep water Gulf of Mexico, where developing wells thousands of feet under the waves can cost billions of dollars. As hydraulic fracturing, or fracking, and other new drilling methods have proliferated, producing oil and gas in onshore shale formations is seen as less technically challenging and more profitable.

In 2012, Apache drilled one operated and five nonoperated wells in the Gulf of Mexico deepwater region, according to the company's web site. Apache finished the year with an interest in 166 blocks in region and about 900,000 gross acres.

Apache held nonoperating interest in two deep water Gulf of Mexico wells, Lucius and Heidelberg, according to its annual report. Apache's Gulf of Mexico total daily production averaged 10,000 barrels of oil and liquids and 48 million cubic feet of natural gas, about 2% of the company's overall production.

Proceeds from the rumored sale could reach $3 billion, analysts at energy investment bank Tudor Pickering Holt & Co. said in a note. Analysts at Simmons & Co International put the figure closer to $2 billion.

"Apache would not be selling a large amount of production or reserves," Simmons analyst Bob Herbert said in a note.

Copyright (c) 2012 Dow Jones & Company, Inc.

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Ivar Aasen and Asha Discoveries to be Jointly Developed

Anglo-Norwegian junior Bridge Energy reported Friday that it has signed an agreement that will see the joint development of the Ivar Aasen field and the Asha discovery, offshore Norway.

Bridge – which is a 20-percent license partner on production license 457, where Asha sits – said the agreement establishes an approach towards unitization of the discoveries and that the process is expected to be concluded by mid-2014. The deal, which Bridge said has been approved by all relevant license holders, will see the Asha discovery form an integral part of the proposed Ivar Aasen field development.

Approval for a plan to develop and operate (PDO) the Ivar Aasen field is expected to be granted by the end of June this year.

The PDO for Ivar Aasen proposes to install a steel legged platform, which will support dry wellheads and processing capacity. Hydrocarbons from Ivar Aasen will be then be exported via the Lundin operated Edward Grieg facilities. Field production start-up is planned for 2016.

Bridge's partners in PL457 include operator Wintershall Norge, which has a 40-percent stake, and VNG Norge and E.On Ruhrgas Norge.

Bridge CEO Tom Reynolds commented in a statement:

"I am pleased to announce this positive step forward on Asha, which clearly underlines the commerciality of this discovery; less than one month after our resource update and three months after drilling.

"With existing estimates indicating more than 13 million barrels of oil equivalent net recoverable to Bridge from Asha, this agreement both accelerates and unlocks significant value within PL457. In addition to the Asha discovery further upside potential exists on this licence within the independent Aglaja and Amol prospective targets."

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Repsol, Alliance Oil Begin Gas Production from SK Field

Repsol reported Thursday that it and its partner Alliance Oil have begun commercial gas production from the Syskonsyninskoye (SK) field in the Khanty-Mansiysk region of Russia. The firm said that the production start-up marks the first success of the A&R Oil and Gas (AROG) joint venture that the two companies established to explore and produce for hydrocarbons in Russia.

Repsol stated that initial gas production amounted to 5,350 barrels of oil equivalent per day (boepd) and that the gas is being delivered to the Gazprom transportation network. To date, five production wells have been drilled and three of these have been put into operation.

The company expects six more wells to be drilled on five locations by early 2014 as the joint venture further develops the field during the coming year.

AROG's total output now stands at 25,000 boepd, while its proven and probable reserves amount to 218 million barrels of oil equivalent.

"The first successful start-up through AROG is especially satisfying for us as we contribute to unlock the great potential of an area which will continue to supply large volumes of gas to the domestic market in coming years," commented Fernando Martinez Fresneda, the general manager for Repsol Russia, in a company statement.

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OTC Announces Technology Awards

The Offshore Technology Conference (OTC), which takes place 6 – 9 May in Houston, has announced 15 technologies that will receive the 2013 Spotlight on New Technology Award recognizing innovative new products that provide significant impact for offshore exploration and production. The awards will be presented at 1600 hours, 6 May, in Reliant Center.

The Spotlight on New Technology Awards, which are for OTC exhibitors, showcase the latest and most advanced hardware and software technologies that are leading the industry into the future. “Our Spotlight Award winners ask, 'What if?' and 'Why not?'" said Spotlight Award Committee Chair Helge Hove Haldorsen.

"It is thanks to them that offshore E&P will continue to play a key role in supplying the world with affordable energy in a sustainable manner."

Winning technologies were selected based on the following five criteria:

• New: less than 2 years old

• Innovative: original, groundbreaking, and capable of revolutionizing the offshore E&P industry

• Proven: through full-scale application or successful prototype testing

• Broad Interest: broad appeal for the industry

• Significant Impact: provides significant benefits beyond existing technologies

"The innovation shown by this year’s Spotlight Award recipients demonstrates the type of ingenuity and forward thinking that is advancing the industry to new levels of safety, productivity, and efficiency,” said Steve Balint, 2013 OTC chairperson. "I congratulate them on their achievements and thank them for making this a highlight of OTC.” Spotlight Recipients and Products for 2013:

• ABB – Onboard DC-Grid

• Baker Hughes – FASTrak LWD Fluid Analysis Sampling and Testing Service

• Bayou Wasco Insulation, Dow Oil & Gas, PIH, Trelleborg Offshore – DOW NEPTUNE Advanced Subsea Flow Assurance Insulation System

• FMC Technologies – Condition and Performance Monitoring

• FMC Technologies and Sulzer Pumps – High-speed, Helico-axial Multiphase Subsea Boosting System

• GE Oil & Gas – RamTel Plus and ROV Subsea Display Panel

• GE Oil & Gas – Deepwater BOP Blind Shear Ram

• Reelwell as – Reelwell Drilling Method Riserless (RDM-R)

• SBM Offshore – Drilling Riser Trip Saver

• ShawCor – Mobile Robotic Cutback System

• STATOIL ASA – Remotely Welded Retrofit Subsea Hot Tap Tee

• Superior Energy Services – Complete Automated Technology System (CATS)

• Wärtsilä Corporation – Wärtsilä GasReformer

• Welltec –Well Cutter

• WeST Drilling Products AS – Continuous Motion Rig (CMR)

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Canadian Overseas Inks Amended Liberian PSC

Canadian Overseas Petroleum and its wholly owned subsidiary, Canadian Overseas Petroleum Bermuda Limited (COPL), announced Friday that a restated and amended production sharing contract (PSC) for Block LB-13 offshore Liberia has been agreed with ExxonMobil Exploration and Production Liberia Limited and the National Oil Company of Liberia (NOCAL).

Liberian President Ellen Johnson Sirleaf, has approved and signed the appropriate paperwork related to the PSC so that it can be sent to the Liberian Legislature for a ratification vote. The terms of the PSC will take effect once ratification has occurred and the PSC is enacted into law. Completion of the transactions contemplated is expected to occur shortly after ratification and remain subject to a number of conditions.

In addition, certain terms of the previously announced purchase agreements between COPL, COPL Bermuda , and Peppercoast Petroleum plc, and between COPL Bermuda and ExxonMobil have been amended. COPL Bermuda and ExxonMobil have amended the Asset Purchase Agreement announced Nov. 16, 2011 such that COPL Bermuda will now have a 20 percent working interest in Block LB-13 and ExxonMobil as operator will have an 80 percent working interest. ExxonMobil will continue to pay COPL Bermuda's working interest portion of drilling expenses for the first $120 million of gross drilling costs committed under the PSC, and COPL Bermuda's share of joint venture costs up to the completion of those operations. As part of the new arrangements, the payment terms as between COPL Bermuda and Peppercoast have also changed from the agreement announced in May 2011.

The new arrangements call for the completion of the acquisition of the original Production Sharing Contract by COPL Bermuda to be funded by NOCAL such that NOCAL shall pay the obligations of COPL Bermuda to Peppercoast. Following that transfer, the ExxonMobil affiliate will pay to NOCAL (1) all funds previously owed to COPL Bermuda under the Asset Purchase Agreement, and (2) on behalf of COPL Bermuda and the ExxonMobil affiliate, all amounts owed by COPL Bermuda and the ExxonMobil affiliate to the Government of Liberia on account of the issuance of the PSC. Upon that payment, the PSC shall be owned 20 percent by COPL Bermuda and 80 percent by the ExxonMobil affiliate. All payments will follow the approval by the Legislature of the Republic of Liberia of these arrangements to assure transparency and compliance with law.

As a result of these changes, COPL will no longer issue any shares to Peppercoast to complete the transaction. Further, other than legal costs, usual closing costs and on-going fees under the PSC, COPL and COPL Bermuda will have no net cash outlay or cost in connection with the closings other than forgiveness of accounts receivable related to the $15 million 3D seismic license fee owing by Peppercoast to COPL and other inter-company amounts and $7 million of fees payable to the Government of Liberia.

Arthur Millholland, president and CEO of COPL, commented, "We are very pleased to have been able to reach agreement with representatives from the Government of Liberia, NOCAL and ExxonMobil for an amended PSC for Block LB-13, and believe that this represents a great opportunity for our shareholders and the citizens of Liberia. The revised Sale and Purchase Agreement with Peppercoast and the revised Asset Purchase Agreement with ExxonMobil provide a low risk method for our involvement in Block LB-13. We look forward to working with ExxonMobil to begin planning exploration activities offshore Liberia."

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Apache Could Earn $3B on Rumored Deepwater US Gulf Sale

Apache Corp. could realize up to $3 billion in a rumored sale of its deep water Gulf of Mexico oil and natural-gas assets, analysts said Thursday.

Apache was said to be considering an exit from the Gulf to concentrate on its onshore North America drilling assets, an unnamed person told Bloomberg Wednesday. Apache declined to comment on the rumors, only noting that it announced in its fourth-quarter earnings release that it planned to sell $2 billion in assets.

"When we have something concrete to share, we will do so," Apache spokesman Bill Mintz said.

A sale would undo Apache's relatively recent investment in the Gulf of Mexico, when it acquired Mariner Energy in 2010 for about $2.4 billion in debt and cash.

Operating costs in the Gulf of Mexico have risen since the deadly 2010 Deepwater Horizon accident due to new safety requirements.

Michael Yeager, CEO of BHP Billiton Petroleum said during a talk at the IHS CERAWeek conference in Houston this week that his company's Gulf of Mexico wells now cost about $170 million to drill, up from $120 million before the Deepwater Horizon accident.

Many U.S. oil and natural-gas producers are trimming their exposure to the deep water Gulf of Mexico, where developing wells thousands of feet under the waves can cost billions of dollars. As hydraulic fracturing, or fracking, and other new drilling methods have proliferated, producing oil and gas in onshore shale formations is seen as less technically challenging and more profitable.

In 2012, Apache drilled one operated and five nonoperated wells in the Gulf of Mexico deepwater region, according to the company's web site. Apache finished the year with an interest in 166 blocks in region and about 900,000 gross acres.

Apache held nonoperating interest in two deep water Gulf of Mexico wells, Lucius and Heidelberg, according to its annual report. Apache's Gulf of Mexico total daily production averaged 10,000 barrels of oil and liquids and 48 million cubic feet of natural gas, about 2% of the company's overall production.

Proceeds from the rumored sale could reach $3 billion, analysts at energy investment bank Tudor Pickering Holt & Co. said in a note. Analysts at Simmons & Co International put the figure closer to $2 billion.

"Apache would not be selling a large amount of production or reserves," Simmons analyst Bob Herbert said in a note.

Copyright (c) 2012 Dow Jones & Company, Inc.

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Lukoil 4Q 2012 Profit Almost Doubles

MOSCOW - OAO Lukoil Holdings, Russia's No. 2 crude oil producer, said Thursday its net profit for the final three months of 2012 nearly doubled compared with the same period the previous year, when it was hit by a nearly $1 billion write-off.

Lukoil said net profit for the period totaled $2.69 billion, compared with $1.35 billion in 2011. That was slightly below a forecast of $2.72 billion from a Dow Jones Newswires survey of five analysts.

The company didn't provide a breakdown of fourth-quarter results, but said revenue for the full year increased 4.1% to $139.2 billion from $133.7 billion, on the back of higher oil prices. Earnings before interest, taxation, depreciation and amortization, or Ebitda, rose 1.7% to $18.9 billion from $18.6 billion. Net profit for the year was up 6.2% on 2011 at $11.0 billion.

Lukoil will host a presentation later Thursday, where analysts say they are looking for information on the company's progress on stabilizing production and plans for international projects, such as West Qurna-2 in Iraq.

Copyright (c) 2012 Dow Jones & Company, Inc.

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