San Leon Energy PLC --- Schiefergas in Polen und mehr (Seite 6)

[texas2]

san leon würde genau so einen treffer benötigen in polen und alles wäre geritzt .... denke lewino könnte das potential haben so eine horizontalbohrung mit 20 fracs zu bohren ...

wenn wenn und wäre nicht wäre wäre :-((



O'Cinneide
14 February 2014 12:19 GMT
.US independent Magnum Hunter has revealed a gas discovery at its first dry gas well in the Utica shale.
The Houston-based player has put the Stalder 3UH well in Monroe County, Ohio on production after testing it at a rate of 32.5 million cubic feet per day.

The well was drilled to a true vertical depth of 10,653 feet with a 5050-foot lateral section, with a 20-stage fracturing job.

“The well is continuing to clean up, and the company believes that the actual gas sales rate will likely increase further over the next several days as this water production declines,” Magnum Hunter said.

The Texas player is operator of the well on 47% and is joined by Norway’s Statoil as well as Eclipse Resources and Northwood Energy.

[texas2]

12 February 2014

San Leon Energy plc
("San Leon")
Siekierki Path to Production
Baker Hughes signs LOI to fully fund production strategy
San Leon Energy plc (AIM: SLE) announces that it has signed a Letter of Intent ("LOI") with Baker Hughes Poland Sp. z o.o. ("Baker") (together "the Companies") to jointly begin to develop the Siekierki Gas Field1 in Poland, including Polish Concessions 206, 207 and 208. The Companies plan to start gas production from four existing wells, namely Trzek-1, Trzek-2ZH and Trzek-3H on the Siekierki structure, and the nearby Krzesinki-1 well (the "Wells").
Under the proposed agreement, it is envisaged that Baker will provide all funding necessary to recomplete and bring into production the Wells. Subject to finalisation of the funding mechanism, Baker's funding may be in the form of cash, in-kind oilfield services, or a combination of both. Baker services will be provided at their standard prices and based upon a Master Service Agreement to be agreed between the Companies.
In return for fully funding the startup of production, Baker will receive a to-be-agreed portion of the profits generated from production until Baker's investment has been fully recovered. Baker will then receive a to-be-agreed net profit interest from the Wells.
The Companies have now entered an exclusivity period during which the final work scope and commercial terms will be negotiated and agreed.
Oisin Fanning, San Leon Executive Chairman, commented:
"We welcome Baker Hughes' involvement in Siekierki. This is a real milestone for San Leon and could lead to the Company's first significant production in Poland. Production from the first four wells in Siekierki will allow San Leon to understand the potential that may exist in the Siekierki complex of fields. During testing, the Trzek wells produced between 2.0-3.0 mmcfd each, and permissions are already in place for various elements of the infrastructure and export systems required to get the gas to market."
1 Acquired in January 2013 on completion of the merger of San Leon and Aurelian Oil & Gas plc.

Bin über Aurelian zu SLE gekommen und war enttäuscht keine Fortschritte zu Siekierki zu sehen. Bei 2-3 mmcf/d sollte gerade so eine wirtschaftliche Produktion darstellbar sein, wenn der Produktionsdecline nicht zu stark und schnell abfällt ...

[texas2]

45-60 Mcft/d oder 1.300-1.700 m³/d
bzw. erhoffte 5.600-10.000 m³/d
da liegen wir mit den 750 m³/d geschätzt aus der sehr manipulativ fotografierten Flamme (wie ich jetzt weiß) ja noch ziemlich weit weg. SLE hat da noch einen steinigen weiten Weg vor sich
So eine tagesrate von 2 mio cft/d wäre super gewesen, dann wären wir übern den Berg mit SLE.
Hilft nix, wir müssen weiter Daumen drücken und warten, dass sle mit der kommenden horizontalen Bohrung einen sweet spot erwischt und den frac weiter optimiert
Das mit geförderte Erdgaskondensat hilft ebenfalls und kann zum Zuckerguß+Sahnehäubchen werden beim Lewinokuchen, wenn alles gut geht



RNS Number : 3091Y
San Leon Energy PLC
23 January 2014



23 January 2014

Lewino-1G2: Successful Vertical Frac Leads To Horizontal Well

San Leon Energy Plc ("San Leon" or "the Company"), the AIM listed company focused on oil and gas exploration in Europe and North Africa, announces the successful completion of flow testing in the Ordovician shales in the Lewino-1G2 well on its 221,000 acre (894 km2) Gdansk W Concession in Poland's northern Baltic Basin. The Company has achieved all of its goals in the Lewino testing programme including extensive data gathering of crucial information required to understand the recipe for a successful frac and commercial flow in the Ordovician shales. Based upon these results San Leon plans to spud its first horizontal well and multi-stage frac at Lewino in the near future.


Highlights

· Sustained gas production rate of 45,000-60,000 standard cubic feet per day (scf/d) after 6 weeks of well clean-up, despite the well not yet being fully cleaned of frac fluid.

· Using the data acquired SIGMA3 Engineering (previously known as Apex) estimates a potential rate of 200,000-400,000 scf/d, based upon full clean-up of frac fluid. A commercial decision was taken to stop cleaning up the well (at a cost of $55,000 per day due to coiled tubing and nitrogen lift), as all necessary data has been acquired for planning a long offset horizontal well with a full multi-staged frac programme. Based upon the well performace it is estimated that several more months' flow is likely to be needed for full clean up.

· Condensate yield of around 20 barrels per mmscf improves overall economic potential of the play.

· Based on the results, a long horizontal well with multi-staged frac will now be drilled and tested as soon as possible - subject to permitting, rig availability and planning with technical partners.

· Flow rates are believed to have been achieved relying only on the highly successful frac 3 in the upper Ordovician, leaving considerable upside for future stimulation of the entire Ordovician.

· One of the key learnings of the vertical frac programme was that it is likely the entire Ordovician interval can be stimulated with a properly-planned frac design. This will be targeted with each frac in the upcoming horizontal well and will be invaluable in future commercial production in our concessions.

· In the US, horizontal wells typically yield 7-30 times the production rate and recovery of vertical wells in the same formation, especially after optimisation and learning.

· Further strengthened strategic relationship with United Oilfield Services (UOS) as both companies work together to pioneer shale gas in Poland.

Executive Chairman, Oisin Fanning, commented:

"This is the most encouraging vertical shale well test in Poland to date. We have moved a long way towards "cracking the code" towards commercial production from our unconventional plays. This has been achieved in conjunction with our technical partners, and is the result of the successful iteration of the frac design to the point where we can now see the production potential of our extensive shale gas acreage in Poland's Baltic Basin. These learnings will be put to good use in the planned multi-staged fracced horizontal well in the Lewino area, where we believe we shall be able to stimulate the entire vertical extent of the Ordovician interval with each frac, and prove commercial flow rates."

Dennis McKee, UOS CEO and President, commented:

"The recovery of gas so early in the flowback of frac fluid is highly unusual and very positive. It suggests to me that the formation really wants to flow gas. In the upcoming horizontal well we can use the success from the frac design from the upper Ordovician to target the whole of the Ordovician, as I think that the lower Ordovician only flowed back during the early stages and then closed up. This lower formation layer may well have been the source of the very early gas, and our knowledge of what works from frac 3 should enable us to keep it open in future wells. I look forward to the horizontal with great anticipation as it stands a strong chance of proving up this play."








Lewino-1G2 Results

Previously Reported Frac Operations

Frac 1 was performed in July 2013 in the lower Ordovician, and achieved very low proppant concentration.

Frac 2 was performed in November 2013 and was a re-frac of the lower Ordovician pay section, using ceramic proppant, different frac fluid chemistry, and a different frac programme. More proppant was emplaced than during frac 1, but still at significantly lower concentration than planned. Frac fluid chemistry issues appeared to have been resolved.

Frac 3 was a further iteration of the frac programme based on the results of fracs 1 and 2, this time targetting the upper Ordovician pay section - a secondary target, chosen as the lower Ordovician primary target was already fracced and re-fracced. This time the frac proceeded as per plan, emplacing far higher proppant concentrations into the formation with relative ease.

Flowback and Rate Measurement

Flowback of frac fluid through the 7" casing began on 13th November 2013, and quickly achieved continuously flared gas. On 21st November 2013 the well was shut in to allow the 2-3/8" completion tubing to be run into the hole, at which point 30% of the frac fluid from the November fracs had been recovered.

The well was reopened to flow on 4th December, now through the 2-3/8" completion tubing, and again with continuously flared gas. By 9th December 2013 37% of the frac fluid from the November fracs had been recovered and coiled tubing was run into the hole to assist with further clean up using nitrogen lift. Due to the significant dilution effect of the nitrogen lift on the formation gas, as expected it was not possible to flare during the early days of nitrogen lift. However on 20th December the flare re-lit intermittently and within a day was flaring again continuously, despite the nitrogen dilution effect. This coincided with a steady decrease in gas mixture density (formation gas plus nitrogen from coiled tubing lift) observed at surface, indicating an increase in formation gas rate as the well cleaned up.

Regular technical discussions were held with United Oilfield Services (UOS) and SIGMA3 Engineering (SIGMA3) in Denver to track and analyse the clean up and performance of the well. Considering the high daily cost of coiled tubing lift with nitrogen, the decision was taken that sufficient data had been acquired to enable post-clean up well performance to be predicted. As such, the coiled tubing was removed from the well on 16th January 2014 and a downhole shut-in tool and pressure gauges were run into the well to perform a pressure build up test over the coming weeks. This data will help refine our interpretation of the well and also frac design on future wells.

The typical formation gas rate achieved at the time the clean up was stopped was around 45,000-60,000 scf/d - a highly encouraging rate, particularly given that the well was still in the process of cleaning up, and also that it had flowed for 6 weeks (and so had time to undergo the steepest part of its natural decline curve). The hydrocarbon gas rate was calculated using surface rate measurement at various nitrogen lifting rates, detailed gas sample analysis and gas density.

In addition to the gas flow, 20 bbl of condensate per mmscf gas was observed. This would be expected to add around 20% additional revenue to future gas sales. The gas itself is "rich" and has very low CO2 and N2, and no measurable H2S.

Results Interpretation

Based upon frac and flowback data SIGMA3 calculates the likely achievable rate of the fully cleaned-up well is in the range 200,000-400,000 scf/d. This models the well with the fracs as they have been performed; with no additional optimisation of design. The well would have been expected to clean up given additional time, as occurs on the vast majority of comparable shale fracs. The 200,000-400,000 scf/d figure is also based solely on the upper Ordovician flowing.

Further, SIGMA3, San Leon and UOS are in agreement that the current production most likely comes almost entirely from the upper Ordovician only. The upper Ordovician was the secondary target for the well and was fracced with frac 3 only because the lower Ordovician already had a frac and re-frac within it (albeit with very low proppant concentrations). Indeed the upper Ordovician was only a contingent target during frac planning. Modelling indicated that the lower Ordovician had insufficient proppant concentration for its fracs to stay open once the well was significantly drawn down - something which all technical parties believe can be addressed in the planned horizontal well programme.

The lower Ordovician net pay has higher effective porosity and gas saturation than the upper Ordovician, although slightly lower net pay thickness. Therefore if the technical interpretation of flow from only the upper Ordovician is correct, then the per-frac potential for the Lewino Ordovician formation is materially higher than measured and inferred from the flowback data and SIGMA3's post-clean up extrapolation. Direct downhole flow measurements were not possible due to the presence of coiled tubing in the well.

Next Steps

Following the highly-encouraging testing results from the Lewino-1G2 vertical well, San Leon is preparing to drill a 1,500 metre horizontal well with a multi-staged frac programme. Successful developments of shale in Poland will likely use wells of this design. Long horizontal multi-fracced wells have a number of advantages over vertical wells in terms, not only of higher production rates and recovery, but also of their physical ability to clean up after fraccing, and for that clean up to be performed in a far more economical manner.

The existing well pad and a pre-prepared drilling cellar will be utilised, reducing cost and time. San Leon already has good-quality 2D seismic across the Lewino area. Some seismic lines were deliberately acquired in the most likely direction for horizontal drilling based upon regional stress directions, meaning that the well will have seismic data coverage across its entire length. Limited faulting with relatively minor offsets is expected, and the trajectory has a very slight upward dip from heel to toe. Subject to operational feasibility, the existing Lewino-1G2 wellbore will be used as a downhole listening post for microseismic data acquisition during the multiple fracs in the horizontal well.

The final frac on Lewino-1G2 provided a step-change insight into the frac design which works in this play. Proppant was emplaced very easily, without any material increase in treatment pressure. This was in-line with the final frac design and provides scope for further modification and optimisation in future fracs. This gives us confidence that fracs can be designed in the horizontal well to cover the whole of the Ordovician net pay interval, and be kept open with high proppant concentrations. Design work continues, but it is likely that the horizontal well will be landed towards the top of the lower Ordovician, providing frac initiation in the optimal zone, while also accessing the upper Ordovician.

In the US, horizontal wells typically yield 7-30 times the production rate and recovery of vertical wells in the same formation, especially after optimisation and learning over time. It is also generally accepted that production rate and recovery of wells drilled later in the development learning curve significantly outperform early wells, suggesting further material upside.

The Company is delighted to continue to work with UOS, with whom it has an existing agreement and relationship enabling flexibility over payment (to include Company shares, at its option). San Leon is also in active discussions with various industry players regarding a potential joint venture.

Summary of Lewino-1G2 Vertical Well Achievements

· Rapid first gas on flowback of final frac campaign.

· Continuous production of high-quality "rich" gas.

· Rate of 45,000-60,000 scf/d, plus around 20 bbl/mmscf condensate. SIGMA3 has calculated a current estimated rate of 200,000-400,000 scf/d with the well fully clean-up of frac fluid.

· First known application of ceramic proppant in Poland.

· Breakthrough in frac design and understanding between fracs 1 and 3.

· Ease of emplacement of proppant in frac 3 gives confidence in the ability to optimise fracs even further in the upcoming horizontal.

· Knowledge of expected significant increase in gas rate per frac when targetting both upper and lower Ordovician with each frac in the horizontal. This is based upon the interpretation that the lower Ordovician, the primary target, was inadequately stimulated by fracs 1 and 2 (prior to the breakthrough in Lewino frac design).

· Temperature log from frac 1 gave an understanding of frac height growth, which is now an input to future frac designs.

· Trial microseismic on frac 1 suggests applicability in the upcoming horizontal.

· Oil-wetting tendency of produced fines seen in frac 1 has been overcome with frac fluid chemistry changes.



Further Information

Enquiries:

[texas2]

Antwort auf Beitrag Nr.: 46.099.561 von texas2 am 22.12.13 16:59:36

Auf der ersten Seite hat SLE jetzt ein Foto von der Fackel beim Test fotografiert
http://www.sanleonenergy.com/media/933533/san-leon-macquarie…
Auf jeden Fall genug Gas für SLE um jetzt eine zusätzliche horizontale Bohrung zu bohren.
Von der Größe der Flamme könnte man vielleicht (???) 750 m³/h schätzen. Andererseits wurde die Flamme ziemlich sicher so fotografiert, damit diese möglichst groß aussieht ....

[texas2]

nix gefunden in marokko

20 December 2013



San Leon Energy plc

("San Leon" or the "Company")



Morocco Update



San Leon Energy Plc ("San Leon"), the AIM listed company focused on oil and gas exploration in Europe and North Africa, notes today's announcement by Cairn Energy ("Cairn") regarding the proposed plugging and abandoning of the FD-1 wildcat exploration well on the F prospect in the Foum Draa block, offshore Morocco.



Cairn is the Operator of the block and holds a 50% net operated interest, San Leon holds 14.17%, Serica holds 8.33% and Longreach holds 2.5%. ONYHM, the Moroccan National Bureau of Petroleum and Mines continues to hold 25%.



Oisin Fanning, Chairman of San Leon, commented:



"While we are disappointed not to have found reservoir-quality rock in the target interval, we are encouraged by the presence of hydrocarbons in the well, which proves that a working hydrocarbon system is in place. We shall now evaluate the data with a view to deciding on next steps for our equity share in the licence. We now look forward to the drilling of our next offshore Morocco well, on the Sidi Moussa prospect, by its operator Genel."



Enquiries:



San Leon Energy plc


[phone]



Oisin Fanning, Executive Chairman

[texas2]

die optimisten sitzen bei SLE
die pessimisten glauben dass in den nächsten 10 jahren kein shale gas in europa gefördert werden wird

'Cracking Europe's shale gas potential'
Source: IRIS International (19-DEC-13)

Despite the transformative impact that shale gas has had on the outlook of US energy markets, the European landscape regarding shale gas is very mixed and markets should exercise caution as multiple issues may slow progress, according to a new report issued by EY today.

On the future impact of shale gas on the European energy market, Dale Nijoka, EY's Global Oil & Gas Sector Leader said, ''The US shale gas success story has heightened speculation over the potential for shale gas to transform energy markets in other regions. Energy-intensive industries in Europe and other developed economies are hoping that development of their shale gas resources will provide access to lower-cost supplies and energy security. There is no denying the economic benefit that the evolution of a shale gas industry could bring to individual countries in Europe, helping to reduce their dependence on imports.''

Shale resources are believed to be present in at least 14 countries across Europe, including Ukraine, Germany, France, Poland and the UK, though no shale gas play has yet been brought into production. Three-quarters of estimated European shale gas reserves are concentrated in just four countries: Russia, Poland, Ukraine and France.

Estimates from a number of organizations suggest that while production costs for US shale gas range from USD 3/MBtu to USD 7/MBtu European production costs could be much higher between USD 8/MBtu and USD 12/MBtu.

Nijoka said, ''The price of natural gas was an important factor in the rapid increase in shale gas production in the US, but European prices are likely to be higher until an understanding of the geology improves and further advances in technology can help drive down costs.''

Predicted natural gas demand growth will also be critical for oil and gas companies when contemplating investment in shale gas projects in Europe, as it is not expected that shale gas production in Europe will reach commercial levels for at least another 10 years. The lack of oilfield service sector capacity, suitable equipment and a skilled labor force have been highlighted as potential bottlenecks preventing the faster development of shale gas in Europe. Shale gas will also need to compete with existing energy sources in Europe, where investments in infrastructure have already been made.

The rapid growth in shale gas production in the US has resulted in concerns about the impact of the development processes on public health and the environment. Opinion on the environmental impact of shale gas and its role in the future energy supply mix has become increasingly polarized.

The physical footprint associated with shale gas exploration and production is larger than that for the exploitation of conventional hydrocarbons. Access to land and land usage are likely to be important issues in densely populated Europe. In addition to the environmental issues, there is the issue of social acceptance of the shale gas industry in Europe. Compared with the US, Europe has a higher population density and more stringent environmental regulations. Issues like noise pollution, which has so far been less of a concern in the US than some of the other issues, might be more of a problem in densely populated regions of Europe.

Looking ahead, Nijoka said, ''Many hope that the experience in the US can be replicated in Europe, but this experience also needs to include learning the lessons from studies under way on the environmental and public health impacts of shale gas development in the US. In addition, these studies can help shape appropriate regulation where necessary in Europe.'

[Horst611]

Kurz vor Börsenschluß in Toronto hat einer wieder 80000 für 0,05 gekauft und damit ein Minus von 17 % erzeugt.

Also wieder nur ein Strohfeuer !

[texas2]

Was mir daran gefällt: SLE hat für die Lewino Bohrung noch einen dritten frac probiert, obwohl die ersten zwei nicht so gut ausgesehen haben. Gibt genug ölfirmen die vielleicht nach dem zweiten frac aufgegeben hätten. Aber lessons learned anwenden und weitermachen: das kann zum Erfog führen.
Dass Lewino die verpumpten Fluids wieder rausspukt ist ein gutes Zeichen. Noch besser wäre es einzuschätzen wenn SLE dazu die Mengen des geförderten Erdgases mitangeben würde.
Türkei: mit den 50.000 m³/d (?) verdient man noch nicht viel. 500.000 oder 5.000.000 m³/d wären da schon besser. Ölfördermengen habe ich überhaupt keine gesehen (oder überhört?) Auf jeden Fall werden auch bei der Ölförderung einige hundert Tonnen Öl /d notwendig sein, damit das Geld für die Finanzierung von Polen aus dem cash flow möglich wird - schätze ich
Bleibt auf jeden Fall spannend und SLE wird eine interssanter 8ter Bahnfahrt, die hoffentlich nicht in der Geisterbahn endet. Der abgestürzte Kurs macht jedenfalls im Augenblick für bereits investierte wenig Spass.

http://www.brrmedia.com/event/119363/partner/oilbarrel

December 17, 2013

Conference report 2: San Leon Energy Provides Polish Shale Insight While Wentworth Resources Highlights East Africa's Overlooked Onshore Potential
By Amy McLellan

AIM-quoted San Leon Energy has never shied away from striking corporate deals to grow its E&P portfolio. It started in 2009 with the acquisition of Gold Point Energy, the beginnings of its Polish adventure, and then continued in 2010 with the acquisition of cash-strapped Island Oil & Gas, in 2011 of Realm Energy while 2013 has seen two corporate deals, the merger with troubled Aurelian Oil & Gas at the start of the year and then September's acquisition of a 75 per cent stake in Turkey's Alpay Enerji.

The latter deal brings some production and near-term development opportunities onto the books so that San Leon can start to build self-sustaining revenues. It reckons it will be cash flow positive in Q2 2014 and those revenues, along with the £31 million raised in a recent placing, should help it fund its flagship projects in Morocco and Poland.

It was the latter country that was the focus of COO Joel Price's presentation, with particular attention to its shale ambitions ( it also has conventional oil and gas opportunities there). Poland has been at the vanguard of Europe's fledgling shale gas industry, with the Government and the population at large supportive of an industry that has the potential to lower high gas prices, drive economic growth and reduce its reliance on Russia.

As we have noted, San Leon was an early mover here, acquiring its licences at around US$5 per acre. Polish exploration shale gas acreage is typically trading at up to US$500 per acre: should the country start to see the same kinds of flow rates and recoveries as North America then valuations could balloon: US development shale gas acreage trades at around US$38,000 an acre.

As Price acknowledged, however, there are many sceptics who don't believe Europe will emulate the same shale gas boon as North America given the higher costs and different geologies.

“But people aren't comparing like with like,” said Price. “Polish gas prices are three times that in the US and the state take is less than half.” It hasn't helped sentiment, however, that a number of high profile players have, for whatever reason, exited the Polish shale sector, including ExxonMobil and San Leon's own former farm-in partner Talisman Energy.

To realise value from its early mover footprint in the Baltic Basin, San Leon needs proof of concept. A key well, Lewino-1G2, has been fracked in the Ordovician and is currently cleaning up. Price provided a high level of detail about this fracking process, which made clear just how sophisticated this process is and the amount of trial and error it takes to get the engineering right to allow the gas to flow from the tight rocks. The first frac on the well involved 10,800 barrels of water pumped in at a rate of 120 barrels per minute along with 42,000 pounds of sand proppant at a very low concentrations: this resulted in a sub-commercial flow of gas and the company and its service contractors went back to the drawing board.

The second frac involved 8,300 barrels and almost double the amount of proppant, this time using ceramic not sand, but still at very limited concentrations. A slick water and gel treatment (the latter being guar gum) were applied to combat pressure spikes but it was still unsuccessful in terms of flow rate. Third time lucky and the company used 10,300 barrels of slickwater and a high concentration of ceramic proppant to hold the fractures open.

“It's evidence that a single frac like that can cover the whole Ordovician interval,” said Price, which would be good news for future development planning and costs.

Well clean up is now underway, with nearly 20,000 barrels, or nearly 3000 tonnes of water, already recovered. “We've got 30 per cent back without even putting in any tubing,” said Price. “Gas also came back very early on and we're continuing to get gas back. When it's sufficiently dry then testing will last for a month.”

Based on what it's seen so far, the company plans a horizontal well with multiple fractures. “We are very encouraged,” said Price, who said if necessary San Leon will be the “last man standing in Poland.” “We see it as a potential company maker,” he said.

It was a technical presentation from someone who clearly knows his stuff. There remain some sceptics about Polish shale, including some shareholders in the audience who were vocal about the stock's performance, but Price did a good job of explaining the complexities and why it takes persistence to try the different iterations to get the fracking job. The coming months, as Lewino-1G2 is cleaned up and tested, will be carefully watched by many company followers and oilbarrel.com delegates will be keen for Price to return next year with an update on the well's performance

[Horst611]

In Kanada steigt der Kurs heute um über 40 %.

Allerdings keine großen Umsätze (ca. 70000 Stück).

[Kettenfett]

bin mit einer kleinen risikoposition dabei !