Chevron natural gas discovery offshore Australia

Chevron reported a natural gas discovery by Australian subsidiary in the Exmouth plateau the Carnarvon basin, offshore Western Australia.

Gas found well about 243 feet (74) of the net pay of the satyr-3. The fountain located 113 miles (182 km) North of Exmouth in the approval WA-374-P and was of water to a depth of 13.369 (4.075 m) in 1.124 3.688 m drilled.

"Satyr 3 of our is thirteenth offshore discovery in Australia since mid-2009," says George Kirkland, Vice President, Chevron Corporation.

"This latest discovery the quality and lasting value strengthens our Australian exploration of leasing companies in the Carnarvon basin."

Chevron Australian subsidiary is the operator of the area permit WA-374-P and holds a 50 per cent, with Exxon Mobil and shell each hold 25 per cent.

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Statoil Gullfaks discovery

Statoil’s drilling of the Skinfaks South well in the North Sea has been completed and the estimated volume is between 1.9 and 6.9 million barrels of oil equivalents.

This is the fourth infrastructure-near discovery in the Gullfaks area in a 10 month period.

Light oil has been confirmed in Middle Jurassic reservoir rocks (Brent group) and a 80 metre high column in good-quality reservoir rocks.

"We are currently evaluating, together with Development and production Norway , how this discovery can be connected to the existing infra-structure," said Tore Loseth, exploration vice president for North Sea.

Skinfaks South is located directly west of the Gullfaks field in the North Sea Tampen area, where Statoil is focusing on infrastructure-led exploration (ILX).

"Our exploration strategy for the Norwegian continental shelf focuses both on high-impact discoveries and what we call time-critical ILX, which is exploration close to installations that within a couple of years will have the capacity to receive the oil and gas we find," said Loseth.

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Chevron natural gas discovery offshore Western Australia

Posted at: December 15, 2011

Chevron reported a natural gas discovery by Australian subsidiary in the Exmouth plateau the Carnarvon basin, offshore Western Australia.

"Find Vos-1 of our Zwolfter offshore discovery in Australia since mid-2009," said George Kirkland, Vice President, Chevron Corporation.

"Our successful drilling program offshore Western Australia shows Chevron global exploration."

Vos-1 is also about occurred 453 feet (138) net gas pay. Located the well was drilled 1484 meter of water in the field permit WA-439-P about 186 miles (300 km) of Exmouth on the western coast of Australia, in 4869 to a depth of 12.461 (3798m).

"Our ongoing exploration success of our Australian raw materials base further underpins our drive as a leading supplier of liquefied natural gas markets and gas to Western Australia, to", said melody Meyer, President, Chevron Asia Pacific exploration and production.

Chevron Australian subsidiary is the operator of WA-439-P and holds a 50 per cent, with shell development (Australia) Pty Ltd holds the remaining 50%.

Written by Richard Price, editor, energyme.com. Follow energyme.com on Twitter @ Energyme. Information provided by companies or PR agencies, are responsible for the content. Send press releases in Word format to richard@energyme.com

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Lundin discovery offshore Malaysia

Lundin Petroleum has discovered oil in the Janglau-1 well that was drilled in Block PM308A, offshore Peninsular Malaysia.

Janglau-1 was drilled to a total depth of 3,820 metres by the jackup rig "Offshore Courageous".

The objectives of the well were Oligocene intra-rift sands and the underlying fractured pre-Tertiary section.

During drilling below 3,153 metres, oil was found in multiple pay sand units in an intra-rift sand/shale section that extended over a gross interval of approximately 300 metres. Oil samples were recovered at surface during drilling.

The well was successfully logged and petrophysical analysis indicates 24 metres of net oil pay. Pressure testing and fluid sampling were completed and oil samples recovered for laboratory analysis. A mini-DST test was successfully completed.

Following completion of the well further work will be undertaken on the data recovered to fully evaluate the discovery and it’s potential.

"Janglau-1 results is further validation of Lundin Petroleum's strategy of pursuing organic growth opportunities in focused core areas with evidence of active petroleum systems," said Ashley Heppenstall.

"This is Lundin Petroleum’s first discovery in this area and follows 2 prior gas discoveries in the Sabah core area drilled earlier in 2011. Janglau-1 confirms a new oil play where Lundin Petroleum has built a significant production sharing contract position. Lundin Petroleum together with partners look forward to further exploration drilling in PM308A in the coming years and building on the encouragement provided by Janglau-1."

The PM308A production sharing contract (PSC) is operated by Lundin Malaysia BV with 35 percent equity interest. Partners are JX Nippon Oil & Gas Exploration (Peninsular Malaysia) Limited with 40 percent and PETRONAS Carigali with 25 percent.

Following completion of Janglau-1 the Offshore Courageous jackup rig will move to the Bertam-2 appraisal well location in the adjacent PM307 PSC area.

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Production potential raised at Carioca discovery, offshore Brazil

BG Group reported an extended well test (EWT) had increased the production potential of the Carioca discovery located on the BM-S-9 concession in the Santos Basin, offshore Brazil.

Results from the EWT in progress at the well 3-SPS-74, known as Carioca Nordeste, indicate potential production of approximately 28 000 barrels of oil per day (bopd), above initial expectations. The well, which is connected to the FPSO Dynamic Producer, is currently producing 23 400 bopd, constrained by facilities.

The potential of the Carioca area was further underlined by results from the 4-BRSA-973A-SPS well, informally known as Abare, located 35 kilometres south of the discovery well 1-BRSA-491-SPS (Carioca) and 293 kilometres off the coast of Sao Paulo state.

Wireline samples showed good quality oil at Abare, about 28 degrees API, in carbonate reservoirs at a depth of about 4 830 metres. A drill stem formation test is planned to evaluate the productivity of the interval.

Five wells have now been drilled in the Carioca area in addition to the completion of two formation tests. This fulfills the evaluation commitments required by the National Agency for Petroleum, Natural Gas and Biofuels (ANP).

Given the promising results at Carioca, the consortium intends to do more appraisal work to further evaluate the area's full potential.

To allow this, the ANP has approved a revision of activities and has extended the deadline for a Declaration of Commerciality from November 2011 to 31 December 2013. There is no change to the consortium's plans and schedule for development and production.

BG Group has a 30% interest in Block BM-S-9 which is comprised of two appraisal areas - Guara and Carioca (Petrobras 45%, operator and Repsol Sinopec 25%).

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PA Resources discovery on Lille John prospect

PA Resources has completed its sidetrack of the Lille John well to a Chalk target but did not encounter effective reservoir.

The sidetrack provided a second penetration of the Miocene sandstone level encountered in the original well, again oil-bearing and with improved reservoir quality compared to the initial penetration.

"We have now ended our successful Danish drilling campaign as operator, with two discoveries from two exploration wells," said Bo Askvik, President and CEO at PA Resources.

"The sidetrack at Lille John has shown improved reservoir quality in the Miocene sandstone which gives us further encouragement that the Miocene seismic anomaly reflects yet better reservoir. We are very satisfied with this result of the campaign and have commenced a comprehensive evaluation to progress Broder Tuck towards development. Additional studies will be conducted to progress the further exploration of the Lille John area and appraisal of the exciting Miocene discovery, made at a reservoir level which has not been widely explored in Denmark."

The exploration sidetrack at the Lille John prospect in Danish Licence 12/06 has been drilled to a total depth of 1,307 meters below mean sea level. It encountered a modest thickness of highly-cemented Chalk with weak hydrocarbon indications, but no effective reservoir.

The sidetrack also penetrated the Miocene sandstones some 180 meters away from the Miocene interval that was found to be oil-bearing in the initial Lille John well in October. Again the Miocene sandstones were oil-bearing in the sidetrack at a depth approximately 930 meters below mean sea level, with improved reservoir quality compared to the original well which confirmed oil of gravity 34-35 degrees API. Both penetrations were primarily located for the Chalk target and as such lie outside of the well-imaged Miocene seismic amplitude anomaly interpreted to reflect better developed oil-bearing sandstone. The sidetrack was not located to allow the secondary Middle Jurassic target to be drilled and so is now being plugged and abandoned.

The Lille John well is located approximately 17 kilometres south of Gorm Field and 8 kilometres from PA Resources’ gas and condensate discovery at the Broder Tuck prospect made in July of this year. The License 12/06 partners will formally declare both Broder Tuck and Lille John as discoveries, which triggers the commencement of further technical and commercial evaluation of the finds and allows a request for a licence extension to be submitted. A comprehensive re-evaluation of the nearby Miocene exploration prospectivity and the Chalk and Middle Jurassic potential which remains in the Lille John prospect will also be conducted using the new well results and reprocessed 3D data.

The following companies participate in Licence 12/06: PA Resources UK Limited (64%), Nordsofonden (Danish North Sea Fund) (20%), Danoil Exploration A/S (8%) and Spyker Energy APS (8%). PA Resources is operator of the licence.

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PA Resources discovery on Lille John prospect

PA Resources has completed its sidetrack of the Lille John well to a Chalk target but did not encounter effective reservoir.

The sidetrack provided a second penetration of the Miocene sandstone level encountered in the original well, again oil-bearing and with improved reservoir quality compared to the initial penetration.

"We have now ended our successful Danish drilling campaign as operator, with two discoveries from two exploration wells," said Bo Askvik, President and CEO at PA Resources.

"The sidetrack at Lille John has shown improved reservoir quality in the Miocene sandstone which gives us further encouragement that the Miocene seismic anomaly reflects yet better reservoir. We are very satisfied with this result of the campaign and have commenced a comprehensive evaluation to progress Broder Tuck towards development. Additional studies will be conducted to progress the further exploration of the Lille John area and appraisal of the exciting Miocene discovery, made at a reservoir level which has not been widely explored in Denmark."

The exploration sidetrack at the Lille John prospect in Danish Licence 12/06 has been drilled to a total depth of 1,307 meters below mean sea level. It encountered a modest thickness of highly-cemented Chalk with weak hydrocarbon indications, but no effective reservoir.

The sidetrack also penetrated the Miocene sandstones some 180 meters away from the Miocene interval that was found to be oil-bearing in the initial Lille John well in October. Again the Miocene sandstones were oil-bearing in the sidetrack at a depth approximately 930 meters below mean sea level, with improved reservoir quality compared to the original well which confirmed oil of gravity 34-35 degrees API. Both penetrations were primarily located for the Chalk target and as such lie outside of the well-imaged Miocene seismic amplitude anomaly interpreted to reflect better developed oil-bearing sandstone. The sidetrack was not located to allow the secondary Middle Jurassic target to be drilled and so is now being plugged and abandoned.

The Lille John well is located approximately 17 kilometres south of Gorm Field and 8 kilometres from PA Resources’ gas and condensate discovery at the Broder Tuck prospect made in July of this year. The License 12/06 partners will formally declare both Broder Tuck and Lille John as discoveries, which triggers the commencement of further technical and commercial evaluation of the finds and allows a request for a licence extension to be submitted. A comprehensive re-evaluation of the nearby Miocene exploration prospectivity and the Chalk and Middle Jurassic potential which remains in the Lille John prospect will also be conducted using the new well results and reprocessed 3D data.

The following companies participate in Licence 12/06: PA Resources UK Limited (64%), Nordsofonden (Danish North Sea Fund) (20%), Danoil Exploration A/S (8%) and Spyker Energy APS (8%). PA Resources is operator of the licence.

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