Downhole production enhancement short joint, oil and gas drilling production enhancement joint system and method

Abstract

The present invention discloses a downhole production enhancement pup joint, an oil and gas drilling production enhancement joint system and method, a downhole production enhancement pup joint, comprising a housing, a first medium axial channel, a radial jet channel arranged on the housing, a high-pressure cutting nozzle arranged at the outer end of the radial jet channel, a valve body arranged inside the first medium axial channel and a motor drive mechanism corresponding to the valve body, the valve body is driven by the motor drive mechanism to close or connect the radial jet channel with the first medium axial channel, and then the switching between the high-pressure cutting nozzle and the rock breaking nozzle of the drill bit is completed to perform different operations. The use of the technology of the present invention can improve the drilling efficiency and the reliability of the drilling production enhancement joint operation.

Description

Technical Field

[0001] The invention belongs to the technical field of oil and gas exploration, and in particular relates to a downhole production-increasing pup joint, an oil and gas drilling production-increasing joint system and a method. Background Art

[0002] my country has abundant reserves of low-grade resources, mainly low-permeability, accounting for more than 45%, which is the key area and direction of current oil and gas exploration and development. Compared with medium and high permeability oil and gas reservoirs, low permeability and ultra-low permeability oil and gas reservoirs have the characteristics of narrow pores, poor connectivity, and low permeability, which makes it difficult to achieve economic and effective development.

[0003] At present, the development of low-permeability and ultra-low-permeability oil and gas reservoirs generally adopts a combination of horizontal well drilling and staged fracturing, but there are still problems such as low recovery rate and single well production capacity, poor economic benefits, and high development costs. At present, the exploration and development of low-permeability oil and gas is gradually developing in deep layers. The rock is densely cemented and the drillability of the formation has deteriorated. Downhole accidents such as well collapse, well leakage, and drill jam are prone to occur during the drilling process, resulting in frequent drilling and drilling, resulting in long drilling cycles and high costs. In addition, low-permeability and ultra-low-permeability reservoirs have poor physical properties, strong heterogeneity, low reservoir drilling rate (referring to the percentage of wells that drill oil (gas) layers to the total number of wells in the statistical area), and great difficulty in mobilization. After drilling the horizontal well, it is necessary to pull out the tubing, then put in the completion tubing and perform staged fracturing to obtain economic benefits. The construction process is complicated and the well construction cycle is long.

[0004] The coiled tubing micro-borehole drilling technology has small borehole size, low drilling equipment power, no need to connect single pipes, low ground condition requirements, and uninterrupted drilling operations. It has the advantages of low operating cost, high operating efficiency, wide trial range, and easy technical integration. It is an important means to reduce development costs, improve development efficiency, and change development methods. At present, the coiled tubing electric drilling rigs and supporting equipment are gradually improving, the performance of the coiled tubing material is constantly improving, the coiled tubing downhole drilling tool combination has been formed, and the drilling control technology is developing rapidly, which provides a foundation for the coiled tubing micro-borehole electric drilling technology.

[0005] In the prior art, in order to achieve the purpose of increasing production during the exploration and development of low permeability oil and gas reservoirs, a downhole production increase short section is arranged at the rear end of the drill bit. The structure of the downhole production increase short section is as follows: Figure 1 As shown, Figure 1 The schematic diagram of the structure of the downhole stimulation short sub in the prior art is as follows: Figure 1As shown, the downhole stimulation sub comprises a housing 1 and a channel switching valve body 2 disposed in the housing 1, and the channel switching valve body 2 can move in the axial direction in the housing 1. In addition, the channel switching valve body 2 has an axial hydraulic channel 21 extending in the axial direction and a radial hydraulic channel 22 extending in the radial direction. The housing 1 is provided with a radial jet channel 11 corresponding to the radial hydraulic channel 22, and a radial jet nozzle 12 is provided at the outer end of the radial jet channel 11. The housing 1 is also provided with a drilling hydraulic channel 13, and the drilling hydraulic channel 13 can be communicated with the axial hydraulic channel 21. The downhole cutting pup joint is connected to the downhole power drill, and the ground control system is in communication connection with the downhole cutting pup joint; during the drilling process, the radial hydraulic channel 22 is staggered with the radial jet nozzle 12, and the radial hydraulic channel 22 is closed. At this time, the axial hydraulic channel 21 is connected with the drilling hydraulic channel 13, that is, the drilling hydraulic channel 13 is opened; when it is necessary to perform a production increase operation, the ground control system issues an instruction to apply an axial force to the valve body by hydraulic means to push the channel switching valve body 2, so that the axial hydraulic channel 21 is not connected with the drilling hydraulic channel 13, and the radial hydraulic channel 22 is aligned with the radial jet nozzle 12, that is, the drilling hydraulic channel 13 is closed, the radial hydraulic channel 22 is opened, and high-pressure water is sprayed from the radial jet nozzle 12, so as to realize the conversion of the drilling operation to the slit production increase operation.

[0006] However, in this method, hydraulic pressure is used to control the opening and closing of the drilling hydraulic channel 13 and the radial hydraulic channel 22, and the control process is unstable. The radial jet nozzle 12 may not be opened smoothly during the production increase operation, thereby reducing the reliability of the drilling and production increase operation; and because the drilling hydraulic channel 13 is arranged on the shell 1, the drilling hydraulic channel 13 is relatively narrow, and a large fluid friction is easily formed during drilling, which affects the drilling rock breaking and cuttings removal effects, thereby reducing the drilling efficiency.

[0007] Therefore, how to improve the drilling efficiency and the reliability of drilling and production increase linkage is a technical problem that needs to be solved urgently by those skilled in the art. Summary of the invention

[0008] The main purpose of the present invention is to provide a downhole production enhancement pup joint, an oil and gas drilling production enhancement joint system and method, so as to solve the problems of low drilling efficiency and low reliability of drilling production enhancement joint system in the prior art.

[0009] In view of the above problems, the present invention provides a downhole production enhancement short section, which is applied to a downhole drilling production enhancement joint subsystem in an oil and gas drilling production enhancement joint system. The downhole production enhancement short section comprises:

[0010] A housing, one end of which is used to connect to the coiled tubing in the downhole drilling and production enhancement subsystem, and the other end of which is used to connect to the drill bit in the downhole drilling and production enhancement subsystem;

[0011] A radial jet channel is provided on the housing;

[0012] A high-pressure cutting nozzle is arranged at the outer end of the radial jet channel;

[0013] A first medium axial passage, inside which a valve body and a motor drive mechanism corresponding to the valve body are arranged; wherein the motor drive mechanism is provided with a second medium axial passage; and the valve body is provided with a third medium axial passage;

[0014] If the motor drive mechanism receives a drilling operation instruction, the motor drive mechanism can move in a direction away from the valve body and separate from the valve body, so that the radial jet channel and the first medium axial channel are closed, and the drilling medium is transported to the drill bit through the first medium axial channel, the second medium axial channel and the third medium axial channel, and is ejected from the rock breaking nozzle of the drill bit to perform the drilling operation;

[0015] If the motor drive mechanism receives an increase production operation instruction, the motor drive mechanism can move in the direction toward the valve body, dock with the valve body, and drive the valve body to move, so that the radial jet channel is connected to the first medium axial channel, and the drilling medium is transported to the high-pressure cutting nozzle through the first medium axial channel, the second medium axial channel and the radial jet channel, and is ejected by the high-pressure cutting nozzle to perform an increase production operation.

[0016] Further, in the above-mentioned downhole stimulation sub, the valve body comprises:

[0017] A limiting component, fixed on the housing and provided with a first opening;

[0018] an elastic component, one end of which is located on the limiting component and is provided with a second opening;

[0019] A sliding component connected to the other end of the elastic component, used to switch the state between the radial jet channel and the first medium axial channel under the action of the motor drive mechanism and the elastic component; the state includes a connected state and a closed state; and the sliding component is provided with a third opening;

[0020] The first opening, the second opening and the third opening form the third medium axial passage.

[0021] Furthermore, in the above-mentioned downhole stimulation sub, the motor drive mechanism comprises:

[0022] A straightening component is fixed on the housing, and the straightening component is provided with a fourth opening;

[0023] The outer cylinder is fixed on the straightening component, and is provided with a control component, a motor, a transmission device and a push rod connected in sequence; wherein the control component is used to control the rotation of the motor; the transmission device is used to convert the rotation of the motor into linear motion, thereby controlling the linear motion of the push rod, so that the push rod can dock with or separate from the sliding component.

[0024] Further, in the above-mentioned downhole stimulation sub, the push rod includes an end portion and a tail portion; the tail portion is connected to the transmission device, the end portion is connected to the tail portion, and the radial dimension of the cross section of the end portion is greater than the radial dimension of the cross section of the tail portion;

[0025] The first medium axial channel is also provided with:

[0026] The stopper is located on the side of the sliding component away from the elastic component and is provided with a fifth opening; wherein the aperture of the fifth opening is larger than the radial dimension of the cross section of the end portion, so that after the push rod drives the sliding component to move, a gap is left between the stopper and the tail portion.

[0027] The present invention also provides an oil and gas drilling production enhancement system, comprising:

[0028] Well drilling control subsystem;

[0029] Downhole drilling stimulation subsystem, including:

[0030] A coiled pipe having a composite cable connected to the wellbore drilling control subsystem;

[0031] A drill bit provided with a rock breaking nozzle;

[0032] The downhole stimulation sub as described in any one of the above items is arranged between the coiled tubing and the drill bit; one end of the shell is connected to the coiled tubing, and the other end of the shell is connected to the drill bit.

[0033] Furthermore, in the above-mentioned oil and gas drilling production enhancement system, the wellbore drilling control subsystem includes:

[0034] Intelligent decision analysis device;

[0035] A ground composite coiled tubing drilling rig device, comprising:

[0036] A communication device, which is in communication connection with the intelligent decision-making analysis device;

[0037] A first control device, connected to the communication device, used to execute the first control device instruction sent by the intelligent decision analysis device;

[0038] The downhole drilling production enhancement subsystem also includes:

[0039] A second control device, connected to the coiled tube, used to execute a second control device instruction sent by the intelligent decision-making analysis device;

[0040] The data acquisition device is connected to the coiled pipe and is used to collect drilling monitoring data during the drilling process and send the drilling monitoring data to the intelligent decision analysis device via the composite cable and the communication device.

[0041] Furthermore, in the above-mentioned oil and gas drilling production increase joint system, the intelligent decision-making analysis device is used to generate at least one of the first control equipment instructions, the second control equipment instructions, the drilling operation instructions and the production increase operation instructions based on the drilling monitoring data and with the goal of optimizing the drilling operation, so as to control the operation of at least one of the first control equipment, the second control equipment and the downhole production increase pup joint; and, based on the drilling monitoring data, generate risk prediction information on the drilling conditions and drilling parameter optimization information.

[0042] The present invention also provides an oil and gas drilling production enhancement joint operation method using the above-mentioned oil and gas drilling production enhancement joint operation system, which is characterized by comprising:

[0043] A. Preparation for construction of well drilling control subsystem;

[0044] B. Perform the following steps during each drilling and production enhancement process until the construction is completed, then pull out the underground drilling and production enhancement subsystem, and lower the oil production equipment into the wellbore for production;

[0045] B1. Drilling operation: Start the ground power supply and mud pump in the uphole drilling control subsystem, and the electric motor in the downhole drilling stimulation subsystem drives the drill bit to rotate to achieve rock breaking. The first medium axial channel, the second medium axial channel and the third medium axial channel are transported to the drill bit, and are sprayed out by the rock breaking nozzle of the drill bit to generate high-pressure water jets to break the rock. At the same time, the drill bit rotates to achieve rotary rock breaking, and the broken rock cuttings are returned to the ground along with the drilling fluid from the coiled tubing and the wellbore annulus;

[0046] B2. When drilling reaches the predetermined depth, turn off the mud pump and stop drilling operations;

[0047] B3, switching the nozzle for the first time: connecting the radial jet channel with the first medium axial channel to open the high-pressure cutting nozzle;

[0048] B4. First-level stimulation operation: Start the high-pressure pump in the on-hole drilling control subsystem, increase the displacement and pressure of the high-pressure pump group, pump in the fracturing fluid that can form high-permeability proppant in situ from the ground, and the electric motor in the downhole drilling stimulation subsystem drives the downhole stimulation sub to rotate, while slowly lifting the coiled tubing, so that the high-pressure cutting nozzle rotates and axial displacement occurs, forming a transverse face seam perpendicular to the wellbore axis;

[0049] B5. Second-level production increase operation: After the first-level production increase operation is completed, stop the high-pressure pump group, drag the coiled tubing so that the high-pressure cutting nozzle is aligned with the second-level oil and gas enrichment area, start the high-pressure pump group and repeat B3 to perform the second-level production increase operation until all levels of production increase operations are completed, stop the high-pressure pump group, and stop the production increase operation;

[0050] B6. Switching the nozzle for the second time: closing the radial jet channel and the first medium axial channel to close the high-pressure cutting nozzle and carry out the next drilling and production enhancement operation.

[0051] Further, in the above method, the drilling medium includes drilling fluid and pre-pad fluid;

[0052] Before increasing the displacement and pressure of the high-pressure pump group, the method further includes:

[0053] The drilling fluid in the wellbore is displaced by circulating the forefluid in the wellbore.

[0054] Furthermore, the above method further includes:

[0055] The logging while drilling device, the logging while drilling device and the near-bit measurement device in the downhole drilling production enhancement linkage subsystem collect drilling monitoring data, and transmit the drilling monitoring data to the uphole drilling control subsystem through the composite cable in the continuous pipe. The uphole drilling control subsystem adopts a machine learning algorithm to analyze the drilling history data and the drilling monitoring data according to the requirements of the enterprise users, and generates drilling control instructions with the goal of optimizing the drilling operation. The drilling control instructions are transmitted to the downhole drilling production enhancement linkage subsystem through the composite cable, so that the downhole drilling production enhancement linkage subsystem works according to the drilling parameters in the drilling control instructions, and generates risk prediction information of the drilling condition and drilling parameter optimization information according to the drilling monitoring data.

[0056] Compared with the prior art, one or more embodiments of the above scheme may have the following advantages or beneficial effects:

[0057] The downhole production enhancement short section, oil and gas drilling production enhancement joint system and method of the present embodiment of the present invention are applied. By arranging a radial jet channel and a high-pressure cutting nozzle on the shell, and arranging a valve body and a motor drive mechanism corresponding to the valve body inside the first medium axial channel, the motor drive mechanism is used to drive the valve body to move, and the switching between the high-pressure cutting nozzle and the rock-breaking nozzle of the drill bit is completed. Compared with the switching between the high-pressure cutting nozzle and the rock-breaking nozzle of the drill bit under hydraulic control, it is more stable, ensuring that the radial jet nozzle can be opened smoothly during the production enhancement operation. At the same time, a second axial channel is arranged on the motor drive mechanism, and a third axial channel is arranged on the valve body. It is no longer limited by the shell thickness, so that the second axial channel and the third axial channel are as wide as possible, reducing the fluid friction during drilling, and improving the efficiency of drilling rock breaking and removing rock debris. The technical solution of the present invention can improve the drilling efficiency and the reliability of the drilling production enhancement joint operation.

[0058] Other features and advantages of the present invention will be described in the following description, and partly become apparent from the description, or understood by practicing the present invention. The purpose and other advantages of the present invention can be realized and obtained by the structures particularly pointed out in the description, claims and drawings. BRIEF DESCRIPTION OF THE DRAWINGS

[0059] The accompanying drawings are used to provide a further understanding of the present invention and constitute a part of the specification. Together with the embodiments of the present invention, they are used to explain the present invention and do not constitute a limitation of the present invention. In the accompanying drawings:

[0060] Figure 1 It is a schematic diagram of the structure of a downhole stimulation short sub in the prior art;

[0061] Figure 2 It is a structural schematic diagram of an embodiment of a downhole stimulation sub of the present invention;

[0062] Figure 3 for Figure 2 Schematic diagram of the structure in the AA direction;

[0063] Figure 4 It is a schematic diagram of the working state of the underground stimulation sub in the stimulation operation state;

[0064] Figure 5 It is a structural schematic diagram of an embodiment of the oil and gas drilling production enhancement system of the present invention;

[0065] Figure 6 Schematic diagram of the fracture surface formed after the multi-branch well drilling and production stimulation operation. DETAILED DESCRIPTION

[0066] The following will describe the implementation methods of the present invention in detail with reference to the accompanying drawings and embodiments, so that the implementation process of how the present invention applies technical means to solve technical problems and achieve technical effects can be fully understood and implemented accordingly. It should be noted that as long as there is no conflict, the various embodiments of the present invention and the various features in the embodiments can be combined with each other, and the technical solutions formed are all within the protection scope of the present invention.

[0067] Embodiment 1

[0068] In order to solve the above technical problems existing in the prior art, an embodiment of the present invention provides a downhole production enhancement pup joint, which is applied to a downhole drilling production enhancement linkage subsystem in an oil and gas drilling production enhancement linkage system.

[0069] Figure 2 It is a schematic diagram of the structure of an embodiment of a downhole stimulation sub of the present invention. Figure 3 for Figure 2 The structural diagram of the AA direction is as follows: Figure 2-Figure 3 As shown, the downhole stimulation device of this embodiment may include a housing 1, a radial jet channel 11, a high-pressure cutting nozzle 12 and a first medium axial channel M1.

[0070] In this embodiment, one end of the housing 1 is used to connect the coiled tubing in the downhole drilling stimulation subsystem, and the other end of the housing 1 is used to connect the drill bit in the downhole drilling stimulation subsystem. A radial jet channel 11 is provided on the housing 1; a high-pressure cutting nozzle 12 is provided at the outer end of the radial jet channel 11; a valve body 3 and a motor drive mechanism 4 corresponding to the valve body 3 are provided inside the first medium axial channel M1; wherein the motor drive mechanism 4 is provided with a second medium axial channel M2; and the valve body 3 is provided with a third medium axial channel M3.

[0071] In a specific implementation process, Figure 1 Since the drilling hydraulic channel is designed on the shell 1, the overall thickness of the shell 1 is limited. Figure 1 The width of the drilling hydraulic channel is limited, which easily forms a large fluid friction, affecting the effect of drilling rock breaking and removing rock debris. In this embodiment, the second medium axial channel M2 and the third medium axial channel M3 are not arranged on the housing 1, which enables the designer to design the second medium axial channel M2 and the third medium axial channel M3 as wide as possible, so that the fluid friction can be reduced during drilling, and the efficiency of drilling rock breaking and removing rock debris can be improved.

[0072] In this embodiment, if the motor drive mechanism 4 receives a drilling operation instruction, the motor drive mechanism 4 can move in a direction away from the valve body 3 and separate from the valve body 3 to close the radial jet channel 11 and the first medium axial channel M1. In this way, the flow path of the drilling medium can be switched to the first medium axial channel M1, the second medium axial channel M2 and the third medium axial channel M3, so that the drilling medium is transported to the drill bit through the first medium axial channel M1, the second medium axial channel M2 and the third medium axial channel M3, and is ejected by the rock breaking nozzle of the drill bit to perform drilling operations. The electric motor in the downhole drilling and production enhancement joint operation subsystem drives the drill bit to rotate to achieve rock breaking. The first medium axial channel M1, the second medium axial channel M2 and the third medium axial channel M3 are transported to the drill bit, and are ejected by the rock breaking nozzle of the drill bit to generate a high-pressure water jet to break the rock. At the same time, the drill bit rotates to achieve rotary rock breaking, and the broken rock cuttings are returned to the ground from the coiled tubing and the wellbore annulus along with the drilling fluid.

[0073] If the motor drive mechanism 4 receives a production increase operation instruction, the motor drive mechanism 4 can move in the direction toward the valve body 3, dock with the valve body 3, and drive the valve body 3 to move, so that the radial jet channel 11 is connected with the first medium axial channel M1. In this way, the flow path of the drilling medium can be switched to the first medium axial channel M1, the second medium axial channel M2 and the radial jet channel 11, so that the drilling medium is transported to the high-pressure cutting nozzle 12 through the first medium axial channel M1, the second medium axial channel M2 and the radial jet channel 11, and is ejected by the high-pressure cutting nozzle 12 to perform a production increase operation. Specifically, the electric motor in the downhole drilling and production increase joint subsystem drives the downhole production increase short section to rotate, and at the same time slowly lifts the coiled tubing, so that the high-pressure cutting nozzle 12 rotates and undergoes axial displacement, forming a transverse surface seam perpendicular to the wellbore axis, and performing a production increase operation.

[0074] The downhole production enhancement short section of this embodiment is provided with a radial jet channel 11 and a high-pressure cutting nozzle 12 on the shell 1, and a valve body 3 and a motor drive mechanism 4 corresponding to the valve body 3 are provided inside the first medium axial channel M1. The motor drive mechanism 4 drives the valve body 3 to operate, and the switching between the high-pressure cutting nozzle 12 and the rock-breaking nozzle of the drill bit is completed. Compared with the switching between the high-pressure cutting nozzle 12 and the rock-breaking nozzle of the drill bit by hydraulic control is more stable, and the radial jet nozzle can be smoothly opened during the production enhancement operation. At the same time, a second axial channel is provided on the motor drive mechanism 4, and a third axial channel is provided on the valve body 3, which is no longer limited by the thickness of the shell 1, so that the second axial channel and the third axial channel are as wide as possible, which reduces the fluid friction during drilling and improves the efficiency of drilling rock breaking and removing rock debris. The technical scheme of the present invention can improve the drilling efficiency and the reliability of the drilling and production enhancement joint operation.

[0075] Embodiment 2

[0076] like Figure 2 As shown, the valve body 3 of the downhole stimulation sub of this embodiment may include a limit component 31 , an elastic component 32 and a sliding component 33 .

[0077] In this embodiment, the limiting component 31 is fixed on the housing 1 and is provided with a first opening; for example, the limiting component 31 can be fixed on the housing 1 by a bolt assembly. The limiting component 31 can use at least two "L"-row limiting blocks, and a gap is left between two adjacent limiting blocks. The gap left between the two adjacent limiting blocks can be used as the first opening. Alternatively, an integral structure can be used with a hole in the middle.

[0078] The elastic component 32 has one end located on the limiting component 31 and is provided with a second opening. In this embodiment, the elastic component 32 is preferably a spring, so that the center hole of the spring can be used as the second opening.

[0079] The sliding component 33 is connected to the other end of the elastic component 32, and is used to switch the state between the radial jet channel 11 and the first medium axial channel M1 under the action of the motor drive mechanism 4 and the elastic component 32; the state includes a connected state and a closed state; and the sliding component 33 is provided with a third opening; in practical applications, the sliding component 33 may include a head and a tail, and the tail is inserted into the spring to prevent the spring from detaching from the limiting component 31. In this embodiment, the first opening, the second opening and the third opening form the third medium axial channel M3.

[0080] like Figure 2 As shown, the motor drive mechanism 4 includes a straightening component 41, an outer cylinder 42, a control component 43, a motor 44, a transmission device 45 and a push rod 46.

[0081] The straightening component 41 is fixed on the housing 1, and the straightening component 41 is provided with a fourth opening. Figure 3 As shown, Figure 3 Only the structural relationship diagram of the shell 1, the straightening component 41 and the outer cylinder 42 is shown. The straightening component 41 can be formed by a plurality of straightening blocks, and the pores between two adjacent straightening blocks can be used as four openings to allow the drilling medium to flow through.

[0082] The outer cylinder 42 is fixed on the straightening component 41, and is provided with a control component 43, a motor 44 and a transmission device 45 connected in sequence. The outer cylinder 42 plays a protective role; wherein the control component 43 is used to control the rotation of the motor 44; the transmission device 45 is used to convert the rotation of the motor 44 into linear motion, thereby controlling the linear motion of the push rod 46, so that the push rod 46 can dock or separate with the sliding component 33. The control component 43 may include a signal receiver, a motor 44 controller and an overload protector, and the transmission device 45 is preferably a ball screw transmission device 45.

[0083] In this embodiment, the signal receiver is used to receive the control signal transmitted from the ground, the motor 44 controller is used to control the parameters such as the number of rotations and the rotation speed of the motor 44, and the overload protector is used to protect the motor 44 from damage caused by excessive current and voltage. The ball screw transmission device 45 converts the rotational motion of the motor 44 into linear motion, thereby controlling the forward and backward motion of the push rod 46.

[0084] The lower end of the push rod 46 is designed to be T-shaped, so that after the push rod 46 pushes the slider to open the high-pressure cutting nozzle 12, the drilling medium can be ejected from the high-pressure cutting nozzle 12 at high speed through the space between the housing 1 and the push rod 46. When in the normal drilling state, the sliding block closes the high-pressure cutting nozzle 12 due to the elastic action of the spring, and the drilling medium flows from the first medium axial channel M1, the second medium axial channel M2 and the third medium axial channel M3 to the drill bit. During the production increase operation, the push rod 46 pushes the sliding component 33 to compress the spring, the high-pressure cutting nozzle 12 opens, and the high-pressure cutting production increase operation begins. The diameter of the high-pressure cutting nozzle 12 is 0.2mm-5mm.

[0085] In practical applications, the sliding component 33 may cause the high-pressure cutting nozzle 12 to open due to the impact of the drilling fluid. Therefore, in this embodiment, a stopper 5 is further provided in the first medium axial channel M1.

[0086] The stopper 5 is located on the side of the sliding component 33 away from the elastic component 32 and is provided with a fifth opening. In this embodiment, the push rod 46 includes an end and a tail. The tail is connected to the transmission device 45, and the end is connected to the tail, and the radial dimension of the cross section of the end is greater than the radial dimension of the cross section of the tail. The aperture of the fifth opening is greater than the radial dimension of the cross section of the end, so that after the push rod drives the sliding component to move, a gap is left between the stopper and the tail. The stopper 5 serves to limit the upper limit position of the sliding component 33 and limit the impact of the incoming flow. The existence of the stopper 5 prevents the sliding component 33 from opening the high-pressure cutting nozzle 12 due to the impact of the drilling fluid during normal drilling.

[0087] In this embodiment, Figure 3 Specifically, it is a schematic diagram of the working status of the downhole stimulation sub during drilling operation. Figure 4 This is a schematic diagram of the working status of the underground production stimulation short section during the production stimulation operation.

[0088] Embodiment 3

[0089] In order to solve the above technical problems existing in the prior art, an embodiment of the present invention provides an oil and gas drilling production enhancement system.

[0090] Figure 5 FIG. 1 is a schematic diagram of the structure of an embodiment of the oil and gas drilling production enhancement system of the present invention. Figure 5 As shown, the oil and gas drilling production enhancement linkage system of this embodiment may include an uphole drilling control subsystem 100 and a downhole drilling production enhancement linkage subsystem 101 .

[0091] The downhole drilling stimulation subsystem 101 may include a coiled tubing 1011 , a drill bit 1012 , and a downhole stimulation sub 1013 of the above-mentioned embodiment.

[0092] The coiled tube 1011 is provided with a composite cable connected to the well drilling control subsystem 100;

[0093] A drill bit 1012 is provided with a rock breaking nozzle;

[0094] A downhole stimulation sub 1013 is disposed between the coiled tubing 1011 and the drill bit 1012 ; one end of the housing 1 is connected to the coiled tubing 1011 , and the other end of the housing 1 is connected to the drill bit 1012 .

[0095] In this embodiment, the well drilling control subsystem 100 can send a drilling operation instruction or a production increase operation instruction to the motor drive mechanism 4. If the motor drive mechanism 4 receives the drilling operation instruction, the motor drive mechanism 4 can move in a direction away from the valve body 3, separate from the valve body 3, and drive the valve body 3 to move so that the radial jet channel 11 and the first medium axial channel M1 are closed. In this way, the flow path of the drilling medium can be switched to the first medium axial channel M1, the second medium axial channel M2 and the third medium axial channel M3, so that the drilling medium is transported through the first medium axial channel M1, the second medium axial channel M2 and the third medium axial channel M3. The water is sent to the drill bit 1012 and sprayed out by the rock-breaking nozzle of the drill bit 1012 to perform drilling operations. The electric motor 1015 in the downhole drilling and production enhancement subsystem 101 drives the drill bit 1012 to rotate to achieve rock breaking. The first medium axial channel M1, the second medium axial channel M2 and the third medium axial channel M3 are transported to the drill bit 1012 and sprayed out by the rock-breaking nozzle of the drill bit 1012 to generate a high-pressure water jet to break the rock. At the same time, the drill bit 1012 rotates to achieve rotary rock breaking, and the broken rock cuttings are returned to the ground along with the drilling fluid from the continuous pipe 1011 and the wellbore annulus.

[0096] If the motor drive mechanism 4 receives a production increase operation instruction, the motor drive mechanism 4 can move in the direction toward the valve body 3, dock with the valve body 3, and drive the valve body 3 to move, so that the radial jet channel 11 is connected with the first medium axial channel M1, so that the flow path of the drilling medium can be switched to the first medium axial channel M1, the second medium axial channel M2 and the radial jet channel 11, so that the drilling medium is transported to the high-pressure cutting nozzle 12 through the first medium axial channel M1, the second medium axial channel M2 and the radial jet channel 11, and is ejected by the high-pressure cutting nozzle 12 to perform a production increase operation. Specifically, the electric motor 1015 in the downhole drilling production increase joint operation subsystem 101 drives the downhole production increase short section 1013 to rotate, and at the same time slowly lifts the coiled tubing 1011, so that the high-pressure cutting nozzle 12 rotates and axial displacement occurs, forming a transverse surface seam perpendicular to the wellbore axis, and performing a production increase operation.

[0097] The results obtained by using the technical solution of the present invention are as follows Figure 6 As shown, Figure 6 This is a schematic diagram of the fracture surface formed after the multi-branch well drilling and production enhancement operation. Figure 6 As shown, after the multi-branch well drilling and stimulation operation, a main wellbore 60, a branch wellbore 61 and a face seam 62 can be formed.

[0098] Embodiment 4

[0099] like Figure 4 As shown, the well drilling control subsystem 100 in this embodiment may include an intelligent decision analysis device 1001 and a ground composite coiled tubing drilling rig device 1002. The ground composite coiled tubing drilling rig device 1002 includes a communication device (not shown again) and a first control device. Among them, the first control device may include a composite coiled tubing drilling rig vehicle group 10022, a drum 100023, a mud pump 10024, a high-pressure pump group 10025, etc. Those skilled in the art may also know that the ground composite coiled tubing drilling rig device 1002 may also include a ground power supply 10026, a ground power transformer 10027, an injection head 10028, etc.

[0100] In this embodiment, the communication device is connected to the intelligent decision-making analysis device 1001 for communication; the first control device is connected to the communication device, and the first control device is used to execute the first control device instruction sent by the intelligent decision-making analysis device 1001. For example, turning on or off the mud pump 10024, turning on or off the high-pressure pump group 10025, increasing or decreasing the speed of the drum 100023, etc.

[0101] In practical applications, the downhole drilling production enhancement subsystem 101 also includes a second control device and a data acquisition device. In this embodiment, the second control device may include an electric disconnect device 1014, an electric motor 1015, a downhole tractor 1016, a rotary guide 1017, etc. The data acquisition device includes a logging while drilling device (Logging While Drilling, LWD) 1018, a measuring while drilling device (Measure While Drilling, MWD) 1019, a near-bit measuring device 1020, etc. Those skilled in the art may also know that the downhole drilling production enhancement subsystem 101 may also include a wet joint 1021, a downhole power transformer 1022, etc.

[0102] In a specific implementation process, the second control device is connected to the coiled tube 1011, and is used to execute the second control device instructions sent by the intelligent decision-making analysis device 1001; the data acquisition device is connected to the coiled tube 1011, and is used to collect drilling monitoring data during the drilling process, and send the drilling monitoring data to the intelligent decision-making analysis device 1001 via the composite cable and the communication device, so that the intelligent decision-making analysis device 1001 generates at least one of the first control device instructions, the second control device instructions, the drilling operation instructions and the production increase operation instructions according to the drilling monitoring data.

[0103] In this embodiment, the wet joint 1021 provides mechanical and electrical connections for the subsequent downhole tool string, and a check valve is integrated on the wet joint 1021 to prevent the backflow of drilling medium.

[0104] The downhole power transformer 1022 transforms the power transmitted via the built-in cable coiled tube 1011 and transmits it to the electric disconnect device 1014, the logging while drilling device 1018, the measurement while drilling device 1019, the electric motor 1015, the downhole tractor 1016, the rotary guide 1017, the near-bit measurement device 1020 and the downhole production enhancement short section 1013.

[0105] The electric disconnect device 1014 is equipped with an electric disconnector. Once an accident such as drill sticking or drill burial occurs, an electric disconnection function can be realized by sending an electrical signal therein, thereby retrieving the coiled tubing.

[0106] The logging while drilling device 1018 and the measurement while drilling device 1019 refer to instruments for timely measuring engineering and geological parameters during the drilling process. The measurable parameters include engineering parameters such as well inclination, azimuth, tool face, impact vibration, drilling pressure, torque, bending moment, and geological parameters such as resistivity, porosity, density, acoustic time difference, gamma, etc.

[0107] The electric motor 1015 is powered by the continuous tube 1011 with the built-in composite cable, and the motor rotor drives the drill bit 1012 to rotate. The ground signal can be transmitted to the electric motor 1015 through the continuous tube 1011 with the built-in composite cable to control the motor speed and torque.

[0108] During the drilling process of the coiled tubing 1011, since the coiled tubing 1011 does not rotate in the wellbore, it is easy to encounter obstacles when lowering and the extension length is limited. The servo stepper motor in the downhole tractor 1016 is powered by the built-in cable coiled tubing 1011 to provide traction for the downhole extension of the coiled tubing 1011. Downhole traction crawling can be achieved as long as the power is turned on, and it does not rely on hydraulic drive, so the drive system structure of the downhole tractor 1016 is also relatively simple. The ground signal controls the opening degree and gripping force of the downhole tractor 1016 slips to achieve control of the traction crawling distance.

[0109] The rotary guide 1017 ensures that the drilling tool drills in the specified direction in a fully rotating state, can accurately control the wellbore trajectory, improve the wellbore smoothness, reduce the risk of drill sticking, and reduce drilling costs. The rotary guide 1017 is powered and a control signal is transmitted through a cable to ensure that the drill bit 1012 drills in the specified direction.

[0110] The near-drill-bit measurement device 1020 can measure the formation information in front of and around the drill bit 1012 in real time and make early predictions during the drilling process of the drill bit 1012, so as to achieve the purpose of geo-steering drilling. The near-drill-bit measurement device 1020 measures geological parameters such as formation resistivity and natural gamma at the position closest to the drill bit. The measured signal is transmitted to the ground through the built-in cable continuous oil pipe. After being analyzed, trained and predicted by the ground intelligent decision analysis device 1001, an instruction is sent to modify the drilling parameters in real time.

[0111] The drilling medium of this embodiment may include drilling fluid and pre-fluid. During the drilling operation, the continuous pipe 1011 with built-in composite cable is inserted into the injection head 10028, and the downhole drilling production enhancement system is lowered, the ground power supply 10026 and the mud pump 10024 are started, and the electric motor 1015 drives the drill bit 1012 to rotate to achieve rock breaking, and the drilling fluid is ejected from the rock breaking nozzle of the drill bit 1012 to assist in rock breaking and carry the rock cuttings to the ground.

[0112] During the production stimulation operation, firstly, a pre-fluid is injected into the formation to displace the drilling fluid in the wellbore. The pre-fluid is composed of clay stabilizer, biological enzyme, composite active agent, fluorocarbon surfactant, water and other materials in a certain proportion; then the formation is cut using high-pressure fluid. When the formation closure pressure is relatively large (≥50MPa), during the production stimulation operation, a fracturing fluid that can form a high permeability proppant in situ is sprayed into the formation through the continuous pipe 1011 at high pressure. The injected fracturing fluid can be converted into discrete proppant solid particles in situ, which not only effectively supports the length and height of the fracture surface formed by high-pressure cutting, but also forms a complex fracture network, thereby maximizing the volume of the oil layer transformation. The liquid is composed of a primary liquid precursor and a secondary liquid precursor, wherein the primary liquid precursor includes materials such as micelle-forming surfactants, liquid solvents, and spherule-forming compounds, and the secondary liquid precursor contains materials such as curing agents and co-curing agents. When the formation closure pressure is relatively low (<50MPa), high-pressure clean water can be directly sprayed into the formation for formation cutting. Abrasives can also be added to the clean water, and the rock cuttings formed during the cutting process can be used as proppants to ensure the opening of the fracture.

[0113] In a specific implementation process, the intelligent decision-making analysis device 1001 integrates functions such as pre-operation design, real-time operation optimization, and post-operation evaluation. It can perform intelligent analysis and decision-making based on the historical data of the wells that have been drilled and the real-time data of the wells being drilled, and then transmit the control signal to the well to adjust and optimize the drilling and production increase parameters, and perform accident warnings at the same time. For example, based on the drilling monitoring data, risk prediction information of the drilling conditions and drilling parameter optimization information are generated. In this way, the intelligent integrated closed-loop operation of drilling and production increase is truly realized. Based on the drilling monitoring data, with the goal of optimizing the drilling operation, it generates at least one of the first control device instructions, the second control device instructions, the drilling operation instructions, and the production increase operation instructions to control the operation of at least one of the first control device, the second control device, and the downhole production increase short section; and, based on the drilling monitoring data, risk prediction information of the drilling conditions is generated.

[0114] In this embodiment, the intelligent decision analysis device 1001 may include a data receiver 10011, a data storage device 10012, a data processor 10013, a machine learning server 10014, and a Web server 10015.

[0115] The data receiver 10011 is used to receive the real-time drilling and production increase data returned from the well during the drilling and production increase process. The data storage device 10012 is used to store the historical data of drilling and production increase of all wells in the block where the construction well is located and the real-time data collected. The real-time drilling data includes drilling time data, footage data, mechanical drilling speed data, measurement while drilling data, well inclination, azimuth, temperature, drilling fluid performance data, near-bit reservoir physical property data, energy consumption data, etc. The real-time production increase data includes surface pump displacement, surface pump pressure, nozzle pressure, high-pressure jet production increase position, etc. The data processor 10013 uses the returned real-time drilling and production increase data to construct a data set, including data definition, data association, data extraction, data fusion, data cleaning, etc. The machine learning server 10014 is used to perform machine learning on historical data and real-time data to obtain optimized data, of which the historical data does not exceed 50% and is not less than 20%. The machine learning algorithms used include convolutional neural network, support vector machine, decision tree, naive Bayes classification, K-means clustering, principal component analysis, independent component analysis, Monte Carlo tree search, Apriori algorithm, etc. Web server 10015 is used to associate account requests of enterprise users (including drilling teams, remote experts, etc.), and users can control the entire intelligent decision analysis device 1001 through Web server 10015. In addition, Web server 10015 can also receive control instructions sent by terminal equipment, and the control instructions are transmitted to data receiver 10011, and then the control instructions are sent to the ground continuous pipe 1011 composite drilling rig device and the downhole drilling production increase joint operation subsystem 101.

[0116] During the drilling operation, the intelligent decision-making analysis device 1001 uses a machine learning algorithm to intelligently analyze the drilling history and real-time data according to the requirements of corporate users, and generates control instructions for the ground composite continuous tubing drilling rig device 1002 with the goal of optimizing the drilling operation. The instructions are transmitted to the downhole drilling and production increase joint operation subsystem 101 through the built-in cable continuous oil pipe to achieve the purpose of adjusting the drilling parameters; during the production increase operation, the engineering and geological data collected during the drilling process are used. After being intelligently analyzed by the intelligent decision-making analysis device 1001, parameters such as pump pressure, displacement, rotation speed of the downhole production increase short section 1013, and lifting speed of the continuous tube 1011 are optimized to achieve the purpose of contacting the oil and gas rich area with the lowest cost and maximum extent.

[0117] Specifically, the intelligent decision analysis device 1001 may be provided with a drilling hydraulics calculation model, a drilling string mechanics calculation model, a wellbore stability analysis model, a drilling risk prediction and diagnosis model, a wellbore trajectory calculation model, a mechanical drilling speed and cost prediction model, and a while-drilling formation pressure prediction model;

[0118] The drilling hydraulic calculation model is used to read the basic data source input by the input device, obtain the drilling pump characteristics, drill string structure, drill bit 1012 type, drilling fluid performance, and the flow state of the drilling fluid in the pipe and annulus; and calculate the real-time drilling circulation flow pressure loss, combine the basic theory of fluid mechanics, optimize and determine the drilling hydraulic target parameters, and then generate control instructions for the drilling process.

[0119] The drilling string mechanical calculation model is used to read the current actual drilling tool combination data input by the input device, obtain the drill tool properties in the actual drilling string, including drill tool type, drill tool length, drill tool inner diameter and outer diameter values, drill tool tensile and torsional values, drill tool service life and drill tool grade information; and calculate the mechanical data of the drill tool during real-time drilling, optimize and determine the drilling mechanical limit constraint protection parameters, and then generate control instructions for the drilling process.

[0120] The wellbore stability analysis model is used to read the derived data source input by the input device, obtain the real-time pressure balance characteristics of the drilling fluid in the annular formation, automatically calculate and identify the formation lithology, and the drillability stability characteristics of different formations and lithologies, and optimize the drilling mud and hydraulic parameters.

[0121] The drilling risk prediction and diagnosis model is used to pre-establish various drilling risk models; the basic data source input by the input device is input into the drilling risk model, the drilling risk model is run, and the risk prediction of the on-site drilling conditions is performed; wherein the drilling risk model includes a well kick risk model, a blowout risk model, a well leakage risk model and a stuck pipe risk model.

[0122] The operation process of the kick risk model, the blowout risk model and the leakage risk model is to obtain the changes in gas detection, drilling time data and drilling fluid parameters through the basic data source, and predict the relevant risks by analyzing the changes in the gas detection, drilling time data and drilling fluid parameters.

[0123] The drill stuck risk model includes the drill stuck risk model due to pressure difference adhesion, the drill stuck risk model due to sand settling, the drill stuck risk model due to collapse, the drill stuck risk model due to block falling from the well wall, the drill stuck risk model due to pump leakage, the drill stuck risk model due to falling objects in the well, the drill stuck risk model due to reduced diameter, the drill stuck risk model due to key slots, and the drill bit 1012 mud bag stuck risk model.

[0124] The wellbore trajectory calculation model is used to obtain complete data of the real stratigraphic profile, including stratigraphic lithology and density, reservoir characteristics and marker layers, gas caps, oil layers, interlayers, oil bottom lithology and depth, stratigraphic fluid depth and fluid pressure, fluid properties, actual drilling three-dimensional wellbore trajectory, real-time working conditions of the drill string and its various sets of accessories and the drill bit 1012, and dynamic working conditions of downhole drilling; the complete stratigraphic profile data is comprehensively analyzed and integrated, and the technical parameters and decisions for optimizing the section to be drilled are obtained through interpretation and processing, and compared with the designed wellbore structure geological and engineering models at all times to generate control instructions for the drilling process.

[0125] The mechanical drilling speed and cost prediction model is used to predict the real-time drilling pressure and optimize the drilling pressure and speed; specifically, the mathematical model of the basic law of the drilling process is associated with the established optimization goal to establish a drilling objective function; on this basis, artificial intelligence control theory and various linear and nonlinear programming methods are used to optimize the various drilling parameters of the objective function while determining various constraints, thereby generating control instructions for the drilling process.

[0126] The formation pressure prediction model while drilling is used for bottom hole pressure control and automatic control of mud manifold system; specifically, it is to analyze and calculate the bottom hole pressure under pump stop, drilling stop, drilling, drilling and drilling conditions in real time, and use the bottom hole pressure balance theory to establish a bottom hole pressure control model, so as to optimize the drilling and drilling speed, and then generate control instructions for the drilling process, and control the occurrence of drilling accidents such as well invasion, overflow, well kick, blowout, well leakage and well collapse.

[0127] In summary, the present invention has the following beneficial effects compared with the existing oil and gas production technology:

[0128] (1) High operating efficiency

[0129] This method relies on high-pressure water jets to break rocks. The drill bit 1012 can be rotated and ground to break rocks as needed, which can implement fast and effective drilling without being restricted by the hardness of the reservoir rock. At the same time, after drilling, there is no need to trip the drill. The underground production increase operation can be achieved by switching the rock breaking nozzle and the production increase nozzle through ground control. The entire drilling production increase operation takes a short time, has a low construction risk, and greatly reduces costs.

[0130] (2) The yield increase effect is good and stable

[0131] When fracturing low-permeability reservoirs, hydraulic fracturing cannot accurately control the direction and length of cracks due to the different rock properties of different rock formations. Horizontal well fracturing is prone to produce longitudinal cracks, resulting in poor fracturing effects. It may also open water layers and gas layers, leading to premature intrusion of water and gas. This method can effectively control the length, depth, and width of the surface cracks. The injected fracturing fluid can be converted into a high-permeability proppant in situ, making the cracks difficult to close. The pressurization process is driven by a motor to control the switching between the high-pressure cutting nozzle 12 and the rock-breaking nozzle of the drill bit 1012, ensuring that the radial jet nozzle can be opened smoothly during the production increase operation to perform the production increase operation.

[0132] (3) Wide reservoir adaptability

[0133] The thickness of some complex oil and gas reservoirs varies greatly, and thin oil layers or thin interlayers are developed, making it difficult to accurately control the borehole trajectory when drilling horizontal wells. This technology can drill ultra-short radius horizontal wells, increase the reservoir encounter rate, and effectively control the borehole trajectory to effectively transform thin reservoirs.

[0134] Embodiment 5 To solve the above-mentioned technical problems existing in the prior art, the embodiment of the present invention provides an oil and gas drilling production enhancement joint operation method using the oil and gas drilling production enhancement joint operation system described in the above embodiment.

[0135] The oil and gas drilling production enhancement method of this embodiment may specifically include the following steps:

[0136] A. Preparation for construction of well drilling control subsystem;

[0137] Specifically, the composite continuous tubing drilling rig and the supporting lifting equipment can be used to install the continuous tubing injection head, and at the same time, the ground power supply, power transformer, mud pump, high-pressure pump group and other equipment can be installed, and the intelligent decision-making analysis device can be connected.

[0138] B. Perform the following steps during each drilling and production enhancement process until the construction is completed, then pull out the underground drilling and production enhancement subsystem, and lower the oil production equipment into the wellbore for production;

[0139] B1. Drilling operation: Start the ground power supply and mud pump in the uphole drilling control subsystem, and the electric motor in the downhole drilling stimulation subsystem drives the drill bit to rotate to achieve rock breaking. The first medium axial channel, the second medium axial channel M2 and the third medium axial channel are transported to the drill bit, and are ejected from the rock breaking nozzle of the drill bit to generate a high-pressure water jet to break the rock. At the same time, the drill bit rotates to achieve rotary rock breaking, and the broken rock cuttings are returned to the ground from the coiled tubing and the wellbore annulus along with the drilling fluid;

[0140] B2. When drilling reaches the predetermined depth, turn off the mud pump and stop drilling operations;

[0141] B3, switching the nozzle for the first time: connecting the radial jet channel with the first medium axial channel to open the high-pressure cutting nozzle;

[0142] B4. First-level stimulation operation: Start the high-pressure pump in the on-hole drilling control subsystem, increase the displacement and pressure of the high-pressure pump group, pump in the fracturing fluid that can form high-permeability proppant in situ from the ground, and the electric motor in the downhole drilling stimulation subsystem drives the downhole stimulation sub to rotate, while slowly lifting the coiled tubing, so that the high-pressure cutting nozzle rotates and axial displacement occurs, forming a transverse face seam perpendicular to the wellbore axis;

[0143] B5. Second-level production increase operation: After the first-level production increase operation is completed, stop the high-pressure pump group, drag the coiled tubing so that the high-pressure cutting nozzle is aligned with the second-level oil and gas enrichment area, start the high-pressure pump group and repeat B3 to perform the second-level production increase operation until all levels of production increase operations are completed, stop the high-pressure pump group, and stop the production increase operation;

[0144] B6. Switching nozzles for the second time: closing the radial jet channel and the first medium axial channel to close the high-pressure cutting nozzle and perform the next drilling and production enhancement operation.

[0145] Further, in the above embodiment, the drilling medium includes drilling fluid and pre-pad fluid;

[0146] Before increasing the displacement and pressure of the high-pressure pump group in step B4, the following steps may also be performed:

[0147] The drilling fluid in the wellbore is displaced by circulating the forefluid in the wellbore.

[0148] Furthermore, in the above embodiment, the oil and gas drilling production enhancement method may further perform the following steps:

[0149] The logging while drilling device, the logging while drilling device and the near-bit measurement device in the downhole drilling production enhancement linkage subsystem collect drilling monitoring data, and transmit the drilling monitoring data to the uphole drilling control subsystem through the composite cable in the continuous pipe. The uphole drilling control subsystem adopts a machine learning algorithm according to the requirements of enterprise users to analyze the drilling history data and drilling monitoring data, and generates drilling control instructions with the goal of optimizing drilling operations. The drilling control instructions are transmitted to the downhole drilling production enhancement linkage subsystem through the composite cable, so that the downhole drilling production enhancement linkage subsystem works according to the drilling parameters in the drilling control instructions.

[0150] Embodiment 6

[0151] This embodiment describes the oil and gas drilling production increase joint operation method in more detail. The oil and gas drilling production increase joint operation method of this embodiment can specifically perform the following steps:

[0152] (1) Ground construction preparation: Use the composite coiled tubing drilling rig and supporting lifting equipment to install the coiled tubing injection head, and install the ground power supply, power transformer, mud pump, high-pressure pump group and other equipment, and connect the intelligent decision-making analysis device;

[0153] (2) The first drilling and production enhancement joint operation:

[0154] ① Drilling operation: insert the built-in cable continuous tubing into the injection head, lower it into the underground drilling and production enhancement joint operation subsystem, start the ground power supply and mud pump, and the electric motor drives the drill bit to rotate to achieve rock breaking. The drilling fluid is ejected from the drill bit rock breaking nozzle to assist in rock breaking and carry the rock cuttings to the ground. During the drilling process, the logging / measurement device while drilling and the near-drill bit measurement device collect engineering and geological data in real time, and transmit the data to the ground and the intelligent decision-making analysis device through the cable in the continuous pipe. According to the requirements of enterprise users, the intelligent decision-making analysis device uses machine learning algorithms to perform intelligent analysis of drilling history and real-time data, with the goal of optimizing drilling operations, and generates control instructions for the ground composite continuous tubing drilling rig system, and transmits the instructions to the underground drilling and production enhancement joint operation system through the built-in cable continuous tubing, so as to achieve the purpose of adjusting drilling parameters;

[0155] ② Stop drilling: When drilling reaches the predetermined depth, turn off the mud pump and stop drilling operations;

[0156] ③First-level stimulation operation: Turn on the high-pressure pump group, use the pre-fluid to circulate the wellbore, and displace the drilling fluid in the wellbore. The push rod of the ground-controlled downhole stimulation short section pushes the sliding body to compress the spring body, opens the high-pressure cutting nozzle, increases the displacement and pressure of the high-pressure pump group (the working displacement is 50-300L / s, and the working pressure can reach up to 400MPa), and pumps in clean water or fracturing fluid that can form high-permeability proppants in situ from the ground (depending on the formation closure pressure). The electric motor drives

[0157] The downhole stimulation sub rotates, and the coiled tubing is slowly lifted up, so that the high-pressure cutting nozzle rotates and axial displacement occurs, forming a transverse seam perpendicular to the axis of the wellbore. During the stimulation operation, the engineering and geological data collected during the drilling process are used, and after intelligent analysis by the intelligent decision-making analysis device, the pump pressure, displacement, downhole stimulation sub rotation speed, coiled tubing lifting speed and other parameters are optimized to achieve the purpose of contacting the oil and gas rich area at the lowest cost and to the maximum extent.

[0158] ④ Second-level production increase operation: After the first-level production increase operation is completed, the high-pressure pump group is stopped on the ground. The intelligent decision-making analysis device obtains the location of the second-level oil and gas enrichment area based on the engineering and geological data collected during the drilling process. Drag the high-pressure coiled tubing to align the high-pressure cutting nozzle with the location of the second-level oil and gas enrichment area, and start the high-pressure pump group to perform the second-level production increase operation;

[0159] ⑤Subsequent production increase operations: Repeat step ④ to complete subsequent production increase operations at all levels.

[0160] (3) Second drilling and production enhancement operation: After completing the first drilling and production enhancement operation, stop the high-pressure pump group on the ground. Lift the coiled tubing to the next branch wellbore, start the ground power supply and mud pump, and the intelligent decision-making analysis device controls the rotary guide to change the direction of the drill bit so that it can drill along the next branch point in the drilling design. Repeat steps ①-④ in (2) to complete the drilling and production enhancement operation of the next branch wellbore;

[0161] (4) Repeat step (3) to complete the drilling and production enhancement operation of multiple branch wellbores.

[0162] (5) After the construction is completed, shut down the surface high-pressure pump group, pull out the underground drilling and production enhancement subsystem, and lower the oil production equipment into the wellbore for production.

[0163] It should be noted that, in the description of the present invention, the terms "first", "second", etc. are only used for descriptive purposes and cannot be understood as indicating or implying relative importance. In addition, in the description of the present invention, unless otherwise specified, the meaning of "plurality" refers to at least two.

[0164] In the description of this specification, the description with reference to the terms "one embodiment", "some embodiments", "examples", "specific examples", or "some examples" means that the specific features, structures, materials or characteristics described in conjunction with the embodiment or example are included in at least one embodiment or example of the present invention. In this specification, the schematic representation of the above terms does not necessarily refer to the same embodiment or example. Moreover, the specific features, structures, materials or characteristics described may be combined in any one or more embodiments or examples in a suitable manner.

[0165] Although the embodiments disclosed in the present invention are as above, the contents described are only embodiments adopted for facilitating the understanding of the present invention and are not intended to limit the present invention. Any technician in the technical field to which the present invention belongs can make any modifications and changes in the form and details of the implementation without departing from the spirit and scope disclosed in the present invention, but the protection scope of the present invention shall still be subject to the scope defined in the attached claims.

Claims

1. A downhole stimulation sub, It is characterized in that Applicable to the downhole drilling production enhancement joint subsystem in the oil and gas drilling production enhancement joint system, the downhole production enhancement short section includes: A housing, one end of which is used to connect to the coiled tubing in the downhole drilling and production enhancement subsystem, and the other end of which is used to connect to the drill bit in the downhole drilling and production enhancement subsystem; A radial jet channel is provided on the housing; A high-pressure cutting nozzle is arranged at the outer end of the radial jet channel; A first medium axial passage, inside which a valve body and a motor drive mechanism corresponding to the valve body are arranged; wherein the motor drive mechanism is provided with a second medium axial passage; and the valve body is provided with a third medium axial passage; If the motor drive mechanism receives a drilling operation instruction, the motor drive mechanism can move in a direction away from the valve body and separate from the valve body, so that the radial jet channel and the first medium axial channel are closed, and the drilling medium is transported to the drill bit through the first medium axial channel, the second medium axial channel and the third medium axial channel, and is ejected from the rock breaking nozzle of the drill bit to perform the drilling operation; If the motor drive mechanism receives an increase production operation instruction, the motor drive mechanism can move in the direction toward the valve body, dock with the valve body, and drive the valve body to move, so that the radial jet channel is connected to the first medium axial channel, and the drilling medium is transported to the high-pressure cutting nozzle through the first medium axial channel, the second medium axial channel and the radial jet channel, and is ejected by the high-pressure cutting nozzle to perform an increase production operation.

2. The downhole stimulation sub according to claim 1, It is characterized in that The valve body comprises: A limiting component, fixed on the housing and provided with a first opening; an elastic component, one end of which is located on the limiting component and is provided with a second opening; A sliding component connected to the other end of the elastic component, used to switch the state between the radial jet channel and the first medium axial channel under the action of the motor drive mechanism and the elastic component; the state includes a connected state and a closed state; and the sliding component is provided with a third opening; The first opening, the second opening and the third opening form the third medium axial passage.

3. The downhole stimulation sub according to claim 2, It is characterized in that The motor drive mechanism comprises: A straightening component is fixed on the housing, and the straightening component is provided with a fourth opening; The outer cylinder is fixed on the straightening component, and is provided with a control component, a motor, a transmission device and a push rod connected in sequence; wherein the control component is used to control the rotation of the motor; the transmission device is used to convert the rotation of the motor into linear motion, thereby controlling the linear motion of the push rod, so that the push rod can dock with or separate from the sliding component.

4. An oil and gas drilling production enhancement system, It is characterized in that include: Well drilling control subsystem; Downhole drilling stimulation subsystem, including: A coiled pipe having a composite cable connected to the wellbore drilling control subsystem; A drill bit provided with a rock breaking nozzle; The downhole stimulation sub as described in any one of claims 1 to 3 is arranged between the coiled tubing and the drill bit; one end of the shell is connected to the coiled tubing, and the other end of the shell is connected to the drill bit.

5. The oil and gas drilling production enhancement system according to claim 4, It is characterized in that The well drilling control subsystem comprises: Intelligent decision-making analysis device; A ground composite coiled tubing drilling rig device, comprising: A communication device, which is in communication connection with the intelligent decision-making analysis device; A first control device, connected to the communication device, used to execute the first control device instruction sent by the intelligent decision analysis device; The downhole drilling production enhancement subsystem also includes: A second control device, connected to the coiled tube, used to execute a second control device instruction sent by the intelligent decision-making analysis device; The data acquisition device is connected to the coiled pipe and is used to collect drilling monitoring data during the drilling process and send the drilling monitoring data to the intelligent decision analysis device via the composite cable and the communication device.

6. The oil and gas drilling production enhancement system according to claim 5, It is characterized in that The intelligent decision-making analysis device is used to generate at least one of the first control equipment instruction, the second control equipment instruction, the drilling operation instruction and the production increase operation instruction based on the drilling monitoring data, with the goal of optimizing the drilling operation, so as to control the operation of at least one of the first control equipment, the second control equipment and the downhole production increase pup joint; and to generate risk prediction information of the drilling condition and drilling parameter optimization information based on the drilling monitoring data.

7. A method for oil and gas drilling production enhancement linkage using the oil and gas drilling production enhancement linkage system according to any one of claims 4 to 6, It is characterized in that include: A. Preparation for construction of well drilling control subsystem; B. Perform the following steps during each drilling and production enhancement process until the construction is completed, then pull out the underground drilling and production enhancement subsystem, and lower the oil production equipment into the wellbore for production; B1. Drilling operation: start the ground power supply and mud pump in the uphole drilling control subsystem, and the electric motor in the downhole drilling stimulation subsystem drives the drill bit to rotate to achieve rock breaking. The drilling medium is transported to the drill bit through the first medium axial channel, the second medium axial channel and the third medium axial channel, and is ejected from the rock breaking nozzle of the drill bit to generate a high-pressure water jet to break the rock. At the same time, the drill bit rotates to achieve rotary rock breaking, and the broken rock cuttings are returned to the ground from the coiled tubing and the wellbore annulus along with the drilling fluid; B2. When drilling reaches the predetermined depth, turn off the mud pump and stop drilling operations; B3, switching the nozzle for the first time: connecting the radial jet channel with the first medium axial channel to open the high-pressure cutting nozzle; B4. First-level stimulation operation: Start the high-pressure pump in the on-hole drilling control subsystem, increase the displacement and pressure of the high-pressure pump group, pump in the fracturing fluid that can form high-permeability proppant in situ from the ground, and the electric motor in the downhole drilling stimulation subsystem drives the downhole stimulation sub to rotate, while slowly lifting the coiled tubing, so that the high-pressure cutting nozzle rotates and axial displacement occurs, forming a transverse face seam perpendicular to the wellbore axis; B5. Second-level production increase operation: After the first-level production increase operation is completed, stop the high-pressure pump group, drag the coiled tubing so that the high-pressure cutting nozzle is aligned with the second-level oil and gas enrichment area, start the high-pressure pump group and repeat B3 to perform the second-level production increase operation until all levels of production increase operations are completed, stop the high-pressure pump group, and stop the production increase operation; B6. Switching the nozzle for the second time: closing the radial jet channel and the first medium axial channel to close the high-pressure cutting nozzle and carry out the next drilling and production enhancement operation.

8. The oil and gas drilling production enhancement method according to claim 7, It is characterized in that The drilling medium includes drilling fluid and pre-pad fluid; Before increasing the displacement and pressure of the high-pressure pump group, the method further includes: The drilling fluid in the wellbore is displaced by circulating the forefluid in the wellbore.

9. The oil and gas drilling production enhancement method according to claim 7, It is characterized in that Also includes: The logging while drilling device, the logging while drilling device and the near-bit measurement device in the downhole drilling production enhancement linkage subsystem collect drilling monitoring data, and transmit the drilling monitoring data to the uphole drilling control subsystem through the composite cable in the continuous pipe. The uphole drilling control subsystem adopts a machine learning algorithm to analyze the drilling history data and the drilling monitoring data according to the requirements of the enterprise users, and generates drilling control instructions with the goal of optimizing the drilling operation. The drilling control instructions are transmitted to the downhole drilling production enhancement linkage subsystem through the composite cable, so that the downhole drilling production enhancement linkage subsystem works according to the drilling parameters in the drilling control instructions, and generates risk prediction information of the drilling condition and drilling parameter optimization information according to the drilling monitoring data.

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