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Showing posts with label plans. Show all posts
Showing posts with label plans. Show all posts

Tuesday, September 13, 2011

Oil India Plans to Invest $4B in Five Years to Raise Output

- Oil India Plans to Invest $4B in Five Years to Raise Output

Tuesday, September 13, 2011
Dow Jones Newswires
NEW DELHI
by Rakesh Sharma

Oil India plans to raise its capital expenditure 73% to about INR190 billion ($4 billion) in the five years starting April 2012 as the state-run explorer seeks to sharply raise oil and gas production, its finance director said.

"We are stepping up exploration and development of our blocks in India and overseas," T.K. Ananth Kumar told Dow Jones Newswires late Monday. "We are also seeking producing assets, so we have raised our capital expenditure plans."

The company's capital expenditure in the five years ending March 2012 is likely to be about INR110 billion. It accounted for a 10th of India's total oil output of 754,000 barrels a day and 4.5% of total gas output of 52.22 billion cubic meters in the last financial year. Kumar didn't say how much the company is aiming to produce.

Oil India will mainly fund its investments through internal accruals, but may raise debt, he said.

The company, which was listed on local stock exchanges in September 2009, has cash reserves of INR130 billion, he added.

Oil India and its bigger state-run rival Oil & Natural Gas Corp. need to boost capital spending to bring new fields into production amid falling output at their aging fields. India, which imports about four-fifths of its crude oil requirements, is encouraging explorers to ramp up exploration and production to meet surging demand for energy in the world's second-fastest growing major economy.

"We have been witnessing an increase in capex by oil and gas explorers in India for the past several years as energy security is a focus. This sort of high capex is quite achievable by Oil India considering they have more than INR120 billion of cash and have been generating a cash flow of about INR40 billion per year," Alok Deshpande, analyst with Elara Securities Ltd., said.

Oil India is seeking to acquire producing oil and gas assets in Australia, Russia, Kazakhstan and Canada, Kumar said.

"We have shifted our focus to acquiring producing assets, rather than going for exploration blocks, as we already have our hands full with existing exploratory blocks. Also, we have enough cash in hand and that would be the best use of it," Kumar said.

Oil India is in talks with French explorer Etablissements Maurel et Prom to buy a stake in its Gabon assets and plans to close the deal by March, Mint newspaper reported Monday. Kumar declined to comment on the report.

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

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Monday, September 12, 2011

CNOOC Okays ConocoPhillips' Plans for Depressurizing and Sealing

- CNOOC Okays ConocoPhillips' Plans for Depressurizing and Sealing

Monday, September 12, 2011
CNOOC Limited

CNOOC Limited (the "Company") announced that State Oceanic Administration of People's Republic of China ("SOA", according to its decision on September 2, 2011, required ConocoPhillips China Inc ("COPC"), the Operator of Penglai 19-3 oil field to, on the condition of imposing no further environmental damage, develop an effective plan for fluid discharge and depressurization ("Depressurization Plan") in order to ensure safety of the field, protect the reservoir as well as reduce reservoir pressure. In addition, the Operator is required to develop a drilling plan for sealing seep sources ("Sealing Plan"). Those Plans should receive approval from China National Offshore Oil Corporation ("CNOOC").

On Sunday, CNOOC announced that it has approved such Depressurization Plan and Sealing Plan.

According to the Depressurization Plan, a number of wells in the field will be restarted to discharge the fluid from the reservoir and to reduce the pressure. The Plan will be implemented step by step. The general principle for depressurization established in the Plan is to discharge fluid and reduce pressure from the wells located at the high pressure zones or near the natural fault.

According to the Sealing Plan, the Operator will carry out the drilling activities and other related operations on six wells in the area of Platform B and C, as additional measures for sealing seep sources.

CNOOC requires the Operator to strengthen its monitoring of the dynamic reservoir condition, in particular the reservoir pressure during the process of fluid discharge and depressurization. Such monitoring results need to be reported to CNOOC in a timely manner. For the Sealing Plan, CNOOC also requires the Operator to ensure the safety of relevant operations.

As the non-operator, the Company will continue to assist COPC to ensure the implementation of those Plans.

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Thursday, September 8, 2011

GOM Outlook Brighter as Noble Plans 2012 GOM Plans

- GOM Outlook Brighter as Noble Plans 2012 GOM Plans

Thursday, September 08, 2011
Rigzone Staff
by Karen Boman

Noble Energy sees a brighter outlook for the Gulf of Mexico from a year ago, Noble Energy Chairman and CEO Charles D. Davidson said at the Barclays Capital 2011 CEO Energy Conference earlier this week.

While the pace of Gulf of Mexico permitting is slower than that prior to the drilling moratorium following the Macondo oil spill, the pace is more predictable and comfortable as Noble moves forward with its 2012 drilling plans for the Gulf, Davidson said.

The company was the first to receive a deepwater permit after the moratorium's end for its Santiago prospect on Mississippi Canyon Block 519 in 6,500 feet of water; the company announced in May that it had encountered 60 feet of oil pay in a high-quality Miocene reservoir at Santiago. The company is now drilling an updip sidetrack at its Deep Blue discovery in approximately 4,700 feet of water – with drilling results expected in a few weeks -- and will next appraise the Gunflint discovery on Mississippi Canyon Block 948.

Noble had drilled a downdip discovery at Deep Blue, but work was halted due to the moratorium, Davidson said. The company originally encountered 32 feet of net pay in the well; the updip sidetrack is targeting 90 to 200 million BOE gross unrisked, with the chance of success increased from 30 percent to 50 percent. Noble is using Ensco semisubmersible Ensco 8501 for its drilling program in the Gulf.

The company anticipates production from its South Raton discovery to come online late this year and production from its Galapagos project to begin in early 2012, Davidson said. As part of the Galapagos project, Santiago and the Santa Cruz and Isabela discoveries on Mississippi Canyon blocks 563 and 562 will be tied back subsea to the Na Kika production platform. Noble's net production at Galapagos will be over 10,000 b/d of oil.

Noble estimates total gross resources discovered in the Galapagos project, including Santiago, to be 130 million barrels BOE, approximately 75 percent of which is oil, and sees multiple low-risk follow-on opportunities of 65 million BOE gross mean potential. Work is progressing on the topsides and subsea loop system for the project.

Noble's current U.S. Gulf portfolio includes 102 lease blocks covering approximately 400,000 net acres and around 40 prospects and 1.9 billion BOE net of net unrisked resources.

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Tuesday, September 6, 2011

Sunoco Announced It Plans To Exit Refining Business

- Sunoco Announced It Plans To Exit Refining Business



Sep 6, 2011

Sunoco (NYSE:SUN) announced that it plans to exit its refining business and has begun a process to sell its refineries located in Philadelphia and Marcus Hook, Pennsylvania. The company also announced it is conducting a comprehensive strategic review of the company to determine the best way to deliver value to shareholders.

Lynn L. Elsenhans, Sunoco's chairman and chief executive officer said, "We have made progress in increasing the efficiency of our refineries over the last several years, but given the unacceptable financial performance of these assets, it is clear that it is in the best interests of shareholders to exit this business and focus on our profitable retail and logistics businesses which have higher returns, growth potential, and provide steady, ratable cash flow."

Sunoco has a potential upside of 27% based on a current price of $36.11 and an average consensus analyst price target of $45.86.

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Monday, August 15, 2011

Doyon Plans New Interior Gas Exploration Effort in Nenana Basin

- Doyon Plans New Interior Gas Exploration Effort in Nenana Basin

Monday, August 15, 2011
Alaska Journal of Commerce
by Tim Bradner

Doyon Ltd., the Interior Alaska Native regional corporation, is planning new seismic work this winter in the northern part of the Nenana Basin, an Interior Alaska basin about 60 miles west of Fairbanks that is considered gas prone but also has oil potential.

About 120 miles of two-dimensional seismic is planned for this winter, according to Jim Mery, Doyon's vice president for lands. The seismic will set the stage for a possible exploration well drilled in the area, he said. It would be the second test well drilled in the Nenana Basin in recent years.

Doyon is an Alaska Native development corporation with about 11 million acres of surface and subsurface land holdings in Interior Alaska. The Nenana Basin project is on state-owned lands held under an exploration license, a form of state lease. The license area includes 483,000 acres of general state lands and an additional 9,500 acres of lands owned by the Alaska Mental Health Trust Authority, a state agency that leases its lands to support mental health programs.

Mery said Doyon plans to press ahead with exploration in spite of an announcement by Golden Valley Electric Association, the regional electric utility, and Flint Hills Resources, operator of a refinery near Fairbanks, that they will pursue a project to truck liquefied natural gas from the North Slope.

The Fairbanks area is a near-term market for any gas discovered in the Nenana Basin, although a 60-mile pipeline would be needed to bring the gas to the Interior city.

On the other hand, a plan by the state of Alaska to pursue a 24-inch pipeline built from the North Slope to Southcentral Alaska would have its line pass through the Nenana Basin near where Doyon plans exploration. If gas is discovered, and if the pipeline is built, Doyon could ship its gas to Southcentral Alaska through the pipeline.

"There are a lot of moving parts to the pipeline and natural gas picture, and our decision is to move ahead with our plans," Mery said.

Doyon and three partners drilled a well two years ago in the southern part of the basin with mixed results. No gas was found but there were indications that hydrocarbons were present in the region. Doyon's partners in the Nenana Basin exploration have been Arctic Slope Regional Corp., another Native development corporation with holdings on the North Slope, and Usibelli Energy LLC, an affiliate of Usibelli Mines, which operates a coalmine near Healy, also in Interior Alaska.

Mery said this winter's program will involve the first seismic done in the northern part of the Nenana Basin, which is believed to hold the deepest part of the basin, with sedimentary rocks possibly as deep as 16,000 feet.

State geologists have said the basin exhibits somewhat similar geology to the prolific Cook Inlet basin in southern Alaska and is generally considered prospective for natural gas. A geologic assessment of the basin indicated the possibility of 3 trillion cubic feet of technically recoverable thermogenic gas in the basin, with the possibility of additional biogenic gas. There were two earlier exploration wells drilled, by Unocal in 1962 and ARCO in 1984, but the wells were drilled at the far southern, and shallowest, part of the basin and were unsuccessful.

A key advantage of Nenana Basin gas for the state's 24-inch pipeline is that a 500 million cubic feet per day limit that applies to the state project because of its contract with TransCanada Corp. does not apply to gas found in Interior Alaska and shipped through the pipeline, said Dan Fauske, president of the Alaska Gasline Development Corp., the state corporation planning the 24-inch pipeline.

The state's 24-inch pipeline could move 500 million cubic feet per day from the North Slope to comply with the TransCanada contract and any gas from the Nenana Basin could be above that amount, Fauske told legislators in recent briefing.

TransCanada and ExxonMobil Corp. are planning a 48-inch pipeline built from the North Slope to Canada and are working with incentives offered by the state. As a part of the agreement the state is limited in helping a competing pipeline that would ship more than 500 million cubic feet per day from the slope.

The 500 million cubic feet per day limit is a source of frustration to many state legislators because it limits the development of industrial customers who would need more than the gas that could be delivered under the limit. Industrial customers are needed for the 24-inch pipeline build to Southcentral Alaska to be economically viable.

Copyright (c) 2011, Alaska Journal of Commerce, Anchorage

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Friday, August 12, 2011

HRT Plans to Drill 65 Wells by End-2014

- HRT Plans to Drill 65 Wells by End-2014

Friday, August 12, 2011
Dow Jones Newswires
RIO DE JANEIRO
by Diana Kinch

Brazilian oil and gas company HRT Participacoes em Petroleo, plans to drill 65 exploration wells and develop production at 52 wells by the end of 2014 in a $3.14 billion expenditure program, the company said Friday.

HRT is drilling its first wells in Brazil's Solimoes Basin and in Namibia this year, chief executive Marcio Rocha Mello told analysts on a conference call. The company's net potential resources at the two sites were recently announced at a total of 7.9 billion barrels of oil equivalent.

HRT has a cash position of 2.2 billion Brazilian reais ($1.37 billion) to finance its development program, the executive said.

"We have a queue of people knocking on our door to join the Namibia project," he said.

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

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Tuesday, August 9, 2011

GM Plans To Halve The Number Of Vehicle Frames

- GM Plans To Halve The Number Of Vehicle Frames



Aug 9, 2011

General Motors (NYSE:GM) plans to be leaner in the future by halving the number of car and truck frames its uses worldwide.

The company also says it plans to increase factory capacity 45% in Brazil, Russia, India and China by 2014 to take advantage of growth.

GM made the statements Tuesday in slide presentations for its annual global business conference for industry analysts.

The slides say that GM built cars and trucks on 30 specific frames last year. That number would be cut to 14 by 2018, saving on engineering, design and manufacturing costs.

The company also plans to keep its investment in research and development steady, even when car sales are down. That will save money by terminating the practice of stopping and starting projects.

General Motors has a potential upside of 71.6% based on a current price of $25.21 and an average consensus analyst price target of $43.25.

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Wednesday, August 3, 2011

Double Eagle Petroleum Briefs 2011 Exploration, Development Plans

- Double Eagle Petroleum Briefs 2011 Exploration, Development Plans

Wednesday, August 03, 2011
Double Eagle Petroleum Co.

Double Eagle Petroleum announced an update to its 2011 drilling program and is providing guidance on its 2012 expected drilling programs. The Company's development program will be focusing on its two major development fields, the Atlantic Rim CBM and the Pinedale Anticline. The major exploration projects are the Niobrara oil shale target in the Atlantic Rim and the Main Fork Unit in north east Utah. Total estimated capital spending for 2011 projects will be approximately $30 million.

2011 Field Development

In 2011, the Company will be increasing its total net well count in the Catalina CBM Unit 25% by drilling approximately 14 gross (13 net) coal bed methane (CBM) wells in this unit to add to the existing 70 gross (51 net) CBM producing wells. Twelve of these wells are in an exploratory area and the Company will have a 100% working interest in these wells. The Company will have a 73% working interest in the two development wells in the existing unit participating area.

Anadarko will be drilling 25 exploration wells in the newly formed Spy Glass Unit which includes the Sun Dog and Doty Mountain participation areas. The exploration wells for 2011 were required by the Spy Glass Unit agreement. The Company will have no interest or costs associated with these wells, but the data obtained will be valuable in determining the nature and extent of the CBM field, which will aid future field development.

The approved Atlantic Rim Environmental Impact Study allows for a total 1,800 CBM wells and 200 conventional (non-coal bed methane) wells. Double Eagle, together with Anadarko Petroleum, are the operators of various units in the Atlantic Rim and as of June 30, 2011 a total of 400 CBM wells have been drilled (no conventional wells). Currently, the Company has 123 approved CBM drilling permits and Anadarko has approximately 30 approved CBM drilling permits for future drilling in the Atlantic Rim.

Also, Double Eagle will participate in the drilling of 16 (gross) new production wells in the Mesa Unit on the Pinedale Anticline, which is an increase of 10 (gross) wells from the initial estimate provided by the operator of the Mesa Units, QEP. The Company has an estimated 8.5% working interest in these planned wells.

2011 Exploration Projects

The Company also plans to drill one Niobrara Oil Shale well in which Double Eagle will have an estimated working interest of 93%. The Company initially planned two Niobrara exploratory wells but due to certain lease holders in the area not cooperating in drilling plans, the Company determined that the best location and opportunity to gain formation knowledge was to drill in a section which the Company controlled. The Company is awaiting final permit approval for this well.

The Company also is evaluating further development of the Main Fork Unit Project (formerly known as Christmas Meadows/Table Top Unit). The Company previously drilled the Table Top Unit #1 well in 2007. The Company is working with a major integrated oil and gas company that has option farm-in rights to advance further unit delineation, assist with costs related to seismic, environmental analysis and, if necessary, an exploratory well. Assuming the farm-in right is exercised; Double Eagle will have a 12%-16% working interest after payout.

Prior seismic data has been reprocessed and a LIDAR (Light Detection and Ranging) survey has been conducted. Preliminary development well locations, pipelines and roads have been identified as part of a full field development environmental impact study being conducted by the USFS. In 2011, surveying and associated archeological and biological studies are being conducted along with a source test in preparation for a potential 2D seismic acquisition program in 2012.

2012 Development Projects

Looking ahead into 2012, the Company's initial plans are to continue development in our two main fields. In the Atlantic Rim, the Company plans to drill 14 new CBM production wells in the Catalina unit, 25 new CBM wells in the Anadarko operated Doty Mountain Unit and, depending upon the results of the initial test well, several Niobrara wells. In the Pinedale Anticline, the Company anticipates 16 new wells to be drilled in 2012. The Main Fork Project is expected to proceed as mentioned above.

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Monday, July 18, 2011

Crimson Updates Production Activity, Ups 2011 Capital Plans

- Crimson Updates Production Activity, Ups 2011 Capital Plans

Monday, July 18, 2011
Crimson Exploration Inc.

Crimson Exploration Inc. on Monday provided an operational update and announced an increase in its 2011 capital program.

In Liberty County, TX, the Catherine Henderson #B-4 (64.0% WI) commenced production at a gross daily rate of 1,379 Boepd, or 721 barrels of condensate, 208 barrels of natural gas liquids and 3.2 Mmcf of natural gas on a 13/64th choke and 7,000 psi of flowing tubing pressure. This well was drilled to a total measured depth of 15,338 feet in the Lower Cook Mountain formation. Approximately one mile to the northwest, Crimson has drilled the Catherine Henderson A-10 (66.0% WI), targeting the Cook Mountain formation, to a total measured depth of 13,742 feet. Completion operations are scheduled to begin by the end of July with first production in early August.

In Zavala County, TX, Crimson completed the KM Ranch #1H (50.0% WI), targeting the Eagle Ford Shale, and has commenced flow-back operations with results expected in mid-August. The well was drilled to a total measured depth of 12,627 feet, including a 5,800 foot lateral and 20 stages of fracture stimulation. The KM Ranch #1H represents Crimson’s first well in Zavala County where Crimson has an estimated 147 drilling locations and approximately 2,300 net acres held by production. Crimson anticipates spudding the KM Ranch #2H (50.0% WI) in the beginning of November subsequent to spudding its first well in the Booth-Tortuga Area, approximately 13 miles to the southwest of the KM #1H, in the beginning of October.

In Karnes County, Texas, Crimson spud the Littlepage McBride #2H (53.0% WI), targeting the Eagle Ford Shale formation, which is drilling at 8,480 feet toward an estimated total measured depth of 15,850 feet. Completion operations are expected to begin mid-third quarter with initial production to follow in September. The Littlepage McBride #2H is located approximately 0.6 miles to the east of the Littlepage McBride #1H well (53.0% WI) which is currently producing 525 Boepd and has produced a cumulative 53,000 Boe since coming online in early April. Due to the success experienced in Karnes County, we have planned a continuous drilling program for the remainder of the year, commencing a well per month beginning in August.

Updated 2011 Capital Program

Crimson’s Board of Directors recently approved increasing its 2011 capital budget to $78 million, a 30% increase, to accelerate oil weighted drilling activities in Zavala, Dimmit and Karnes Counties. This decision was made based on Crimson’s extensive portfolio of drill ready oil opportunities and recent success. The increase in capital expenditures marks the beginning of an Eagle Ford development program that represents a strategic shift to oil and liquids rich projects in proven areas. As a result, preliminary internal forecasts indicate Crimson’s production mix will be over 40% crude oil and natural gas liquids by January 2012 and over 50% crude oil and natural gas liquids by the second quarter of 2012.

Second Quarter 2011 Production

Crimson produced approximately 4.4 Bcfe of natural gas equivalents, or an estimated 48,740 Mcfe per day, during the second quarter 2011, compared with 2.7 Bcfe, or 30,084 Mcfe per day, produced during the second quarter of 2010, a 62% increase period over period. The second quarter production results were in line with management’s guidance.

Crimson Exploration is a Houston, TX-based independent energy company engaged in the acquisition, development, exploitation and production of crude oil and natural gas, primarily in the onshore Gulf Coast regions of the United States. The Company owns and operates conventional properties in Texas, Louisiana, Colorado and Mississippi, approximately 12,000 net acres in the Haynesville Shale, Mid-Bossier, and James Lime plays in San Augustine and Sabine counties in East Texas, approximately 6,700 net acres in the Eagle Ford play in South Texas and approximately 11,000 net acres in the Denver Julesburg Basin of Colorado.

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American Petro-Hunter Plans 11 Horizontal Wells for Okla. Project

- American Petro-Hunter Plans 11 Horizontal Wells for Okla. Project

Monday, July 18, 2011
American Petro-Hunter

American Petro-Hunter is pleased to announce updated plans regarding the Company's continued participation in a proposed field development horizontal drilling program of the Mississippi formation at the North Oklahoma Project.

Based on the commercial success of the recent NOM-1H horizontal well, the Company and working interest partners have determined that the development plan for this newly defined Mississippi oil and gas reservoir can accommodate the drilling of a minimum of 11 horizontal wells.

The drilling schedule, which includes direct offsets to the producing NOM-1H, will involve the drilling of approximately one horizontal Mississippi well every 30 to 60 days with plans to commence the program in early September. The schedule allows for a predictable time frame to drill, complete and put in requisite production facilities for both oil sales plus a gas line hook up every other month.

This aggressive drilling schedule signifies there will be well drilling, completion and potential production activity on the Ripley project leases for the remainder of 2011 and throughout 2012. In total, 12 production wells are targeted for the full development of the project.

The operator has further advised the Company that the same group of professional oil and gas contractors and engineers will be involved in all aspects of the engineering design, vertical and directional drilling of the proposed program as the group performed well above expectations on the drilling and completion of the NOM-1H well.

Company President Robert McIntosh states, "We couldn't be more pleased with the proposed engineering plans to drill 11 more horizontal wells on the Ripley leases. Our commitment to this project is indicative of how this area has become a core asset and means we aim to be very busy drilling wells in this area for the foreseeable future. The continued success of this project is poised to dictate our growth and will prove instrumental in meeting our long range production targets."

About American Petro-Hunter, Inc. (OTC.BB:AAPH - News)
The Company is a goal-oriented exploration and production (E&P) Company aiming to become an intermediate level oil and gas producer within 12 months. The Company is in production at the Poston Project in Trego County, Kansas and the North Oklahoma Project. With the achievable target of becoming a 1,000 BOE producer as our goal, American Petro-Hunter is actively on the "hunt" for domestic petroleum assets. Visit us at: www.americanpetrohunter.com

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Friday, July 8, 2011

Faroe Clinches Credit Facilities for Future Growth Plans

- Faroe Clinches Credit Facilities for Future Growth Plans

Friday, July 08, 201
Faroe Petroleum plc

Faroe announced the signing of two new banking credit facilities, which provide substantial additional finance to underpin the Company's growth plans.

The two facilities are:
  • NOK 1 billion (approx. £110 million) Norway Exploration Financing Facility, of which NOK 500 million (approx. £55 million) is initially committed by the participating banks, and a further NOK 500 million is available on an uncommitted "accordion" basis. Faroe Petroleum currently has approximately 20 exploration licenses offshore Norway and expects to drill 12 exploration and appraisal wells in Norway by the end of 2013. This facility is designed to have the capability of financing the majority of Faroe's exploration and appraisal costs on the Norwegian Continental Shelf. The facility will mature on 31 December 2014.
  • US $250 million (approx. £156 million) Reserve Base Lending Facility, of which US $125 million (approx. £78 million) is initially committed by the banks, and a further US $125 million is available on an uncommitted "accordion'' basis. This facility is available to finance approved capital expenditure, operating costs and acquisitions. The facility will mature on June 30, 2016, with an amortizing repayment profile from June 2013.

Six participating banks have been selected and brought together as one group to provide the two facilities pro rata. The participating banks are BNP Paribas and Lloyds TSB Bank plc, as Mandated Lead Arrangers, together with Commonwealth Bank of Australia, DnB NOR Bank ASA, Royal Bank of Scotland plc and SEB. BNP Paribas are also acting as Facility Agent and Security Trustee under both facilities, with Lloyds TSB Bank plc acting as Technical and Modelling Bank under the Reserve Base Lending facility.

At 1 July 2011 the Group had cash balances of approximately £84.2m and, together with the cash flow from its existing producing assets, which now include the Blane oil field, and the forthcoming production income from the Brage, Njord, Ringhorne East and Jotun fields in Norway, the Group is well financed.

Commenting on the new facilities, Iain Lanaghan, Finance Director, said, "We are delighted to have concluded this financing exercise, and to have received such strong support from our banks, all of whom took part in a competitive process to participate in these facilities. The new facilities provide us with substantial new funding to support the growth of the Group."

"With an exciting drilling program ahead, of which the majority of wells will be drilled in Norway, the new Norway Exploration Financing Facility provides us with a powerful and efficient means of maximizing our equity participation for minimum cost. The combination of our new Reserve Base Lending facility and strong cash flow from our significantly enhanced portfolio of producing assets ensures that Faroe Petroleum is well funded for investment growth in our core areas."

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Friday, July 1, 2011

Petrobras Production Plans, Brazilian Oil Consumption Impact Oil Exports

- Petrobras Production Plans, Brazilian Oil Consumption Impact Oil Exports

Friday, July 01, 2011
Rigzone Staff
by Karen Boman

Brazil's path to becoming a major oil exporter will depend partially on whether Petrobras' executes its production expansion plans on its proposed time schedule, according to a June 30 report by Barclays Capital.

Since 2000, the nation has gone from having a deficit in oil supply, or implied net imports of 790,000 b/d, to implied net exports at present of 480,000 b/d, a trend that will likely continue as new oil projects are brought on stream over the next few years. Petrobras expects to increase domestic oil production from 2.1 million b/d in 2010 to 3.95 million b/d in 2020, a 6.5 percent year-over-year increase; other companies are planning to add production as well.

However, Barclays sees adding such sizeable volumes on schedule to be challenging. "The pace of output growth in Brazil has consistently fallen short of initial targets in recent years, with actual combined output in 2009-10 coming in some 30 percent below initial International Energy Agency estimates," Barclays said. With a huge investment plan of approximately $214 billion through 2014, and an incremental share of investment to be poured into the development of the pre-salt area, the likelihood of project slippages remains high.

Recent delays in Petrobras' release of its 2011-15 business plan "suggest a possible renewed focus on reducing capex [capital expenditure] costs," Barclays added. "Local content rules and construction backlogs will also likely constrain the speed of development and, in our view, a 5% rate of output increase over the next 10 years should be seen as a positive result."

Barclays also sees risk for Brazilian oil consumption growth to exceed three percent per year, the consensus estimate for consumption growth, in the context of continued healthy economic growth, which means exportable production runs the risk of falling short of 1 million b/d by 2020. Transportation is expected to be a key source of oil consumption growth as car ownership in Brazil is still well below the country's potential, and rising living standards will help drive vehicle penetration higher and, in turn, oil consumption. The transport sector currently accounts for the bulk of Brazil's oil consumption at 60 percent.

"Additionally, the potential for rising infrastructure investment during the period could add a further layer of strength to domestic oil demand and energy demand more generally," Barclays said, adding that it expects primary energy demand to rise by over 40 percent over the next decade.

In spite of having sizeable gas reserves, Brazil's natural gas production has grown slowly in recent years, constrained by transportation and low domestic prices. The country was a net importer as of 2010, with most gas sourced from Bolivia or from deliveries to its two liquefied natural gas (LNG) regasification facilities.

Most of the country's gas production takes place offshore in the Campos Basin; the pre-salt fields offshore Brazil are estimated to contain substantial amounts of gas. Petrobras plan to quickly expand gas production in coming years, anticipating a threefold increase in output by 2020, largely associated with ambitious oil output targets. Achieving these targets, however, will depend on a parallel expansion of pipeline and other infrastructure, especially due to the distance of offshore fields from the Brazilian coastline, Barclays said.
Brazil's Export Outlook

Brazil is the world's largest exporter of coffee, sugar and orange juice, a dominant exporter of meat, soy products and iron ore and an increasingly important producer of oil, corn and other raw materials. Barclays noted that prospects for strong global commodity demand growth over the next 10 years, amid a struggling supply side, implies a high and rising call on Brazilian commodity exports in the coming years.

However, Brazil's infrastructure requires investment to fuel sustainable growth. Barclays quoted the World Economic Forum's 2010-11 global competitiveness report, which ranked Brazil 62nd out of 139 countries for the quality of infrastructure. The report identifies the most problematic areas in the quality of ports, which ranked 123rd, roads, which ranked 105th, air transport infrastructure, which ranked 93rd, and railroad infrastructure, which ranked 87th.

The report noted, "This assessment reflects the appalling state of the transport infrastructure in the country, its underdeveloped railroads, the unexploited potential of its 48000 km of navigable waterways, its congested ports and airports." A survey published in the same report noted that poor infrastructure was the third most problematic factor for doing business in Brazil.

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Thursday, June 23, 2011

Colombia Oil Group Plans $80B Spend, Govt May Sell 10% -Executive

- Colombia Oil Group Plans $80B Spend, Govt May Sell 10% -Executive

Thursday, June 23, 2011
Dow Jones Newswires
LONDON
by Benoit Faucon

Colombia's Ecopetrol group of oil companies is planning to spend $80 billion through 2020 in a bid to produce 1.3 million barrels a day, a top Ecopetrol executive said Thursday.

Hernando Zerda, head of corporate strategy and business performance, said the government may also sell a 10% stake in Ecopetrol, the main shareholder in the group of oil companies mostly operating in the Latin American nation.

Speaking at the World National Oil Companies Congress here, Zerda said the companies of the Ecopetrol group are set for a total capital expenditure of $80 billion during 2011-2020.

The spending will help achieve a goal to produce 1.3 million barrels a day in the Ecopetrol companies--most of it in Colombia--in 2020, up from just above 700,000 barrels a day today, he said.

The majority of the financing will come from cash generation, but "sometime in the future, we will need to issue new shares" potentially representing 10% of the Ecopetrol capital "if prices are good," he said.

Separately, "the government is considering selling 10%" in Ecopetrol, the executive said.

But both considerations are "not confirmed," he said.

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

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Wednesday, June 22, 2011

BP Plans to Build 300 Wells in Oman

- BP Plans to Build 300 Wells in Oman

Wednesday, June 22, 2011
Dow Jones Newswires
LONDON
by Alexis Flynn

BP aims to develop 300 natural gas wells in Oman in what would be one of the company's largest global projects, Chief Executive Bob Dudley said Wednesday.

"Today we have just the three wells (in Oman), the plan is to have 300," Dudley said. Developing tight gas resources in the Gulf State "will be one of the largest projects in BP's portfolio."

Dudley's comments follow a recent report that BP is considering investing $15 billion over 10 years to develop the Block 61 tight gas fields in the country.

Citing the vice-president of BP Oman, Oil & Gas Journal reported that the company will submit a field development plan to the government early next year, which includes a 1.2 billion cubic-feet-a-day gas processing plant, with production seen starting by early 2017.

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

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Wednesday, June 15, 2011

Weatherford Plans to Sell Up To $1B in Assets -Wells Fargo

- Weatherford Plans to Sell Up To $1B in Assets -Wells Fargo

Wednesday, June 15, 2011
Dow Jones Newswires
HOUSTON
by Ryan Dezember

Weatherford plans to sell between $500 million and $1 billion worth of assets, according to analysts with Wells Fargo Securities, who said company officials briefed them on the plan in a recent meeting.

The divestitures would be of "mostly non-oilfield subsidiaries Weatherford has accumulated through its myriad acquisitions over the years," the analysts wrote in a client note.

Weatherford officials were not immediately available to respond to requests for comment.

Shares of Weatherford were up 0.28%, or 5 cents, at $17.66 in midday trading.

In selling the assets, the company's goals "are to free up both capital and managerial attention currently dedicated to these businesses," the analysts wrote.

Oilfield-service profits have risen rapidly from the recession as producers raced to exploit North America's unconventional onshore reserves amidst high oil prices. Weatherford's earnings, however, have lagged behind competitors Halliburton, Schlumberger, and Baker Hughes.

The Wells Fargo analysts said their meeting with Weatherford officials in Houston on Monday was one of several in which the executives are meeting with investors and "working on rebuilding the company's credibility."

In early March, Weatherford disclosed errors in its tax accounting for 2007 through 2010, which forced the company to adjust previously reported earnings. The March 2 disclosure pushed shares, which had been trading near a 52-week high, down 12.6%.

Late last month, in a rare rebuke, shareholders voted against the company's executive compensation plan in an advisory say-on-pay tally.

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

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Monday, June 13, 2011

Cuba Oil Plans Raise Prospect of Changing U.S. Embargo

- Cuba Oil Plans Raise Prospect of Changing U.S. Embargo

Monday, June 13, 2011
Knight Ridder/Tribune Business News
by David Goodhue, The Reporter, Tavernier, Fla.

The potential for vast oil reserves off the coast of Cuba, and the possibility that drilling there could start by the beginning of fall, has some saying that the United States could end or soften its Cold War-era trade embargo on its neighbor to the south.

Rice University political science professor and Latin American expert Mark Jones said ending the 50-year-old embargo remains a political non-starter among Florida politicians who feel it would make them appear "soft," which would result in a backlash from anti-Castro Cuban-Americans and cost them elections.

But, he said, Americans' appetite for the embargo is weakening and younger generations of Cuban-Americans are finding it harder to justify continuing the punitive policy.

"In the past, that threat [from anti-Castro voters] was real, but in recent years it is increasingly hollow with the proportion of the Cuban-American population that strongly supports the embargo diminishing, both due to a softening of attitude and particularly to generational turnover," Jones said in an e-mail this week.

The gateway for the United States to end or weaken the embargo may be the giant oil rig, the Scarabeo 9, which could be on its way to the Florida Straits from a shipyard in Singapore any day now. The Spanish oil company RepSol is the first of several foreign energy companies scheduled to explore for oil in deep water 50 miles from Key West. Drilling could begin by September.

Blocked by embargo

The operation is worrisome to Floridians and those in other coastal states in large part because the trade embargo would make it difficult for the United States to lend equipment, manpower and expertise to the area should there be an oil spill like the BP DeepWater Horizon disaster that lasted for months in the spring and summer of 2010.

The Obama administration has signaled it wants to improve relations with Cuba's communist government. In a controversial move, President Barack Obama last year lifted some travel restrictions for Cuban-Americans visiting relatives and friends on the island. Going any further, however, could prove too politically risky. But if the Cuban half of the Straits becomes an oil-producing hub, lifting sanctions may make more sense and appear justified, Jones said.

"What the oil production angle allows the administration to do is present to Floridians a self-interested rationale for softening or ending the embargo; if we do not, there could be a BP-type catastrophe, and the presence of the embargo would adversely impact the ability to keep the spill from harming the Florida coast and fisheries," Jones said.

Lawmakers respond

But Sen. Bill Nelson, Florida's senior senator, said through spokesman Bryan Gulley that the U.S. government already has licenses in place that it could authorize to allow companies and others to provide assistance in a disaster situation.

Gulley added that Nelson would not support lifting or easing the embargo "unless it was tied to democratic reforms in the country, including free and open elections and the release of political prisoners."

Representatives for Sen. Marco Rubio, Florida's Republican senator, did not respond to interview requests for this report.

Rep. Ileana Ros-Lehtinen, South Florida's Republican congresswoman, remains steadfastly against granting any leeway to the Castro regime. Her office e-mailed a statement regarding the question of lifting the embargo that started, "I don't deal in hypotheticals, but in what is actually happening now."

"I favor maintaining the embargo until in Cuba there is free expression, multi-party elections, freedom for political prisoners and human rights are respected," she said.

Both Nelson and Ros-Lehtinen have introduced legislation in response to the Scarabeo 9 project that would punish companies that help Cuba in its energy-production endeavors. Nelson last month asked Secretary of State Hillary Rodham Clinton to apply diplomatic pressure on Spain to convince RepSol to abandon the project.

Attitude change

But Jones thinks a lot can happen in the next year or two, especially if RepSol finds a lot of oil. He said he expects the Obama administration to stay quiet on the embargo through the November 2012 presidential elections. But if Obama wins re-election and the straits prove to be rich with crude, Jones said to expect a ramped-up effort on Obama's part to end the embargo.

"During his second term, assuming substantial oil reserves are found and significant production begins in Cuban waters, I would expect him to amplify the administration's movement towards better relations with Cuba, a major component of which would be ending or limiting the scope of the embargo and setting up bilateral mechanisms by which to deal with any potential oil spill or related catastrophe," Jones wrote in an e-mail.

Lee Hunt, president of the International Association of Drilling Contractors, favors relaxing certain aspects of the embargo, especially when it comes to oil exploration. But he said there is still avid support for maintaining the embargo among many Floridians and an equally strong opposition toward drilling off the state's coast. These factors together place doubt on Jones' theory, he said.

"I don't think Floridians are so 'fuel hungry' as to concede a half century's ideology for a few barrels of oil," Hunt said.

He said he did agree that if any significant change happens in the United States' Cuban policy, it won't be until after the 2012 elections.

"However, we are continuing to work to create a narrow exception to the embargo for services required in the event of a spill, i.e. in U.S. interests in protecting its coast and environment," Hunt said.

Jorge Pinon, a former energy industry executive and current visiting research fellow at the Cuban Research Institute at Florida International University, said changes could be coming in the embargo, but only in terms of oil equipment and services. He agreed with Nelson that these exemptions would be given only in cases of emergency and could be made by the president issuing a "general license."

"Remember it is Congress, not even the president, who can get rid of the U.S. economic embargo against Cuba," Pinon said.

Copyright (c) 2011, The Reporter, Tavernier, Fla.

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Friday, June 3, 2011

Statoil Plans to Become US Shale Operator by Early 2013 -Exec

- Statoil Plans to Become US Shale Operator by Early 2013 -Exec

Friday, June 03, 2011
Dow Jones Newswires
by Angel Gonzalez

Statoil, which built its oil and gas expertise in Norway's offshore waters, is stretching its land legs in the U.S., where it seeks to partake of the shale bounty.

Like many international oil and gas companies, Norway's Statoil has poured billions into joint ventures with some of the North American independents that in the last decade figured out how to profitably unlock the oil and gas trapped in shale, bankrolling their drilling while hoping to learn some of their techniques. But peering over its partners' shoulders is not enough: Statoil plans to run its own U.S. shale operation in South Texas's Eagle Ford Shale by early 2013, said the company's executive vice president for North America, Bill Maloney.

"We have aspirations and definite plans to become an operator in the onshore ourselves," he told Dow Jones Newswires in a recent interview at Statoil's North American headquarters in Houston. The company last October struck a $1.3 billion joint venture deal with Talisman in the Eagle Ford, which allows it the option to become operator.

"We are working towards that," Maloney said.

Statoil has been in the shale business since 2008, when it acquired 32.5% of a joint venture with Chesapeake in the Marcellus Shale, a big natural gas-rich rock formation in the Northeastern U.S. for $3.4 billion. Maloney said he sees some expansion in the Marcellus, but added that Statoil is really interested in growing its presence in the Eagle Ford, which is richer in oil.

High oil prices have turned the Eagle Ford into one of the hottest drilling basins in the world. On Wednesday, Marathon said it bought $3.5 billion in acreage from a company partially owned by private equity firm Kohlberg Kravis Roberts & Co., in one of the largest deals seen in the region.

Statoil is also interested in investment opportunities in other shales around the U.S., Maloney said.

Statoil's shale forays underscore the newfound promise found in the U.S. oil patch, once thought tapped out of its energy riches. It is now seen by large international oil companies as a key area for growth, as high oil prices have enabled many developing oil-rich countries to erect barriers to foreign investment.

Statoil helped make Norway the third-largest energy exporter, after Russia and Saudi Arabia, but the company's investments now extend all over the planet, from Algeria to Canada to Venezuela.

Its expansion in North America was gradual; throughout the years company made several large acquisitions in Canada and the U.S., including sizable deepwater acreage in the U.S. Gulf of Mexico, a position in Albertan oil sands, and the 2008 Chesapeake deal. By the time Maloney assumed the helm of a newly created North America unit in January, Statoil's assets in the continent had reached a critical mass.

Statoil had no employees in Houston in 2003, Maloney said. Now the company occupies nine floors in a high-rise near Houston's energy corridor--three floors more than last year--where nearly 400 employees work.

"We saw opportunities; we went after them," Maloney said. "Then, lo and behold, we built something here of size that we needed to separate out."

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

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Thursday, May 26, 2011

Bahrain Plans Oil Investment Push

- Bahrain Plans Oil Investment Push

Thursday, May 26, 2011
Knight Ridder/Tribune Business News
by Mandeep Singh, Gulf Daily News, Manama, Bahrain

Bahrain is set to invest more than $20 billion (BD 7.56B) in the oil and gas sector in the next two decades, according to Energy Minister Dr. Abdulhussain Mirza.

He said most would be used as part of a push to try and find lucrative new oil wells and the remainder on upgrading the Bapco refinery.

"Nearly $15B (BD 5.67B) will be used by oil exploration company Tatweer Petroleum at its operations in the Bahrain Field, where it will dig 3,600 new oil wells, while $6B (BD 2.26B) has been earmarked for the development and upgrade of the Bapco refinery," Dr. Mirza told the GDN.

He was speaking on the sidelines of a ceremony to officially inaugurate the new regional offices of primary energy business advisory firm Contax Partners in Seef.

"A process to dig deeper than ever before for natural gas is also well underway as is also the $350 million (BD 132MM) Saudi-Bahraini crude oil pipeline refurbishing project," said Dr. Mirza.

"Plans are being made in such a way that the 55km pipeline will be routed to circumvent residential and populated areas to spaces outside."

Dr. Mirza said a $430m (BD 162MM) lube base oil project, a joint investment venture between National Oil and Gas Authority (Noga) Holding, Bapco and Finland's NESTE Oil Company, is almost complete and would begin operations soon.

"Another project in the offing is the $120m (BD 45.3MM) waste water treatment project between Bapco and Korea's GS Engineering and Construction Company, which will be completed in 2012," he said.

The minister said confidence was fast returning to Bahrain after the recent unrest.

"Contax Partners setting up their regional headquarters in the country is a sure sign of that," he said.

"We are sure this step will prove to be a catalyst for more international players to set up their base in Bahrain."

Dr. Mirza said Noga welcomed foreign investment and played a vital role in attracting them to the energy field and its supporting services.

"Noga also provides support to overcome difficulties in order to boost business growth and investment for the development of Bahrain," he said.

Contax Partners chief executive Filippo Fantechi said the launch of its Bahrain headquarters was another step forward for the company, which has been in the Middle East energy industry for more than 25 years.

"We look forward to take these relationships to new horizons," he said.

Copyright (c) 2011, Gulf Daily News, Manama, Bahrain

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Tuesday, May 24, 2011

Global Energy Plans Seismic Acquisition at Bocachico Area

- Global Energy Plans Seismic Acquisition at Bocachico Area

Tuesday, May 24, 2011
Global Energy Development plc

Global Energy Development announced that, in addition to the previously announced seismic plan for its Bolivar Association Contract area, it is now also planning the acquisition of 200 square kilometers of new 3D seismic over the Company's Bocachico Association Contract area.

As with the seismic plan for its Bolivar Contract area, the Company has engaged Third Coast Enterprises, Inc. to aid in the design of an approximately 200 square kilometer 3D survey. The reservoirs of the Torcaz field in this block are in a stratigraphically complex group of formations. A high resolution 3D survey is key to delineating the extent of individual reservoirs, thus ensuring proper well placement. The current model for the field indicates that higher gravity crude exists on the flanks of the field, and the 3D survey will ensure proper mapping of these reservoirs where the Company has little data currently. The 3D survey will also delineate areas of improved reservoir continuity which will aid in the design and implementation of the overall field development plan including future secondary recovery projects.

The Company is still in the design phase of its 3D seismic survey for its Bolivar Contract area and, with the addition of the 3D seismic plans for its Bocachico Contract area, expects to complete the design phase during the second quarter 2011.

Steve Voss, the Company's Managing Director, indicated "By moving forward with these new 3D programs in both Bolivar's and Bocachio's reserve rich contract areas, we can gain much higher resolution data to identify fracture intersections in the various productive reservoirs of Bolivar and characterize areas of improved sand quality in the main Mugrossa-Bocachico reservoir. Achieving these objectives will ensure proper placement of lateral wellbores in the Bolivar fractured reservoirs and high grade the early development drilling locations in the Torcaz/Bocachico field."

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Tuesday, May 10, 2011

Russia Plans to Boost Investments in Iraq's Oil, Energy Sectors

Russia Plans to Boost Investments in Iraq's Oil, Energy Sectors

Tuesday, May 10, 2011
Knight Ridder/Tribune Business News
by Nehal El-Sherif, dpa, Berlin

The Russian government was working to increase its investments in Iraq, especially in the oil and energy sectors, Russian Foreign Minister Sergey Lavrov said Tuesday.

"Russia supports the Iraqi government in its efforts to restore security and develop the economy," Lavrov said at a joint press conference with his Iraqi counterpart Hoshyar Zebari in Baghdad.

"We are also working to increase cooperation and our investments here ... We are delighted that Russian companies are working in Iraq in the energy field," he said.

A consortium led by Russia's private oil company, Lukoil, secured the rights to develop an oilfield in 2009. Lukoil recently announced plans to quadruple its oil production from the massive West Qurna oilfield, to the west of Basra. It said initial production was scheduled for 2012 and full production should begin in 2017.

Iraq has held three international bidding rounds since late 2009 to attract investments in its oil and gas industry.

It relies heavily on oil exports for its revenue and aims to raise production from 2.5 million barrels to 12 million barrels per day within six years.

Lavrov said they also discussed the security situation in Iraq and cooperation in the defense sector. He also said Russia intends to open a consulate in the southern city of Basra, where some of the largest oilfields are located.

Copyright (c) 2011, dpa, Berlin. Distributed by McClatchy-Tribune Information Services.

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