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GEOL6350 Advanced Structural Geology - Naruk5
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00:05 Okay, So here's some examples um Argentina from the Balcombe murdered a
00:11 struck. And this is cool because can see how laterally extensive some of
00:17 could be going all the way all the way here along the
00:20 Another one here very extensive so they extend laterally for quite large distances.
00:29 . And this is just a zoomed picture on this part of the betting
00:34 fracture. And you can see how thick these guys are there. Quite
00:40 thick if you have a vertical. , sorry. Go ahead. I
00:47 gonna ask if you if you had vertical fracture propagating and it hit one
00:51 these, uh, bed parallel Did they typically travel along the bed
00:56 or did they typically propagate a particular through them? That's that's a good
01:07 . I I think they typically propagate them on bond. Part of that
01:14 is that these had to have formed the source rock was in the maturation
01:22 and thes vertical ones that we see formed later they post state hydrocarbon generation
01:31 during the early stages of a And so I'll expect these to propagate
01:39 the betting parallel fractures and a Z through. We'll have to look and
01:45 if we see examples of that or . So why the calcite? Good
01:56 . I don't have a good answer that. Um, we see these
02:00 with calcite, silica, gypsum. , any hydro thermally low temperature mineral
02:10 highly soluble. In another example here Marcellus core variable thickness, centimeters so
02:23 here. Down to a couple of here in these guys. Okay,
02:33 . We're gonna shift now and talk geo mechanics and fracture mechanics. The
02:37 of fractures to the imposed stresses, ? Some way talking about this.
02:48 block diagram before, um, where have of signal one maximum compressive stress
02:56 three, the minimum compressive stress. then on the fall, thes two
03:02 are resolved into a in a shear that acts parallel to the fault.
03:12 these air what we used to go the the more Coolum analyses there
03:21 And so what I have here the part of this picture is discriminating.
03:27 pool, um, stress diagram where is the normal stress. So this
03:34 this stress acting perpendicular to a shear in this. Why is,
03:45 normal stress? But I should issue It's the normal stress acting on the
03:49 . And then the shear stress is component of stress acting parallel to the
03:57 . And what I'm showing here is core plug that's been subjected to a
04:01 actual deformation experiment where it started out a core plug hole core plug and
04:09 , um, subjected thio increasing maximum stress until a fracture formed until it
04:17 . By sheer failure to get these Coolum envelopes or we generate, we
04:25 a Siris of experiments like this, in each case, off calculate and
04:31 the normal stress and the shear stress the fall. And we do it
04:36 increasing Sigma wanna and increasing Sigma So we get a Siris of stress
04:43 here, here in red, here in black, and the tangent to
04:51 circles is defined as the more common envelope. Hm. So any time
04:59 have a combination of normal stress and stress that lies on that envelope,
05:07 you've achieved the conditions for cheer Okay, now that's that's good for
05:21 fault and sheer fractures. Well, want to know what the stress conditions
05:26 for tensile fractures for these joints, this example from the Marcellus. So
05:32 tensile joints, by definition, have shear stress. They have no sheer
05:38 along them. They're just opening mode fractures. And so these have to
05:46 where the shear stresses is basically So they're gonna form, uh,
05:54 this in this portion of the the envelope with negative with zero low shear
06:04 in and requiring an actual negative sigma to get over into this quadrant.
06:16 , and I've added here now a circle that represents tensile failure. So
06:22 get this, um, we have have, uh, we have to
06:30 the signal three into the negative which requires high fluid pressure. So
06:41 requirements for these joints for tensile failure low total stress. This circle has
06:47 be a really small diameter circle to able to fit underneath here. So
06:53 ah, low total stress, low stress. The diameter of this circle
06:58 to be small to fit in and we have to have a high
07:02 pressure to move that stress circle from the right out here into that on
07:11 quadrant of shear. Stress of One of normal stress. John.
07:17 that happens, and the the Mode fractures are vertical, we get
07:24 When they're horizontal, we get Um, and they ge mechanically the
07:32 . They just formed from different orientations signal one from vertical to horizontal.
07:38 , the other important point to make is that essentially, the trend of
07:43 , that strike of these is parallel signal one that's a that's a critical
07:49 will come back to you, So this explains the role of fluid
07:58 . There's, um there's my more failure envelope Where it's read. Here
08:03 where I get sheer failure all along . So any combination of high stress
08:10 potentially generate cheer failure to get the one tensile fractures here, where the
08:18 stressed is negative, have to have , high fluid pressure to shift that
08:24 circle to the left, decreasing the normal stress where it moves into the
08:30 values in here. Excuse me, , can you let Joe back
08:34 I believe he was. Oops. correct. Um, Maria Can you
08:42 let him in? Yeah. Okay, I see we're up to
09:15 . Are we good to go? back. Mhm. Mhm.
09:45 Joe, are you there? Did did you hear the slide when I
09:48 talking about four pressure? Uh, , no. But you have to
09:55 back. Don't worry. Well, just talk about this one.
10:00 Um, To get the tensile joints here where you have no sheer
10:04 you have to have a high fluid to move that stress circle from the
10:08 to the left to where your normal stress become zero. All
10:19 so I have a series of slides to talk about How that how that
10:24 . Um, the the black circle represents my my vertical stress. My
10:32 one, my main normal stress. this is with no overburden. If
10:38 increase the fluid pressure, the fluid basically starts toe carry some of the
10:44 . It starts to float. Some the rock weight basically and moves this
10:50 stress for the left by an amount determined by the, uh, by
10:56 fluid pressure on. So this is the vertical stress with no fluid
11:03 This is the vertical stress with low pressure. And if I raise the
11:07 pressure higher, I can migrate this V all the way over here to
11:13 I have an effective stress with high . All right, so now if
11:22 is if it failure conditions If this my are Sigma V it failure,
11:31 could construct a circle that intersects the envelope here and gives me a minimum
11:37 effective stress here, allow at both these Have low overpressure. If I
11:44 the same thing, it high over here you can see I'm going to
11:48 a much smaller stress circle in Who would this tie overpressure my effective
11:57 stress. Here, the minimum stress failure lies here. This circle intersects
12:04 failure envelope and is much smaller diameter this original circle that I started with
12:11 low overpressure or with no overpressure. so if I continue to increase this
12:21 pressure toe where it's essentially equal to main effective stretch, my main effective
12:30 , I can migrate that stress circle the way over to the left,
12:33 the negative, and then the negative Stress region and generate joints and tensile
12:43 . And if if my main stresses , thes fractures will be joints if
12:51 main stresses horizontal thes structures will be parallel fractures or beef. Uh
13:02 Okay, So talking now about the of this of the gym mechanics for
13:06 stress orientations. So for joints, important point is that the strike of
13:17 joints is parallel to the strike of one in stigma. Three strived perpendicular
13:24 the joints. So here's a cartoon my joint. My mode one pencil
13:29 . There's no shear offset. it's it's opening, as shown in
13:34 direction by the zeros. So these represent my signal. Three in the
13:39 of the fracture represents my signal. if I flip this thing on the
13:47 . So my signal one is still . But now my sigma three is
13:52 . I get betting parallel fractures or again. No sheer offset along the
13:58 . Just your opening mode. signatories. Vertical signal. One is
14:04 in the Uh huh. The fluid to do this has to be about
14:13 , toothy overburden stress. So are pressure to get these Has to be
14:18 life aesthetic. Okay. Um so this is Ah, discussion.
14:35 don't we, uh let's let's take quick break here. Maybe 10
14:41 See, I have about it about of two. Let's come back at
14:46 2, and then we'll talk about the questions on this slide.
17:30 We've got almost everybody, so we'll ahead. Um, you feel free
17:35 turn your video off again if you . Um, So let's let's discuss
17:40 question. We have J one J two here. J one strikes
17:47 . J two is perpendicular to that . What were the orientations of signal
17:53 and Sigma three during J one. during J one, what was what
17:58 Sigma one? Anybody? Anybody take guess. Was it a normal,
18:05 force? Be max. Signal one normal. You know what was
18:15 let me let me rephrase that. , what was the maximum Horace?
18:21 of the maximum horizontal stress on Some stress is like is like the
18:27 position as the arrow, but like but finding the swift. Yeah.
18:35 for J one, the maximum horizontal parallel to the strike of the
18:42 What does that mean for the minimum stress Follow. Ridiculous. Yeah.
18:50 this orientation so that the joints air against the minimum horizontal stress in this
18:59 . Okay. During J when J formed what was the orientation of the
19:03 horizontal stress? I feel like it's to J one. Or just a
19:13 TJ do. Yeah, pretty stay to J two. Um, either
19:19 is correct here, but the more correct answer is parallel to J
19:24 So the strike of these joints is us the strike of the maximum horizontal
19:30 and the minimum horizontal stress is gonna perpendicular to that. What does that
19:38 or imply in terms of, or circle diagram. Anybody want to
19:42 a stab at that? J one have a really large circle.
19:53 and J two would have really small towards closer to the tension that curve
20:00 occurs of close half right. The would be back there. Your share
20:15 that zero. That's right. Shear it. Zero. How about the
20:24 of the stresses? We large So guess the curve will be inverted instead
20:32 junior increasing with both of them. both needs to be big.
20:37 So it's the opposite. Both need be both need to be small.
20:43 ? Yeah. So both of these tensile failure. So failure is occurring
20:54 here in Moore Coons Stress spaces. the stress circle has to be very
21:00 to fit into that space. um, because it's small, it's
21:08 doesn't take much change for this One of the sigma three to swap
21:16 change the orientation from a northeast to . I didn't. So when you
21:23 you see these multiple joint sets the strike of the joints is telling
21:29 the strike of the Sigma H. and, um, the presence of
21:37 starts that hi angles to that is you that the stresses air very close
21:43 each other in value so that they easily swap in terms of the the
21:49 in the max value and the more stress space. I'm so this so
22:00 this is important. The strike of joints is parallel to the max.
22:05 stress in the magnitude of the stresses to be very small to get into
22:11 tensile region on the in the Mechanical analysis. So I have a
22:19 . But you mean the You mean just You mean between J two and
22:31 one? They're both very small because already broke. So the stress is
22:41 . Is this graphic for J one tube? It's for the graphic is
22:48 both Thinks part of the graphic is both since. Okay, So this
22:56 analysis this graphic doesn't tell you anything the orientation of the joints. It
23:03 tells you about the stresses when they E. I'm thinking that j one
23:08 it looks in the picture so much than the then Jay too, that
23:14 kind of expected to see something different them. Um, the grasses.
23:28 an interesting point. The the length the spacing is really independent of this
23:40 on Once you get a once, get a through going set, it's
23:47 toe limit the length of all the set. So J to the length
23:52 J two is going to be limited the spacing of J one.
23:58 and the the length of J one could be almost infinite, depending on
24:12 , uh, the area that's affected the food pressures and the depending on
24:19 area that's affected by the fluid So I would expect, in all
24:26 , for the length of the first to be very long and the length
24:31 the 2nd and 3rd sets will be by the spacing of that J 17
24:46 , Mhm. Any other comments or on that questions? Okay,
25:08 we'll go on a little bit. . One of the interesting things we've
25:18 recently is that the joints that we at the surface and outcrop are not
25:24 present in the subsurface. And when we this is an example of
25:33 Marcellus joints and outcrop, you see J one here, Here,
25:39 J twos here. Ah, butting the J ones in the subsurface Onley
25:48 J twos or president. So we We don't see these j ones in
25:53 subsurface. Yeah, and all over Northeast, in New York and
26:02 But we get both of these joints . We get the northwest trending one
26:08 the northeast trending one that represents the one and is parallel to the present
26:14 of signal H backs. And in case, it is the signal
26:20 the J two is northwest trending more less throughout this whole region.
26:28 if we go south in Pennsylvania and and West Virginia, we see the
26:32 relationships. We see a through going one set trending roughly Northeast and a
26:40 trending J to set roughly perpendicular to J one. But when we look
26:50 the subsurface data, uh, we see the J two step that northeast
26:57 J once that is absent in the . And this comes from some work
27:02 done by a Wilkins and Van Mountain in a PG bulletin. They looked
27:10 , um, Warhol image logs and from several wells, uh, the
27:18 where these red lines are the The solid spots represent areas where they
27:26 core. The open circles represent where had image logs on. And in
27:33 of these cases, they only saw Northwest training set. They never saw
27:37 Northeast trending set. What's the reason that? Dancing subsurface. So that's
27:48 an excellent question. Um, we that this Northwest training sent set is
27:57 to the stresses at the time of Allegheny Nirajan e at the time of
28:02 folding and thrusting that formed the major here Eso This was late Pennsylvanian
28:10 And and we think that this orientation those compressive stresses. Um, in
28:21 the other joint sets, we think the stresses imposed present day during
28:29 So they formed much, much And at this Northeast orientation related to
28:36 present day S H. Max shown by the arrows here and here.
28:41 I think these guys formed early in pen perm Allegheny in and the Northeast
28:49 ones that are absent in the subsurface during uplift in the present day stress
28:58 . Thanks. Let's go. What's the, uh, that pitch max
29:03 that, uh, southwestern part of map to be, uh, you
29:08 , towards the Northeast? E there's like Cincinnati art right there.
29:14 I didn't know. I didn't know was that setting right there. You
29:18 , I honestly don't know the reason that. Um, it's, uh
29:31 it's probably good. Yeah, I speculate, but I don't I don't
29:36 know the reason for that. just . Thanks. Yeah, I could
29:43 up a geology story, but I'll put my foot in my mouth for
29:47 . So I won't, um it be worth going back to this article
29:53 see if they if they explain Because I don't recall that we see
30:04 similar thing in the Gulf Coast. there it's related to the are to
30:09 Gulf of Mexico drifting and filling. I'm I'm not sure what it's related
30:16 you here. I have a question Yes. So in this, in
30:24 case, the principal stress is along the foot in parallel to the
30:31 Right. Um, the the principal when they formed was parallel to the
30:41 . The present, a principal stresses to that, but it's parallel to
30:48 second joints that folks. Okay, ? So? So when When it's
30:56 to them, it also needs to bigger than the perpendicular one. Which
31:00 the one from from the top. . So does this mean that it
31:07 higher than the overburden pressure? If I'm thinking about the overburden pressure
31:16 , that its's the column off frog the fracture. Um, you think
31:24 the you think about the overburden pressure . But when the IT present day
31:31 the stress, the main stress in orientation these rocks are shallower than they
31:40 earlier in their history. So the that they're experiencing now are actually
31:46 then previously in their geologic history. , just because they're not buried is
31:57 . Yeah, it's only at the when they form. Correct.
32:15 Yeah. So this is the joints . Very interesting story there. Very
32:21 features. So there's tons and tons tons of literature on them on
32:25 Only in the last few years with drilling that we've gotten subsurface information that
32:34 constrains the story on these. So toe summarize, uh, in
32:51 outcrop, we see two very prominent sets, but only one of them
32:56 J tube is present in the And we think that relates to the
33:03 at the time of formation that this the Allegheny in compressive stress on in
33:10 represents the present day compressive stress. . Allow these things to form during
33:18 , and hence it much shallower Okay, so this now is a
33:27 history for for the Marcellus shale. this? This layer represents the Marcellus
33:35 . So it was initially deposited in mid Paleozoic, subsided to a maximum
33:46 near the Paleozoic Mesozoic boundary, and subsequently was uplifted. Now, when
33:56 look at the fluid inclusions in the , we see too high temperature populations
34:06 one high, high temperature population that at maximum burial. And at this
34:16 , the marshals would have been generating been generating gas. And we see
34:23 the fluid inclusions to phase inclusions mostly , indicating that the fractures formed are
34:32 this on this phase of of uh, during or I shortly after
34:37 gas generation window. So those so joints had to form sometime. What
34:49 it? Here in the the early during the beginning stages of uplift.
35:04 have similar observations from the Eagle Ford in South Texas. The oil shale
35:08 there. So this is a temperature . Ah, time getting from old
35:14 young here on the top death here temporal. Sorry temperature here in degrees
35:22 in this curve represents the burial history the Eagle furred. When we look
35:29 bed, parallel and joint veins in eagle. Furred. Um, we
35:34 that they contain hydrocarbons both oil and . And it's And that suggests that
35:40 formed after the oil generation window or in the oil generation window somewhere here
35:46 the first stages of up left. and so the uplifting unloading both here
35:53 the Marcellus are important points are important in the generation of those joints.
36:07 , so I have a little calculation for you. We just saw that
36:14 joints Marcellus joints had to form it 25,000 ft T v d. Based
36:20 the fluid inclusions. So what I you to do is to calculate the
36:27 that's required to form those joints. so, in the in the overpressure
36:34 is the flute pressure above hydrostatic. what? We know that we had
36:42 total stress. Negative Sigma three High pressure, low differential stress. These
36:47 all the requirements to get that stress over into the tensile failure realm.
36:53 what I want you to calculators how that food pressure had to be to
36:58 the stress circle over here or and can assume that the uh, signal
37:06 is Sigma one, and that's gonna with that. At a rate of
37:10 one PS I per foot, the stress is going to be about 70%
37:18 that. So my minimum stresses Sigma , and it's gonna be about 70%
37:23 the Sigma V, and then the water pressure increases with depth at a
37:29 of about 0.455 p s soccer So given this information in that
37:37 you can calculate what overpressure was required form the joints at this at this
37:45 . Okay, um so go Solved that. Pull out your
37:53 pull out your calculators. Mhm and on that. Let's see. I'll
38:01 you I'll give you about 15 Take a break if you want,
38:09 , and and do these calculations, when you're done, turn your video
38:15 on so I can see when you're , and we can start to discuss
38:19 answer. Maria, it'll be another minutes or so before we start
41:16 So you might want to hold off recording until then. Sorry. Are
41:28 any Yes. So I was just , um, it'll be another 10
41:34 or so Before we start discussing the , you might want to pause the
41:39 for a while. That's okay. off. Yeah, I was just
41:52 at it again. Um, so guess I'm I just wanna make sure
41:59 get mine. What I'm doing is getting the 25,000 PSE for Sigma
42:07 and then 70% of that is, , 7 18,050 at those together.
42:15 then subtract that by the hydrostatic. pressure 32,000 bc, Um, you
42:25 your one for three? Yeah. . Amir, what did you
42:39 I went directly to the affected, I just subtracted the 25,000 pc from
42:46 the hydrostatic pressure. I got 13 6 to 5, and, uh
42:59 that's it. I wasn't sure if should switch it to the minimum component
43:03 just use this one. Yeah. need to take the minimum component.
43:13 , J d What did you Okay, So did a process similar
43:20 Clayton. And then I figure that would need an overpressure greater than
43:29 125 pc. Yeah, that's The onset of fraction. Yeah,
43:40 good. So the only thing I differently than Clayton was used that the
43:45 men? Oh, yeah, it's critical. They use that. H
43:50 that Sarah, What did you So I didn't tell her, but
44:00 guess I used the box instead of men. But I did not.
44:09 . I got 17 5. It's . When I out of those feelings
44:15 traffic. Ps I Calculation. I 31 1 25. Okay.
44:24 you don't You wouldn't add those to would just take the same age.
44:36 . Yeah, Joseph, what did car groups It is that the same
45:09 61 25. I was just wondering negative Sigma three, though,
45:19 And then just like overall low total that, like, relative to the
45:23 that you're looking at, I think muted. See? Yeah, it's
45:36 relative to that system. It's It's relative to that Sigma one. Sigma
45:54 . Grant. Did you finish the ? Yeah, I did. E
46:00 25,000 PSC for signal wanted 17,500 PSC Sigma three. 11,375 p.
46:09 I for the hydrostatic and then 6125 . S I over overpressure.
46:16 It's perfect. I put it I that into an excel document. If
46:26 you have to change is your I pressure change in your depth and you
46:31 and sigma be you could pretty much that across the board. You think
46:35 is a pretty good way to do ? Yes. Yes, absolutely.
46:42 fact, when we when we talk , we'll talk about over pressures in
46:49 weeks and we'll set ups. Um , figures and excel that judge Just
46:55 based on this taking, taking when extrapolations of this. We used to
47:27 that Shelley and P stood for Shell in Power Point because you could just
47:32 so many problems in excel. Come . Okay, Daniel, Welcome
49:37 What did you calculate? You're We can't hear you. Sorry.
49:57 , yeah, I wasn't too Like I'm not I'm honestly not too
50:01 what I did. E subjected 70% the 25,000 from 25,000 of them.
50:09 that by 0.455 Um, Okay. you wanted to run Now let's calculate
50:25 of that. 25,000. That gives the signal. Three, that you
50:31 to, uh, get enough water to equal. And so then you
50:38 that 70% of 25,000 and subtract the water pressure from that. And that
50:46 gives you the over pressure that you Thio, Dr Sigma. 3 to
50:50 or negative. So that put So 70% of that 25,000 is
51:05 So you subtract, um, 0.455 17,500. You subtract the product of
51:16 times 25,000. Okay, used. . Say I get up. 1
51:37 . Yeah. Yeah, that's Okay, so I've put up the
51:57 here in red and the key thing , um, the key thing here
52:05 that joints require the fluid pressure to equal Sigma three. They've got to
52:11 greater than or equal to Sigma three . So first you need to calculate
52:18 One. The 25,000 ft that gives our Sigma the that's 25,000 p s
52:27 25,000 ft, times one this 25,000 , and then the Sigma three is
52:33 to be about 70% of that. I take 70% of that 25 and
52:39 17,500. That's the total fluid pressure I need to generate the joints.
52:49 then I want to subtract my hydrostatic from that to get the overpressure.
52:56 the next step is to calculate your pressure, which is the 0.455 times
53:02 . That gives you 3 11,075. then if you subtract that from the
53:10 that gives you the overpressure necessary for the joints, which is 6125
53:17 Um, so it's ah, calculating food pressures is a pretty straightforward
53:29 The key thing to remember is that joints require food pressure equal or greater
53:35 Sigma three time, and then these things. They're just straight algebra,
53:42 linear functions. Um, you can can set this up in excel and
53:47 a general solution with calculating each of as a function of depth.
53:53 but for this for this particular all right, with the joints for
53:58 in 25,000 ft. Need about 6000 . S. I overpressure Thio,
54:03 enough overpressure to drive those joints. other comments or questions on that before
54:18 move on? Okay, I will ahead. All right, So we're
54:56 to go on and talk briefly about role of fluid pressures and hydro fractures
55:01 hydro fractures form exactly the same as fractures. And the key is that
55:07 fluid pressure reduces the stress. It the effective stress and the tensile.
55:14 tensile failure requires those high food pressures we just calculated. Um and that's
55:20 on the fracking sites, you see those pump trucks and tank trucks and
55:27 pumps and huge of parallels to count to create the high fluid pressures that
55:34 need to get the hydraulic fractures. see. Okay, So this was
55:50 was another discussion point that I wanted have well, looking at a map
55:57 the the Permian Basin in West all these blue lines in these green
56:03 are ligaments of various sorts. Just those for For now, each one
56:08 these red spots represents a well where have hydro fracture orientations from your whole
56:17 logs. And you see, they're trending pretty consistently Northwest. They're a
56:23 bit curvilinear, strongly northwest down here little bit. Maurice Tewes to appear
56:29 the northern part of the basin. the point. I want to discuss
56:36 . What does What does this tell about the strikes off signal H Max
56:42 signal H men. Yeah, that some areas, the signem. It
57:00 of some Mr Last almost like in middle in the north, right?
57:13 . How about down here in the ? Yeah. Yeah. So?
57:24 the hydraulic fractures air just like natural . They they strike in the orientation
57:30 this big May age, max. then here the signage Max is basically
57:37 southeast. Here, it's a little East west. Uh, here it's
57:42 more East west again. Northwest, , over here. Home. And
57:48 so, if that's my signal. Max, what's my signal? H
57:57 ridiculous. Perpendicular to that? So Northeast, Southwest, over
58:04 Little more north south here and appear north south for me. And so
58:14 of you know this already. What's optimum orientation of, well,
58:19 And why some of you know this your jobs perpendicular to the full direction
58:32 enhance the recovery so perpendicular to which ? So it's a direction off signatory
58:44 the direction of signatory and direction to to signal one. Yes,
58:49 Exactly. Right. In that when you when you do a frack
58:56 , you're opening fractures against the So the least signage men, the
59:03 , the smallest horizontal stress. And get the most effect if,
59:09 stimulation job. Yeah, so it took todo so like what? So
59:19 the optimum has moved again. So the album, as myth
59:24 is pretty much northeast Southwest. You go perpendicular to the So all these
59:32 ? Yeah. Okay. Well, do you think about drilling? Update
59:37 down? Dio. I don't think should make any difference. Do you
59:56 you does Anybody have experience? I've always heard update balls or better
60:04 of, uh, near wellbore And the hell the well, a
60:08 of times they put, uh, The idea is to heal the
60:12 You can put those, uh, and them better, and they have
60:16 , better drainage. At least that's I've heard from my eagle for production
60:22 . So excuse. Okay, That's a good point for me to
60:31 . I wasn't aware of that. it's hard. It's hard to prove
60:37 because then we tried toe, you ? Then then you really try to
60:40 at rock properties along the lateral and your stages communicating? And it's,
60:47 , it gets really, really in weeds. I don't know. I
60:51 I don't have anything in either It's like whatever the reservoir engineer
60:54 right. No, it's a hard or anything, but I'd say it's
61:00 like Do you want to? Then like lips in there to try Thio
61:04 the oil from the other end? your info like right? It doesn't
61:11 more or less oil. Futural Update um, yeah, I'm scared in
61:19 ways, and, uh, I've arguments on both sides. Nobody seems
61:23 know you. Have you seen anything affects the declines? The declines I've
61:34 are just very, very rapid and They They declined to a plateau,
61:44 , and then hang around that plateau years. But the plateau was pretty
61:48 compared to their early production inspires like toe down. I'm not really
61:56 I'd say a lot of times when production goes away really fast, it's
62:00 they just opened the choke right up the very beginning, as opposed
62:03 like, slow, gradual. But just gonna be the economics. And
62:06 did you want? Did you don't quick investment return or do you need
62:11 timeto classical form? There seems to a parent child problem there,
62:18 Like also related to lateral spacing. . You get him in to
62:25 and they're they're just no good. , also, like not only just
62:32 spacing, same benches. But, , you know, the company
62:36 Oh, well, we have, know, five different intervals that we
62:40 target here, and they're different separated these, uh, back barriers.
62:45 then you go to you drill like the wolf camp, lower you drill
62:49 can't be well and in a well an X and Y fans and a
62:53 phone Well, all in the same . And, uh, they had
62:56 assumption that there, um, multiple . But then when you go to
63:01 . Um, it's there's tons of between between the different reservoirs. So
63:11 what was it like a star? ahead. See? Oh, I
63:14 just gonna say some of the work seen using, um, micro seismic
63:19 to try and monitor the volume of rock that stimulated. It's it is
63:24 huge volume, mhm, laterally and . I've seen that. And also
63:33 used a tracer data or try to chemical traces tracers toe. So look
63:38 , um, production flow back for parts of the lateral. And,
63:43 , so we try to you try bring it all together, but it's
63:46 difficult. It's really difficult. Doesn't tracers usually don't really tell you much
63:51 the end. Least what? We it out. Okay, good.
64:10 , well, so this was this more or less the answer that I
64:13 you to get that from these poor image fractures. You're They're telling you
64:21 the signage max is more or less here. It does deviate tomb or
64:26 west up here in the northern part the basin. Signage men is going
64:31 be perpendicular to that. So that's to be basically northeast southwest in that
64:36 becomes the orientation of your optimal um, lateral. So,
64:42 you drill northeast or southwest and hydrofracking generate fractures that air, hoping against
64:53 least horizontal show opening against the minimum stress. And that gives you the
64:58 effective frack job. Okay, the other interesting thing is how the
65:15 H Max varies. So this is map of the whole Permian Basin,
65:23 these black lines represent orientations of of signage, Max. And so here
65:33 the southern part of the Delaware it's mostly southwest northeast, and then
65:38 starts to trend more east west. he come into the northern part of
65:41 basement we saw. And as you further north under the shelf, it
65:47 becomes, uh, Mawr Northeast, and over to the middle and
65:53 It's essentially East west. Wow. the signage Max varies quite a
66:02 just over the scale off the basin here, where you're getting into the
66:13 Basin here we're starting to see the of the Gulf of Mexico, opening
66:20 the signal three oriented this way and H. Max oriented roughly parallel to
66:26 coastline, Parallel to the off the faults that achieving the extension.
66:34 and here we're we think we're still more basement range. Rio Grande Rift
66:42 of influence over here. Okay, last topic today will be the impact
66:54 natural fractures on well, performance. I've got a graph here Now,
67:01 scatter plot that compares matrix permeability well, test permeability. So each
67:08 point on here represents a point where have data from a core plug.
67:16 gives me a nun fractured core plug gives me the matrix permeability. And
67:20 see these, especially in, the unconventional reservoirs tend to be
67:25 very low. And the Y axis gives me well, test permit abilities
67:34 , uh, extended well, tests , um, from reservoir simulations from
67:42 like that. Where the, uh have Well, you have actual,
67:45 , data to back out a permeability the stimulated volume Iraq. And,
68:00 , each one of these lines represents order of magnitude increase. So this
68:05 1 to 1 where the wealth test in the matrix permeability are the
68:11 This is where the well test perm 10 times the matrix 100 times the
68:17 . 1000 up to 10,000 times the in what this shows is how the
68:24 permeability of fractured reservoirs is just up 10,000 times greater than the main.
68:31 , fractured matrix permeability. The blue here are all naturally fractured reservoirs.
68:39 red triangles here are all stimulated. francs, reservoirs. Mhm. And
68:45 all show pretty much the same. trends. The Hydra Fracked reservoirs.
68:50 course, you're only going to do where you have the loan matrix.
68:54 , ease. But the hydraulic fractures the same effect of increasing the effect
69:00 permeability by several orders of magnitude so naturally fractured reservoirs and hydraulically stimulated reservoirs
69:10 the same trends. So those were carbonate reservoirs in? No, they're
69:16 mix of carbonates and classics. Oh, my. I was gonna
69:41 a question on the side. Can hear me? Yes. Go
69:44 Okay. Great. I'll just Can comment on? I've always found interesting
69:48 we used to monitor, um, heavily while we were completing wells.
69:54 it was just interesting to think about you could see communication well, the
70:01 and you know, you're fracturing your these higher poor affirm systems while you're
70:07 the job. But it was interesting we found that you see,
70:12 events, you know, up to to 14 days after you complete some
70:17 the world. So it was interesting you saw such a hot, you
70:20 , communicate high amount communication early And then that pressure was still still
70:26 in the system for, ah, time after that, in the in
70:31 unconventional reservoirs. Um, I guess makes sense because the the permeability the
70:43 is so low that you won't dissipate pressures through the through the matrix.
70:49 they Well, because of that, linger on for an extended period of
70:55 . Uh, all right, because of this on, we've always
71:12 that natural fractures will enhance the productivity the reservoir. Right. And there's
71:21 a quick bit of literature on that back to this figure, particularly the
71:27 . I always thought that all these fractures, even even the J twos
71:33 the J ones, would help of well productivity. Um, in
71:42 that's true function knows there uh, that flow per unit area should be
71:50 function of fracture intensity. So here looking at discharge or flow per unit
71:57 and and in the numerator is We have fracture at that. Your
72:02 the fracture spacing Hello gravity and the density. And then in the numerator
72:11 , in the numerator I'm sorry. the numerator we have fracture spacing.
72:15 , D h is the d does head radiant are fracture Spacing is in
72:22 numerator in in use the the fluid . And so for fractures the the
72:32 fracture spacing you have in the wider you will get mawr discharge per unit
72:39 . So by adding natural fractures to rock volume, you would be increasing
72:47 and decreasing d and you would expect mawr flow from naturally fractured reservoirs than
72:57 . Okay, but what we see is that that's not really the
73:03 Um, we did a study of Permian Wolf camp comparing natural fractures and
73:10 with production data. And so we through, I don't know, a
73:15 feet of core logging the number of per foot of core. And this
73:20 a graph of one of those cores we have measured death here as the
73:27 axis a number of fractures per foot as the X axes. So you
73:35 , in the core we've got natural ranging up to 10 national fractures per
73:41 of core and averaging sort of five per foot, of course. So
73:45 have pretty intensity, pretty high intensity natural fractures, and we compared that
73:53 well declined curves from nearby wells. wherever we had a at a
73:59 well, we tried to find production that was close to that cord.
74:05 , and here we're looking at a of barrels per day versus days on
74:11 . The black is oil barrels per , green is water barrels per
74:16 And you see these decline really rapidly the first 1 to 200 days and
74:22 kind of platt throughout. Ah, . Atwater values around 4 to 500
74:29 a day versus oil values of 1 200 barrels a day. And then
74:33 just go on for years. the decline of these is very,
74:39 gradual. Oh, in this gradual in this gradual dissipation off pressure is
74:49 to what I think you're seeing with , uh, with the decline of
74:54 the Hydra Fracked pressures. And it's take a long time for those fractures
74:58 those pressures to decline. All there are in the Permian. We
75:11 all kinds of fractions. We have , uh, joins thes near vertical
75:16 shown by the red arrows. and we have a few bed parallel
75:22 , but the joints in your vertical represent about 80% of the fractures.
75:28 , some of the joints are Some of them, like this
75:31 are partially submitted or completely open. , and these are the ones where
75:37 see sort of 52 10 of these per foot of core, and we
75:44 see many veins. We see, , less than one vein for plus
75:49 parallel vein for foot of core. , Right. And one of the
75:58 things about the premium is that they're There's no mechanicals photography. So here's
76:03 correlation. Suspecting, looking at 12345 wells are. And these were the
76:13 of the different wolf camp formations. is preferentially fractured compared to,
76:36 one of the other one of the members. It's all pretty comparably,
76:42 fractured. So no, no, distinct mechanicals photography. And this is
76:54 graph now preparing the fractures with the data. So on the X axis
77:00 have the near vertical natural fractures per , of course. So this is
77:04 natural fractures and these air just just joints both cemented and un cemented.
77:11 on the Y axis here I have per day on a logarithmic scale,
77:17 oil was shown in black water was in blue. Uh, the oil
77:23 pretty consistent at around 1 to 200 a day. The water bounces around
77:29 little bit from sort of 500 toe barrels a day with one outlier here
77:35 greater with, like 20,000 barrels a , all right, and really no
77:42 of the production rates with the natural intensity. Um, and what we
77:51 we include concluded from that is just The intensity of the hydraulic fractures must
77:57 overwhelmed the abundance of the natural And we we also compare a core
78:11 some hydraulic through a hydraulically fractured I looked at both the natural and
78:16 induced fractures, and we can We differentiate the two based on these characteristics
78:25 the of the induced fractures, the fractures, you have really irregular
78:31 You don't see the nice clean surfaces we see like a natural joints.
78:37 see all these sort of unique little features on the stimulated fractures that we
78:44 see unnatural joints. And we see lot of steps in the stimulated fractures
78:49 we don't see in the natural So we could use these things to
78:54 the hydra fractures from the natural fractures this plot. Now shows on compares
79:05 number of hydraulic fractures with the number natural fractures and thieves come from a
79:14 deviated well latter like this. It from a well in the middle and
79:19 . So not in the Not in wolf therapist, none of the Delaware
79:24 proper over in the middle of And, uh, within that
79:30 we see lots of fractures at Various orientations, mostly high angle to
79:35 , uh to the well bore Down on the bottom, I have a
79:42 of number of fractures per foot of versus, uh, measured depth along
79:49 lateral here. And the hydraulic fractures shown in the blue. And then
79:57 two sets of natural fractures here in brown and in the green. And
80:02 this shows is that the intensity of hydraulic fractures is just much, much
80:08 than either or both sets off natural over the length of this lateral
80:17 we average 0.35 hydraulic fractures per foot core compared 2.16 natural fractures per foot
80:25 core. So the hydraulic fracture intensity twice the natural fracture intensity. And
80:34 think that's why the hydraulic fractures just overwhelmed contributions of the natural fractures in
80:41 core. Um, so in these these Permian Basin wells, the intensity
80:50 the natural fractures just doesn't really It's completely overwhelmed by the intensity of
80:55 hydraulic fractures. Right. Um, I'm going going to summarize and wrap
81:04 here of four. This section on and Jim mechanics we talked about.
81:12 have three generic types of fractures mode , Moto two and Moto three.
81:17 mainly interested in the Mode one. are the tensile fractures the joints and
81:22 bed, parallel fractures or beef. air fractures with no fracture parallels here
81:27 any direction. The mode to in most tree have a sheer component in
81:33 , uh in the plane of the , and the lack of that sheer
81:37 is what distinguishes Mode one from these guys. It makes the mode one
81:42 pure opening or pure tensile joints gee, mechanically. These tensile fractures
81:50 high fluid pressures and load deviate orrick . So, um, so we
81:55 to have that high, high fluid in a small stress circle to get
82:00 stress circle over into the negative part the more cruel diagram. Low TV
82:07 T V tour stress means, the small, small diameter to that
82:12 that signal one minus Sigma three is . The difference between the stress is
82:18 small. That difference is also important that's what enables a different joints.
82:24 to form in different orientations. Because stresses are comparable in value, it's
82:30 for signal one sigma three toe to . Sure, the budding relationships give
82:37 the relative timing of the different joints , and this is what distinguishes J
82:43 vs Jake versus J three. And on. PLOO. Most features we
82:48 on the joints indicate the propagation direction each individual joint. The strike of
82:55 joints equals the strike of the signal . Max at the time of
83:01 So we can we can use that strike to constrain what that signal
83:06 Max was at the time of joint . Mhm both the joints in the
83:12 . Parallel fractures require high food They require that to get that stress
83:17 far over to the left in that realm. Uh huh. The
83:22 the bed, parallel fractures implied that fluid pressure approximately equals the overburden.
83:29 these guys are signal. One is , are signatory, is vertical.
83:34 so we're opening these bed parallel fractures Sigma three against the way of the
83:40 column. And the fluid pressure to that has to be approximately equal to
83:44 overburden. Thanks. Many he joins during uplift. So, like we
83:55 about Marcellus andan, the eagle furd the joints, the joints have to
84:00 during the early to late stages of . And what that means is
84:07 What that implies it is that the and outcrop are not necessarily what we
84:14 in the subsurface. So thinking back the Marcellus, we see those two
84:19 sets an outcrop. But only one them, the less prominent one,
84:22 present in the subsurface and hydro fractured . Intensity of hydro fractures is just
84:30 , much greater than the intensity than intensity of the natural fractures. And
84:37 of that, the intensity of the fractures has little to no effect on
84:42 , performance in these hydraulically stimulated Okay, so questions or comments or
84:54 ? This is where I was going stop for this session. I like
85:03 you say insensitive natural fractures has no of, well performance. And I
85:07 . I did like to see that because, ah, lot of times
85:10 hear or I've heard the people You know, when they kinda can't
85:14 they run out of ways to describe the well is doing better than their
85:17 beating type period or something like they'll default. Thio. Oh,
85:21 must be naturally fractured. Like I've it used this kind of like a
85:25 out. Well, performance so All , it's interesting to see that.
85:30 , we actually, we initiated that because that was our working assumption.
85:37 we thought that we could use the data help predict the productivity of the
85:42 . And we were kind of taken when we saw that there was not
85:46 correlation. It wasn't what we expected find eyes. Is there a limit
86:05 terms of death for the tensile Because, according to point number
86:10 I was going, I was almost to conclude that it only happens in
86:15 shallow section because of the requirements of law. The Theodoric stress. So
86:23 guess the question is, how how is it toe happen in in a
86:28 section, Or or it's mostly limited the shell sections? No, it
86:35 common in the deeper sections as well the deeper sections just require higher fluid
86:44 . Okay, so in the in shallow section, you can generate those
86:49 low fluid pressure, but you can generate him. It creates depth as
86:54 as you have high fluid pressure. the case of the Marcellus, from
87:09 subsurface data, we saw that one set was present at depths of,
87:15 , you know, 15 to 25,000 . So they're still forming at those
87:20 depths. It just requires high food to do that. Have you seen
87:52 asked one last question. Have you a correlation between discreet fracture network modeling
87:58 and any I mean, have you worked or done any DFM work or
88:03 any products from that? And correlated back to, like, maybe micro
88:06 maker etcetera for for some of these fractures or induced fractures, I haven't
88:16 it for induced tractors. I've seen lot of it from Oman incorporated reservoirs
88:26 naturally fractured reservoirs. Mhm. And there it's it It's a little bit
88:37 because they're they use the production data , uh, to help constrain
88:43 The fracture intensity and the extent of discreet fracture networks is mhm. So
88:56 , uh I'm not sure of the predictive value of those defense, I
89:06 if you have ah dfm with a of calibration wells, then you have
89:10 good control points and it should be . And yeah, I've seen that
89:18 natural fractures, but not for induced . Yeah. So the E
89:23 The study was they had fiber, , around some world wars, her
89:29 wells, cyber case, cyber And they're monitoring the wells while they
89:33 completing them. And then they were to link that back toe some of
89:36 models that they had for the section they drilled it to see if,
89:43 , they thought their FRACKED network is to do what? They thought their
89:47 models were. Correct or not? , that would be interesting to
89:53 I haven't I haven't seen any results that. Mhm. It sure would
89:57 an interesting, interesting study. Did see? Were they able to conclude
90:04 from that? That is actually really . So you could It's called Alexa
90:08 company and the, uh, you monitor it real time. So it's
90:13 a zoo long as the fibers live it stays in the well permanently because
90:17 cemented casing. Um, you could with it something that the life of
90:22 are like Indian hot basins. It's very, very good, but but
90:26 can definitely see communication and really what trying. They see large liniment that
90:31 correlate from maybe seismic or known But some of the interesting is to
90:37 to see what fracture networks are outside what you can see in seismic or
90:41 what you video? Uh huh. know, I know. In the
90:54 chalk, the contribution of the fractures ah is a big unknown. A
91:01 question that the the well productivity suggests lot more contribution from the fractures then
91:13 we would expect, given the given amount of data that we have constraining
91:17 fractures, given what we think is fracture intensity, Um, and I
91:23 know where that is heading. We the we did something very similar in
91:28 bacon where you have metal baking wells 34 12 and say we did for
91:33 wells per section. And when we completing our, uh, middle blocking
91:38 , you would you would start. the first five or six stages for
91:42 three foreclose pressure up the system is the assumption was. And then you
91:47 fracking your middle blocking wells and then know you track, you know simultaneously
91:52 that, but you get it, get a jump start a couple stages
91:55 your three forks walls is all used do this interest. And they were
92:00 lower Well, so the thought process you. You pressure at the lower
92:03 . So you're so you don't lose middle blocking. Frank's just,
92:08 because you've got the upper blocking layer it. So we thought that all
92:11 our fax we're gonna be probably getting instead of going up? Yes.
92:19 did the what did the declines look in the bacon? They are insanely
92:24 and like, there was saying we to go from from nothing to a
92:28 like open choking in almost 48 are think it was a lesson. 48
92:34 sometimes. And so they're Declines are . I think we had some.
92:39 were 11,000 b o E. In hour period. And then,
92:45 I mean that I think they drop . I mean, 200 say level
92:49 like 15 1600 barrels after 90 Something like that. Water cuts aren't
92:56 . The water cuts are really First like 10%. And then,
92:59 you get once you hit bubble point drop off the light or they are
93:02 Sorry. It comes up to Yeah, it comes up pretty
93:05 It's pretty, very substantial. Um, it's interesting. In the
93:14 , those water cups stay fairly They you get that initial high,
93:19 then it declines rapidly, and then just plateaus. But and most of
93:23 wells, it doesn't increase again. just keeps slowly declining. Yeah,
93:29 something like it's the same story in Austin chalk in Louisiana. There's that
93:33 play, that Kanako and Marathon um E I think there was one
93:38 player that used to be in but the wells air 1000 barrels a
93:42 , but 90% water, so and , yes, Mhm. You
93:55 I was afraid that would be a for the Permian. That just the
93:59 disposal problem? Well, that's got . That's got its own set of
94:07 . So they a lot of that is, um, is truck north
94:12 Dallas and over and across the border Oklahoma and, uh, injected in
94:18 deep injection wells. And when they that, they see, um,
94:25 earthquakes. And you can imagine what just went through that. When they
94:29 that water down and pressure up whatever they're putting it into, they're going
94:35 . They're gonna induce small faults and from pressuring up those reservoirs. You
94:49 , actually, if you if you're . If the, uh, Oklahoma
94:53 , like, a Twitter page and have a really good map on
94:56 Okay, g s website, and you could has a really good
95:01 map that you can watch all of . I think it SAARC live web
95:04 . You can watch all the and it's pretty much every about 15
95:07 minutes. There's person that there's some right now. Maybe not so much
95:12 year, since there's been less but Okay, Wow, that's That's
95:20 That's pretty intense. Every 15 20 . I'll have to go look for
95:25 . That sounds entertaining. I was looking at some production from some of
95:39 well that I steered in the Eagle and some of the better ones.
95:45 know, they'll come on with the joke it 3 400 barrels of oil
95:51 day, and then I'm looking at one. That's about 18 months
95:57 and it's doing about 100 under barrels day. Mhm at 64th. So
96:06 Net's. That's a pretty aggressive decline . That's one of the better
96:09 too. Stuff in that part of eagle food. I have a
96:28 Um, Professor, were you involved ? Are you familiar with? I'm
96:33 you're familiar with it, but shell the U shaped lateral the horizontal.
96:42 you shape letter? No, nothing that. Yeah. Shell drill the
96:46 , it's kind of really interesting on went like that. Sorry. And
96:55 ? They did it. It was U shaped well, so if they
96:58 they drilled the well, they landed . And they kicked all the way
97:02 and they drilled all the and then frack this half. They skipped the
97:05 stages, and then they frack the half. So the theory was instead
97:08 putting four wells, are you four or two wells in the section?
97:13 this real one. Well, not heal section of one of the wells
97:18 then just complete the laterals on both them. How? How far
97:23 With laterals. Um, let's I'm not sure what? The space
97:30 requirements for the basin that they were that would have that would. I'm
97:34 to think I don't really know. stopped my head. I'm sure it
97:36 have been too far because I don't what the deviation was on the curve
97:40 when the bend. But you should it up. I think there's a
97:43 sure there's an article out there on , but a friend of mine worked
97:46 the company that they did all the data for on, uh, they
97:49 it was really, really interesting. . Did they? Did they see
97:56 between the laterals? Oh, for . Especially in the hell section.
98:01 , I just thought up an It says it's about 1300 ft between
98:05 two. It's interesting. I'll have have to dig up some information on
98:25 one. See what I could Mhm. Well, the other the
98:31 one that was supposed to be just magical thing was the cubic play.
98:37 know if you all heard about tell us if Well, I'm
98:41 I'm not too educated on it. gonna have thio the internet right
98:45 but uh, who is it? There's a West Texas thing, of
98:52 . And they just decided to dio treat the rock is a cube and
98:59 just kind of put the wells in this. And the spacing was just
99:04 . I'll probably give me well, of a non starter can't can't really
100:06 anything good on it. But the is that you just drill multiple layers
100:11 the same time and in a cubic , and you just end up with
100:15 insanely close, well, spacing, frack them all together they were in
100:28 in instances like that in the where there's getting to the point where
100:32 where they're doing so many in fields because the wealth that originally drilled in
100:36 section they had older completion techniques. instead of going back in and cleaning
100:40 all those cast iron bridge blood, just drill a well right inside of
100:43 and then used updated. So there's instances where I've steered Wells where we're
100:49 over top of one well, and drilling this section and then finishing the
100:54 above the next. Well, so you've got multiple anti collision hazards Just
100:59 in one section at one World I had a question, JD.
101:30 until unless I was pulled up. you. Um, I'm still
101:39 Okay. Yes. So, Steve did this project where and, um
101:45 , the company didn't want to spend on any new data sets thio figure
101:52 out. So what they did was took my law gas shows from the
101:56 bore. Yeah, from the And we would say any time that
102:00 saw, um, and he just spikes in total gas, not
102:07 We normalize it for some other drilling . R a p and cork and
102:13 pump speed, that kind of We did a correction for that.
102:16 then we just tried to figure out the, um, fracture networks,
102:23 , or like, large fracture networks , um, contributing to the
102:27 And we thought maybe by seeing some those gas shows along the lateral,
102:30 could help correlate different. Let me that, you know, they may
102:34 in communication. So you think that it was kind of a rough science
102:40 we couldn't make much of a but you think that would be,
102:43 , justifiable, you know? I think that's I think that's
102:48 Um, when? What? When we drilled through service. Seismic
102:57 faults. And the especially the damage around those faults. We often
103:03 um, gas shows even take And so those who's false and damaging
103:11 definitely contributing, um, to the in the well for sure.
103:38 J d. Any luck? I'm really striking out here. I
103:51 even remember the company that was pioneering . Forget it. Forget I ever
103:57 it. It's not happening. Uh . Yeah. All right.
104:05 if you do stumble on it, could bring it up in one of
104:07 next sessions. There's obviously a lot interest. All right, so,
104:22 , I'll wrap up there for the . If you have any more comments
104:26 questions or discussion points, we can with those, but, um,
104:31 gone through everything that I wanted to for the day. So,
104:35 we'll wrap up unless you have anything you want to discuss. I put
104:50 article I found in the check. was it was in Kana that was
104:55 it is everything that we went through today. What's gonna be on the
105:08 room or is also stuff on next ? Gonna be included. Also stuff
105:13 next Friday? Yes, from And go through. We'll go through a
105:20 of everything. The last session, couple hours before them in term.
105:27 ? And then my my plan for midterm was Thio. Take take two
105:32 . I would email you the test have you email it back to me
105:38 the end of two hours on. I was gonna email it as a
105:43 word document that you could then type or or drawn. And then just
105:50 that Neil, email it back to . That way I could give you
106:03 . Ah, more creative, thought questions. Maybe give you some realistic
106:20 . All right, Good. We'll a good week. I'll see you
106:23 next. Next Friday afternoon. Thanks lot. Thank you. Thank
106:29 Thank
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