Member Info for AlexHodler

I will obviously hold my position, but surely I was not impressed on George interview, we are spending 10 mil dollars in a Plant and we do not have an estimation of resources suitable for the plant purchased(analizyng now the chamical composition to assess the volumes suitable for the plant)......part of the equipment is one month Late, and he mentioned that there is no need to inform about a delay "at this stage" and he is focusing on getting things done on time getting people to work during holidays.... so basically we are stretched and any additional delay will result in ....to you the conclusion.......i might have misunderstood something but I found the speach generally uninformative. I m still positive on Prem..Obviously

Thank you for sharing Brian, The main value of having gas into formation is the fact that gas is carrying the Oil to surface while expanding, there is an Ideal GOR (gas oil ratio) that should be maintained with Time, more gas you keep down and faster oil recovery you will have over time, leading to better economic returns. Now how do you keep the gas down? You cant really change this dynamic but once the gas is on surface you can reinject the Gas down to formation with permanent compressors and a re injection well, this is normally done after the field is in production with a few production wells and reserves are appraised accurately , the gas also needs to be analyzed to assess the best compressor design. it would be interesting to know the Actual GOR numbers between 350 to 500(m3/m3) are good numbers for oil production .

The only thing I can tell you for sure is that separating formation water from frac fluid at wellsite it is not possible, they will keep monitoring the presence of chlorides in the water base fluids recovered usually tests are done on site every hour during well test,- Looking forward as the project has had quite a bit of the risks taken off the board, i wonder wich steps are taken to organize and connect the field to the flowline, this needs to be done in conjunction with a flow line test/maintenance . and it is something that takes a great effort/time to be reached this in terms of design /risk analisys/organization of simops /resources(material and economical).

Hi from the flare picture, I can see at the end a plume of black smoke this is an indication that there is Oil going into flare(at least one part of the produced) another indication is that they are not pumping enough Air to support proper combustion, also I noticed a small Oil tank capacity the 4 tanks they have are 50M3 cap each if they plan to produce 1200 bbls per day they will be full within 24H . then need to wait a few days for oil and water disposal, if this is the case the well test process will take some time........ I suppose the Oil is not sour as the Oil tanks vent system appears not to have gas scrubbers and they mentioned that they will use gas for generation........the overall picture seems ok we just need to be patient so they can get the numbers.

Will do.

The equipment is on site they already fow the well back if I understand well, there is an initial clean up stage that aims in recovering Water based fluids usually below 1% , water base fluids alterate the flowback models and tend to create emulsion in some cases, on my opinion we should get some figures within days. from what I figured out at the moment the fracs where done through Coiled tubing using a straddle packer, as the volumes they pumped are relatively small.(this is an opinion based on what i know so far)

WELL....I just moved in with a investment i m one of you now......hope for the best

Thanks Buzz-

If they perforated they used a conventional fracking tecnique with rig setting RBP(retrievable bridge plugs) to isolate the single zones in order to frac coruous to know if they performed Fracking with Proppant or without.

It is the most efficient system in the market, it saves rig time therefore money, as I mentioned it depends on original planning. it is something you can t suddenly do.It needs to be in the plans.

Brombarb thank you for the highlights, That is the Schlumberger system , usually the choice is done before the drilling starts, each comany has a well construction manager that is taking care of identifiyng and drawing a well construction program, including materials requirements (including wellhead) a thorely Capex budget etc etc......

Hi Marmaris hope you are well, the number of sleeves is decided from the geology petroleum engineering based on interest on object, I personally ran Fracs in 90 deg horizontal holes 5900 meters deep with 9 sleeves after you drop the balls and complete the frac operation the baffles in the completion are milled with a choice of CT or Electric line with dowhole tractors this will equalize the borehole diameters, the balls are made of composite material and flown back with
well test, they are now developing biodegradable balls. off course all the above depends on Company Budget and technology level.

Thanks Tech.... Usually these include a cased hole with Swellpackers technolgy and a series of shifting sleeves placed to frac with ball dropping , mostly nowadays the test is reduced to minimum for environmental reasons, the swell packers will allow them to isolate the lower zones in case of high water content, off course this will work if there are no fractures (vertical)between swell packers...... the deeper stimulation is often done with mininimal fluids and displaced with hydrocarbons...

Does anyone know if the test will be done commingled? or they plan a test for each oil bearing zone.
Thanks

Hammered I m a convinced investor of Prem .... i have in Prem my largest holding within LSE after I sold yesterday shares of greenx ..... I think Prem is in an outstanding position to take advantage of the Lithium trend, and as I see the management seems capable of handling, sorry if I seemed negative, I like generally to share my thoughts, we are all learning.

Caledonia mining build a solar plant to support the operations, and funded that with shares....... I think this is one of the first steps Prem should take, Water scarcity is another problem in Zimbawe it is a seasonal problem it will need to be tackled South africa stopped sending electricity because there is no water in the Dam.

Zimbabwe has passed regulations allowing the state to collect mining royalties partly in the form of minerals, I think this applyes only to precious metals but i m not sure,

Southern Africa’s Biggest Dam Halts Power Generation to Zimbabwe (27th November 2022). Not sure how Prem intends to source Power for machineries but the unstable Zimmbawe network is surely something not to rely on for stable business conditions...

energy profits can be manipuated the oilco can increase their spendings in many ways likely the mayors will do acquisitions or strong commitment to expansion .. this needs to be done by year end.... fiscal year.......... the oil co push you to spend all the money they have on budget for the year or they will not be able to be credible on their next request(following year budget estimation)

ARE THESE WELLS SHALE RELATED?