Tuesday, February 19, 2013

Keppel FELS Delivers Two Jackups Ahead of Schedule

Keppel FELS, a subsidiary of Keppel O&M, revealed Monday that it has delivered two jackup rigs ahead of schedule, bagging it a combined bonus of $810,000 (SDG1.5 million).

Transocean Siam Driller was delivered 22 days ahead of schedule, while the second unit – AOD 1 – was delivered 29 days ahead of schedule. Both of the rigs were handed over to their respective owners at the end of January, a spokesperson with Keppel FELS confirmed.

Customized to meet Transocean's requirements, Siam Driller has been contracted to Chevron to work in offshore Thailand, while AOD 1 has been contracted to Saudi Aramco to work in offshore Saudi Arabia.

Siam Driller is built to the Super B Class Bigfoot design, but enhanced with larger spud cans so that it is suitable for drilling where soft soil is predominant. The rig is installed with offline stand building features in its drilling system package, which allows for simultaneous drilling and the preparation of drill pipes to take place. The Super B Class jackup is an enhanced version of the standard B Class; the former is able to drill to a depth of 35,000 feet.

AOD 1 is built to the standard B Class design. The jackup will be able to operate in water depths of 400 feet, drill to a depth of 30,000 feet and accommodate 150 people.

Meanwhile, Transocean has on order a second Super B Class jackup with Keppel FELS. The jackup, Transocean Andaman, is at present under construction and scheduled to be delivered in March this year.

Commenting on the company's performance, Keppel O&M’s Managing Director, Wong Kok Seng said in a statement: "With some 20 rigs to deliver in 2013, we are working hard to maintain our high standards of delivering on time, within budget and without incidents. Of the rigs to be delivered this year, 15 are built to our KELS B Class family of designs, four to our Super A Class design and one to our proprietary semisubmersible drilling tender design."

Quintella has reported on the upstream and downstream oil and petrochemicals markets from 2004. Email Quintella at quintella.koh@rigzone.com.

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Diamond Offshore 4Q Net Falls 17% Amid Lower Day Rates

Diamond Offshore Drilling Inc.'s fourth-quarter earnings fell 17% as lower day rates dampened improved utilization of ultradeep-water and midwater floaters.

Results topped consensus estimates and the contract driller's board once again declared a special cash dividend of 75 cents a share. The board also reiterated its policy of considering the payment of special cash dividends on a quarterly basis.

Diamond Offshore, which is majority owned by Loews Corp. (L), had seen declining revenue over the past year as the offshore-drilling sector struggles with a recovery from 2010's Deepwater Horizon rig explosion in the Gulf of Mexico. U.S. authorities in February 2011 resumed the approval of deep-water drilling programs, which now face heightened scrutiny.

Diamond Offshore reported a profit of $155.7 million, or $1.12 a share, down from $188.5 million, or $1.36 a share, a year earlier. Revenue climbed 0.3% to $750.5 million.

Analysts polled by Thomson Reuters had most recently forecast earnings of $1.10 a share on revenue of $740 million.

Operating margin shrank to 26% from 29.2%.

Day rates for ultradeep-water floaters fell 2.2%, while utilization increased to 89% from 70% a year earlier.

For deep-water floaters, day rates dropped 12% while utilization fell to 85% from 97%.

Meanwhile, midwater floaters saw a 1.1% decline in day rates, with utilization improving to 70% from 60%.

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

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Armour Engages Drilling Contractor for 2013 Campaign

Armour Energy revealed Tuesday that it has entered into a contract with Silver City Drilling for a series of wells in the onshore McArthur, Isa Super and South Nicholson basins.

Under the agreement, Silver City will supply a Schramm TX130XD drill rig, equipment, a drilling crew and a management team to carry out Armour's 2013 exploration program in North Queensland and the Northern Territory.

Armour noted that the contract with Silver City has been designed with set criteria to avoid previous problems encountered during its drilling program last year. A statement posted by Armour Sep. 5, 2012, revealed that the company was forced to terminate its drilling contract "on the basis that the contractor was unable to satisfactorily remedy matters relating to the performance of its obligations."

Armour's exploration program is slated to start in late April, with the drilling of three vertical wells and one lateral well at the company's recently granted ATP 1087 permit. These wells target the target the highly prospective shale gas potential of the Lawn Hill Formation, where exploration by Comalco in 1991 encountered gas shows of up to 390 units from a continuous 410 foot (125 meters) shale gas column.

Armour aims to define up to nine trillion cubic feet of resources and reserves in the Lawn Hill Formation; the company said that, if proven, this is a sufficient resource to supply a six million tonne liquefied natural gas facility for more than 20 years.

Quintella has reported on the upstream and downstream oil and petrochemicals markets from 2004. Email Quintella at quintella.koh@rigzone.com.

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PTTEP Aims to Operate Montara Field at 100% of Capacity by June

PTT Exploration and Production (PTTEP) confirmed Tuesday that it is aiming to start operations in the Montara field offshore Western Australia by end-March this year, with a ramp-up of production to 100 percent of capacity expected by end-June.

"Oil production from the Montara field will be in the range of 20,000 barrels of oil per day (bopd) to 23,000 bopd this year," a spokesperson from PTTEP told Rigzone.

The Montara Development Project (MDP) started with the drilling of production wells in March 2008. The installation of the well head platform jacket and topsides was being completed in August 2009. On Aug. 21, 2009, while drilling completion activities were underway, there was an uncontrolled release of gas, oil, condensate and water vapour from the H1 well.

A relief well successfully intersected the H1 well and briefly stopped the well release before the well fluids caught fire Nov. 1, 2009. The well release was stopped and the fire extinguished Nov. 3, 2009.

PTTEP started on replacement works on the project during end-2011 and early-2012. Three production wells and one gas injection well sited in the Montara field were also tied back and completed during the same period. Field development has since been continuing and has included the arrival on site of the Montara Venture floating production storage and offloading facility.

PTTEP noted Feb.1 that it is targeting a sales volume of 310,000 barrels of oil equivalent (boe) for this year, with the bulk of its increased oil sales to be derived from the start of commercial operations at the Montara field. PTTEP's sales volume for 2012 was at 275,923 barrels of oil equivalent. The spokesperson disclosed that PTTEP has already inked sales contracts based on its projected 2013 production from the Montara field.

The MDP, at its maximum level, can produce 35,000 bopd.

Quintella has reported on the upstream and downstream oil and petrochemicals markets from 2004. Email Quintella at quintella.koh@rigzone.com.

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Lundin Expects to Produce up to 38,000 boepd in 2013

Sweden's Lundin Petroleum said Monday that it expects to produce between 33,000 and 38,000 barrels of oil equivalent (boepd) per day during 2013.

Releasing an update on its 2P reserves, Lundin CEO Ashley Heppenstall said that the firm expects to exit 2013 with a production rate of 40,000 boepd after its Brynhild field, offshore Norway, comes on stream later this year.

Lundin's 2P reserves are now 201.5 million barrels of oil equivalent, which is down from the 210.7 million barrels reported for the end of 2011. The firm said its 2P reserves have been positively affected by its Bertam field, offshore Malaysia, which has been added to the figure. Further increases resulted from Lundin's main producing assets – the Alvheim and Volund fields, offshore Norway – as well as the Brynhild field.

However, Lundin pointed out that these additions were offset by reserves reductions predominantly on the Gaupe gas/condensate field offshore Norway and producing assets in the Komi Republic in northern Russia.

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Crude-Oil Futures Fall As Commodities, Equities Retreat

U.S. crude oil futures slipped lower Monday, part of a slump across commodities and equities markets as investors grow skeptical that a month-long rally can continue.

Light, sweet crude for March delivery settled $1.60, or 1.6%, lower at $96.17 a barrel on the New York Mercantile Exchange, handing back all of last week's gains and retreating from a four-month high. Brent crude on the ICE futures exchange fell $1.16 to $115.60 a barrel.

Oil prices followed stock markets lower as the Dow Jones Industrial Average dropped back below 14000, the first triple-digit decline this year. Meanwhile, the dollar rose against the euro, which typically results in falling oil prices as it makes crude more expensive for buyers using other currencies.

After strong rallies in oil, stocks and other raw materials since the start of the year, analysts and traders said the markets were due for a correction as investors locked in recent gains.

"We are just having a flight out of commodities, out of equities," said Matt Smith, an analyst at Summit Energy, who attributed the losses to profit taking by investors. "It was bloodletting across the board."

The euro recently traded at $1.3517, down 0.9% from Friday.

Oil prices have been on a tear to start the year. Even with Monday's losses, the market has gained 4.7% in 2013 a investors cheered economic data that showed a better labor market in the U.S. and renewed confidence among businesses and consumers. The stock market has also rallied, and oil traders often use stocks as an indicator of investors' overall economic outlook.

But as oil prices pushed toward triple digits last week, some market watchers said technical indicators suggested that futures were due to retreat.

"We definitely got a boost from the economic optimism, but all good things come to an end," said Phil Flynn, an energy analyst at Price Futures Group. "We've had an incredible run."

Meanwhile, oil traders are also looking ahead to Chinese economic data due later this week. China will begin releasing January data Friday.

As the world's second-largest oil consumer, the reports on inflation and trade will likely keep traders' attention for any signals about the country's oil demand.

Front-month March reformulated gasoline blendstock, or RBOB, settled 4.21 cents lower at $3.0115 a gallon. March heating oil settled 0.66 cent lower at $3.1540 a gallon.

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

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Ithaca Completes Cook Field Acquisition

North Sea-focused Ithaca Energy announced Tuesday that it has completed the acquisition of an additional 12.885 percent of the Cook field via the purchase of the UK-owned subsidiary of U.S. firm Nobel Energy. Ithaca now holds 41.345 percent of the field.

The completion marks the closure of part of a deal arranged by Ithaca in October to buy two subsidiaries from Noble for $38.5 million. The firms also agreed that Ithaca would gain Noble’s 14-percent interest in the MacCulloch field.

Ithaca expects both acquisitions to increase its net proven and probable reserves by 3.4 million barrels of oil equivalent.

The Cook oil field, operated by Shell, lies in Block 21/20a in the central North Sea. The field has been developed as a single well subsea tie-back to the Shell-operated Anasuria floating production, storage and offloading vessel (FPSO). This serves as a host processing facility to several nearby fields, with oil exported from the FPSO via shuttle tankers and gas via pipeline to shore.

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

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Armour Engages Drilling Contractor for 2013 Campaign

Armour Energy revealed Tuesday that it has entered into a contract with Silver City Drilling for a series of wells in the onshore McArthur, Isa Super and South Nicholson basins.

Under the agreement, Silver City will supply a Schramm TX130XD drill rig, equipment, a drilling crew and a management team to carry out Armour's 2013 exploration program in North Queensland and the Northern Territory.

Armour noted that the contract with Silver City has been designed with set criteria to avoid previous problems encountered during its drilling program last year. A statement posted by Armour Sep. 5, 2012, revealed that the company was forced to terminate its drilling contract "on the basis that the contractor was unable to satisfactorily remedy matters relating to the performance of its obligations."

Armour's exploration program is slated to start in late April, with the drilling of three vertical wells and one lateral well at the company's recently granted ATP 1087 permit. These wells target the target the highly prospective shale gas potential of the Lawn Hill Formation, where exploration by Comalco in 1991 encountered gas shows of up to 390 units from a continuous 410 foot (125 meters) shale gas column.

Armour aims to define up to nine trillion cubic feet of resources and reserves in the Lawn Hill Formation; the company said that, if proven, this is a sufficient resource to supply a six million tonne liquefied natural gas facility for more than 20 years.

Quintella has reported on the upstream and downstream oil and petrochemicals markets from 2004. Email Quintella at quintella.koh@rigzone.com.

Generated by readers, the comments included herein do not reflect the views and opinions of Rigzone. All comments are subject to editorial review. Off-topic, inappropriate or insulting comments will be removed.

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Murkowski Report Offers 'Blueprint' for Future Energy Policymaking

U.S. Sen. Lisa Murkowski (R-Alaska) unveiled a report Monday offering a blueprint for the conversation about where energy and natural resource policies should go over the next few years.

In the report, Energy 20/20, A Vision for America's Energy Future, Murkowski offers recommendations on how to align federal energy policy with what Murkowski sees as a consensus that the United States should make energy abundant, affordable, clean, diverse and secure. These recommendations not only include oil and gas, but renewable resources as well.

Among these recommendations is for the United States to establish a national goal to produce enough additional oil, biofuels and synthetic fuels to become independent by 2020 of imports from the Organization of the Petroleum Exporting Countries (OPEC).

"The fulfillment of this commitment would support the creation of millions of well-paying jobs, increased federal revenues, reduction of U.S. budget and trade deficits, and help maintain affordable world energy prices," Murkowski noted.

The federal government can help achieve energy independence from OPEC by 2020 by:

Expediting federal permitting and reviewing decisions for energyNatural resources and related infrastructure projectsAllowing construction of the Keystone XL pipeline to move forwardRequiring the U.S. Department of the Interior outline plans for development of Outer Continental Shelf (OCS) resources to more accurately estimate available resources and set minimum production targets, taking into account necessary environmental requirements

"Although these targets would be set administratively, they should be achievable and binding," Murkowski commented in the report. "If and when actual production is projected to fall short of such targets, additional leasing, onshore or offshore, should be made available to compensate for the shortfall."

Murkowski also called for an expansion of OCS leasing to the eastern Gulf of Mexico and offshore Virginia, North Carolina, South Carolina and Georgia. Additionally, legislation should be passed for a consolidated offshore regulator, with a reaffirmed and strengthened statutory authority to develop offshore resources expeditiously through a certain and fair permitting process, while incentivizing safety and best environmental practices.

Additional amendments Murkowski calls for in the report concerning future oil and gas development include directing a share of revenues to participating offshore energy producing states – including offshore wind, tidal and wave generation – and establishing permanent revenue sharing for offshore development from leasing, bonus bids, rents, and royalty receipts at 27.5 percent with provision for direct partial payments to affected coastal communities.

The senator also called for the administration and its departments and agencies to reform the methods and processes through which energy policy is implemented and administered. This includes identifying impediments to federal oil and gas leasing and production. Specifically, the U.S. Department of the Interior must establish a review program and an accelerated auction schedule for previously and consistently nominated lease parcels that have yet to be put up for sale.

The National Petroleum Reserve-Alaska also must be immediately placed into full availability for oil and gas leasing, consistent with statutory designation.

"The reserve must be thoughtfully developed with roads, bridges and pipeline facilities that promote broad onshore development of the diffuse resource base, while simultaneously accommodating the transportation of oil and gas from offshore fields in the Chukchi Sea to the TransAlaska Pipeline System," Murkowski noted.

Murkowski also said that the benefits of the U.S. shale boom, and the jobs, higher wages and increased federal, state and local government tax revenues, should not be put at risk under a new federal regime for hydraulic fracturing that only makes it harder or impossible to produce U.S. shale resources.

"Particularly given the federal deficit, agencies should focus on directing limited resources where they are most needed and warranted, not where states are already effectively regulating and policing their activities," Murkowski commented.

New technology and studies continue to indicate that North America has a vast hydrocarbon base, with potential to substantially affect supply in world markets. Last year, the U.S. Energy Information Administration reported the United States to have 220.2 billion barrels of technically recoverable oil, or more than a century's worth of projected imports from the Organization of the Petroleum Exporting Countries. This figure does not include vast unconventional oil resources that will become commercially viable in the future.

"Abundant energy is possible, and there are already many signs of it becoming a reality as technological breakthroughs have lowered the cost of producing previously uneconomic supplies," Murkowski noted, adding that affordable energy is vital to U.S.
economic well-being, and a prudent balancing of energy production with proper standards for environmental regulation is more pressing than ever.

While the trend for oil production on state and private lands are quite positive – with approximately 96 percent of domestic oil production growth due to growth on state and private land – oil production on federal lands remained largely flat from 2003 through 2011, and sales of natural gas from federal lands fell by 31 percent. Of equal concern, the number of permits issued for onshore and offshore production on federal lands – a key indicator of future production – has also dropped significantly since the preceding administration.

"Our nation is too often hamstrung by burdensome regulations, delayed permits, and overzealous litigation," Murkowski commented. "This can render projects uneconomic by attrition and prevent timely, efficient and urgently needed investments in energy supply and conservation."

Murkowski noted that President Obama and the new Congress should work together to renew energy and natural resource policies through "discrete bills" and targeted oversight that proceed from a shared understanding of the facts.

"The ongoing boom in American oil and gas production must be fundamental to our national energy policy," Murkowski commented. "We no longer should view energy policy from a perspective of scarcity, but rather, from a perspective of increasing abundance. With the right policies, abundant and affordable energy is achievable."

Karen Boman has more than 10 years of experience covering the upstream oil and gas sector. Email Karen at kboman@rigzone.com.

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Earnings Rise, Oil Production Declines for ExxonMobil

Earnings Rise, Oil Production Declines for ExxonMobil

ExxonMobil recorded higher fourth quarter and full year 2012 earnings, but saw its upstream earnings and oil production decline as it ramped up 2012 capital and exploration expenditures to a record level.

The Irving, Texas-based oil major recorded fourth quarter 2012 earnings of more than $9.9 billion, up 6 percent from the fourth quarter of 2011, and full year 2012 earnings of $44.9 billion, up 9 percent from 2011, and record earnings per share of $9.70.

The company spent a record $39.8 billion on expenditures as it pursues opportunities to find and produce new supplies of oil and natural gas to meet global energy demand.

"Energy is fundamental to economic growth and improved living standards," said Chairman Rex W. Tillerson in a statement Friday. "ExxonMobil's strong financial performance enables continued investment in new energy supplies, which creates jobs and supports economic expansion."

While ExxonMobil's fourth quarter earnings were up, the company's upstream earnings for fourth quarter 2012 were approximately $7.7 billion, down approximately $1.1 billion from fourth quarter 2011. Fourth quarter earnings were impacted by lower liquids realizations partially offset by improved natural gas realizations, production volume and mix and lower gains from asset sales.

U.S. upstream earnings for fourth quarter 2012 rose $420 million from fourth quarter 2011 to $1.6 billion, while non-upstream earnings declined approximately $1.5 billion from the previous year to $6.1 billion.

Fourth quarter downstream earnings were approximately $1.8 billion, up $1.3 billion from the same quarter a year ago, on stronger refining margins. U.S. downstream earnings rose $667 million to $697 million, while non-U.S. downstream earnings rose $676 million to approximately $1.1 billion.

ExxonMobil's full year 2012 earnings included $9.9 billion of divestment and restructuring gains, mainly from restricting of its Japan-based operations, with $6.5 billion. But the company's upstream earnings for 2012 of $29.8 billion were down $4.5 billion from 2011 due to a number of factors, including lower liquids realizations, production volume and mix effects, higher operating expenses, lower asset sale gains, unfavorable tax items and negative foreign exchange effects.

ExxonMobil saw its full year 2012 upstream earnings decline by $4.5 billion from 2011 to approximately $29.9 billion. The company recorded U.S. upstream operation earnings of $3.9 billion, down approximately $1.2 billion from 2011, and earnings outside the U.S. of $25.9 billion, down $3.3 billion.

The company's U.S. and international downstream businesses recorded higher earnings due to stronger refining-driven margins and the $5.3 billion gain associated with ExxonMobil's restructuring in Japan and other divestment gains. Downstream earnings grew approximately $8.7 billion from 2011 to $13.2 billion in 2012, with U.S. downstream earnings of approximately $3.5 billion, up $1.3 billion from 2011, and non-U.S. downstream earnings of $9.6 billion, up $7.4 billion from 2011.

Excluding entitlement volumes, OPEC quota effects and divestments, ExxonMobil's fourth quarter 2012 production declined by 2.1 percent from fourth quarter 2011. Fourth quarter gas production was down 2.8 percent, excluding entitlement volumes and divestments, as field decline was partially offset by higher demand and lower downtime.

The company's 2012 full year oil and gas production was also down by 1.7 percent and 1.9 percent respectively.

Despite lower oil production, ExxonMobil noted that its participated in three major liquids project start-ups in West Africa last year with capacity of 350,000 gross barrels of oil per day.

The company also announced early January that it would move forward with the Hebron oil field development projects offshore eastern Canada. ExxonMobil will spend as estimated $14 billion on the project, which will involve constructing a gravity-based structure to recover more than 700 million barrels of oil.

ExxonMobil also started operations at one of the world's largest ethylene steam crackers, the centerpiece of the company's multi-billion dollar expansion at its Singapore petrochemical complex. The expansion will add 2.6 million tonnes per year of new finished product capacity.

Karen Boman has more than 10 years of experience covering the upstream oil and gas sector. Email Karen at kboman@rigzone.com.

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