.

lol..... steak au poivre will do.,.

Pro You seem to have plenty of time making a new Argos thread and posting on there all the time can I ask whats a matter with the thread I started?

I would call that bloody rude and lack of respect.

LoL - Don't be fooled, Pro and his many aliases start threads to create interest in his stocks, even to the extent of talking to 'himself' when it's quiet. Without these BBs his ramping days would be over.

I find it curious he keeps on banging on about his IP address which only proves to serve he's considered this aspect of multiple IDs.

As for XEL, without an updated CPR there doesn't seem to be much news in the pipeline (scuse the pun) to invigorate the SP for a while. I would imagine the rig signing is already in the SP, although official news may cause a spike. Future financing still to announce, which surely must involve an issue and therefore dilution, it will be interesting to see what price they get any fund raising away at. Certainly still a strong long term hold, but having closed my SB, I'll sit on the sidelines for a while and see if I can get back in at a lower price; if not, there's always other stocks.

and there's no logical reason why you should not buy higher than the price at which you sold if the stock and impetus looks right

Indeed Ricardo, the middle bit of a trend is the best bit. Picking tops and bottoms can be very dangerous.

No apologies for going over old ground as I will just put words down as delivered and recorded to best of my typing abilities. I appreciate it is a little disjointed, but that is the nature of real time transcript recording from someone that kept falling behind! Comments in<> mine . The rest as near as possible to actual words spoken:

I am confident that Share price will double or treble in next 18 months, but cant promise 700 and 800 percent rises last two years have seen respectively.

Extension of block that retain with more prospects in it . Oil in place billion barrel in place to be defined . More than know, but not sure how much, recoverable work in progress, some months because outside of range predicted.

Drill showed high porosity,high permeability and high productivity index. In a word exceeded all previous expectations.

Took 1200-2400 barrells expectations initially so maximum 2900 very pleasing. Shows mobility and reservoir qualities around or partially above our high end expectations.

500 metre well with no significant issues, stabilised flow rates which was one thing that people said could not be done, but did do, by paying attention to how facilites operated despite hose break and having to resort to 200 tote tanks one at a time over 2 day period .

Still a lot of work to be done to deliver new numbers of recoverable barrels not least because so much better than initially expected and more to map! Target date late feb early march, thats when we expect to see more information coming . Not waiting though for this information though and priority to move to first stage production as soon as possible with fourth quarter still on target . Building same faciities does not change. Definitive number does not interfere with progress.

Process into bankable reserves gradual processs. When define and go forward reserves defined to that project then up to next level . 2 or 3 step process of building C1, C2 C3 into P1, P2 and P3 as add extra things extra reseource to end up with final reserves.

In other words the story will get stronger and stronger and the BOD will continue to add value bit by bit ,but ensuring they err on conservative scenario each time continuing to overdeliver.

Chance of Success now officially increased from 70 to over 90%. 90% barrier means happening and reserves will be proven. 750 million resource (not recoverable) expectation oil in place will be revised . Previous recoverable estimate of 120 million to low, 250 high for now, but expect 200 million barrels recoverable. Better recovery could increase this by 50 to 100 per cent .

Chairman has said all along that he expect half a billion barrels will be recovered when finished. Real confidence in this, but stage by stage process.

Valuation, encouraged by support with investors. 900 million dollars at the moment equivalent around $4.60 per barrel based on 200 million barrels.

Risks gone now, dont sell up, potential to come up to range of $10 dollare or closer to $15 as C turns to P1,2 and 3.

Still comfortable scope to to double or treble as safe bet. Aim to give investors as much as that value as can achieved. Not instant, but not that long term in next 12-18 months as production kicks in and further fields are established.

Pilot well confirmed on eastern flank much higher than thought. Refractory in boulder challenging to determine. Gave us a path to follow to put horizontal well. 400-550 metres . Flowed 36 hours limited by equipment and time. The well flow behaved immaculately far better than they thought it would. Previous tests if not operate in right way cant see wood from trees . 1,200 minimum then stepped right up when hit 2900 hit - limits that we can do . When achieved this view taken was lets go home,well over highest expectations ...job done! . Using productivity index, half draw down easily 3,000-3,500 a day easily if use bigger facilities even at those rates acceptable draw done pressures.

Total belief that can move contignency resources will translate into reserves . Moving on with contractors and vendors make sure achieve before end of year. Rig in final stage of negotiating rates ...will be with us October.

Preliminary review of structure . Extra reserves have not discovered everything yet, much more there. Hugh improvement, helped us get high quality log a lot of confidence going forward . Sceptics say it cant be that good, but difficult to show that it is not! High quality logs, ideal high porosity for putting horizontal well in. Lower down porosity lower. This is actually a good thing as they want low porosity layers to slow water down, because this will give higher recoverability.

Spreads right across reservoir. 73 feet of pay ended up being 113 feet nearly 50 per cent extra . Flat or domed not sure.... everything higher than original interpretations . Tracked rservoir down whole length of well . Very positive . No sign of roof coming down .

Beautiful sands if it was light oil, it would be called a bonanza. Now outside of original envelope. More work to convert into confident numbers. Need to produce a new in place number, full scale structure model. Interim reserves, multi stage process . Info in to get first level of reserves . Conservative initially definitely not less than that will fit with first stage prodcution. Very close to finishing negotating with rig. 15th not hard and fastg date . Will finish when finished wait and see .

First oil October/ November . Medium term whole process resources into reserves but have to remodel whole reservoir in parallel with everything else.

Field plant plan to government with full life cycle plans Will go in second quarter ready effectively for approval start of production last quarter . Will continue to add value. Delivering first oil first target just before Christmas will be determined on scale of things. Before end of year.

This opportunity is not finished, more to come now derisked for full value that we know we have. Successful flow tests gives no risk 200 million. Proved commerciality without doubt, proving reserves. Aim will be realised as number 2 independent in North Sea, still doubling or tripling sp just in this field alone and well not going to stop here. Well leverage knowledge of using other opps to bear further fruits .

Question How does Bently alliance work?

Alliance is a framework upon which contractors can apply their net experience, degree of risks they feel they can take and as we ascertain next stage they will elect what stage of risk to next stage .
Encouraged by contractor community want to take some risk on this project . In reality risk normal, just that Xcite is a new kid on the block. Alliance partners are not equity partners. They are within costing regions increasing their ability to get more margin as project develops. Very controlled process. Opt in process.

What about the South east Jurassic?

South east Jurassic 15 feet of something oil shows there, evaluating currently not enough to commit well to that area . Working example, currently have zero value on then and will until prove them, when wells down will continue. 2 wells in new blocks. Not flowable yet. Were not expecting it to.

Why did directors sell so many shares that will be worth 2 to 3 times?

Charles handed over to Rupert Cole on this. He explained that after 7 hard years sacrifice with loans, mortgages, pressures on family on line they felt entitled to take some out .

Will CPR increase data on east?

New blocks work first? High probability some, Jurassic higher risk. Live system know they are there. Main effort main field into production. During implenmentation stage of using FSP will be dipping into 12-24 month period.

Private questions asked after event by another investor.....Will there be a big placement/ dilution shortly?

30 million shortfall after drawdown for rig contract etc, but may finance this through debt or if they raise the money by a small placement of no more than 5-7 per cent < this is fantastic news and makes sense>

Rig signing delayed.

but with no added penalty ..... very strange, but i suppose linked to the delay in the CPR

or it could be weather related.....the longer they can delay the better the weather ..hopefully.,.

The board yesterday said it was in hand and no problems

MMs enjoying themselves again - 355/360

Only a matter of time before this breaks the 400p mark......wonderful for short and long term trading.....

have a feeling i might buy somemore today if it drops a bit more.,.

sp all over the place yet again, and being MM only, effectively impossible to leave an order in the market

http://www.oilbarrel

http://www.oilbarrel.com/nc/news/display_news/article/conference-report-2-surging-share-prices-ensure-plenty-of-support-for-gulf-keystone-petroleum-and/771.html

Oil barrel write up

Gramacho a well respected poster on the iii board (talk about a very detailed analysis!):

I dare say following Oilbarrel you are all suffering a bit of post meeting minutes fatigue by now. This post attempts to provide insights from what was said in relation to guideline reserves and potential value. It contains quite a bit of info and analysis so you might want to read it a couple of times. The following is IMO and of course is based on publically available information.

BENTLEY VALUE BASED ON M&A ACTIVITY
Although C L-C did say there is room to double or triple the share price just in Bentley alone, i.e. excluding the exploration upside, he did not directly say this would be in the next 12 months. He made a joke about a 2 3 fold increase being adequate after 800% and 700% increases in 2009 and 2010. He also talked about moving down the line in the next 12-18 months.

I have no doubt there will be a significant increase in sp in 2011 as contingent resources in the core area of the field are moved into the 2P category. The example in Slide 5 of the presentation shows XEL valued at $4.65/bbl based on a sp of 3.80 and the guideline estimate of 200 mmbbl contingent resources. C L-C used Sinochems purchase of a 40% stake in Statoils Peregrino heavy oil field (13 API) in 2010 as an example of what Bentleys reserves could be valued at. The deal was estimated by analysts to be worth over $15/bbl to Statoil.

Whenever anyone mentions valuing reserves at $ X/bbl and then goes on to use this figure to value an asset or company it is important to realise that there is a huge simplification in doing so. Clearly 200 mm bbl reserves that have a full production facility in place are worth more than 200 mm bbl reserves that require $2 Bn to be spent on facilities before the reserves can be accessed. (This is where a DCF analysis with good quality cost input provides more insight into forward value.)

So whats the story with Peregrino? The field will be developed with wellhead platforms and an FPSO to process and store the crude. A key point here is that the 1 Bn Euro FPSO is being leased by Statoil (from Maersk). This makes a $/bbl bid figure less dependent on the timing of the bid within the construction phase than if the FPSO was being purchased and being paid for. Sinochem will pay for their WI share of the FPSO contract costs via lease payments commencing on production start up (there will be a mob fee too). In other words, from Sinochems perspective, a large component of the total development costs, the FPSO, is yet to be spent even though the deal was done in the year prior to startup. Nevertheless Peregrino was still worth more than $15/bbl to it.

So would the Bentley field also be worth $15/bbl to Sinochem or another NOC and when would that be the case? There are a number of aspects to consider.

Firstly is the size of Bentley reserves of similar strategic significance to Sinochem and other NOCs as Peregrino? If Bentley P50 is in the range 200 225 mm bbl then its reserves would be about half those currently attributed to Peregrino. Its relative importance would then depend on whether the deal with Statoil contained rights to purchase Statoils 60% production stream from Peregrino. Statoil has large downstream interests and has announced refining projects in Brazil and is a leader in upgrading heavy oil. Hence it is likely Statoil believes it can add value to its Peregrino crude and it would be reasonable to assume it has elected to retain control of its share, particularly as there was no mention of Sinochem rights to purchase Statoil liftings in the coverage of the deal. Without this Sinochem would have rights to 120 240 mm bbl crude (field total reserves range is 300 600 mm bbl).

XEL on the other hand has no downstream interests. Rights to all the 200+ bbl of Bentley crude would put Bentley on par with Peregrino. However there is an agreement with BP that it markets the crude. The agreement incentivises BP to minimise the discount to Brent so whether this agreement would prevent an NOC structuring a deal to secure XELs share of production is uncertain.

Hence Bentley has the potential to rank alongside Peregrino from an NOCs security of supply perspective but existing commercial arrangements may or may not restrict its potential to do so.

BTW the above discussion is based on the assumption that the Peregrino figures refer to P50 (2P) reserve estimates. In my experience when a fields reserves numbers are discussed and when analysts estimate production profiles to value a field they are based on the proven + probable reserves. XEL has also made this assumption as shown in slide 5 of the Oilbarrel presentation.

Secondly does a comparison of the fiscal regimes between Brazil and the UK support the view that a strategic UK asset in the development phase could also command $15/bbl? The answer is yes.

The three main elements of the Brazil fiscal regime are Royalty (10%), Special Participation Tax and CT (34%). SPT is a tiered tax with multiple rates at various production levels and varies by year until year 4+. Peregrino will plateau at about 100 k bbl/d. It turns out that the marginal rate of tax at this rate and down to 83 k bbl/d is 50-55%. In addition there are other indirect taxes that can increase the state take.

In contrast in the UK there is no Royalty and CT is 30%. Although there is a 20% Supplementary CT charge, a large element of SCT relief was granted to promote the development of heavy oil fields. My calcs suggest Bentley would pay very little SCT during the first 6 years of full field production by which time almost 60% of the reserves would have been produced taking into account the FPS production. Hence a marginal rate of tax of only 30% is applied to over half of the reserves.

The third aspect is whether development costs would prohibit Sinochem et al from offering $15/bbl for Bentley. A comparison of development costs between Bentley and Peregrino is tricky without access to proprietary cost information and it is easier to assess this by reference to a project economic model. As inferred earlier in this post a DCF model has been set up for a nominal 200 mmbbl case. Cost and profile input is quick look with a view to not being overly optimistic. (It could be more sophisticated but that can wait until an updated CPR is released. In the meantime it draws on the 2009 CPR info and experience.)

NOCs have the financial latitude to base acquisitions on a lower discount rate than the 10% commonly used by oil majors and independents. Goldman Sachs noted that the Peregrino deal was one of the most aggressive to date and estimated it was based on a discount rate of about 6% whereas many NOC deals are done at a 7 or 8% discount rate.

The model is summarised below, figures in brackets are the 2009 CPR 166 mm bbl case.
Reserves: 200 mmbbl (166)
Peak Rate: 60 k bbl/d (64)
Full Cycle Capex: $3.0 Bn ($2.7 Bn note not clear if 2009 CPR includes FPS costs)
Main Production Phase Capex: $2.7 Bn excluding P&A costs
Opex: $3.0 Bn ($2.2 Bn)
Field Life: 19 yrs (15 yrs)

And economics are as follows:
Brent Oil price: $80/bbl flat real ($80/bbl flat real)
Bentley discount 12%
NPV10 1/1/12 $2283MM ... This will be a $2Bn company ($1535MM)
NPV10 1/1/12 $11.5/bbl ($9.3/bbl)

I believe the CPR pre-dates the introduction of the heavy oil supplementary tax allowance in June 09 so this explains the higher NPV10 in $/bbl terms for my model. Also it is not clear if the CPR is full cycle or main development only.

The Bentley NPV6 is $3410MM or $17.8/bbl which is slightly higher than the $15.4/bbl ascribed to the Sinochem Peregrino purchase (slide 5 Oilbarrel presentation) and sugges Bentley could indeed support a bid based on $15/bbl. (DCF calculations assume NOC does not need to pay finance interest costs.) Note the above NPV10 is equivalent to a sp of 930p and the NPV6 is equivalent to a sp of 1390p.

This is all well and good but it assumes XEL receives a competitive bid from an NOC for the entire 100% W.I. The NOC would then have to commit to become the field operator, with the organisational impact that would have, rather than be a non operating partner. This might be a barrier.

What if such a bid is not forthcoming? XEL would then need to consider how to get the development funded. E-type01 has raised the question of financing. He is obsessed with finance. Do you think this is because the HP company repossessed his Ford Granada lol!

BENTLEY VALUE UNDER RETENTION OPTIONS
There are several options to obtain funding in the industry e.g.
1) Issuing Equity
2) Reserves Based Lending
3) Project Finance, bank loans to be repaid from future project production
4) Farming down working interest in return for funding

1) Issuing Equity
Option 1 does not look attractive because it would involve a mega placement and massive dilution. At a current sp of about 360p XEL is valued at about $960 MM which is almost half the $2300 MM value associated with the 200 mm bbl sale of field case. This case requires about $2700 MM funding for the main development. Even without taking into account the discount that would be required for a placing, over 450 MM shares would need to be issued to raise this amount. The success case NPV 10 would equate to only about 245p/sh with over 600 MM shares in circulation.

2) Reserves Based Lending
In examining the other options it is important to realise that, despite its market cap, XEL is a minnow at the extreme end of the spectrum. Reserve based lending is based on production from existing wells providing the assurance to lenders that the loan can be serviced. XEL has no other assets in production to use as collateral so Option 2 does not look feasible.

3) Project Finance via Bank Loans
There will be a few wells in production following the FSP. These could amount to about 20 mm bbl proved developed reserves and hopefully 100++ mm bbl proved undeveloped reserves. Slide 4 Oilbarrel presentation indicates XEL believe the low case (roughly equivalent to proved reserves) will be 120+ mmbbl in the pre-FSP reserves assessment. Following the FSP there will be additional reserves proven by a well in Bentley East (aka Prospect A in the 2009 CPR).

Banks try to take as little risk as possible and much prefer to lend on the basis of proved reserves (1P) rather than proved and probable reserves (2P). After all there is an equal probability that ultimate reserves will be lower or higher than a 2P estimate whereas there is a 90% probability that ultimate reserves will be equal to or higher than the proved reserves estimate. The feasibility of Option 3 is therefore very dependent on the economics of the 1P reserves case.

This was examined by building a case in which the facilities are built for 200 mm bbl recovery but the reservoir only produces 130 mm bbl. Development capex for the main development is about $2450 MM (some wells omitted being uneconomic in this downside scenario). This case yielded an NPV10 of about $1000 MM i.e. it remains economic. Moreover it generates $3430 MM cash flow, i.e. 1.4x the capital requirement. Surplus cash would pay off a staged loan equal to the capex in 9 yrs at an 8% interest rate, cumulative production being about 100 MM bbl at this point.

From the above, project finance may well be feasible. TBH I do not know what level of coverage banks feel they need to be comfortable with offering project finance. They would obviously want to look at other scenarios such as low oil price, capex over run etc. XEL are obviously well aware of this and no doubt the FSP has been planned to provide sufficient confidence to facilitate project financing of the subsequent main development. Nevertheless one should realise the scale of the financing required is very large, a world scale investment is needed. The more conservative lenders will consider the risks to be quite high, because XEL has no other assets, and the risks would probably need to be spread over multiple lenders.

This route to field development produces an NPV10 of $1880 MM which equates to an sp of 770p.

4) Farming Out W.I. in Return for Funding
Finally there is Option 4. It is interesting to look at how a similar style of deal to that of Peregrino might look from the perspective of both XEL holders and an NOC.

If an NOC were to pay XELs dev costs for the main phase of development in return for a 50% equity stake this would amount to a cash injection of about $1.35 Bn for 100 MM bbl reserves i.e. the price paid would be $13.5/bbl. TBH I am not sure how to model the tax implications of this but the XEL valuation is currently modelled by assuming zero capex expenditure for the main phase. This generates an NPV10 of about $1800 MM with an equivalent sp of 740p. The deal could be sweetened to pay for FSP back costs to simulate a deal nearer to $15/bbl. As modelled this transaction is not as tax effective as it could be because there is no development capex to reduce taxable income and hence reduce the supplementary charge. If a more tax efficient deal were structured the sp equivalent would be north of 740p.

From an NOC perspective this deal appears attractive. It generates an NPV10 of $350 MM and an NPV6 of $820 MM. This is partly because the NOC is credited with the tax relief afforded by 100% of the field capex set against revenue from 50% of the field production. As mentioned above transferring some of this tax efficiency to XEL would improve the value from an XEL shareholder perspective whilst still retaining sufficient value from an NOC perspective.

CONCLUSIONS
1) Bentley Field economics, based on a development of the guideline 200 MM bbl 2P reserves outcome, are sufficiently attractive to support a valuation of greater than $15/bbl for takeover purposes. However this is a limited scenario that would require an NOC to bid with the intention of acquiring 100% W.I. and operating the field. In this outcome, if the bid was based on a 6% discount rate, XEL would be worth about 1390p/share (about 10% less on a FD basis) or 1215p if a bid was based on $15/bbl.

Since this outcome appears to be significantly more advantageous to XEL shareholders than other options involving retention of the field such a bid is likely only to come if a competitive bidding environment can be established.

2) If an attractive bid for the entire field did not transpire then XEL could develop the field and repay a financing loan with an assumed 8% interest rate even under the downside scenario investigated (Brent $80 flat real, Bentley 12% discount, facilities built for 2P reserves of 200 MMbbl but downside reservoir performance produces 1P reserves of 130 MMbbl)

The 2P reserves would generate an NPV10 equivalent to an sp of 770p.

3) The field could also be developed if XEL was able to obtain a carry of its development costs in return for farming down to a 50% W.I. This was modelled in a manner that was somewhat inefficient for tax purposes but nevertheless generated an NPV equivalent to an sp of 740p. The NOC pays $13.5/bbl for its 50% stake.

4) This analysis suggests XEL has multiple options going forward to secure more value for shareholders. The options investigated suggest the share price could double in the next 18 months.

5) Substantial upside exists from Bentley EOR, additional exploration prospects in Dornoch sands and Jurassic sands and possibly further structural upside outside the Bentley core area.

6) All of the above would explain the very high degree of confidence exhibited by the BOD members at Oilbarrel.

Having completed this analysis I am very pleased to retain my investment in XEL. IMO the outlook is excellent with the opportunity of a really good return at a lower risk than many other AIM oil companies.

I would caution that this is all IMO so DYOR. If there are any accountants on the BB it would be useful to hear your thoughts about the tax implications of a Peregrino type deal in which XEL is carried or paid their development costs in return for a stake in Bentley.

http://www.pressandjournal.co.uk/Article.aspx/2096176?UserKey=


Two decades after he first spotted the potential of a massive North Sea field, Stephen Kew has fulfilled his dream of bringing its oil to the surface. The exploration and development director of Xcite Energy tells Graeme Smith of the long journey to success
Oilman realises a Bentley dream

Read more: http://www.pressandjournal.co.uk/Article.aspx/2096176?UserKey=#ixzz1BZPePZcQ

It's worth a lot more than today's present valuation, that's for sure....but just won't go up at the moment....most people will have taken most profits including myself....but still in with some....

RF am just sitting and waiting for CPR,thought it best to sit this one out and leave all my money there as its pretty safe,news of rig soon should be intresting which one they go for.


http://brokermandaniel.com/

January 20, 2011 The XCITE JACKPOT! 500p/600p!!

Just a quick note here for the Xcite Brigade!

Theres NO point in the Blog constantly writing posts re XEL.

I can understand investors who are feeling as though they are in a News-Limbo. What I would say to the Blogosphere is this:

Why are investors fretting over a stock that has just completed a massive oil discovery? It has now flowed at commercial rates and is being FAST-TRACKED for production?

The recent extension of the Letter of intent to the 31/Jan/011 for the Rowan Norway N-Class Jack-up Rig seems to be causing some confusion. Its just idle minds working over-time, does any one out there really believe that a rig will NOT be signed on? Come come shake your heads! Get some back-bone and get back in-touch with REALITY!

Xcite energy will probably hit 500/600p before any production begins and you can take it as nailed on that the CPR will improve upon previous figures. The Bentley field will be reclassified Proven Reserves and very likely the 2009 CPR will be substantially improved upon, so goes the feeling within the City of London; reservoir properties to be above the upper end of modelled expectations.

They have settled roundabout 350p all AIM stock drift on lack of news that is a fact! There is more to come here this company have hit the JACKPOT! And so have its investors! News will come and the feeling from seasoned oil sector watchers is that the XEL story will only get better. There are still gains to be had here for holders.( Compare Nautical they settled at about 330p they are now 460/470p) You cant put a spin on good news and the news here is very good!

Hold for 500p/600p it will be hit!

Viva!

Daniel

Firming up on level 2....one of the few up today looks like it will go higher!!