Tullow's Twiga South-1 Discovery Flows at 2,812 bopd

Africa-focused Tullow Oil unveiled results from flow tests at its Twiga South-1 oil discovery in Kenya, which showed a combined flow rate of 2,812 barrels of oil per day (bopd) from three reservoir zones.

In a statement released Thursday, Tullow added that the combined rate has the potential to flow at around 5,200 bopd. However, the company also said that its Ugandan Ondyek-1 exploration well did not encounter hydrocarbons.

Tullow said the Twiga South-1 results provide encouragement for the company's forthcoming testing program at Ngamia-1A on Block 10BB, where four zones are planned to be tested using the Weatherford 804 rig. Testing activities here are expected to begin in March and be complete by the end of May.

Meanwhile, the firm said Ondyek-1 well in Uganda has now been plugged and abandoned after it failed to find hydrocarbons but that it is carrying out further evaluation of the nearby Lyec-1 discovery, with the partners on block EA-1A reevaluating the remaining exploration potential of the area.

Tullow Exploration Director Angus McCoss commented in a statement:

"While it is still early days for our exploration campaign in Kenya, these flow tests results at Twiga South-1 are an important step on the way towards understanding the commercial potential of the two discoveries we have made so far. The Ondyek-1 well in Uganda did not encounter hydrocarbons but has contributed much to our understanding of the limits of the EA-1A block."

Tullow has a 50-percent operated interest in the Twiga South-1 well.

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Tullow's Twiga South-1 Discovery Flows at 2,812 bopd

Africa-focused Tullow Oil unveiled results from flow tests at its Twiga South-1 oil discovery in Kenya, which showed a combined flow rate of 2,812 barrels of oil per day (bopd) from three reservoir zones.

In a statement released Thursday, Tullow added that the combined rate has the potential to flow at around 5,200 bopd. However, the company also said that its Ugandan Ondyek-1 exploration well did not encounter hydrocarbons.

Tullow said the Twiga South-1 results provide encouragement for the company's forthcoming testing program at Ngamia-1A on Block 10BB, where four zones are planned to be tested using the Weatherford 804 rig. Testing activities here are expected to begin in March and be complete by the end of May.

Meanwhile, the firm said Ondyek-1 well in Uganda has now been plugged and abandoned after it failed to find hydrocarbons but that it is carrying out further evaluation of the nearby Lyec-1 discovery, with the partners on block EA-1A reevaluating the remaining exploration potential of the area.

Tullow Exploration Director Angus McCoss commented in a statement:

"While it is still early days for our exploration campaign in Kenya, these flow tests results at Twiga South-1 are an important step on the way towards understanding the commercial potential of the two discoveries we have made so far. The Ondyek-1 well in Uganda did not encounter hydrocarbons but has contributed much to our understanding of the limits of the EA-1A block."

Tullow has a 50-percent operated interest in the Twiga South-1 well.

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Tullow's Twiga South-1 Discovery Flows at 2,812 bopd

Africa-focused Tullow Oil unveiled results from flow tests at its Twiga South-1 oil discovery in Kenya, which showed a combined flow rate of 2,812 barrels of oil per day (bopd) from three reservoir zones.

In a statement released Thursday, Tullow added that the combined rate has the potential to flow at around 5,200 bopd. However, the company also said that its Ugandan Ondyek-1 exploration well did not encounter hydrocarbons.

Tullow said the Twiga South-1 results provide encouragement for the company's forthcoming testing program at Ngamia-1A on Block 10BB, where four zones are planned to be tested using the Weatherford 804 rig. Testing activities here are expected to begin in March and be complete by the end of May.

Meanwhile, the firm said Ondyek-1 well in Uganda has now been plugged and abandoned after it failed to find hydrocarbons but that it is carrying out further evaluation of the nearby Lyec-1 discovery, with the partners on block EA-1A reevaluating the remaining exploration potential of the area.

Tullow Exploration Director Angus McCoss commented in a statement:

"While it is still early days for our exploration campaign in Kenya, these flow tests results at Twiga South-1 are an important step on the way towards understanding the commercial potential of the two discoveries we have made so far. The Ondyek-1 well in Uganda did not encounter hydrocarbons but has contributed much to our understanding of the limits of the EA-1A block."

Tullow has a 50-percent operated interest in the Twiga South-1 well.

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Norwest's Arrowsmith-2 Well Flows Promising Amount of Early Gas

Norwest Energy said Tuesday that flow-back and testing of primary shale target, the Carynginia Formation, has started in the onshore Arrowsmith-2 well, and early results are promising with a maximum gas rate of 350,000 standard cubic feet per day (scf/d) recorded on several occasions since the well started flow-back Feb.15.

In its statement, Norwest disclosed that the Carynginia Formation only had a limited period of flowback in the original 2012 hydraulic fracture stimulation program due to a tight operational timeline, and as a result there is still a significant percentage of the frac fluid remaining on the formation.

"Despite this, the Carynginia is demonstrating a strong early gas rate from this zone; a very encouraging sign," Norwest said in a statement.

The Carynginia Formation is considered a primary target in the well; it is the most typical "shale" formation in the basin, is demonstrated to be laterally extensive, and is approximately 820 feet (250 meters) thick in the vicinity of the well. The Kockatea Shale, classified as an oil producing zone, has been marked Norwest as a secondary target in the exploration program.

Arrowsmith-2 first flowed gas from the High Cliff Sandstone at a maximum rate of 777,000 scf/d in July last year. The well was temporarily shut-in in September when Norwest discovered oil being produced to surface in the early stages of flow back and testing of the Kockatea Shale, and again in December for pressure build up monitoring works, according to separate statements released by Norwest last year. Operations at the well were restarted in January this year.

Following testing of the Carynginia Formation, operations will continue with the testing of the Irwin River Coal Measure and High Cliff Sandstone intervals. In total, testing works in the three zones will take up to four months, Norwest revealed.

Norwest is the operator of Arrowsmith-2 with a 27.945 percent interest. The other shareholders are AWE and Bharat Petroleum, with shares of 44.252 percent and 27.803 percent respectively. 

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

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Norwest's Arrowsmith-2 Well Flows Promising Amount of Early Gas

Norwest Energy said Tuesday that flow-back and testing of primary shale target, the Carynginia Formation, has started in the onshore Arrowsmith-2 well, and early results are promising with a maximum gas rate of 350,000 standard cubic feet per day (scf/d) recorded on several occasions since the well started flow-back Feb.15.

In its statement, Norwest disclosed that the Carynginia Formation only had a limited period of flowback in the original 2012 hydraulic fracture stimulation program due to a tight operational timeline, and as a result there is still a significant percentage of the frac fluid remaining on the formation.

"Despite this, the Carynginia is demonstrating a strong early gas rate from this zone; a very encouraging sign," Norwest said in a statement.

The Carynginia Formation is considered a primary target in the well; it is the most typical "shale" formation in the basin, is demonstrated to be laterally extensive, and is approximately 820 feet (250 meters) thick in the vicinity of the well. The Kockatea Shale, classified as an oil producing zone, has been marked Norwest as a secondary target in the exploration program.

Arrowsmith-2 first flowed gas from the High Cliff Sandstone at a maximum rate of 777,000 scf/d in July last year. The well was temporarily shut-in in September when Norwest discovered oil being produced to surface in the early stages of flow back and testing of the Kockatea Shale, and again in December for pressure build up monitoring works, according to separate statements released by Norwest last year. Operations at the well were restarted in January this year.

Following testing of the Carynginia Formation, operations will continue with the testing of the Irwin River Coal Measure and High Cliff Sandstone intervals. In total, testing works in the three zones will take up to four months, Norwest revealed.

Norwest is the operator of Arrowsmith-2 with a 27.945 percent interest. The other shareholders are AWE and Bharat Petroleum, with shares of 44.252 percent and 27.803 percent respectively. 

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

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Beach's Halifax-1 Well Flows Back Gas and Stimulation Fluid

Beach Energy disclosed Thursday that the flow back of stimulation fluid and gas from the Halifax-1 well, located in the onshore ATP 855P permit, started Feb.11, 2012.

As at 1800 local time Wednesday, the flow was being constrained to 2.2 million standard cubic feet per day by a 24/64 inch choke due to temperature restrictions on elements of the surface equipment. It is anticipated that the choke will be further opened as the ratio of gas to fluid in the well stream increases.

The well reached total depth at 13,994 feet (4,267 meters), after which a 14 stage fracture stimulation program was completed throughout the whole of the gas saturated Permian target zone.

Seven stages were completed in the deeper Patchawarra Formation, one in the Murteree Shale, two in the Epsilon Formation, two in the Roseneath Shale, one in the Daralingie Formation and one in the Toolachee Formation.

Commenting on the well's results, Beach's Managing Director Reg Nelson said: "Halifax-1 is the fourth vertical well to have flowed gas from the unconventional exploration program that Beach has operated to date. Each well in the exploration program is integral to the program as a whole, with various data points obtained along the way. It is anticipated that Halifax-1 will provide relevant information over the coming months that will continue to move this unconventional play toward commercialization."

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