WO2000058599A1

WO2000058599A1 - Method of and apparatus for horizontal well drilling

Info

Publication number: WO2000058599A1
Application number: PCT/US2000/006084
Authority: WO
Inventors: Carl W. Landers
Original assignee: Landers Carl W
Priority date: 1999-03-31
Filing date: 2000-03-09
Publication date: 2000-10-05

Abstract

A method and apparatus for penetrating a well casing (12) and surrounding earth strata includes the insertion of a flexible shaft having a ball cutter (22) on an end thereof into upset tubing (18) within a well casing. The upset tubing is provided with an elbow (20) at its lower extremity for receiving the ball cutter therein. The flexible shaft is then rotated and the ball cutter cuts a hole in the well casing. The flexible shaft and ball cutter are then removed and a flexible tube having a nozzle blaster (46) on an end thereof is then inserted into the upset tubing in the channel. A first fluid at high pressure is then pumped into the tube wherein the high pressure first fluid passes through orifices in the spiral drill thereby cutting an extension into the previously cut channel. The tube is continually fed into the channel as the high pressure first fluid continues to blast away the earth's strata. The channel is then cut at preselected distance from the well up to 200 feet and beyond. A second fluid at high pressure may then be pumped into the strata to clean out the channel as the flexible tube is backed out of the channel.

Description

METHOD OF AND APPARATUS FOR HORIZONTAL WELL DRILLING

TECHNICAL FIELD OF THE INVENTION

This invention relates to a method and apparatus for horizontal drilling into the earth strata surrounding a well casing. More specifically, the present invention relates to a method and apparatus for drilling through the walls of a vertically extending well casing at a 90° angle to provide horizontal drilling into the earth's strata for a substantial distance radially from the vertically extending well casing.

Oil and gas wells are drilled by the use of rotary drilling equipment vertically into the earth's strata. The vertically extending well holes generally include a casing usually of mild steel in the neighborhood of 4 inch (11.4 cm) to 8 inch (20.3 cm) in diameter which define the cross- sectional area of a well for transportation of the oil and gas upwardly to the earth's surface. However, these vertically extending wells are only useful for removing oil and gas from the general vicinity adjacent to and directly underneath the terminating downward end of the well. Thus, not all of the oil and gas in the pockets or formations in the earth's strata, at the location of the well depth, can be removed. Therefore, it is necessary to either make other vertical drillings parallel and close to the first drill, which is timely and costly, or provide means to extend the original well in a radial or horizontal direction. The most common means for horizontal extension of the well has been to drill angularly through the well casing at a first 45° angle for a short distance and then to turn the drill and drill at a second 45° angle thereby making a full 90° angular or horizontal cut from the vertically extending well. These horizontal drills have proved useful for extending the well horizontally. However, most of these horizontally extending cuts have proved to be relatively expensive. There have been a number of patents issued which teach a number of different ideas for accomplishing horizontal drillings or cuttings into the earth's strata surrounding an existing well, but, again, most of these have proved to be costly and have also not produced the desired results. U.S. Patent No. 4,640,362 teaches a method of penetrating a well casing and surrounding earth strata with the use of a punch member for cutting through a well casing wherein the punch member includes a retractable jet nozzle means therein for penetrating the surrounding earth's strata after the punch member has cut through the casing. Moreover, U.S. Patent No. 4,185,705 teaches a well perforating tool for drilling holes in a well casing which includes an upset tubing with a downward terminating end curving laterally away from its longitudinal axis and terminating in a threaded end portion that passes through a correspondingly shaped aperture formed in the wall of the well casing. Other patents which teach drilling components for horizontal extensions from vertically extending wells wherein hydraulic fluid directing nozzles are used in the drilling operations include U.S. Patent No. 2,271,005; U.S. Patent No. 2,345,816; U.S. Patent No. 3,838,736; U.S. Patent No. 3,873,156; and, U.S. Patent No. 4,168,752.

SUMMARY OF THE INVENTION

The present invention is directed to a method and apparatus for penetrating a well casing and surrounding earth strata. Furthermore, the present invention is directed to a method of penetrating a well casing and surrounding earth strata utilizing a two-step process wherein a flexible shaft having a cutter or cutter head on one end thereof is used to make a cut through the well casing and the second step involves the use of a flexible tube having a nozzle blaster on the end thereof which is then inserted down the well casing into the cut and in combination with a high pressure fluid pumped through the flexible tube and out through the nozzle blaster, a horizontal extension through the cut can then be made up to a distance of more than 200 feet (61 m) . The upset tubing can then be turned from the surface 90° to repeat the process in another direction. One can then cut another hole through the casing and repeat the process up to 4 directions on one level . Many levels can be opened with the same procedure. This invention has application in drilling oil, gas, or water, for example.

More particularly, the present invention is also directed to a method for penetrating a well casing and surrounding earth strata comprising the steps of: inserting an upset tubing having an elbow on an end thereof a preselected distance into a well casing; inserting a flexible shaft having cutting means on an end thereof into said upset tubing, said cutting means extending through said elbow; rotating said flexible shaft and said cutting means cutting a hole in said well casing; removing said flexible shaft and said cutting means from said upset tubing; inserting a flexible tube having a nozzle on an end thereof into the upset tubing and said channel; pumping a first fluid into the flexible tube and nozzle; cutting an extension of said channel in said earth's strata while forcing the flexible tube and nozzle into said channel; and, backing the flexible tube and nozzle out of said channel and simultaneously pumping a second fluid into said channel .

Even more particularly the present invention is directed to a unique elbow used in combination with a ball cutter in an apparatus for cutting an opening in a well casing.

Also, the present invention is directed to the use of novel fluids in the cutting of extensions of channels into the earth's strata and the cut of openings in a well casing.

BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1A is a side elevational view showing a gas or oil well, in section, and the down hole apparatus of the present invention being used in cutting an opening in the well casing;

FIG. IB is a side elevational view showing a gas or oil well, in section, and the down hole apparatus of the present invention being used in extending horizontally the cut in the earth's strata shown in FIG. 1A;

FIG. 2 is an enlarged sectional view of FIG. 1A but with emphasis on the lower portion of the well where a cut into the hole casing is to be made;

FIG. 3 is an enlarged perspective view of the cutting ends of the apparatus of FIG. 2;

FIG. 4 is an enlarged elevational view of FIG. IB with emphasis being placed on the lower end of the well to emphasize the apparatus utilized in drilling an extension into the earth's strata away from the well;

FIG. 5A is an enlarged perspective view of the cutting end of the apparatus of FIG. 4;

FIG. 5B is a perspective view of FIG. 5A with selected portions cut-away, and rotated 90°;

FIG. 6A is an enlarged sectional view similar to the view of FIG. 2, showing a second preferred apparatus for making a cut through a well casing, with emphasis on the lower portion of the well where the cut into the hole casing is to be made;

FIG. 6B is an enlarged sectional view similar to FIG. 6A, showing completion of a cut through the well casing;

FIG. 7 shows the lower portion of the upset tubing and a preferred elbow of the present invention;

FIG. 8A shows an exploded view of a ball cutter connected to its operating means for the apparatus shown in FIG. 6A;

FIG. 8B shows the ball cutter of FIG. 8A connected for operation;

FIG. 9A is an enlarged sectional view showing a third preferred apparatus for making a cut through a well casing with emphasis on the lower portion of the well when the cut into the hole casing is to be made; FIG. 9B is an enlarged sectional view of FIG. 9A showing the completion of the cut through the well casing;

FIG. 10 shows the ball cutter of FIG. 9A connected for operation;

FIG. 11 is a side view of one preferred nozzle blaster of the present invention;

FIG. 11A is an end view of FIG. 11;

FIG. 11B is a sectional view taken along lines 11B-11B of FIG. 11;

FIG. 11C is an enlarged sectional view taken along lines 11C-11C of FIG. 11B; and,

FIG. 12 shows the lower portion of the upset tubing and another preferred elbow of the present invention.

DESCRIPTION OF THE PREFERRED EMBODIMENT

FIG. 1A and FIG. 2 of the drawing shows the employment of a preferred embodiment of the invention in an oil well 10 having a well casing 12 which extends downwardly through the earth's strata 14 into a pocket of oil or gas. FIG. 1A shows the apparatus 16 used in making a cut through the well casing 12.

The apparatus 16 includes upset tubing 18 which extends downwardly through the well casing 12 a preselected distance, the preselected distance being the distance to which a cut into the well casing 12 is to be made and the positioning of the terminating end 18a for the horizontal cut into the earth's strata. The upset tubing 18 may be any upset tubing well known in the art, but at the terminating end 18a of the upset tubing 18 is an elbow 20 (Fig. 7) or elbow 220 (Fig. 12) which is positioned to be rotated to a specific position within the well casing 12 for making the cut therethrough as well as to receive a ball cutter 22 and flexible shaft 24 therethrough. The elbows 20, 220 are generally made from a block of metal usually of octagonal-shape (Fig. 7) or rectangular or square-shaped (Fig. 12) with an opening extending therethrough. The inlets 20a (Fig. 7) , 220b (Fig. 12) and outlets 20b (Fig. 7), 220b (Fig. 12) are 90° to each other. In Fig. 7, inlet 20a has a larger diameter than the outlet 20b, whereas in Fig. 12 inlet 220a and outlet 220b are of substantially the same cross-sectional area. The upset tubing 18 has an O.D. less than the I.D. of the well casing 12 and is usually made of rolled steel. In a preferred embodiment, the upset tubing is metallic and the terminating end 18a is attached to the elbow 20 by welding at the location noted by the numeral 30. The upset tubing 18 is generally mounted onto the head of the well 32. Located at a down hole position just inside the well is a blow out preventer 34 which is generally well known in the oil and gas drilling art wherein blow out preventers are used to prevent the blow back of materials up through the upset tubing at the well head 32.

The ball cutter 22 is coupled to the flexible shaft 24 on one end and shaft 24 on its opposite end is coupled to a fluid driven motor 38 which is suspended down into the upset tubing 18. Fluid returns through exhaust vent on the motor 38 and then flows between flex tubing 48 and the tubing 18, carrying the fluid for the operation of the fluid driven motor 38. The fluid driven motor 38 is, for example, an Ingersol-Rand Model No. DLO 21B-5-P which is operable in response to 1000 psi (70.3 kilograms/sq cm) of hydraulic pressure as delivered through the fluid tube 48. Fluid driven motor 38 generally turns at 500 rpm.

However, in the present operation a reducer 42 is attached to the outlet shaft 44 of the motor 38 wherein the reducer 42 reduces the 500 rpm rotating speed down to generally between 40 to 60 rpm. One preferred ball cutter 22 is a tungsten carbide cutter with a roughened surface and in cutting through the well casing 12 is designed to rotate at a relatively low speed, such as the 40 to 60 rpm noted previously. Operation of the ball cutter 22 of the present invention at a high rate of speed generally makes the cutting through the well casing 12 difficult to control and it has been found that with a rotatable speed of 40 to 60 rpm, the ball cutter can still make a cut in a relatively short period of time, such as in about 15 minutes through a well casing 12 which is 1/8 inch (3.2 mm) thick.

In FIG. IB a preferred embodiment of the present invention is shown wherein a cut in the well casing 12 is utilized as the starting point for drilling a hole into the earth's strata 14 outwardly from the well casing 12. A nozzle blaster 46 is suspended to the oil well 10 wherein the nozzle blaster 46 is threadably attached to the end of a fluid tube 48. Fluid tube 48 may be of an elastomeric or metallic material, but must be capable of withstanding internal fluid pressures of up to and greater than 4000 psi (281 kgms/sq cm) . One preferred tube is a flexible, seamless, stainless steel tubing approximately 0.25 inches (6.35 mm) I.D. and approximately 0.375 inches (9.53 mm) O.D. Alternatively, a flexible, seamless, stainless steel tubing approximately 0.5 inches (12.7 mm) O.D. can be utilized. As best shown in FIGS. 4, 5A, and 5B, the nozzle blaster 46 is provided with a plurality of apertures or nozzles 50 therein, the apertures 50 being dispersed uniformly over the conical portion 46a of the nozzle blaster. The apertures are positioned to provide openings from the inside of the nozzle blaster 46 so that fluid passing from the inside of the nozzle 46 is directed outwardly away from the well casing 12 at an angle, usually about 45°, from the longitudinal axis passing therethrough. In the base portion 46b of the conically shaped nozzle blaster 46, the apertures 50 are also disposed at an angle, usually about 45°, to the longitudinal axis to provide high pressure fluid inwardly towards the well casing 12 thereby keeping the channel or cut open as the nozzle 46 moves outwardly away from the well casing. In a preferred nozzle blaster 46, apertures 50 are approximately .026 inch (6.6 mm) in diameter. It has been found that in wells with old casings, it is possible with the use of a nozzle blaster to jet right through the casing into the formation without the use of a ball cutter. In a preferred nozzle blaster, identified by the numeral 246, and shown in FIGS. 11, 11A, 11B, AND 11C, nozzle blaster 246 is provided with usually three apertures or openings 250 spaced equidistance around the front conically shaped portion 246a of the nozzle blaster 246, the openings 250 being at an angle "y" from the longitudinal axis passing through the nozzle blaster 246. The angle "y" is usually about 45°. Also, nozzle blaster 246 is provided with usually three apertures or openings 252 spaced equidistance around the base portion 246b of the nozzle blaster 246, the openings 252 being at an angle "x" from the longitudinal axis passing through the nozzle blaster 246. The angle "x" is usually about 15°. Fluid flowing from and out through openings 250 blast the earth's strata usually in increments of about 2 inches lateral while fluid flowing from the rear facing openings 252 propel the nozzle blaster 246 forward. Also, the fluid from openings 252 clean the cut hole as the tubing is removed.

As best shown in Fig IB, the fluid tube 48 at its inlet end is in flow communication with a tank container 54 which includes fluid 56 therein. The container 54 is separate and free standing and tube 48 is coiled onto a rotatable drum 60 also mounted on the platform skid 58. The fluid tube 48 is rolled upon or unrolled from drum 60 for use within the oil well 10.

The fluid in the container 54 is generally denoted by the numeral 56 and may be either a first fluid which is used for cutting an extension of a channel from the well casing or a second fluid which is used in backing the fluid tube 48 and nozzle blaster 46, 24b out of the cut extension. In the drilling operation, the fluid 56 may be heated in a heat exchanger 62 also mounted on the platform skid 58 which maintains the fluid in a heated condition. One first fluid may be a mixture of a surfactant and water wherein the surfactant is generally from about 1 to 5% by weight of the total solution. Generally, the temperature of the surfactant water solution is between about 130°F (54°C) and 160°F (71°C) . And, the surfactant is generally selected from a group consisting of water wetters, oil wetters, and surfactants with a sodium salt . One preferred surfactant is a product manufactured by Climax Performance Materials Corporation under the trademark ACTRASOL-MY-75 which is a mixture of sulfonated soybean oil, a sodium salt, and a methyl ester of soybean oil.

Other first fluids include water, as well as a mixture of water with a clay stabilizing agent, such as Haliburton Energy Service's CLA-STA additive. It has also been found that inert gases, such as, for example, air, nitrogen, carbon dioxide, helium, argon, and the like when used at a pressure of 600 to 2000 psi, and preferably at approximately 1200 psi are useful as either first or second fluids in the present invention. Other second fluids include acidic solutions, such as, for example, acetic acid solutions containing from 5 to 20 per cent by weight of acetic acid, preferably about 10 per cent by weight, or a muriatic acid solution containing from 3 to 15 per cent by weight of muriatic acid, preferably about 7.5 per cent by weight. Petroleum distillates have also been found useful as a first or second fluid, but for a second fluid an acidic solution is preferred as the acid solutions clean up the recently formed channels as the tubing 48 is removed. Since most of the strata is generally limestone or the like, the acids leach out or solubilize the recently cut particles within the channels thereby leaving the channels cleared of the channel extension cuttings. The fluids, when being in liquid form, are generally pumped at pressures of 3000 psi to 8000 psi, preferably about 6000 psi.

Also provided on the platform skid 58 is a pump 64 which is, for example, Giant Industries, Model Number P450A which will produce a fluid discharge pressure of up to 5000 psi (352 kgms/sq cm) , or Landers Horizontal Drill Pump which will produce a fluid discharge pressure of up to 10,000 psi (703 kgms/sq cm) or a Kerr Pump Model 3208B Mustang, or the like. Pump 64 mounted onto the platform skid 58 is in fluid communication with the fluid tube 48 for pumping the fluid 56 from the container 54 into the oil well 10 wherein the high pressure fluid 56 discharges through the openings in the nozzle blaster 46 at 3000 to 8000 psi. And, with continual feeding of the tube 48 down through the upset tubing 18, a horizontal drill or cut into the earth's strata 14 in excess of 400 feet away from the well casing 12 is possible.

In operation, the upset tubing 18 having the elbow 20, 220 on the end thereof is lowered into a well casing 12 to a preselected position therein, the position being determined as the location for a horizontal drill into the earth's strata 14. A fluid tube 48 having a fluid driven motor 38 on the terminating end thereof with a reducer 42, flexible shaft 24 and ball cutter 22 extending therefrom is lowered into the well casing 12, 122 until the ball cutter 22 passes out through the elbow 20, 220 until the ball cutter 22 is positioned adjacent to the inside of the well casing 12. A motor driving fluid at approximately 1000 psi (70.3 kgms/sq cm) is pumped down through a fluid tube 48 wherein the motor driving fluid, which is generally a surfactant-water mixture activates the fluid driven motor 38 and in turn the reducer 42. Reducer 42 turns the flexible shaft 24 thereby rotating the ball cutter 22 at approximately 40 to 60 rpm. Within about 15 minutes the ball cutter 22 cuts through the well casing 12 which is usually about 1/8 inch (3.2 mm) in thickness. After the cut through the casing 12, flexible fluid tube 48 is continually lowered so the ball cutter 22 continues moving outwardly into the earth's strata for a preselected distance, generally a distance up to 12 inches (25.4 cm) and preferably only about 1 ^XA inches (3.8 cm) to 2 inches (5.1 cm) . The 1 ^X inches (3.8 cm) is generally sufficient for the starting point for the horizontal drilling or extension of the pre-cut into the earth's strata. The ball cutter 22 is then removed from the upset tubing 18 and wound back up onto a drum 66 on the platform skid 58. The fluid tube 48, including the nozzle blaster 46 on the terminating end thereof, is then lowered down into the upset tubing 18 and is continued to be rolled off of the drum 60 until it extends through the elbow 20, through the opening in the well casing 12 which has been made previously by the ball cutter 22, and to the end of the pre-cut into the earth's strata 14 by ball cutter 22. When the nozzle blaster has reached the pre-cut distance from the well casing 12, pump 64 is turned on and a first fluid is then pumped at a pressure of about 6000 psi from the container 54 through the heat exchanger 62 down into the oil well 10 and out through the nozzle blaster 46. The high pressure first fluid is continually pumped and the tube 48 is continually unwound from the drum 60 until a preselected distance from the well casing 12 is obtained. The high pressure first fluid spewing from the nozzle blaster 46 is capable of cutting through the earth's strata including limestone layers and other softer materials without delay and within 8 to 10 minutes can blast or cut horizontally at least 200 feet.

After the cut is complete, the pump 64 is cut off and restarted with a second fluid mixture being pumped at a pressure of about 6000 psi from a second container 54. Pumping of the second fluid continues for about 20 minutes to clean out the first fluid in tubing 48, then the tube 48 is backed out of the cut channel and re-wound on drum 60, which takes usually about 10 minutes.

FIGS. 6A-8B show a second preferred apparatus 116 used in making a cut through the well casing 12. As with the embodiment of FIG. 1A, the apparatus 116 includes upset tubing 18 which extends downwardly through the well casing 12 a preselected distance, the preselected distance being the distance to which a cut into the well casing 12 is to be made and the positioning of the terminating end 18a for the horizontal cut into the earth's strata. At the terminating end 18a of the upset tubing 18 is elbow 20 which is positioned to be rotated to a specific position within the well casing 12 for making the cut therethrough as well as to receive a ball cutter 122 and flexible shaft 124 therethrough. Again, the terminating end 18a of upset tubing 18 is attached to elbow 20 (Fig. 7) , 220 (Fig. 12) by welding at the location noted by the numeral 30.

The elbow 20 has an inlet 20a and an outlet 20b disposed 90° to each other. Inlet 20a has a larger diameter than the outlet 20b. Between inlet 20a and outlet 20b is a "bowed" channel 20c. This bow makes it easier for the cutter assembly, including cutter 122 and the flexible shaft 124 connecting to motor 138, as explained hereinafter, to make the 90° bend from inlet 20a to outlet 20b. The bottom portion of channel 20c has about a 5° upslope toward outlet 20b.

As shown in Fig. 12, elbow 220 has an inlet 220a and an outlet 220b disposed 90° to each other. Inlet 220a and outlet 230b are of substantially the same cross-sectional area. Between inlet 220a and 220b is a "bowed" channel 220c. The bottom portion of the channel 220c is horizontally aligned with outlet 220b. Also, elbow 220 is of a rectangular or square-shape, but may be any multi-sided shape that fits within the well casing 12.

Referring back to Figs. 6A to 6B, the ball cutter 122 is shown having a shaft 123 extending therefrom. A plurality of preferably stainless steel ball bearings 126 are employed. FIGS. 6A and 6B show seven such balls 126. The endmost ball 126a has opposed bores 130 and 132 for receiving flexible shaft 124 and ball cutter shaft 123, respectively. A bore 134 connects to bore 132 and receives, for example, a threaded set screw 136 to securely retain ball cutter shaft 123 within bore 132. Flexible shaft 124, having for example a diameter of about 5/16 inch (7.9 mm) , has one end secured within bore 132. For example, ball 126a can be hydraulically compressed to secure ball 126a onto shaft 124. Balls 126, other than endmost ball 126a, have diametric bores 128 therethrough, sized so that balls 126 will fit over flexible shaft 124. Springs 125 are placed over shaft 124 between the balls 126 to maintain spacing between each of the balls 126. The end of flexible shaft 124 opposite ball cutter 122 is coupled to a fluid driven motor 138 which is suspended down into the upset tubing 18. As with motor 38 of the first embodiment, fluid returns through an exhaust vent on the motor 138 and then flows between flex tubing 48 and the tubing 18, and carries the fluid for the operation of the fluid driven motor 38. With this embodiment, the fluid driven motor 138 is, for example, a Micro Motor Model No. MMF0002, which is operable in response to 110 psi (7.7 kilograms/sq cm) of air pressure as delivered through the fluid tube 48. Fluid driven motor 138 generally turns at 23 rpm. Therefore, a reducer is not employed with this model. Ball cutter 122 can make a cut in a relatively short period of time, such as in about 15 minutes through a well casing 12 which is 1/4 inch (6.4 mm) thick.

A motor detent insert 143 is secured within the lower portion of upset tubing 18. Motor detent insert 143 has diametrically opposed slots 145 which receive a horizontal detent wing 139 of motor 138. This prevents motor 138 from rotating during operation. For example, insert 143 can be about 12 inches (30.5 cm) in height. Attached within upset tubing 18 about 4 inches (10.2 cm) above insert 143 is a tipper 141. Tipper 141 serves to align horizontal detent wing 139 with diametrically opposed slots 145.

FIGS. 9A, 9B and 10 show another preferred embodiment which is a variation of the apparatus 116 as shown in FIGS. 6A-8B. In this embodiment the ball cutter 122 is replaced by a ball cutter 222. Ball cutter 222 is substantially identical to ball cutter 122 except in size. Ball cutter 222 has a diameter less than the diameter of the steel ball bearings 126 and, particularly ball 126a to which ball cutter 222 is attached in the same manner as ball cutter 122. Moreover, ball cutter 222 has a diameter greater than the thickness of the wall of well casing 12. In this embodiment, the ball cutter 222 is positioned to cut through the wall of the well casing 12, but will not extend into the surrounding earth's strata as the ball 126a will not pass through the cut in the wall casing 12. It is realized that while the preferred embodiments of the invention have been disclosed herein, further modifications to the preferred embodiments will occur to those skilled in the art and such obvious modifications are intended to be within the scope and spirit of the present invention.

Claims

1. A method for penetrating a well casing and surrounding earth strata comprising the steps of : inserting an upset tubing having an elbow on an end thereof a preselected distance into a well casing; inserting a flexible shaft having cutting means on an end thereof into said upset tubing, said cutting means extending through said elbow; rotating said flexible shaft and said cutting means cutting a hole in said well casing; removing said flexible shaft and said cutting means from said upset tubing; inserting a flexible tube having a nozzle on an end thereof into the upset tubing and said channel ; cutting an extension of said channel in said earth's strata while forcing the flexible tube and nozzle into said channel and simultaneously pumping a first fluid into the flexible tube and nozzle; and backing the flexible tube and nozzle out of said channel and simultaneously pumping a second fluid into said flexible tube and nozzle.

2. The method of Claim 1, said second fluid being an inert gas, an acidic solution, petroleum distillate, or water.

3. The method of Claim 2, said inert gas being air, nitrogen, carbon dioxide, helium or argon.

4. The method of Claim 2, said acidic solution being an acetic acid solution containing from 5 to 20 per cent by weight acetic acid or a muriatic acid solution containing from 3 to 15 per cent by weight of muriatic acid.

5. The method of Claim 4, said acetic acid solution being approximately 10 per cent by weight of acetic acid.

6. The method of Claim 4, said muriatic acid solution being approximately 7.5 per cent by weight of muriatic acid.

7. The method of Claim 1, said second fluid being an inert gas at a pressure of 600 to 2000 psi.

8. The method of Claim 7, said pressure being approximately 1200 psi.

9. The method of Claim 1, said second fluid being a liquid at a pressure of 3000 psi to 8000 psi.

10. The method of Claim 9, said pressure being approximately 6000 psi.

11. The method of Claim 1, said first fluid being water.

12. The method of Claim 11, said first fluid including a clay solubilizing agent.

13. The method of Claim 1, said first fluid and said second fluid being the same fluid.

14. An apparatus for cutting a hole in a well casing comprising: a cutter; a flexible shaft having said cutter on one end thereof ; means to rotate said flexible shaft; and, means to position said cutter at a preselected position within a well casing, said means to position said cutter includes an elbow at a terminating end of an upset tubing in a well casing through which said cutter is received therethrough, said elbow being provided with an inlet and outlet opening in flow communication, said elbow being shaped with at least four-sides wherein said inlet is on one side thereof and said outlet is on another side at a 90° angle from said inlet, said opening being of substantially the same cross-sectional area at said inlet and said outlet, said elbow including a bowed channel between said inlet and said outlet, said bowed channel having a bottom portion substantially horizontal with said outlet.

15. An apparatus for drilling horizontally into the earth's strata from an opening in a well casing comprising: a high pressure fluid nozzle blaster; a flexible conduit having a nozzle blaster on an end thereof; means to transfer a first and a second fluid at high pressure to said flexible conduit ; means to position said nozzle blaster in said opening; and, means to feed said flexible conduit through said opening.

16. The apparatus of Claim 15, said second fluid being an inert gas, an acidic solution, a petroleum distillate, or water.

17. The apparatus of Claim 16, said inert gas being air, nitrogen, carbon dioxide, helium, or argon.

18. The apparatus of Claim 16, said acidic solution being an acetic acid solution containing from 5 to 20 per cent by weight of acetic acid or a muriatic acid solution containing from 3 to 15 per cent by weight of muriatic acid.

19. The apparatus of Claim 18, said acetic acid solution being approximately 10 per cent by weight of acetic acid.

20. The apparatus of Claim 18, said muriatic acid solution being approximately 7.5 per cent by weight of muriatic acid.

21. The apparatus of Claim 15, said second fluid being an inert gas at a pressure of 600 to 2000 psi.

22. The apparatus of Claim 21, said pressure being approximately 1200 psi.

23. The apparatus of Claim 15, said second fluid being a liquid at a pressure of 3000 psi to 8000 psi.

24. The apparatus of Claim 23, said pressure being approximately 6000 psi.

25. The apparatus of Claim 15, said first fluid including a clay solubilizer.

26. The apparatus of Claim 15, said first fluid and said second fluid being the same fluid.

27. An apparatus for cutting a hole in a well casing and then a lateral channel outwardly from the casing, the apparatus comprising: a cutter head, a flexible shaft and a motor, said flexible shaft being connected between the motor and the cutter head; a cutting nozzle and flexible hose; an elbow providing an inlet and outlet with a passageway therebetween for the cutter head and the flexible shaft; guide tracks aligned with the inlet to the passageway; said guide tracks guiding the motor for movement of the cutter head and the flexible shaft down the well casing to move the cutter head out the outlet into cutting engagement with the well casing when the motor drives the flexible shaft; said elbow passageway being configured to guide said cutting nozzle and said flexible hose as the flexible hose is fed through the inlet and outlet so that the nozzle can cut the lateral passageway, said elbow inlet being of substantially the same cross-sectional area as said elbow outlet, said elbow passageway including a bowed channel, said bowed channel having a bottom portion, said bottom portion being in horizontal alignment with said outlet, said outlet being disposed 90° from said inlet; and, said motor, flexible shaft and cutter head being removable from the elbow to be replaced by said nozzle and said flexible hose.

28. An apparatus for cutting a hole in a well casing and then a lateral channel leading outwardly from the well casing, the apparatus comprising: upset tubing to be lowered down the well casing and having a lower end; an elbow fixed to the lower end of the upset tubing, said elbow providing an inlet and an outlet with a passageway therebetween and the outlet facing the well casing, said inlet and said outlet being of substantially the same cross- sectional area, said elbow passageway including a bowed channel, said bowed channel having a bottom portion, said bottom portion being in substantially horizontal alignment with said outlet, said outlet being disposed 90° from said inlet . a motor, flexible shaft and a cutter head, the flexible shaft drivingly connecting the motor to the cutter head;

29. An apparatus for use with upset tubing having a lower end in a well casing to cut a hole in the wall of the casing and a lateral channel extending outwardly from the casing, the apparatus comprising: an elbow to be mounted on the upset tubing at its lower end to be lowered into the well casing, said elbow providing an inlet and outlet with a passageway therebetween, said inlet opening upwardly in the upset tubing and said outlet opening outwardly toward the wall of the casing, said passageway inlet being of substantially the same cross-sectional area as said passageway outlet, said passageway including a bowed channel, said bowed channel having a bottom portion, said bottom portion being in horizontal alignment with said outlet; a motor, a flexible shaft and a cutter head, said flexible shaft extending between the motor and the cutter head to provide a rotary drive connection, said flexible shaft and cutter head being movable through the passageway to have the cutter head engage the well casing adjacent the outlet to cut a hole in the casing; and, a cutting nozzle and hose configured to be lowered into the elbow passageway to exit the outlet and cut the lateral channel outwardly from the hole by fluid pressure from the nozzle.