OGX, a largest privately owned oil & gas company in Brazil, today announced that it has identified the presence of hydrocarbons in the Albian and Aptian sections of well 1-OGX-63-SPS in the BM-S-57 block, in the shallow waters of the Santos Basin. OGX holds a 100% working interest in this block.
“This discovery is important for its huge hydrocarbon column and net pay identified in the Albian section, as well as by the quality of the Aptian reservoir and its behavior,” commented Paulo Mendonça, General Executive Officer and Exploration Officer of OGX.
A hydrocarbon column of approximately 1,000 meters was encountered in Albian reservoirs with about 110 meters of net pay. The drilling of the well, which is still in progress, already reached the Aptian section of the reservoir identifying hydrocarbons through a high gas presence that resulted in a kick, which is already controlled.
The OGX-63 well, known as Fortaleza, is still in progress and located in the BM-S-57 block and is situated approximately 102 kilometers off the coast of the state of Rio de Janeiro at a water depth of approximately 155 meters. The Ocean Quest rig initiated drilling activities on October 08, 2011.
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The oil and gas company’s eastern Australia vice president James Baulderstone told a conference that he expected gas prices to more than double within two decades, driven by demand and linking it to oil prices.
Soaring global demand for liquefied natural gas (LNG) is expected to contribute to Australia’s wealth and make it one of the world’s biggest exporters of the commodity.
However the use of fracking to access coal seam gas (CSG) or shale gas is strongly opposed by many Australians and Americans, including farmers, who say it contaminates prime agricultural land.
Santos insists that is false and gas is a safe, low-carbon alternative to coal for providing energy, with eastern Australia potentially having enough gas to supply it for a century.
“The five LNG trains already sanctioned, with more planned, represent a quantum change in eastern Australian natural gas demand,” Mr Baulderstone told the Opportunities and Challenges for Australian Gas conference on Monday.
“Provided natural gas development activity is allowed to proceed at the right pace, and the market is willing to pay the increased cost of extraction, there is sufficient gas in Eastern Australia to meet this demand.”
But he added that it was not viable to develop much of the gas reserves to meet the new demand at current Australian gas prices of about $4 a gigajoule.
Australian gas prices were some of the cheapest in the developed world, Mr Baulderstone said.
“Comparatively modest price increases driven by this anticipated stronger demand will make the development of extensive additional resources economic for the first time.”
Domestic users would be able to absorb such increases as gas prices had been flat for a decade and a rise was long overdue, he said.
He predicted prices would move to $6 to $9 a gigajoule.
“Industrial customers like Rio Tinto, BHP and Xstrata have benefited greatly over the past decade from basically flat east coast Australian gas prices while their commodity prices (iron ore, copper, silver, coal) have increased in some instances nearly ten fold during the same period,” Mr Baulderstone said.
Santos is heavily invested in CSG through the $US16 billion ($A15 billion) Gladstone Liquefied Natural Gas (GLNG) project it is leading and is also developing shale gas projects in the Cooper Basin in central Australia.
It is also close to finalizing a $924 million bid for NSW-based Eastern Star Gas, which controls NSW’s largest CSG resource.
“Even if the development of Santos’ CSG business in NSW was a third of the size of our Queensland project, $2 billion would be added to NSW state revenues and over 1,000 direct jobs would be created,” he said.
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