CN113236224A - High-curvature branch well position control device - Google Patents
High-curvature branch well position control device Download PDFInfo
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- CN113236224A CN113236224A CN202110654607.1A CN202110654607A CN113236224A CN 113236224 A CN113236224 A CN 113236224A CN 202110654607 A CN202110654607 A CN 202110654607A CN 113236224 A CN113236224 A CN 113236224A
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/02—Determining slope or direction
- E21B47/024—Determining slope or direction of devices in the borehole
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
- E21B7/04—Directional drilling
Abstract
The invention discloses a high-curvature branch well position control device, which relates to the technical field of oil-gas exploration and comprises the following components: comprises two strings of downhole operation tools which are respectively arranged in two wells to be communicated or mutually kept at a distance, wherein at least one set comprises a directional drilling short section serial which is arranged in the high-curvature branch well, is used for communicating well operation through a high-curvature well section with the curvature radius within a preset range, and the two strings of underground operation tools are respectively provided with a first signal transceiving unit and a second signal transceiving unit, wherein the second signal transceiver unit can calculate the relative position relationship between the first signal transceiver unit and the second signal transceiver unit by receiving the signal transmitted by the first signal transceiver unit, or, the first signal transceiver unit can calculate the relative position relationship between the first signal transceiver unit and the second signal transceiver unit by receiving the signal transmitted by the second signal transceiver unit.
Description
Technical Field
The invention relates to the technical field of oil-gas exploration, in particular to a high-curvature branch well position control device.
Background
The detection of underground resources requires the use of a large number of communicating well instruments. The prior art can carry out communication well or parallel drilling and complete double-horizontal well drilling aiming at a vertical well, an inclined well and a branch well. However, the prior art cannot perform communication well or double parallel well drilling through a high curvature well section or a branch well section with a curvature radius of less than 30 meters, especially cannot perform a very short radius well section or a very short radius branch well section with a curvature radius of less than 10 meters. This limits the operation of dual parallel wells or communicating wells while drilling for high curvature wellbores, increases the difficulty of the operation, and hinders the evaluation of thin layer resources or resources beside the wells.
Therefore, it is necessary to provide a high curvature branch well position control device to solve the above problems in the background art.
Disclosure of Invention
In order to achieve the purpose, the invention provides the following technical scheme: a high curvature lateral well position control device, comprising: the directional drilling pup joint string can penetrate through a branched well bore with the curvature radius within a preset range, a second signal transceiving unit positioned in another target well bore, a resolving module and a controller;
the directional drilling short section tandem comprises a plurality of bearing short sections which are connected in a hinged mode, and the bearing short section positioned at the lower part is also connected with the guide short section;
the second signal receiving and transmitting unit can transmit signals to the directional drilling short section serial and the stratum where the directional drilling short section serial is located, or receive signals fed back or transmitted by the directional drilling short section serial;
the resolving module is used for resolving the relative position relation between the directional drilling nipple string and the target borehole and controlling the directional drilling nipple string to adjust or keep the preset relative position relation with the target borehole through the controller. In the present invention, the target borehole B may be a vertical well, a slant well or a horizontal well.
Further, preferably, the method further comprises: a first drill string disposed above the string of directional drilling subs for conveying the string of directional drilling subs into the lateral wellbore;
the length of the directional drilling pup joint string is greater than that of a branch well section of the branch well bore; the bearing short section is connected in series in the directional drilling short section string in a hinged mode, and the axial length of the bearing short section is less than or equal to 5 times of the outer diameter of the guide short section;
the downhole tool string comprises a first signal transceiver unit and a second signal transceiver unit, wherein the first signal transceiver unit is arranged in the first downhole tool string;
the resolving module is a second position resolving module, is in communication connection with the second signal transceiving unit and is used for resolving the position relation between the directional drilling pup joint string and the second downhole tool string by adopting data measured by the second signal transceiving unit, and the second position resolving module can be arranged in the second downhole tool string or at the wellhead end;
the controller is a wellhead control end, the wellhead control end is in communication connection with the directional drilling nipple serial and the second position calculation module respectively, the directional drilling nipple serial is controlled by the position relation between the directional drilling nipple serial and the second downhole tool string obtained through calculation of the calculation module, the directional drilling nipple serial is adjusted or kept in a preset relative position relation with a target borehole, and the wellhead control end can be an FPGA and/or a digital chip and/or an engineer capable of executing control and communication functions.
Further, preferably, the second downhole tool string at least comprises two second signal transceiver units, and the second signal transceiver units are electromagnetic probe probes and are used for transmitting and/or receiving electromagnetic wave signals to the formation; the at least one second signal transceiving unit is provided with a signal transmitting module and is used for applying transient electromagnetic excitation signals to the electromagnetic probe; at least one second signal transceiving unit comprises a signal pickup module for picking up secondary eddy current field signals induced in the electromagnetic probe from the directional drilling sub string.
Further, preferably, the second downhole tool string comprises at least one set of phased array acoustic transceiver units, the acoustic transceiver units comprising transducers for transmitting and/or receiving acoustic signals in a controllable direction; the acoustic signal transmitting module is used for driving the transducer to transmit an acoustic signal; the system also comprises an acoustic signal pickup module which is used for picking up a reflected signal received by the transducer from the directional drilling short section string.
Further, preferably, the directional drilling pup joint string further comprises a first signal transceiving unit, and the first signal transceiving unit is arranged in any bearing pup joint;
the second signal transceiver unit can calculate the relative position relationship between the first signal transceiver unit and the second signal transceiver unit by receiving the signal transmitted by the first signal transceiver unit, or the first signal transceiver unit can calculate the relative position relationship between the first signal transceiver unit and the second signal transceiver unit by receiving the signal transmitted by the second signal transceiver unit.
Further, preferably, the first signal transceiver unit includes a magnetic sensor and a first position calculating unit, and the magnetic sensor is electrically connected to the first position calculating unit; the second signal transceiving unit comprises a magnetic field transmitting device. The first position calculating unit is in communication connection with the first signal transceiving unit and is used for calculating the position relation between the directional drilling pup joint string and the second downhole tool string by adopting data measured by the first signal transceiving unit;
the controller is a closed-loop control module which is arranged in any bearing short section in the directional drilling short section string, and the closed-loop control module is in communication connection with the guide short section and the first position calculating unit respectively and is used for controlling the directional drilling short section string to be adjusted or kept in a preset relative position relation with a target well hole by adopting the position relation between the directional drilling short section string and the target well, which is obtained by calculating by the first position calculating unit.
Further, preferably, the magnetic field emission device is a magnet;
the device also comprises a second drill string which can drive the magnet to rotate so as to generate an alternating magnetic field to be measured;
or the like, or, alternatively,
a motor is connected between the second drill string and the magnet and can drive the magnet to rotate so as to generate an alternating magnetic field to be measured;
or the second drill string drives the magnetic field emission device to rotate through the second short section serial connection, so that an alternating magnetic field to be detected is generated.
Further, preferably, the first signal transceiving unit comprises a magnetic field transmitting device; the second signal transceiver unit comprises a magnetic sensor and a second position resolving module, and the second signal transceiver unit is electrically connected with the second position resolving module.
The controller is a wellhead control end which is in communication connection with the directional drilling nipple serial and the second position calculation module respectively and used for controlling the directional drilling nipple serial to adjust or keep a preset relative position relation with a target borehole by adopting the position relation between the directional drilling nipple serial and the second downhole tool string obtained by calculation of the second position calculation module.
Further, preferably, the first signal transceiving unit comprises a receiving transducer and a first position calculating unit, and the receiving transducer is electrically connected with the position calculating unit; the second signal transceiving unit comprises a transmitting transducer;
or
The second signal transceiving unit comprises a receiving transducer and a second position resolving module, and the receiving transducer is electrically connected with the second position resolving module; the first signal transceiving unit comprises a transmitting transducer.
Further, preferably, the first signal transceiving unit and the second signal transceiving unit both comprise transducers so as to transmit and/or receive signals to the stratum in the form of sound waves;
at least one bearing short section is used for accommodating the control unit and the first position calculating unit, and the bearing short section is connected in series to any position in the directional drilling short section series in a hinged mode, or arranged above the directional drilling short section series, or arranged below the directional drilling short section series;
the control unit and the first position resolving unit are electrically connected with the first signal transceiving unit through a cross-over measuring line, and are used for controlling the first signal transceiving unit to transmit signals to the stratum when the control unit and the first position resolving unit are the control units, and are used for collecting the stratum signals received by the first signal transceiving unit when the control unit and the first position resolving unit are the position resolving units.
Further, preferably, the first signal transceiver unit and the second signal transceiver unit each include a coil, and/or the first signal transceiver unit and the second signal transceiver unit each include a transducer;
the directional drilling pup joint string at least comprises two first signal transceiving units so as to transmit and/or receive signals to the stratum in the form of electromagnetic waves or sound waves;
and each first signal transceiving unit is respectively arranged on different bearing short sections.
Further, preferably, the first signal transceiver unit and the second signal transceiver unit both include coils, and/or the first signal transceiver unit and the second signal transceiver unit both include transducers;
a second drill string; the second drill string comprises at least two second signal transceiving units so as to transmit and/or receive signals to and/or from the stratum in the form of electromagnetic waves and/or sound waves;
and each second signal transceiver unit is respectively arranged on different bearing short joints of a second drill string.
Further, preferably, the method further comprises: and the elastic piece penetrates through the directional drilling pup joint serial and is used for enabling the bearing pups bearing the first signal receiving and transmitting units to be in a coaxial state with the adjacent bearing pups.
Further, preferably, the method further comprises: and the attitude measurement unit and the first signal transceiving unit are arranged on the same bearing short section.
Further, preferably, the attitude measurement unit includes: the system comprises at least one accelerometer and one magnetometer, wherein the accelerometer and the magnetometer are arranged on the axis of a bearing short section carrying a first signal transceiver unit and are used for measuring the inclination angle and the azimuth angle of the bearing short section carrying the first signal transceiver unit.
Further, preferably, the method further comprises: the lower communication circuit, the jumper wire, the upper communication circuit and the information remote transmission device are electrically connected from bottom to top in sequence;
the lower communication circuit is in communication connection with the first position resolving unit and/or the guide short section;
and the lower communication circuit transmits the signal from the first position resolving unit to the upper communication circuit through the jumper line, or the upper communication circuit transmits the signal to the lower communication circuit through the jumper line and transmits the signal to the guide short section through the lower communication circuit.
Further, preferably, in the directional drilling short joint string, the maximum deflection angle between the axes of two adjacent short joints is controlled by two adjacent load-bearing short joints through a structural dead point of the hinge structure, and when the position of the structural dead point is reached between two adjacent short joints, the maximum deflection angle is 2-10 degrees.
Further, preferably, the transducers operate in the range of 20-200 khz, or two or more transducers are used to operate in multiple frequency bands, wherein a transducer operating in a low frequency band is used to perform positioning in a long distance condition and a high frequency transducer is used to perform positioning in a short distance condition.
Compared with the prior art, the invention provides a high-curvature branch well position control device, which has the following beneficial effects:
the invention comprises two drilling tool combinations which are respectively arranged in two wells to be communicated or keep a distance with each other, wherein at least one set of the drilling tools comprises a directional drilling short section serial which is arranged in a high-curvature branch well and is used for communicating well operation by penetrating a high-curvature well section with a curvature radius within a preset range, and the two drilling tools are respectively provided with a first signal transceiving unit and a second signal transceiving unit, wherein the second signal transceiving unit can calculate the relative position relation between the first signal transceiving unit and the second signal transceiving unit by receiving signals transmitted by the first signal transceiving unit, or the first signal transceiving unit can calculate the relative position relation between the first signal transceiving unit and the second signal transceiving unit by receiving signals transmitted by the second signal transceiving unit, so that the positioning of the high-curvature branch well and other wells can be realized, in addition, the directional drilling short section string is formed by connecting a plurality of bearing short sections in a hinged mode, the flexibility is high, and the directional drilling short section string can transmit or detect signals through a high-curvature well section with the curvature radius within a preset range.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to the drawings without creative efforts. In the drawings:
FIG. 1 is a schematic diagram of a first high-curvature lateral position control apparatus according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of a second high-curvature lateral position control apparatus in accordance with an embodiment of the present invention;
FIG. 3 is a schematic diagram of a third high-curvature lateral position control apparatus in accordance with an embodiment of the present invention;
FIG. 4 is a partial schematic view of a second high curvature lateral position control device in accordance with an embodiment of the present invention;
in the figure:
1, guiding a short joint to move to a position,
2, a short loading joint is arranged on the bearing,
3, a drill bit is used for drilling the hole,
4 a first signal transceiving unit for receiving and transmitting signals,
5 a first position-resolving unit for determining a position of the object,
6 a lower communication circuit is arranged on the lower part of the device,
7 the line is bridged by a jumper wire,
8 a communication circuit is arranged on the base station,
9, the information remote-transmitting device is arranged,
10 are connected across the measuring line or lines,
11 a closed-loop control module for controlling the operation of the motor,
12 a second signal-transceiving unit for receiving and transmitting signals,
14 a magnetic field emission means for emitting a magnetic field,
15 of the torque-transmitting pins, and 15 of the same,
16 of the torque-transmitting grooves are formed,
19 a second position resolving module for determining a second position of the vehicle,
121 a signal transmission module for transmitting a signal,
122 a signal pick-up module for picking up the signal,
x a first drill string to be drilled,
the Y-directional drilling short section is connected in series,
z a second drill string, the second drill string,
k a second downhole tool string,
a, branching a well bore,
b target borehole.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the embodiments of the present invention are further described in detail below with reference to the accompanying drawings. The illustrative embodiments of the present invention and the description thereof are provided to explain the present invention and should not be construed as limiting the present invention
Referring to fig. 1-2, in an embodiment of the present invention, a high-curvature branch well position control apparatus includes: the directional drilling pup joint string Y can penetrate through a branch well A with the curvature radius within a preset range, and a second signal transceiving unit, a resolving module and a controller are positioned in another target well B;
the directional drilling short section tandem comprises a plurality of bearing short sections which are connected in a hinged mode, and the bearing short section positioned at the lower part is also connected with the guide short section;
the second signal transceiving unit 12 can transmit signals to the directional drilling pup joint string Y and the stratum where the directional drilling pup joint string Y is located, or receive signals fed back or transmitted by the directional drilling pup joint string Y;
the resolving module is used for resolving the relative position relation between the directional drilling nipple string Y and the target borehole B and controlling the directional drilling nipple string to adjust or keep the preset relative position relation with the target borehole B through the controller.
As shown in fig. 1, in this embodiment, the method further includes:
a first drill string X arranged above the directional drilling nipple string Y and used for conveying the directional drilling nipple string Y into the branch well hole A;
the length of the directional drilling pup joint string is greater than that of a branch well section of the branch well bore;
the bearing short section 2 is connected in series in the directional drilling short section series Y in a hinged mode, and the axial length of the bearing short section 2 is less than or equal to 5 times of the outer diameter of the guide short section 1;
the downhole tool string comprises a first signal transceiving unit and a second signal transceiving unit, wherein the first signal transceiving unit is arranged in the first downhole tool string. The resolving module is a second position resolving module, is in communication connection with the second signal transceiving unit and is used for resolving the position relation between the directional drilling pup joint string and the second downhole tool string by adopting data measured by the second signal transceiving unit, and the second position resolving module can be arranged in the second downhole tool string or at the wellhead end;
the controller is a wellhead control end, the wellhead control end is respectively in communication connection with the directional drilling pup joint string and the second position calculation module, and is used for controlling the directional drilling pup joint string to adjust or keep a preset relative position relation with a target borehole by adopting the position relation between the directional drilling pup joint string and the second downhole tool string obtained by calculation of the calculation module, and the wellhead control end can be an FPGA (field programmable gate array) and/or a digital chip and/or an engineer capable of executing control and communication functions;
the second position calculating module is in cable communication connection with the second signal transceiving unit, the second position calculating module is in wired or wireless communication connection with the wellhead control end, the wellhead control end adopts an instruction downloading device to adjust the pressure or the discharge capacity of the drilling fluid supplied to the directional drilling nipple serial to realize the downloading of a control instruction, so that the directional drilling nipple serial is controlled to be adjusted or to be kept in a preset relative position relation with a target borehole.
In this embodiment, the second downhole tool string at least includes two second signal transceiver units, where the second signal transceiver units are electromagnetic probe probes, and are used to transmit and/or receive electromagnetic wave signals to the formation; the at least one second signal transceiving unit is provided with a signal transmitting module and is used for applying transient electromagnetic excitation signals to the electromagnetic probe; the at least one second signal transceiving unit comprises a signal pickup module for picking up a secondary eddy current field signal induced in the electromagnetic probe from the directional drilling sub string Y, and it should be explained that the signal pickup module can transmit the secondary eddy current field signal to a resolving module through a cable, and the resolving module is used for analyzing the relative position relationship between the second downhole tool string and the directional drilling sub string Y.
In this embodiment, the second downhole tool string comprises at least one set of phased array acoustic transceiver units, the acoustic transceiver units comprising transducers for transmitting and/or receiving acoustic signals in a controllable direction; the device also comprises an excitation circuit, a signal processing circuit and a signal processing circuit, wherein the excitation circuit is used for driving the transducer to emit an acoustic signal; the system comprises a phased array acoustic signal transceiving unit, a transducer, a signal pickup circuit and a resolving module, wherein the phased array acoustic signal transceiving unit is used for receiving signals transmitted by the transducer, and the signals are transmitted to the resolving module through a cable.
As shown in fig. 2, in this embodiment, the directional drilling pup joint string Y further includes a first signal transceiver unit 4, where the first signal transceiver unit 4 is disposed in any of the bearing pups 2;
the second signal transceiver unit can calculate the relative position relationship between the first signal transceiver unit and the second signal transceiver unit by receiving the signal transmitted by the first signal transceiver unit, or the first signal transceiver unit can calculate the relative position relationship between the first signal transceiver unit and the second signal transceiver unit by receiving the signal transmitted by the second signal transceiver unit.
The directional drilling pup joint series is formed by connecting a plurality of bearing pup joints in a hinged mode, is high in flexibility, and can transmit or detect signals through a high-curvature well section with a curvature radius within a preset range; the drilling machine also comprises a transceiving unit, a control unit, a position calculating unit, a directional tool and a drill bit. The receiving and transmitting unit can transmit and/or detect a magnetic field, an electric field, electromagnetic waves and sound waves, and the position calculating unit is used for calculating the spatial position relation between the two wells to be positioned by using signals detected by the receiving and transmitting unit. The invention can realize the positioning of the high-curvature branch well and other wells. Further, the second signal transmitting unit may be lowered into the target borehole B by a wireline or may be fed into the target borehole B by a drill string.
The resolving module is connected with a first position resolving unit 5, and the first position resolving unit 5 is in communication connection with the first signal transceiving unit and is used for resolving a position relation between the directional drilling pup joint string and the second downhole tool string by adopting data measured by the first signal transceiving unit;
in this embodiment, the first signal transceiver unit 4 includes a magnetic sensor and a first position calculating unit 5, and the magnetic sensor is electrically connected to the first position calculating unit 5; the second signal transceiving unit 12 comprises a magnetic field transmitting device 14;
the controller is a closed-loop control module 11, the closed-loop control module is arranged in any bearing short section in the directional drilling short section string, and the closed-loop control module 11 is respectively in communication connection with the guide short section 1 and the first position calculating unit 5 and is used for controlling the directional drilling short section string to adjust or keep a preset relative position relation with the target well B by adopting the position relation between the directional drilling short section string and the target well obtained by the calculation of the first position calculating unit 5;
the magnetic field emission device 14 is a magnet; the second downhole tool string includes a second drill string Z capable of driving rotation of the magnet to produce an alternating magnetic field to be measured.
In this embodiment: this intercommunication well device includes: the system comprises at least one set of directional drilling pup joint string, a position calculating unit and a directional drilling tool, wherein the directional drilling pup joint string is used for measuring the communicated well by penetrating a high-curvature well section with the curvature radius within a preset range, which is completed by pre-drilling, and the directional drilling tool is used for drilling another well to realize the communication with the high-curvature well section with the curvature radius within the preset range, which is completed by pre-drilling; the directional drilling pup joint serial comprises a plurality of bearing pups joints and a plurality of first signal receiving and transmitting pups joints, wherein first signal receiving and/or signal transmitting units are arranged on the first signal receiving and transmitting pups joints; the bearing short sections are connected by adopting a joint structure and/or a torque transmission structure, and the bearing short sections are connected with the signal receiving and transmitting short sections by adopting a joint structure and/or a torque transmission structure; and the position calculating unit is used for acquiring the signals received by the signal transceiving unit and obtaining the distance and/or relative position relation between the directional drilling tool and the signal transceiving short section. The directional drilling pup joint string Y is arranged in the branch well hole A, and the directional drilling tool is arranged in other well holes. In addition, the directional drilling nipple string is used for entering the high-curvature branch well hole, the directional drilling nipple string is driven by a drill string, and the drill string enters the branch well hole through the directional drilling nipple string in the main well hole to perform measurement and positioning work of the communication well. Meanwhile, the directional drilling tool realizes bit feeding by another drill string to drill communicated wells. The first signal transceiver sub is not representative of only one signal transceiver sub, but is representative of a signal transceiver sub disposed on the directional drilling sub string.
In this embodiment, the first signal transceiving unit and the second signal transceiving unit each comprise a transducer, so as to transmit and/or receive signals to the formation in the form of sound waves; it should be noted that: the transducer can realize receiving and transmitting functions;
at least one bearing short section 2 is used for accommodating a control unit and a first position calculating unit 5, and the bearing short section 2 is connected in series at any position in the directional drilling short section serial Y in a hinged mode, or arranged above the directional drilling short section serial Y, or arranged below the directional drilling short section serial Y;
the control unit and the first position resolving unit 5 are electrically connected with the first signal transceiving unit 4 through a cross-over measuring line 10, and when the control unit and the first position resolving unit 5 are control units, the control unit and the first position resolving unit 5 are used for controlling the first signal transceiving unit 4 to transmit signals to the stratum, and when the control unit and the first position resolving unit 5 are position resolving units, the control unit and the first position resolving unit 5 are used for collecting the stratum signals received by the first signal transceiving unit 4.
In this embodiment, the first signal transceiver unit and the second signal transceiver unit each include a coil, and/or the first signal transceiver unit and the second signal transceiver unit each include a transducer;
the directional drilling pup joint string Y at least comprises two first signal transceiving units so as to transmit and/or receive signals to the stratum in the form of electromagnetic waves or sound waves;
and each first signal transceiving unit is respectively arranged on different bearing short sections.
In this embodiment, the first signal transceiver unit and the second signal transceiver unit each include a coil, and/or the first signal transceiver unit and the second signal transceiver unit each include a transducer;
a second drill string; the second drill string comprises at least two second signal transceiving units so as to transmit and/or receive signals to and/or from the stratum in the form of electromagnetic waves and/or sound waves;
and each second signal transceiver unit is respectively arranged on different bearing short joints of a second drill string.
As a preferred embodiment, the method further comprises the following steps: and the elastic piece is a spring plate, an elastic rod or an elastic tube and penetrates through the directional drilling short section serial Y, and is used for enabling the plurality of bearing short sections bearing the first signal receiving and transmitting units 4 to be in a coaxial state with the adjacent bearing short sections.
As a preferred embodiment, the method further comprises the following steps: and the attitude measuring unit and the first signal transceiving unit 4 are arranged on the same bearing short section 2.
As a preferred embodiment, the attitude measurement unit includes: the system comprises at least one accelerometer and one magnetometer, wherein the accelerometer and the magnetometer are arranged on the axis of a bearing short section carrying a first signal transceiver unit and are used for measuring the inclination angle and the azimuth angle of the bearing short section carrying the first signal transceiver unit.
As a preferred embodiment, the method further comprises the following steps: the lower communication circuit 6, the jumper line 7, the upper communication circuit 8 and the information remote transmission device 9 are electrically connected from bottom to top in sequence;
the lower communication circuit 6 is in communication connection with the first position resolving unit 5 and/or the guide short joint 1;
the lower communication circuit 6 transmits the signal from the first position resolving unit 5 to the upper communication circuit 8 through the jumper 7, or the upper communication circuit 8 transmits the signal to the lower communication circuit 6 through the jumper 7 and transmits the signal to the guide short section 1 through the lower communication circuit 6.
The information remote transmission device 9 is used for transmitting a communicated well signal to a receiving end at the wellhead through the first drill string X, or receiving a control instruction transmitted to the guide short joint 1 by a wellhead control end through the first drill string X
In a preferred embodiment, in the directional drilling short joint string Y, two adjacent load-bearing short joints control the maximum deflection angle between the axes of two adjacent short joints through the structural dead point of the hinge structure, and when the structural dead point position is reached between two adjacent short joints, the maximum deflection angle is 2-10 degrees.
As shown in fig. 3, in a preferred embodiment, the second signal transceiver unit 12 is a transducer, and the working range of the transducer is 20-200 khz, or two or more transducers are used to realize the working in multiple frequency bands, wherein a transducer working in a low frequency band is used to realize the positioning in a long distance condition, and a transducer working in a high frequency band is used to realize the positioning in a short distance condition.
Example 1: as shown in fig. 2, the first signal transceiving unit 4 includes a magnetic sensor and a first position calculating unit 5, and the magnetic sensor is electrically connected to the first position calculating unit 5; the second signal transceiving unit 12 comprises magnetic field emitting means 14.
Further, the magnetic field emission device 14 is a magnet;
the device also comprises a second drill string Z which can drive the magnet to rotate so as to generate an alternating magnetic field to be measured;
or the like, or, alternatively,
a motor is connected between the second drill string and the magnet and can drive the magnet to rotate so as to generate an alternating magnetic field to be measured;
or, the second drill string drives the magnetic field emission device 14 to rotate through the second short section string K, so as to generate an alternating magnetic field to be measured.
Example 2: the first signal transceiving unit 4 comprises a magnetic field transmitting device 14; the second signal transceiving unit includes a magnetic sensor and a second position calculating module 19, and the magnetic sensor is electrically connected to the second position calculating module 19.
Example 3: as shown in fig. 3, the first signal transceiving unit 4 includes a receiving transducer and a first position calculating unit 5, and the receiving transducer is electrically connected to the position calculating unit; the second signal transceiving unit 12 comprises a transmitting transducer;
example 4: the second signal transceiving unit 12 comprises a receiving transducer and a second position resolving module 19, wherein the receiving transducer is electrically connected with the second position resolving module 19; the first signal transceiving unit comprises a transmitting transducer.
The above description is only for the preferred embodiment of the present invention, but the scope of the present invention is not limited thereto, and any person skilled in the art should be considered to be within the technical scope of the present invention, and the technical solutions and the inventive concepts thereof according to the present invention are equivalent to or changed within the technical scope of the present invention.
Claims (18)
1. A high curvature lateral well position control device, comprising: the directional drilling pup joint string (Y) can penetrate through a branched well (A) with the curvature radius within a preset range, a second signal transceiving unit (12) positioned in another target well (B), a resolving module and a controller;
the directional drilling short section tandem (Y) comprises a plurality of bearing short sections (2) connected in a hinged mode, and the bearing short section (2) positioned at the lower part is also connected with the guide short section (1);
the second signal transceiving unit (12) can transmit signals to the directional drilling pup joint string (Y) and the stratum where the directional drilling pup joint string is located, or receive signals fed back or transmitted by the directional drilling pup joint string (Y);
the resolving module is used for resolving the relative position relation between the directional drilling nipple string (Y) and the target borehole (B) and controlling the directional drilling nipple string to adjust or keep the preset relative position relation with the target borehole (B) through the controller.
2. The high curvature lateral position control device of claim 1, further comprising:
a first drill string (X) disposed above the string of directional drilling subs (Y) for conveying the string of directional drilling subs (Y) into the lateral wellbore (A);
the length of the directional drilling pup joint string is greater than that of a branch well section of the branch well bore;
the bearing short section (2) is connected in series in the directional drilling short section string (Y) in a hinged mode, and the axial length of the bearing short section (2) is less than or equal to 5 times of the outer diameter of the guide short section (1);
the downhole tool string comprises a first signal transceiver unit and a second signal transceiver unit, wherein the first signal transceiver unit is arranged in the first downhole tool string;
the resolving module and a second position resolving module (19), the second position resolving module (19) is in communication connection with the second signal transceiving unit and is used for resolving the position relation between the directional drilling pup joint string and the second downhole tool string by adopting data measured by the second signal transceiving unit;
the controller is a wellhead control end, the wellhead control end is in communication connection with the directional drilling nipple string (Y) and the second position calculation module (19) respectively, and the position relation between the directional drilling nipple string and the second downhole tool string obtained through calculation by the second position calculation module (19) is used for controlling the directional drilling nipple string to adjust or keep a preset relative position relation with a target borehole (B).
3. A high curvature lateral position control device as claimed in claim 2, wherein the second downhole tool string comprises at least two second signal transceiving elements, the second signal transceiving elements being electromagnetic probe heads for transmitting and/or receiving electromagnetic wave signals; wherein the at least one second signal transceiving unit has a signal transmitting module (121) for applying a transient electromagnetic excitation signal to the electromagnetic probe; at least one second signal transceiving unit comprises a signal pickup module (122) for picking up secondary eddy current field signals induced in the electromagnetic probe from the directional drilling sub string (Y).
4. A high curvature lateral position control device as claimed in claim 2, wherein the second downhole tool string comprises at least one set of phased array acoustic transceiver units comprising transducers for steerable transmission and/or reception of acoustic signals; the acoustic signal transmitting module is used for driving the transducer to transmit an acoustic signal; the system also comprises an acoustic signal pickup module which is used for picking up a reflected signal received by the transducer from the directional drilling short joint string (Y).
5. A high curvature lateral position control device according to claim 1, wherein the directional drilling sub string (Y) further comprises a first signal transceiver unit (4), the first signal transceiver unit (4) being arranged in any of the carrier sub (2);
the second signal transceiver unit can calculate the relative position relationship between the first signal transceiver unit and the second signal transceiver unit by receiving the signal transmitted by the first signal transceiver unit, or the first signal transceiver unit can calculate the relative position relationship between the first signal transceiver unit and the second signal transceiver unit by receiving the signal transmitted by the second signal transceiver unit.
6. A high curvature lateral well position control device according to claim 5, characterized in that the first signal transceiver unit (4) comprises a magnetic sensor and a first position resolving unit (5), the magnetic sensor being electrically connected with the first position resolving unit (5); the second signal transceiving unit (12) comprises a magnetic field transmitting device (14);
the resolving module is connected with a first position resolving unit (5), and the first position resolving unit (5) is in communication connection with the first signal transceiving unit and is used for resolving the position relation between the directional drilling pup joint string and the second downhole tool string by adopting data measured by the first signal transceiving unit;
the controller is a closed-loop control module (11), the closed-loop control module is arranged in any bearing short section in the directional drilling short section string, the closed-loop control module (11) is in communication connection with the guide short section (1) and the first position calculating unit (5) respectively and is used for calculating by the first position calculating unit (5) to obtain the position relation between the directional drilling short section string and the target well and controlling the directional drilling short section string to adjust or keep the preset relative position relation with the target well hole (B).
7. The high curvature lateral position control device of claim 6, wherein the magnetic field emitting device (14) is a magnet;
the second downhole tool string comprising a second drill string (Z) capable of driving the magnet in rotation, thereby generating an alternating magnetic field to be measured;
or the like, or, alternatively,
a motor is connected between the second drill string and the magnet and can drive the magnet to rotate so as to generate an alternating magnetic field to be measured;
or the second drill string drives the magnetic field emission device (14) to rotate through the second short section string (K), so that an alternating magnetic field to be measured is generated.
8. A high curvature lateral well position control device according to claim 5, characterized in that the first signal transceiving unit (4) comprises a magnetic field emitting device (14); the second signal transceiving unit comprises a magnetic sensor and a second position resolving module (19), and the magnetic sensor is electrically connected with the second position resolving module (19).
9. A high curvature lateral well position control device according to claim 5, wherein the first signal transceiver unit (4) comprises a receiving transducer and a first position resolving unit (5), the receiving transducer being electrically connected to the position resolving unit; the second signal transceiving unit (12) comprises a transmitting transducer;
or
The second signal transceiving unit (12) comprises a receiving transducer and a second position resolving module (19), wherein the receiving transducer is electrically connected with the second position resolving module (19); the first signal transceiving unit comprises a transmitting transducer.
10. A high curvature lateral position control device as claimed in claim 5, wherein the first and second signal transceiving units each comprise a transducer to transmit and/or receive signals in the form of acoustic waves into the formation;
at least one bearing short section (2) is used for accommodating a control unit and a first position calculating unit (5), and the bearing short section (2) is connected in series at any position in the directional drilling short section serial (Y) in a hinged mode, or is arranged above the directional drilling short section serial (Y), or is arranged below the directional drilling short section serial (Y);
the control unit and the first position resolving unit (5) are electrically connected with the first signal transceiving unit (4) through a cross-over measuring line (10), and when the control unit and the first position resolving unit (5) are control units, the control unit and the first position resolving unit (5) are used for controlling the first signal transceiving unit (4) to transmit signals to the stratum, and when the control unit and the first position resolving unit (5) are position resolving units, the control unit and the first position resolving unit are used for collecting the stratum signals received by the first signal transceiving unit (4).
11. A high curvature lateral well position control device as claimed in claim 5, wherein the first and second signal transceiving units each comprise a coil, and/or wherein the first and second signal transceiving units each comprise a transducer;
the directional drilling pup joint string (Y) at least comprises two first signal transceiving units so as to transmit and/or receive signals to the stratum in the form of electromagnetic waves or sound waves;
and each first signal transceiving unit is respectively arranged on different bearing short sections.
12. A high curvature lateral well position control device as claimed in claim 5, wherein the first and second signal transceiving units each comprise a coil, and/or wherein the first and second signal transceiving units each comprise a transducer;
a second drill string; the second drill string comprises at least two second signal transceiving units so as to transmit and/or receive signals to and/or from the stratum in the form of electromagnetic waves and/or sound waves;
and each second signal transceiver unit is respectively arranged on different bearing short joints of a second drill string.
13. The high curvature lateral position control device of claim 5, further comprising: and the elastic piece penetrates through the directional drilling short section string (Y) and is used for enabling the bearing short sections bearing the first signal transceiving units (4) to be in a coaxial state with the adjacent bearing short sections.
14. The high curvature lateral position control device of claim 5, further comprising: and the attitude measurement unit and the first signal transceiving unit (4) are arranged on the same bearing short section (2).
15. The high curvature lateral position control device of claim 14, wherein the attitude measurement unit comprises: the system comprises at least one accelerometer and one magnetometer, wherein the accelerometer and the magnetometer are arranged on the axis of a bearing short section carrying a first signal transceiver unit and are used for measuring the inclination angle and the azimuth angle of the bearing short section carrying the first signal transceiver unit.
16. A high curvature lateral well position control device as claimed in any one of claims 2, 5, 8-9, 14-15, further comprising: a lower communication circuit (6), a jumper line (7), an upper communication circuit (8) and an information remote transmission device (9) which are electrically connected from bottom to top in sequence;
the lower communication circuit (6) is in communication connection with the first position resolving unit (5) and/or the guide short section (1);
the lower communication circuit (6) transmits signals from the first position resolving unit (5) to the upper communication circuit (8) through the jumper line (7), or the upper communication circuit (8) transmits signals to the lower communication circuit (6) through the jumper line (7) and transmits the signals to the guide short joint (1) through the lower communication circuit (6).
17. The high-curvature lateral well position control device according to claim 1, wherein in the directional drilling sub string (Y), two adjacent load-bearing subs control the maximum deflectable angle between the axes of two adjacent subs through the structural dead point of the hinge structure, and when the structural dead point position is reached between two adjacent subs, the maximum deflectable angle is 2 ° to 10 °.
18. A high curvature lateral well position control device as claimed in any one of claims 4, 10 to 12, wherein the transducers are operated in the range of 20-200 khz or in multiple frequency bands by two or more transducers, wherein transducers operating in the low frequency band are used for positioning at long distances and high frequency transducers are used for positioning at short distances.
Priority Applications (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202110654607.1A CN113236224A (en) | 2021-06-11 | 2021-06-11 | High-curvature branch well position control device |
| PCT/CN2022/096137 WO2022253208A1 (en) | 2021-06-02 | 2022-05-31 | High curvature branch well position control apparatus |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202110654607.1A CN113236224A (en) | 2021-06-11 | 2021-06-11 | High-curvature branch well position control device |
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| CN113236224A true CN113236224A (en) | 2021-08-10 |
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| CN202110654607.1A Pending CN113236224A (en) | 2021-06-02 | 2021-06-11 | High-curvature branch well position control device |
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Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2022253208A1 (en) * | 2021-06-02 | 2022-12-08 | 徐梓辰 | High curvature branch well position control apparatus |
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