Member Info for GreyPanther

Hi Gwynwin. Are you posting about Biscathorpe or something to do with Wressle?
Unlike some here, most aren't mind readers

Sorry for the premature posting. I agree with Serif. Years ago I was shown some reservoir maps (based on 2D seismic data, I know) of the area around Corrib and Inishkea. IMO there was absolutely no way, from a technical POV that production from Corin could have drained the gas from Inishkea.

Hi Serif.

I agree with you Serif. Years ago I was shown some reservoir maps (based on 2D seismic data, I know) of the area around Corrib and Inishkea. IMO there was absulutely no way, from a tecnical PPV that the proction from Corin could have drained gas form

Thanks S740. I'm OK with either 30.5/64ths or 61/128ths, even if Mr Haydock wouldn't be), but I'm still wondering if this is the current choke size. A 30.5/64ths choke suggests to me that last summer the 1 inch choke was nearly half way open. But what we don't know is whether, and by how much, Egdon may have had to choke the well back to keep the gas below 10 tonnes per day. By now the choke could possibly be less than half way open, so maybe 1/3rd open is reasonable..

Hi Olivia. Gaffney Cline's estimate of 10.12 million barrels of oil in place and a recoverable resource of 2.43 MM bbl for the "Speculative Deeper Oil-Water Contact)" suggests a (possible) recovery factor of 24%. While this seems reasonable, or even fairly good ,for an Upper Carboniferous field like Wressle, I wonder if the sustained high productivity with no water etc, is indicating that the recovery factor could ultimately be a bit better than 24%. All the wells near Wressle are in more or less a straight line from Crosby Warren to Brigg, so it's possible that the Ashover Grit may thicken to the SW, away from the trend, and this could also increase the oil in place. What do you think?

Hi mymine. I think the well is being flowed at a particular choke size to keep the gas rate below 10 tonnes per day. But what's the source of your "manually chocked by 1/3"? Do we know the current choke size, or what the maximum choke size is to maintain a particular flow rate? I suspect we don't know as I've not seen it in an RNS - as far as I'm aware. I'd be keen to hear your views on this. Thanks. GP

Hi Stas20. You asked "1. Does anyone know if we are paid WTI price for oil or Brent? 2. Does anyone know Wressle's production profile, how many days per year are they producing?"
1. it's definitely a Brent price, though I think there's a small discount of maybe $1 to $2 per barrel compared with Brent. 2. I asked someone who is fairly knowledgeable. about these matters They felt that production "up-time" of about 90% to 95% might be expected but I haven't seen nothing in print to confirm whether it's the case at Wressle.

Have a look at:
https://www.egdon-resources.com/media/presentations
and open "2022 AGM Presentation"
You'll see this about Wressle "Daily rate of 1,029 bopd achieved during December 2022 following 4-day maintenance shut-down"

Perhaps UJO's management is more highly regarded than EOG's?

Hello Heid. Could you please explain what you mean by "Shell are already piggy backing West Newton"? IMO they went into Pensacola because they formed a view based their own technical assessment of it, and about other Zechstein wells nearby, rather than our so far rather inconclusive WN results.

Hi itsawrap. Europa may have particularly streesed Broughton North is because it lies between Wressle and their producing well at Crosby Warren,. Mind you, it does seem a bit odd that neither Egdon nor UJO have said anything about it because it's a prospect that EOG thinks is ready to be drilled in 2024. The Broughton-1 well was drilled by BP in 1984 and was abandoned with good oil shows. The Ashover Grit was only about 10 metres thick there, compared with about 13 metres thick at Wressle but it looks OK on the logs. Unfortunately not much has been published on the size of the prospect but the UKOG Library's published 2D seismic lines seem to suggest that it's not very big. it would be good to know if Egdonalso feel that it's worth a well, rather than possibly being over-hyped by EOG

Hi itsawrap. I don't think we should assume that the next WN well will be a side-track from a pre-existing well. It's more likely, IMO, to be a completely new well with a long horizontal section (and not a side-track), and that it will be drilled from either the A site or the B site. That's why the cost has been estimated at Cdn$19 million / £12 million gross.

Hi Serif. Thank you for that. It would obviously be much more convenient to drill another well from the Wressle wellsite since finding new sites is always problematic. But is there enough room for a further well at the current site, and would Egdon be allowed to drill there while producing oil at the current high rate? Also, I'm not entirely sure that the current site offers the best location to drill a P'stone well to its structural crest. According to the NSTA's data, the Wressle-1 well was highly deviated to get to the Ashover crest, although I suppose the P'stone and Ashover crests may not be in exactly the same area.

A very good RNS this morning, IMO, but only if it' proves to be true by the end of 2023 .I'm wondering if oddy will deliver the promised two Pen'stone wells and a Broughton well in the Wressle. area Or has he shot himself in the foot again? I sincerely hope not but with, as far as I can see, no planning application(s) submitted by Egdon to North Lincs Council, I worry that the liklihood of our drilling more than one Wressle well in 2023 looks remote, especially if one thinks about Egdon's and Europa's historic performance. IMHO it would be better to under- promise and over-deliver.

I believe they will be still be allowed to flare 10 tonnes and use (say) 1 tonne in the micro-turbine.

We've been told on good authority that Wressle produced at 715 bopd in October, thanks to the NSTA. So if two or three micro-generators use one tonne of gas per day, the field should be able to produce at 715 plus 10-11%, or about 787 - 794 bopd. And if the new generators are able to use 2 tonnes per day, then we might expect 715 plus 20-25%, or 858 - 894 bopd. However, I wouldn't expect this to be apparent until we see the NSTA's February figures in late April / early May.

Hi Olivia. You could well be right on the maths, but let's wait and see the actual February figures which will probably be available in late April / early May. However, just as an flying guess, that the February figure wil be between 900 and 1,000 bopd. Let's hope so. And a $150 oil price too!

Hi Pboo. "Please explain your maths". You may not agree with my arithmetic, but which part of the equation don't you agree with? We now know that Wressle produced at 715 bopd in October according to the NSTA. So if two micro-generators can use one tonne of gas per day, the field should be able to produce at 715 x 10/9, or 794 bopd. But if the new generators are able to use 2 tonnes per day, then we might expect 715 x 10/8, or 894 bopd. However, I wouldn't expect this to be apparent until we see the January or even the February NSTA figures.

IMO only two of the three generators which are on site, but probably not yet connected, will be in use at any time, with one being kept in reserve or as a spare in case of downtime on those that are being used. My other thought is that each geneator will use up to about a tonne of gas per day, and this will produce far more electricity than the site can use. So maybe we should stand by for fairy lights on the portacabins, or even - dare I day it - the electricity being used in some other way, or even wasted. The EA's flaring allowance is 10 tonnes per day, so on an arithmetic basis, oil production could be in creased by as much as 10/8 = 1.25 (+25%). Similarly, a i tonne /day gas usage could add 10/9 = 1.111 (+11.1%). This may seem counter-intuitive, but I think it's correct.

According to the NSTA's maps the licence on which the Ossian well was drilled was relinquished sometime ago, . This probably teel us all we need to know regarding its commerciality, since the test had a water cut of nearly 80%.