JPS63184692A - Well penetrating device - Google Patents

Abstract

(57) [Summary] This bulletin contains application data before electronic filing, so abstract data is not recorded.

Description

Detailed Description of the Invention (Industrial Application Field) The present invention relates to a drilling device for a casing of an oil or gas well;
It is in the field of means and methods. In particular, the present invention uses a high-pressure fluid-driven punch to cut and drill a well casing, followed by a high-pressure jet to cut a passageway into the surrounding formation at a distance outwardly from the casing. This invention relates to a unique device and method for flowing liquid or gaseous hydrocarbons into a casing.

(Prior Art) The majority of oil and gas wells are drilled by rotary drilling methods, in which drilling mud containing very fine particles is placed inside the drilling string or tube row. is pushed downward and released from the bit, removing chips,
It has cooling and other beneficial effects. The most widely used drilling mud material contains fine particles of barite.

The formation surrounding the wellbore was found to be contaminated by drilling fluid between 18 inches and 4 feet from the wellbore. This contamination, consisting primarily of particulate matter from the mud, often poses a significant barrier to the flow of hydrocarbons into the well casing.

A number of approaches have been proposed and attempted in an effort to provide flow passages into the surrounding formations to allow hydrocarbons to enter and increase into the well casing. Probably most methods use a bullet fired from a gun-like device placed inside a casing, but the bullets from such devices usually cannot penetrate beyond the contaminated area, resulting in Usually it was not possible to obtain optimal flow conditions.

Many other proposals have therefore been made for penetrating the surrounding strata. For example, U.S. Patent No. 4.022,27
No. 9 proposes drilling a spiral hole quite far outward from the well casing to increase production. However, since this patent does not show a specific device for opening the desired spiral shape, it is unlikely that such a structure actually exists.

U.S. Pat. No. 3,370,887 shows a fracturing device using a blowing plug, which is blown radially through a well casing by high pressure blown into a housing in which it is mounted. It has become. U.S. Patent No. 3.4(11). No. 980 and U.S. Pat. No. 3,402.965 show a tool projecting downwardly from the lower end of a well casing from which an extendable pipe or hose member descends while injecting high pressure liquid. A depression or hole is created at the bottom of the well.

This patented device is used to mine salt.

U.S. Patent No. 3.402.967 is the aforementioned U.S. Pat.
4(11). No. 980 and No. 3,402.965 show similar devices.

U.S. Pat. No. 3,547,491 shows a device lowered into a well to inject high pressure fluid from a nozzle device. The jet fluid exiting the nozzle device flows through pre-drilled holes in the casing.

U.S. Pat. No. 3,318,395 shows a tool containing a solid rocket propellant body that is lowered into a desired location within a well. This rocket fuel is ignited and exhaust is ejected from a nozzle arrangement, cutting the casing and the cement around it. The propellant from the rocket contains abrasive grains that aid in the cutting action and also create notches in the surrounding structure to weaken it and desirably improve productivity.

U.S. Pat. No. 4,050,529 shows a tool that includes a nozzle device that is lowered into a well casing and jets high pressure water containing abrasive particles to cut the casing and surrounding structures. . The use of abrasive materials permanently contaminates the well and creates wear problems for valves, pumps, etc. used subsequently. The abrasive grains are absorbed into the surrounding structure and close the pores in that tissue.

U.S. Pat. No. 4,346,761 shows a system that includes a nozzle mounted up and down in a casing to cut pores in the casing.

Although the nozzle arrangement does not protrude from the casing, it is clear that the high pressure jet emerging from the nozzle cuts into the surrounding formations.

Among other patents showing high pressure nozzles for cutting well casings are U.S. Pat. US Patent No. RE, 29.021 shows an underground mining system that uses a radial jet that remains within a wellbore to cut surrounding structures. U.S. Patent Nos. 4 and 3
No. 17,492 shows a high pressure water jet type system that is useful in mining and drilling operations because the nozzle that creates the jet moves radially out of the bottom of the well. U.S. Pat. No. 3,873,156 shows a jet-type mining device that can be exited from the bottom of a salt well to create a depression in the well. U.S. Patent No. 4.365.676
No. indicates a mechanical drilling device that can be moved radially out of the well to drill lateral holes. A number of additional U.S. patents describe the use of high pressure nozzle devices to cut formations at or near the bottom of a well, including U.S. Pat. ,0
．． (10) No. 2,271, (11) No. 5, 2.345
, No. 816, No. 2,707,616, 2.758.65
There are No. 3, No. 2,796.129, and No. 2.838.117.

(Problems to be Solved by the Invention) Such conventional devices have not been very successful due to various drawbacks. For example, a device that simply fires a high pressure jet from a nozzle placed inside the casing cannot cut a sufficient distance around the casing. Furthermore, the direction and extent of cutting obtained by such devices are influenced by many parameters, including the properties of surrounding structures, making it difficult to obtain definitive results. One problem that arises with all high-pressure jet devices that operate through the wall of a well casing is that a hole must be drilled through the casing and surrounding cement as a prerequisite for cutting into the surrounding structure. . In some conventional devices, this hole can be drilled by the nozzle jet itself, while in other devices, this requires the use of a separate mechanical cutting device. These devices, which use nozzle jets to cut through the casing, have very serious drawbacks.

That is, cutting fluids often contain abrasive particles that remain in the casing and subsequently cause wear problems on pumps, valves, and other components.

The use of separate mechanical cutting equipment as described above requires significant additional expense both in the cost of extra equipment and in the cost of time to use said extra equipment to cut the casing. There are drawbacks. This requires that such equipment be lowered to the bottom of the well, after which it must be removed, and that the jet device must be placed inside the casing before using the nozzle-jet type cutter. It's understandable if you think about it. Each time a tool is placed or removed from a well, time is expended and the lifting and replacement of tube rows or strings is expensive.
- A common drawback of all types of piercing devices is that they do not adequately drill the outer components of the casing over a sufficient distance to improve productivity. Therefore, it has been desired to develop a device that can effectively drill holes in the strata surrounding the well casing beyond the contaminated area outside the casing.

OBJECTS OF THE INVENTION In view of the above, the main object of the present invention is to provide a novel method and apparatus for drilling holes in a geological structure surrounding a well casing.

(Example) Casing 12 extending downward in oil-containing layer 14
Reference is now made to FIG. 1, which illustrates a preferred embodiment of the present invention as implemented in an oil well 10 having an oil well.

A contaminated zone 16 extending around the periphery of the casing contains drilling mud components that have been forced into the oil-bearing layer during the drilling operation. Still further, the area immediately surrounding the casing typically includes a concrete blanket that is placed in place upon completion of the well.

The present invention includes an elongate downhole apparatus 20 suspended from the ground by a pipe string or bank 22, which includes a plurality of conventional tubular pipe sections, the lowest pipe section being a conventional pipe section. The horizontal stabilizer/anchor (horizontal stabilizer/mooring body) 24 is connected to a structural stabilizer/anchor (horizontal stabilizer/mooring body) 24, and the horizontal stabilizer/anchor body 24 is outwardly adapted to engage with the inner wall of the casing 12 in order to anchor it in a fixed position. Includes a selection actuator that can be extended to The upper end of the elongated pilot hole device 20 is suspended from the horizontal stabilizer/tether 24 by a short tube section 26.

At the upper end of the tube array 22 is a swivel 28 suspended from a refurbishment rig (not shown) or the like by conventional fittings 230, the swivel 28 connecting a high pressure hose 34 to a source of high pressure fluid.
and a low pressure hose 32. Said hose 32.3
4 extends from a vehicle in the form of a trailer 36 fitted with a control cabinet 38 having a control panel 40 . Furthermore,
The trailer 36 is equipped with a motor 37 connected to the hoses 32,34 and driving conventional high and low pressure pumping equipment controlled by the control panel 40. Add unleaked working fluid from the tank trunk 19 and
1) Working fluid enters the pump from a suction pipe 17 extending from a conventional two-stage element filter device 18 which leaks all particles larger than a micron. Said□
The high-pressure pump is a positive displacement pump with five pistons, and has a pulsating discharge type that can adjust the number of cycles.

- The aforementioned elongated pilot hole device 20 is made up of a plurality of connected tubular housing members containing devices for performing various functions. As shown in FIG.
(11) ce cylinder) section 48, lance (
l(11)ce) Section 50. punch compartment 52, punch cylinder
) partition 54 is present.

The filter compartment 44 has an upper part 44A, a middle part 44B and a lower part 4.
Equipped with 4C. Upper portion 44a and lower portion 44C are threadedly connected to intermediate portion 44B as best shown in FIG. 5A. A cylindrical filter 56 is attached to a support sleeve 58 within the upper portion 44a to filter particles larger than one (11) micron that enter the working fluid from the tube array as well as other devices downstream of the filter device 18. .

A guard 60 covering the upper end of the filter 56 comprises a plurality of parallel lower leg members 61 which are fastened to the support sleeve 58 by conventional fastening members 62. The working fluid of this device is usually diesel fuel gas or seawater. The working fluid enters the filter compartment down the tube row, through the upper port 64, from where it descends and then rises inside, through the cylindrical filter 56, into the interior of the support sleeve 58, and from there into the lower port 64. is discharged downwardly through the outlet 64 and from there to the control action section 4.
Enter 6.

The lower end of the lower housing portion 44C is threadedly connected to a tubular connecting member 66 (FIG. 5B) having a relatively thick inner wall 68 with a small diameter hole 70 at the lower end and a large diameter bore 70 at the lower end. It has a central hole 72 with a large diameter, and a large diameter hole 74 at the upper end. A threaded sleeve 76 is attached to the threads of the tapped hole 72 and a high pressure conduit 78 passes through the sleeve 76. The presence of the sealing device 80.82 ensures that liquid passing through the wall 68 can flow through the inner passage 79 of the high pressure conduit 78.

The lower end of the high pressure conduit 78 is screwed to the side wall 84 of a fifth tubular housing part 86 whose upper end is screwed to the lower end of the connecting member 66. A roadway check valve 110 installed under the side wall 84 is connected to the upper end of the discharge pipe 108, and the discharge pipe 10B is equipped with a flow rate restriction device 109 and passes behind the achievator 106, the cylinder 98, etc. The lower end is connected to a rotation control valve 150 (FIGS. 5E and 18A). A second high pressure conduit 9 is attached to a fitting 91 provided on the side wall 84 for connection to the first high pressure conduit 78.
0 is concatenated. The lower end of the second high pressure conduit 90 is a T member 9
2 (FIG. 5C), and from the T member a third high pressure pipe 9
4 and a fourth high pressure pipe 96 extend.

The third high pressure pipe 94 is connected to the lower end of the punch starting cylinder or valve driving cylinder 98, and the lower end of the fourth high pressure pipe 96 is connected to the second T member 1 (11) (FIG. 5D). The upper end of the cylinder 98 is connected to the third T member 10 by a pipe 99.
2, said third T member 102 is connected by a tube 104 to the lower end of a conventional low pressure accumulator 106, said low pressure accumulator is connected to a floating piston 105 (the 18th
It is equipped with an upper high-pressure gas chamber and a lower oil chamber, which are divided by the upper part (Fig. A). At the upper end of the low pressure accumulator 106 is provided an attachment 107, at the upper end of which the upper chamber above the piston 105 can be set to a constant pressure of 70 kg/cj (1 (11) 0 psi) at the surface of the well. Next, the lower chamber is 105kg/ci (15
(11) psi) so that piston 1
05 occupies the center position of the accumulator, and the nitrogen pressure is in equilibrium with the oil pressure. Further, the third T member 102 is connected to the pipe 112.
is connected to a metering valve 114 which is used to initially fill the upper end of the tubes 104, 112 and cylinder 98 with a working fluid in the form of diesel oil before discharging it to the bottom of the well of the system.

Valve drive cylinder 98 actuates rotary converter 116;
The rotary converter alternately operates a conventional rotary valve 118 in one of two locations.

The rotary valve 118 is connected to the second T member 1 (11) by a pipe 120.
and a high pressure inlet connected to tube 185.122.
124 (Fig. 5D). Flow resistor 10
9' and a check valve 110' are discharge pipes 108' and 18A.
As shown in the figure, it is connected to valve 11B. Rotary valve 118
A high-pressure accumulator 126 is located below, which is identical to the low-pressure accumulator 106, but with nitrogen in its upper chamber at the top of the well.
0 kg/cd (2 (11) 0 psi) and connects the tube 128 to the lower end, the conduit 128 descends to the fourth T.
Member 130 (Figure 5E) is reached.

The high pressure accumulator 126 includes a piston 127 that separates its upper gas chamber from a lower oil chamber pressurized to a pressure of 168 kg/c+d (24 (11) psi) and centered approximately around the piston 127. Position and increase nitrogen pressure to the same value. A tube 132 extends downwardly from the T-member 130 for connection to the upper end of the second valve drive cylinder 134, ie, the cut start cylinder 134.

The tube array and accumulator pressures can be adjusted at will to meet different well specifications.

The valve drive cylinder 134 has a piston 136 with a rod 13B, on the outer end of which a roller 140 is mounted, which roller engages a linear guide surface 141 and a slot 142 of the follower 144. engage with. roller 140
Based on the joint action of the guide surface 141 and the piston rod 1
Since the rod 138 cannot rotate about its axis, when the rod 138 reciprocates in the axial direction, the follower 144 and the pore 1
42 causes the follower 144 to rotate. Since the follower 144 is attached to the upper end of the rotary spool 148 of the second rotary valve 150, the piston 13
Actuation of 6 results in rotation of the spool to one of two possible positions to control flow through the valve. Further, the first valve driving cylinder 98 and its counterpart, the first rotary valve 118, have the same structure as the cylinder 134 and the second rotary valve 150 described above.

A pressure pipe 160 descends from the second T member 1 (11) (FIG. 5D), and its lower end is connected to a fifth T member 162 (FIG. 5E). A tube 164 extends from the fifth T member 162 and is connected to the lower end of the second valve drive cylinder 134 . A pressure tube 166 descends from the fifth T member 162 and connects to the inlet of the second rotary valve member 150 . Also tube 170.17
2 is connected to valve 150 as well as pipe 174.

The lower end of the fifth tubular housing section 86 is threadedly connected to the upper end of the sixth tubular housing section 176, as shown in FIG. 5F. A lateral inner wall 178 at the upper end of the sixth tubular housing section 176 includes a fitting 180 connected to the lower end of the tube 122 above the lateral inner wall 178 and connected to the lower end of the flexible high pressure hose 182. connected to the top end. The opposite end of the high pressure hose 182 is connected to a movable cam 256 (
It is connected to a conduit 184 whose lower end is connected to the base 257 (FIG. 13).

Tubes 170, 172 descend from the rotary valve 150 and connect to fittings that extend through the lateral inner wall 178. The lower end of the sixth tubular housing section 176 is connected to the seventh tubular housing section 176.
the seventh tubular housing part 1;
A nozzle drive cylinder 188 is attached to 76 .

A lower end of the tubular housing part 186 is connected to an upper end of the eighth tubular housing part 189. The housing part 18
A hose telescoping retraction drive cylinder 188 attached to 6 is provided with a cylinder head 190;
The lower end of the tube 172 is connected to the tube 172 so that it can communicate with the hole 191 as shown in FIG. 5F. As shown in Figure 5G, a tube 170 connects to the rod end of cylinder 18B. The piston 192 is the piston rod 194
The piston rod 194 includes an axial passageway 196 extending all the way through the piston 192, as best seen in FIG. 5F. The axial passage 196 of the piston rod 194 has its lower end connected to the passage 2 of the connecting block 202.
It turns out that it is connected to 04. A conduit 184 descends behind cylinder 18B.

Shell 208 made of flexible spiral stainless steel mesh
A flexible synthetic nozzle hose 20G consisting of an inner high-pressure plastic tube 209 made of KELVBR (registered trademark of DuPont) is reciprocally connected to the movable carriage block 2 (11). The opposite end of hose 206 turns out to be a support for jet nozzle arrangement 210, as shown in FIG. In any case, the movable carriage block 2 (11) is placed in a perforated metal guide tube 216 attached to a perforated anchor block 212 (FIG. 8) which is fixed to the eleventh tubular housing part 186 by means of a threaded hole 214. Can be put in. A descending perforated metal guide tube 216 is attached at its upper end to the anchor block 212 and is provided with longitudinal perforations 21B along its entire length;
The pores are located in the neck 2 (of the movable carriage block 2 (11)
10) and has a width that allows it to be moved. Pore 21
8 connects the carriage block 2 (11) to the piston rod 19
4 stroke and 4 S, they have enough length to move the same distance.

The upper end of the hole 220 of the movable carriage block 2 (11) is closed, and the lower end thereof is connected to the high pressure hose member 206, and has a plurality of connecting holes 23 as shown in FIG. 5G.
0 to the hole 204. For purposes of detailed description later, axial hole 196, hole 204, outer hole 230.
Cutting fluid for the nozzle jet 210 is routed via 220 . The lower end of the guide tube 216 reaches a transverse wall 232 provided at the upper end of the eighth tubular housing part 203, and the hose 206 extends through a hole 236 in the wall 232. First and second guide tube retainer blocks 222.22 are used to hold the lower end of the guide tube 216 in a fixed position in the housing.
4 is attached to the inner wall of the seventh tubular housing section 186.

The upper end of the eighth tubular housing part 2.34 is threadedly connected to the lower end of the seventh tubular housing part 186. The lower end of the eighth tubular housing section 234 is connected to the ninth tubular housing section 244 by a screw.

A second guide tube 238 descends from the opening 236 and connects the coupling 23 .
0 to the third guide tube 242 as shown in FIG. 5H. The nozzle hose 206 is the guide tube 238.24
2 so that it can move in the axial direction.

The lower end of the third guide tube 242 passes through a hole 250 in a guide plate 252 (FIG. 13), and the guide plate 252 is connected to the upper end of a punch driving cam 256 by a screw 254.
56 includes a base 257 and a longitudinal tube receiving groove 258 for receiving tube 242. The lower end of tube 242 has an inner threaded stub 262 and a removable outer tip 26.
4 and a cam driven base 258 of the punch member 260.
is connected to.

The first and second punch drive cams 256 are provided on a common plane.
The punch extension flat cam surfaces 268,270 respectively engage flat follower surfaces 272,274 of the base end 258 of the casing punch device. In addition, punch drive cam 2
56] drive cam surface 28 for punch extension
0.282 drivingly engages the flat surfaces 284, 286 of the base end 258 of the punch member 260. As a result, when the punch drive cam 256 rises, the punch device 258.2
62.264 is moved outward to perform a punching action. Conversely, when the cam 256 descends, the
As shown in the figure, the dovetail cam surface 29 of the cam 256
0,292 interacts with adjacent planes 293,294 of the base end 258 of the punch device 260 to retract the punch member.

A screw 304 is attached to the base end 257 of the punch drive cam 256.
A piston rod 3 having a connecting head 302 connected with
(11) By moving the punch drive cam 25
Move 6 upward.

Cylinder member 20 with head 310 connected to the upper end with a screw
The lower end of the rod 3 (11) is connected to the piston 306 in the rod 8. The head 310 further includes a threaded sleeve, the upper end of which is threadedly connected to the lower end of the tenth tubular housing section 246, and the upper end of the tenth tubular housing section 246 is threaded to the lower end of the ninth tubular housing section 244. It is connected with. A cylinder head 312 covers the lower end of the cylinder 308 and a protective tip member 314 is attached to the lower end of the cylinder head 312 to remove the tool member 20.
Configure the lower range of .

An axial hole 316 extends through the entire length of rod 3 (11) and communicates with the upper end of cylinder 308, as shown in Figure 5J.

In addition, the rod 3 (11) is connected to the rod 31 as shown in Fig. 5J.
A second hole 318 whose lower end communicates with an annular chamber 320 provided at
It is equipped with The above-mentioned communication is provided by holes 32.0.322.324 provided in the connecting head 257, as shown in FIG.

Similarly, hole 318 communicates with conduit 184 by holes 330, 332, 334.

The casing punch device 2260 is connected to the tubular housing portion 246.
and is oriented radially with respect to the tubular housing portion 246. In addition, the heavy reinforcing cylinder portion 342 is attached to the tubular housing portion 24.
51, with a guide sleeve 340 extending through the cylinder portion 342 as shown in FIG. is welded to the outer surface of the first O tubular housing portion 246 at. As a result, pillow board 3
50 acts to absorb and diffuse the reaction force caused by the punch member moving outward relative to the casing during the drilling operation.

Punch member 260 has an axial hose passageway 353 (thirteenth
), through which the hose member 206 can be extended or retracted.

Grooves 354 are also provided on both sides of the inner threaded stub 262 and outer tip 264 to allow chips to be channeled back into the casing. The outer end of the removable outer tip 264 is defined by first and second planes 356, 358 that intersect along the axis of the punch. A curved passage 362 connects the hose positioning hole 353 to the lower end of the third guide hole 242 to provide a smooth guide path for the hose member 206. Retracting the tip 264 sufficiently after a drilling operation will result in significant lateral forces such as would occur in the event of a failure, and will allow the tip 264 to be severed from the inner stub 262 when an upward force is applied to the tool. It has a structure.

Jet nozzle arrangement 210 includes an axial orifice 374 extending from a central chamber 376 and having a dished diffusion surface 378 .

A rotating sleeve 380 rotatably attached to the outer surface of the nozzle block 372 connects a plurality of diagonal nozzle jets 38.
2, the nozzle jets are each connected at their inner ends to an annular groove 384, which communicates with the central chamber 376 by a radial passage 386 of the nozzle block 372.

A rotating sleeve 380 has a retaining clip 38 that engages the outer end.
8. The nozzle jet 3
The outer end of 82 terminates in an annular dish-shaped diffusion groove 390 on the outer surface of rotating sleeve 380 . The interior of the nozzle block 372 is connected with a plastic inner and outer metal hose jacket member 208 such that high pressure fluid exiting therefrom flows to the central chamber 376 through apparent passageway 394 . A retaining device 396 holds the connection between the hose arrangement and the nozzle body element.

Although the complete working cycle is described, it is understood that it can be used both when penetrating a new well for the first time and when reworking an old well.

The method is the same for both types of work.

The tube bank and all downhole equipment are first pulled out of the well to fill the well with fluid to maintain the total downhole pressure.

Low pressure accumulator 106 and high pressure accumulator 126
respectively 70kg/aj (10, (11)psi)
and 140 kg/cIil (2,(11)0psi)
The device 20 is prepared to be lowered into the well by raising the pressure to . Accumulator 106 and cooperating element 104.102
1 from the valve 114 to the lower end of the first drive cylinder 98 and the upper end of the first drive cylinder 98.
05 kg/aJ (1,5 (11) psi) of working fluid.

Similarly, the lower end of the high pressure accumulator 126 and the cylinder 13
168 kg/d (2,4(11)ps
Add the working fluid of i). It is desirable to ensure that all hydraulic lines, valves, cylinders, etc. are sufficiently filled with liquid to sufficiently prevent the formation of bubbles, and conventional methods are used for this purpose.

The elongated downhole device 20 is then lowered into the well by the tube row 22. A low pressure hose connection 32 fills the section of tube array 20 with fluid when it is added to the top of the well. Said device 2
0 reaches the required depth, hydraulic pressure is applied through the pipe array 22 to activate the conventional mooring device 24 for stabilizing hydraulic pressure, and the hydraulic pressure causes the wedge block 25 to protrude and engage with the inner wall of the casing 12. , thus making the tool casing 1
It can be effectively fixed at two fixed positions.

Also, conventional mechanical mooring devices can be used.

The high pressure hose 34 is then connected to the swivel 28 to increase the pressure applied to the tube row at the top of the well to 280 kg/cd.
(4, (11) 0 psi) and hold at this pressure for about 5 minutes to check for leaks in the device.

If no leak is detected, the pressure is removed and the equipment is considered ready to begin drilling.

During this stage of operation, the parts occupy the positions shown in FIG. 18A and the positions indicated by T in FIG. 19. Especially piston 3
06 is in the lowest retracted position and the punch member 258.
262 and 264 are in the retracted position. piston rod 19
4 is in the retracted position (upper position) and the nozzle jet) 2
10 lies in an axial direction 353 passing through the punch components 262, 264 with a fully covering recess. At time T2 the surface pressure begins to increase and at T, 350k
This is the sum of g/cJ (5, (11) 0 psi) and the pressure drop due to friction loss inside the pipe. This pressure is high pressure pipe 90
18A, thereby increasing the pressure at the rod end of the first valve drive cylinder 98 sufficiently to exceed the nitrogen gas pressure in the accumulator 106, so that the piston in the cylinder 98 is in the extended position of FIG. 18A. Moved from 18th B
The retracted position shown in the figure is reached at time T4.

This movement of the piston within the cylinder 98 moves the valve 118 to the position of FIG. 18B, so that high pressure is applied to the head end of the cylinder 308 and causes the piston 306 and connecting rod 3 (11) to move. The punch drive cam 256 begins to rise. As a result, the punch device 25
8.262.264 begins to approach the wall of the casing, but its speed of movement is controlled by the fact that the discharge liquid from the rod end of cylinder 308 is restricted by flow restriction device 109'. The piston 306 is the 18th A
It takes about 1'A<Ta to T to move from the retracted position shown in the figure to the extended position shown in Fig. 18B.

11), during which the punch member 264 and the like move from the maximum retracted position to the intermediate position shown in FIG. Move to the starting position. Since the pores 354 are present, the tab member 4 (11) is removed by drilling. 402 is bent backwards away from the casing, but remains connected to the casing. Therefore, the part that is removed from the casing to create a hole in the casing remains attached to the casing and does not interfere with the operation of the nozzle jet or the flow of oil from the formation after the drilling operation is completed. cylinder 18
The loft 194 of FIG. 8 remains in the retracted position of FIG. 18 as the punch moves to the extended position because the operating pressure in the high pressure conduit 90 is not high enough so that the head end of the cylinder 134 without the hydraulic pressure in the high pressure accumulator 126 overcoming the gas pressure in the high pressure accumulator 126 and as a result the valve 15
This is because 0 remains at the position shown in FIG. 18A.

After the punch member reaches its maximum extended position, the device is fully stabilized for an additional 1z minutes at 350 kg/c+J (5,000 psi). After the stabilization period has passed, the apparatus is prepared to begin penetrating the nozzle apparatus 210 etc. into the surrounding formations.

The pressure in conduit 90 is set to 525 kg/cd (7,5(
11) Begin the formation penetration operation at T by beginning to increase the combined pressure of psi) and additional pressure losses in the tube train and downhole equipment. High pressure is reached at T7. The increase in pressure has no effect on the position of valve 118, which remains in the position shown in FIG. 18B. However, this high pressure is high enough to move the piston in cylinder 134 from its extended position to the retracted position (reached at Ts) overcoming the gas pressure in high pressure accumulator 126.

As a result, valve 150 moves to the position of FIG. 18 at T, applying high pressure fluid through tube 172 to the head end of cylinder 188, which immediately begins to move from the retracted position to the extended position.

Is the moving speed of the cylinder 188 limited by the bag inside the discharge pipe 10B? 1i109.

When high pressure fluid acts on the head end of cylinder 188 at time T7, piston and rod assembly 192.1
94 begins to move downwardly and outwardly, high pressure fluid flows through passageways 191, 196, 204, 230, 220 into hose member 209, thereby activating jet nozzle arrangement W210 at the outer end of the hose member. The high-pressure jet coming out of the nozzle w210 cuts through the surrounding strata, and the cutting debris blows into the punch member components 262 and 264.
The water flows back into the casing through pores 254 on both sides of the casing. The nozzle jet cleans the end piece 264 of the punch member by activating the high pressure pump to provide pressure pulsations of 2 (11) times per minute at a frequency of 5 (11) times per minute.
1) It becomes the pulsation of times. The velocity at which the nozzle jet enters the surrounding formation is determined by the discharge pipe 170 exiting the cylinder 188.
It is controlled by a restriction device 171 provided at. Hose arrangement 209 and nozzle arrangement 210 eventually reach the maximum extended position of FIG. 4 at time T. As a result, a depression 5 (11) is cut into the stratum 14. Hollow 5 (11
) extends outwardly from the casing, which is somewhat longer than the stroke length of the piston cylinder 188;
This is due to the cutting action of the fluid jet obtained by. The cylinder 188 also extends outwardly from the casing by 450 mm.
It should be appreciated that they can be made long enough to penetrate to depths of 15 feet or more.

The opening device is maintained at a high pressure level for a predetermined period of time appropriate to fully extend the lance jet device.

After this time has elapsed, the pressure in the conduit is reduced to zero. starts at , quickly reaches zero pressure at Tll,
cylinder 98.134 accumulator 106.126
The valve 118.15 is moved to the extended position by the gas pressure of the valve 118.15.
0 is simultaneously returned to the position of FIG. 18A. But part 1
94.256.262.264.306 are all 1B
It remains in the position shown in the figure. This is because there is no hydraulic pressure acting on either piston 188 or piston 308, so that they remain in the extended position shown.

The pressure in the conduit 90 is 280 kg/cA at T1□.
Retract the lancejet device by increasing the pressure to (4,(11)0 psi). 280 in conduit 90
kg/cm (4, (11) 0 psi) pressure is applied to valve 11.
B and conduit 122.182.184.374.332.3
30.318 to the rod end of cylinder 308 and begins to retract piston 306 and its mating punch drive cam 256. Its retraction speed is controlled in an obvious manner by the limiter 319, and the cylinder 308 reaches its maximum retraction position at Tll. Exhaust from the head of the cylinder 308 is discharged through a check valve 110 which discharges into the housing of the device 20;
A small hole (not shown) is provided in the housing to allow exhaust fluid to flow into the casing. Cylinder 188 is also actuated simultaneously with cylinder 30B at T1□, i.e., pressure fluid exiting conduit 90 passes through conduit 170 to cylinder 1
88 and begins to retract the cylinder and nozzle jet hose assembly 209, 210, etc. When this cycle ends at T13, punch member 262.
264 returns to its initial position completely inside the casing and hose member 206 is fully retracted so that nozzle jet 2 (10) is completely encased within the punch member. The pressure in conduit 90 goes to zero at T14, leaving the device either completely removed from the well or reinserted into the well.

The stabilizing mooring device 24 is then released and the downhole device 20 is moved to another location in the casing for the next penetration of the surrounding formations. The tool can be moved by simply rotating it to a new position at the same depth within the casing, or the entire tool can be lowered or raised to a different depth for subsequent penetration operations. Figure 4 shows a second depression 5(11)A shallower than depression 5(11), and a depression 5(11)A located at an intermediate level. 5(11)A and a third through recess 5(11)B located at a different angle. After completing the required number of penetrations, the entire tool is removed from the casing, and production piping and associated pumps are placed in conjunction with the well to allow for the treatment of product flowing out of the surrounding formation 14.

It can thus be seen that the present invention can effectively penetrate much deeper and more accurately into the surrounding formations than conventional penetration equipment. Moreover, the device of the invention is very reliable and problem-free in that the entire operation can be controlled simply by varying the pressure of the working fluid supplied to the tube bank at the top of the well. It does not require sophisticated downhole sensors, control devices, or other highly sensitive equipment.

While preferred embodiments of the invention have been described herein, many modifications will occur to those skilled in the art, and the spirit and scope of the invention should be limited only by the claims.

[Brief explanation of the drawing]

Fig. 1 is a sectional view of above-ground equipment and downhole equipment of the present invention used for drilling gas wells or oil wells, Fig. 1A is a sectional view taken along line A-A in Fig. FIG. 3 is a plan view of a control panel for monitoring and controlling the present invention; FIG. 5A is a cross-sectional view similar to that shown in FIG. 3, but rotated approximately 90 degrees to the left from the position shown in FIG.
A cross-sectional view of the top of the preferred embodiment of the invention along section 5B.
, 5C, 5D, 5B, 5F, 5G. 5H15■, 5J are all cross-sectional views taken along line 5--5 in FIG. 6 is a cross-sectional view taken along line 6--6 of FIGS. 5g and 5h, FIG. 7 is a cross-sectional view taken along line 7-7 of FIG. 6, and FIG. 8 is used for the preferred embodiment described above. FIG. 9 is a cross-sectional view taken along line 9--9 of FIG.
Figure 0 is a cross-sectional view taken along line 10-10 in Figure 9, and Figure 11 is a cross-sectional view taken along line 11-11 in Figure 9, showing the extended state of the casing punch immediately after making a hole in the casing. Figure 12 is a cross-sectional view similar to Figure 11, but shows the arrangement of parts at the initial stage of the casing drilling work, and Figure 13 is a cross-sectional view showing the operation of the casing punch device that punches a hole in the well casing. An exploded view of the punch drive device,
14 is an exploded view of the nozzle device used in the preferred embodiment, FIG. 15 is a perspective view of the nozzle device of FIG. 14, and FIG. 16 is a perspective view of the nozzle device of FIG.
15 is a cross-sectional view taken along line 16--16 of FIG. 15, FIG. 17 is a cross-sectional view taken along line 17-17 of FIG. 16, and FIG. Schematic diagrams of hydraulic and mechanical devices showing the arrangement of example power components;
FIG. 18b is a schematic diagram of a hydraulic system similar to FIG. 18a showing the arrangement of components after drilling the well casing, and FIG. 19 is a timing chart showing the operating cycle of the preferred embodiment. DESCRIPTION OF SYMBOLS 10... Oil well, 12... Casing, 14... Geological stratum, 16... Contaminated area, 17... Suction pipe, 18...
・Filter device, 19...Tank truck, 20・
... Bottom hole device, 22 ... Pipe row, 28 ... Swivel joint, 32 ... Low pressure hose, 34 ... High pressure hose, 36
...Trailer, 37. Motor, 40. Control panel, 44. Filter section, 46. Control action section, 48. Lance cylinder section, 50.
... Lance section, 52 ... Punch section, 54 ... Punch cylinder section, 56 ... Cylindrical filter, 58
...Support sleeve, 66...Connecting member, 68...
Inner wall, 70... Small diameter hole portion, 72... Center hole portion, 7
8...High pressure conduit, 80.82...Sealing device, 106
...Accumulator, 108...Discharge pipe, 109.
...Flow rate restriction device, 110...Check valve, 134...
- Valve drive cylinder, 150... Rotation control valve.

Claims (14)

[Claims] (1) In a well penetrating device for use in a well having a casing; (a) an elongated housing having an upper end and a lower end;
a housing sized and shaped such that the upper end is connectable to a surface-mounted support device and the housing is movable axially within a well casing; (b) an inner end and an outer end; (c) supporting the punch member, the punch member being movable outwardly and having a casing cutting device that cuts a hole in the casing when the outer end is forcibly pressed against the casing; a guide device for movable relative to the elongate housing between a retracted position and an extended position, the outer end of the punch member being positioned generally within the range of the elongate housing in the retracted position; and (d) the elongated housing and punch member are arranged in the well casing when the punch device is in the retracted position. (e) an outer end of the punch device is configured to protrude from an outer surface of the casing when the punch member is in an extended position; a power-operated punch drive for movement between a retracted position and an extended position; (f) coupled to a nozzle apparatus mounted for movement within said punch member between a retracted position and an extended position; a high-pressure liquid jet supply device including a source of high-pressure working fluid, the nozzle device being disposed inside the punch member in the retracted position and the nozzle device being disposed outside the punch member in the extended position; A well penetrating device comprising: the high pressure liquid jet supply device capable of injecting a high pressure jet outward from an outer end of the punch member to cut and remove surrounding strata. (2) The punch member includes an inner nozzle guide passage extending inwardly thereof, and the jet supply nozzle device is disposed within the nozzle guide passage so as to be movable therealong. The well penetrating device according to scope (1). (3) The outer end of the punch member includes two generally flat surfaces that intersect along a transverse line generally perpendicular to the longitudinal axis of the punch member. ) The well penetration device described in section 2. (4) The punch member is additionally provided with a chip removal passage extending along the outer surface of the punch member for conveying soil cuttings generated by the operation of the nozzle device into the casing. A well penetrating device according to claim (3). (5) the high pressure liquid jet supply device includes: (a) a flexible hose arrangement having an inner end connected to the source of high pressure working fluid and an outer end connected to the nozzle for receiving high pressure cutting fluid; (b) moving the hose arrangement to the punch member to move the nozzle arrangement outwardly of the punch member into surrounding soil formations or to retract the nozzle arrangement to a position within the confines of the punch member; The well penetration device of claim 4, further comprising a hose drive power unit for axial movement within the well penetration device. (6) A well penetrating device for drilling a hole in a well casing and surrounding strata, comprising: (a) a support housing having dimensions such that it can be placed in the well casing; (b) a hole in the casing in which said support housing is placed; a power-driven casing cutter device mounted in the support housing for cutting; (c) a cutter drive device; (d) a source of working fluid in the support housing; (e) a cutter drive device;
) a movable conduit attached to the housing and having a first end and a second end for connection to the source of high pressure fluid; (f) a nozzle jet device attached to the second end of the movable conduit; (g) a guiding device for directing the nozzle jet device and a large portion of the movable conduit outwardly through a hole cut in the casing by the casing cutter device; (h) a guiding device for directing the movable conduit and the nozzle jet device a conduit drive for extending or retracting through a hole in a casing; (i) sequentially moving the cutter drive, the nozzle jet device, and the conduit drive in response to changes in pressure of working fluid in the source of working fluid; a control device coupled to the source of high pressure fluid for activation or deactivation. (7) (a) the casing cutter device includes a punch; and (b) the cutter drive device includes a cutter drive hydraulic cylinder drivingly connected to the punch. The well penetration device described in section 6). (8) a device for initiating actuation of the hydraulic punch in response to the pressure of the actuating fluid in the source of actuating fluid being at a first pressure level; a device for initiating operation of the conduit driver to extend the conduit and nozzle jet device from the aperture in response to fluid pressure reaching a second pressure level subsequent to the first pressure level; A well penetrating device according to claim 6, characterized in that it includes: (9) A method for drilling a hole in a well casing and surrounding strata, comprising: (a) positioning a punch member inside the casing at a desired depth alongside the stratum to be drilled; (b) casing; (c) pushing the punch member through the casing to an extended position in preparation for drilling a hole in the casing; (c) moving a jet nozzle arrangement outwardly along a stabilizer of the punch member through the hole in the casing; , simultaneously providing a high pressure fluid jet from the nozzle device to cut surrounding formations, and simultaneously holding the punch device in an extended position through the hole. (10) A patent characterized in that the step (c) is carried out by moving the hose device to which the nozzle device is attached to the outer end along a guide device provided inside the punch member. The method according to claim (9). (11) performing step (b) in response to supplying a working fluid at a first pressure level to the hydraulic control circuit; and performing step (b) in response to supplying a working fluid at a second pressure level to the hydraulic control circuit. The method according to claim 10, characterized in that step (c) is performed. (12) retracting the punch member and the jet nozzle device into the well casing in response to supplying the working fluid to the hydraulic control circuit in stages at a third pressure level and then at a fourth pressure level; A method according to claim 11, characterized in that it comprises the steps of: (13) A method according to claim (11), characterized in that said various pressure levels are obtained by controlling the output of a pump having an outlet connected to said hydraulic pressure control circuit. (14) The order of magnitude of the pressure levels from the lowest to the highest is a third pressure level, a fourth pressure level, a first pressure level, and a second pressure level. ) Method described in section.