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Showing posts with label billion. Show all posts
Showing posts with label billion. Show all posts

Thursday, August 18, 2011

Noble Energy Pays $3.4 Billion For 50% Stake in Consol's Marcellus Assets

- Noble Energy Pays $3.4 Billion For 50% Stake in Consol's Marcellus Assets



Aug 18, 2011

Noble Energy (NYSE:NBL) agreed to pay $3.4 billion to Consol Energy (NYSE:CNX) for a 50% interest in Consol's Marcellus Shale assets.

The two companies will create a joint venture to develop Consol's 663,350 acres in the region.

In early trading, Consol rose $1.80, or 4.24%, to $42.22. In spite of the deal between Consol and Noble, most companies with property in the Marcellus region are declining along with the broader market.

Noble Energy (NYSE:NBL) has a potential upside of 33.4% based on a current price of $83.39 and an average consensus analyst price target of $111.25.

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Thursday, July 7, 2011

Baraka: Rig Headed to Georgina Basin

- Baraka: Rig Headed to Georgina Basin

Thursday, July 07, 2011
Baraka Energy and Resources Ltd.

Baraka and joint venture partner PetroFrontier announced that the long awaited Rig mobilization by Major Drilling has begun from Brisbane, Queensland to the Southern Georgina Basin in the Northern Territory, Australia.

Drilling Program Update

The rig will mobilize approximately 3,000 kilometers and is expected to arrive at the Baldwin-2 well site in approximately one week. Once the rig arrives on location and is rigged up, it will be subject to a final government audit prior to spud. PetroFrontier will provide a further update once a spud date has been confirmed.

Baldwin-2 is located in the southern part of EP 103 in the Southern Georgina Basin. Its primary target is the Basil Arthur Creek "hot" shale with a secondary target being the Hagen Member above the hot shale. Management believes that the Arthur Creek is analogous to the Bakken play found in Saskatchewan, Canada and North Dakota, USA. PetroFrontier has identified 13 older unconventional wells within the Arthur Creek "hot" shale zone on its lands.

PetroFrontier has a 100% working interest in EP 103 and is the operator.

After completion of drilling the Baldwin-2 well, the rig will then move to the MacIntyre-2 well site located in the northeastern corner of EP 127. MacIntyre-2 will be fracked and completed immediately after it is drilled and then the rig and frac crew will return to Baldwin-2 to conduct fracking and completion operations on that well.

According to a report prepared by Ryder Scott Company Canada (independent oil and natural gas reservoir engineers), dated November 1, 2010, the unrisked, undiscovered, prospective (recoverable) resource, based on a best (P50) scenario, for the unconventional Basil Arthur Creek shale zone in EP 103 and EP 127 may contain approximately 13.2 billion barrels and 2.7 billion barrels (gross) of oil respectively.

The Ryder Scott Resource Report on the resource potential of the Southern Georgina Basin describes the prospective (recoverable) portion of "Undiscovered Resources", as defined by the Canadian Oil and Gas Evaluation Handbook and does not represent an estimate of reserves. The Ryder Scott Resource Report is compliant with National Instrument 51-101 "Standards of Disclosure for Oil and Gas Activities" (NI 51-101). There is no certainty that any portion of the resources will be discovered. If discovered, there is no certainty that it will be commercially viable to produce any portion of the resources.

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Wednesday, July 6, 2011

Namibia Sees 11 Billion Barrels In Offshore Oil Reserves

- Namibia Sees 11 Billion Barrels In Offshore Oil Reserves

Wednesday, July 06, 2011
Dow Jones Newswires
WINDHOEK

An estimated 11 billion barrels in oil reserves have been found off Namibia's coast, with the first production planned within four years, mines and energy minister Isak Katali announced Wednesday.

The finding could put Namibia on par with neighboring Angola, whose reserves are estimated at around 13 billion barrels and whose production rivals Africa's top producer, Nigeria.

Katali said that Enigma Oil & Gas, owned by London-listed Chariot Oil & Gas, has identified 11 prospects along the southern coast.

"The largest of these, the Nimrod Prospect in 350 meters (1,150 feet) depth, and most likely reserves in the event of success are estimated to be greater than four billion barrels," he told parliament.

"Enigma expects to find oil rather than gas," Katali said, adding that first production could begin as early as 2015.

Enigma holds a 50% equity in the offshore Southern Block together with Brazil's Petrobras.

According to Katali, another Brazilian company, HRT Oil & Gas Ltd, has raised $1.3 billion on the Brazilian stock market, with $300 million earmarked for oil and gas exploration in Namibia.

He said that HRT has certified about 5.2 billion barrels of potential reserves.

"This finding could turn offshore Namibia into a great producer of oil and gas in a short time," Katali said.

In his statement to Parliament, Katali added that HRT would drill three to four wells in that area as early as next year.

Another find off Namibia's central coast called Delta Prospect contained recoverable resources of up to two billion barrels of oil, by Arcadia Expro Namibia and British firm Tower Resources, he said.

"We expect that six to eight wells to be drilled in Namibia's waters in the next 18 months, the highest number in Namibia's exploration history," he said.

Namibia has long been seen as a potential new source of oil, hampered by a lack of exploration to determine the extent of its reserves. Its offshore geology is similar to Brazil, which is seeing a boom in oil.

Copyright (c) 2011 Dow Jones & Company, Inc.

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Tuesday, July 5, 2011

Songa Snatches New Semisub Gig from Statoil

- Songa Snatches New Semisub Gig from Statoil

Tuesday, July 05, 2011
Songa Offshore SE

Songa Offshore's 100% owned subsidiary, Songa Rig AS, has received and accepted a Letter of Award (LOA) from Statoil for two new build "Cat-D" semisubmersibles with firm terms of 8 years each, and options that could extend this period to 20 years. The firm part of the contract has an aggregated revenue value of approximately USD 2.5 Billion, inclusive of mobilization, with a higher contract value upon program commencement due to escalation provisions taking effect from 2011. Statoil has awarded the contract for the two new build Cat D rigs on behalf of the participants in the Troll-license.

Statoil has an option to award contracts for two additional rigs to Songa.

Mobilization of the units to Statoil will take place in direct continuation of the rigs' delivery from Daewoo Shipbuilding & Marine Engineering Co., Ltd (DSME) in 1Q and 3Q 2014. The fixed price, inclusive of yard's project management and commissioning, is USD 565 million per unit with 20/80 payment terms staggered by delivery schedule. The construction cost is expected to be funded from a combination of ongoing cash flows in addition to bank debt.

Asbjørn Vavik, CEO of Songa Offshore SE, said, "We are pleased to secure a contract for two new build high specification semisubmersibles for mid-water harsh environment in the Norwegian North Sea, which is consistent with our strategy of fleet renewal. We consider this an excellent opportunity to further strengthen our relationship with Statoil and manifest our position as a leading provider of offshore rigs for the Norwegian North Sea region. The contract value for the fixed 8 years contracts represents a significant increase in our backlog and earnings visibility."

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Maersk Extends Rig Fleet with $1.3B Drillship Order

- Maersk Extends Rig Fleet with $1.3B Drillship Order

Tuesday, July 05, 2011
A.P Moller - Maersk Group

Maersk Drilling, a business unit within the A.P. Moller- Maersk group, has declared its option to build two ultra deepwater drillships at Samsung Heavy Industries in South Korea.

The drillships are scheduled for delivery in the second and third quarters of 2014, respectively. The total project cost for the two drillships is approximately USD 1.3 billion, which includes a turnkey contract with the yard, owner furnished equipment, project management, commissioning, start-up costs and capitalized interest. Simultaneously, Maersk Drilling has obtained a new option for the construction of two additional drillships.

"We have an ambition of becoming one of the leading drilling contractors in the ultra deepwater segment and this order is another important step in taking a bigger share of this attractive market segment," said Claus V. Hemmingsen, CEO of Maersk Drilling and member of the Executive Board of the A.P. Moller – Maersk Group. "The order reflects our commitment to grow our rig fleet enabling us to serve our customers in the ultra deepwater segment on a more regular basis," Claus V. Hemmingsen continued.

Year to date, Maersk Drilling has invested USD 3.8 billion in two new jack-up rigs and four drillships.

Maersk Drilling had a revenue of USD 1.6 billion and a profit of USD 399 million after tax in 2010.

Hemmingsen sees a strong market for deepwater drilling rigs as the global demand for oil is increasing while at the same time production from mature fields is declining.

"This means that about six times the current Saudi production must be brought on stream over the next 20-25 years which will drive a solid growth in the demand for drilling services. The main part of this growth will take place in frontier areas such as deepwater," he said.

The two drillships will be of similar design to the two drillships Maersk Drilling ordered from Samsung in April 2011. The 228 meter long drill ships will be able to operate at water depths up to 12,000 ft (3,650 m) and will be capable of drilling wells of more than 40,000 ft (12,200 m).

Similar to the design philosophy on Maersk Drilling's ultra deepwater semi-submersibles the drillship design includes features for high efficiency operation including a dual derrick, which allows for parallel and offline activities. The extensive storage areas and tank capacities provide an advantage when operating in areas with less developed infrastructure and limited presence of suppliers. Together with the higher transit speed the increased capacity will reduce the overall logistics costs for the oil companies. The drillships will have accommodation capacity for 230 people.

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Thursday, June 30, 2011

Woodside Strikes Over A$1 Billion Deal With Landowners Over Browse

- Woodside Strikes Over A$1 Billion Deal With Landowners Over Browse

Thursday, June 30, 2011
Dow Jones Newswires
SYDNEY
by Ross Kelly

Woodside Petroleum Ltd. (WPL.AU) said Thursday that it has signed an agreement with landowners allowing it to develop the massive Browse gas export project in Western Australia state.

Woodside said the agreement with the Goolarabooloo Jabirr Jabirr native title claim group includes initiatives worth over A$1 billion, such as education, training and employment programs, support for indigenous businesses and payments when project milestones are met.

The Browse joint venture also includes Royal Dutch Shell PLC (RDSB.LN), Chevron Corp. (CVX), BHP Billiton Ltd. (BHP.AU) and BP PLC. (BP.LN).

It's planning to give final approval to the development, estimated by analysts to cost more than $30 billion, by mid-2012.

Copyright (c) 2011 Dow Jones & Company, Inc.

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Thursday, April 28, 2011

OXY Touts $1.1B in 1Q 2011

OXY Touts $1.1B in 1Q 2011

Thursday, April 28, 2011
Occidental Petroleum Corp.

Occidental Petroleum Corporation (OXY) announced core income of $1.6 billion ($1.96 per diluted share) for the first quarter of 2011, compared with $1.1 billion ($1.35 per diluted share) for the first quarter of 2010. Net income for the first quarter of 2011 was $1.5 billion ($1.90 per diluted share), compared with $1.1 billion ($1.31 per diluted share) for the first quarter of 2010.

In announcing the results, Dr. Ray R. Irani, Chairman and Chief Executive Officer, said, "The first quarter of 2011 core income of $1.6 billion was 45-percent higher than the first quarter of 2010. Our oil and gas production for the first quarter of 2011 increased over 4 percent, as compared to the first quarter of 2010, to 730,000 BOE per day."

QUARTERLY RESULTS

Oil and Gas

Oil and gas segment earnings were $2.5 billion for the first quarter of 2011, compared with $1.9 billion for the same period in 2010. The increase in the first quarter of 2011 results was due to higher crude oil prices and higher sales volumes in the Middle East, partially offset by higher operating costs and DD&A rates.

For the first quarter of 2011, daily oil and gas production volumes averaged 730,000 barrels of oil equivalent (BOE), compared with 701,000 BOE in the first quarter of 2010. Volumes increased over 4 percent, primarily in domestic gas and NGL production and Middle East/North Africa crude oil volumes. The domestic gas increase was from the new acquisition in South Texas, which closed in the first quarter of 2011. The Middle East/North Africa increase included new production from Iraq and higher volumes from the Mukhaizna field in Oman.

As a result of higher year-over-year average oil prices affecting production sharing and similar contracts, production was negatively impacted in the Middle East/North Africa, Long Beach and Colombia by 12,000 BOE per day. Dolphin and Elk Hills volumes were also lower from planned maintenance and production shut-downs in the first quarter of 2011.

Daily sales volumes increased over 6 percent from 685,000 BOE per day in the first quarter of 2010 to 728,000 BOE per day in the first quarter of 2011.

Oxy's realized price for worldwide crude oil was $92.14 per barrel for the first quarter of 2011, compared with $74.09 per barrel for the first quarter of 2010. Worldwide realized NGL prices rose from $47.48 per barrel in the first quarter of 2010 to $52.64 per barrel in the first quarter of 2011. Domestic realized gas prices dropped from $5.62 per Mcf in the first quarter of 2010 to $4.21 per Mcf for the first quarter of 2011.

Apache Boosts 1Q Production by 25%

Apache Boosts 1Q Production by 25%

Thursday, April 28, 2011
Apache Corp.

Apache reported production of 732,000 barrels of oil equivalent (boe) per day and earnings of $1.1 billion, or $2.86 per diluted share, for the three-month period ending March 31, 2011. These compare with production of 586,000 boe per day and net income of $705 million, or $2.08 per diluted share, for the same period in the prior year.

"Apache is beginning the year with a solid, strong performance," said G. Steven Farris, chairman and chief executive officer. "Despite a number of challenges, our diversified portfolio of assets delivered exceptional earnings and operating results. Liquids production increased 57,000 barrels to 358,000 barrels per day, which enabled Apache to achieve stand-out earnings and cash flow as a leading beneficiary of rising oil prices."

Higher oil prices and production from new wells drilled during the quarter and assets acquired during 2010 combined to increase revenues to $3.9 billion, up from $2.7 billion last year. Cash from operations before changes in operating assets and liabilities* increased 43 percent from the prior year to $2.2 billion. Excluding certain items that management believes affect the comparability of operating results, Apache reported adjusted earnings* of $1.1 billion in first quarter 2011 compared with $712 million in the year-earlier period. On a per-share basis, adjusted earnings were $2.90 in the first quarter compared with $2.10 per diluted share in the prior-year period.

Liquid hydrocarbons represented 49 percent of production and 77 percent of revenues. Approximately 60 percent of the company's oil production came from operations outside North America and received in excess of a $10 premium per barrel compared with domestic production benchmarked to West Texas Intermediate prices.

On the operational front, the company achieved several milestones. These include:
  • Apache's most prolific development well in the Forties field (North Sea), which came online at approximately 11,800 barrels of oil per day.
  • In the Permian Basin, Apache is operating 24 rigs, up nearly five-fold from a year ago. Targeting primarily oil objectives, Apache drilled 110 wells including 15 horizontals during the first quarter.
  • Since drilling the first-ever horizontal Hogshooter well last year, Apache has drilled six wells into this oil-rich segment of the Anadarko basin's Granite Wash formation. To date, every well has tested in excess of 1,000 barrels of oil and 2 million cubic feet of gas per day.
  • The company's first operated deepwater production in the Gulf of Mexico with start-up at the Balboa field.
  • Offshore Australia, Apache's Zola discovery well encountered 410 feet of net gas pay.
  • In Egypt, Apache operated 22 rigs during the quarter, drilling 33 wells, including the company's first wells in the Tayim development lease in West Kalabsha producing from deeper Paleozoic pay. Apache's production remained online throughout the quarter, increasing sequentially from the previous three months.

"We continue to strengthen our land position, both in North America and internationally. Our LNG initiatives, Kitimat in Canada and Wheatstone in Australia, are steadily progressing toward project sanction with their respective joint venture partnerships," Farris said.

"Apache's opportunity set has never been more robust. We have a deep backlog of exploitation opportunities across our portfolio. In addition to our legacy plays in core areas, we have other potentially large-scale, long-life assets such as deepwater, LNG, and unconventional plays that can provide lasting, long-term value to our shareholders."

Tuesday, April 26, 2011

Saudi Aramco plans $125 billion spending spree


Apr 26, 2011
Sangim Han

SEOUL // Saudi Aramco, the world's largest oil exporter, will spend about $125 billion (Dh459bn) on projects over the next five years as it seeks to increase refining capacity by 50 per cent, Chief Executive Officer Khalid al-Falih said.

The company wants to boost oil-processing capacity to 6 million barrels a day from the current 4m barrels, Mr al-Falih said in a speech in Seoul today. Aramco is building two plants in the kingdom and is considering a further four "grassroots" facilities, he said. That includes one refinery at Jaizan in Saudi Arabia and possible joint-venture projects in China, Vietnam and Indonesia, he said.

"Saudi Aramco isn't just about petroleum production," he said. "We are also one of the world's largest producers of natural gas, a major player in refining, and we are ramping up our petrochemical activities."

Aramco's domestic and international spending plans include oil exploration and production as well as natural gas, refining and petrochemical facilities, he said. Saudi Arabia plans capital expenditure of more than $450bn in the same period, according to Mr al-Falih.

All 12 members of the Organisation of Petroleum Exporting Countries including Saudi Arabia will need to provide a daily average of 29.8m barrels a day this year to satisfy global requirements, or about 600,000 a day more than they pumped in March, the International Energy Agency said April 12.

Aramco built the world's largest natural gas network about 30 years ago, and doubled its processing capacity.

The company plans to expand the network to exceed 14bn standard-cubic-feet per day of capacity in the next five years when the network will encompass seven world-scale gas plants.

For the expansion, the company continues to make natural gas discoveries in places including the Gulf, while beginning exploration in areas such as the Red Sea and the north-west region of the kingdom.

These activities are adding to the company's reserves of 275 trillion cubic feet, the world's fifth-largest proven holdings of gas, in addition to the world's biggest reserves of conventional crude oil, he estimated.

The company is also expanding its petrochemical capabilities in the kingdom, through a petrochemical project in Jubail with Dow Chemical and a planned expansion of Rabigh Refining & Petrochemicals, its joint venture with Sumitomo Chemical.

Mr Al-Falih said South Korea is now among Saudi Arabia's four largest trading partners.

The country accounts for about a fifth of Saudi Arabia's total petroleum exports, and Aramco supplies 30 per cent of South Korea's crude imports.

Aramco is holding its board meeting for the first time in South Korea this week, Mr al-Falih said.

"The Far East is the destination for two out of every three barrels of crude oil" that Aramco exports, he said.

Aramco owns 35 per cent of S-Oil, South Korea's third- largest refiner that's expanding its processing capacity in Ulsan to more than 650,000 barrels a day.

Export Import Bank of Korea and Korea Trade Insurance each signed a memorandum of understanding with Aramco on possible future project financing, according to the website of the oil and gas producer.

Tuesday, April 19, 2011

Petronas Sells Cairn India Stake for $2.1B

Petronas Sells Cairn India Stake for $2.1B

Tuesday, April 19, 2011
Dow Jones Newswires
by Ankur Relia, Raghavendra Upadhyaya & Eric Yep

Malaysia's Petroliam Nasional Berhad, or Petronas, Tuesday said it exited Cairn India by selling its entire 14.94% stake in the oil and gas explorer for about $2.1 billion.

Petronas held 283.4 million shares in the Indian unit of Cairn through its overseas arm Petronas International Corp.

"The transaction brings to a close a successful association as a shareholder with Cairn India since 2006," Petronas said in a statement.

Petronas had raised its holding in Cairn India to 14.94% in 2009-10 after acquiring a 2.3% stake from Cairn Energy.

Petronas didn't reveal the names of the buyers but a person with knowledge of the matter told Dow Jones Newswires that the stake was sold to India-focused miner Vedanta and institutional investors in India via block deals.

Bank of America Merrill Lynch was the sole adviser on the deal, said the person, who declined to be named.

The stake sale by Petronas brings Vedanta closer to its goal of acquiring a majority stake in Cairn India as analysts don't expect a big response to Vedanta's open offer. Petronas' sale may also allow Edinburgh-based explorer Cairn Energy to retain a larger stake in Cairn India.

In August last year, Vedanta had offered to buy a 51%-60% stake in the Indian unit of Cairn Energy, in a deal expected to cost up to $9.6 billion.

The deal is awaiting approval from the Indian government.

Cairn Energy owns a 62.37% stake in Cairn India.

Vedanta has proposed to acquire up to 51% of Cairn India from its U.K. parent for INR405 a share. Vedanta unit Sesa Goa launched an open offer on April 11 for up to 20% of Cairn India from minority shareholders at INR355 a share. The open offer price doesn't include the INR50 non-compete fee that Vedanta had offered to Cairn Energy.

The open offer closes on April 30. Shares of Cairn India, which had earlier risen to as much as INR370, closed up 2.3% on Tuesday at INR344.25.

Vedanta, Cairn Energy and Cairn India didn't immediately respond to queries.

Earlier Tuesday, data on Factset showed that about 283.43 million shares of Cairn India were traded through block deals on the Bombay Stock Exchange. The three largest deals were for 265.19 million shares traded at a weighted average price of INR331.08 apiece, 12.08 million shares at INR331.08 each and 5.07 million shares at INR331.07 apiece.

The CNBC-TV18 television channel reported, citing sources it didn't name, that Vedanta bought an 11% stake in Cairn India from Petronas.

Cairn Energy has extended by more than a month the deadline for the stake sale to Vedanta to May 20 in order to accommodate the completion of the open offer and as an Indian ministerial panel scrutinizes the deal.

Cairn India holds stakes in 10 oil and gas blocks in India, including the huge RJ-ON-90/1 oil block at Barmer in western Rajasthan state. The block's output of 125,000 barrels a day accounts for about 17% of India's total crude production.

Monday, April 18, 2011

OGX Notes 4 Bboe Increase in Potential Resources Offshore Brazil

OGX Notes 4 Bboe Increase in Potential Resources Offshore Brazil

Monday, April 18, 2011
OGX S.A.

OGX disclosed the results of the reports prepared by petroleum consultants DeGolyer & MacNaughton ("D&M"), which estimate new volume of resources held by the Company in Brazil's Campos and Parnaiba basins and three basins in Colombia. These reports indicate net potential resources for OGX of 5.7 billion barrels of oil equivalent ("boe") in the Campos Basin, 1.0 billion boe in the Parnaíba Basin and 1.1 billion boe in Colombia. When combined with the estimates from the previous report for the Santos, Espírito Santo and Pará-Maranhão Basins (Sep/09), these new results present a total volume of net potential resources of 10.8 billion boe.

These results validate the successful and accelerated evolution of the Company's asset portfolio and its ability to grow organically, through massive discoveries as well as via the acquisition of new areas, demonstrating a unique capacity of to create value and deliver results.

"These results, presented by an independent, internationally-renowned consulting group, confirm the extraordinary success of our business strategy and execution, which has been to focus on world-class assets located mostly in shallow waters. We have discovered accumulations of scale and levels of productivity comparable to those found in the pre-salt areas, and will be able to develop them at a much lower cost, utilizing fully tried-and-tested technologies," commented Eike Batista, Chairman and CEO of OGX.

"OGX has demonstrated that it has the technical and managerial expertise to discover billions of barrels in accumulations in basins which vary greatly in their geological formations, and to transform their prospective resources into contingent resources. At the same time, we have expanded our exploration portfolio with high-potential assets. We have also made huge strides in the delineation of new discoveries and production, while continuing to grow and create value for all stakeholders," emphasized Paulo Mendonça, General Executive Officer and Head of Exploration for OGX.

The five reports submitted by D&M were prepared with the information available as of December 31, 2010, for the Campos and Parnaíba Basins, and as of March 31, 2011 for Colombia. The documents cover a period of approximately 15 months of exploration and 22 wells, and do not include the wells drilled subsequently. For the Campos Basin, only the post salt sections were considered. The new reports update the figures that were previously available for these two basins and present the first estimates for the five blocks held by OGX in Colombia. D&M's potential resource report dated September 2009 continues to apply for the Santos, Espírito Santo and Pará Maranhão basins.

The results of these studies reflect the success of OGX's strategy to prioritize, in the initial phase of its campaign, the accomplishment of ANP work program and the exploratory drilling of wildcat wells to maximize the discovery of accumulations. In response to the large number of discoveries made, the Company is intensifying its appraisal campaign in preparation for Declarations of Commerciality and the start-up of production.

"The identification of our discoveries and the recent chartering of five FPSOs and two WHPs with OSX, which will be followed by new orders, represent an important step towards production. We have rapidly executed on our business plan and achieved important milestones, enabling us to the begin production and commercialization within a timeframe that is unprecedented for the oil and gas industry," stated the Production Officer, Reinaldo Belotti.

Batista: No Need for OGXto Sell 30% Stake in Campos Basin

Batista: No Need for OGXto Sell 30% Stake in Campos Basin

Monday, April 18, 2011
by Jeff Fick

OGX is continuing to explore the sale of part of its Campos Basin oil fields but has reduced the size of the stake to be sold, said OGX Chairman Eike Batista.

"We have discovered such high-quality oil and such high-productivity that we don't see it as necessary to sell a maximum of 30% of our assets," Batista said in a conference call with investors. "The farm-out is ongoing, but it will be reduced to 10%." OGX is part of the billionaire investor's ever-growing industrial conglomerate, which includes energy, mining, logistics and oilfield services companies.

OGX gave investors a clearer picture of the company's value late Friday, when it announced that oilfield consultants DeGolyer and MacNaughton had certified prospective, contingent and delineated resources of 10.8 billion barrels of oil equivalent, or BOE. That was up from an earlier estimate of 6.8 billion BOE made in September 2009. The total included OGX's first contingent resources in the offshore Campos Basin, where the company booked 3 billion barrels of oil equivalent, or BOE.

The report did not include any possible pre-salt resources from the Campos Basin, which could add more than 1 billion BOE to the 5.7 billion BOE total resources in the basin, Batista said.

"We have a huge area to be added," said OGX Chief Executive Paulo Mendonca. The company will further evaluate the pre-salt prospects with fresh three-dimensional seismic data, Mendonca added.

While OGX's pre-salt prospects will require further evaluation, the company is quickly closing in on moving from a pure exploration play to a crude oil producer.

In September, OGX plans to produce its first crude oil. The company will start an extended well test at the Waimea prospect, which is expected to produce about 20,000 barrels a day later this year. The OSX-1 floating production, storage and offloading vessel, or FPSO, will be installed at the site in August, OGX officials have said.

OGX's Batista said that the quality of the oil to be produced from the company's Campos Basin field would range between 20 and 21 degrees on the American Petroleum Institute's grading scale. In talks with refiners in Houston and London, the crude should fetch a better-than-expected price for the company, he added.

"We will fetch Brent oil prices considering today's market situation," Batista said. The company had previously expected to receive a price at a $10-a-barrel discount to U.S. WTI prices, he said.

The shallow waters of the basin will also allow the company to produce the crude at about $7 a barrel, with total operating expenses of about $16 a barrel, Batista said.

Friday, April 15, 2011

Lukoil Buys 25.1% Stake in Trebs, Titov Project

Lukoil Buys 25.1% Stake in Trebs, Titov Project

Friday, April 15, 2011
Dow Jones Newswires
by Jacob Gronholt-Pederson

Lukoil has agreed to buy a 25.1% stake in the Trebs and Titov exploration project in northwest Russia from mid-sized oil company Bashneft.

Lukoil paid RUB4.7 billion ($166.7 million) for the stake in the project, which needs investment of $6 billion, Lukoil's Chief Executive Vagit Alekperov said.

Lukoil expects first oil from Trebs and Titov in the fourth quarter 2013 or the first quarter 2014, he said.

Bashneft, which is majority-owned by conglomerate AFK Sistema, last year won the right to develop the Trebs and Titov oil fields ahead of bigger rivals such as Lukoil and TNK-BP Ltd.

Last year's auction for the Trebs and Titov fields, which combined hold 1.5 billion barrels of oil, was mired in controversy after bidders were told by authorities they couldn't bid because of incorrectly-filed applications.

Thursday, April 14, 2011

Gulf Keystone Boosts Estimates from Shaikan Discovery

Gulf Keystone Boosts Estimates from Shaikan Discovery

Thursday, April 14, 2011
Gulf Keystone Petroleum Ltd.

Gulf Keystone announced a major revision of the gross oil-in-place volumes for the Shaikan discovery in the Kurdistan Region of Iraq.

The revised gross oil-in-place volumes for the Shaikan discovery, as calculated by Dynamic Global Advisors (DGA), independent Houston-based exploration consultants, are a P90 value of 4.9 billion barrels to a P10 value of 10.8 billion barrels of oil-in-place with a mean value of 7.5 billion barrels and a P1 value of 15 billion barrels.

This is a very significant upward revision from the previously announced range of 1.9 to 7.4 billion barrels of gross oil-in-place with a mean value of 4.2 billion barrels and a P1 value of 13 billion barrels, also calculated by DGA. The revision is based on the data acquired since the last resource evaluation of the Shaikan discovery by DGA issued in January 2010, which was supported by an additional third party analysis by Ryder Scott consultants with a range of gross total petroleum-initially-in-place (PIIP) of 1.52 (P90) to 7.52 (P10) billion barrels.

The new data has been acquired as a result of:

* Shaikan-2 oil discovery and well test in the upper section of the Jurassic section, nine km to the east of Shaikan-1
* Shaikan-1 extended well test production
* Shaikan-3 testing and production results
* Preliminary results of the analysis of 3D seismic data acquired for the Shaikan (599km²) and Sheikh Adi (215km²) blocks
* Evaluation of existing seismic lines and regional geological data for the Ber Bahr, Akri-Bijeel (Bijeel-1 well) and Sheikh Adi blocks.
* PVT (pressure, volume, temperature) analysis of oil samples from the Triassic Kurre Chine tests at Shaikan-1.

The Shaikan-2 appraisal well is now drilling deeper into the Jurassic and is scheduled to drill on into the Triassic. Once the well reaches TD at the bottom of the Triassic or into the top of the Permian interval, the Company will consider a possible further revision of the Shaikan oil-in-place volumes, taking into account additional information from the reservoirs previously only penetrated by Shaikan-1 and from potential additional discoveries from possible zones below those reached by Shaikan-1, projected by DGA to contain an additional 1 to 5 billion barrels of prospective resources.

John Gerstenlauer, Gulf Keystone's Chief Operating Officer, commented, "We have always believed that the initial gross oil-in-place range for the Shaikan discovery was a conservative estimate that would increase as more information became available. This gross oil-in-place volumes revision by DGA, entirely supported by the Company's management and Board of Directors, confirms that belief. We eagerly look forward to additional drilling results from Shaikan-2, the soon to be spudded Shaikan-4 and the remainder of the Shaikan appraisal drilling program. We firmly believe that even with this upward revision the numbers for the Shaikan discovery are still conservative."

Wednesday, April 13, 2011

Seadrill Sells West Juno Rig

Seadrill Sells West Juno Rig

Wednesday, April 13, 201
Seadrill Ltd.

Seadrill has entered into an agreement to sell the newly built jack-up drilling rig West Juno to an undisclosed buyer incorporated in the UK for a total consideration of US $248.5 million.

Seadrill expects to record a gain on sale of approximately US $18 million on closing. Closing of the agreement and the transfer of ownership of the unit is scheduled upon completion of the rig's present drilling assignment late second quarter or early third quarter 2011. Seadrill expects to have an EBITDA contribution from the rig in the period up to closing of approximately US $6 million.

Alf C Thorkildsen, CEO of Seadrill Management AS, said, "We are continuously evaluating sale and purchase opportunities in order to maximize the long term return for our shareholders. This dynamic approach can from time to time lead to divestments and reallocation of capital. We have through the sale of West Juno at an attractive price been able to monetize the underlying strength of the jack up market. Although we remain optimistic on the market outlook for premium jack-up rigs, we have decided to relocate the proceeds to fund investment in other new unit as we since October 2010 have committed to investing US $4.7 billion in newbuildings."

Seadrill's fleet of jack-up rigs remains the world largest modern jack-up fleet with a total of 19 units built after 2006. Furthermore Seadrill has options for construction of further six units at attractive prices compared to going market prices.

Tuesday, April 12, 2011

Statoil, Partners Sign $1.5B EPC Contract with Petrofac

Statoil, Partners Sign $1.5B EPC Contract with Petrofac

Tuesday, April 12, 2011
Statoil

Statoil, BP and Sonatrach have signed a USD 1.15 billion engineering, procurement and construction (EPC) contract with Petrofac International (UAE) LLC in Algiers for the execution of the In Salah Southern Fields development project.

The EPC contract is part of the phase two development of the In Salah license. For Development and Production International the project marks an important step towards maturing barrels for profitable production.

The three gas fields – Krechba, Teg and Reg – located in the northern part of the license, were initially developed in phase one, with the objective of delivering a production profile of nine billion cubic meters of gas annually. This phase started in late 2001, and first commercial gas was delivered in July 2004.

Based on the expected decline of gas production from these three fields, phase two of the development has now implemented to maintain the production plateau and sustain long-term gas sales commitments. It consists of four gas fields – Garet El Bifna, Gour Mahmoud, In Salah and Hassi Moumene – in the southern part of the license.

Under the EPC contract Petrofac will build a number of facilities – including well pads, manifolds, flowlines, and a new central processing facility (CPF) with a gas processing capacity of 17 million cubic meters per day. The CPF will be constructed north of In Salah town and tied back to the existing producing facilities located in Reg for further transport of the gas to Krechba CPF for carbon dioxide removal and gas export.

In his speech, Victor Sneberg, Statoil's country president in Algeria, stated his expectation to Petrofac to deliver on time, cost and schedule.

First gas from the Southern Fields development project is expected for the first half of 2014. Gas produced from In Salah is marketed by joint marketing company "In Salah Gas Limited" – an association between Sonatrach, BP and Statoil. The three partners in the In Salah license have investment shares of 35% (Sonatrach), 33.15% (BP) and 31.85% (Statoil), respectively.

Monday, April 11, 2011

TGS Strengthens PMS Position with Stingray Acquisition

TGS Strengthens PMS Position with Stingray Acquisition

Monday, April 11, 2011
TGS-NOPEC Geophysical Co. ASA

TGS has entered into an agreement to acquire 100% of the shares of Stingray Geophysical Limited (Stingray). The transaction will provide TGS with a strong position in the rapidly growing market for Permanent Reservoir Monitoring (PRM) solutions. The acquisition will substantially increase TGS' addressable market through access to production seismic spending from large international oil companies as well as national oil companies (NOCs), while maintaining its successful asset light model.

Robert Hobbs, CEO of TGS said, "The age of "easy to find" oil is over, forcing oil companies to increase investment in their existing fields to extend production and increase recovery factors. The acquisition of Stingray allows TGS to access a larger portion of the reservoir optimization market. The combination of TGS and Stingray will leverage both companies' strengths to create a powerful PRM offering to the industry."

Martin Bett, Managing Director of Stingray added, "TGS brings complementary capabilities, a global organization, established seismic project management skills and financial strength to Stingray. As a part of TGS, Stingray is now well positioned to deliver innovative PRM solutions that will assist our clients to increase production and reserves whilst decreasing risk and costs of their Enhanced Oil Recovery programs."

The 4D seismic market, of which PRM is an integral and increasing part, was estimated to be over USD 1 billion in 2010 with the majority of data being acquired by towed streamers (source: ODS PetroData). Expectations are for the 4D market to exceed USD 2.5 billion within the next four years (source: Stingray estimate). New PRM installations are expected to trend towards optical versus electrical solutions due to the expected increase in reliability and flexibility that this technology offers, especially in deep water.

The transferred assets include 11 employees and an extensive portfolio of intellectual property. All management team members and employees of Stingray will continue as employees of TGS.

The consideration for 100% of the shares is based on an initial payment of USD 45 million and incremental payments of up to USD 35 million based on the success in commercializing the technology.

The transaction is expected to complete in April 2011.

KazMunaiGas Scoops Up 4 Blocks

KazMunaiGas Scoops Up 4 Blocks

Monday, April 11, 2011
JSC KazMunai Gas Exploration Production

KazMunaiGas announced agreements reached with the JSC National Company KazMunayGas ("NC KMG") to acquire four hydrocarbon exploration contracts.

As per the agreement, KMG EP acquires the following four contracts: Temir, Teresken, Karaton-Sarkamys and the territory adjacent to Uzen and Karamandybas.

Temir and Teresken blocks are located in the Aktobe region in close proximity to the assets of Kazakhoil Aktobe LLP and Kazakhturkmunai LLP, as well as other assets, which may be of interest to KMG EP. The geographic location of the contract area has several advantages, including infrastructure and logistics.

The territory adjacent to Uzen and Karamandybas is located in the area of operations of Uzenmunaigas production facility. Block Karaton-Sarkamys is located in the Atyrau region 100km south-west of the Kulsary deposit in the area of operations of Embamunaigas production facility.

The acquisition cost of the four contracts is USD $40 million. The transactions will be financed from KMG EP's own funds.

According to the Company's estimates, the geological resources on four blocks are around 1.5 billion barrels of oil equivalent.

The terms of the contracts on the territory adjacent to Uzen and Karamandybas, Karaton-Sarkamys block and Temir, is 6 years from 2010, with the right of extension until 2019. With regard to the Teresken block, the license is for 6 years, starting in 2006, with the right of extension until 2015.

Significant synergies can be achieved through the use of the existing infrastructure of Embamunaigas and Uzenmunaigas production facilities in Atyrau and Mangistau regions, which will help to optimize capital and operating costs.

It is anticipated that the acquired assets will enhance the quality of the Company's on-shore projects portfolio and, in case of successful exploration, will increase the Company's recoverable reserves in the medium term, including Uzen and Emba groups of fields.

Askar Balzhanov, CEO of KMG EP, said, "The acquisition of these contracts is another step towards the implementation of the Company's strategy to grow via acquisitions and expansion of exploration. KMG EP has repeatedly stated its intention to purchase these four blocks, and now the agreement is reached. The Company will continue its search for highly promising assets, acquisition of which will serve the interests of all shareholders."

The acquisition was approved by the Board of Directors of KMG EP and the Board of Directors of NC KMG. Approvals of the Government regulators have been received.

The closing of the deal is expected in the second quarter of the current year.

Asian stocks struggle to eke out gains as investors worry about surging oil prices

Asian stocks struggle to eke out gains as investors worry about surging oil prices

April 11 ,2011
By AssociatedPress

HONG KONG — Most Asian stock markets fell Monday as investors continued to worry about soaring oil prices and Japan’s struggle to recover from its worst-ever earthquake.

Japan’s Nikkei 225 stock average dipped 0.5 percent to 9,717.84 while South Korea’s Kospi edged down 0.3 percent to 2,121.49. Benchmarks in Taiwan, Singapore and India also fell while Hong Kong’s Hang Seng index was nearly flat at 24,397.44.

Australia’s S&P/ASX 200 was up 0.7 percent at 4,972.70 while mainland China’s Shanghai Composite Index rose 0.7 percent to 3,051.38.

Oil prices hovered at 30-month highs near $113 a barrel Monday in Asia as traders eyed a wobbly U.S. dollar and fresh Middle East tension.

“Oil prices are now at levels that have historically acted as a marked constraint on global output,” Daragh Maher, a foreign exchange strategist at Credit Agricole CIB, said in a research note.

Benchmark oil for May delivery slipped 11 cents to $112.68 a barrel in electronic trading on the New York Mercantile Exchange. The contract rose $2.49, or 2.3 percent, to settle at $112.79 on Friday and set new 30-month highs almost every day last week.

Oil-related stocks were benefiting from the rising prices. Sinopec, Asia’s largest refiner by capacity, was up 2.4 percent to $4.10 Hong Kong dollars while PetroChina, the country’s biggest oil and gas producer, jumped 4 percent.

Companies with big fuel bills, like airlines, were suffering. Korean Air Lines Co. Ltd. dropped 3.7 percent, Qantas Airways Ltd. fell 2.7 percent, and Cathay Pacific Airways Ltd. was down 0.9 percent.

Oil moved higher as the dollar plunged against other major currencies. Oil is traded in dollars and tends to rise when the greenback falls and makes crude cheaper for investors holding foreign currency.

Some analysts were warning investors to avoid shares in Japanese automakers, whose production was severely curtailed by power outages and supply chain disruptions following the March 11 earthquake and tsunami. The twin disasters decimated the country’s northeastern coast, causing $310 billion in damage, killing up to 25,000 people and setting off a radiation leak at a nuclear power plant that was still not under control.

“We have turned bearish on the auto sector,” Citigroup Global Markets said in a report. The company said that the full extent of damage to the industry “is being underestimated by the market ... and we would avoid the sector as things stand.”

Shares of Toyota Motor Corp., the world’s No. 1 automaker, tumbled 2.5 percent. Nissan Motor Corp. drooped 2.2 percent, and Honda Motor Corp., slid 1.9 percent.

Japanese shares also fell after a report showed that machinery orders fell 2.4 percent in February, before the devastating earthquake and tsunami struck. Orders had risen 4.2 percent in January.

Chinese shares rose after the country reported a small trade surplus of $140 million in March, up from a deficit of $7.3 billion the month before.

“Chinese trade balance figures came out above analysts’ forecasts and provided some support to the Shanghai Composite, which is currently the best performer in the region,” said Chris Weston, a research analyst at IG Markets.

Oil prices are a concern in China, but there’s “still much liquidity, which means the stock market can still go higher,” said Linus Yip, chief strategist at First Shanghai Securities.

In New York on Friday, stocks were weighed down by oil prices as well as the threat of a government shutdown. But that risk was averted after the market closed when lawmakers agreed to a last-minute deal to cut about $38 billion in federal spending.

The Dow Jones industrial average lost 0.2 percent to close at 12,380.05. The Standard & Poor’s 500 index slipped 0.4 percent to 1,328.17. The Nasdaq composite lost 0.6 percent to 2,780.42.
In currencies, the dollar slipped to 84.79 yen from 84.89 yen late Friday. The euro stood at $1.4460, up from $1.4435 late Friday, its strongest level since January 2010.

Sunday, April 10, 2011

Partnership in clean energy prospers

Partnership in clean energy prospers

Apr 11, 2011
Guy Warrington

While fossil fuels may have been the framework within which energy co-operation between the UK and the UAE began, we are now increasingly focusing on working together to develop and pioneer new technologies based on alternative and renewable energy.

The Abu Dhabi Future Energy Company's Masdar City is the prime example. This features the expertise of British companies such as Foster+Partners, which has designed the city's Master Plan and completed the recently inaugurated Masdar Institute, and Mott MacDonald, which is delivering infrastructure development and design.

The Masdar Institute complex uses 51 per cent less energy than a typical building of its size.
Further collaboration between the UK and the UAE is reflected in the work being done on the London Array, an offshore wind farm under construction in the Thames Estuary, which will generate enough power for almost 500,000 homes.



Its first foundations were installed last month, and it is expected to become the world's largest offshore wind farm when completed. Mubadala Development, a strategic investment company owned by the Abu Dhabi Government, has invested more than Dh1.7 billion (US$462.8 million) in this project through Masdar.

Both our governments recognise that energy sources of the future must diversify. However, in the short term, reality will follow vision only if profitability is not compromised.

Adapting to an uncertain climate: a world of commercial opportunities, an Economist Intelligence Unit report commissioned by UK Trade & Investment, focuses on the commercialisation of low-carbon goods and services.

About 150 companies based in the Gulf, among a global total of more than 700, were polled about the potential business opportunities involved in adapting to anticipated changes in the global climate.


The results show that while the Middle East and Africa are right on the global average in responding actively in terms of planning or adapting to the effects of climate change, the UAE is well above the average in taking action on these issues. This is not surprising, given the leadership the UAE has shown in committing to a low-carbon economy, which is leading a drive of wider engagement by the business community.

It has become clear that successful businesses of the future will be those that see the opportunities, and act on them.

Many British companies, such as Atkins, the engineering consultancy responsible for UAE landmarks such as the Burj Al Arab and the Dubai Metro, have embraced the challenge, building adaptation into their short and long-term business plans. Professional service companies, such as PricewaterhouseCoopers in the UK, have teams to help businesses capitalise on climate-fuelled opportunities, as well as manage the risks.


The British government is also working to boost investment and create innovation in the UK energy market by creating a green investment bank, and launching an ambitious electricity market reform programme.

These present great opportunities for future partnership, especially given the UAE's commitment to being a world-class low-carbon leader.

Areas for future development include the world's largest offshore wind regime and new nuclear power construction across the UK.

While climate change is an issue that will affect businesses in all sectors of the economy, creating, identifying and acting on opportunities for innovation and commercialisation are significant.

By working together in partnership, as governments and through enterprise, the UK and the UAE can lead the way in securing prosperity through adaptation, for today, and for generations to come.