Monday, June 24, 2013

Inpex, ENI Sign Up for Timor Sea Exploration

Inpex, ENI Sign Up for Timor Sea Exploration

TOKYO - Inpex Corp., ENI SpA and East Timor's national oil company have signed a production-sharing contract for an oil field in the Timor Sea with the governments of East Timor and Australia, Inpex said Monday. 

The new site is adjacent to the Kitan oil field, where the three partners have been producing oil since November 2011. Both field are located within permit area JPDA 06-105, inside the joint development area between Australia and East Timor. 

Inpex said in a statement Monday the three partners sought the contract as their exploration license for the permit area is expiring. 

The new field is located about 240 kilometers south of Dili, the capital of East Timor, and 500 kilometers northwest of Darwin, Australia. 

ENI has a 40.53% stake in the permit area, while Inpex holds 35.47%. Timor GAP EP owns 24%.

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Forest Oil Partners with Schlumberger on Eagle Ford Shale Land

Forest Oil Corp. inked a strategic partnership with oil-fields services giant Schlumberger Ltd. to develop the energy producer's Eagle Ford Shale land in Gonzales County, Texas, allowing for accelerated production growth and improvement of the project's economics.

Forest's shares jumped 11% premarket to $5.55. As of Thursday's close, the stock was down 25% so far this year. Schlumberger's shares closed at $77.14 and were unchanged premarket.

Under the terms of the agreement, Schlumberger will pay a $90 million drilling carry in the form of future drilling and completion services and related development capital in order to earn a 50% working interest in Forest's Eagle Ford Shale acreage position. Forest and Schlumberger will then participate in future drilling on a 50/50 basis.

"We believe that our Eagle Ford position is a valuable oil asset and being aligned and working together cooperatively with a strategic partner such as Schlumberger will greatly enhance the value of this important asset," Forest Chief Executive Patrick R. McDonald said.

He added Schlumberger will provide the technology, integrated services and capital resources needed for Forest to retain and develop a substantial portion of its acreage position.

Forest will be the operator of the drilling program and currently expects the drilling carry will be fully realized by the end of 2014.

As natural gas prices have tumbled, Forest and other companies that focus on natural-gas production have seen revenue decline. Forest has been shedding some of its noncore assets, shifting its focus toward liquids, in an effort to improve its balance sheet. In January, the company sold properties in South Texas, excluding the Eagle Ford Shale, for about $307 million to raise cash to repay debt.

In February, Forest said it swung to a fourth-quarter loss as write-downs and debt extinguishment costs weighed on the company's results, though core earnings topped market expectations.

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First Tubular on Hejre Jacket Completed

Almost precisely one year after DONG Energy awarded the Hejre main EPC contract to Technip France, the first tubular for the Hejre jacket was completed.

This happened on Feb. 26 of this year at the SIF group in Roermond in the Netherlands. Technip has subcontracted the construction work to the Heerema Vlissingen yard in south of the Netherlands.

Heerema and its suppliers - German and Dutch specialist companies are to deliver more than 7.000 tonnes of steel plates and tubulars which all in the end shall become the Hejre jacket.

This prefabrication work will continue nonstop until July 2013. By that time, 12 large main leg components, each about 98 feet (30 meters) long, will arrive at coastal Vlissingen, in the Netherlands, by barge. Remaining tubular components will arrive in parallel by road transport.

'We have now begun the actual construction of the jacket for the Hejre platform precisely one year after the contract with Technip was signed, and now the project really picks up momentum,' says Arild Wilson, Hejre project director at DONG Energy.

Weight will be 8,818 tons (8,000 tonnes).

Heerema will at its yard in Vlissingen assemble, roll up and complete the jacket before load out on a barge and finally transportation by sea to the Hejre field in the North Sea in 2014.

DONG Energy is operator of the Hejre field and owns 60 percent of the license. Bayerngas is partner and owns 40 percent.

The Hejre field expectedly contains 100 million barrels of oil and 565 billion cubic feet (16 billion cubic meters) of natural gas in recoverable reserves.

Approximately 1,000 people are busy with developing, designing and constructing the Hejre platform and related work ahead of 2015.

The field development is expected to create close to 500 permanent jobs, the major part in Esbjerg on the Danish west coast.

The field is HPHT - High Pressure/High Temperature. In concrete figures the pressure in the reservoir is at 1,010 bar and the temperature at 160 degrees Celsius.

When Hejre starts producing in late 2015, DONG Energy will be co-owner of six Danish fields in production, eight Norwegian fields and two British fields.

DONG's ambition is to double oil and gas production to 150,000 barrels of oil equivalents per day in 2020. The production is to come from oil and gas fields in Denmark, Norway and UK.

Copyright 2013 Normans Media Limited. All Rights Reserved.

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MOG Details Ombrina Mare Drilling Plans

Italy-focused Mediterranean Oil & Gas (MOG) highlighted its drilling plans for its Ombrina Mare and Maltese assets as the firm reported a first quarter update Friday.

After a positive ruling on MOG's submission of its environment impact assessment (EIA) for Ombrina Mare offshore development, the company has commissioned ERC Equipoise to complete by June a competent persons report detailing the reserves and resources in the field. MOG then plans to drill a pilot development well in the first half of 2014.

Meanwhile, MOG has made progress in Malta with the completion of its farm out to Genel Energy and the appointment of AGR Well Management for the drilling of the Hagar Qim 1 well.

MOG achieved net gas production of some 3.9 million cubic feet of gas per day during the first quarter, with 3.34 million cubic feet per day coming from its offshore Guendelina field. Guendelina well GUE-2ss – which accounts for 30 percent of the field's production – was taken offline on March 5 in order to find out what had caused an influx of water. MOG and its partner Eni (the operator) are analyzing possible remedial work so that the well can be restarted.

Analysts at London-based investment bank Liberum Capital commented that the shut-in "appears temporary and recoverable reserves should be unaffected".

Commenting on the update Friday, MOG Chief Executive Dr Bill Higgs said in a statement:

"We have had a busy start to what is going to be an important year for MOG as we gear up for the drilling program in Malta in Q4 2013 and as Ombrina Mare appraisal drilling draws nearer. We are financially strong and continue to build our cash position from production."

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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Crude Oil Settles Lower on Weak Demand; Brent falls to 9-Month Low

Crude-oil futures prices fell sharply Friday, hit by growing worries over rising U.S. oil supplies and slowing growth in global oil demand.

ICE North Sea Brent crude-oil futures, a key global benchmark, dropped for a third straight day, settling at a nine-month low.

Traders said Brent is under pressure from continued worries about weakness in European economies and reduced demand caused by refinery maintenance in Europe and Asia, along with growing competition from rising U.S. oil output.

U.S. benchmark oil futures settled at five-week lows as crude oil inventories have risen to their highest level since July 1990, even as domestic refiners have lifted crude oil processing rates to the highest early April level in eight years. Those busy processers are increasing supplies of gasoline, erasing concerns about tight supplies ahead of the peak spring-summer driving season, which looks to be stuck in reverse this year due to weak demand.

Government forecasters, while warning of a slowdown in the growth of global oil consumption, expect demand for gasoline --the most widely used petroleum product in the world's biggest oil consumer--to slip to a 12-year low in the peak season. The EIA said U.S. vehicles' increased miles per gallon more than offsets the expected rise in miles traveled, the EIA said.

Spurred by the weak outlook and news that inventories in the key East Coast region now top five-year averages, traders slashed gasoline futures by 14 cents as gallon over the past three sessions, leaving prices at a three-month low on Friday.

"It's simply a supply-demand situation," said Dan Flynn, an analyst at Price Futures. "We've basically got more supply here than we know what to do with."

Light, sweet crude oil for May delivery on the New York Mercantile Exchange settled 2.4%, or $2.22 lower, at $91.29 a barrel, the lowest price since March 6.

ICE North Sea Brent for May delivery settled 1.1%, or $1.16 a barrel lower, at $103.11 a barrel, after an intraday low of $101.09 a barrel.

Forecasts this week from the U.S. Energy Information Administration, the Organization of the Petroleum Exporting Countries, and the International Energy Agency call for demand in the current quarter to drop by 180,000 to 400,000 barrels a day from the first-quarter level. That compares with a quarter-to-quarter rise at this time last year of 300,000 barrels a day, according the IEA, the energy watchdog of the major industrialized nations.

Tim Evans, analyst at Citi Futures, said prices have been hit hard by a "relatively consistent gloomy picture that is weighing on market sentiment."

Weak seasonal demand in the current quarter means, "there's simply no reason to anticipate a quick recovery," Mr. Evans said. "Demand and prices may rebound in the third quarter, but it will likely begin from a lower price level."

Analysts at Barclays said current oil-price weakness is "transient" and demand will pick up in coming months, as European refiners return from maintenance by late May and boost crude oil demand. Asian refiners are expected to wrap up seasonal work in June, providing a further lift for crude prices.

Lower global refiner demand for Brent comes as imported crudes are losing market share in the U.S. due to rising domestic output. PBF Energy Inc. said this week it plans to process up to 70,000 barrels a day of crude oil from North Dakota's Bakken shale oil region at its 190,000 barrels-a-day refnery in Delaware, a move which analyst said will lower crude imports, adding to pressure on Brent crude prices.

Gene McGillian, broker and analyst at Tradition Energy noted that U.S. crude prices have fallen by more than more than $7.50 a barrel since the April 1 high of $97.80, and said good part of the worries about the global economy may be factored into current prices.

"We may see a test of $90 a barrel, but I don't think the bears will get much more ferocious unless we get signs a further downturn," he said.

May reformulated gasoline blendstock futures settled 1%, or 2.92 cents, lower at $2.8018 a gallon, the lowest price since Jan. 18.

May heating oil futures fell 2.73 cents, to settle at $2.8719 a gallon, the lowest price since March 19.

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Plains All American To Build New Oil Pipeline in Texas

Plains All American Pipeline LP is building a new pipeline to bring oil from an increasingly fruitful West Texas field to the Corpus Christi and Houston refining markets, the company said Monday.

The pipeline, called the Cactus pipeline, is expected to start shipping up to 200,000 barrels of day of oil in the first quarter of 2015. It would be the latest venture allowing oil producers in West Texas' Permian Basin to send their crude directly to the U.S. Gulf Coast refining belt.

Plains expects the 310-mile pipeline, with an expected cost of up to $375 million, to carry sweet and sour crude to Texas coast. By avoiding the oil transport hub in Cushing, Okla., producers hope to avoid the glut there that has helped depress prices on oil from Cushing.

Plains said it has entered into a letter of intent with a third party regarding a long-term commitment for a majority of the Cactus pipeline's capacity and is in discussions with several potential shippers for the remaining capacity. The pipeline company did not identify the company which has made the commitment or the companies with which Plains has had negotiations.

Several companies have been attracted by the idea of delivering West Texas crude directly to the refineries that dot the U.S. coast of Gulf of Mexico. Sunoco Logistics Partners started shipping such crudes to the Houston area on its Permian Express pipeline in the first quarter. Around the same time, Magellan Midstream Partners LP (MMP) reversed its Longhorn Express pipeline to ship crude from the Permian Basin to Houston.

Plains noted that crude oil delivered through the Cactus pipeline will have access to rail-loading capacity at the Gardendale, Texas, station operated by Plains All American and access to the Eagle Ford barge-dock facility in the Corpus Christi area.

The pipeline company added that the Cactus pipeline capacity can be increased as demand warrants.

Plains has experienced strong demand as it benefits from a huge boost in the U.S. supply of onshore oil.

The company, which transports, stores and sells oil, receives fees for many of its services, so it is less affected by the volatility of oil and gas prices.

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Cairn to Use Cajun Express for Frontier Drilling

Cairn Energy announced Monday that it has secured a long-term contract with Transocean for the Cajun Express (DW semisub) rig.

The rig, which is on an initial one-year contract, will be used by Cairn on its planned multi-well frontier exploration program in Senegal, Morocco and other areas.

Cairn said that it expects to mobilize the rig to begin operations offshore Morocco on the Foum Draa license during the second half of 2013, subject to the necessary approvals.

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