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I would agree with Bigspike you’re posts are spot on Coopgare and very much appreciated! Are you GJ in disguise, if not please could you fly to California and watch over this frac for us to ensure this goes as planned!!! :)
Thanks coopgare... your a big help to the board. It’s going to be interesting to see how tulainyo flows...
Bigspike, there's a very high potential of connecting to productive zones above and below, however, when GJ mentioned dual completions he got me scratching my head. They've already completed this well, the design and planning involved in turning this into a dual completion (i.e. 2 wellbores) doesn't bear thinking and is highly complex and extremely risky. I'm hoping he actually meant that he could turn it into a well where he could selectively produce from different zones - this is achievable and less risky with multiple production packers and sliding sleeves. It would still require a workover though. Coop
Thanks for reply coopgare. I know the perforated zone has been termed a relatively thin sand but it’s my interpretation that there are a number of sands in this zone. Fracture stimulation is hoping to increase communication between the sands above and below the perforated zone with the well bore. There’s lots of positives with Dempsey and dual completion could be a fall back option too. GLA...
Thanks Coop. Most interesting. Particularly like the idea that the stimulation might be exploratory in this way, as well as productive of better flow - and too, may increase connected volumes. The more I hear about this fraccing exercise, the more I like the concept. Highly encouraging. From your previous post: 'The extended flow test will provide a lot of quantitative information with regards volumes. Don't be too surprised that after the fracture stimulation that the connected volumes increase as well as the permeability (flow rates); remember we'll be fraccing vertically as well as radially'
Mooncheese, there is always the potential to frac into a fault / fracture which can increase the production potential significantly it really depends on how stressed the formation is and the propensity for faulting. Natural fractures tend to occur close to faults as these areas are highly stressed. Since this is exploration I doubt we know much about the formation stress regime other than how the structure has been formed (via seismic). They'll get some information during the drilling / logging of the well that may indicate if they have crossed a fault or if there are fractures present but the wellbore is like sticking a needle into a giant haystack. The fracture stimulation will provide a much bigger radius of investigation to hit something more productive. Coop
Good post, coop. Thanks again. The higher numbers (100 to thousand/s - earlier posts only 10-100 times you mentioned) seem to apply if we somehow connect to natural fractures, in addition to the fractures the stimulation creates. Is this the idea of a fractured basement play you mentioned a few months back? And if we don't get the higher numbers is that because we just didn't connect to such a fracture this time, or would you then rule out the likelihood of this potentially being a fractured basement play for our reservoir/s? No need to reply, if busy - just speculative thoughts on my part. Cheers.
Sorry for delay in reply. Bigspike, that range would apply for a vertical well since there are many unknowns / variables at play here. What I would say is that there is specific criteria for candidate selection when looking to hydraulically fracture a well - this is where the extended well test comes into it's own. The best candidate wells for hydraulic fracturing treatments in a tight gas reservoir have a substantial volume of OGIP and good barriers to vertical fracture growth above and below the net pay intervals. Such reservoirs have: - A thick pay zone (unlikely in Dempsey) - Medium to high pressure (Yes) - In-situ stress barriers to minimize vertical height growth (this will be known to SGC and the JVP) - Substantial areal extent (this will be known via seismic and extended well test data) Tight gas reservoirs that are not good candidates for hydraulic fracturing are those with: - A small volume of gas in place because of thin reservoirs - Low reservoir pressure - Small areal extent When we fracture a well, what are we actually trying to do?? We physically cannot change the matrix porosity and permeability of the reservoir but what we can achieve is a massive increase in contact with the matrix. When we drill and complete a well we install a single very conductive tube into the reservoir which allows the hydrocarbon within the matrix to flow into. When the matrix properties are very poor then a single contact (conductive tube) may not be enough. Think of it like having a very large accumulator filled with gas which feeds into a pipe. Between the accumulator and pipe there is a very small choke preventing flow into the pipe - that's what we currently have. What if we could create hundreds / thousands of small conductive tubes over a relative area (determined by frac length) which then feeds into the large conductive tubing installed as our completion. Now, we have our large accumulator filled with gas but instead of 1 pipe we have hundreds of pipes connected to the accumulator (each with their own little choke) all producing simultaneously - that's what we're trying to do and this is where the increase in flow comes from. That's the easiest way I can think of to explain this. Coop
3 JVPs need cash quite badly, it is almost like they are waiting for Tulainyo2 result to have some nearolgy to raise on. The city aint buying Dusty Dempsey after the mego hype whilst drilling. World Class Discovery my eye. Take Care
Yes moncheese that’s an interesting range. I take it, that range applies to a vertical well? can coopgare confirm? There appears to be many options for this well and with 6000psi shut in pressure, it just needs a pathway to escape.
From coopgare's post below - emphasising point 2: 'The Frac will increase effective permeability by an order of magnitude (above 10 but below 1000).' Imagine a flow of 1000 times what we've currently got - might move the share price up a tad?
I just wanted to clarify a few things I've read on this and various boards about the Dempsey Frac. 1. The Frac does not increase the porosity of the rock, the porosity is the porosity - this is where your hydrocarbons are stored. 2. The Dempsey we has poor permeability - this is a measure of how well the pore space (i.e. porosity) of the rock is connected. The Frac will increase effective permeability by an order of magnitude (above 10 but below 1000) - depends if it connects to natural fractures which may be present. 3. A vertical well is the easiest and cheapest to Fracture stimulate - we don't need to worry about the magnitude of minimum and maximum horizontal stresses as we would in a highly deviated well. 4. The frac will grow vertically until it reaches a bounding stress - a stress plot can be obtained from the gamma ray which is representative. 5. The frac will also grow radially (or tangential) to the wellbore. 6. What limits frac growth is pressure and rate - hence with a frac spread which will consist of multiple high pressure pump units all connected in parrallel to a single high pressure manifold. 7. The frac could potentally grow 200 - 500ft vertically and 300 - 500 ft radially or more - a hell of a lot better that a few perforations that will only go 6 to 8 inches into the formation - we don't know what perforation skin is present and what damage zone is present from the drilling - we're currently having to produce through these - the stimulation removes all these barriers to flow. Risks: 1. A CBL (cement bond log) will be required if it hasn't already been conducted to ensure the integrity of the cement bond and prevent the frac propagating parallel to the casing / liner - this is one of the reasons that water tables can become contaminated 2. Because this is a sandstone, they'll need to use a proppant to ensure that once they create the fracture, they can keep it open. Screen out is the big risk here - this is when you don't get all the proppant into the formation and you leave some in the casing / tubing - They would need to rig up coil tubing to go in and clean out the proppant prior to flowing the well - adds additional time and cost The extended flow test will provide a lot of quantitative information with regards volumes. Don't be too surprised that after the fracture stimulation that the connected volumes increase as well as the permeability (flow rates); remember we'll be fraccing vertically as well as radially. Coop