Africa Oil Corp. - World-Class East Africa Oil Exploration (Seite 98)
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ISIN: CA00829Q1019 · WKN: A0MZJC · Symbol: AOI
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Antwort auf Beitrag Nr.: 47.246.838 von texas2 am 02.07.14 13:27:41RE:Lots of new info from Keith Hill today (July 3)
Great find, thanks Wallstreet1112. For anyone interested here is the translated article.
Hopefully we will see the updated resource report before the end of this month. GLTA.
Africa Oil's recent update of drilling results received mixed reviews by the market and analysts. Especially the fact that Sala deposit in Kenya were found to contain gas, rather than oil, got negative attention.
Exploration Company CEO Keith Hill is not disappointed.
"Oil is normally better than gas, but in this particular case, I think that the gas can be very profitable," he says in an interview with news agency Direkt.
Kenya suffers from a lack of electricity and the country's government has pressed hard for new power projects to become a reality. It's one of the reasons that the time from discovery of the deposit to a positive cash flow will be shorter than if the oil discovered.
"We will meet with government representatives in Nairobi next week. The advance notice we have received indicates that we should be able to get permission and sign contracts quickly, "says Keith Hill.
Negotiations will now begin on prices and terms, while studies on the environmental and social impacts should be performed.
"That part of the process should take about six months. If the groundwork is done right takes construction work not more than one year. We should be able to be in production within 18 to 24 months, "said Africa Oil chief.
A longer term project is the 150-mil-long pipeline for oil planned to go through Kenya and Uganda, a project with costs of 2-2.5 billion dollars, equivalent to 16 billion. The planning goes forward.
"The authorities in Kenya and Uganda have now largely coordinated their interests and both want to have this pipeline. On the financing side, institutions like the World Bank and the IMF, but also large conglomerates in Asia, showing interest, "said Keith Hill.
The most optimistic analysts have talked about a completion in 2017, while Africa Oil has been on the 2018 and aiming for 2019.
"The most realistic is perhaps sometime in 2018 or 2019., I think 2017 would be very difficult to reach," says Keith Hill.
A more closely related reference point for Africa Oil's next resource update, which the company is currently working on. Preliminary data have been obtained, but more work is information from a couple of the biggest fields.
"It's important data and I have high expectations," said Keith Hill, who expects to publish the final report in the second half of July.
In the slightly longer term, Africa Oil one or more partners to develop their discoveries.
Another option is that the entire company is bought by a bigger player. As recently as April, a pair of such corporate deals announced, when Glencore acquired Caracal Energy for the equivalent of more than 9 billion investment fund Al Mirqab from Qatar offered even a little more for Heritage Oil.
"It shows that the interest in mid-sized exploration companies is large. I get calls about acquisitions or partnerships every week, but during the past quarter, the intensity increased, "says Keith Hill.
He continues:
"We expect to be involved in any form of industry business recently in late 2015".
The Company's cash is calculated with current plans to last until the second quarter of next year. Exactly how long will depend on the rate at which drilling is performed.
"After that, some form of bridge financing needed, but it's nothing I'm worried about. There are many options, "said CEO: n
Africa Oil traded since the turn of the Stockholm Stock Exchange's Large Cap list, where the largest companies listed. Now wait as road shows on both sides of the Atlantic in September.
"It is important for us to be among the big companies. It provides more institutional clients to invest in us and we hope for some new owners, both in Sweden and elsewhere in Europe, "says Keith Hill.
Read more at http://www.stockhouse.com/companies/bullboard/v.aoi/africa-o…
Great find, thanks Wallstreet1112. For anyone interested here is the translated article.
Hopefully we will see the updated resource report before the end of this month. GLTA.
Africa Oil's recent update of drilling results received mixed reviews by the market and analysts. Especially the fact that Sala deposit in Kenya were found to contain gas, rather than oil, got negative attention.
Exploration Company CEO Keith Hill is not disappointed.
"Oil is normally better than gas, but in this particular case, I think that the gas can be very profitable," he says in an interview with news agency Direkt.
Kenya suffers from a lack of electricity and the country's government has pressed hard for new power projects to become a reality. It's one of the reasons that the time from discovery of the deposit to a positive cash flow will be shorter than if the oil discovered.
"We will meet with government representatives in Nairobi next week. The advance notice we have received indicates that we should be able to get permission and sign contracts quickly, "says Keith Hill.
Negotiations will now begin on prices and terms, while studies on the environmental and social impacts should be performed.
"That part of the process should take about six months. If the groundwork is done right takes construction work not more than one year. We should be able to be in production within 18 to 24 months, "said Africa Oil chief.
A longer term project is the 150-mil-long pipeline for oil planned to go through Kenya and Uganda, a project with costs of 2-2.5 billion dollars, equivalent to 16 billion. The planning goes forward.
"The authorities in Kenya and Uganda have now largely coordinated their interests and both want to have this pipeline. On the financing side, institutions like the World Bank and the IMF, but also large conglomerates in Asia, showing interest, "said Keith Hill.
The most optimistic analysts have talked about a completion in 2017, while Africa Oil has been on the 2018 and aiming for 2019.
"The most realistic is perhaps sometime in 2018 or 2019., I think 2017 would be very difficult to reach," says Keith Hill.
A more closely related reference point for Africa Oil's next resource update, which the company is currently working on. Preliminary data have been obtained, but more work is information from a couple of the biggest fields.
"It's important data and I have high expectations," said Keith Hill, who expects to publish the final report in the second half of July.
In the slightly longer term, Africa Oil one or more partners to develop their discoveries.
Another option is that the entire company is bought by a bigger player. As recently as April, a pair of such corporate deals announced, when Glencore acquired Caracal Energy for the equivalent of more than 9 billion investment fund Al Mirqab from Qatar offered even a little more for Heritage Oil.
"It shows that the interest in mid-sized exploration companies is large. I get calls about acquisitions or partnerships every week, but during the past quarter, the intensity increased, "says Keith Hill.
He continues:
"We expect to be involved in any form of industry business recently in late 2015".
The Company's cash is calculated with current plans to last until the second quarter of next year. Exactly how long will depend on the rate at which drilling is performed.
"After that, some form of bridge financing needed, but it's nothing I'm worried about. There are many options, "said CEO: n
Africa Oil traded since the turn of the Stockholm Stock Exchange's Large Cap list, where the largest companies listed. Now wait as road shows on both sides of the Atlantic in September.
"It is important for us to be among the big companies. It provides more institutional clients to invest in us and we hope for some new owners, both in Sweden and elsewhere in Europe, "says Keith Hill.
Read more at http://www.stockhouse.com/companies/bullboard/v.aoi/africa-o…
Danke in die Slowakai
Email from Sophia
For those interested:
Hi!
I haven’t checked those numbers but they will be available on Sedi.ca.
Everybody has been blacked out from exercising options or trading stock for several months and there have been some options that either expired during the blackout or coming up for expiration. Nowadays, when one exercises options one has to pay taxes to the government immediately – taxes are very high here in Canada and most people have to sell a bit of stock in order to pay for the taxes (then they have to pay tax on that too!). In the past most of the guys didn’t sell shares to pay taxes – they just issued cheques to the government out of savings – it gets quite hard to do that forever so they’ve had to sell some stock – it’s not a reflection of their feelings about the Company – in fact it’s maddening to them because they would prefer to accumulate as much stock as possible given the exciting potential for the Company.
Best regards,
Sophia
From: Robert GGG
[mailto:robert.ggg@nextra.sk]
Sent: Tuesday, July 01, 2014 1:37 AM
To: Sophia Shane
Subject: Insider sell -off
Hi Sophia,
I’m an AOI investor.
Could you please comment insider sell off that occurred at the end of last week?
Jun 27/14 Phillips, James Common Shares -75,000 $7.33
Jun 27/14 Martinez, Paul Common Shares -49,800 $7.37
Jun 27/14 Gibbs, Ian Common Shares -150,600 $7.41
Jun 26/14 Hill, Keith Charles Common Shares -200,000 $7.25
Jun 25/14 Phillips, James Common Shares -75,000 $7.37
Should we fear?
Many thanks,
Best regards,
Robert GGG
Slovakia
Read more at http://www.stockhouse.com/companies/bullboard/v.aoi/africa-o…
Email from Sophia
For those interested:
Hi!
I haven’t checked those numbers but they will be available on Sedi.ca.
Everybody has been blacked out from exercising options or trading stock for several months and there have been some options that either expired during the blackout or coming up for expiration. Nowadays, when one exercises options one has to pay taxes to the government immediately – taxes are very high here in Canada and most people have to sell a bit of stock in order to pay for the taxes (then they have to pay tax on that too!). In the past most of the guys didn’t sell shares to pay taxes – they just issued cheques to the government out of savings – it gets quite hard to do that forever so they’ve had to sell some stock – it’s not a reflection of their feelings about the Company – in fact it’s maddening to them because they would prefer to accumulate as much stock as possible given the exciting potential for the Company.
Best regards,
Sophia
From: Robert GGG
[mailto:robert.ggg@nextra.sk]
Sent: Tuesday, July 01, 2014 1:37 AM
To: Sophia Shane
Subject: Insider sell -off
Hi Sophia,
I’m an AOI investor.
Could you please comment insider sell off that occurred at the end of last week?
Jun 27/14 Phillips, James Common Shares -75,000 $7.33
Jun 27/14 Martinez, Paul Common Shares -49,800 $7.37
Jun 27/14 Gibbs, Ian Common Shares -150,600 $7.41
Jun 26/14 Hill, Keith Charles Common Shares -200,000 $7.25
Jun 25/14 Phillips, James Common Shares -75,000 $7.37
Should we fear?
Many thanks,
Best regards,
Robert GGG
Slovakia
Read more at http://www.stockhouse.com/companies/bullboard/v.aoi/africa-o…
Kenya: Taipan Upbeat At Local Oil Opportunities
By Anthony Langat, 27 June 2014
Nairobi — THE announcement of discovery of gas by Africa Oil in Sala-1 well on Block 9 in Kenya has boosted the optimism of Taipan Resources, which is drilling at a prospect that is within the region.
Just days after the announcement of the oil find at Sala-1 which Africa Oil and Marathon Oil share in a 50-50 basis, Taipan has said that an oil source could also be present in the Cretaceous section at Badada-1 Well which is its prospect.
Taipan said that the Sala-1 well is located approximately 60 kilometres from Taipan's Badada prospect, on Block 2B, which is expected to spud in late 2014 or early 2015.
Paul Logan, the Exploration Manager at Taipan said that the announcement of a gas discovery with associated oil shows in Sala-1 has significantly de-risked the prospectively of the Anza Basin. He said that Sala-1 is believed to have tested a Cretaceous rollover structure against the Lagh Bogal Fault in a similar position to the Badada prospect, but at a much deeper stratigraphic level.
“Badada-1 will test an as yet, undrilled thick Tertiary sequence of probable Miocene age, similar to that present in the Kingfisher Field in the Albert Basin of Uganda and the Tertiary discoveries of the Lokichar basin in Kenya. The anticipated 3 000 metres of Tertiary section is expected to contain both source and reservoir intervals. The presence of oil shows in Sala-1 suggests that an oil source could also be present in the Cretaceous section at Badada-1,” said Logan.
http://allafrica.com/stories/201406271538.html?aa_source=acr…
By Anthony Langat, 27 June 2014
Nairobi — THE announcement of discovery of gas by Africa Oil in Sala-1 well on Block 9 in Kenya has boosted the optimism of Taipan Resources, which is drilling at a prospect that is within the region.
Just days after the announcement of the oil find at Sala-1 which Africa Oil and Marathon Oil share in a 50-50 basis, Taipan has said that an oil source could also be present in the Cretaceous section at Badada-1 Well which is its prospect.
Taipan said that the Sala-1 well is located approximately 60 kilometres from Taipan's Badada prospect, on Block 2B, which is expected to spud in late 2014 or early 2015.
Paul Logan, the Exploration Manager at Taipan said that the announcement of a gas discovery with associated oil shows in Sala-1 has significantly de-risked the prospectively of the Anza Basin. He said that Sala-1 is believed to have tested a Cretaceous rollover structure against the Lagh Bogal Fault in a similar position to the Badada prospect, but at a much deeper stratigraphic level.
“Badada-1 will test an as yet, undrilled thick Tertiary sequence of probable Miocene age, similar to that present in the Kingfisher Field in the Albert Basin of Uganda and the Tertiary discoveries of the Lokichar basin in Kenya. The anticipated 3 000 metres of Tertiary section is expected to contain both source and reservoir intervals. The presence of oil shows in Sala-1 suggests that an oil source could also be present in the Cretaceous section at Badada-1,” said Logan.
http://allafrica.com/stories/201406271538.html?aa_source=acr…
Antwort auf Beitrag Nr.: 47.225.962 von texas2 am 28.06.14 11:01:44bzw. müßte sich die Gastestrate verzehnfachen, wenn sie uns damit beim Aktienkurs herausreißen wollen; aber auch mit den 170.000 m³/d wird man in der Zukunft gutes Geld verdienen - wenn jetzt auch nicht Exxon, Shell, BP, Chevron, Conoco aus ihren Löchern herauslocken, um die staatlichen Ölfirmen zu überbieten.
In the first quarter of 2013, the Tullow-Africa Oil joint venture tested a Cretaceous play in the Anza Basin with the
Paipai-1 commitment well in Block 10A (Kenya), encountering light hydrocarbon shows. Due to concerns over
economic viability, the Company and its partners have relinquished Block 10A as the partnership focuses its
activities on the main Tertiary Rift Play across Kenya and Ethiopia.
In December 2013, the Company reported that the Bahasi-1 well on Block 9 in Kenya, had only encountered minor
shows of gas. The rig then moved to drill Sala-1 on the northeastern flank of the basin to test a large prospect in the
Cretaceous Anza rift, which is up-dip of two wells that had significant hydrocarbon shows.
In June 2014, the Company announced the Sala-1 well had resulted in a gas discovery in Block 9 onshore Kenya. The
Sala-1 drilled a large 80 square kilometer anticlinal feature along the northern basin bounding fault in the
Cretaceous Anza graben and encountered several sandstone intervals which had oil and gas shows. The well was
drilled to a total depth of 3030 meters and petrophysical analysis indicated three zones of interest over a
1000 meter gross interval which were subsequently drill stem tested. An upper gas bearing interval tested dry gas
at a maximum rate of 6 mmcf/d from a 25 meter net pay interval. The interval had net reservoir sand of over
125 meters and encountered a gas water contact so there is potential to drill up-dip on the structure where this
entire interval will be above the gas-water contact. A lower interval tested at low rates of dry gas from a 50 meter
potential net pay interval which can also be accessed at the up-dip location. It should also be noted that there were
oil shows while drilling and small amounts of oil were recovered during drilling and testing which indicates there
may be potential for oil down-dip on the structure.
An appraisal plan to follow up this discovery is currently being evaluated by the partnership in consultation with the
Kenyan government. Plans being discussed include an up-dip location to confirm the areal extent of the gas zones
tested where the full net sand interval can be intersected above the gas-water contact. The partnership is also
considering a down-dip appraisal location to test an on-lapping stratigraphic wedge on the flanks of the structure
which is of the same age as the zones in the nearby Ndovu-1 well which had oil and gas shows
In July 2013, the Company reported that the Sabisa-1 well on the South Omo Block in Ethiopia, the most northerly
well drilled on the Tertiary rift trend to date, had confirmed a viable hydrocarbon system with oil and heavy gas
shows. In December 2013, the Company announced that the potential hydrocarbon bearing sands in Sabisa-1 were
not present at the Tultule-1 well location. There were gas shows in the section, which point to a potential
hydrocarbon source, and the results of these two wells will be analyzed to determine the future exploration
program direction in the North Turkana Basin. The Company plans to drill two exploration wells in the Chew Bahir
Basin, located to the east of the South Omo Block, in 2014. In May 2014, the Company released the results of the
first of these wells, Shimela-1, which reached a final depth of 1,940 meters and encountered water bearing
reservoirs. Shimela-1 was drilled to test a prospect in a north-western sub-basin of the vast Chew Bahir basin. The
frontier wildcat well encountered lacustrine and volcanic rocks including almost 100 meters of net sandstone
reservoir within siltstones and claystones. Trace thermogenic gas shows were recorded at 1,900 meters. The
Gardim well, the second well in the Chew Bahir basin, is currently drilling.
The Company and its partners continued to actively acquire, process and interpret an extensive 2D seismic program
totaling approximately 3,044 kilometers during 2013 over Blocks 10BA, 10BB, 12A, 13T in Kenya and the South Omo
Block in Ethiopia with two onshore and one offshore 2D seismic crews operating through the year. A third onshore
2D seismic crew operating in the South Omo Block was released in May 2013 after completing 1,174 kilometers of
2D seismic. During 2014, the Company is planning to acquire 1,270 kilometers 2D seismic over the North Lokichar
and Kerio Basins covering Blocks 10BB, 10BA and 13T. In addition, the Company and its partner in Blocks 10BB and
13T have commenced the acquisition of a 550 square kilometer 3D seismic survey over the discoveries and
prospects along the western basin bounding fault in the South Lokichar Basin.
In the first quarter of 2013, the Tullow-Africa Oil joint venture tested a Cretaceous play in the Anza Basin with the
Paipai-1 commitment well in Block 10A (Kenya), encountering light hydrocarbon shows. Due to concerns over
economic viability, the Company and its partners have relinquished Block 10A as the partnership focuses its
activities on the main Tertiary Rift Play across Kenya and Ethiopia.
In December 2013, the Company reported that the Bahasi-1 well on Block 9 in Kenya, had only encountered minor
shows of gas. The rig then moved to drill Sala-1 on the northeastern flank of the basin to test a large prospect in the
Cretaceous Anza rift, which is up-dip of two wells that had significant hydrocarbon shows.
In June 2014, the Company announced the Sala-1 well had resulted in a gas discovery in Block 9 onshore Kenya. The
Sala-1 drilled a large 80 square kilometer anticlinal feature along the northern basin bounding fault in the
Cretaceous Anza graben and encountered several sandstone intervals which had oil and gas shows. The well was
drilled to a total depth of 3030 meters and petrophysical analysis indicated three zones of interest over a
1000 meter gross interval which were subsequently drill stem tested. An upper gas bearing interval tested dry gas
at a maximum rate of 6 mmcf/d from a 25 meter net pay interval. The interval had net reservoir sand of over
125 meters and encountered a gas water contact so there is potential to drill up-dip on the structure where this
entire interval will be above the gas-water contact. A lower interval tested at low rates of dry gas from a 50 meter
potential net pay interval which can also be accessed at the up-dip location. It should also be noted that there were
oil shows while drilling and small amounts of oil were recovered during drilling and testing which indicates there
may be potential for oil down-dip on the structure.
An appraisal plan to follow up this discovery is currently being evaluated by the partnership in consultation with the
Kenyan government. Plans being discussed include an up-dip location to confirm the areal extent of the gas zones
tested where the full net sand interval can be intersected above the gas-water contact. The partnership is also
considering a down-dip appraisal location to test an on-lapping stratigraphic wedge on the flanks of the structure
which is of the same age as the zones in the nearby Ndovu-1 well which had oil and gas shows
In July 2013, the Company reported that the Sabisa-1 well on the South Omo Block in Ethiopia, the most northerly
well drilled on the Tertiary rift trend to date, had confirmed a viable hydrocarbon system with oil and heavy gas
shows. In December 2013, the Company announced that the potential hydrocarbon bearing sands in Sabisa-1 were
not present at the Tultule-1 well location. There were gas shows in the section, which point to a potential
hydrocarbon source, and the results of these two wells will be analyzed to determine the future exploration
program direction in the North Turkana Basin. The Company plans to drill two exploration wells in the Chew Bahir
Basin, located to the east of the South Omo Block, in 2014. In May 2014, the Company released the results of the
first of these wells, Shimela-1, which reached a final depth of 1,940 meters and encountered water bearing
reservoirs. Shimela-1 was drilled to test a prospect in a north-western sub-basin of the vast Chew Bahir basin. The
frontier wildcat well encountered lacustrine and volcanic rocks including almost 100 meters of net sandstone
reservoir within siltstones and claystones. Trace thermogenic gas shows were recorded at 1,900 meters. The
Gardim well, the second well in the Chew Bahir basin, is currently drilling.
The Company and its partners continued to actively acquire, process and interpret an extensive 2D seismic program
totaling approximately 3,044 kilometers during 2013 over Blocks 10BA, 10BB, 12A, 13T in Kenya and the South Omo
Block in Ethiopia with two onshore and one offshore 2D seismic crews operating through the year. A third onshore
2D seismic crew operating in the South Omo Block was released in May 2013 after completing 1,174 kilometers of
2D seismic. During 2014, the Company is planning to acquire 1,270 kilometers 2D seismic over the North Lokichar
and Kerio Basins covering Blocks 10BB, 10BA and 13T. In addition, the Company and its partner in Blocks 10BB and
13T have commenced the acquisition of a 550 square kilometer 3D seismic survey over the discoveries and
prospects along the western basin bounding fault in the South Lokichar Basin.
Tullow Oil To Begin Kenyan Oil Production In 2017
June 27, 2014 Fumnanya Agbugah Business, Energy
VENTURES AFRICA – Tullow oil has placed a 2017 time frame, in line with the government’s target, to commence oil production after describing the oil as that of a “high quality and of international marketable standard.”
“The government of Kenya is looking forward to have its first oil in 2017,” said Tullow’s CEO, Paul McDade.
Having discovered eight commercially viable wells in Kenya since 2012, the British company can sell part of its stake in Kenya oil blocks to potential buyers from Europe and eastern part of the world.
To meet its 2017 target, the company has to construct a 1,330km underground heated pipeline between Holma in Uganda and Lamu through Lokichar in Kenya. This will ease transportation of Kenyan and Ugandan oil through a single pipeline.
“The quality of oil Uganda and Kenya has are compatible and can pass through the same pipeline” said Tullow vice president, for south and east Africa, Gary Thomson.
President Uhuru Kenyatta has set this plan rolling by inviting locals to buy a stake in the pipeline in other to get the full value of the infrastructure.
“We have started working with 50km corridor which will narrow to 2km and later 200m” Mr Thomson disclosed.
http://www.ventures-africa.com/2014/06/tullow-oil-to-begin-k…
June 27, 2014 Fumnanya Agbugah Business, Energy
VENTURES AFRICA – Tullow oil has placed a 2017 time frame, in line with the government’s target, to commence oil production after describing the oil as that of a “high quality and of international marketable standard.”
“The government of Kenya is looking forward to have its first oil in 2017,” said Tullow’s CEO, Paul McDade.
Having discovered eight commercially viable wells in Kenya since 2012, the British company can sell part of its stake in Kenya oil blocks to potential buyers from Europe and eastern part of the world.
To meet its 2017 target, the company has to construct a 1,330km underground heated pipeline between Holma in Uganda and Lamu through Lokichar in Kenya. This will ease transportation of Kenyan and Ugandan oil through a single pipeline.
“The quality of oil Uganda and Kenya has are compatible and can pass through the same pipeline” said Tullow vice president, for south and east Africa, Gary Thomson.
President Uhuru Kenyatta has set this plan rolling by inviting locals to buy a stake in the pipeline in other to get the full value of the infrastructure.
“We have started working with 50km corridor which will narrow to 2km and later 200m” Mr Thomson disclosed.
http://www.ventures-africa.com/2014/06/tullow-oil-to-begin-k…
Trading Spotlight
Die Zusammenfassung aus dem Prospekt (siehe unten). Wir benötige unbedingt eine weiter Ngamia 1 mit einer Testrate über 5.000 bbl/d oder besser 10.000 bbl/d wenn es mit dem Aktienkurs dem Trend nach weiter steil nach oben gehen soll (auch wenn wir uns glücklich schätzen können dass Ngamia die erste Bohrug war). Die 500 bbl/d Tests machen im Augenblick nicht glücklich (obwohl man damit in der Zukunft bei der Förderung ebenfalls gutes Geld verdienen wird) Aber mit 500 bbl/d Bohrungen wird man keine 800 km Pipeline bauen und keine Exxon anlocken. Also weiter warten und auf die Kracher hoffen
In 2012 Africa Oil with partner Tullow announced successful results from the Ngamia-1 exploration well on Block
10BB, which was the first exploration well for the Company in the Tertiary Rift Play in the Lokichar Basin. The well
encountered more than 240 meters of net oil pay and confirmed the discovery of a significant new oil producing
province, and the first significant oil discovery in Kenya. This discovery was followed by Twiga South-1 some
22 kilometers north, which also discovered and tested light gravity and further confirmed a potentially significant
extension of the Tertiary Rift Play. A third significant discovery followed in the Etuko-1 well. By early 2014 the
Company had announced additional oil discoveries in the Ekales, Agete, Amosing and Ewoi wells. The Lokichar
Basin oil volumes now exceed the threshold for development studies to commence.
On the back of the successful exploration activities in Kenya during 2012, the Company, together with its partners,
ramped up its exploration program in Kenya and Ethiopia. Entering 2013, two Tullow-Africa Oil joint venture rigs
were operating in Kenya and one joint venture rig was operating in Ethiopia. Two additional Tullow-Africa Oil joint
venture rigs (one of which is a testing and completion unit) were mobilized, the drilling unit commenced operations
in November 2013 and the testing and completions unit commenced operations in February 2014. The Company,
as operator, and its partner in Block 9 (Kenya) secured a sixth rig, which commenced drilling operations in
September 2013. In addition, the Company and its partners in Block 7/8 (Ethiopia) mobilized a seventh rig for a one
well commitment, which commenced drilling operations in October 2013. The Company will shortly release the rig
operating block 7/8 (Ethiopia) and then expects to have six drilling rigs operating in the region through the rest of
2014. During 2013, the Company completed seven exploration wells and two multi-zone well tests across its blocks
and exited the year with three wells drilling and one well under testing.
All operations in Block 10BB and Block 13T in Northern Kenya were temporarily suspended for approximately
12 days beginning on October 28, 2013 as a precautionary measure following demonstrations by members of local communities. Operations resumed after successful discussions relating to the operating environment with central
and regional government and local community leaders. These discussions led to the signing of a Memorandum of
Understanding which clearly lays out a plan for the Government of Kenya, county government, local communities
in Northern Kenya and the Tullow-Africa Oil joint venture to work together inclusively over the long-term and to
ensure operations can continue without disruption in the future.
During the first half of 2013, the Company completed a series of well tests at both Twiga South-1 and Ngamia-1 on
Blocks 13T and 10BB in Kenya, respectively. These successful well tests confirmed over 5,000 barrels of oil per day
(“bopd”) flow potential per well and doubled the previous estimates of net oil pay. Transient Pressure Analysis has
been conducted on the Twiga South-1 and Ngamia-1 well tests. No pressure depletion was recorded over the
duration of the tests.
In July 2013, the Company announced a new oil discovery at Etuko-1. Etuko-1 is located 14 kilometers east of Twiga
South-1 in Block 10BB and was the first test of the Basin Flank Play in the eastern part of the South Lokichar Basin.
The well encountered approximately 40 meters of net oil pay in the Auwerwer and Upper Lokhone targets and
approximately 50 meters of additional potential net pay in the Lower Lokhone interval based on log analysis. In
February 2014, the Company announced the results of five well tests conducted on five Lokhone pay intervals in
Etuko-1. Light 36 degree API waxy crude oil was successfully flowed from three zones at a combined average rate of
over 550 barrels of oil equivalent per day. In March 2014, the Company announced the results of the Etuko-
2 exploration well drilling to test the upper Auwerwer sands overlying the previously announced Etuko discovery.
Etuko-2 penetrated a potential significant oil column identified from formation pressure data and oil shows while
drilling and in core, with good quality reservoir but flowed only water on drill stem test. The results are considered
inconclusive and analysis is underway to consider further options to evaluate this reservoir.
In September 2013, the Company announced a new oil discovery at Ekales-1 located in the Basin Bounding Fault
Play between the Ngamia-1 and Twiga South-1 discoveries. Logs indicated a potential pay zone of 60 to 100 meters
to be confirmed by flow testing. Well testing was conducted utilizing the recently mobilized Tullow-Africa Oil joint
venture testing and completion rig. In March 2014, the company announced the results of testing operations on
the Ekales-1 well which confirmed this significant discovery. Two drill stem tests were completed and flowed at a
combined rate of over 1,000 bopd from a combined 41 meter net pay interval. The upper zone had a very high
productivity index of 4.3 stb/d/psi.
In November 2013, the Company announced a new oil discovery at Agete-1 located seven kilometers north of the
Twiga South-1 discovery along the Basin Bounding Fault Play in Block 13T. Logs indicated a significant oil column
with an estimated 100 meters of net oil pay in good quality sandstone reservoirs. In June 2014, the Company
announced that well test results confirmed the Auwerwer pay previously released with a tested flow rate of
500 bopd. Agete-2, a downdip appraisal, is currently drilling.
In January 2014, the Company announced a new oil discovery at Amosing-1 located seven kilometers southwest of
the Ngamia-1 discovery along the Basin Bounding Fault Play in Block 10BB. Logs indicate 160 to 200 meters of
potential net oil pay in good quality sandstone reservoirs. Amosing-2, a downdip appraisal well, with a planned
sidetrack, is currently drilling.
Also in January 2014, the Company announced a new oil discovery at Ewoi-1 located four kilometers to the east of
the Etuko-1 discovery in the Basin Flank Play on the eastern side of the South Lokichar Basin in Block 10BB. Logs
indicate potential net pay of 20 to 80 meters to be confirmed by well testing. Testing operations are ongoing at
Ewoi-1.
In March 2014, the Company announced the results of the Emong-1 well located four kilometers northwest of
Ngamia-1 field discovery in Block 13T. The well encountered oil and gas shows while drilling, however the
Auwerwer sandstones that are the primary reservoirs in the Ngamia field were thin and poorly developed in
Emong-1 and the well was plugged and abandoned. It is believed that the reservoir was poorly developed due to its
proximity to the basin bounding fault and its location within what appears to be a local isolated slumped fault
margin. The results are not expected to impact the thickness and quality of reservoir throughout the main Ngamia
field area.
In May 2014, the Company and its partner drilled a new prospect in the discovered basin in Northern Kenya, the
Ekunyuk-1 well, which is located on the eastern flank play on trend with recent discoveries at Etuko and Ewoi. The
well has now reached a final total depth of 1,802 meters and has encountered some 5 meters of net oil pay, within
approximately 150 meters of reservoir quality water-bearing sandstone and an equal thickness of a basin-wide rich
oil shale.
In May 2014, the Company announced initial results from the Twiga-2 appraisal well in the discovered basin in
North Kenya. The initial wellbore at Twiga-2 was drilled near the basin bounding fault and encountered some
18 meters of net oil pay within alluvial fan facies, with limited reservoir quality. A decision was made to sidetrack
the well away from the fault to explore north of Twiga-1 and some 62 meters of vertical net oil pay has been
discovered in the Auwerwer formation, similar in quality to the initial Twiga-1 discovery. The well is currently being
deepened to evaluate the Lower Lokhone sand reservoirs and a testing program for this successful well is planned
to be conducted later this year.
In June 2014, the Company announced the results of the Ngamia-2 well which was drilled 1.7 kilometers from the
Ngamia-1 discovery well to test the northwest flank of the prospect. The well encountered up to 39 meters of net
oil pay and 11 meters of net gas pay and appears to have identified a new fault block trap north of the main
Ngamia accumulation. The reservoirs were high quality with more than 200 meters of net reservoir sands with
good permeability inferred from MDT sampling. The well has been suspended for testing and the rig will continue
to drill up to 4 additional appraisal wells in the Ngamia field area for an extended well test program. A 3D seismic
program is currently being concluded over the field area which should allow for detailed mapping of the fault
trends.
Given the significant volumes discovered and the extensive exploration and appraisal program planned to fully
assess the upside potential of the basin, the Tullow-Africa Oil joint venture has agreed with the Government of
Kenya to commence development studies.
In addition, the partnership is involved in a comprehensive pre-FEED study of the export pipeline. The current
ambition of the Government of Kenya and the joint venture partnership is to reach project sanction for
development, including an export pipeline, by the end of 2015 or early 2016. The South Lokichar basin is located in
the remote northwest of Kenya, approximately 800 kilometers from the Indian Ocean, and is serviced by limited
existing infrastructure. To export the oil an 800 kilometers pipeline from the South Lokichar basin to a storage and
offloading terminal near to Lamu on the coast is being planned. Due to the waxy nature of the oil the pipeline will
be insulated and heated, which is standard technology to manage this type of crude oil. It is anticipated that the
export pipeline will be developed jointly with the Uganda Lake Albert oil fields, which will reduce the unit export
costs for both developments.
In 2012 Africa Oil with partner Tullow announced successful results from the Ngamia-1 exploration well on Block
10BB, which was the first exploration well for the Company in the Tertiary Rift Play in the Lokichar Basin. The well
encountered more than 240 meters of net oil pay and confirmed the discovery of a significant new oil producing
province, and the first significant oil discovery in Kenya. This discovery was followed by Twiga South-1 some
22 kilometers north, which also discovered and tested light gravity and further confirmed a potentially significant
extension of the Tertiary Rift Play. A third significant discovery followed in the Etuko-1 well. By early 2014 the
Company had announced additional oil discoveries in the Ekales, Agete, Amosing and Ewoi wells. The Lokichar
Basin oil volumes now exceed the threshold for development studies to commence.
On the back of the successful exploration activities in Kenya during 2012, the Company, together with its partners,
ramped up its exploration program in Kenya and Ethiopia. Entering 2013, two Tullow-Africa Oil joint venture rigs
were operating in Kenya and one joint venture rig was operating in Ethiopia. Two additional Tullow-Africa Oil joint
venture rigs (one of which is a testing and completion unit) were mobilized, the drilling unit commenced operations
in November 2013 and the testing and completions unit commenced operations in February 2014. The Company,
as operator, and its partner in Block 9 (Kenya) secured a sixth rig, which commenced drilling operations in
September 2013. In addition, the Company and its partners in Block 7/8 (Ethiopia) mobilized a seventh rig for a one
well commitment, which commenced drilling operations in October 2013. The Company will shortly release the rig
operating block 7/8 (Ethiopia) and then expects to have six drilling rigs operating in the region through the rest of
2014. During 2013, the Company completed seven exploration wells and two multi-zone well tests across its blocks
and exited the year with three wells drilling and one well under testing.
All operations in Block 10BB and Block 13T in Northern Kenya were temporarily suspended for approximately
12 days beginning on October 28, 2013 as a precautionary measure following demonstrations by members of local communities. Operations resumed after successful discussions relating to the operating environment with central
and regional government and local community leaders. These discussions led to the signing of a Memorandum of
Understanding which clearly lays out a plan for the Government of Kenya, county government, local communities
in Northern Kenya and the Tullow-Africa Oil joint venture to work together inclusively over the long-term and to
ensure operations can continue without disruption in the future.
During the first half of 2013, the Company completed a series of well tests at both Twiga South-1 and Ngamia-1 on
Blocks 13T and 10BB in Kenya, respectively. These successful well tests confirmed over 5,000 barrels of oil per day
(“bopd”) flow potential per well and doubled the previous estimates of net oil pay. Transient Pressure Analysis has
been conducted on the Twiga South-1 and Ngamia-1 well tests. No pressure depletion was recorded over the
duration of the tests.
In July 2013, the Company announced a new oil discovery at Etuko-1. Etuko-1 is located 14 kilometers east of Twiga
South-1 in Block 10BB and was the first test of the Basin Flank Play in the eastern part of the South Lokichar Basin.
The well encountered approximately 40 meters of net oil pay in the Auwerwer and Upper Lokhone targets and
approximately 50 meters of additional potential net pay in the Lower Lokhone interval based on log analysis. In
February 2014, the Company announced the results of five well tests conducted on five Lokhone pay intervals in
Etuko-1. Light 36 degree API waxy crude oil was successfully flowed from three zones at a combined average rate of
over 550 barrels of oil equivalent per day. In March 2014, the Company announced the results of the Etuko-
2 exploration well drilling to test the upper Auwerwer sands overlying the previously announced Etuko discovery.
Etuko-2 penetrated a potential significant oil column identified from formation pressure data and oil shows while
drilling and in core, with good quality reservoir but flowed only water on drill stem test. The results are considered
inconclusive and analysis is underway to consider further options to evaluate this reservoir.
In September 2013, the Company announced a new oil discovery at Ekales-1 located in the Basin Bounding Fault
Play between the Ngamia-1 and Twiga South-1 discoveries. Logs indicated a potential pay zone of 60 to 100 meters
to be confirmed by flow testing. Well testing was conducted utilizing the recently mobilized Tullow-Africa Oil joint
venture testing and completion rig. In March 2014, the company announced the results of testing operations on
the Ekales-1 well which confirmed this significant discovery. Two drill stem tests were completed and flowed at a
combined rate of over 1,000 bopd from a combined 41 meter net pay interval. The upper zone had a very high
productivity index of 4.3 stb/d/psi.
In November 2013, the Company announced a new oil discovery at Agete-1 located seven kilometers north of the
Twiga South-1 discovery along the Basin Bounding Fault Play in Block 13T. Logs indicated a significant oil column
with an estimated 100 meters of net oil pay in good quality sandstone reservoirs. In June 2014, the Company
announced that well test results confirmed the Auwerwer pay previously released with a tested flow rate of
500 bopd. Agete-2, a downdip appraisal, is currently drilling.
In January 2014, the Company announced a new oil discovery at Amosing-1 located seven kilometers southwest of
the Ngamia-1 discovery along the Basin Bounding Fault Play in Block 10BB. Logs indicate 160 to 200 meters of
potential net oil pay in good quality sandstone reservoirs. Amosing-2, a downdip appraisal well, with a planned
sidetrack, is currently drilling.
Also in January 2014, the Company announced a new oil discovery at Ewoi-1 located four kilometers to the east of
the Etuko-1 discovery in the Basin Flank Play on the eastern side of the South Lokichar Basin in Block 10BB. Logs
indicate potential net pay of 20 to 80 meters to be confirmed by well testing. Testing operations are ongoing at
Ewoi-1.
In March 2014, the Company announced the results of the Emong-1 well located four kilometers northwest of
Ngamia-1 field discovery in Block 13T. The well encountered oil and gas shows while drilling, however the
Auwerwer sandstones that are the primary reservoirs in the Ngamia field were thin and poorly developed in
Emong-1 and the well was plugged and abandoned. It is believed that the reservoir was poorly developed due to its
proximity to the basin bounding fault and its location within what appears to be a local isolated slumped fault
margin. The results are not expected to impact the thickness and quality of reservoir throughout the main Ngamia
field area.
In May 2014, the Company and its partner drilled a new prospect in the discovered basin in Northern Kenya, the
Ekunyuk-1 well, which is located on the eastern flank play on trend with recent discoveries at Etuko and Ewoi. The
well has now reached a final total depth of 1,802 meters and has encountered some 5 meters of net oil pay, within
approximately 150 meters of reservoir quality water-bearing sandstone and an equal thickness of a basin-wide rich
oil shale.
In May 2014, the Company announced initial results from the Twiga-2 appraisal well in the discovered basin in
North Kenya. The initial wellbore at Twiga-2 was drilled near the basin bounding fault and encountered some
18 meters of net oil pay within alluvial fan facies, with limited reservoir quality. A decision was made to sidetrack
the well away from the fault to explore north of Twiga-1 and some 62 meters of vertical net oil pay has been
discovered in the Auwerwer formation, similar in quality to the initial Twiga-1 discovery. The well is currently being
deepened to evaluate the Lower Lokhone sand reservoirs and a testing program for this successful well is planned
to be conducted later this year.
In June 2014, the Company announced the results of the Ngamia-2 well which was drilled 1.7 kilometers from the
Ngamia-1 discovery well to test the northwest flank of the prospect. The well encountered up to 39 meters of net
oil pay and 11 meters of net gas pay and appears to have identified a new fault block trap north of the main
Ngamia accumulation. The reservoirs were high quality with more than 200 meters of net reservoir sands with
good permeability inferred from MDT sampling. The well has been suspended for testing and the rig will continue
to drill up to 4 additional appraisal wells in the Ngamia field area for an extended well test program. A 3D seismic
program is currently being concluded over the field area which should allow for detailed mapping of the fault
trends.
Given the significant volumes discovered and the extensive exploration and appraisal program planned to fully
assess the upside potential of the basin, the Tullow-Africa Oil joint venture has agreed with the Government of
Kenya to commence development studies.
In addition, the partnership is involved in a comprehensive pre-FEED study of the export pipeline. The current
ambition of the Government of Kenya and the joint venture partnership is to reach project sanction for
development, including an export pipeline, by the end of 2015 or early 2016. The South Lokichar basin is located in
the remote northwest of Kenya, approximately 800 kilometers from the Indian Ocean, and is serviced by limited
existing infrastructure. To export the oil an 800 kilometers pipeline from the South Lokichar basin to a storage and
offloading terminal near to Lamu on the coast is being planned. Due to the waxy nature of the oil the pipeline will
be insulated and heated, which is standard technology to manage this type of crude oil. It is anticipated that the
export pipeline will be developed jointly with the Uganda Lake Albert oil fields, which will reduce the unit export
costs for both developments.
National Oil Corporation to back in Blocks 10BB and 13T
—June 26, 2014 by Samuel Kamau M.
The National oil corporation of Kenya will exercise its right to back in 2 blocks in North Western Kenya that have already yielded successful results namely Block 10BB and block 13T operated by Tullow Oil and its partner Africa Oil.
This will be the first time that the industry regulator which doubles as the Kenyan government explorer will back in on any block as the government hopes to play a part in the production of oil and gas that is currently estimated to be over 600mbbl.
This is part of the contract under the production sharing agreement that allows the government to participate should any discovery be made by acquiring some equity on the block in question despite not having invested in exploration.
According to National Oil Corporation managing director Summaya Athmani in an interview with OilNews Kenya the company is yet to discuss internally to agree on what percentage stake it will acquire.
“Under the PSC we have a clause that allows the government to acquire a stake in blocks inside the country should a discovery be made. National Oil on behalf of the government will therefore exercise this right although we are yet to decide on the equity to acquire,” says Athmani.
“Government has elected in that development area. If the Government exercises its option to participate, the contractor (or each entity constituting the contractor pro-rata) shall transfer to the Government that percentage interest specified by the Government. The Government’s participation shall be effective from the date the development plan hereof is adopted,’ reads part of the current Kenyan PSC.
Once the government participation has kicked in shall own and separately take and dispose of its share in the petroleum produced and saved to which the contractor is entitled under this contract in respect to all decisions taken under the participation agreement.
http://oilnewskenya.com/2014/06/26/national-oil-corporation-…
—June 26, 2014 by Samuel Kamau M.
The National oil corporation of Kenya will exercise its right to back in 2 blocks in North Western Kenya that have already yielded successful results namely Block 10BB and block 13T operated by Tullow Oil and its partner Africa Oil.
This will be the first time that the industry regulator which doubles as the Kenyan government explorer will back in on any block as the government hopes to play a part in the production of oil and gas that is currently estimated to be over 600mbbl.
This is part of the contract under the production sharing agreement that allows the government to participate should any discovery be made by acquiring some equity on the block in question despite not having invested in exploration.
According to National Oil Corporation managing director Summaya Athmani in an interview with OilNews Kenya the company is yet to discuss internally to agree on what percentage stake it will acquire.
“Under the PSC we have a clause that allows the government to acquire a stake in blocks inside the country should a discovery be made. National Oil on behalf of the government will therefore exercise this right although we are yet to decide on the equity to acquire,” says Athmani.
“Government has elected in that development area. If the Government exercises its option to participate, the contractor (or each entity constituting the contractor pro-rata) shall transfer to the Government that percentage interest specified by the Government. The Government’s participation shall be effective from the date the development plan hereof is adopted,’ reads part of the current Kenyan PSC.
Once the government participation has kicked in shall own and separately take and dispose of its share in the petroleum produced and saved to which the contractor is entitled under this contract in respect to all decisions taken under the participation agreement.
http://oilnewskenya.com/2014/06/26/national-oil-corporation-…
Zur Stock-Exchange: Upgrade!
----------------
AFRICA OIL TO COMMENCE TRADING ON NASDAQ OMX STOCKHOLM AND PUBLISHES PROSPECTUS
June 26, 2014 (AOI-TSX, AOI-NASDAQ OMX First North) … Africa Oil Corp. (“Africa Oil” or the “Company”) is pleased to announce that it has obtained approval of a secondary listing of its shares on NASDAQ OMX Stockholm (the “Main Market”) (the “Listing”). The shares are expected to commence trading on the Main Market on July 1, 2014. The last day of trading of the Company's shares on NASDAQ OMX First North is expected to be June 30, 2014. Holders of the Company's shares are not required to take any action in connection with the Listing. There is no issue of new shares in connection with the Listing, and the trading symbol “AOI” and ISIN-code CA00829Q1019 will remain the same. The Company’s common shares will continue to trade on the Toronto Stock Exchange under the symbol “AOI”.
A prospectus has been prepared in connection with the application for admission of the Company’s shares to trade on the Main Market. The Company’s listing prospectus has been approved by and registered with the Swedish Financial Supervisory Authority and is available on the Company’s website at www.africaoilcorp.com and Pareto Securities AB’s website at www.paretosec.com.
Keith Hill, President and CEO, commented, "The Company has enjoyed tremendous growth over the past few years as a result of our multiple major oil discoveries in Kenya. We expect much continued growth as our exploration continues on our large prospective land package in Kenya and Ethiopia. Our acreage encompasses over 215,000 square kilometres and we've really only just begun to uncover the extent of the oil resources there. It is timely now to graduate to the NASDAQ OMX Stockholm main board as it will provide greater liquidity for the Company's shares and allow for a broader shareholder base."
Pareto Securities AB is the financial advisor to the Company in connection with the Listing.
About Africa Oil Corp.
------------
Prospectus, 197 Seiten: http://www.africaoilcorp.com/i/pdf/Prospectus-Africa-Oil.pdf
----------------
AFRICA OIL TO COMMENCE TRADING ON NASDAQ OMX STOCKHOLM AND PUBLISHES PROSPECTUS
June 26, 2014 (AOI-TSX, AOI-NASDAQ OMX First North) … Africa Oil Corp. (“Africa Oil” or the “Company”) is pleased to announce that it has obtained approval of a secondary listing of its shares on NASDAQ OMX Stockholm (the “Main Market”) (the “Listing”). The shares are expected to commence trading on the Main Market on July 1, 2014. The last day of trading of the Company's shares on NASDAQ OMX First North is expected to be June 30, 2014. Holders of the Company's shares are not required to take any action in connection with the Listing. There is no issue of new shares in connection with the Listing, and the trading symbol “AOI” and ISIN-code CA00829Q1019 will remain the same. The Company’s common shares will continue to trade on the Toronto Stock Exchange under the symbol “AOI”.
A prospectus has been prepared in connection with the application for admission of the Company’s shares to trade on the Main Market. The Company’s listing prospectus has been approved by and registered with the Swedish Financial Supervisory Authority and is available on the Company’s website at www.africaoilcorp.com and Pareto Securities AB’s website at www.paretosec.com.
Keith Hill, President and CEO, commented, "The Company has enjoyed tremendous growth over the past few years as a result of our multiple major oil discoveries in Kenya. We expect much continued growth as our exploration continues on our large prospective land package in Kenya and Ethiopia. Our acreage encompasses over 215,000 square kilometres and we've really only just begun to uncover the extent of the oil resources there. It is timely now to graduate to the NASDAQ OMX Stockholm main board as it will provide greater liquidity for the Company's shares and allow for a broader shareholder base."
Pareto Securities AB is the financial advisor to the Company in connection with the Listing.
About Africa Oil Corp.
------------
Prospectus, 197 Seiten: http://www.africaoilcorp.com/i/pdf/Prospectus-Africa-Oil.pdf
Antwort auf Beitrag Nr.: 47.184.480 von motz1 am 20.06.14 15:28:29Das entsprechende Statement nun auch für Somalia - da verstehe ich es ja eher. http://www.africaoilcorp.com/i/pdf/reports/Statement-by-Afri…
Diesmal mit eindeutigem Datum, vom 23.06. Enorm auffällig im Blickfeld der Mainpage platzierte Links, ist das CSR und CG? Shift in policy? Nordea- oder Stock-Exchange-related? Arbeitsnachweis für Alex Budden? Ich werde nicht schlau daraus, die Situation ist schon zig Jahre alt.
Diesmal mit eindeutigem Datum, vom 23.06. Enorm auffällig im Blickfeld der Mainpage platzierte Links, ist das CSR und CG? Shift in policy? Nordea- oder Stock-Exchange-related? Arbeitsnachweis für Alex Budden? Ich werde nicht schlau daraus, die Situation ist schon zig Jahre alt.
Prime information, thx gabbo!
Ich habe mal ein paar Infos zum gestrigen Capital Markets Day von Tullow zusammengetragen: in Bild und Ton.
Präsentation, Folien: http://files.the-group.net/library/tullow/files/pdf_434_t.pd…
Präsentation, Folien & Video: http://www.media-server.com/m/p/r4t8zpz5 (Einmalige Anmeldung nötig)
Jedem der den Slides aus der Präsentation etwas abgewinnen kann, möchte ich besonders das Video ans Herz legen - man kann die Stellen anhand der Slides ansteuern
. So ab 1:15:00 wird es für East Africa richtig interessant. Ab Slide 53 findet eine interessante Fragerunde/Diskussion statt, die zumindest von Seite der Fragen nur Kenia beinhaltet. Die Infrastrukturplanung wird ausführlich besprochen, FID (Final Investment Decision, normalerweise for FEED) wird nun für spätestens Q1 2016 angenommen (Slide 47). Die Pipeline wird in Bezug auf deren Kapazität in vielen Szenarien geplant, um mögliche weitere Basin-Openings in Kenia direkt berücksichtigen zu können. Gut ist, dass mittlerweile wohl nicht nur Tullow mit Kenya und Uganda gut zusammenarbeitet, sondern auch die Regierungen untereinander. Early Export wird es neben der Pipeline nicht geben, insgesamt zu viel Aufwand (Zeit, Arbeit, Kosten, ...). Der Gesamtfokus liegt auf der schnellen Realisierung und Inbetriebnahme der Pipeline.
Bei 2:40:00 wird mitgeteilt, dass das Drillout im Lokichar darauf abzielt, die bisherige Zahl von 600Million Barrel bei den bisherigen Discoveries zu verdoppeln...
Ich habe mal ein paar Infos zum gestrigen Capital Markets Day von Tullow zusammengetragen: in Bild und Ton.
Präsentation, Folien: http://files.the-group.net/library/tullow/files/pdf_434_t.pd…
Präsentation, Folien & Video: http://www.media-server.com/m/p/r4t8zpz5 (Einmalige Anmeldung nötig)
Jedem der den Slides aus der Präsentation etwas abgewinnen kann, möchte ich besonders das Video ans Herz legen - man kann die Stellen anhand der Slides ansteuern
. So ab 1:15:00 wird es für East Africa richtig interessant. Ab Slide 53 findet eine interessante Fragerunde/Diskussion statt, die zumindest von Seite der Fragen nur Kenia beinhaltet. Die Infrastrukturplanung wird ausführlich besprochen, FID (Final Investment Decision, normalerweise for FEED) wird nun für spätestens Q1 2016 angenommen (Slide 47). Die Pipeline wird in Bezug auf deren Kapazität in vielen Szenarien geplant, um mögliche weitere Basin-Openings in Kenia direkt berücksichtigen zu können. Gut ist, dass mittlerweile wohl nicht nur Tullow mit Kenya und Uganda gut zusammenarbeitet, sondern auch die Regierungen untereinander. Early Export wird es neben der Pipeline nicht geben, insgesamt zu viel Aufwand (Zeit, Arbeit, Kosten, ...). Der Gesamtfokus liegt auf der schnellen Realisierung und Inbetriebnahme der Pipeline.Bei 2:40:00 wird mitgeteilt, dass das Drillout im Lokichar darauf abzielt, die bisherige Zahl von 600Million Barrel bei den bisherigen Discoveries zu verdoppeln...
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