THIS is very nice to see

HAHA poor MMS can't even bring this back to .0001 and make me sell mine!!! GOOOD LUCK THERE MM's you will have to pry mine from my cold dead hands NOT EVEN A NO BID WILL WORK SO GOOD LUCK!!

HAHAHAH THATS THE BEST GOOD ONE HIGHWAY!!!

hahaha he's licking up the skid marks in his "shorts" hahahahahahahah GOOOOOO DEWM!!!!!!!!!!!!

read the latest filings in AEGY the answer is right there. A few of us across the boarder were lucky enough to pick some up before the CTO came into effect. Someone else mentioned having a retainer paid and going after Alberta securities commission but never heard anything since.

YOU LOSE

that's a big 10-4 on that......and YES there is a lot of fishy BS with this one

nuthin wrong with pump and dumps but i follow the rule of riding free shares in the .bong stocks cause someone is going to come out on top.....$$$$$$$$$$$$$$$$$ GOOOOO PRPM

LOLOL 18 wells/leases X 45 BPD = 810 BPD production..........(walking by while whistling with hands in pockets)

DEWM is gonna make us very happy. Great CEO. great product. great vision. AS for OSPREY......how does the skidmark in your "SHORTS" taste LOLOLOL HAHAHAAHAHAHAHAHAH

GOOOOOOOOOOOOOOOOOOO DEWM!!!!!!!!!!!!!!!!!!!

THIS HAS GOT TO BE TO MOST AWESOME THING I HAVE EVER SEEN AS A SHAREHOLDER!!!! CONGRATULATIONS TO ALL!!!!! GO AEGY!!!

Can't PM you but i'd be interested in helping financially if needed let me know

- 18 leases/wells X 45 BPD = 810 BPD into production by end of FEB/2014 first results end of MAR/2014.

omg are you serious???? you have got to be handicapped in the brain man GO AWAY ALREADY.

Congratulations to all the longs here its but a stepping stone in the bigger picture here. I am lucky to have got in before the cease trade put on us south of the border. 'tis ok all will work out for us lucky ones here.

GLTA

Good day to all the arguing BS of the board. MY TAKE - 18 leases/wells X 45 BPD = 810 BPD into production by end of FEB/2014 first results end of MAR/2014.

That is all.....carry on.

another note with all of the wells that peii owns it would probably be feasible to say that at least 2/3 wells would be needing to be worked over.

It would be a good field for rig and crew to get into because they would have steady and contiuous work and as i said before a typical pump change and tubing inspection/run on would take around a day to do. so no need for the well to be out of production for too long so long as their is a rig in the area full time.

not knowing the area i can't give real good guess on how many times these wells do need to be worked on the keep them up and running. Alot of different factors involved here. Typically if you have freshly frac'd well the chances of its pump sanding off during initial production is greater.

If smith goes about it the right way or at least what i call the right way he would start off slowly pressurizing the formations and slowly drawing on them with the pumps this gives our formation, (sandface) as some call it, the chance to solidify and become permeable to allow fluids to flow through it without breaking it down and carrying pieces of it with the fluid that tend to plug off (sand off) the pump, tubing and rods.

just my two cents

i think what Floyd means is the wells are not producing (shut in) due to circumstances such as a hole in the tubing, down hole pump is worn out etc. etc. So they need to be reworked.

At the same time i would assume he is going to fracture each well as he brings them online. at least if fracing or acid wash is working that is what i would do since im already pulling the production equipment out of the well to do necessary repairs.

i assume smith is starting with the workover and fracing of the simon lease wells and will move on there.

I see i was in a hurry and had some improper info here in bold

"ya seen the BPW thing so calculate 18 wells X 45bpw increase /by days of week and you get 115 bbl/day + nominal well production of say 10 bbl per day (it was double that on the first) without co2/fluid injection is another 160 BPW /7 days per week is 137 total bbl per week. and finally ad the fact that the pressure increase on the first well was below maximum and already picked up an increase of 45 bbl per week."

c02 increase of 45BPW X 18 wells = 810 BPW or 115 BPD
nominal well production 10 BPD X 18 wells = 180 BPW or 25 BPD
increase in pressure X 18 wells = unkown at this time

conservative estimate on 18 wells production is 140 BPD
40 BPD X 80$ per barrel (give or take its higher at he moment) is 336,000 give or take per month in potential revenue.

We have 104 wells total according to their assets list with 90 of those capable of being produced.

90-18 already calculated 72 wells potential of 55BPD per well (co2+nominal) is another 3960 BPD production resulting in another 9,504,000 in revenue per month for peii

I believe that 55BPD is a really low estimate. At the same time this is based on ALL wells can be put back online.

Providing no unexpected setbacks a frac and recompletion should take no more than 3 days lets say 4 days for the hell of it X 18 wells is 72 days.

As far as pricing it all depends on the things i said before. Does the well contain most of the equipment already or do we need to buy new? What are we paying the subsidiary Petron Well Servicing for the rigs per hour? according to Floyd we were getting a deal. Floyd mentioned the wells producing alot of gas do we have to use snubbers to run pipe in the hole? Its really hard to calculate a cost without this info.

125-150 sounds right for a new well. Its stated that some leases have 5-7 pay zones which is great if you can drill through more than one pay zone with each well which is done all the time. That being said are the existing wells on these lease already drilled through multiple strikes?

Patience is key in all investments and this one is no exception. Providing Peii owns what it says it owns as far as wells are concerned there is no reason that at some point we cannot become profitable.

umm if i had the coin, 2 service rigs and 4 crews for 24 hour shifts i could get 18 wells frac'd and producing in less than a month. just sayin. Didnt do any DD last night had a few issues to deal with late into the evening. Very busy for oil/gas out here. cmon PEII get your fkn s#$t together LOL

ya seen the BPW thing so calculate 18 wells X 45bpw increase /by days of week and you get 115 bbl/day + nominal well production of say 10 bbl per day (it was double that on the first) without co2/fluid injection is another 160 BPW /7 days per week is 137 total bbl per week. and finally ad the fact that the pressure increase on the first well was below maximum and already picked up an increase of 45 bbl per week.

All these numbers are there i am just taking from what i can remember give or take a barrel.

I will do more checking tonite when im havin a cold beer and see if i can figure out exactly how many individual wells there are. As well i will do some more accurate calculations based on what i can find.

Any help on this is greatly appreciated especially where number of individual producing wells in ALL areas that PEII owns or has interest in. GO PEII

all meaningless when we break 100bbl/day GLTA

GO PEII

Look all that gibberish means nothing. The following is all that is needed for DD either it works OR it doesn't

75bbl a day with the recent positive increase on one well.......100bbl to break even............17ish more wells? or is it 17 ish more leases which potentially have more than one well on it?? Either way once we break 100 BBL a day and sell some produced product we should see an increase in PPS.

GO PEII!!

UPDATE FOR CANADIAN CEASE TRADE ORDER AEGY

Thank you for contacting the Alberta Securities Commission (ASC).

You wrote:

You sent me some information in regards to the ASC cease trade order. I have some questions.

Does ASC not have a mouse and computer with keyboard to look at the current filings that are public information in the USA?

The simple fact of the matter is, they are required to report their financials not only to the American authorities, but to the Canadian authorities. Despite the fact they may have filed their continuous disclosure in the United States, they still are required to file their continuous disclosure in Canada.

Does ASC not recognize that AEGY is otc QB which means they are up to date with their filings to be listed QB.

There are clear requirements set out in Alberta legislation under Multilateral Instrument 51-105 ISSUERS QUOTED IN THE U.S. OVER-THE-COUNTER-MARKETS. The company by virtue of having Mr. Gelmon as Chairman and Director triggered reporting issuer status in Alberta and is responsible for filing information with the ASC. The company has chosen not to do so, and accordingly was cease traded.

Does ASC take information from a person/persons including the person by the name of ****** ***** to make decisions on whether or not to apply a cease trade order.

The companies listed on the OTCBB have attracted considerable attention from regulators all over North America. That is why virtually all provinces in Canada passed MI 51-105. I understand you may not agree with the actions the ASC has taken in this regard. Our cease trade is aimed at protecting the Alberta marketplace and its investors. To the extent you wish to trade your own securities in the company, you may wish to consult counsel with regard to have that might be facilitated. If you are an Albertan investor, then you can contact our offices to see an exemption from the order, which will be considered. If you are not resident in Alberta, then I suggest you contact counsel.
Please reply at your earliest convenience.

Kind regards





Don Rodgers
Information Officer
Alberta Securities Commission
Suite 600, 250-5th Street SW
Calgary, AB, T2P 0R4 Tel: 403.355.4476
Toll-Free: 877.355.4488
Fax: 403.355.4453
Email: don.rodgers@asc.ca
www.albertasecurities.com

I think you mean oil companies fracing their own wells? or is this info being out out there by fracing companies?

What happens when an oil company wants a well fractured is they call in the fracing company. They tie into the well and by way of calculation of bottom hole pressure they set up to exceed this pressure so they can push the fracing compound (usually frac sand) into the formation. Think of having layers of rock compressed together and then wedging these small balls of sand in between the rock to allow flow of fluids and gases out of the rock.

This is extremely high pressure in the 10's of thousands of pounds per square inch. The equipment used is highly specialized piping and pumps that can handle that amount of pressure while pumping the sand into the formation which leads to your next question.

Tweaking the pressure of the Co2 injection can really only go so far as the equipment has to be able to withstand the back pressure created by the formation. You also CANNOT exceed the formation pressure or you would be fracturing the formation with Co2 causing removal of your frac sand that is in place and/or just generally agitating the formation which is not what we want to accomplish.

Geologist with the proper info on the particular well/formation will be able to give a good number as to how much pressure would be required to succesfully move the fluids from the formation to the production equipment.

I get the idea Floyd is a bit old school. From that i think Floyd would adjust c02 pressure on the formation and take cuts (samples of produced fluid) and put them in old style centerfuge (we still do this here) spin the cut and record the amount of sand/fluid/water ratio in the cut. Then increase pressures until he sees the sand cut pick up percentage wise and back of a notch from there. We want fluid and not pieces of the formation or frac sand we sent down there. That is what i would do maybe im old school too. LOL

We only need 25 more barrels production to break even. We have ALOT of potential for more then that. GO PEII!!!!!

yes actually now that i look closer at the information it seems that alot of them are two different depths meaning they do kick off one depth is TVD true vertical depth the other is TD total depth which is the actual distance to the bottom/end of the well. (note production string does not necessarily go to the bottom of the case hole.)

Anyway these are relatively shallow wells in comparison to some gas wells we have recently done here @ 14000 feet.

My rambling point was only to give an idea of what is involved in working over and producing of these wells. Some of them do kick off so the wear potential on tubing and rods is greater. they vary in depths that would take a full day to pooh (pull out of hole) scope tubing (using scoping equipment) to inspect for holes or thin spots, change the pump etc. All in all a good days work for the service rig to get a downed producing well back online.

Floyd did say the subsidiary PEII well servicing would give them a better deal somewhere in his filings in regards to cost of utilizing their service rigs.

I still think that if 75bbl/day is being produced and 100bbl/day is break even and we still have 17ish wells to finish injections on then it should be easy to figure out based on the increased production from injection done on the first well.....

Nice these are shallow wells. Easily worked over at a rate of two per day providing the distances aren't to far for rig move and providing the rig crew isn't lazy LOL.

Shallow wells take less equipment obviously and to a certain extent do not wear out as quickly. Assuming these are total vertical and no directional or horizontal is another asset to the longevity of the equipment in a well. Couldn't find anything about H2s levels if its present in high concentrations the deterioration of the equipment is a little quicker. Im not sure how they class wells in the US but here a sour well above certain BHP(bottom hole pressure)/release rate can be classified as class 3. If this is the case then time to work them over will take longer as there are more precautionary steps required to work on them as well as a class 3 bop system is needed.

Anyway those are my thoughts. If were truly producing 75 bbl a day and break even is a hundred and we still have 17? wells left in the one area to put back online i can't see any reason why profitability by the second quarter, as stated by Mr. Smith, wouldn't be achievable.

GLTA

Ok we get it I-Glow. The beta section on the site showing the following...

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Means absolutely nothing......hey everyone sell your shares the world is ending I-GLOW SAID SO SELL SELL LMFAO

Ok lol now were arguing with grumpy over there about how much i may or may not know. It is ok.

You did mention again or said something about drilling. Guys you need to understand as far as i can see these wells are pre-existing wells. they are drilled already we don't need the drilling rig to put these back online.

A service rig is the rig that will put these back online. They are capable of drilling as well with a service rig. all you need is power swivel or mud motor and drill collars and associated materials etc. we do this alot on re-entries as most times there will be a plug/packer and variably up to 100 meters or more of cement on top to drill through.

Swim you mentioned not having enough collateral for a 10 million loan. Well if i had well files i could verify this quite easily. But i'll take a shot. If each of the 18 leases contains at least one oil tank one pump jack one complete well with pipe and rods and insert pump/or rotary pump in the case of a screw pump you would be surprised at the replacement cost * 18 wells plus the pipeline they mentioned they had. Also they said they own service rigs at 3000000$ cost per service rig package brand new thats a chunk of assets as well.

Seen someone ask about how these wells run. most pump jacks are run from a single piston engine that can run on propane OR well bore gas from a producing well. Free fuel...pretty neat. They can also be run off an electric motor.

I like peii because a small investment can payout some fairly large returns. And if there are 18 wells that can go online and they can successfully recharge the formations during their secondary recovery operations i do not see why we wouldnt at least have a little bit of an upswing in the PPS sometime.

Anyway i wont say "have a good day" in case thats what someone else says LOL

YOu sure are a miserable peice of work hey. Bet ya all my shares if i had the well files/current well data i could figure cost of production to within ten percentof actual buddy.

Have a good day. GO PEII

haha I-blow takes a month and ALL that typing to spread his "word" and you crush his BS in 10 words. LMAO GO AEGY TO DOLLAR LAND AND BEYOND!!!

Well as far as 50$/barrel of oil we have to look at it this way. I would call that the initial cost. I have worked on wells that have pumped for years i mean 15 years without ever having to be touched. So if that well produced that oil for that long without any input cost then the cost per barrel ratio will be reduced dramatically. That is an extreme example of 15 years and not often that happens in my opinion. 1-5 years though is very common.

There are a ton of variables in cost to frac/workover. Im not sure if these wells flow on their own which is not likely but maybe with increased pressure they will thus not needing to run the pump jacks to produce them (or screw pumps if those are used there as well)

Other considerations in costs is there equipment in the hole or surface equipment. Are some or all or any of these wells suspended.

If there is equipment (pipe/rods) in the hole are they in good condition to use or are we spending to replace this equipment. Im not sure what depth these zones are at i probable could find out if we know what zones they are producing or at least get an idea. If you have to replace a string of pipe 60.3 mm 73mm and 88.9 mm can run from 150-300 per joint. A 1000 meter well roughly 115 joints of tubing say 60.3 mm is 17000$. These are rough numbers its been a few years since i've been in the loop of purchasing replacement equipment but this is just general idea and more to give those not in the know some insight as to what it takes to get a well put back online. So enough rambling on there. LOL

I dont recall reading anything or hearing Floyd say anything about drilling. I am pretty sure PEII owns its own service rig company though and there must be some benefits to owning them cost wise. Mobile double service rigs here are in the 550-750$/hour cost.

As far as drilling im sure it would be most feasible to hire a reputable drilling company to drill new wells. Western Energy is a large one and works in the states as well. HAHA they just bought the company i work for so i guess i had to throw that in there.

Wow almost a novel there. Go PEII

im not sure how this came about no one was arguing whether canadian laws applied to american laws or vice/versa.

i will post any updates i have in regards to the CTO in canada against aegy. I am persuing it further.

as i stated before we can BS the night away sometime over a few beers. not here to argue just want the opportunity available to us and not have it ripped away by some greedy little bitch who thinks she can get away with it.

GO AEGY

i heard something about some being in canada but that makes no sense whatsoever it clearly states in the email that i posted that they are protecting the "integrity" of our markets

Already started with the ASC as in Mark Dickey and have his superiors contact info in hand. THIS WILL ESCALATE.

Thanks all for the advice looking into the media angle as well.

GO AEGY!!!

exactly what i have been working on already since this shit started. THANK YOU for the encouragement. GO AEGY!!!!!!

i have bunch of shares and just speculating. I have been in the oil industry since 1999 in Alberta Canada. Started on the ground floor working on the service rig side of it and all the way up from there still in the service rig part of it today.

I know the costs for fracing/working over a well can be VERY expensive. Things do go wrong ie: when equipment failure allowed pipe to drop down the hole during operations.

Shit does happen and unforseen events do occur. Especially on already produced wells. Sometimes well files are innacurate and you can RIH (run in hole) with frac equipment and run into artificial TD meaning there is something there that is not recorded on the the files. THIS DOES HAPPEN. Shit dropped down hole, cemented wrong area or too much volume, Suspensions the list goes on and on.

I side with Floyd yes he is trying to paint a good picture so that we dont all pull out and he has nothing to work with thats why these shares are available on the open market so we can provide PEII with funds to make this work.

Anyway thats my two cents i dont give shit what the bashers say and i dont give shit what the pumpers say. The only thing we ALL can do is give it time and for god sakes if your buying now dont invest your families grocery money you probably wont be rich monday morning.

If you have PATIENCE and a small amount of disposable income this could give a very good ROI

PS. IDIOTS need not reply to this post as i do not care what you have to say. GO PEII!!!!

and i have names.....GO AEGY

i absolutely agree. I have other info but names involved i cannot post for fear of being banned or "put in jail" GO AEGY