CN109356570B - Method and equipment for transmitting drilling guide parameters - Google Patents
Method and equipment for transmitting drilling guide parameters Download PDFInfo
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- E—FIXED CONSTRUCTIONS
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- 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
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
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Abstract
The embodiment of the invention provides a method and equipment for transmitting drilling guide parameters. Wherein the method comprises the following steps: representing the drilling guide parameters in a differential dynamic mode to obtain differential dynamic drilling guide parameters, and packaging the differential dynamic drilling guide parameters into a drilling guide parameter data packet; and sending the differential dynamic drilling guide parameters packaged into the drilling guide parameter data packet to an underground rotary guide drilling system. According to the method and the device for transmitting the drilling guide parameters, the compressed drilling guide parameter data are expressed by adopting a dynamic difference method, and the larger drilling guide parameter data are compressed by adopting a coding method, so that the drilling guide parameters can be timely and efficiently transmitted to the underground rotary guide drilling control system.
Description
Technical Field
The embodiment of the invention relates to the technical field of oil drilling, in particular to a method and equipment for transmitting drilling guide parameters.
Background
In the process of petroleum Drilling, particularly in the process of Drilling wells with complex structures such as horizontal wells, extended reach wells, branch wells and the like, various downhole parameters needing to be known in real time by well site personnel are measured and Logged While Drilling (LWD) systems. The measurement while drilling and well logging system consists of an underground controller, various underground parameter measuring instruments, a measurement while drilling information transmission system and a ground information receiving, processing and displaying system. The development of various subsystems of measurement while drilling and logging systems is extremely unbalanced for a long time, and the development is mainly characterized in that the quantity of underground information needing to be transmitted is continuously increased and the transmission rate of an information transmission subsystem is low. With the development success and application of various new measuring instruments, the parameters required by measurement while drilling are more and more, and the measurement of a plurality of geological parameters such as the bit pressure, the torque, the pressure, the temperature, the natural gamma ray, the formation resistivity and the like is developed from the measurement of the geometrical parameters such as the initial well deviation, the azimuth, the tool face and the like. The amount of data to be measured, 45Kb, increased from 1960 every 1000 feet to 60Mb in 1993, and the MWD data required to be transmitted has reached 150bps in 1997. Since the last 90 s, the information transmission rate of measurement while drilling has been the bottleneck of development of measurement while drilling and well logging systems.
The ground control system receives real-time drilling data in the well, the computer system simulates and reproduces the working condition of the downhole drilling tool by using the data, calculates the working parameters of the drill bit to be corrected by comparing the actual drilling track with the designed drilling track, and then sends the intervention commands for realizing the operation of the change of the drill bit to the downhole rotary steering drilling tool system through the transmission channel. And the controller of the downhole rotary steering drilling tool system receives the control instruction, so as to guide the steering attitude of the downhole steering tool and realize the real-time control of the well track. In this way, closed loop control of the entire rotary steerable drilling system is achieved. The underground receiving technology of the ground drilling guiding parameter transmission achieves closed-loop control. In the prior art, the change process of the drilling guide parameters is slow, small changes are not easy to perceive, and the data volume is usually large, so that the drilling can not be carried out according to the predicted well track. Based on the above practical situation, finding a method capable of efficiently, timely, sensitively and effectively transmitting drilling guide parameters to an underground rotary steering drilling system becomes a technical problem which is widely concerned in the industry.
Disclosure of Invention
In view of the above problems in the prior art, embodiments of the present invention provide a method and an apparatus for transmitting drilling guide parameters.
In a first aspect, embodiments of the present invention provide a method for transmitting drill guide parameters, including: representing the drilling guide parameters in a differential dynamic mode to obtain differential dynamic drilling guide parameters, and packaging the differential dynamic drilling guide parameters into a drilling guide parameter data packet; and sending the differential dynamic drilling guide parameters packaged into the drilling guide parameter data packet to an underground rotary guide drilling system.
Further, before said representing the drilling guide parameter in a delta dynamic manner, the method further comprises: and carrying out time-length value coding on the drilling guide parameters to obtain coded drilling guide parameters, and sending the coded drilling guide parameters to an underground rotary guide drilling system.
Further, the time-length value encoding of the drill guide parameter comprises:
wherein Ta is a time length value and is used for representing an azimuth angle value; t is a first encoding duration for compressing 360 into a time length of value T.
Further, the time length value encoding of the drilling guide parameter comprises:
wherein Ti is a time length value and is used for expressing the deflecting strength; n is a second encoding duration for compressing 180 into a time length of value N.
Further, the format of the drill guide parameter data packet comprises: data packet type identification, data domain definition, data packet number and parameter domain; the data packet type identification is used for marking the property of the data packet; the data domain definition is used for marking the data length of the parameter domain; the data packet number is used for marking the specific type of the data packet; and the parameter field is used for storing a data field of downhole parameters.
Further, the properties of the data packet include: a full packet and/or an incremental packet.
Further, the dynamically representing the drilling guide parameter by the dispersion comprises:
wherein R is the real value of the drilling guide parameter,
the magnitude-difference expansion value of the drilling guide parameter, c is the complete data of the drilling guide parameter, k is the magnitude-difference coefficient,
is the magnitude difference of the complete data relative to the last drill guide parameter.
In a second aspect, embodiments of the present invention provide a device for transmitting drill guide parameters, comprising:
the dynamic differential representation module of the drilling guide parameters is used for representing the drilling guide parameters in a differential dynamic mode to obtain differential dynamic drilling guide parameters and packaging the differential dynamic drilling guide parameters into a drilling guide parameter data packet;
and the drilling guide parameter transmission module is used for transmitting the differential dynamic drilling guide parameters packaged into the drilling guide parameter data packet to the underground rotary guide drilling system.
In a third aspect, an embodiment of the present invention provides an electronic device, including:
at least one processor; and
at least one memory communicatively coupled to the processor, wherein:
the memory stores program instructions executable by the processor to invoke the program instructions to perform the method of transmission of drilling guide parameters provided by any of the various possible implementations of the first aspect.
In a fourth aspect, embodiments of the present invention provide a non-transitory computer readable storage medium storing computer instructions for causing a computer to perform a method of transmitting drilling guidance parameters as provided in any one of the various possible implementations of the first aspect.
According to the method and the device for transmitting the drilling guide parameters, the compressed drilling guide parameter data are expressed by adopting a dynamic difference method, and the larger drilling guide parameter data are compressed by adopting a coding method, so that the drilling guide parameters can be timely and efficiently transmitted to the underground rotary guide drilling system.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, a brief description will be given below to the drawings required for the description of the embodiments or the prior art, and it is obvious that the drawings in the following description are some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to these drawings without creative efforts.
FIG. 1 is a flow chart of a method for transmitting drilling guide parameters according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of a three-up and three-down command format provided in the prior art;
FIG. 3 is a schematic diagram of a drill guide parameter encoding provided by an embodiment of the present invention;
FIG. 4 is a schematic diagram illustrating the effect of data compression ratio on drilling guide parameters provided by an embodiment of the present invention;
FIG. 5 is a schematic structural diagram of a device for transmitting drilling guide parameters according to an embodiment of the present invention;
fig. 6 is a schematic physical structure diagram of an electronic device according to an embodiment of the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are some, but not all, embodiments of the present invention. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention. In addition, technical features of various embodiments or individual embodiments provided by the invention can be arbitrarily combined with each other to form a feasible technical solution, but must be realized by a person skilled in the art, and when the technical solution combination is contradictory or cannot be realized, the technical solution combination is not considered to exist and is not within the protection scope of the present invention.
The drilling guide parameters mainly comprise two guide parameters of azimuth angle and deflecting strength, data are required to be processed when the angle parameters are transmitted to the underground rotary guide drilling system, and each time a transmission instruction is sent, the pulse valve controls the system and controls the pulse valve to be opened or closed according to the following time sequence. Referring specifically to fig. 2, in fig. 2, the opening time T of the pulse valve is controlledFTime T of reclosingF+TR1Wherein T isR1=mTFM is an integer of 0 or more; controlling the opening time TF and the reclosing time T of the pulse valveF+TR2Wherein, TR2=nTFN is an integer of 0 or more; controlling the opening time T of the pulse valveFTime T of reclosingF+TR3。TR3The value of the check code is determined by n and m; controlling the opening time T of the pulse valveFThen closing the system until the instruction transmission system sends the next transmission instruction; m and n correspond to the transmission instructions one by one through permutation and combination, and refer to a transmission instruction schematic table 1 specifically; the four mud pressure negative pulses are provided with two command areas: a first command area and a second command area; a first command area is arranged between the falling edges of the first negative pulse and the second negative pulse, and a second command area is arranged between the falling edges of the second negative pulse and the third negative pulse; between the falling edges of the third and fourth negative pulses is a verify region.
TABLE 1
Although there are 36 instructions, the data to be transmitted are azimuth angle (0-360 degrees) and strength of deflecting (0-100 degrees), the specific magnitude values of the numerical values of the azimuth angle and the strength of deflecting cannot be accurately and practically transmitted, and the instruction representation method can only represent that the azimuth angle is increased by 30 degrees, for example, and cannot be realized if only the azimuth angle is increased by 5 degrees. In this command transmission method, the average value of m and n is 2.5, and the average value of m + n is 5, which results in that each command is transmitted for too long time because the drilling fluid transmission speed is slow. Too long a time easily results in commands being passed to the drill bit, and the commands have failed, resulting in the inability to drill in the intended wellbore trajectory. It can be seen that there is a need to find an effective way to reduce the time to transmit drilling guide parameters while ensuring efficient transmission of the parameters.
The embodiment of the invention provides a transmission method of drilling guide parameters, and referring to fig. 1, the method comprises the following steps:
101. representing the drilling guide parameters in a differential dynamic mode to obtain differential dynamic drilling guide parameters, and packaging the differential dynamic drilling guide parameters into a drilling guide parameter data packet;
102. and sending the differential dynamic drilling guide parameters packaged into the drilling guide parameter data packet to an underground rotary guide drilling system.
On the basis of the foregoing embodiment, the method for transmitting a drill guiding parameter provided in an embodiment of the present invention, where the drill guiding parameter is represented in a differential dynamic manner, includes:
wherein R is the true value of the drilling guide parameter,
the magnitude difference expansion value of the drilling guide parameter, c is the complete data of the drilling guide parameter, and k is the magnitude differenceThe coefficients of which are such that,
is the magnitude difference of the complete data relative to the last drill guide parameter.
The quantity difference coefficient k needs to be initially configured by the user on the ground, and the purpose is to avoid data redundancy caused by decimal place like 0.001, so as to further shorten the digit of the data. In another embodiment, the azimuth angle precision is 0.1, the delta coefficient k is 10, the complete data c of the drill guiding parameter transmitted to the ground at the last time is 105.7 degrees, the value acquired at the time is 106.1 degrees, and the delta c is 0.4 degree, so that only the delta expansion value of the drill guiding parameter needs to be transmitted at the time
And 4, the real value R of the drilling guide parameter can be calculated to be 106.1 degrees by the ground receiving end. The dynamic differential representation technology can effectively compress the data length and reduce the data redundancy. In another embodiment, 6 pieces of data continuously collected from 1601.68m to 1662.32m at 3 depths of an Tianjin Tang oilfield are selected, and the length change of the parameter in the data packet after the differential data representation method is adopted is shown in the length change table of the parameter in the data dynamic differential representation method in Table 2 (the differential coefficient k is set to 10).
TABLE 2
The lengths of the 6 pieces of data in table 2 before and after compression are compared, and for the sake of clarity, see fig. 4. In fig. 4, the vertical axis represents data compression rate (in units), and the horizontal axis represents the number of well depth position points, which include: well depth 1611.19 location point 402, well depth 1623.34 location point 403, well depth 1635.23 location point 401, well depth 1650.67 location point 404, and well depth 1662.32 location point 405. As can be seen from fig. 4, the data compression rate of the position point 401 at the well depth 1635.23 is the highest, reaching 40%; the compression rates of the remaining position points were 20%.
On the basis of the foregoing embodiment, the method for transmitting a drilling guidance parameter provided in an embodiment of the present invention further includes, before the drilling guidance parameter is represented in a differential dynamic manner: and coding the drilling guide parameter by a time length value to obtain a coded drilling guide parameter, and sending the coded drilling guide parameter to an underground rotary guide drilling system.
Referring to fig. 3, in fig. 3, Ts is a start signal to mark the beginning of transmission of the steering parameters; ta is an azimuth angle value (the azimuth angle value is represented by the time width value of Ta), Ti is a build-up rate value (the azimuth angle value is represented by the time width value of Ti), Te is a pulse signal transmission end mark, wherein the fixed time values of Ts and Te are set according to the transmission requirements of the drilling guide parameters. Since the range of the azimuth value is 0 to 360 degrees, in another embodiment, the specific calculation method of the azimuth value is Ta × 360/15, and the calculation method of the build-up rate (i.e., build-up strength) value is Ti × 180/10. Therefore, a relatively large value of 360 degrees can be represented by using the condition that the azimuth angle value is the largest, namely the time length of 15 seconds, and the transmission time is saved. The representation of the build slope value is based on the same principle.
On the basis of the foregoing embodiments, the method for transmitting a drilling guide parameter provided in an embodiment of the present invention, where the time-length value coding is performed on the drilling guide parameter, includes:
wherein Ta is a time length value and is used for representing an azimuth angle value; t is a first encoding duration for compressing 360 into a time length of value T.
On the basis of the foregoing embodiments, the method for transmitting a drilling guide parameter provided in an embodiment of the present invention, where the time-length value coding is performed on the drilling guide parameter, includes:
wherein Ti is a time length value and is used for expressing the deflecting strength; n is a second encoding duration for compressing 180 into a time length of value N.
On the basis of the foregoing embodiments, the method for transmitting a drill guide parameter provided in an embodiment of the present invention, where the format of the drill guide parameter data packet includes: data packet type identification, data domain definition, data packet number and parameter domain; the data packet type identifier is used for marking the property of the data packet; the data domain definition is used for marking the data length of the parameter domain; the data packet number is used for marking the specific type of the data packet; and the parameter field is used for storing a data field of downhole parameters.
On the basis of the foregoing embodiments, the method for transmitting a drill guide parameter provided in an embodiment of the present invention includes: a full packet and/or an incremental packet.
The format of the drill guide parameter data packet can be seen in the format table of the drill guide parameter data packet in table 3.
TABLE 3
Data packet type identification: for indicating the nature of the packet, a binary 1 or 0 is used to indicate the nature of the packet, where a 1 indicates a full packet and a 0 indicates an incremental packet. Data field delimitation refers to marking the data length of each subsequent field with data in the field for determining the boundary between data fields. The data packet numbers are used for indicating the specific types of the data packets, each number represents a unique parameter combination form and an arrangement sequence, and 100 numbers of 0-99 are reserved in the protocol. The parameter domains (1 to n) are used for storing data domains of various parameters in the well, adopt decimal form and can represent 10 effective digits (the symbol and decimal point respectively occupy one digit) in total from 0 to 9.
The head of the data packet only has three fixed contents of a data packet type identifier, a data field delimitation and a data packet number, and the number and the size of parameters in the packet text are not limited, so that a user can flexibly customize the data packet according to transmission requirements. The type division, data delimitation, efficient data transmission and the like are important problems in data packet design, and a data packet numbering method, a digital arrangement data domain delimitation method and a dynamic difference representation method are respectively adopted.
When delimiting the parameter domain of the drilling guide parameter data packet, a method of fixing the length of the data domain or inserting a special separator between the data domains is often adopted. The former determines the boundary by the fixed length preset for each parameter, and has the defect that the corresponding data domain length cannot be adjusted according to the actual value of the parameter, which easily causes the redundant waste of the data packet space; the latter determines parameter boundaries by inserting special characters between data fields, which enables the length of each data field to be flexible, but the inserted boundary characters occupy a large amount of data transmission space, which is inefficient.
The method of digital arrangement data field delimitation is to determine the boundary of each parameter data field by using the value of the 'data field delimitation' field in the data packet. The delimiting rule is as follows: firstly, when a drilling guide parameter data packet is generated, calculating and obtaining the values of the delimited fields of the data fields according to the actual lengths of the current parameter fields, and sequentially arranging and combining decimal representation digits (a negative sign and a decimal point respectively occupy one digit) of the values of the fields. Secondly, when the data packet is used by ground splitting, the boundary of each data field is determined in sequence according to the value of the delimited field of the data field, and parameters are extracted.
The first bit of the data field delimiting field indicates the length of the data packet number, and takes values of 0, 1 and 2. For example, the value delimited by the data field is 3896, which indicates that the packet number length of this transmission is 3, and includes 3 parameters, the data length of parameter 1 is 8, the data length of parameter 2 is 9, and the data length of parameter 3 is 6.
Compared with the length delimitation of the fixed data domain, the digital arrangement data domain delimitation method provided by the patent does not need to set the fixed length for each parameter in advance, can adjust the size of the corresponding data domain in real time according to the actual value of the parameter, and can not cause the redundant waste of the data packet space. Compared with the method of inserting special delimiters among domains, the method does not need to insert special characters among the domains to determine the boundary, and saves a large amount of space overhead of data packets. Therefore, the data packet delimitation method for transmitting the drilling guide parameters is improved by the digital arrangement data field delimitation method, and the transmission efficiency of the system is effectively improved.
The data packet numbers are used for determining the specific type of data packets, and different numbers represent different parameter combinations and arrangement sequences in the data packets. According to the actual requirements of the current drilling process on the guiding parameters, a user can define the format of the data packet by himself, namely, a worker can set a measuring instrument to be put into a well through a ground computer system. When defining the data packet format, the correlation degree, the change frequency, the guiding control purpose and other factors of the parameters need to be considered, then the parameters are flexibly combined and arranged, and finally the arranged data packets are uniquely numbered.
And numbering the data packets by adopting 2 decimal digits, wherein the numbering range is 0-99, namely, at most 100 data packet formats can be defined by user. The packet with a high frequency of use is represented by a 1-bit number, the packet with a low frequency of use is represented by a 2-bit number, and the number with the highest frequency of use is 0, whereby the length of the packet can be further reduced. The data packet numbering technology can enable the measurement while drilling system to customize the data packet format according to the needs, and compared with the traditional data packet with fixed type, the flexibility of the system is improved; the reserved data packet numbers provide an extension mechanism for the measurement while drilling system, and when more downhole parameters need to be transmitted, the mechanism enables the system to define a new data packet format to meet the requirement of drilling guide parameter transmission. See table 4 for an example of a specific drill guide parameter data packet.
TABLE 4
The drill guide parameter data packet in table 4 was validated based on 10 well history data for a well from a pond field, in the packet format of the above-described embodiment of the present invention. The number of the data packet is "0", and the parameters are the inclination angle and the azimuth angle. The incremental coefficient for the borehole angle and azimuth angle is set to "10".
According to the transmission method of the drilling guide parameters, the compressed drilling guide parameter data are expressed by adopting a dynamic difference method, and the larger drilling guide parameter data are compressed by adopting a coding method, so that the drilling guide parameters can be timely and efficiently transmitted to the underground rotary guide drilling system.
The implementation basis of the various embodiments of the present invention is realized by programmed processing performed by a device having a processor function. Therefore, in engineering practice, the technical solutions and functions thereof of the embodiments of the present invention can be packaged into various modules. Based on this reality, on the basis of the embodiments, the embodiments of the present invention provide a device for transmitting a drilling guide parameter, which is used for executing the method for transmitting a drilling guide parameter in the above method embodiments. Referring to fig. 5, the apparatus includes:
the drilling guide parameter difference dynamic representation module 501 is used for representing the drilling guide parameters in a difference dynamic mode to obtain difference dynamic drilling guide parameters, and packaging the difference dynamic drilling guide parameters into a drilling guide parameter data packet;
and a drilling guide parameter transmission module 502 for transmitting the differential dynamic drilling guide parameters packaged into the drilling guide parameter data packet to the downhole rotary guide drilling system.
According to the transmission device for the drilling guide parameters, the drilling guide parameter difference dynamic representation module and the drilling guide parameter transmission module are adopted, the compressed drilling guide parameter data are represented by adopting a dynamic difference method, the larger drilling guide parameter data are compressed by adopting a coding method, and the drilling guide parameters can be timely and efficiently transmitted to the underground rotary guide drilling system.
The method of the embodiment of the invention is realized by depending on the electronic equipment, so that the related electronic equipment is necessarily introduced. To this end, an embodiment of the present invention provides an electronic apparatus, as shown in fig. 6, including: at least one processor (processor)601, a communication Interface (Communications Interface)604, at least one memory (memory)602, and a communication bus 603, wherein the at least one processor 601, the communication Interface 604, and the at least one memory 602 communicate with each other through the communication bus 603. The at least one processor 601 may invoke logic instructions in the at least one memory 602 to perform the following method: representing the drilling guide parameters in a differential dynamic mode to obtain differential dynamic drilling guide parameters, and packaging the differential dynamic drilling guide parameters into a drilling guide parameter data packet; and sending the differential dynamic drilling guide parameters packaged into the drilling guide parameter data packet to an underground rotary guide drilling system.
Furthermore, the logic instructions in the at least one memory 602 may be implemented in software functional units and stored in a computer readable storage medium when sold or used as a stand-alone product. Based on such understanding, the technical solution of the present invention may be embodied in the form of a software product, which is stored in a storage medium and includes instructions for causing a computer device (which may be a personal computer, a server, or a network device) to execute all or part of the steps of the method according to the embodiments of the present invention. Examples include: representing the drilling guide parameters in a differential dynamic mode to obtain differential dynamic drilling guide parameters, and packaging the differential dynamic drilling guide parameters into a drilling guide parameter data packet; and sending the differential dynamic drilling guide parameters packaged into the drilling guide parameter data packet to an underground rotary guide drilling system. And the aforementioned storage medium includes: a U-disk, a removable hard disk, a Read-Only Memory (ROM), a Random Access Memory (RAM), a magnetic disk or an optical disk, and other various media capable of storing program codes.
The above-described embodiments of the apparatus are merely illustrative, and the units described as separate parts may or may not be physically separate, and parts displayed as units may or may not be physical units, may be located in one place, or may be distributed on a plurality of network units. Some or all of the modules may be selected according to actual needs to achieve the purpose of the solution of the present embodiment. One of ordinary skill in the art can understand and implement it without inventive effort.
Through the above description of the embodiments, those skilled in the art will clearly understand that each embodiment may be implemented by software plus a necessary general hardware platform, and may also be implemented by hardware. Based on the understanding, the above technical solutions substantially or otherwise contributing to the prior art may be embodied in the form of a software product, which may be stored in a computer-readable storage medium, such as ROM/RAM, magnetic disk, optical disk, etc., and includes several instructions for causing a computer device (which may be a personal computer, a server, or a network device, etc.) to execute the method according to the various embodiments or some parts of the embodiments.
Finally, it should be noted that: the above examples are only intended to illustrate the technical solution of the present invention, but not to limit it; although the present invention has been described in detail with reference to the foregoing embodiments, it will be understood by those of ordinary skill in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some technical features may be equivalently replaced; and such modifications or substitutions do not depart from the spirit and scope of the corresponding technical solutions of the embodiments of the present invention.
Claims (7)
1. A method of transmitting a drill guide parameter, comprising:
representing the drilling guide parameters in a differential dynamic mode to obtain differential dynamic drilling guide parameters, and packaging the differential dynamic drilling guide parameters into a drilling guide parameter data packet;
sending the differential dynamic drilling guide parameters packaged into the drilling guide parameter data packet to an underground rotary guide drilling system;
before the dynamically representing the drilling guide parameters by using the differential quantity, the method further comprises the following steps:
coding the drilling guide parameters by time length values to obtain coded drilling guide parameters, and sending the coded drilling guide parameters to an underground rotary guide drilling system;
the time-length value encoding of the drill guide parameter comprises:
wherein Ta is a time length value and is used for representing an azimuth angle value; t is a first encoding time length used for compressing 360 into a time length with a value of T;
the dynamic mode of differential quantity is adopted to represent the drilling guide parameters, and comprises the following steps:
wherein R is the real value of the drilling guide parameter,
the magnitude-difference expansion value of the drilling guide parameter, c is the complete data of the drilling guide parameter, k is the magnitude-difference coefficient,
is the magnitude difference of the complete data relative to the last drill guide parameter.
2. The method of claim 1, wherein the time-length value encoding of the drill guide parameter comprises:
wherein Ti is a time length value and is used for expressing the deflecting strength; n is a second encoding duration for compressing 180 into a time length of value N.
3. The method of claim 1, wherein the drill guide parameter data packet is formatted to include:
data packet type identification, data domain definition, data packet number and parameter domain;
the data packet type identifier is used for marking the property of the data packet;
the data domain definition is used for marking the data length of the parameter domain;
the data packet number is used for marking the specific type of the data packet;
and the parameter field is used for storing a data field of downhole parameters.
4. The method of claim 3, wherein the data packet comprises, in part:
a full packet and/or an incremental packet.
5. A device for transmitting drilling guide parameters, comprising:
the dynamic differential representation module of the drilling guide parameters is used for representing the drilling guide parameters in a differential dynamic mode to obtain differential dynamic drilling guide parameters and packaging the differential dynamic drilling guide parameters into a drilling guide parameter data packet;
the drilling guide parameter transmission module is used for transmitting the differential dynamic drilling guide parameters packaged into the drilling guide parameter data packet to an underground rotary guide drilling system;
before the representing the drilling guide parameter in a differential dynamic mode, the method further comprises the following steps:
coding the drilling guide parameters by time length values to obtain coded drilling guide parameters, and sending the coded drilling guide parameters to an underground rotary guide drilling system;
the time-length value encoding of the drill guide parameter comprises:
wherein Ta is a time length value and is used for representing an azimuth angle value; t is a first coding duration, and is used for compressing 360 into a time length with a value of T;
the dynamic mode of differential quantity is adopted to represent the drilling guide parameters, and comprises the following steps:
wherein R is the real value of the drilling guide parameter,
the delta expansion value of the drilling guide parameter, c is the complete data of the drilling guide parameter, k is the delta coefficient,
is the magnitude difference of the complete data relative to the last drill guide parameter.
6. An electronic device, comprising:
at least one processor, at least one memory, a communication interface, and a bus; wherein,
the processor, the memory and the communication interface complete mutual communication through the bus;
the memory stores program instructions for execution by the processor, which are invoked by the processor to perform the method of any of claims 1 to 4.
7. A non-transitory computer-readable storage medium storing computer instructions that cause a computer to perform the method of any one of claims 1-4.
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