Member Info for LayLadyLay

And a repeat for willowpillow ... in4cedros goes into a bar and asks the bartender for the wifi passphrase You'll have to buy a drink first, says the bartender I'll have a coke, says in4cedros Is Pepsi ok? Sure. How much is that? �3 Can I have the wifi passphrase now? You'll have to buy a drink first Lower case, no spaces

Sad news at the Nestle factory today where a member of staff was seriously hurt when a pallet of chocolate fell more than 50 feet & crushed him underneath. He tried in vain to attract attention but every time he shouted " The milky bars are on me " everyone just cheered.

An American fighter plane was flying over Syria when he noticed a flying carpet on each side of his plane, both with machine guns on board. Sensing danger he shot them down. Back at base his commander was furious ... apparently they were Allied Carpets

'Did LK do any video media to accompany yesterday's rns ?' I believe he's at Ealing Studios as we speak, doing a remake of that old comedy classic 'Carry on Columbus'. :) I'm sure there is something in the pipeline.

. Discovered in 1911 by the Grieg 1 well . Delineated by 16 wells, the field currently has 10 wells available for reactivation . Production was suspended in mid-2016 following which a subsidiary of Columbus performed limited reactivation work on three Bonasse wells in June 2017 . Additional shallow drilling targets available within the field boundaries. . Columbus believes significantly greater potential exists for additional production through the application of proven technologies which Columbus has already used on its Goudron field . Reactivation programme to commence in 2Q 2018, fully funded from available cash resources

'Is anyone ware of what Bonasse did previously and give any insight to what may behold ?' Production was suspended in mid-2016 following which a subsidiary of Columbus performed limited reactivation work on three Bonasse wells in June 2017. At present, Bonasse is intermittently producing at around 10 barrels of oil per day.

I'm not keen on watching those presentations because all I see is a used car salesman. Will he continue to receive 50% of his salary in shares after his first anniversary or revert to 100% cash?

In April 2015 investors were singing the praises of the company plans, roadmap to the future. Fast forward to April 2018 and the wheel has come full circle. If it were not for the share consolidation last year the current SP would be 0.28p Only time will tell if the new management can succeed where the previous management failed. So far they have carried out low cost well workovers and optimisations similar to how LGO approached the problem of increasing/maintaining production in 2015. 'During the period April to July 2015 five legacy wells were reactivated with the use of new perforations into existing and new production zones at both the Goudron Sandstone and C-sand horizons. This work has assisted in offsetting the production decline of the legacy wells and further candidates for improved production in legacy wells are being sought, however, the principal focus of the operations remains new wells and their successful management.' The real test for CERP will be when the company resumes drilling operations which are inherently more capital intensive. There is an ongoing waterflood trial but so far we have yet to have any results reported. The past is not irrelevant. There are the same problems that CERP has to overcome if it is to be more successful than the previous incumbents.

If all roadmaps proved to be accurate then LGO/CERP would have been producing over 3000 bopd in 2016, slightly less in 2017. 5500 bopd in 2018 with the benefit of waterflood, peaking at 7500 bopd in 2019 before production begins to decline anually. The reality is very different. Source: LGO ACIP meeting presentation 15th April 2015

Wendy says to say hi to Twinky and she says she hopes you're wearing a thermal vest as it must be freezing up there. I've had enough of you lot for today so have a good Easter break and don't do anything I wouldn't ;) https://www.youtube.com/watch?v=uZM42X_qYmE

So much for 3D seismic data. It clearly isn't infallible as a means of locating deposits.

'You�ve provided little info to evaluate the drilling prospect of Hofwiese - 1, got anything to suggest why they chose that drill location? ' Rhein Petroleum expects to find sizeable oil resources in lower Tertiary sandstone formations. To reach the selected target in the subsurface, the well will be initially drilled vertically to some 400 m depth and then deviated towards the northwest. Hence, the length of the well reach some 2,300m along hole. In 2012, Rhein Petroleum acquired a large 3D seismic survey nearby Karlsruhe covering an area of more than 280 square kilometres. The results revealed the presence of prospective structures under Graben-Neudorf and several other locations. However, proof of oil in the subsurface requires the drilling of the Hofwiese - 1 well. According to Dr. Michael Suana, CEO of Rhein Petroleum, Hofwiese-1 is located in an area of previous oil production. The nearby Graben and Huttenheim fields were producing until the 1960s and the Leopoldshafen field until the 1980s. Today, Rhein Petroleum is working on re-establishing domestic oil production by applying modern, small footprint technology. Once the target is reached and the presence of oil is demonstrated, Rhein Petroleum plans to perform production tests. Dr..Suana emphasizes also that oil from the Upper Rhine Graben is of excellent quality. It is light, contains very low sulphur and has many valuable ingredients. Read the full article here ... http://tulipoil.com/rhein-petroleum-spud-of-hofwiese-1-at-graben-neudorf

Emily - the Oligocene period lasted a mere 11 million years and ended some 23 million years ago. Your reference to a well drilled 65 years ago is understandable as that sounds a long time ago and of course technology has evolved since then. But the fact that water was found in the Oligocene and only a small amount of oil pay in a shallower zone is more evidential than any amount of mapping and surveying. Fyzabad is only some 40 km away from SWP. Whether SWP exhibits different characteristics at deep level remains to be seen. The proof of the pudding will be a test drill as that trumps any amount of theoretical data. As you know LK has become non-executive chairman of Rhein Petroleum which is the operating company largely owned by Tulip Oil. On 16 August 2016 the company made an announcement. I know this is before the time that LK joined the company but doubt that if he had been in place earlier that it would have made any material difference to the outcome. I am exhibiting this purely as an example and to demonstrate that risks should be taken seriously by investors and not to jump to the conclusion that anything in oil exploration is undoubtedly going to be successful simply because the team doing the planning and work are of the highest calibre. 'Rhein Petroleum GmbH - in which Tulip Oil Holding B.V. holds a 90% interest - is proceeding with operations to plug and abandon its exploration well Hofwiese - 1 located close to the town of Graben-Neudorf in the German federal state of Baden W�rttemberg. The well was spudded on 23 June 2016 and reached the planned target timely and safely. However, the objective geological formations at 1800 m below surface were found water-bearing.'

3rd time lucky - maybe. Emily, The Maturin Basin of eastern Venezuela, including Trinidad. has produced approximately 9.5 billion brls of oil, and is the site of significant new discoveries at El Furrial and El Carito. The present structural basin was formed by oblique compression during Oligocene to Miocene time, with the northem flank being a folded and thrusted terrane over-riding the South American continental margin. This deformed northern flank extends into the subsurface to the basin axis, and includes the southern half of the onshore and offshore territory of the Republic of Trinidad and Tobago. The basin was infilled from west to east by deep-marine shales, turbidites, pelagic oozes and deltaic sediments of Neogene age. Deltaic sands form the reservoirs of all the important oilfields in the basin. Oil occurrence on the northern flank of the basin is associated with thrust-related structures in Venezuela and wrench-related structures in Trinidad. There are many excellent prospects along the flanks of wrench-related ridges with diapiric cores in the Trinidad and Tobago portion of the basin. Late Pliocene and Pleistocene deltaic sands shale-out northwards in very thick aggradational lobes, enhancing the prospectivity of the southern flanks of these ridges. The prospectivity of the fold-and-thrust belt in Trinidad and Tobago is limited by the distribution of reservoir facies in pre-Pliocene sediments. Candidates for non-deltaic reservoirs are Miocene limestones, Oligocene sheet-sands, Eocene turbidites and Cretaceous fractured argillites. In 1954, Apex drilled Well 560 to test the Oligocene. This is the deepest well ever drilled onshore in Trinidad, reaching a total depth of 16,155 feet. Some 30 feet of oil pay was found in the Cruse formation (at a much higher level) but drilling was stopped on reaching the Oligocene due to the presence of water. I'm not saying that the SWP is not going to yield any significant oil at depth as we shall just have to wait for the results of any future drilling. But Well 560 demonstrates that there is a possibility of similar results to those found at Fyzabad in which case any finds would most likely be in the shallower Cruse and not the gusher that everyone hopes for. Offshore presents better prospects in my opinion but let's wait and see.

Hopefully easier to read. Emily, The Maturin Basin of eastern Venezuela, including Trinidad. has produced approximately 9.5 billion brls of oil, and is the site of significant new discoveries at El Furrial and El Carito. The present structural basin was formed by oblique compression during Oligocene to Miocene time, with the northem flank being a folded and thrusted terrane over-riding the South American continental margin. This deformed northern flank extends into the subsurface to the basin axis, and includes the southern half of the onshore and offshore territory of the Republic of Trinidad and Tobago. The basin was infilled from west to east by deep-marine shales, turbidites, pelagic oozes and deltaic sediments of Neogene age. Deltaic sands form the reservoirs of all the important oilfields in the basin. Oil occurrence on the northern flank of the basin is associated with thrust-related structures in Venezuela and wrench‐related structures in Trinidad. There are many excellent prospects along the flanks of wrench-related ridges with diapiric cores in the Trinidad and Tobago portion of the basin. Late Pliocene and Pleistocene deltaic sands shale-out northwards in very thick aggradational lobes, enhancing the prospectivity of the southern flanks of these ridges. The prospectivity of the fold-and-thrust belt in Trinidad and Tobago is limited by the distribution of reservoir facies in pre-Pliocene sediments. Candidates for non-deltaic reservoirs are Miocene limestones, Oligocene sheet-sands, Eocene turbidites and Cretaceous fractured argillites. In 1954, Apex drilled Well 560 to test the Oligocene. This is the deepest well ever drilled onshore in Trinidad, reaching a total depth of 16,155 feet. Some 30 feet of oil pay was found in the Cruse formation (at a much higher level) but drilling was stopped on reaching the Oligocene due to the presence of water. I'm not saying that the SWP is not going to yield any significant oil at depth as we shall just have to wait for the results of any future drilling. But Well 560 demonstrates that there is a possibility of similar results to those found at Fyzabad in which case any finds would most likely be in the shallower Cruse and not the gusher that everyone hopes for. Offshore presents better prospects in my opinion but let's wait and see.

Emily, The Maturin Basin of eastern Venezuela, including Trinidad, is the site of significant new discoveries. The present structural basin was formed by oblique compression during Oligocene to Miocene time, with the northem flank being a folded and thrusted terrane over‐riding the South American continental margin. This deformed northern flank extends into the subsurface to the basin axis, and includes the southern half of the onshore and offshore territory of the Republic of Trinidad and Tobago. The basin was infilled from west to east by deep‐marine shales, turbidites, pelagic oozes and deltaic sediments of Neogene age. Deltaic sands form the reservoirs of all the important oilfields in the basin. Oil occurrence on the northern flank of the basin is associated with thrust‐related structures in Venezuela and wrench‐related structures in Trinidad. There are many excellent prospects along the flanks of wrench‐related ridges with diapiric cores in the Trinidad and Tobago portion of the basin. Late Pliocene and Pleistocene deltaic sands shale‐out northwards in very thick aggradational lobes, enhancing the prospectivity of the southern flanks of these ridges. The prospectivity of the fold‐and‐thrust belt in Trinidad and Tobago is limited by the distribution of reservoir facies in pre‐Pliocene sediments. Candidates for non‐deltaic reservoirs are Miocene limestones, Oligocene sheet‐sands, Eocene turbidites and Cretaceous fractured argillites. In 1954, Apex drilled Well 560 to test the Oligocene. This is the deepest well ever drilled onshore in Trinidad, reaching a total depth of 16,155 feet. Some 30 feet of oil pay was found in the Cruse formation (at a much higher level) but drilling was stopped on reaching the Oligocene due to the presence of water. I'm not saying that the SWP is not going to yield any significant oil at depth as we shall just have to wait for the results of any future drilling. But Well 560 demonstrates that there is a possibility of similar results to those found at Fyzabad in which case any finds would most likely be in the shallower Cruse and not the gusher that everyone hopes for. Offshore presents better prospects in my opinion but let's wait and see.

They will quote a percentage increase from the lowest to the highest production in the period as that will more impress the gullible. What is more important is the average and total production for the period. Then you should look to see if they can maintain any increase in future periods as the dreaded Goudron decline will not have disappeared simply because there's a new management team. If they can maintain production or increase it further then you have to look at underlying costs attributed to workover/ well optimisation efforts which are not a one-off exercise. I mean real costs not word of mouth inteview stuff. You won't see the real numbers for some considerable time. SWP is speculative. Exploration is a different ball game in terms of costs and risks. Success may be achieved but for those claiming this is a no brainer and CERP can only go one way should take a look at other oilers that have failed. Remember KEA? PUKA3 was supposed to be a game changer, drilling into the sweet spot which turned out to be mostly water. I have reason to believe that a deep drill on the SWP could have a similar outcome. Good luck, though. It's an interesting one to watch.

Hellraiser1 ... point to where I have ever stated an estimate for ongoing costs in Spain. You can't because I have never made an estimate. You keep linking me to Ross but that only shows how quickly you have been suckered into a way of thinking by the rampy pampy gang. There is no connection between Ross and I except in the fevered brains of those who try to split the board. As blobblob has already pointed out, there is no effective saving for over 9 months. Smoke and mirrors comes to mind.

... will lose out IMHO. I don't think Koot loves you; you are just a means to an end. But what will that end be?

... but many will try to distort it. https://www.youtube.com/watch?v=Go2jbER0wk0