A method, apparatus and storage medium for transmission while drilling

Abstract

This invention provides a transmission-while-drilling (TSD) encoding method, comprising: setting a parameter offset vector, wherein the parameter offset vector is the vector of minimum values ​​of each parameter in a pre-set length of wellbore subsequently drilled; obtaining the actual measured parameter vectors through downhole measurement, combining the parameter offset vectors with pulse position modulation encoding to obtain an encoded signal, and generating a mud pulse pressure wave signal based on the encoded signal; decoding the acquired mud pulse pressure wave signal at the surface, and reconstructing the actual measured parameter vectors by combining the parameter offset vectors. This invention overcomes the problems of long transmission time and low bandwidth utilization in conventional pulse position modulation encoding when transmitting large amounts of data. The device has a reasonable structure, is easy to manufacture, and has strong adaptability, effectively improving the transmission efficiency of downhole data.

Description

Technical Field

[0001] This invention relates to the field of drilling engineering technology in oil and gas exploration and development, and more specifically, to a method, apparatus and storage medium for transmitting codes while drilling. Background Technology

[0002] During oil drilling, especially in complex well structures such as horizontal wells, extended reach wells, and branch wells, well site personnel need to monitor various downhole parameters in real time, such as well inclination, azimuth, and tool face. Measurement While Drilling (MWD) technology is essential for achieving this. By uploading formation and drilling data in real time, MWD technology can reduce rig downtime and ensure data acquisition in high-risk wells. Mud pulse transmission is a commonly used data transmission method. Its principle is that downhole instruments use pulse generators to change the mud pressure in the drill string, creating pressure waves that transmit measurement data to the surface in pulse form. Based on the pulse generation method, mud pulse transmission can be divided into positive pulse, negative pulse, and continuous wave transmission. Negative pulse transmission is rarely used nowadays due to its destructive effect on the wellbore.

[0003] With the successful development and application of various new downhole measurement instruments, the amount of information that needs to be uploaded from downhole is increasing daily. Therefore, the transmission rate of mud pulse data transmission systems is gradually becoming a bottleneck in measurement-while-drilling (MSWD) systems. Solutions to this problem mainly include two approaches: improving positive pulse transmission and developing continuous wave transmission. Positive pulse transmission has advantages such as simple instrument structure, convenient operation and maintenance, and stable and reliable signal transmission, making it the most widely used mud pulse transmission method at present, but its transmission rate is relatively low. Continuous wave transmission has a higher transmission rate, but its signal is susceptible to interference and its instrument reliability is poor; currently, it is still in the experimental stage in China. Therefore, "tapping the potential" of traditional positive pulse transmission is a rapid and feasible method at this stage.

[0004] The transmission channel in mud is extremely harsh; pulse signals attenuate continuously during transmission and are interfered with by various environmental factors. To enhance anti-interference capabilities, data encoding is essential. Pulse Position Modulation (PPM) is a commonly used method for transmitting mud pulse data. Its principle is that one pulse represents one hexadecimal number (0-F), the specific number depending on its position, i.e., the time interval between it and the previous pulse or synchronization pulse. The time required for data transmission using PPM changes with the data being transmitted. Traditional PPM does not consider the data characteristics of the application environment; the time required to transmit data "0x0" is always less than the time required to transmit data "0xF". This can lead to a significant waste of transmission bandwidth in certain situations (e.g., when the data to be transmitted is always near "0xF").

[0005] To address the aforementioned problems in the prior art, the present invention provides a method, apparatus, and storage medium for transmission encoding while drilling. Summary of the Invention

[0006] To address the problems of the prior art, the present invention provides a method for transmission coding while drilling, the method comprising the following steps:

[0007] Set a parameter offset vector, which is the vector of minimum values ​​of each parameter for subsequent drilling of a wellbore of a preset length;

[0008] The actual measurement vector of the parameters is obtained from downhole measurement. The parameter offset vector is combined with the pulse position modulation encoding to obtain the encoded signal. The mud pulse pressure wave signal is generated based on the encoded signal.

[0009] The mud pulse pressure wave signal collected on the ground is decoded, and combined with the parameter offset vector, the actual measurement vector of the parameter is restored.

[0010] According to one embodiment of the present invention, setting the parameter offset vector includes setting the parameter offset vector by a downhole codec controller before the drilling transport instrument is run into the well.

[0011] According to one embodiment of the present invention, setting the parameter offset vector includes:

[0012] Based on the actual measurement vector of the current parameters received from the ground and the subsequent wellbore design trajectory parameters, the parameter offset vector is set;

[0013] Based on the parameter offset vector, the mud is diverted according to the time sequence encoding, so that the mud flow rate in the wellbore changes according to the time sequence.

[0014] The latest parameter offset vector is obtained by timing decoding based on the flow velocity change signal.

[0015] According to one embodiment of the present invention, pulse position modulation coding is performed in conjunction with the parameter offset vector to obtain a coded signal, and a mud pulse pressure wave signal is generated based on the coded signal, comprising:

[0016] Subtract the parameter offset vector from the actual measured vector of the parameter to obtain the parameter difference vector;

[0017] The parameter difference vector is subjected to pulse position modulation encoding to obtain the encoded signal;

[0018] Under the control of the encoded signal, the mud is blocked or allowed to pass through, thereby generating the mud pulse pressure wave signal.

[0019] According to one embodiment of the present invention, the mud pulse pressure wave signal acquired on the ground is decoded, and combined with the parameter offset vector, the actual measurement vector of the parameter is reconstructed, including:

[0020] Acquire the mud pulse pressure wave signal transmitted from downhole;

[0021] The parameter difference vector is decoded from the mud pulse pressure wave signal;

[0022] The parameter difference vector is added to the parameter offset vector to restore the actual measured vector of the parameter.

[0023] According to another aspect of the present invention, a drilling transport coding apparatus is also provided, which performs a drilling transport coding method as described in any of the preceding claims, the apparatus comprising:

[0024] The downhole unit is used to measure the actual measurement vector of the parameters, combine the parameter offset vector with pulse position modulation encoding to obtain an encoded signal, and generate a mud pulse pressure wave signal based on the encoded signal.

[0025] The surface unit is used to set the parameter offset vector, which is the minimum value vector of each parameter for subsequent drilling of a preset length of wellbore, and to decode the acquired mud pulse pressure wave signal, and combine it with the parameter offset vector to restore the actual measurement vector of the parameter.

[0026] According to one embodiment of the present invention, the downhole unit comprises:

[0027] A downhole encoder / decoder controller is used to set the parameter offset vector before going downhole and combine it with the actual measured parameter vector to perform pulse position modulation encoding to obtain the encoded signal;

[0028] A measuring probe, used to measure and obtain the actual measurement vector of the parameters;

[0029] A mud pulse generator is used to generate the mud pulse pressure wave signal based on the encoded signal.

[0030] According to one embodiment of the present invention, the ground unit comprises:

[0031] A pressure sensor is used to acquire the mud pulse pressure wave signal to generate a mud pulse electrical signal;

[0032] The ground calculation module is used to decode the mud pulse electrical signal and, in combination with the parameter offset vector, reconstruct the actual measurement vector of the parameter.

[0033] According to one embodiment of the present invention, the device includes a mud diversion unit for diverting the mud circulating in the wellbore under the control of the surface computing module, thereby causing the mud flow rate circulating in the wellbore to change according to a set time sequence.

[0034] According to another aspect of the invention, a storage medium is also provided, which includes instructions for performing the methods described in any of the preceding claims.

[0035] The present invention provides a method, apparatus, and storage medium for transmitting data while drilling, which has the following advantages: it overcomes the problems of long transmission time and low bandwidth utilization in conventional pulse position modulation coding when transmitting large amounts of data. The apparatus has a reasonable structure, is easy to manufacture, and is highly adaptable, effectively improving the transmission efficiency of downhole data.

[0036] Other features and advantages of the invention will be set forth in the description which follows, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures particularly pointed out in the description, claims, and drawings. Attached Figure Description

[0037] The accompanying drawings are provided to further illustrate the invention and form part of the specification. They are used in conjunction with the embodiments of the invention to explain the invention and do not constitute a limitation thereof. In the drawings:

[0038] Figure 1 A flowchart of a drilling transport coding method according to an embodiment of the present invention is shown;

[0039] Figure 2 A simplified flowchart of a drilling transport coding method according to an embodiment of the present invention is shown;

[0040] Figure 3A complete flowchart of the drilling transport coding method according to an embodiment of the present invention is shown;

[0041] Figure 4 The diagram shows a waveform of transmitting the same data using different encoding methods according to an embodiment of the present invention.

[0042] Figure 5 A schematic diagram of a drilling transport encoding device according to an embodiment of the present invention is shown.

[0043] In the accompanying drawings, the same parts use the same reference numerals. The drawings are not drawn to scale.

[0044] The meanings of the reference numerals in the attached drawings are as follows: 1-Wellbore; 2-Non-magnetic drill collar; 10-Downhole codec controller; 20-Measuring probe; 30-Mud pulse generator; 40-Generator rotor; 50-Generator rectifier module; 60-Generator rotor speed measurement module; 70-Surface pressure wave acquisition module; 71-Pressure sensor; 80-Surface calculation module; 90-Mud pump; 100-Mud diversion pipe; 101-Diversion valve; 102-Diversion valve controller; 110-Mud pit; 120-Riser. Detailed Implementation

[0045] To make the objectives, technical solutions, and advantages of the present invention clearer, the embodiments of the present invention will be further described in detail below with reference to the accompanying drawings.

[0046] The purpose of this invention is to address the shortcomings of existing technologies and provide a method, apparatus, and storage medium for transmission while drilling (DWD) encoding, specifically relating to downhole measurement while drilling (MWD) technology, particularly for the encoded transmission of downhole mud pulse signals. Compared with conventional pulse position modulation encoding methods and apparatuses, the method, apparatus, and storage medium provided by this invention take into account the data characteristics of the downhole measurement environment. Through a mud pulse uplink and downlink system, larger measurement values ​​are converted into smaller measurement values, shortening the transmission time of larger measurement values ​​and improving the transmission efficiency of downhole data.

[0047] Figure 1 A flowchart of a drilling transport coding method according to an embodiment of the present invention is shown.

[0048] like Figure 1 As shown, in step S1, a parameter offset vector X0 is set. The parameter offset vector X0 is the minimum value vector of each parameter for subsequent drilling of a pre-set length of wellbore. Specifically, the parameter offset vector X0 = [INC0, AZI0, TF0, TEMP0…], where X0 is the minimum value vector of each parameter for subsequent drilling of a pre-set length of wellbore. Here, INC represents well inclination, AZI represents azimuth, TF represents tool face, and TEMP represents temperature.

[0049] In one embodiment, the parameter offset vector X0 is set in two ways. The first way is to set the parameter offset vector X0 through the downhole codec controller 10 before the drilling transport instrument is run into the well. The second way is to set the parameter offset vector X0 based on the actual measured vector X1 of the current parameter received from the surface and the subsequent wellbore design trajectory parameters; based on the parameter offset vector X0, the mud is diverted according to time-series encoding, so that the mud flow velocity in the wellbore changes according to time; and the latest parameter offset vector X0 is obtained by time-series decoding based on the flow velocity change signal.

[0050] like Figure 1 As shown, in step S2, the downhole measurement obtains the actual measurement vector X1 of the parameters, combines it with the parameter offset vector X0 to perform pulse position modulation encoding to obtain the encoded signal, and generates the mud pulse pressure wave signal based on the encoded signal.

[0051] In one embodiment, step S2 includes: subtracting the parameter offset vector X0 from the actual parameter measurement vector X1 to obtain the parameter difference vector X2; performing pulse position modulation encoding on the parameter difference vector X2 to obtain an encoded signal; and blocking or allowing the mud to pass under the control of the encoded signal to generate a mud pulse pressure wave signal.

[0052] like Figure 1 As shown, in step S3, the mud pulse pressure wave signal collected on the ground is decoded, and combined with the parameter offset vector, the actual parameter measurement vector X1 is restored.

[0053] In one embodiment, step S3 includes: acquiring a mud pulse pressure wave signal on the ground; decoding a parameter difference vector X2 from the mud pulse pressure wave signal; and adding a parameter offset vector X0 to the parameter difference vector X2 to reconstruct the actual parameter measurement vector X1.

[0054] Figure 2 A simplified flowchart of a drilling transport coding method according to an embodiment of the present invention is shown.

[0055] like Figure 2 As shown, in step S201, the downhole codec controller 10 sets the parameter offset vector X0. Specifically, before the drilling transport instrument is run into the well, the surface engineer sets the parameter offset vector X0 = [INC0, AZI0, TF0, TEMP0…] through the downhole codec controller 10, where X0 is the minimum value vector of each parameter for the subsequent drilling of a preset length of wellbore. Here, INC represents well inclination, AZI represents azimuth, TF represents tool face, and TEMP represents temperature.

[0056] like Figure 2As shown, in step S202, the parameter difference vector X2 is obtained by subtracting the parameter offset vector X0 from the actual parameter measurement vector X1. Specifically, the drilling transport instrument enters the bottom of the well, and the measurement probe 20 continuously measures data. The codec controller 10 reads the parameter offset vector X0 and the actual parameter measurement vector X1. X1 is subtracted from X0 to obtain the parameter difference vector X2, which is always greater than 0.

[0057] like Figure 2 As shown, in step S203, the parameter difference vector X2 is pulse position modulated and encoded, and then transmitted to the ground via mud pulses. Specifically, the encoder / decoder controller 10 performs pulse position modulation and encoding on the parameter difference vector X2 to obtain an encoded signal. The encoder / decoder controller 10 transmits the encoded signal to the mud pulse generator 30, controlling the mud pulse generator 30 to generate a mud pulse pressure wave signal that is transmitted to the ground.

[0058] like Figure 2 As shown, in step S204, the ground calculation module 80 decodes the parameter difference vector X2. Specifically, pressure data is collected by the pressure sensor 71 and the ground pressure wave acquisition module 70 and sent to the ground calculation module 80, which then decodes the parameter difference vector X2 from the collected data.

[0059] like Figure 2 As shown, in step S205, the parameter difference vector X2 is added to the parameter offset vector X0 to obtain the actual parameter measurement vector X1. Specifically, the ground calculation module 80 decodes the parameter difference vector X2, and adds it to the parameter offset vector X0 to obtain the actual parameter measurement vector X1.

[0060] Figure 3 A complete flowchart of the drilling transport coding method according to an embodiment of the present invention is shown.

[0061] like Figure 3 As shown, in step S301, the ground calculation module 80 sets the parameter offset vector X0. Specifically, the ground calculation module 80 resets the parameter offset vector X0 based on the received current parameter actual measurement vector X1 and subsequent wellbore design trajectory parameters, and encodes and sends this value to the diversion valve controller 102.

[0062] like Figure 3As shown, in step S302, the mud diversion unit transmits the parameter offset vector X0 to the downhole codec controller 10. Specifically, the diversion valve controller 102 controls the diversion valve 101 to divert mud through the mud diversion pipe 100 according to the time sequence encoding, thereby further causing the mud flow velocity in the wellbore 1 to change according to the time sequence. The rotational speed of the downhole generator rotor 40 changes with the mud flow velocity. The generator rotor speed measurement module 60 detects the change in rotational speed, and then detects the change in mud flow velocity, and transmits the flow velocity change signal to the codec controller 10. The codec controller 10 obtains the latest parameter offset vector X0 through time sequence decoding.

[0063] like Figure 3 As shown, in step S303, the parameter difference vector X2 is obtained by subtracting the parameter offset vector X0 from the actual parameter measurement vector X1. Specifically, the measuring probe 20 continuously measures data. The encoder / decoder controller 10 reads the parameter offset vector X0 and the actual parameter measurement vector X1. X0 is subtracted from X1 to obtain the parameter difference vector X2, which is always greater than 0.

[0064] like Figure 3 As shown, in step S304, the parameter difference vector X2 is pulse position modulated and encoded, and then transmitted to the ground via mud pulses. Specifically, the encoder / decoder controller 10 performs pulse position modulation and encoding on the parameter difference vector X2 to obtain an encoded signal. The encoder / decoder controller 10 transmits the encoded signal to the mud pulse generator 30, controlling the mud pulse generator 30 to generate a mud pulse pressure wave signal that is transmitted to the ground.

[0065] like Figure 3 As shown, in step S305, the ground calculation module 80 decodes the parameter difference vector X2. Specifically, pressure data is collected by the pressure sensor 71 and the ground pressure wave acquisition module 70 and sent to the ground calculation module 80, which then decodes the parameter difference vector X2 from the collected data.

[0066] like Figure 3 As shown, in step S306, the parameter difference vector X2 is added to the parameter offset vector X0 to obtain the actual parameter measurement vector X1. Specifically, the ground calculation module 80 decodes the parameter difference vector X2, and adds it to the parameter offset vector X0 to obtain the actual parameter measurement vector X1.

[0067] Figure 4 A waveform diagram illustrating the transmission of the same data using different encoding methods according to an embodiment of the present invention is shown.

[0068] like Figure 2The transmission method shown can convert a parameter vector X1 with a relatively large value to be transmitted into a parameter vector X2 with a very small value. For example, in the horizontal section, the well inclination is approximately 90 degrees. Assuming the well inclination measured at a certain moment is 89.98°, and 12-bit precision is used for transmission, when processed using the traditional pulse position modulation coding method, the corresponding hexadecimal number for this data is "0x7FF". Using methods such as... Figure 2 When processing using the encoding method shown, if the well deviation offset INC0 = 85° is set, then the well deviation difference is INC2 = (89.98 - 85)° = 4.98°, and the corresponding hexadecimal number is "0x071".

[0069] Depend on Figure 4 It can be seen that when the pulse width is 1s, transmitting "89.98" using the traditional pulse position modulation coding method takes 24.5s. Using a different method... Figure 2 The encoding method shown takes 10 seconds to transmit "89.98". Therefore, this invention can significantly improve the transmission efficiency of downhole data.

[0070] Furthermore, when downhole parameters change significantly during drilling, the parameter difference vector X2 may also be large. To further improve efficiency, methods such as... Figure 3 The transmission method shown dynamically updates X0 by transmitting commands from the ground, so that X1-X0 always maintains a small value.

[0071] Therefore, compared with conventional pulse position modulation coding methods, this invention takes into account the data characteristics of the downhole measurement environment. By using a mud pulse uplink and downlink system, it converts larger measurement data into smaller measurement data, overcoming the problems of long transmission time and low bandwidth utilization that exist in conventional pulse position modulation coding when transmitting large data.

[0072] The drilling-while-transfer encoding method, apparatus, and storage medium provided by this invention can also be used in conjunction with a computer-readable storage medium. The storage medium stores a computer program, which is executed to run the drilling-while-transfer encoding method. The computer program is capable of executing computer instructions, which include computer program code. The computer program code can be in the form of source code, object code, executable file, or some intermediate form.

[0073] Computer-readable storage media can include: any entity or device capable of carrying computer program code, recording media, USB flash drives, portable hard drives, magnetic disks, optical disks, computer memory, read-only memory (ROM), random access memory (RAM), electrical carrier signals, telecommunication signals, and software distribution media, etc.

[0074] It should be noted that the contents of computer-readable storage media may be appropriately added to or subtracted from the contents according to the requirements of legislation and patent practice in a jurisdiction. For example, in some jurisdictions, according to legislation and patent practice, computer-readable storage media may not include electrical carrier signals and telecommunication signals.

[0075] Figure 5 A schematic diagram of a drilling transport encoding device according to an embodiment of the present invention is shown.

[0076] like Figure 5 As shown, a drilling transmission coding device includes a downhole unit, which is used to measure the actual measurement vector X1 of the parameter, combine it with the parameter offset vector X0 to perform pulse position modulation coding to obtain a coded signal, and generate a mud pulse pressure wave signal based on the coded signal.

[0077] In one embodiment, the downhole unit includes: a downhole codec controller 10, a measuring probe 20, and a mud pulse generator 30. Specifically, the downhole codec controller 10 is used to set a parameter offset vector X0 before running into the well, and to perform pulse position modulation encoding in combination with the actual parameter measurement vector X1 to obtain an encoded signal; the measuring probe 20 is used to measure the actual parameter measurement vector X1; and the mud pulse generator 30 is used to generate a mud pulse pressure wave signal based on the encoded signal.

[0078] like Figure 5 As shown, a drilling transmission encoding device includes a surface unit, which is used to set a parameter offset vector X0. The parameter offset vector X0 is the minimum value vector of each parameter of the subsequent drilling of a preset length of wellbore. The device also decodes the acquired mud pulse pressure wave signal and, combined with the parameter offset vector, restores the actual parameter measurement vector X1.

[0079] In one embodiment, the ground unit includes a pressure sensor 71 and a ground computing module 80. Specifically, the pressure sensor 71 is used to acquire mud pulse pressure wave signals to generate mud pulse electrical signals; the ground computing module 80 is used to decode the mud pulse electrical signals and, combined with the parameter offset vector X0, reconstruct the actual parameter measurement vector X1.

[0080] In one embodiment, such as Figure 5 As shown, the downhole codec controller 10, measuring probe 20, mud pulse generator 30, generator rotor 40, generator rectifier module 50, and generator rotor speed measurement module 60 constitute the downhole unit of the drilling transport device. This part is installed inside the non-magnetic drill collar 2, which is connected to the drill string assembly.

[0081] In one embodiment, such as Figure 5As shown, the pressure sensor 71, the ground pressure wave acquisition module 70, the ground calculation module 80, the mud pump 90, the mud tank 110, and the riser 120 constitute the ground unit of the drilling transmission device.

[0082] like Figure 5 As shown, the downhole encoder / decoder controller 10 reads various parameters measured by the measuring probe 20 at regular or irregular intervals, and performs pulse position modulation encoding on these parameters to form encoded signals. Under the control of these encoded signals, the mud pulse generator 30 blocks or allows mud to pass through, thereby generating mud pulse pressure wave signals.

[0083] The mud pulse pressure wave signal is transmitted to the riser 120 through the mud channel in wellbore 1 and is acquired by the pressure sensor 71, forming a mud pulse electrical signal. The surface pressure wave acquisition module 70 acquires the mud pulse electrical signal and transmits it to the surface calculation module 80. The surface calculation module 80 decodes the acquired signal and restores it to various parameters measured by the measuring probe 20.

[0084] The generator rotor 40 rotates according to the mud flow velocity in the wellbore 1, generating alternating current of varying magnitudes. The generator rectifier module 50 rectifies this alternating current to output direct current, which is then supplied to various modules downhole. The generator rotor speed measurement module 60 detects the speed changes of the generator rotor 40 and transmits the data to the downhole encoder / decoder controller 10. The downhole encoder / decoder controller 10 acquires the data and instructions transmitted from the surface mud diversion system according to pre-defined rules.

[0085] like Figure 5 As shown, the mud diversion pipe 100, the diversion valve 101, and the diversion valve controller 102 constitute a mud diversion unit. This part can divert the mud circulating in the wellbore 1 under the control of the ground calculation module 80, and then convert various instructions and data into changes in the mud flow rate circulating in the wellbore 1 according to the set time sequence.

[0086] In summary, the present invention provides a method, apparatus, and storage medium for transmitting data while drilling, which has the following advantages: it overcomes the problems of long transmission time and low bandwidth utilization in conventional pulse position modulation coding when transmitting large amounts of data. The apparatus has a reasonable structure, is easy to manufacture, and is highly adaptable, effectively improving the transmission efficiency of downhole data.

[0087] It should be understood that the embodiments disclosed herein are not limited to the specific structures, processing steps, or materials disclosed herein, but should be extended to equivalent substitutions of these features as understood by those skilled in the art. It should also be understood that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting.

[0088] In the description of this invention, unless otherwise stated, "a plurality of" means two or more; the terms "upper," "lower," "left," "right," "inner," "outer," "front end," "rear end," "head," "tail," etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings, and are only for the convenience of describing the invention and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation, and therefore should not be construed as a limitation of the invention. Furthermore, the terms "first," "second," "third," etc., are used for descriptive purposes only and should not be construed as indicating or implying relative importance.

[0089] In the description of this invention, it should be noted that, unless otherwise explicitly specified and limited, the terms "connected" and "linked" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium. Those skilled in the art can understand the specific meaning of the above terms in this invention based on the specific circumstances.

[0090] The phrase "an embodiment" or "an embodiment" used in this specification means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the invention. Therefore, the phrase "an embodiment" or "an embodiment" appearing in various places throughout the specification does not necessarily refer to the same embodiment.

[0091] The embodiments of the present invention are given for illustrative and descriptive purposes only, and are not intended to be exhaustive or to limit the invention to the forms disclosed. Many modifications and variations will be apparent to those skilled in the art. The embodiments were chosen and described in order to better illustrate the principles and practical application of the invention, and to enable those skilled in the art to understand the invention and to design various embodiments with various modifications suitable for a particular purpose.

[0092] While the embodiments disclosed in this invention are as described above, the content is merely for the purpose of facilitating understanding of the invention and is not intended to limit the invention. Any person skilled in the art to which this invention pertains may make any modifications and variations in form and detail of the implementation without departing from the spirit and scope disclosed herein; however, the scope of patent protection for this invention shall still be determined by the scope defined in the appended claims.

Claims

1. A method for encoding while drilling, characterized in that, The method includes the following steps: Set a parameter offset vector, which is the vector of minimum values ​​of each parameter for subsequent drilling of a wellbore of a preset length; The actual measurement vector of the parameters is obtained from downhole measurement. The parameter offset vector is combined with the pulse position modulation encoding to obtain the encoded signal. The mud pulse pressure wave signal is generated based on the encoded signal. The parameter offset vector is subtracted from the actual measurement vector of the parameters to obtain the parameter difference vector. The pulse position modulation encoding is performed on the parameter difference vector to obtain the encoded signal. The mud pulse pressure wave signal collected on the ground is decoded, and combined with the parameter offset vector, the actual measurement vector of the parameter is restored. Setting the parameter offset vector includes: setting the parameter offset vector via a downhole codec controller before the drilling instrument is run into the well; resetting the parameter offset vector based on the actual measured vector of the current parameters received from the surface and the subsequent wellbore design trajectory parameters; based on the parameter offset vector, diverting mud according to time-series encoding via a mud diversion unit; obtaining the latest parameter offset vector through time-series decoding based on the flow velocity change signal; in the mud diversion unit, the diversion valve controller controls the diversion valve to divert mud through the mud diversion pipeline according to time-series encoding, thereby causing the mud flow velocity in the wellbore to change according to time.

2. The drilling transport coding method as described in claim 1, characterized in that, Combining the aforementioned parameter offset vector with pulse position modulation encoding to obtain an encoded signal, and generating a mud pulse pressure wave signal based on the encoded signal, further comprising: Under the control of the encoded signal, the mud is blocked or allowed to pass through, thereby generating the mud pulse pressure wave signal.

3. The drilling transport coding method as described in claim 2, characterized in that, The mud pulse pressure wave signal acquired on the ground is decoded, and combined with the parameter offset vector, the actual measured parameter vector is reconstructed, including: Acquire the mud pulse pressure wave signal transmitted from downhole; The parameter difference vector is decoded from the mud pulse pressure wave signal; The parameter difference vector is added to the parameter offset vector to restore the actual measured vector of the parameter.

4. A drilling-while-transfer encoding device, characterized in that, The apparatus for performing a drilling transport coding method as described in any one of claims 1-3 comprises: The downhole unit is used to measure the actual measurement vector of the parameters, combine the parameter offset vector with pulse position modulation encoding to obtain an encoded signal, and generate a mud pulse pressure wave signal based on the encoded signal. The surface unit is used to set the parameter offset vector, which is the minimum value vector of each parameter for subsequent drilling of a preset length of wellbore, and to decode the acquired mud pulse pressure wave signal, and combine it with the parameter offset vector to restore the actual measurement vector of the parameter.

5. The drilling-while-transfer encoding device as described in claim 4, characterized in that, The downhole unit includes: A downhole encoder / decoder controller is used to set the parameter offset vector before going downhole and combine it with the actual measured parameter vector to perform pulse position modulation encoding to obtain the encoded signal; A measuring probe, used to measure and obtain the actual measurement vector of the parameters; A mud pulse generator is used to generate the mud pulse pressure wave signal based on the encoded signal.

6. The drilling-while-transfer encoding device as described in claim 4, characterized in that, The ground unit includes: A pressure sensor is used to acquire the mud pulse pressure wave signal to generate a mud pulse electrical signal; The ground calculation module is used to decode the mud pulse electrical signal and, in combination with the parameter offset vector, reconstruct the actual measurement vector of the parameter.

7. The drilling-while-transfer encoding device as described in claim 6, characterized in that, The device includes the mud diversion unit, which is used to divert the mud circulating in the wellbore under the control of the surface calculation module, thereby causing the mud flow rate circulating in the wellbore to change according to a set time sequence.

8. A storage medium, characterized in that, It contains instructions for performing the method as described in any one of claims 1-3.

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