Commodity Corner: Oil Settles Higher on Euro Rebound

- Commodity Corner: Oil Settles Higher on Euro Rebound

Monday, September 12, 2011
Rigzone Staff
by Matthew V. Veazey

Monday came and went without a Greek debt default, and the euro managed to rebound from its lowest point since mid-February.

Because oil becomes a better value for investors when other currencies strengthen against the U.S. dollar, the price of a barrel of light sweet crude oil for October delivery gained 95 cents to settle at $88.19 Monday. The Brent contract price, however, lost 52 cents to end the day at $112.25 a barrel.

Investors increasingly braced themselves last week for Greece to default on its national debt payments, with some expecting the situation to reach a head on Monday. As a result, the euro headed downward for much of the day until bottoming out at $1.3495. The currency regained some positive movement against the dollar. According to the European Central Bank, Monday's reference rate was $1.3656.

The WTI traded within a range from $85.00 to $88.95 while the Brent contract fluctuated from $110.62 to $113.69.

With Tropical Storm Nate steering clear of the U.S. Gulf Coast, instead making landfall in Mexico's Tabasco state, investors see no near-term threats to oil and gas infrastructure in the Gulf. Moreover, forecasters expect Tropical Storm Maria to remain in the Atlantic and veer away from the U.S. East Coast. As a result, October natural gas lost three cents to end the day at $3.885 per thousand cubic feet.

Natural gas peaked at $3.925 and bottomed out at $3.83 Monday.

October gasoline also lost three cents, settling at $2.74 a gallon. The front-month contract fluctuated from $2.71 to $2.78.

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Commodity Corner: WTI, Brent Settle Higher

- Commodity Corner: WTI, Brent Settle Higher

Tuesday, August 30, 2011
Rigzone Staff
by Matthew V. Veazey

The WTI and Brent crude oil benchmarks settled higher Tuesday after the Federal Reserve left investors contemplating whether the central bank will try yet again to shore up the sagging U.S. economy.

Light sweet crude oil gained $1.63 to settle at $88.90 a barrel while the Brent picked up $2.14 to end the day at $114.02 a barrel after the Fed released the minutes of the August 9, 2011, joint meeting of the Federal Open Market Committee and the Federal Reserve Board of Governors. The minutes reveal support among some members for more monetary action to spur economic growth.

One possible Fed move, which the central bank has initiated twice since the 2008-2009 financial crisis, is quantitative easing. The approach calls for the Fed's purchase of U.S. Treasury bonds so that banks would have more money available to lend to businesses and consumers.

Both "QE1" and "QE2" yielded a weaker U.S. dollar, which in turn was bullish for crude oil. When the dollar weakens, oil—priced in greenbacks—becomes a better value for investors holding other currencies. The minutes show that the Fed voted to extend its September meeting to two days rather than one, giving it more time to consider the merits of "QE3" and any other options remaining at its disposal.

Also boosting oil was the development of Tropical Storm Katia in the eastern Atlantic Ocean. Located approximately 750 miles west of the Cape Verde Islands late Tuesday, Katia was moving toward the west-northwest at 20 miles per hour. The National Hurricane Center expects the storm to be a major hurricane by Saturday afternoon, when it should be centered to the east of the Lesser Antilles.

During Tuesday's floor trading, the WTI fluctuated from $86.46 to $89.21. The Brent peaked $114.20 and bottomed out at $111.22.

Natural gas for October delivery settled at $3.91 per thousand cubic feet, up a nickel from the final price for the now-expired September contract. October natural gas traded within a range from $3.78 to $3.92.

September gasoline gained nine cents to end the day just under $3.00 a gallon. The futures price fluctuated from $2.897 to $3.00.

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Record Output, Higher Prices Drive Devon's 2Q Profit to $2.7B

- Record Output, Higher Prices Drive Devon's 2Q Profit to $2.7B

Wednesday, August 03, 2011
Devon Energy Corp.

Devon reported net earnings of $2.7 billion for the quarter ended June 30, 2011, or $6.50 per common share ($6.48 per diluted share). This is a 288 percent increase compared with second-quarter 2010 net earnings of $706 million, or $1.59 per common share ($1.58 per diluted share).

For the six months ended June 30, 2011, Devon reported net earnings of $3.2 billion, or $7.44 per common share ($7.41 per diluted share). This compares with net earnings for the six months ended June 30, 2010, of $1.9 billion, or $4.26 per common share ($4.24 per diluted share).

Second-quarter 2011 financial results were impacted by certain items securities analysts typically exclude from their published estimates. The most significant of the adjusting items was a $2.5 billion gain on the sale of assets in Brazil. Excluding adjusting items, Devon earned $726 million or $1.71 per diluted common share in the second quarter. The adjusting items are discussed in more detail later in this news release.

Record Production and Higher Prices Drive Oil and Gas Sales

Sales of oil, natural gas, and natural gas liquids from continuing operations were $2.2 billion in the second quarter of 2011, a 23 percent increase over the second quarter of 2010. Both higher production and higher oil and natural gas liquids pricing contributed to the increase.

Devon's North American onshore production averaged the highest daily rate in the company's history at 660,000 oil-equivalent barrels (Boe) per day in the second quarter of 2011. This represents a production increase of more than six percent over the second-quarter 2010, driven by a 12 percent increase in oil and natural gas liquids production.

Devon's marketing and midstream operating profit totaled $148 million in the second-quarter 2011, a 19 percent increase over the second quarter of 2010. The improvement resulted from higher natural gas liquids production and prices as well as increased gas throughput.

Strategic Repositioning Completed; Share Repurchase Plan Remains on Schedule

In May, the company closed the $3.2 billion sale of its Brazilian operations. Devon has now substantially completed its International and Gulf of Mexico divestiture plan. In aggregate, sales proceeds from the combined divestitures exceeded $10 billion with after-tax proceeds expected to approximate $8 billion.

"The execution of Devon's strategic repositioning was excellent," said John Richels, president and chief executive officer. "Devon has emerged with a pristine balance sheet, a deep inventory of oil and liquids-rich growth opportunities and a highly competitive cost structure. As demonstrated by our second-quarter results, the repositioned Devon is delivering profitable growth per share."

In May 2010, Devon commenced a program to repurchase $3.5 billion of its common stock. As of June 30, 2011, the company had repurchased 33.5 million shares at a total cost of $2.5 billion. Devon expects to complete the stock repurchase program by the end of 2011.

Production Growth Leads Operating Highlights

• In the Permian Basin, Devon increased production 17 percent over the second quarter of 2010, to 49,000 oil-equivalent barrels per day. Oil and natural gas liquids accounted for 75 percent of the quarter's production.
• The company completed nine operated Bone Spring wells within the Permian Basin in the second quarter. Initial daily production from the nine wells averaged more than 700 Boe per day per well. Devon has an average working interest of 77 percent in these wells.
• In Canada, Devon commenced steam injection and achieved first production from its Jackfish 2 oil sands project in the second quarter. Production from the 100 percent-owned project is expected to ramp-up to 35,000 barrels per day before royalties over the next 18 months.
• Production from the company's Cana-Woodford Shale play averaged a record 189 million cubic feet of natural gas equivalent per day in the second quarter, including nearly 9,000 barrels per day of liquids. This represents an 80 percent increase in total production compared to the year-ago quarter.
• Devon's Barnett Shale production increased 13 percent over the second-quarter 2010 to a record 1.3 billion cubic feet of natural gas equivalent per day, including 46,000 barrels per day of liquids production.
• Devon brought eight operated Granite Wash wells online in the second quarter. Initial production from these wells averaged 2,010 barrels of oil-equivalent per day, including 200 barrels of oil and 730 barrels of natural gas liquids per day. The company has an average working interest of 71 percent in these wells.
• The company has assembled 1.1 million net acres targeting new oil and liquids-rich gas opportunities across multiple basins in the U.S. Devon plans to drill more than 30 wells this year targeting the Tuscaloosa Marine Shale, Niobrara Shale, Mississippian Lime, Ohio Utica Shale and the A1 Carbonate and Utica Shale in Michigan.

Cost Containment Efforts Offset Rising Industry Costs

Lease operating expenses (LOE) were $453 million in the second quarter of 2011, or $7.55 per Boe. This represents a one cent per Boe decrease from the second-quarter 2010. Effective cost management and higher production offset the effects of the strengthening Canadian dollar and rising service and supply costs.

Taxes other than income increased $28 million to $120 million in the second quarter of 2011. The year-over-year increase was driven by higher production taxes, resulting from the significant increase in oil and natural gas liquids revenues.

Second-quarter 2011 general and administrative expenses (G&A) totaled $135 million, or $2.26 per Boe. Compared to the second quarter of 2010, G&A per Boe increased approximately two percent. Efficiencies gained through the company's strategic repositioning helped mitigate the effects of the strengthening Canadian dollar and an increase in overall activity levels.

Depreciation, depletion and amortization expense (DD&A) of oil and gas properties increased to $485 million in the second quarter of 2011. Compared to the year-ago quarter, unit DD&A increased 11 percent to $8.08 per Boe.

Interest expense decreased 24 percent in the second quarter to $85 million. Second-quarter 2010 interest expense included a $19 million charge related to the early redemption of senior notes.

Second-quarter income tax expense from continuing operations totaled $1.2 billion, or 87 percent of pre-tax earnings. This unusually high tax rate resulted from a $744 million charge related to U.S. income taxes on foreign earnings assumed to be repatriated under current U.S. tax law. After adjusting for this and other items generally excluded by securities analysts, Devon's second quarter tax rate totaled 32 percent of pre-tax earnings from continuing operations.

Cash Flow and Divestiture Proceeds Total $4.8 Billion

Cash flow before balance sheet changes totaled $1.6 billion in the second quarter of 2011, a 115 percent increase over the year-ago quarter. In addition, Devon received $3.2 billion of pre-tax proceeds from the sale of its assets in Brazil.

As of June 30, 2011, the company's cash and short-term investments reached $6.7 billion and its net debt to adjusted capitalization ratio declined to five percent. Reconciliations of cash flow before balance sheet changes, net debt and adjusted capitalization, which are non-GAAP measures, are provided in this release.

Devon Adds To Natural Gas Hedges

Devon continued to bolster its natural gas hedge positions for 2011 and 2012. For the second half of 2011, the company now has approximately 980 million cubic feet per day protected utilizing swap and collar contracts with a weighted average floor price of $5.28 per Mcf. For 2012, Devon now has hedges covering 815 million cubic feet per day hedged at a weighted average floor price of $4.89 per Mcf. The company's natural gas hedges for both 2011 and 2012 are based on the Henry Hub benchmark index.

Divestitures Impact Reported Financial and Operational Results

In accordance with accounting standards, Devon has classified the assets, liabilities, and results of its international segment as discontinued operations for all accounting periods presented in this release. Included with this release is a table of revenues, expenses, production categories, and the amounts classified as discontinued operations for each period presented.

Items Excluded from Published Earnings Estimates

Devon's reported net earnings include items of income and expense that are typically excluded by securities analysts in their published estimates of the company's financial results. These items and their effects upon reported earnings for the second-quarter 2011 were as follows:

Items affecting continuing operations

• U.S. income taxes on foreign earnings assumed to be repatriated to the U.S. decreased second-quarter earnings by $744 million.
• A change in the fair value of oil, gas and NGL derivative instruments increased second-quarter earnings by $357 million pre-tax ($233 million after tax).
• A change in fair value of interest-rate and other financial instruments decreased second-quarter earnings by $30 million pre-tax ($20 million after tax).
• Restructuring costs decreased second-quarter earnings by $6 million pre-tax ($3 million after tax).

Items affecting discontinued operations

• Divestitures of assets in Brazil resulted in a second-quarter gain of $2.5 billion pre-tax ($2.5 billion after tax).
• Restructuring costs increased second-quarter earnings by $8 million pre-tax ($5 million after tax).

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Commodity Corner: Oil Settles Higher on Bullish Stocks Data

- Commodity Corner: Oil Settles Higher on Bullish Stocks Data

Wednesday, July 20, 2011
Rigzone Staff
by Matthew V. Veazey

The price of light sweet crude oil gained 64 cents Wednesday to settle at $98.14 a barrel on news of a larger-than-expected drop in U.S. oil stocks. The Brent benchmark gained $1.09 to end the day at $118.15 a barrel.

The U.S. Energy Information Administration reported Wednesday that the country's commercial crude oil inventories fell nearly 1.1 percent last week to 351.7 million barrels. The 3.8 million-barrel draw was well above analysts' expectations. For instance, a Platts survey of analysts projected a draw of only 1.3 million barrels.

WTI futures fluctuated from $96.80 to $99.02 during Wednesday's session. The Brent contract peaked at $118.56 and bottomed out at $117.06.

Americans from the Upper Midwest to the South to the East Coast are seeking air-conditioned relief from high heat and humidity. Triple-digit heat indices are common throughout the eastern half of the country, and such conditions are expected to continue into next week. In spite of the sweltering heat, natural gas futures edged downward Wednesday to $4.50 per thousand cubic feet.

Front-month natural gas traded within a range from $4.43 to $4.60.

Gasoline futures ended the day higher at $3.15 a gallon—the intraday high. The intraday low for gasoline was $3.10.

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EIA: Higher US Gas Production Expected for 2011

- EIA: Higher US Gas Production Expected for 2011

Tuesday, July 12, 2011
Dow Jones Newswires
NEW YORK
by Amy D'Onofrio

The U.S. Energy Information Administration raised its forecast for natural-gas production for 2011, and said inventories are expected to come close to last year's record levels this fall.

The EIA also expects demand for gas to be slightly stronger than previously expected.

U.S. gas production is expected to average 65.4 billion cubic feet a day in 2011, up 5.8% from last year. The forecast was up from last month's prediction of 4.5% growth in output, according to the agency's monthly Short Term Energy Outlook released Tuesday.

"Growing domestic natural gas production has reduced reliance on natural gas imports and contributed to increased exports," the EIA said.

That increase in production is partly due to drilling to access gas in shale rock formations, where output has shot up in recent years.

Pipeline gross exports to Mexico and Canada are expected to average 4.2 Bcf/d in 2011, up from 3.1 Bcf/d in 2010, while liquefied natural gas imports are seen falling to 1 Bcf/d, from 1.2 Bcf/d in 2010, the agency said.

Production continues to grow faster than consumption. Total gas consumption is forecast to increase by 2% in 2011 to 67.4 billion cubic feet a day, on higher demand from industrial and electric power consumers.

Consumption is expected to drop slightly in 2012 to 67.3 billion cubic feet a day. The EIA expects residential and commercial consumption to decline because cooler weather is expected in the Midwest and West, the EIA said.

Natural-gas prices at the benchmark Henry Hub should average $4.26 per million British thermal units over the second half of 2011, "as the inventory deficit relative to last year narrows," the EIA said. In June, prices averaged $4.54, or 34 cents higher than the forecast last month.

Uncertainty over natural gas prices is still lower this year compared with the same time last year, the statistical arm of the Department of Energy said.

Gas prices will likely come under downward pressure as inventories rise during the summer months, but prices are expected to average $4.54 in 2012 as production growth slows.

This year, inventories should remain high, however.

Inventories are forecast to surpass 3.8 trillion cubic feet at the end of October "because of current high production rates and a milder summer relative to last year," according to the report.

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

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Chevron Sees Increase in 2Q Earnings on Higher Oil Prices

- Chevron Sees Increase in 2Q Earnings on Higher Oil Prices

Tuesday, July 12, 2011
Chevron Corp.

Chevron reported in its interim update that earnings for the second quarter 2011 are expected to be higher than in the first quarter 2011. Upstream results are projected to improve between sequential quarters, benefiting from higher crude oil prices.

Basis for Comparison in Interim Update

The interim update contains certain industry and company operating data for the second quarter 2011. The production volumes, realizations, margins and certain other items in the report are based on a portion of the quarter and are not necessarily indicative of Chevron's full quarterly results to be reported on July 29, 2011.

Unless noted otherwise, all commentary is based on two months of the second quarter 2011 versus full first quarter 2011 results.

UPSTREAM

U.S. net oil-equivalent production during the first two months of the second quarter was in line with the first quarter 2011. International net oil-equivalent production declined 76,000 barrels per day, largely reflecting maintenance activity in Kazakhstan.

U.S. crude-oil realizations for the first two months of the second quarter increased about $18 per barrel to $111.11, and International liquids realizations improved approximately $13 to $108.46 per barrel. U.S. natural gas realizations increased $0.28 to $4.32 per thousand cubic feet, and international natural gas realizations increased $0.41 to $5.44 per thousand cubic feet.

International Upstream earnings in the second quarter are expected to reflect higher exploration expenses.

The company's general guidance for the quarterly net after-tax charges related to corporate and other activities is between $250 million and $350 million. Due to foreign currency effects and the potential for irregularly occurring accruals related to income taxes and other matters, actual results may significantly differ from the guidance range.

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Tullow 1H Revenue Seen Boosted By Jubilee, Higher Oil Price

- Tullow 1H Revenue Seen Boosted By Jubilee, Higher Oil Price

Tuesday, July 05, 2011
Dow Jones Newswires
LONDON

Tullow Oil said it expects to post record first-half revenue of $1.05 billion next month, as the London-based explorer continues to ramp up production from its Jubilee field offshore Ghana to 80,000 barrels of crude a day, a 14.3% increase from the level announced last month.

In a trading update, Tullow said first-half working interest production has averaged 75,350 barrels of oil equivalent a day, an 35% increase from the 55,800 boe/day logged in the corresponding period in 2010.

For the full year, Tullow said it expects to produce 90,000 to 94,000 boe/day, more than 50% higher than last year, boosted by new licenses in Ghana and the North Sea acquired earlier this year.

"The performance of our business since the beginning of 2011 has been excellent and we expect to deliver record financial results for the first half of the year," said Chief Executive Aidan Heavey.

Tullow said it expects total first-half revenue of around $1.05 billion, compared with $486 million for the same period in 2010, attributing the sharp rise to higher sales volumes thanks to the contribution of Jubilee, its largest discovery and which is expected to reach plateau production of 120,000 barrels a day in August.

The company's anticipated surge in revenue has also been underpinned by "significantly higher" oil and gas prices, the company said, adding that its oil production sold at an average discount of approximately 2% to Brent during the first half of 2011.

Analysts said while the trading update didn't contain any surprises, it did confirm Tullow's growth program remains on track.

Angus McPhail said it was further evidence "that Tullow is graduating from E&P to integrated player," while Oriel Securities' Richard Rose said its diverse exploration portfolio had "considerable upside potential."

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

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Commodity Corner: Oil, Natural Gas Settle Higher

- Commodity Corner: Oil, Natural Gas Settle Higher

Thursday, June 30, 2011
Rigzone Staff
by Matthew V. Veazey

The price of light sweet crude oil for August delivery gained 65 cents Thursday to settle at $95.42 a barrel.

The WTI received a boost from a weaker dollar as well as a slight improvement in new jobless claims. The Dollar Index declined 0.4 percent, signifying that dollar-denominated crude oil became a better value for investors holding currencies other than the greenback. In addition, the U.S. Department of Labor reported that first-time claims for unemployment insurance declined by 1,000 to 428,000 last week.

The August WTI contract price fluctuated from $93.88 to $95.82. Brent futures settled at $112.40 a barrel. The Brent contract traded within a range from $108.10 to $112.67.

August natural gas gained 5.5 cents to settle at $4.37 per thousand cubic feet. The U.S. Energy Information Administration (EIA) reported that the country's natural gas inventories rose by 78 billion cubic feet last week. The implied build was lower than what analysts had expected. A Platts survey of analysts projected an increase of 80 to 84 Bcf.

Natural gas futures traded within a range from $4.21 to $4.42 Thursday.

July gasoline gained two cents to end the day at $3.03 a gallon—the intraday high. Gasoline bottomed out at $2.98 Thursday.

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Commodity Corner: Oil Settles Higher on Greek Bailout Hopes

- Commodity Corner: Oil Settles Higher on Greek Bailout Hopes

Monday, June 20, 2011
Rigzone Staff
by Matthew V. Veazey

Crude oil for July delivery gained 25 cents Monday to settle at $93.26 a barrel.

Monday's increase reflected investors' optimism that the Greek government will be able to broker a debt restructuring deal with the European Union (EU) and the International Monetary Fund (IMF). Eurozone finance ministers met through the weekend to develop a bailout deal to prevent Greece from defaulting on its public debt.

In order to qualify for a loan from the EU and IMF, the Greek government needs to adopt austerity measures. An austerity plan proposed by the ruling Socialist government includes tax hikes, spending cuts, and privatizations. The proposal has generated considerable discontent among the Greek populace.

Crude oil peaked at $93.49 and bottomed out at $91.14 Monday.

Summer officially begins Tuesday in the Northern Hemisphere, but the Upper Midwest and Northeast regions of the U.S. have been experiencing a dearth of scorching temperatures lately. Thanks to these mild conditions and expectations of more of the same, cooling demand has not been higher than normal. July natural gas lost a penny to end the day at $4.32 per thousand cubic feet.

Natural gas traded within a range from $4.28 to $4.38 Monday.

The front-month price for a gallon of gasoline fell four cents to settle at $2.91 Monday. July gasoline fluctuated from $2.90 to $2.95.

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O&G Companies Fear Higher Royalty Payments under Obama Effort

- O&G Companies Fear Higher Royalty Payments under Obama Effort

Thursday, June 09, 2011
Dow Jones Newswires
WASHINGTON (Dow Jones Newswires)
by Tennille Tracy

Energy companies are concerned they could be forced to pay higher oil and gas royalties under a new Obama administration effort to revamp royalty calculations for energy extracted from federal lands and waters.

The Interior Department, which launched the effort last month, insists the proposed changes will simplify how oil and gas is valued and should not increase or decrease the royalty payments themselves.

Oil and gas companies are not so sure. They say changes could create an unfair calculation that leads to higher royalty payments, which would dampen the industry's profits and hurt smaller producers particularly hard.

"It makes us nervous when we hear of the government trying to simplify things," said Kathleen Sgamma, director of government affairs for the Western Energy Alliance, a group representing oil and gas producers in western U.S. states.

This debate comes as the energy industry has battled the Obama administration on other matters, such as a bid to eliminate billions of dollars of tax incentives for oil and gas companies.

The new royalty formula also comes as the Obama administration looks for ways to trim the widening deficit. Generating nearly $9 billion in reported revenue last year, oil and gas royalties represent one of the largest sources of non-tax revenue for the federal government.

The Interior Department is also considering, through a separate effort, an increase to onshore production royalty rates, now at 12.5%. The royalty rate for offshore production is 18.75%.

Government watchdogs have said the Interior Department's royalty program fails to collect the government's fair share of revenue from the industry. Earlier this year, the Government Accountability Office identified the program as being at a "high risk" of fraud, waste, abuse or mismanagement.

When calculating royalty rates, the Interior Department can often rely on the sale price between the buyer and seller to determine the value of the oil or gas. But in many cases--such as when affiliated companies sell to each another--the Interior Department questions whether this sale price reflects the true market value and conducts its own review. This creates a burden for government officials and leads to disputes with the industry.

Hoping to simplify the process, the Interior Department is considering a process where it relies on standardized prices to calculate royalty payments. These could be published prices from trade publications or prices at which the products are traded on exchanges.

But the industry is concerned standardized prices could lead the Interior Department to assign a higher value to oil and gas than what producers receive from a sale. And that would lead to bigger payments to the federal government.

Such a system could hurt smaller producers particularly hard because they often receive less money for their production than large multinational companies, said L. Poe Leggette, partner-in-charge at Fulbright & Jaworski's Denver office.

Interior Department spokesman Patrick Etchart said they welcome the industry's comments. Interior wants a system "that provides fair certainty to us that we get paid the proper amount," he said.

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

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Delta Air Lines Reports Generally Higher May Traffic, Surpassing American Airlines

- Delta Air Lines Reports Generally Higher May Traffic, Surpassing American Airlines



Jun 7, 2011

Delta Air Lines (DAL) today posted its May traffic results, with system traffic up 2.2% from the year-ago month on a 2.2% increase in capacity making it the world's largest carrier by traffic, surpassing American Airlines. Load factor is still at 83.9%, which is flat with last year.

Domestic traffic also increased by 1.9% versus last year on a 0.4% increase in capacity. Load factor for domestic increased to 85.1%. International traffic is up 2.6% versus last year on a 5% capacity increase, with load factor down 2 points to 82.2%.

The higher traffic is due to the consolidation of Delta's subsidiary Northwest Airlines, which was completely integrated into Delta network in January of 2010.

DAL shares are down slightly 0.21% to $9.60.

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SSGC: Pakistan's Estimated Gas Reserves Higher Than Expected

- SSGC: Pakistan's Estimated Gas Reserves Higher Than Expected

Monday, May 23, 2011
Asia Pulse Pte Ltd.

Pakistan holds an estimated 33 trillion cubic feet (tcf) of tight-gas reserves, higher than the existing estimated 27 tcf in the country, said the deputy managing director of operations of Sui Southern Gas Company (SSGC) Syed Hassan Nawab.

Nawab made the comment addressing the 7th International POGEE Conference 2011 for Oil and Gas and Energy Industry at the Karachi Expo Center on Wednesday. Joint Secretary Ministry of Petroleum and Natural Resources Raashid Bashir Maser was the chairman of the session.

Referring to a report of Pakistan Petroleum Exploration and Production Companies Association (PPEPCA), Nawab said the country will have sufficient natural gas if tight gas is explored with the help of advanced technology. He pointed out that the government has prepared the draft policy for tight gas and it is currently with the Council of Common Interest (CCI) and this will be approved soon.

Quoting some of the incentives in the draft tight gas policy, he said that investors will be offered 40 percent premium on the current gas price for exploring tight gas. Similarly, 50 percent premium will be offered on current gas price to investors if they commission their project by December 2011.

Hassan Nawab said that Pakistan can also produce gas from Thar coal with the help of underground coal gasification (UCG) technology. There is a potential to produce 35 tcf of coalbed methane from Thar coal, he noted.

He said that the availability of natural gas can be enhanced through import of liquefied natural gas (LNG) from neighboring countries like Qatar and Iran-through 3rd party arrangements. He said the country has a very large network of pipelines and the importer of LNG can pump this gas to their buyers in upcountry destinations.

(C) 2011 Asia Pulse Pte Ltd.

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Commodity Corner: Oil Settles Higher After Sharp Drop

- Commodity Corner: Oil Settles Higher After Sharp Drop

Friday, May 20, 2011
Rigzone Staff
by Matthew V. Veazey

Crude oil for June delivery gained $1.05 to end a volatile trading day at $99.49 a barrel.

The front-month contract plunged to an intraday low of $95.99 as the U.S. dollar gained 0.75 percent against the euro. Oil becomes a better value for investors holding non-U.S. currencies when the dollar grows weaker because crude is priced in dollars.

Given the relative value of the expiring June oil contract relative to the higher July contract price, however, oil rebounded later Friday as investors sensed a buying opportunity. Crude topped out at $99.49 for the day and is down less than 0.2 percent for the week.

A day after falling 2.6 percent following a U.S. Energy Information Administration report showing a higher-than-expected build in inventories, June natural gas gained 14 cents to settle at $4.23 per thousand cubic feet. Buoying Friday's rally were forecast models predicting above-normal temperatures throughout the eastern U.S. for the remainder of the month. Warmer conditions in the region would likely boost demand for electricity to power air conditioners.

June natural gas traded within a range from $4.08 to $4.26 Friday. It is down 0.5 percent for the week.

The June gasoline contract gained a penny to end the day at $2.94 a gallon. It fluctuated from $2.86 to $2.96. June gasoline has fallen 4.2 percent since last Friday.

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Exxon Mobil 1Q Profit Soars 69% on Higher Oil Prices

Exxon Mobil 1Q Profit Soars 69% on Higher Oil Prices

Thursday, April 28, 2011

Dow Jones Newswires

by Tess Stynes

ExxonMobil's first-quarter earnings surged a bigger-than-expected 69% as the company benefited from high oil prices and stronger refining margins.

The world's largest publicly traded oil company by market value has reported stronger results in recent quarters due to rising oil profits and improved refining industry profitability. The growth was a reflection of a recovery from the recession for the broader energy sector, which appears poised for a return toward the boom days that preceded the financial collapse in 2008.

Exxon's $25 billion takeover of natural-gas producer XTO Energy Inc. acquisition last year boosted its production and reserves, though prices have remained soft. The move is anticipated to be highly profitable in the long term, on expectations that natural-gas consumption will grow.

Exxon Mobil reported a profit of $10.65 billion, or $2.14 a share, up from $6.3 billion, or $1.33 a share, a year earlier. Revenue climbed 26% to $114 billion after climbing 41% a year earlier.

Analysts polled by Thomson Reuters most recently forecast earnings of $2.07 on revenue of $114.85 billion.

Exploration and production earnings rose 49%. Exxon Mobil's production rose 10%, boosted by its acquisition last year of XTO Energy Inc., which boosted its natural gas production by 24%.

Refining and distribution business earnings soared amid stronger refining margins and sales of petroleum products.

Exxon Mobil said it spent $5.7 billion for stock repurchases, buying back 69 million shares. The total included $5 billion of buybacks to reduce shares outstanding.

Shares were down 0.5% at $87.32 in premarket trading. The stock through Thursday's close is up 27% in the past year.

Husky's 1Q Profit Leaps on Higher Output, Prices

Husky's 1Q Profit Leaps on Higher Output, Prices

Wednesday, April 27, 2011
Husky Energy Inc.

Husky achieved strong earnings and cash flow growth in the first quarter of 2011 compared to the same quarter of 2010. Performance was driven primarily by increased production volumes, higher realized crude oil prices for the Atlantic Region and South East Asia, and higher throughput rates and margins within the downstream segment.

"Our first quarter results are in accordance with our execution plan," said CEO Asim Ghosh. "Actions undertaken to grow near-term production have achieved the intended result during a period of strengthening prices. At the same time, our downstream refining segment posted strong performance, with higher throughput enabling us to capitalize on improving market conditions."

"In addition, we have made steady progress in advancing our mid and long-term growth initiatives. Steps taken in the quarter have enabled Husky to achieve important milestones towards progressing the Liwan Gas Project offshore China. This project will create shareholder value by tapping into the fast growing energy markets in Hong Kong and mainland China."


A summary of first quarter results, together with recent key highlights, follows:

• Net earnings of $626 million, or $0.70 per share (diluted), including an after-tax gain of $143 million on the sale of non-core assets, an increase of 70 percent from a year ago.
• Cash flow from operations of $1,164 million, or $1.30 per share (diluted), an increase of 36 percent from a year ago.
• Total production before royalties for the quarter averaged 310,400 boe/day, 5 percent above the same quarter of last year and 11 percent higher than the fourth quarter of 2010.
• Progressed the Liwan Gas Project as the Company expects to submit the Overall Development Plan for Liwan 3-1 to the Chinese authorities in the second quarter. The Liwan Gas Project includes several fields; Liwan 3-1, Liuhua 34-2 and Liuhua 29-1 with first gas anticipated from Liwan 3-1 and Liuhua 34-2 in late 2013, ramping up through 2014. Liuhua 29-1 production is anticipated late 2014. Husky's production share is 49 percent.
• Liwan gas is expected to be sold under a long-term contract at competitive prices in the Guangdong and Hong Kong markets.
• Phase I of the Sunrise Energy Project progressed on schedule as development drilling commenced in early 2011 with 12 horizontal wells spud and seven drilled in the quarter.
• In the Atlantic Region, the Company continued to ramp up North Amethyst volumes.
• The Lloydminster Upgrader resumed normal operations in April at which time repairs were completed.
• Closed the previously announced Western Canada asset acquisition on February 4th.
• Closed a $300 million preferred share financing to enhance our liquidity and financial flexibility.

First quarter production averaged 310,400 boe/day in line with guidance. Volumes compare positively with 280,500 boe/day in the fourth quarter of 2010 and 295,900 boe/day in first quarter of 2010. Production volumes were driven higher by the February closing of the Western Canada asset acquisition and good performance from White Rose and North Amethyst.

First quarter cash flow and earnings growth were driven by higher upstream production volumes, higher realized light crude oil prices for the Atlantic Region and South East Asia, and stronger throughput rates and margins within the downstream segment. These were partially offset by the impact on Western Canada realized crude oil pricing of higher discounts to WTI, the impact of a strong Canadian dollar, lower throughput at the Lloydminster Upgrader and weak natural gas prices.

Light crude oil prices averaged U.S. $104.97 per barrel for the quarter, 38 percent higher compared to same period of 2010. Of the Company's total production, approximately 20 percent is priced and sold relative to light crude prices (North Sea Brent). U.S. refining market crack spreads were stronger during the quarter with the average Chicago 3:2:1 crack spread at U.S. $16.58 per barrel, compared to U.S. $6.23 in the same period of 2010.

"We continue to prudently manage our financial position and exercise discipline in all aspects of our capital and operating expenditures," said Alister Cowan, CFO.

KEY AREA SUMMARY AND GROWTH UPDATE:

Western Canada - Unconventional and Conventional

The Company continues to maintain production levels from Western Canada and has accelerated development drilling.

Oil Resource Plays

Within the oil resource portfolio, the Company is focused on developing its opportunities in the Lower Shaunavon and Bakken zones in Southern Saskatchewan along with the Viking zone in Southwest Saskatchewan and central Alberta. Husky has approximately 500,000 net acres in its oil resource portfolio. Seventeen wells were drilled during the period with six placed on production.

Gas Resource Plays

Husky advanced development drilling of its liquids-rich gas assets in the Alberta Deep Basin. In the Ansell area, four rigs were active and a total of 20 Cardium formation wells were drilled during the quarter and an additional six exploration and development wells were drilled in Kakwa, Bivouac, the Horn River Basin and on the Cypress acreage.

Through a combination of crown land sales and private purchases, Husky increased its land holdings in its gas resource portfolio during the first quarter by 29,000 acres.

Heavy Oil

Husky is amongst the industry leaders in heavy oil production and has a significant land and resource portfolio along with a solid integrated infrastructure position. Within its heavy oil operations, the Company's strategy is focused on maintaining production levels, being a low cost producer and continuing to drive new enhanced recovery techniques to sustain production volumes.

Construction of the 8,000 bbl/day South Pikes Peak project was approximately 58 percent complete at the end of the first quarter with production expected in mid 2012. The project continues to progress as expected.

The 3,000 bbl/day Paradise Hill project activity commenced in the first quarter, and will utilize the existing Bolney infrastructure. Production is anticipated in late 2012.

Oil Sands

The Company advanced the recently sanctioned Phase I Sunrise Energy Project. Twelve horizontal wells were spud and seven drilled during the quarter. The Company made several significant equipment orders that included the steam generators, vessels, water treating plant and a camp to support the project.

Tucker contributed positive earnings in the quarter with an average production volume of 6,200 bbls/day. Further wells will be brought on production in the second quarter.

Atlantic Region

Through the first quarter, North Amethyst performed well with average production of 21,400 bbls/day net to Husky. In 2011, Husky expects to tie-in an additional producer and one more injector well.

The West White Rose satellite pilot development is progressing on schedule. These wells will provide additional information on the reservoir to refine understanding of the best development scheme for the full West White Rose field. First production from the pilot is anticipated in the third quarter of 2011.

Husky holds exploration rights to nineteen parcels of land in the area. In 2011, the Company plans to participate in the drilling of an appraisal well at the Mizzen discovery and an exploration well to the south of Terra Nova.

South East Asia

Development of the Liwan Gas Project is progressing in accordance with the Heads of Agreement signed with China National Offshore Oil Corporation (CNOOC) in December 2010. Under the Heads of Agreement, Husky will operate the deepwater portion of the project involving development drilling and completions, subsea equipment and controls, and subsea tie-backs to a shallow water platform. CNOOC will operate the shallow water portion of the project including a shallow water platform, approximately 270 km of subsea pipeline to shore, and the onshore gas processing plant.

Development of the Liwan Gas Project comprises three discoveries on Block 29/26; Liwan 3-1, Liuhua 34-2 and Liuhua 29-1, with first gas production expected in late 2013, ramping up through 2014. Official project sanction is expected later in 2011. It is anticipated the natural gas will be sold under a long-term contract at competitive prices in the Guangdong and Hong Kong markets.

The partnership has made considerable progress in advancing the Liwan Gas Project as the Overall Development Plan (ODP) for Liwan 3-1 has been prepared and is undergoing final reviews with submission to authorities scheduled in the second quarter. Development of the Liwan 3-1 and Liuhua 34-2 fields are proceeding in parallel and will share infrastructure. The ODP for the Liuhua 34-2 field is in preparation and planned for submission to authorities mid-2011. Liuhua 29-1 is expected to be fully delineated later this year with an ODP submission targeted before year end.

All nine development wells for the Liwan 3-1 field have been successfully drilled confirming the quality and extent of the reservoir. Fabrication and construction has begun, and long lead time items ordered in accordance with the schedule. Deepwater installation and pipe lay work are planned to take place in 2012 and 2013.

CNOOC is progressing with the development of the shallow water portion of the project. The infrastructure is designed to allow for the tie-in of incremental wells and fields. Gas from the Liuhua 29-1 field will be processed through the same shallow water platform and onshore gas plant as the other two fields and is expected to come on stream in late 2014.

In Indonesia, Husky and its partners continue to progress and plan for the development of the BD and MDA gas fields with first gas production expected in 2014. The long lead time items for the BD field, including the FPSO, are set to go to tender by mid-year. An appraisal well for the MDA field will be drilled later this year as well as a nearby low risk exploratory well targeting the same type of reservoir.

Eni's Earning Soars on Higher Oil Prices

Eni's Earning Soars on Higher Oil Prices

Wednesday, April 27, 2011
Eni S.p.A.

Eni, the international oil and gas company, today announces its group results for the first quarter of 20111 (unaudited).

• Financial Highlights
  • Adjusted operating profit: up 18.4% to € 5.13 billion
  • Adjusted net profit: up 21.6% to € 2.22 billion
  • Net profit: up 14.6% to € 2.55 billion
  • Cash flow: € 4.19 billion
• Operational Highlights
  • Oil and natural gas production for the quarter was down by 8.6% due to the shutdown of activities in Libya
  • Natural gas sales for the quarter rebounded from a year ago, up by 6%
  • Acquisition of two important exploration and development leases in Ukraine
  • Continuing exploration success with the Perla 4 appraisal well and offshore discoveries in Ghana, the Barents Sea and the UK North Sea

Paolo Scaroni, Chief Executive Officer, commented, "In the first quarter of 2011, marked by the Libyan events, Eni delivered a solid set of financial results on the back of a favorable oil price environment. In spite of ongoing uncertainties regarding resumption of our activities in Libya, the profitability and growth outlook for our Company has remained positive underpinned by a sound financial position, the quality of our asset portfolio, and a strong projects pipeline."


Adjusted operating profit

Adjusted operating profit was €5.13 billion, up 18.4% from the first quarter of 2010. This was due to a better operating performance reported by the Exploration & Production Division (up 32.1%) on the back of stronger oil prices. The Engineering & Construction Division reported a strong performance. The Petrochemical Division also improved versus a year ago as operating losses were substantially cut. These positive trends were partially offset by poor performance reported by the Refining & Marketing Division due to high costs for oil feedstock which were only partially transferred to refined product prices and the Gas & Power Division which was affected by weaker margins on gas sales.

Adjusted Net Profit

Adjusted net profit was €2.22 billion, up 21.6% compared with a year ago, as a result of better operating performance and a decreased adjusted tax rate (from 53% to 50.5%).

Capital expenditure

Capital expenditure for the quarter amounted to €2.87 billion mainly related to continuing development of oil and gas reserves, the construction of rigs and offshore vessels in the Engineering & Construction segment and the upgrading of gas transport infrastructure.

Cash flow

Net cash generated by operating activities amounted to €4.19 billion and were used to fund capital expenditure (€2.87 billion) as well as pay down net borrowings2 which was down by €1.17 billion from December 31, 2010, to €24.95 billion. Cash flow from operating activities was negatively affected by a lower cash inflow of €347 million associated with transferring trade receivables due beyond end of 2010 to factoring institutions amounting to €1,279 million in the fourth quarter 2010, while the current quarter benefitted from transferring €932 million of trade receivables due beyond March 31, 2011 to those institutions.

Financial Ratios

Return on Average Capital Employed (ROACE)3 calculated on an adjusted basis for the twelve-month period ending on March 31, 2011, was 11.4%. The ratio of net borrowings to shareholders' equity including non-controlling interest – leverage3 – decreased to 0.44 at March 31, 2011, from 0.47 as of December 31, 2010. This change was due to profit for the period and reduced net borrowings, notwithstanding the appreciation of the euro against the US dollar as recorded at March 31, 2011, vs. December 31, 2010 (up 6.4%) which reduced shareholders' equity by €1.9 billion.

Exploration & Production

Eni reported liquids and gas production of 1,684 kboe/d for the first quarter of 2011, down by 8.6% from the first quarter of 2010 (down 158 kboe/d). The magnitude of this reduction was the result of the shutdown of activities at several of Eni's producing sites in Libya and the closure of the GreenStream pipeline transporting gas from Libya to Italy which occurred on February 22, 2011, as a result of ongoing political instability and conflict in the Country. From April 2011, Eni production in Libya has been flowing at a level of 50-55 kboe/d and with the full supply supporting local production of electricity. Performance in the quarter was negatively impacted by lower entitlements in the Company's PSAs due to higher oil prices with an overall effect of 32 kboe/d compared to the year-earlier quarter, in addition to the above mentioned Libyan shutdown that caused a production loss of 129 kboe/d compared to the first quarter of 2010. These negatives were partly offset by continuing production ramp-up in Egypt, Iraq and Italy.

Gas & Power

Eni's worldwide natural gas sales recovered from the first quarter of 2010 (up 6% to 32.33 bcm). Sales on the Italian market increased by 10.2% due to client additions in the industrial, power generation and wholesale segments as well as higher volumes supplied. In Europe, Eni sales showed growth in all of the Company's major markets (up by 14.2% on average), excluding Belgium as a result of strong competitive pressures. Turkey, France, the Iberian Peninsula and Germany/Austria were the markets posting the largest increases. Sales to shippers which import gas to Italy decreased by 42.5%. This was due to lower availability of Libyan production and lower volumes purchased.

Portfolio developments

Ukraine

In April 2011, Eni reached an agreement with Cadogan Petroleum plc for the acquisition of an interest in two exploration and development licenses located in the Dniepr-Donetz basin, in Ukraine. This agreement is part of the development of cooperation initiatives in hydrocarbon exploration and production in the Country also reaffirmed in a Memorandum of Understanding with the Ukrainian Ministry of Ecology and Natural Resources.

Alaska

In February 2011, production start-up was achieved at the Nikaitchuq operated field (Eni 100%), located in the North Slope basins offshore Alaska, with resources of 220 million barrels. Production is expected to peak at 28 kbbl/d.

China

In January 2011, Eni signed a Memorandum of Understanding with CNPC/PetroChina to promote common opportunities to jointly expand operations in conventional and unconventional hydrocarbons in China and outside China. The parties will also cooperate in the field of advanced technology, with a special focus on the exploitation of unconventional oil and gas resources.

Angola

In January 2011, Eni was awarded rights to explore and the operatorship of offshore Block 35 in Angola, with a 30% interest. The agreement foresees drilling 2 wells and 3D seismic surveys to be carried out in the first 5 years of exploration. This deal is subject to the approval of the relevant authorities.

Exploration activities

In the first quarter of 2011, significant exploratory success was achieved in:

• Ghana with the appraisal well Sankofa-2 in the offshore license Cape Three Points (Eni 47.22% , operator);
• the Norwegian sector of the Barents Sea with the Skrugard oil and gas discovery in the PL532 license (Eni 30% );
• Venezuela with the Perla 4 appraisal well of the homonymous discovery in the Cardon IV offshore block (Eni 50%, operator);
• United Kingdom with the appraisal of the Culzean discovery (Eni 16.95%).

Outlook

Management expects that the global economic recovery will progressively strengthen across the year 2011. Nonetheless, the 2011 outlook is characterized by a certain degree of uncertainty and volatility also in light of ongoing political instability and conflict in Libya. Eni forecasts an upward trend for Brent crude oil prices supported by healthier global oil demand. For short-term economic and financial projections, Eni assumes an average Brent price of 101 $/bbl for the full year 2011. Management expects that the European gas market will remain weak as sluggish demand growth is insufficient to absorb current oversupplies. Refining margins are expected to remain unprofitable due to weak underlying fundamentals and high feedstock costs. Against this backdrop, management expectations about the main trends in the Company's businesses for 2011 and beyond are disclosed below.

• Production of liquids and natural gas is forecast to decline from 2010 (1.815 million boe/d was the actual level in 2010 at 80 $/bbl) at the Company's pricing scenario of 101 dollar a Brent barrel for the full year. The decline is expected as a result of volumes losses in Libya following the shutdown of almost all of the Company's production facilities. Better production performance at the Company's assets elsewhere in the world will help offset the impact associated with rising crude oil prices on PSAs entitlements. The magnitude of the Libyan production loss will depend on how long the situation lasts, which management cannot predict for the time being. From April 2011, Eni's production in Libya has been flowing at the rate of 50-55 kboe/d, down from the expected level of 280 kboe/d for the year. Management estimates that each day in which production remains at current levels will cause a reduction of approximately 600 boe/d in the full-year average daily production. Management has been implementing its plans to target production growth in the Company' assets by ramping up fields that were started in 2010, growing the production plateau at the giant Zubair oilfield in Iraq, starting up new fields in Australia, Algeria and the US, as well as executing production optimizations in particular in Nigeria, Egypt, Angola and the United Kingdom;
• Worldwide gas sales are expected to grow from 2010 (in 2010 actual sales amounted to 97.06 bcm), in spite of sales losses to certain Italian importers due to lower availability of gas from Libya. Management plans to drive volume growth in Italy leveraging clients additions in the power generation, industrial and wholesale segments, as well as organic growth in key European markets. Considering mounting competitive pressure in the gas market, the achievement of the planned volumes target will be underpinned by strengthening the Company's leadership on the European market; marketing actions intended to strengthen the customer base in the domestic market and renegotiating the Company's long-term gas purchase contracts. The cash flow impact associated with lower sales to Italian shippers will be offset by expected lower cash outflows associated with the Company's take-or-pay gas purchase contracts as the Company is planning to meet lower availability of Libyan gas with gas from other sources in its portfolio;
• Regulated businesses in Italy will benefit from the pre-set regulatory return on new capital expenditures and continuing efficiency actions;
• Refining throughputs on Eni's account are expected to slightly decline compared to 2010 (actual throughputs in 2010 were 34.8 mmtonnes). The decline is mainly expected at the Venice refinery due to difficulties in supplying Libyan crude oil. Higher volumes are expected to be processed on more competitive refineries and the optimization of refinery cycles, as well as efficiency actions, are expected to be implemented in response to a volatile trading environment;
• Retail sales of refined products in Italy and the rest of Europe are expected to be substantially in line with 2010 (11.73 mmtonnes in 2010) against the backdrop of weaker demand. Management plans to improve sales leveraging selective pricing and marketing initiatives, starting new service stations, developing the "non-oil" business and service upgrade;
• The Engineering & Construction business confirms solid results due to increasing turnover and a robust order backlog.

In 2011, management plans to make capital expenditures broadly in line with 2010 (€13.87 billion was invested in 2010) and will mainly be directed to developing giant fields and starting production at new important fields in the Exploration & Production Division, refinery upgrading related in particular to the realization of the EST project, completing the program of enhancing Saipem's fleet of vessels and rigs, and upgrading the natural gas transport infrastructure. Assuming a Brent price of $101/barrel and the planned divestment of certain assets, management forecasts that the ratio of net borrowings to total equity (leverage) at year-end will be lower than in 2010.

Crude Prices Rise For Second Day After Report of Reduced Saudi Production

Crude Prices Rise For Second Day After Report of Reduced Saudi Production



Apr 14, 2011

Crude oil climbed for a second day on the New York Mercantile Exchange on a report out of Saudi Arabia that the holder of the world's largest oil reserves, and the second largest producer of oil, has reduced output this month.

May oil futures were up almost 1% to $108.10 per barrel, after the chief economist at Riyadh-based Banque Saudi Fransi said the Kingdom of Saudi Arabia had cut production by 300,000 barrels per day.

Barclays Plc (NYSE:BCS) said the country might be reducing production of its lighter oil blends introduced in response to the disruption of Libyan output last month.

Prices have gone up 18% this year as unrest has swept across the Middle East. Elections in Nigeria later this month have many fearful of decreased output from that country, Africa's top crude producer.

Stream O&G to Enter Second Phase of Seismic Prog. at Delvina

Stream O&G to Enter Second Phase of Seismic Prog. at Delvina

Thursday, April 14, 2011
Stream O&G Ltd.

Stream O&G reported the advancement of its Delvina Block gas exploration program Phase II with the award of the seismic tomography contract. This second phase of the seismic program is target oriented, focused on improving the definition of the three structures in preparation for drilling of the exploration wells. The additional seismic data will be integral to the successful execution of the Company's Plan of Exploration ("PoE") on the Delvina Block, accessing over 600 BCF of gas resources.

The field segment of the program will commence in May 2011, providing monitoring of the north, south and east structures adjacent to the existing producing Delvina field. The resulting information will be utilized to determine the location of the planned exploration well.

"Our exploration program at Delvina is moving forward as planned," said Dr. Sotirios Kapotas, President and CEO. "The Delvina gas field and Block offer significant growth potential for the Company, and is expected to provide new opportunities in a scarce gas environment. The production potential can be utilized in various ways to the benefit of Stream adding shareholder value."

Per the November 30, 2010 independent reserves report, the Delvina gas field and block were evaluated to hold approximately 616 BCF of gas initially-in-place (high estimates; AJM Petroleum Consultants). Future activities at Delvina are expected to result in the conversion of possible reserves into probable reserves, while the drilling of the first horizontal well is expected to convert probable into proved reserves and contingent resources into probable reserves. Drilling exploration wells in the adjacent structures is expected to convert prospective resources.

Stream plans to expand its existing gas market and is finalizing gas utilization plans which will support the Delvina development program timelines. A small power generation plant is expected to be installed in 2011 at the Delvina gas field. Plans are being finalized for a large scale power generation plant in support of the Company's full scale field and block development. These activities are expected to provide production for additional markets for power generation, oilfield enhanced oil recovery utilization and other industrial consumers.

Gas Prices Continue Rise, Approach $4 A Gallon

Gas Prices Continue Rise, Approach $4 A Gallon



AAA reported today that the price of gas had reached a national average of $3.79 per gallon for regular grade, a $0.29 jump over the last 2 weeks, and nearly $1 higher than the same time last year.

Former president of Shell Oil John Hofmeister predicted that American could be paying $5 per gallon by 2012.

Drivers are already altering their habits. Data from MasterCard's Spending Pulse showed fuel consumption down 3.6% in the week ending April 1st.

The average price for a gallon of gas reached a peak of $4.11 on July 17, 2008.

Oil is trading down 3.42% to $106.16 per barrel.

Chevron Expects 1Q Earnings to Rise, Helped by Higher Prices

Chevron Expects 1Q Earnings to Rise, Helped by Higher Prices

Tuesday, April 12, 2011
Dow Jones Newswires
by Isabel Ordonez & Ben Lefebvre

Chevron said it expects first-quarter earnings to rise from the prior quarter, helped by higher oil prices and slightly offset by lower profits from its refining and marketing arm.

The outlook from the second-largest U.S. oil company by market value after Exxon Mobil Corp. signals that major oil companies will report a surge in quarterly earnings for the period ended March 31, boosted by climbing oil prices, which appreciated in average almost $20 a barrel compared with the same quarter a year ago, says Fadel Gheit, an analyst at Oppenheimer & Co.

Chevron said an interim earnings update released Monday afternoon that its exploration and production earnings for the first quarter will be higher than fourth quarter, but added that profits will be hurt by less production received due to the negative effect of production-sharing contracts signed with foreign governments. These type of contracts lower the reserves the company can book when oil prices rise.

Chevron said that, during the first two months of the quarter, the company received $88.23 a barrel for crude oil from its U.S. fields, up 11% from the prior quarter and up 20% from a year earlier. Natural-gas prices rose 14% from the prior quarter but fell 22% from the year-earlier period to $4.15 per thousand cubic feet.

San Ramon, Calf.-based Chevron said its U.S. production in the first two months of the quarter was 686,000 barrels of oil equivalent per day. For the full first quarter of 2010, production was 734,000 barrels of oil equivalent a day. International output was 2.07 million barrels of oil equivalent per day in January through February. For the entire quarter a year earlier, daily international production reached 2.05 million barrels of oil equivalent.

Shares rose 1.8% to $109.76 in after-hours action. As of the close, the stock had risen 36% in the past year.

Chevron said it expects its downstream quarterly earnings to sink as it processed less fuel to sell than during the same period of the year before. The company said its U.S. plants processed 870 million barrels of oil a day into gasoline, diesel and other fuels through February 2011, compared to 889 barrels a day for the first full quarter of 2010.

Despite the lower sales volumes, Chevron realized a higher profit margin for the fuel it sold during the quarter. Refining margins at its U.S. plants averaged $21.08 through March, 40% higher than in the full quarter of 2010.

The oil giant also said its refining and marketing earnings in the first quarter are expected to be negatively impacted by the adjustment in the accounting of the fair value of some assets tied to oil prices. Oppenheimer's Gheit said this is likely to mean the company's downstream earnings will be affected by the difference between the price the company paid for oil and what it was worth by the time it was delivered to the company's refineries.

Chevron also noted that it expects to post between $250 million and $350 million of after-tax charges for the quarter. It said it expects the total charges to be at the high end of the guidance range.

The company has reported better results of late, helped by higher prices. In January, Chevron said its fourth-quarter earnings jumped 72%.

Chevron is slated to report first-quarter earnings on April 29.