CN1039464A - Drill pipe and casing with multi-conduit tubing - Google Patents

Abstract

A multi-conduit tubing for use in drilling operations has fluid conduits and electrical conduits with associated surface fluid and electrical commutators, and downhole sensors for providing instantaneous formation data to surface monitors. Each pipe includes a plurality of uniform linear conduits passing therethrough, and sealing discs with gaskets are arranged between each connected pipe to ensure high-pressure sealing between each connected pipe. The sealing disc has an intermediate electrical connector for connecting the electrical conduit connectors of one pipe to the other pipe.

Description

This invention relates generally to drilling operations and, more particularly, to methods and apparatus for drilling subterranean boreholes, injecting high and low pressure fluids into multiple conduit tubing, and monitoring downhole parameters to control drilling or production operations for optimum efficiency.

The basic drilling operation has remained the same for years, and until now has been a series of connected drill pipes forming a drill string, which rotates to turn the bit and grind away the formation. During the drilling process, various drilling parameters need to be measured, such as drilling formation, formation inclination, temperature, pH value, etc. Obtaining instantaneous downhole data has historically been a problem since the drill string is in many cases rotating thousands of feet below ground.

For example, drilling operations are most efficient when drillers understand formation properties. For different types of formations, such as rock, soil, or fluid and gas layers, it is often desirable to change the way the surface operates to effectively handle the type of formation the drill bit is encountering at the time. For the formation cuttings eroded by the drill bit, the traditional treatment method is to pump fluid down the drill pipe to bring the cuttings to the wellhead through the annular space around the drill string. It takes quite a long time for the cuttings to rise to the ground, so checking these cuttings cannot obtain reliable information on the formation being drilled at that time.

U.S. Patent No. 3,419,092 of Ekhamburg is a known technology related to drilling. This patent adopts a dual-channel drill pipe with inner and outer concentric tubes to pump down the drilling fluid for ventilation in a conduit, so as to reduce the drilling fluid on the drill bit. hydrostatic head, thereby accelerating the velocity of cuttings moving up to the surface in another drill pipe guide. In this way, cuttings representing the type of formation being drilled can reach the surface more quickly, allowing the drilling operation to be changed accordingly. Although the fluid reversing process of the various concentric conduits of the Erborg drill pipe is not too complicated, from the practical point of view of the drill pipe structure, the number of such conduits that can be applied is limited after all.

U.S. Patent 2,951,680 to Kemp et al. teaches that the number of conduits can be increased by using non-concentric multi-conduit drill pipe. But for fluid reversing, the transition of the fluid passage from the conduit to the end of the drill pipe spirals into a generally concentric circular passage. As a result, the Kemp et al. drill pipe, while capable of diverting different fluids into the conduits, complicates the manufacture of the drill pipe and is therefore expensive.

Those familiar with the art recognize the advantages of using multi-conductor drill pipe, but there are a number of reasons why such drill pipe has not found widespread use. One disadvantage encountered in joining such drill pipes together is the manner in which the conduit of one drill pipe is sealed to the conduit of the other drill pipe. Common seals are O-rings or V-rings (US Patent 2,951,680) or conventional seals (US Patent 3,077,358). The type of seal employed and the manner in which the seal is used enable the seal to withstand fluid pressures typically in the range of 7,500 psi partial pressure.

Therefore obviously need to have such a kind of high-pressure multi-tube drill pipe, the number of pipes of the drill pipe is not limited, and the structure or manufacturing process of the drill pipe is not too complicated or the cost is too high.

In addition, there is an urgent need to monitor downhole drilling operations, transmit the results to the wellhead in real time, and to incorporate the transmission media with the drill pipe in such a way that the ability of the drill pipe to carry fluids is not seriously compromised.

In the past, it was proposed to use the central hole of the drill pipe as a small chamber for placing the wire. Examples of this are described in U.S. Patent Nos. 2,795,397 and 3,904,840. But in this way, the insulation of the wires would be eroded by the drilling fluid, or expensive protective devices would have to be used.

The problem that arises with the use of wires in fluid-carrying bores is that of isolating the electrical connectors that join together the lengths of wire from the fluid. To solve this problem, complex and special techniques have been resorted to. The problem is further complicated by the fact that the wires are connected from one drill rod to the other in the form where one section of drill rod is required to be rotated and threaded to another. In U.S. Patent 2,798,358, this is solved by leaving sufficient cable length so that the cable can be twisted together with the drill pipe. In other cases, namely U.S. Patent No. 3,879,097, the cable is carried in the central bore along most of its length, except for ring joints at both ends which pass through the side walls of the drill pipe to the ends of the drill pipe. Obviously, using this technique limits the number of wires.

An example of a current arrangement for joining together multiple wires at each end of the drill pipe is that described in U.S. Patent 2,750,569. In this patent, the cables are routed through fluid carrying holes. This makes the cables and joints susceptible to corrosion or erosion by the drilling fluid.

Another important consideration in drilling technology that affects the total cost of the operation is the composition of the drilling "mud". The density, viscosity or other properties of the mud must be periodically adjusted with different substances and chemicals. This adjustment can only be made gradually as the mud circulates from the bit area up through the surface equipment. In some cases, such as in the case of an emergency blowout, the density of the mud must be changed extremely quickly to prevent this from happening. Therefore, there are many blowouts that cannot be avoided with known techniques. Therefore, it is necessary to manufacture a drill string that can change the drilling mud pressure in time to control blowout or increase the drilling speed.

Even after the drilling operation is completed, from the perspective of mine management, it is necessary to monitor downhole parameters during the production phase. Heretofore, common drilling casings have been highly sophisticated for the wellbore, but extremely poorly equipped for the passage of wires, gases or liquids (except fluids to be pumped up). As an interim measure, telemetry wires have traditionally been secured to the outer perimeter of the casing with metal or plastic bands and run downhole to the telemetry equipment. It is also known to provide additional piping outside the casing for air pressure to form artificial lift holes.

Hence the need to have a multiple conduit drilling casing for pumping process fluids, as well as additional conduits to house telemetry wires and carry solvents, antifreeze solutions and many other fluids.

The present invention provides a method and apparatus for diverting a plurality of high pressure and low pressure fluids through a unique drill pipe having several identical conduits and transmitting electrical signals or power downhole to sensors for gathering information about subsurface formations .

The present invention provides such a multi-conduit drill pipe which is uniform throughout its cross-section and which can be manufactured by extrusion. In cross section, the drill pipe has an outer cylindrical wall, and an inner cylindrical wall defining a central bore, and a plurality of other conduits located between the inner and outer walls.

One of the conduits holds the electrical leads and a connector is secured in the conduit at the end of each drill pipe. Since it may generally be desirable for different fluid or electrical lines to occupy various conduits, an indicator lug and an indicator notch are provided at the other end of each drill rod so that the conduits of each drill rod will remain in place when connected together. in a straight line. In addition to the indicator lugs and notches, each drill rod is provided with a variety of different lugs and notches to allow one rod to drive the other.

The present invention provides a seal with orifices, the shape of the sealing cross-section is the same as that of the drill pipe, and one of the orifices is equipped with an electrical intermediate joint for connecting the electrical circuits of the various drill pipes together. An elastomer on each side of the seal ensures high pressure integrity between the conduits when the drill pipes are connected.

According to another aspect of the present invention, the drill pipes are connected together with a seal between them by a coupling ring with a threaded thread, one end of the coupling ring has an inner threaded thread of uniform diameter, and the other end also has an inner threaded thread of uniform diameter , but each of these coupling rings has a different diameter and thread pitch. Each end of the drill pipe section has a threaded thread having a diameter and pitch corresponding to the coupling ring. This allows the drill rods to be coupled together by partial threading which compressively squeezes the seal between adjacent drill rods to seal.

According to another feature of the present invention, multiple fluids from respective fluid sources are diverted to the various drill pipe conduits using a fluid diverter having a shaft connecting the various fluids Rotating in the manifold of the source. The cylindrical shaft has internal passages, each corresponding to the conduit of each drill rod. Each commutator shaft channel also leads to an inlet hole in the cylindrical side of the shaft. In the passage of the fluid around the various inlet holes (the holes are spaced apart axially along the commutator shaft), there are several corresponding annular grooves in the manifold. Each commutator shaft channel is connected through its manifold groove to a fluid source. With this arrangement, the various drill pipe conduits are in uninterrupted communication with a selected fluid source.

With regard to the relevant features of the present invention, the fluid source diverter shaft is connected to each drill string through a channel connecting each diverter shaft (and thus the fluid source) to a selected one of the drill pipe conduits . In this way, a number of couplings can always be on hand and interchanged with each other to connect various fluid sources through the diverter shaft to a desired conduit in the drill string.

In another aspect of the present invention, the quill portion of the gooseneck faucet has a quill having an electrical connector for terminating the drill pipe electrical leads. A number of slip rings corresponding to the number of wires carried in the drill pipe are arranged around the quill, each slip ring being connected to a wire in the drill pipe. The stationary brush device is in contact with each slip ring, and transmits the electrical response signal downhole to the monitoring equipment on the surface.

As noted above, an improved drilling method is possible in which high-pressure fluids are separately injected into one or more drill pipe conduits to, for example, simultaneously erode the formation, clean and cool the drill bit Or the drill bit path, and at the same time, other low-pressure fluids in other conduits are mixed downhole with gas in other conduits to reduce the hydrostatic pressure downhole. At the same time, each sensor of the drill bit or drill pipe can transmit information about temperature, pressure, inclination, etc. to the monitoring equipment on the surface, so that the information can be applied immediately to change the drilling operation.

Such information can also be used, for example, to control the pressurization of annular fluid or mud, and to prevent blowouts. In addition, according to the present invention, in case a possible blowout is detected, the pump can be activated to apply pressure to counteract the excessive rising flow in the central channel of the drill pipe. In addition, the present invention is also characterized in that the present invention employs an annular pressure accumulator which regulates the pressure applied to the liquid in the annulus of the borehole to maintain a given pressure of the annular liquid. This ability to pressurize the annular fluid in the drilling annulus has the effect of increasing the mud density by eliminating the need to recirculate the mud and add material to increase its weight.

A similar feature of great importance to the present invention is the use of multi-conductor drilling casings which impart a variety of characteristics to the drillpipe, including a generally large central bore which can accommodate large volumes of production fluids, which can monitor a number of downhole parameters, It can simultaneously inject fluid and solution downhole under various pressures, so that the mine can achieve the best productivity, all of which have improved the management level of the mine.

The structure and mode of operation of the present invention will now be described in more detail with reference to the following description taken in conjunction with the accompanying drawings. In the attached picture:

Fig. 1 is the general schematic view of the wellhead and downhole equipment that realizes various aspects and characteristics of the present invention;

Fig. 2 is a partial side view of two drill rods connected together, wherein a part is cut away to show the engagement of the screw thread between each drill rod and the coupling sleeve;

Figure 3a is a transverse cross-sectional view of the multi-conduit tubing taken along line 3-3 of Figure 2 .

Figure 3b is a transverse cross-sectional view of another alternative embodiment of the multi-conduit tubing, showing the configuration of the circular peripheral conduits around the central conduit;

Figure 3c is a transverse cross-sectional view of yet another embodiment of a hollow tube, showing an outer tube, an inner tube forming a central conduit, and a plurality of other tubes forming a conduit arranged peripherally around the inner central tube.

Figure 3d is a transverse cross-sectional view of yet another embodiment of a multi-conduit tubing, showing a set of individual conduits filling one conduit of the drill pipe of Figure 3a.

Figure 4 is a transverse cross-sectional view of the connected multi-conduit tubing taken from line 4-4 of Figure 2;

Figure 5 is an oblique view of a tubular seal in which an intermediate electrical connector is housed;

Figure 6 is a transverse cross-sectional view at the junction of connected pipes, showing the seal and the intermediate electrical connector;

Figure 7 is a transverse sectional view of a tubular conduit with electrical leads, connectors and contacts;

Figures 8 to 10 are transverse sectional views taken along lines 8-8, 9-9 and 10-10 in Figure 7, respectively;

Figure 11 is an exploded oblique view of a tubular end portion ready to be connected to a seal;

Figure 12 is a front view of one embodiment of a drilling derrick showing a gooseneck water hydrant and drill pipe suspended therefrom;

Figure 13 is a lateral side view of a gooseneck faucet showing the arrangement of the fluid and electrical commutators in the casing section together with the drill pipe drive equipment;

Fig. 14 is an oblique view of the fluid distribution manifold and the commutator. A quarter of the manifold is cut away to show the situation when there is fluid transmission in the shaft inlet hole and the annular groove of the manifold;

Figure 15 is a bottom view of the pipe joint of Figure 14, illustrating the situation where two or more drill pipe conduits can be shared with a single reversing shaft passage;

Fig. 16 is a transverse cross-sectional side view of the fluid diverter, showing the connection of the manifold annular grooves to the respective shaft inlet holes, and to the bushing portion through the respective shaft passages;

Figure 17 is a schematic illustration of an electrical slip ring on a quill shaft showing the corresponding brushes for transmitting electrical signals to and from the drill pipe;

Figure 18 is a side plan view of the adapter of the present invention together with the sensing device attached thereto;

Fig. 19 is a longitudinal sectional view of an adapter showing the blocked portion of the fluid conduit for mounting sensors and telemetry devices, the holes of the adapter being arranged around the branch portion of the conduit;

Fig. 20 is a schematic diagram of the symbols of the components of the annular pressure accumulator for applying a specified pressure to the drilling fluid in the drilling annular zone;

Figure 21 is a cross-sectional plan view of a multi-conduit drill pipe and accompanying drill bits, some of which employ high velocity fluids to drill the formation and clean the bit, and other conduits for uploading around the annulus. Low-pressure fluid for sending drill cuttings;

Fig. 22 is another view similar to Fig. 21, in which gas is forced down a drill pipe conduit and out the downhole to reduce the hydrostatic pressure there.

Figure 23 is a schematic diagram of a drilling operation employing liquid and gas reverse circulation and coring techniques;

Figure 24 is a simplified schematic illustration of a multi-conduit tubing employing a drilling casing;

Figure 25 is a transverse sectional view of the multi-tubular drilling casing taken along line 25-25 of Figure 24;

Figure 26 is an end view of the truncated bottom of the drilling casing taken along line 26-26 of Figure 24;

Figure 27 is a lateral side view of the short head of the drilling casing removed from the multi-conduit pump section;

Figure 28 is a partial transverse section view of the stub terminal end of the drilling casing taken through the sensor chamber.

See attached picture now. Figure 1 is an overview of the method and apparatus of the present invention. As shown, the present invention includes a multi-conductor drill pipe generally indicated at 10 driven by a multi-fluid gooseneck faucet 12 . Drill bit 14 can be a wide variety of drill bits available for drilling eroded subterranean formations 16 .

Various downhole sensors such as a temperature sensor 18 or a pH sensor 20 may be employed in the drill bit 14 to collect downhole data and transmit the data to monitoring equipment at the surface via drillpipe wires (not shown in FIG. 1 ). If necessary, the drill bit sensor and the controller of the downhole electrical appliance can also be powered by the power supply 25 .

Liquid pump 24 supplies high or low pressure fluid to the fluid diverter in the gooseneck faucet. Other similar pumps may also be used. In this way, various fluids can be pumped downhole at the same or different pressures to advance drilling techniques to unprecedented levels. Compressor 28 similarly supplies fluid diverter 26 with a gas such as nitrogen for distribution therein to the conduits in the drill pipe to which it is distributed. When the central conduit 32 of the drill pipe is used as a channel for carrying formation cuttings upwards in liquid or gas, the cuttings are carried by the gooseneck hose 34 to the cyclone separator 36, which is effectively separated from the backflow separated from the drilling fluid. A liquid pump 38 is also connected to the gooseneck hose to pump fluid from a fluid source (not shown) down through the central conduit 32 to drill the well or otherwise counteract the blowout in the conduit due to blowout occurring in the well. any undesired fluid flow. Pump 38 may also be used to pump cement or other sealing material downhole to seal the borehole. Valve 40 automatically closes when pump 38 is activated so that the pumped material does not enter separator 36 .

Depending on the desired drilling method, a kill line pump 42 may be provided to pump drilling fluid down the annulus 44 of the well. Annular pressure accumulator 46 maintains the pressure of the annular fluid in the well at a specified value.

As can be seen from the foregoing description, the present invention provides various alternatives for optimizing drilling operations according to conditions. As will become more apparent from the following discussion, the present invention provides an unprecedented advance in technology.

Referring now to Figure 2. It can be seen from the figure that the joined pipe sections, in particular the drill pipe forming part of the drill pipe, and more specifically, the manner in which the end sections of the drill pipe are joined. What Fig. 2 shows is the situation of drill pipe, wherein, a plurality of conduits (the number 30 of one of them) are in the whole drill pipe, thus in passing through the drill pipe that will be drill pipe 50 and another drill pipe 52 together All in joint 48 are uniform. This conduit 30, although shown in Figure 2 as having a slightly larger diameter at the fixed portions 54 and 56 of the drill pipe for strength and sealing requirements, is linear in nature.

The condition of the drill pipe 50 can be seen more clearly from the cross-sectional view of the multi-tube pipe in Fig. 3a. From the point of view of multi-faceted adaptability, it is extremely important in practical application to set up multiple conduits in the drill pipe. All these conduits are linear and can be connected to each other to supply any desired number of liquids or gases downhole. ; Each liquid or gas is isolated from each other, so it can be supplied at different pressures and quantities. For this reason, the present invention proposes a kind of drill rod in the recommended scheme, and this drill rod has an outer sidewall 58 and a concentric inner sidewall 60, constitute central duct 62, most fluid (optional but not necessary) promptly passes through duct 62 pumped. The various longitudinal ducts 30 are interposed between the inner side wall 60 and the outer side wall 58 , forming a longitudinal annular passage between the inner and outer side walls. The radial partition 64 divides the annular passage into a number of separate ducts 30 . Therefore, the entire cross-section of each conduit 30 is trapezoidal, and its curved sides are parallel to each other.

The extremely advantageous point of using this structure is that the drill pipe or drilling casing can be made of extruded aluminum, and its thickened part can be made of steel, or it can be made of high-grade steel. Conduit configurations other than those shown in Figure 32a can of course also be used to meet individual requirements. For example, Figure 3b is another alternative form of multi-conduit tubing. The tube has an outer side wall 66 and an inner side wall 68 by which the central conduit 62 is also bounded. In this form, however, between the inner side wall 68 and the outer side wall 66, a series of ducts 70 of circular cross-section are equally spaced about the central duct 62. This form of tubing is conveniently manufactured by standing the tubing at one end and drilling vertically through the conduits.

FIG. 3c is another form of multi-conduit tubing similar to FIG. 3b except that it consists of a large tube 72 whose outer wall forms the outer side wall and a smaller tube 74 which forms the central conduit 62 . Between the large tube 72 and the small tube 74 are arranged a plurality of tubes 76 of smaller diameter along the circumference. Each tube is thus welded to adjacent tubes at both ends of the tube.

Figure 3d is a pipe improved from 3b. A cylindrical multi-channel insert 78 is inserted into the pipe with several circular conduits 70 on its periphery, fixed by welding or the like. Insert 78 has a central axial passage 80 and peripheral passages 82, all effectively increasing the number of conduits in the tubing despite the reduced diameter.

It can thus be seen that the present invention provides an easily manufactured pipe having a plurality of individual conduits running uniformly throughout the length of the pipe. The following sections describe in detail how to actually use these conduits to optimize drilling or production operations.

See Figure 2 again. The multiple conduit tubing is connected to each other using coupling collars 84 with threaded fasteners. When so connected, seal 86 ensures the integrity of the pressure in each conduit, as will also be described in more detail below. The ends of the drill pipe 50 and the end of the drill pipe 52 have different thread pitches through the threads 88 and 90 between the outer pipe threads 88 and 90 and the outer coupling collar threads 92 and 94 . For example, the end of the drill pipe 50 shown in FIG. 2 may have four threads 88 per inch (.25 pitch), and the end of the tube 52 shown may have five threads 90 per inch (.2 pitch). Coupling collar 84 is similarly threaded and has thick threaded threads 92 for engagement with corresponding threaded threads on drill pipe end 50 and fine threaded threads 94 (five threads per inch) on the other collar end for To engage with the respective fine threads of the drill rods 52 . It should be noted that the thin threaded threads 94 and 90 and the thick threaded threads 92 and 88 of the coupling collar 84 and the drill pipes 50 and 52 are all threaded with the same diameter at their respective threaded portions. But the diameter of the thick threaded button 88 of the drill rod 50 is greater than the diameter of the thin threaded button 90 at the end of the drill rod 52 . The diameters of the coupling collar 84 threads are similar. The fact that the thread diameters are different allows the coupling collar 84 to be unthreaded from the drill pipe 50 to the drill pipe 52 without causing the thick thread 92 of the coupling collar 84 to engage the fine thread 90 of the drill pipe 52 . In this way, the coupling sleeve 84 can be lowered onto the drill pipe 52 until it abuts against the stop flange 96 .

Both threads 88 and 90 are either right-handed or left-handed threads, since each end of the drill pipes shown has a different pitch for differential coupling purposes. When the drill pipes are only connected by coupling collar 84, the threads are preferably oriented such that the rotary action of the drill bit impels the connection between the drill pipes to be tightened. Generally speaking, each thread is turned in a right-hand direction. It should be noted from the above that the other ends of the drill rods 50 and 52 have the opposite pitch and thread diameter to those of the respective drill rod ends. In other words, each drill rod has coarse threads 88 at one end and fine threads 90 at the other end.

The diameter of the coupling collar 84 is also larger than the diameter of the drill pipe it is connected to so that any wear caused against the borehole wall damages the casing rather than the drill pipe. To this end, the drill pipe coupling 84 is made removable from the drill pipe 52 by leaving an annular recessed portion 98 on the coupling end so that it does not engage the pipe threads 90 . As another alternative, the inner thread 94 of the connecting collar can also be extended to the end of the collar. In this way, it is not difficult to remove and replace the coupling collar 84 from the drill pipe 52 when it is severely damaged. Typically, the drill pipe is stored and transported with its coupling sleeves 84 fully up on the drill pipe end against the stop flange 96 for reasons that will be discussed below.

With further reference to Figure 2, in accordance with the present invention the ends of drill rods 50 and 52 are engaged to each other prior to making them threadably coupleable so that drive torque can be transferred from one drill rod to the next. Thus, the driving torque of the drill string is not transmitted by means of the threaded coupling collar 84 . The threaded coupling collar 84 and the drill pipe end therefore do not require conventional conical boxes and male threaded tool joints for torque transmission, such threads requiring expensive cutting dies.

FIG. 4 is a schematic illustration of several drive lugs 100 seated in respective drive recesses 102 engaging coupled drill rods with each other. Referring to FIG. 11 , this is a schematic diagram of the drill pipes 103 and 105 together with their electrical leads 110 . A number of drive lugs 100 on the drill rod 105 and a drive notch 102 (shown in phantom) at the end of the drill rod 103 can be clearly seen from the figure. The interengagement between drill rods 103 and 105 is essentially a staggered arrangement of drive lugs 100 and notches 102 .

One lug 104 of the drill rod 105 and the notches 106 of the drill rod 103 are different in size from the other drive lugs 100 and drive notches 102 . Specifically, lug 104 is an index lug which, in conjunction with index notch 106, allows drill rod 105 to be coupled together in a predetermined desired arcuate or rotational alignment. According to the present invention, the arc alignment between the drill rods of the drill string is of the utmost importance because of the need to keep the drill rod guides in line throughout the drill string. In addition, it is even more important to maintain each drill pipe (such as 103 and 105) in a specific arc alignment, because there is a conduit (electrical conduit 108) equipped with signals and electrical power to the downhole sensors and signals to each sensor. Electrical conductors supplied from sensors or appliances to surface equipment. The term "signal" here also includes electrical energy from sources such as AC or DC sources.

It can thus be seen that not only is alignment between the fluid-carrying conduits necessary, but individual calibration is required since one of these conduits (conduit 108) is fitted with electrical leads. It will be appreciated that when it is desired to convey fluid through each conduit of the drill pipe, only the drive lug 102 is required to keep the entire conduit (not the individual conduits) in line. It is contemplated that in some cases electrical conductors may be provided in more than one conduit.

As mentioned above, being able to receive electrical signals from downhole sensors (such as 18 and 20) in real time during drilling operations and to work in a closed loop mode helps to improve drilling operations to an optimum state. As can be seen in FIGS. 7 to 10 , the electrical conduit 108 of the drill pipe 103 carries three electrical conductors 110 held together in a clamp 112 . The clamp 112 is preferably provided with a cover made of a strong durable material such as Teflon or Giler so that any frictional movement between the clamp 112 and the inner surface 114 of the conduit 108 during drilling does not cause an electrical short.

Each electrical conductor 110 is connected to a terminal terminal block 116 at the end of the drill pipe which has three conductor terminals 118 and their associated pin contacts 120 . Each electrical conductor is soldered to a terminal 118 which is a pin contact 120 for each purpose. Terminal blocks 116 at each end of the drill pipe may be glued or sealed within electrical conduit 108, or secured therein by other suitable means (not shown).

To maintain electrical and fluid path communication between one drill pipe and the respective conduits of the other drill pipe, a seal 86 is provided, as shown in FIG. 5 . Seal 86 is flat and has a cross-section similar to that of the illustrated drill pipe. In detail, the seal of Fig. 5 is similar in cross-section to that of the tubular embodiment of Fig. 3a, made of steel disc-shaped gaskets with gaskets placed between the ends of the drill pipe. Conduit seals for use with the tubing of Figures 3b to 3d can be made by those skilled in the art as described below. As shown in FIG. 5, the seal 8b has a central through hole 122, and peripheral through holes 124 are equally spaced around the periphery. A socket type electrical intermediate connector 126 is fixed in one of the through holes, as shown in FIGS. 5 to 7 . There are several socket contacts 128 at each end of the intermediate connector 126, and the pin contacts of the drill pipe wiring board 116 can be inserted into the socket contacts 128 by friction force to ensure high-quality electrical connection between drill pipes. In addition, both the socket contacts 128 and the pins 120 are plated with gold or other suitable material to protect against oxidation commonly found in drilling environments.

The intermediate connector 126 together with the drill pipe terminal block 116 may be glued or fixed into the sealing disc 86 . Alternatively, the intermediate connector 126 may also have mounting features that allow the connector to “float” within the seal 86 . This allows some leeway for the intermediate connector 126 to move laterally within the seal 86 to accommodate small differences in size between drill pipes that are aligned.

The addition of the sealing 86 and the intermediate connector 126 is the difference between the present invention and the common drill pipe electrical connection. The intermediate connector 126 has the great practical advantage of allowing the end of the drill pipe to be equipped with a pin contact type terminal block 116 . With this symmetrical arrangement, the seal 86 does not need to be oriented face up and can be installed quickly by simply touching either end of the intermediate connector 126 to either end of the drill pipe. In addition, the manufacturing process of the illustrated drill pipe is simplified by simply installing a pin-type terminal block 116 in the electrical conduit at the end of each drill pipe.

Importantly, the seal 86 has a rubber or elastomeric seal or gasket arrangement 130 disposed around each peripheral through hole 124 (including the central passage hole 122). In the preferred form of seal 86, seal 86 has grooves 132 on each front side defining the boundaries of adjacent and central through-holes 124 and 122. To facilitate manufacture of the seal 86 and the elastomeric gasket 130, the groove 132 between adjacent through-holes is common so that the elastomeric gasket 130 is formed in one piece. It can be seen from Fig. 6 that when the collar 84 connects the drill pipes 103 and 105 together and firmly connects them, the elastomer gasket 130 is tightly pressed into its groove to play a highly sealing role, ensuring that each fluid conduit and the electrical conduit Perfection of pressure between. This seal is capable of maintaining an upward pressure differential of 50,000 psi between adjacent conduits. This sealing arrangement is more advanced than O-ring or chevron seals, which can only withstand upward pressure differentials of about 7,500 psi. For clarity, the electrical terminal block 116 in each end of the electrical conduit is not shown in FIG. 6 .

Another advantage of the drill rod of the present invention can be seen in FIG. 11 . As shown in FIG. 11 , coupling collar 84 rests against stop flange 96 (not shown). Coupling collar 84 is of such a length that when it is fully backed onto drill pipe 105, its terminal edge is at least flush with terminal edge 136 of the lug so that such lugs are less prone to breakage or damage during storage and handling. For the same purpose, but also to reduce vulnerable weak points, a continuous cylindrical edge 138 is provided around the terminal end of the mating drill rod 103, together with the drive notch 102 and the indicator notch 106 on its inside surface. Like this, because edge 138 is continuous, thereby the terminal end of this drill rod 105 is not easy to be damaged, and this is our urgent hope; The entire drill pipe becomes unsafe.

From the foregoing, it will be appreciated that a plurality of drill pipes can be quickly and easily joined together to achieve the desired arc alignment, maintaining its fluid passages and electrical conduits intact throughout the drill string.

An important feature of the present invention can be seen from FIGS. 12 and 13 . The drilling operations of Figures 12 and 13 are used to transmit fluid and electrical signals to and from the drill string to surface equipment for transmission. The hoisting device 140 is suspended from cables 142 connected to the derrick frame 144 to securely hang the gooseneck water hydrant 12 above the wellhead (not shown). A cable winch (not shown) is used to coarsely adjust the drill string in the wellbore, thereby coarsely adjusting the weight of the drill bit. The torque stop cable 148 prevents the gooseneck faucet 12 from rotating with the topmost drill pipe 150 .

Vertical fine adjustment of the gooseneck faucet 12 above the wellhead is performed by means of a pair of oil-inflated hydraulic cylinders 152 supporting the sleeve 154 and the flush tube 156 portion of the gooseneck faucet 12 to the lifting device 140 . As shown in Figure 13, hydraulic cylinders 152 each have a piston 158 housed in a partially oil-filled cylinder 160 to maintain the desired bit load. There is an annular seal 162 around each piston 158, which keeps the piston 158 and the oil cylinder 160 sealed, and keeps the oil level above the piston 158, and isolates it from the atmospheric pressure below the piston 158. Hoses 164 couple the upper portion of each hydraulic cylinder 132 to an oil source (not shown) with gas above. It is not difficult to understand that the high gas pressure in the oil source reduces the load on the drill bit. The piston rod 166 of each hydraulic cylinder 158 is connected to the lifting device 140 via a toggle joint 168 . Various fluids are connected to the gooseneck faucet 12 through the high pressure hoses 170, 172 and 174 of FIG. A high pressure hose 176 on top of the gooseneck water cage head allows fluid to be pumped down the center bore of the drill pipe 150 or up the shaft from the center bore.

Components such as the motor transmission of the drill string, the blowout preventer at the wellhead, etc., have little to do with the present invention, and their existence and application are well known to those skilled in the art, so the commonly used components of this type of drilling operations are described in this description and are omitted in the accompanying drawings.

The gooseneck faucet 12 of Fig. 13 is mainly made up of sleeve part 154, flushing pipe 156 and fluid diverter 182, and sleeve part 154 then comprises sleeve shaft 178, and its bottom end is connected to the top with tubular collar 180. The drill pipe 150. A nipple 184 is effective to couple the fluid diverter 182 to the quill 178 . Both the nipple 184 and the quill 178 have fluid passages therein for delivering the desired fluids to the several of the drill pipe conduits. The manner in which the various fluids are diverted to the desired drill pipe conduits will be described in more detail below.

The gooseneck faucet 12 also includes an electrical commutator 186 for maintaining electrical connections to the conductors of each drill string as the drill string rotates. Quill shaft 178 is driven by a gear 188 splined thereto by a hydraulic or electric motor (not shown). The motor drive is mounted in a frame 190 through which the sleeve 178 rotates in bearings 192, 194 and a thrust bearing 195. Shaft 178 is also provided with a suitable oil seal.

A simplified version of fluid diverter 182 is shown in FIG. 14 , wherein diverter shaft 196 is rotatable in fluid manifold 198 and includes the high pressure seals discussed shortly with reference to FIG. 16 . The diverter 196 includes a number of inlet holes 200 and 202 corresponding to the number of fluids desired to be pumped through the various drill pipe conduits. For demonstration purposes, only two fluid sources connected to fluid diverter 182 are shown here. Each inlet port 200 and 202 has a fluid passage 204 and 205 (shown in phantom) in the commutator shaft 196, and such passages have an outlet at the bottom end of the commutator shaft 196. The diverter shaft 196 also has a central bore 208 therethrough through which drilling fluid or the like is conveyed into the central conduit 62 of the drill pipe 150 .

The joint 184 is interposed between the commutator shaft 196 and the sleeve shaft 178, and is fixed between the commutator shaft 196 and the sleeve shaft 178 with the pin 179 and the notch 181 device and the pin nut 183. FIG. 14 is a schematic perspective top view of connector 184 . Adapter 184 has a center bore 210 communicating with commutator shaft bore 208 and two passages 212 and 214 communicating with commutator shaft passages 204 and 206 . FIG. 15 is a schematic diagram of the structure of the bottom edge of the joint 184 . In the illustrated embodiment of sleeve portion 154, it is intended that two different fluids be pumped down the various drill pipe conduits. Accordingly, at the bottom edge of the joint 184, hollowed-out areas 216 and 218 are provided around the respective passageways 214 and 212. With this configuration, passageway 212 can simultaneously deliver fluid to, for example, the other four corresponding quill conduits 222 while passageway 214 is delivering fluid to three corresponding quillway conduits 224 . The non-perforated area 22 on the adapter 184 blocks the remaining conduit 226 in the quill 178 .

Thus in essence the inlet ports 204 of the diverter 196 can distribute one fluid into four adjacent sleeve conduits 222 and thus into four corresponding drill pipe conduits. Similarly, inlet hole 202 may be used to distribute another drilling fluid into three adjacent drill pipe conduits. It should now be clear that a drilling site may provide a variety of joints for distributing fluid from several fluid sources into several drill pipe conduits. This is accomplished by having the area of the site or the recessed portion of the bottom of the joint 184 have a different shape.

In addition, drilling operators can also learn from the teachings of the present invention that more than two fluid sources at different pressures can be used to optimize drilling operations. In this case, the method of modifying three or four inlet port diverters to distribute the same number of different fluids to each drill pipe conduit is clear from the description of the present invention.

As seen in greater detail in FIGS. 14 and 16 , fluid manifold 198 has channels 230 and 232 connected on the inside to respective fluid sources and on the outside to the diverter shaft by means of a pair of annular grooves 234 and 236 . Inlet holes 200 and 202 . Thus, the inlet ports 200 are continuously fluid-communicating as the fluid flows in their respective annular grooves 234 . Likewise, the inlet port 202 continuously conveys another fluid through its annular groove 236 .

Because the fluid commutator 182 bears the fluid pressure limited only to the strength of the connecting hoses 170 to 174 (Fig. 12), it must be arranged to keep sealing between each annular groove 234 and 236 and the rotating commutator shaft 196. special device. The high pressure seal shown in more detail in Figure 16 is used in the fluid diverter 182 of the gooseneck faucet 12 so that various high pressure fluids can be used to facilitate downhole drilling operations. The outer surface of the commutator shaft 196 is coated with ceramic material 240 to provide a strong and durable support surface for the shaft 196 in the fluid manifold 198 .

A high pressure seal 242 surrounds each annular groove 234 and 236 to seal the fluid manifold 198 to the ceramic facing 240 of the commutator shaft 196 . A low pressure seal 243 is disposed at the other end of the shaft 196 . High pressure control fluid is applied to one side of the high pressure seal 242 to counteract the high pressure applied to the other side of the high pressure seal 242 . This reduces the pressure differential across the high pressure seal 242, thereby reducing the likelihood of a pressure blowout. Therefore, a high-pressure sealing fluid inlet hole 244 (as shown in FIG. 16 ) is provided, and its function is to provide high-pressure fluid to one side of each high-pressure sealing ring 242, so as to balance the high-pressure drilling fluid flowing along each drilling conduit on the other side of the high-pressure sealing ring. The pressure generated by pumping down. Low pressure seal fluid outlet ports 246 are provided for returning leakage pressure control fluid equalizing high pressure seal 242 to a reservoir (not shown).

The central bore 208 in the commutator shaft 196 can be sealed by the same high pressure method as described above, which will not be repeated here.

It will be understood that, in view of the foregoing, the present invention enables the drilling operator to selectively inject different numbers of UHP differential fluids into any number of different drill pipe conduits, and to add fluids to downhole equipment, for example, for cleaning or Cool the drill bit, ventilate the drilling fluid, or promote cavitation and erosion of the formation, or a combination of these.

An electrical commutator (186 in FIG. 17) maintains an electrical path between each rotating conductor 110 in the drill pipe and the surface monitoring equipment 22. Drill pipe electrical leads 110 are coupled from the topmost drill pipe 150 and pass through corresponding connectors (not shown) below the quill 178 . The tops of the electrical leads in quill 178 are also connected to connector 250 and finally to connector 252 in FIG. 17 . Here as an example, four electrical conductors are carried in the drill pipe 150 . Four corresponding wires 254 , 256 , 258 and 260 are secured to terminal box 262 . Each of the four wires is routed from terminal box 262 to a respective slip ring 264 , 266 , 268 and 270 . Each slip ring is made of brass or other suitable conductive material, and they are fixed on the quill 178 so as to rotate with the quill 178 .

Thus, the electrical signals carried by the wires 110 from the downhole sensors appear on the rotating slip rings 264-270. Four brushes 272, 274, 276 and 278 are crimped and fixed on respective slip rings so that they have good electrical contact. Each electric brush is stationary, and each brush holder is pressed on the slip ring, as shown in number 280 among the figure. Each brush holder is fixed on the support 282, and support 282 is fixed on the frame of gooseneck faucet again. In support 282, wires, such as 284, are connected to brushes 278 to carry electrical signals to monitoring equipment. The electrical commutator 186 is covered with a protective cover (not shown) to prevent the slip ring from being exposed to the harsh environment of drilling.

Therefore it can be seen that the present invention is provided with a plurality of electrical conductors 110 routed along the drill string to the downhole equipment. The electrical signal from the downhole equipment is immediately available to the surface monitoring equipment 22 so that it can act upon the signal.

Another feature of the present invention can be seen from Figures 18 and 19. This is a schematic diagram of the adapter, which is best suited for use with improved drill pipe to extend its versatility. The transition joint 286 is a short section of the drill pipe, with the casing joint introduced above, and the sensing device numbered 288 is also provided. Specifically, three sensors can be seen from the figure. Pressure sensor 290 , pH sensor 20 and temperature sensor 18 .

Each sensor is electronically controlled and is therefore connected to telemetry or conversion means 292 for converting the physical input values of the sensors into electrical signals for transmission to ground monitoring equipment. As shown, the telemetry unit 292 is wire connected to the electrical wire clamp 112 and extends up the drill string to the slip rings. The wire clamp 112 is disposed in the electrical conduit 108 .

A portion of fluid conduit 294 is blocked with separators 296 and 298 since there may not be a large enough space in electrical conduit 108 to accommodate sensing and telemetry equipment. The blocked portion 303 is connected to the electrical conduit 108 by a channel 297 so that electrical wires can be routed from the electrical conduit 108 to the telemetry device 292 located in the blocked portion 303 . The channel mounting plate 300 fits into the channel opening 302 of the blocked portion 303 of the fluid conduit 294 . Mounting plate 300 is secured to the adapter wall with screws 306 along with washers 304 . The gasket 304 can be an ordinary rubber gasket, because the blocked conduit 303 does not bear too much pressure.

Access to conduit bulkhead 310 is provided with a plurality of adapter holes 308 for allowing fluid to flow from the upper portion of conduit 294 back to the lower portion of conduit 294 through fluid conduit 312 bypassing blocked conduit portion 303 .

To reduce the hydrostatic head at the wellbore, it is common to aerate the drilling fluid. The illustrated adapter 286 thus has an outer vent hole 314 for venting drilling fluid in the wellbore annulus 44 and an inner vent hole 316 for venting the drilling fluid in the center conduit 318 . As shown in FIG. 19, fluid conduits 320 and 322 connected to respective central conduit 318 and borehole annulus 44 through each vent hole are vented with a gas under pressure, such as nitrogen, for internal and external ventilation. It should be understood that a single adapter 286 cannot embody all of the features of the illustrated adapters. In addition, the specially manufactured drill pipe described above may be provided with one or more of the features described above in connection with the adapter.

Sleeves 324 and 326 serve to protect the sensors from damage during storage or downhole use. The sleeve 324 also acts as a stop for the coupling collar 84 .

Adapter 286 thus allows surrounding formation sensors to be installed in the drill string while allowing fluid flow in the various fluid conduits. It should be understood that when adapter 286 is used, the same fluid should be pumped into conduits 294 and 312 as these conduits deliver fluid through orifice 308 .

The annular pressure accumulator 46 can be seen in FIG. 20 . The accumulator 46 allows selective mechanical adjustment of the hydrostatic head of the wellbore to further enhance the integrity of the wellbore and allows for continuous adjustment as subsurface pressures vary. Specifically, the present device prevents events that could lead to catastrophic and costly blowouts. Typically, excessive downhole pressure is counteracted by increasing the density of the drilling mud in the annular space 44 of the borehole. When the pressure is raised too quickly or the drilling operator does not notice the pressure rise, the density of the drilling mud cannot be adjusted quickly enough to prevent a blowout from occurring.

At this time, the annular pressure accumulator can apply pressure to the annular space 44 of the borehole, and quickly change the actual density of the drilling mud 327 to handle this emergency. Annular accumulator 46 has a reservoir 328 connected by suitable piping 330 to the annulus of the borehole. The swivel head 331 forms an annular seal around the drill pipe making the system a closed loop system. The reservoir 328 has a flexible membrane 332 that isolates the drilling mud 327 from the pressurized gas 324 thereon. It can be seen that as the gas pressure on the diaphragm 332, and thus the bit and mud 327, increases, the actual density of the mud increases. The gas pump 336 presses the gas into the gas supply tank 338 with a larger volume, so that the pressure of the gas 334 in the accumulator storage tank 328 can be rapidly increased when needed. The regulator 340 is adjustable so that the pressure between the air supply tank 338 and the accumulator tank 328 can be adjusted. Thus, in the event of an indication that a pressure adjustment is required, the regulator 340 may be opened to increase the gas pressure of the drilling mud 327, thereby increasing the actual density.

According to an important aspect of the present invention, regulator 340 can be made to automatically adjust and be connected to surface pressure monitor 342 to automatically adjust accumulator reservoir 328 in response to transient changes in downhole pressure detected by pressure sensor 290 . In this way, emergency blowout disasters can be detected and prevented early by applying the present invention through a closed-loop system. In addition, the pressure monitor 342 can be used to prime the pump 42 to maintain the downhole fluid level at a desired level.

Having described the apparatus in what we consider to be the most practical and preferred embodiment, an improved method of drilling using this apparatus will now be described. From this point of view, we turn to Figures 21 to 23, which are detailed views of drill pipe and boreholes utilizing various features of the present invention.

Figure 21 illustrates a drilling method that simplifies removal of formation cuttings 347 from a drill bit 348 by a high velocity firing action using a fluid 344 (e.g., a drilling fluid having a first density) pumped downhole in one or more conduits 346 the process of. Debris 347 suspended in the drilling mud is carried up through the borehole annulus 44 to the surface. Drilling fluid 344 is also pumped downhole in other conduits 352 . In these conduits 352, fluid 344 is subjected to much greater pressure than in conduits 346 and is introduced into the drill bit borehole path 354 to erode the formation and/or rapidly clear the borehole path 354 of cuttings 347. A large amount of drilling fluid 356 having a second density can be pumped down along the drill pipe central conduit 358, mixed with drilling fluid 344 in the drill bit area 348, and then the mixed fluid is pressed upward into the wellbore annular space 44 to carry Formation cuttings 347.

So with this multi-tube drillpipe, for the first time in their lives, the drilling operator is pumping drilling fluid downhole at the same time at a pressure high enough to clear the cuttings from the bit, pumping drilling fluid at extremely high pressure to erode the formation, Another low-pressure fluid is pumped downhole in large volumes to force cuttings up into the borehole annulus.

The drilling operation shown in Figure 22 is similar to that of Figure 21, but a transition joint 360 is added, in which pressurized gas 362 is pumped into the wellbore annular space 44 through the external vent 314 in the transition joint 360, so as to give the mixed density The drilling fluid is aerated, thereby reducing the actual density. In other words, the venting process reduces the hydrostatic pressure in bit region 348 . It will therefore be understood that the density of the drilling fluid can be varied rapidly over a wide range between the venting process of the present example and the pressurization of the drilling fluid with the annular accumulator 46 .

Figure 23 shows a coring operation in which high pressure drilling fluid 344 is passed through certain conduits 346 and 352 and applied through nozzles (not shown) to the drill bit area 348 and then through the center conduit 358 of the drill pipe along with formation cuttings 347 reverse cycle together. In addition, the efficiency of the reverse circulation of the drilling fluid 344 is improved by pumping the compressed gas 362 down through the fluid conduit 364 and then venting it through the inner vent hole 316 into the central conduit 358 . Alternatively fluid can be injected into the outer annular space of the drill pipe to properly condition the outer zone.

It is also not difficult to understand that the arrangement shown in FIG. 23 can also be changed by using the drill bit 14 in FIG. 21 . In this embodiment, the size of the cuttings is reduced so that the efficiency of pneumatic transport of the cuttings throughout the wellhead can be improved.

The improved drilling apparatus and method are described above. It is not difficult to understand that the above aspects and features can be combined to further improve the efficiency of drilling operations. For example, other sensors than those described above can be installed on the drill pipe to detect desired formation data, like the pressure sensors described above, and be connected to surface equipment to change the drill pipe operation program. This closed-loop system eliminates the possibility of delayed action or no action at all after the operator receives the information. In addition, this closed-loop system allows for continuous adjustment of any volume of drilling operations, allowing the system to achieve optimum efficiency.

According to an important aspect of the present invention, the following three functions can be separated from each other and thus can be independently manipulated and controlled: (1) maintaining the chemical and pressure integrity of the wellbore, (2) circulation of cuttings, and It is discharged out of the well, and (3) it plays an auxiliary role in cutting or eroding the formation. Therefore, the present invention can use multiple fluids separated from each other and their mixed fluids to perform the above three functions. In contrast, in the prior art, the above-mentioned functions cannot be separated and thus cannot be manipulated or controlled independently.

Another main object of the present invention is to provide a drilling casing with multiple conduits. Multi-tube drilling casing has similar advantages as described above in relation to drill pipe.

Those familiar with the profession understand that even after a mine is in production, a well-crafted mine management plan needs to be followed to ensure maximum mine productivity. The overall production management of a mine to date has historically been limited by the amount of downhole information that can be gathered to change downhole conditions to improve efficiency, and to change pumping operations at the surface to improve efficiency. Very similar to the above-mentioned drilling operation, a high-efficiency mine production closed-loop system can also be realized under the condition that various fluid and electrical signals can be transmitted. In a highly developed production system, the items that need to be understood are the downhole pressure, temperature, flow rate, fluid viscosity and density, fluid pH and so on. It is beneficial to monitor these and other parameters in order to control operating conditions at the surface in order to, for example, control the pressure of gas forced downhole to reduce hydrostatic pressure downhole, and to inject solvents or solutions downhole to dissolve oil or adjust pH. Other solutions can also be pumped downhole at the same time to further affect the formation to release more oil or other materials. In other applications, it may be necessary to inject an alcoholic solution or antifreeze downhole to prevent undesired cold conditions due to the cooling effect of the gas flow.

From the situation introduced above, it can be seen that it is urgent to monitor various parameters downhole while pumping various fluids downhole. Examples 24 and 25 are examples of a multi-conductor drilling casing 366 that can remedy the deficiencies of previous drilling casings in accordance with the present invention. The general performance of the drilling casing 366 and its configuration in connection with the casing to form the drill string are the same as those described above in relation to the drill pipe. Since the various conduits of casing 366 may also carry high pressure fluid, seals 86 (Fig. 27) equivalent to those of Fig. 5 are provided to ensure the integrity of the pressure between the various conduits of drilling casing 366.

In particular, FIG. 25 shows the structure of a cross-section of a drilling casing 366 including a central bore 370 , a plurality of fluid conduits 372 and an electrical conduit 374 with a plurality of telemetry wires 376 . Each telemetry lead 376 is connected to a connector at each end of the electrical conduit and, through the intermediate connector 126 of the seal 86, to a corresponding telemetry lead at each section of the other drilling casing of the drill string. It should be noted that the multi-tube drilling casing 366 of Figure 25 is generally the same as the multi-tube drilling pipe of Figure 3b, except that the drilling casing has a larger tubular cross-section within the diameter of the borehole. In addition, the central bore 370 is slightly larger in diameter to accommodate the large volume of production fluid being pumped up.

Referring to FIG. 24 , the topmost drilling casing 366 is coupled to a wellhead cap designated 378 with a collar 84 . The short head 380 of the wellhead cap is similar in cross-section to that of the drilling casing 366 and is provided with a seal 86 (not shown) and the indication and drive lugs and notches described above in connection with FIG. 11 . Wellhead cap 378 has a plurality of passageways 382 (dashed lines) therethrough connecting each well casing conduit 372 and 374 to a respective fluid or solution source and monitoring control panel 394 . In the illustrated embodiment of the invention, each of the seven fluid conduits 372 of the drilling casing can be connected to a respective fluid source 388 via a fluid distributor 386 . High pressure hose, such as hose 384 shown, connects each wellhead cap passage 382 to an outlet 390 of fluid distributor 386 .

Telemetry wires 376 in electrical channel 374 are coupled to monitoring control board 394 through wellhead cap electrical channel 392 (shown in phantom). The monitoring control board 394 may include various gauges, alarms, curve monitors or amplifiers to convert the telemetry signal into other signals to, for example, actuate a bank of solenoid valves (reference number 396), such as with the fluid dispenser 386 The fluid manifold 397 is equipped with a solenoid valve.

In this way, a closed-loop system is provided in which surface equipment can operate automatically based on changes in downhole parameters detected by various sensors. For example, based on an indication of an increase in the viscosity of the downhole production fluid (detected by sensor 424, discussed in more detail below), the supervisory control board 394 would process the electrical indication and cause one of the solenoid valves 396 to move the alcohol fluid source through the fluid Distributor 386 is coupled to one or more drilling casing fluid conduits 372 to vary the viscosity of the production fluid. Additionally, while the viscosity sensor communicates the instantaneous viscosity of the downhole production fluid to the monitoring control panel 394, one or more other solenoid valves 396 can be actuated or released to increase fluid volume by routing the fluid through other fluid conduits 372 or by reducing pump flow. The number of fluid conduits 372 through which the solvent is sent reduces the amount of fluid pumped downhole.

The above only enumerates the general specific configuration of the solenoid valve 396 and the manifold device, and those who are familiar with this profession can design it separately.

A manually operated button plate 400 may also be provided to manually operate the solenoid valve 396 to allow any fluid to be pumped through any one or more of the well casing fluid conduits 372 .

The wellhead cap 378 also has a central hole (not shown in the figure), through which the pump shaft 402 extends downhole to play a pumping role, and the production fluid is lifted to the surface by means of this pumping role.

The bottommost portion of the drilling casing has a drilling casing stub 404 from which the fluid conduits 372 exit and a number of electrical telemetry sensors. Drilling casing stub 404 may be threadedly coupled to a dedicated multi-conduit tubing 406 containing conventional reciprocating plungers for raising production fluids to the surface.

26 and 27 illustrate various features of the short head 404 of the drilling casing. Seen from the bottom, the drilling casing stub 404 ( FIG. 26 ) includes a screen 408 covering the central hole 370 , the openings of which are sized to prevent sand particles etc. from entering the pumping zone 406 . The screen 408 is made of stainless steel or other corrosion-resistant similar materials, and has a number of holes on its periphery in line with the fluid conduit, so that fluid can be ejected from the bottom of the short head of the drilling casing 404 without being restricted by the screen 408 . The screen 408 is sandwiched between a shoulder 410 of the sub 412 and the conduit terminal head 414 and secured in the drilling casing stub 404 . The conduit terminal tip 414 of the short head 404 has a plurality of fluid conduits 372 , a central bore 370 and an electrical conduit 374 all aligned with corresponding conduits of the multi-conduit drilling casing 366 through the multi-conduit pump section 406 . Additionally, the drilling casing stub 404 has drive and indicator lugs that mate with respective drive and indicator notches on the multi-conduit pump section 406 . As noted above, the seal 86 ensures the integrity of the pressure between each respective conduit of the drilling casing stub 404 and the multi-conduit pump section 406 .

As can be seen in Figure 26, the fluid conduits pass through nozzle holes 416 to the bottom of the wellbore. It can be seen from the figure that nozzle holes with different diameters can be installed according to different needs.

FIG. 27 further illustrates the telemetry wires 376 in the drilling casing stub 404 and the multi-conduit pump zone 406 . Electrical conduit connector 418 , sealed intermediate connector 126 and drilling casing stub connector 420 provide a continuous electrical path between telemetry wire 376 and sensor 422 . An enlarged detail view of the sensor chamber 422 in the drilling casing stub 404 is shown in FIG. 28 . In FIG. 26 , a plurality of sensors are arranged at the end of the sensor chamber 422 , and the number of one sensor is 424 . Sensor 422 has threaded inlets 426 into which external threaded sensor 424 is secured. This arrangement is very similar to the arrangement of the threaded fuse in the gas junction box, except that a packing 428 is provided therein to prevent fluid from leaking into the sensor chamber 422 . The spring loaded sensor contact 430 provides a continuous electrical path between the sensor element 424 and the telemetry lead 376 .

This arrangement is of great benefit because several sensor elements 424 can be pre-selected and fixed in the drilling casing stub 404 to detect individual downhole parameters critical to the production of a certain type of mine. Amplifiers and other detectors on the supervisory control board 394 may be wired to the type of sensors 424 mounted in the drilling casing stub 404 so that individual parameters sensed may be converted or represent useful indications of those parameters. In addition, if it is desired to use more sensor elements 424 and telemetry wires 376 that can be accommodated in a single electrical conduit 374, the telemetry wires and corresponding connectors can be housed in other fluid conduits to expand the capacity of the sensing device.

Referring to Fig. 27, connector 412 secures catheter terminal tip 414 to multi-catheter pump section 406 by means of corresponding inner and outer threads. The multi-conduit pump section 406 has a central hole 432 as a pump cylinder, and the pump plunger 434 reciprocates in the central hole to pump the production fluid upward. The pump plunger 434 has a general perimeter seal 436 to prevent fluid from leaking above and below the pump plunger 434 . During the downstroke of pump plunger 434 , production fluid is forced up to the top edge of pump plunger 434 through passage 440 , open check valve 438 . During the downstroke of the plunger 434, the check valve 438 closes and the production fluid is forced up into a storage tank (not shown) at the surface.

In general, the benefits of using multi-conduit tubing as drilling casing are listed above. Due to the setting of many conduits, there are many passages available at the bottom of the wellbore, so that multiple parameters in the well can be detected, and the total production management efficiency of the mine can be raised to a very high level through various fluid conduits.

Although some of the best embodiments of the drilling method and equipment have been described above with reference to various pipes, conduits, connection methods, etc., it is self-evident that the scope of the present invention can be It is only a matter of engineering choice to make various modifications. Those skilled in the art can even, for example, implement the various features of the adapter directly on the drill pipe or drill bit, and by means of the present invention, they will find it very easy to realize this option. Furthermore, it is not necessary to apply all the advantages of the invention to a composite pipe in order to realize the individual advantages of the invention. Furthermore, it is intended that the scope of the invention not be limited by the above details disclosed in this specification, but be consistent with the full scope of the claims and thus include any and all equivalent devices and methods.

Claims (25)

1. A pipe for drilling and mine production, characterized in that the pipe comprises a long and thin drill pipe, each end of which is suitable for connecting with other similar drill pipes, and there are a plurality of arched intervals in the drill pipe through separate conduits, each of which extends substantially uniformly from one end of the drill pipe to the other, thereby allowing a plurality of different fluids to be transported to or from the wellbore. 2. The tubing of claim 1, wherein said drill pipe further includes concentric inner and outer walls, said inner side walls forming a central conduit of said plurality of conduits, the other conduits of said plurality of conduits being It is arranged radially outside the inner side wall. 3. The tubing of claim 2, wherein said other conduits are defined by an elongated annular passage between said inner and outer walls, a plurality of radial partitions in said passage forming each of said other conduits. The side walls of the ducts. 4. The tubing of claim 2 wherein said other conduits comprise a plurality of separate elongate channels of circular cross-section. 5. The tubing of claim 4, further comprising an elongated insert secured within said one passage, said insert including a plurality of separate elongated passages. 6. The tubing of claim 2, wherein said drill pipe includes an inner cylinder having an inner sidewall defining said central conduit and an outer cylinder concentric with said inner cylinder, said outer sidewall defining said outside of said drill pipe. , then the other conduits are bounded by a plurality of other cylinders fixed between the inner and outer cylinders. 7. A pipe as claimed in claim 1, characterized in that the pipe is provided with indicating means for aligning said pipe with another similar pipe in an arc during connection so that said conduits are aligned in the desired alignment. Some conduits are aligned with corresponding conduits of similar tubing to which the tubing is joined. 8. The pipe of claim 1, further comprising a seal for coupling one said pipe to another like pipe and maintaining the integrity of each of said conduits extending therethrough, said seal Holes are included for connecting respective conduits of one said tubing with another like tubing and for isolating adjacent conduits. 9. The tubing of claim 8, wherein said seal further comprises a disc having a mesh similar in cross-section to an orifice associated with each of said conduits, and a disc on each face of said disc. An elastic body on the top is disposed around the periphery of each conduit port. 10. A pipe as claimed in claim 9, characterized in that each face of said disk has a network of grooves, said elastomeric part being embedded in said grooves. 11. The tubing of claim 1, further comprising an electrical conductor for carrying electrical signals and secured within an electrical conduit of said tubing. 12. The pipe according to claim 11, characterized in that the pipe further comprises electrical connection means disposed in each opening of said electrical conduit for terminating said electrical wire, said connection means comprising a contact, said The electric wire is electrically connected to the contact. 13. The tubing of claim 12, further comprising means for sealing said connector to said electrical conduit. 14. The tubing of claim 8, further comprising an electrical conductor disposed in an electrical conduit of said plurality of tubes, an electrical conductor attached to each end of said electrical conduit with a terminal for terminating said conductor. first and second connectors of the contacts at each end, the second connector being in said seal for coupling a contact of said first connector of said pipe to an electrical circuit of another similar pipe . 15. The tubing of claim 1, wherein said tubing comprises a drill pipe and includes fluid reversing means for coupling each of a plurality of fluid sources to said conduits as said drill pipe rotates The conduit to which you wish to join. 16. The tubing of claim 14, wherein said tubing comprises a drill pipe and includes electrical reversing means for coupling electrical signals from said wire during rotation of said drill pipe. 17. The tubular material of claim 1, further comprising means and pressure means for confining the drill pipe fluid within an annular space of the wellbore formed by said tubular material, the pressure means comprising A reservoir for storing pressurized gas for exerting a desired pressure on the drilling fluid in said annular space, thereby changing the actual density of the drilling fluid in said annular space. 18. The tubing of claim 17, further comprising a pressure transducer fixed to the side wall of said tubing, means for transmitting a signal indicative of well pressure in said tubing, and means for adjusting the pressure applied to said tubing. pressure of said drilling fluid, means responsive to said signal. 19. The tubing of claim 15, further comprising means connected to said fluid reversing means for pumping a first fluid at a first pressure in said first conduit and for passing through said second conduit. means for promoting erosion of the formation by pumping a second fluid through the conduit at a second pressure higher than the first pressure. 20. The pipe according to claim 19, characterized in that the pipe further comprises a closed-loop system comprising a sensor fixed to the side wall of the pipe, a device for transmitting an electrical signal through the pipe (the signal representing a certain drilling parameter) and a controller for controlling a said fluid according to said electrical signal. 21. A management method for production mines, characterized in that the method comprises the following steps: extract production fluids from said mine; Monitoring downhole parameters; transmitting a signal of said parameter to the wellhead; and In response to certain signals of said parameters indicating an out-of-limit condition, the desired pumped fluid is pumped downhole to bring said parameter back to the limit value. 22. The method of claim 21, further comprising: independently pumping multiple fluids downhole according to said overrun conditions. 23. The method of claim 22, further comprising independently pumping a plurality of different fluids downhole. 24. The method of claim 23, further comprising simultaneously and independently pumping a plurality of different fluids downhole. 25. The method according to claim 21, characterized in that the method further comprises monitoring a plurality of downhole parameters at the same time, and pumping fluid downhole according to the exceeding limit of each said parameter, so as to restore each said parameter to the limit value .

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