Method and apparatus for calculating fluid mobility while drilling

Abstract

The application relates to a method and device for calculating fluid mobility in a while-drilling operation, wherein the method comprises the following steps: controlling a while-drilling instrument to carry out first fluid extraction according to a preset pumping volume; after judging that the pressure in a fluid pipeline is restored to stability, taking the time when the pressure is restored to stability as the starting time of second fluid extraction, and controlling the while-drilling instrument to carry out the second fluid extraction according to the preset pumping volume; after judging that the pressure in the fluid pipeline is restored to stability again, calculating the fluid mobility according to the time and real-time pressure at each time point in the process of restoring the pressure in the fluid pipeline to stability after the second extraction is started. The application does not need to upload pressure data, and can complete the calculation of the fluid mobility in the well, so that the calculation of the permeability can be realized by uploading the calculated fluid mobility information to the ground, and the application has the advantages of simple calculation and good timeliness.

Description

Technical Field

[0001] This invention belongs to the field of well logging technology, specifically relating to a method and apparatus for calculating fluid mobility under drilling conditions, as well as a computing device and computer storage medium. Background Technology

[0002] Permeability is an extremely important parameter in the evaluation of reservoir fluid properties. Permeability is related to the viscosity and mobility of the fluid. When the viscosity of the fluid is known, the permeability can be calculated by obtaining the mobility data of the fluid through logging instruments.

[0003] Generally, the formation testing instrument operates downhole and communicates with the surface via a pulser. Due to the limitations of the pulser's upload speed, the pulser cannot upload enough data within a certain time to calculate the fluid flow rate, which results in the inability to obtain accurate permeability data through calculation.

[0004] Therefore, in existing technologies, the data acquired by the drilling instrument is usually stored in a Flash array. When the instrument returns to the surface, the data in the Flash array is read by a testing device, and then the fluid flow rate is calculated. However, this method has the disadvantage of poor timeliness. Summary of the Invention

[0005] In view of the above problems, the present invention is proposed to provide a method, apparatus, computing device and computer storage medium for calculating fluid mobility under drilling conditions to overcome or at least partially solve the above problems.

[0006] According to one aspect of the present invention, a method for calculating fluid mobility under drilling conditions is provided, comprising:

[0007] The drilling instrument is controlled to perform the first fluid extraction according to the preset extraction volume;

[0008] After determining that the pressure in the fluid pipeline has stabilized, the time when the pressure stabilizes is taken as the start time of the second fluid extraction, and the drilling instrument is controlled to perform the second fluid extraction according to the preset extraction volume.

[0009] After determining that the pressure in the fluid pipeline has stabilized again, the flow rate of the fluid is calculated based on the time at each moment during the process from the start of the second suction to the stabilization of the pressure in the fluid pipeline, as well as the real-time pressure at each moment.

[0010] Furthermore, before calculating the fluid flow rate based on the time intervals from the start of the second suction to the pressure stabilization in the fluid pipeline and the real-time pressure at each interval, the method further includes:

[0011] Convert the time at each moment into a time series in the corresponding digital field;

[0012] The calculation of the fluid flow rate based on the time and real-time pressure at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline is specifically as follows:

[0013] The fluidity is calculated based on the digital domain time series corresponding to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, as well as the real-time pressure at each moment.

[0014] Furthermore, the specific steps of converting the time at each moment into a time series in the corresponding digital field are as follows:

[0015] The time series of the digital field corresponding to each time point is equal to the time at each time point divided by the sampling period of the drilling instrument.

[0016] Furthermore, the calculation of the fluid flow rate based on the digital domain time series corresponding to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, and the real-time pressure at each moment, further includes:

[0017] When the second suction begins, the accumulated pressure value is set to zero. The accumulated pressure value for each time series after the start of the second suction is calculated, and the accumulation is stopped when the pressure in the fluid pipeline returns to stability. The accumulated pressure value at this time is obtained. The accumulated pressure value for each time series after the start of the second suction is equal to the sum of the pressure value for the current time series and the accumulated pressure value for the previous time series.

[0018] The fluidity is calculated based on the accumulated pressure value when the pressure in the fluid pipeline stabilizes, the sampling period, the time series and pressure value corresponding to the start time of the second suction, the time series and pressure value corresponding to the time when the pressure in the fluid pipeline stabilizes, the preset suction volume, and the pressure drop flow factor.

[0019] Furthermore, the calculation of the fluid flowability based on the accumulated pressure value when the pressure in the fluid pipeline recovers to stability, the sampling period, the time series and pressure value corresponding to the start time of the second suction, the time series and pressure value corresponding to the time when the pressure in the fluid pipeline recovers to stability, the preset suction volume, and the pressure drop flow factor specifically involves:

[0020] The cumulative pressure value when the pressure in the fluid pipeline recovers to a stable state is set to sum[N5], the sampling period is T, the preset suction volume is V, and the pressure drop flow factor is C. pfThe time series corresponding to the start time of the second suction is N3, the pressure value corresponding to the start of the second suction is P[N3], the time series corresponding to the time when the pressure in the fluid pipeline recovers to a stable state is N5, the pressure value corresponding to the start of the second suction is P[N5], and the fluidity is set to MOB, then:

[0021]

[0022] Furthermore, the method for determining whether the pressure in the fluid pipeline has returned to stability is as follows:

[0023] If the pressure fluctuation in the fluid pipeline is less than 1 psi / min within a certain period of time, it is determined that the pressure in the fluid pipeline has returned to stability, and at this time the pressure in the fluid pipeline is equal to the formation pressure.

[0024] Furthermore, after calculating the fluid flow rate based on the time intervals from the start of the second suction to the pressure stabilization in the fluid pipeline and the real-time pressure at each interval, the method further includes:

[0025] The calculated fluid flow rate is transmitted to the ground receiving unit via a pulser, so that the ground receiving unit can calculate the fluid permeability based on the received fluid flow rate.

[0026] According to another aspect of the present invention, an apparatus for calculating fluid mobility under drilling conditions is provided, comprising:

[0027] Control unit: used to control the drilling instrument to perform the first fluid extraction according to the preset extraction volume; and used to control the drilling instrument to perform the second fluid extraction according to the preset extraction volume after determining that the pressure in the fluid pipeline has recovered to a stable state, taking the time of recovery to a stable state as the start time of the second fluid extraction.

[0028] The calculation unit is used to calculate the flow rate of the fluid based on the time and real-time pressure at each moment during the process from the start of the second suction to the pressure in the fluid pipeline stabilizing again, after determining that the pressure in the fluid pipeline has stabilized again.

[0029] According to another aspect of the present invention, a computing device is provided, comprising: a processor, a memory, a communication interface, and a communication bus, wherein the processor, the memory, and the communication interface communicate with each other via the communication bus;

[0030] The memory is used to store at least one executable instruction, which causes the processor to perform the operation corresponding to the method for calculating fluid mobility under drilling conditions described above.

[0031] According to another aspect of the present invention, a computer storage medium is provided, the storage medium storing at least one executable instruction that causes a processor to perform operations corresponding to the method for calculating fluid flow rate under drilling conditions as described above.

[0032] As can be seen from the above technical solution, the method and apparatus for calculating fluid mobility under drilling conditions provided by the present invention have the following beneficial effects:

[0033] This invention does not require uploading pressure data; fluid mobility can be calculated downhole. The calculated fluid mobility information can then be uploaded to the surface to calculate permeability. It has the advantages of simple calculation and good timeliness.

[0034] The above description is merely an overview of the technical solution of the present invention. In order to better understand the technical means of the present invention and to implement it in accordance with the contents of the specification, and in order to make the above and other objects, features and advantages of the present invention more apparent and understandable, specific embodiments of the present invention are described below. Attached Figure Description

[0035] Figure 1 This is a schematic diagram of a method for calculating fluid mobility in the prior art;

[0036] Figure 2 A graph showing the relationship between pressure and digital domain time series in existing fluid computation methods;

[0037] Figure 3 This is a flowchart illustrating a method for calculating fluid mobility under drilling conditions according to an embodiment of the present invention;

[0038] Figure 4 This is a graph showing the relationship between pressure and digital domain time series in the calculation method of this invention.

[0039] Figure 5 This is a flowchart of a flow rate calculation method according to another embodiment of the present invention;

[0040] Figure 6 This is a circuit block diagram of the present invention;

[0041] Figure 7 A schematic diagram of a computing device embodiment of the present invention is shown. Detailed Implementation

[0042] Exemplary embodiments of the invention will now be described in more detail with reference to the accompanying drawings. While exemplary embodiments of the invention are shown in the drawings, it should be understood that the invention may be implemented in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this invention will be thorough and complete, and will fully convey the scope of the invention to those skilled in the art.

[0043] The drilling formation tester includes a probe, sample line, pressure gauge, suction pump, and control circuit. When the drilling formation tester is working, the formation is sealed by rubber gaskets around the probe. Then, the suction pump is started by the control circuit. After the suction pump is started, the formation fluid or core fluid is extracted through the sample line and the probe.

[0044] Existing technologies for calculating fluid mobility using uploaded downhole pressure data include... Figure 1 As shown, the specific steps include: after the drilling formation tester enters the target bottom layer, the control probe seals the formation. After sealing the formation, suction begins until the volume of the suction fluid equals the preset suction volume V. After suctioning to the preset suction volume, the pressure is allowed to recover. After the pressure recovers, all pressure data from before suction began until the pressure stabilizes (or all pressure data after the instrument is powered on) is uploaded to the ground. After receiving the data, the ground first manually determines the formation pressure, and then determines the time to start suction based on the formation pressure using interpolation methods, and then calculates the fluid mobility information.

[0045] Specifically, such as Figure 2 As shown, Figure 2 In the P[n] coordinate axis, the time series in the digital domain is represented. The relationship between the time series n and the real-time t is: n*T = t, where T represents the sampling period. The P[n] coordinate axis represents the pressure in the fluid pipeline corresponding to the time series. After the suction begins, the pressure in the fluid pipeline decreases. When the preset volume is suctioned, the pressure in the fluid pipeline is less than the formation pressure. Figure 2 In the diagram, point N1 represents the time series point at the start of suction, and point N3 represents the time series point at the end of suction. After suction ends, the pressure inside the fluid pipeline gradually increases until it reaches a stable state. Figure 2 The N4 point represents the time series point where the pressure returns to stability, and the pressure corresponding to the N4 time series point is the formation pressure.

[0046] Once the pressure data is received at the ground, the location of the N4 time series point needs to be determined based on the pressure fluctuations. Then, the timing of extracting formation fluid during this extraction is determined using interpolation, i.e., determining the N2 time series point where the real-time pressure during the extraction process equals the pressure at time N4. Finally, the fluid mobility MOB is calculated based on the real-time pressure at each time series point between N2 and N4, using the following formula:

[0047]

[0048] Where, C pfdenoted by , T represents the sampling period, V represents the preset suction volume, P[N4] represents the pressure of the fluid pipeline corresponding to time point N4, and P[n] represents the pressure of the fluid pipeline corresponding to time point n.

[0049] Existing calculation methods require manual determination of the N4 time series points and the use of interpolation to obtain the N2 time series points, which makes the calculation complex and the accuracy cannot be guaranteed. Furthermore, existing algorithms require calculations to be performed on the ground after the pressure data is uploaded, which results in poor real-time performance.

[0050] Figure 3 A flowchart illustrating an embodiment of the present invention provides a method for calculating fluid mobility under drilling conditions, which is applied in a computing device. The computing device includes a processor, a memory, a communication interface, and a communication bus. The processor, the memory, and the communication interface communicate with each other via the communication bus. The memory stores at least one executable instruction, which causes the processor to perform the operation corresponding to the method for calculating fluid mobility under drilling conditions. Figure 3 As shown, the method includes the following steps:

[0051] Step S110: Control the drilling instrument to perform the first fluid extraction according to the preset extraction volume;

[0052] Step S120: After determining that the pressure in the fluid pipeline has stabilized, the time of stabilization is taken as the start time of the second fluid extraction, and the drilling instrument is controlled to perform the second fluid extraction according to the preset extraction volume.

[0053] Step S130: After determining that the pressure in the fluid pipeline has stabilized again, calculate the fluid flow rate based on the time at each moment during the process from the start of the second suction to the stabilization of the pressure in the fluid pipeline and the real-time pressure at each moment.

[0054] Specifically, the drilling instrument in this embodiment is a drilling formation tester. The first suction serves to clean the residual fluid in the fluid pipeline and achieves the connection between the pipeline and the formation. The volume of the first suction is a preset volume.

[0055] During the first suction process, the pressure in the fluid pipeline will drop below the formation pressure. After the suction stops, the pressure in the fluid pipeline will gradually recover. Once the pressure in the fluid pipeline stabilizes, the drilling instrument will be controlled to perform a second suction. The suction volume of the second suction is still the preset volume. After the preset volume is suctioned for the second time, the pump will be stopped. The fluid flow rate is calculated based on the time and real-time pressure at each moment during the process from the start of the second suction to the pressure in the fluid pipeline stabilizing.

[0056] In this embodiment, after the first extraction, when the fluid pipeline pressure stabilizes, the pressure inside the fluid pipeline equals the formation pressure. Therefore, the second extraction in this embodiment is the extraction of formation fluid. Compared with the prior art, this embodiment does not require determining the timing of the extraction of formation fluid. Secondly, since the formation fluid is extracted during the second extraction in this embodiment, the fluid flow rate is calculated based on the time and real-time pressure at each moment during the process from the start of the second extraction to the stabilization of the pressure in the fluid pipeline. This has the advantage of simple calculation.

[0057] In an alternative embodiment, before step S130 calculates the fluid flow rate based on the time intervals from the start of the second suction to the pressure stabilization in the fluid pipeline and the real-time pressure at each interval, the method further includes:

[0058] Convert the time at each moment into a time series in the corresponding digital field.

[0059] Specifically, since the downhole circuit is a digital circuit, before calculating the fluid flow rate, it is necessary to convert the time at each moment from the start of the second pumping to the pressure recovery and stabilization of the fluid pipeline into a digital time series.

[0060] In practice, for example, the time when the drilling instrument is powered on is taken as the starting point, and the time at each moment from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline is recorded, and the time at each moment is converted into a time series of the digital field corresponding to each moment.

[0061] Specifically, converting the time at each moment into a time series in the digital field corresponding to the time at each moment means that the time series in the digital field corresponding to the time at each moment is equal to the time at each moment divided by the sampling period of the drilling instrument.

[0062] Specifically, let n represent the time series in the digital domain and t represent the real-time time, then n*T = t, where T represents the sampling period. Therefore, the corresponding time series in the digital domain can be obtained based on the real-time time t.

[0063] like Figure 4 As shown, the n-axis represents the time series in the digital field, and P[n] represents pressure. Figure 4 In the N1 time series point, the time series point at the start of the first suction is represented, and the N2 time series point at the end of the first suction is represented. During the first suction, the pressure gradually decreases. When the preset suction volume is reached, the pressure drops below the formation pressure. After the preset suction volume is reached, the suction pump is controlled to stop suction. After the suction pump stops suction, the pressure in the fluid pipeline gradually recovers. When the pressure recovers to a stable level, the pressure in the fluid pipeline is equal to the formation pressure.

[0064] refer to Figure 4 ,exist Figure 4 The pressure fluctuation within the pipeline is relatively small at time point N3, therefore this is the time point corresponding to the pressure stabilization, and the pressure P[N3] at this point is equal to the formation pressure P. fromation At this point, the second suction begins, and the suction volume of the second suction is also equal to the preset suction volume. The N3 time series point represents the time series point at which the second suction begins, the N4 time series point represents the time series point at which the second suction ends, and the N5 time series point represents the time series point at which the pressure in the fluid pipeline returns to stability after the second suction.

[0065] Therefore, based on the digital domain time series and the corresponding pressure, in this embodiment, step S130, which calculates the fluid flow rate according to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, and the real-time pressure at each moment, specifically involves calculating the fluid flow rate according to the digital domain time series corresponding to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, and the real-time pressure at each moment.

[0066] In other words, this embodiment calculates the fluid flow rate based on digital domain time series and real-time pressure, specifically based on... Figure 4 The fluidity is calculated using the digital domain time series and corresponding pressure between N3 and N5.

[0067] In one alternative approach, calculating the fluid flowability based on the digital domain time series corresponding to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, and the real-time pressure at each moment, further includes:

[0068] When the second suction begins, the accumulated pressure value is set to zero. The accumulated pressure value for each time series after the start of the second suction is calculated, and the accumulation is stopped when the pressure in the fluid pipeline returns to stability. The accumulated pressure value at this time is obtained. The accumulated pressure value for each time series after the start of the second suction is equal to the sum of the pressure value for the current time series and the accumulated pressure value for the previous time series.

[0069] The fluidity is calculated based on the accumulated pressure value when the pressure in the fluid pipeline stabilizes, the sampling period, the time series and pressure value corresponding to the start time of the second suction, the time series and pressure value corresponding to the time when the pressure in the fluid pipeline stabilizes, the preset suction volume, and the pressure drop flow factor.

[0070] Specifically, such as Figure 5 As shown, after the first aspiration volume V, aspiration is stopped and the pressure is allowed to recover. (Refer to...) Figure 4The time series corresponding to the pressure recovery and stabilization is N3. At this time, the second suction begins. At the same time, the accumulated pressure value sum[N3] at the start of suction is set to zero. The accumulated pressure value corresponding to each time series after the start of the second suction is calculated, and the accumulation is stopped when the pressure in the fluid pipeline recovers and stabilizes to obtain the accumulated pressure value at this time.

[0071] Specifically, after the second suction begins, the cumulative pressure value sum[n] for each time series is equal to the sum of the pressure value P[n] for the current time series and the cumulative pressure value sum[n-1] for the previous time series.

[0072] That is, the principle for calculating the cumulative pressure value is: the cumulative pressure value at time N3 sum[N3] = 0, and the cumulative pressure value at each time after N3 sum[n] = P[n] + sum[n-1]. Thus, the cumulative pressure value sum[N5] can be calculated when the pressure in the fluid pipeline returns to stability after the second suction.

[0073] Then, based on the accumulated pressure value sum[N5] when the pressure in the fluid pipeline recovers to a stable state, the sampling period T, the time series N3 corresponding to the start time of the second suction, the pressure value P[N3] corresponding to the start time of the second suction, the time series N5 corresponding to the time when the pressure in the fluid pipeline recovers to a stable state, the pressure value P[N5] corresponding to the start time of the second suction, the preset suction volume V, and the pressure drop flow factor C... pf This allows you to calculate the fluidity (MOB). Specifically,

[0074]

[0075] Before step S120 and before step S130, it is necessary to determine whether the pressure in the fluid pipeline has returned to stability after suction. Specifically, the method for determining whether the pressure in the fluid pipeline has returned to stability is as follows: if the pressure fluctuation in the fluid pipeline is less than 1 psi / min within a certain time period, it is determined that the pressure in the fluid pipeline has returned to stability, and at this time the pressure in the fluid pipeline is equal to the formation pressure.

[0076] In an alternative embodiment, after calculating the fluid flow rate in step S130 based on the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, and the real-time pressure at each moment, the method further includes: transmitting the calculated fluid flow rate to the ground receiving unit via a pulser, so that the ground receiving unit can calculate the fluid permeability based on the received fluid flow rate.

[0077] In this embodiment, the data transmitted to the ground is the calculated fluid mobility data. The permeability can be calculated based on the fluid mobility data. Compared with the prior art, this embodiment greatly shortens the data transmission time and has the advantage of better timeliness.

[0078] Specifically, such as Figure 6 As shown, ground commands, such as preset suction volumes, are transmitted to the main control board via the pulse generator. The main control board is equipped with a TBUS interface, and the pulse generator and the TBUS interface of the main control board communicate via the TBUS bus. At the same time, the TBUS bus also powers the main control board. The main control board transmits commands to the power management board, the sealing mechanism control board, the suction control board, and the pressure gauge via the RS485 interface. The pressure data from the pressure gauge is transmitted to the MSP430 microcontroller via the RS485 interface and the RS85 bus. The MSP430 microcontroller is used to calculate the flow rate and transmits the calculation results to the pulse generator, which then transmits the flow rate results to the ground.

[0079] According to another aspect of the present invention, an apparatus for calculating fluid mobility under drilling conditions is provided, comprising:

[0080] Control unit: used to control the drilling instrument to perform the first fluid extraction according to the preset extraction volume; and used to control the drilling instrument to perform the second fluid extraction according to the preset extraction volume after determining that the pressure in the fluid pipeline has recovered to a stable state, taking the time of recovery to a stable state as the start time of the second fluid extraction.

[0081] The calculation unit is used to calculate the flow rate of the fluid based on the time and real-time pressure at each moment during the process from the start of the second suction to the pressure in the fluid pipeline stabilizing again, after determining that the pressure in the fluid pipeline has stabilized again.

[0082] Specifically, the drilling instrument in this embodiment is a drilling formation tester. The first suction serves to clean the residual fluid in the fluid pipeline and achieves the connection between the pipeline and the formation. The volume of the first suction is a preset volume.

[0083] During the first suction process, the pressure in the fluid pipeline will drop below the formation pressure. After the suction stops, the pressure in the fluid pipeline will gradually recover. Once the pressure in the fluid pipeline stabilizes, the drilling instrument will be controlled to perform a second suction. The suction volume of the second suction is still the preset volume. After the preset volume is suctioned for the second time, the pump will be stopped. The fluid flow rate is calculated based on the time and real-time pressure at each moment during the process from the start of the second suction to the pressure in the fluid pipeline stabilizing.

[0084] In this embodiment, after the first extraction, when the fluid pipeline pressure stabilizes, the pressure inside the fluid pipeline equals the formation pressure. Therefore, the second extraction in this embodiment is the extraction of formation fluid. Compared with the prior art, this embodiment does not require determining the timing of the extraction of formation fluid. Secondly, since the formation fluid is extracted during the second extraction in this embodiment, the fluid flow rate is calculated based on the time and real-time pressure at each moment during the process from the start of the second extraction to the stabilization of the pressure in the fluid pipeline. This has the advantage of simple calculation.

[0085] In one alternative embodiment, before the calculation unit calculates the fluid flow rate based on the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, and the real-time pressure at each moment, this embodiment further includes a conversion unit for converting the time at each moment into a time series in the digital domain corresponding to the time at each moment.

[0086] Specifically, since the downhole circuit is a digital circuit, before calculating the fluid flow rate, it is necessary to convert the time at each moment from the start of the second pumping to the pressure recovery and stabilization of the fluid pipeline into a digital time series.

[0087] Specifically, converting the time at each moment into a digital domain time series corresponding to that moment is as follows: the digital domain time series corresponding to each moment is equal to the time at each moment divided by the sampling period of the drilling instrument. Specifically, let n represent the digital domain time series and t represent the real-time time, then n*T = t, where T represents the sampling period. Therefore, the corresponding digital domain time series can be obtained based on the real-time time t.

[0088] Therefore, based on the digital domain time series and the corresponding pressure, in this embodiment, the calculation unit calculates the fluid flow rate according to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, as well as the real-time pressure at each moment. Specifically, the fluid flow rate is calculated based on the digital domain time series corresponding to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, as well as the real-time pressure at each moment.

[0089] In one alternative approach, calculating the fluid flowability based on the digital domain time series corresponding to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, and the real-time pressure at each moment, further includes:

[0090] When the second suction begins, the accumulated pressure value is set to zero. The accumulated pressure value for each time series after the start of the second suction is calculated, and the accumulation is stopped when the pressure in the fluid pipeline returns to stability. The accumulated pressure value at this time is obtained. The accumulated pressure value for each time series after the start of the second suction is equal to the sum of the pressure value for the current time series and the accumulated pressure value for the previous time series.

[0091] The fluidity is calculated based on the accumulated pressure value when the pressure in the fluid pipeline stabilizes, the sampling period, the time series and pressure value corresponding to the start time of the second suction, the time series and pressure value corresponding to the time when the pressure in the fluid pipeline stabilizes, the preset suction volume, and the pressure drop flow factor.

[0092] Specifically, based on the accumulated pressure value sum[N5] when the pressure in the fluid pipeline recovers to a stable state, the sampling period T, the time series N3 corresponding to the start time of the second suction, the pressure value P[N3] corresponding to the start of the second suction, the time series N5 corresponding to the time when the pressure in the fluid pipeline recovers to a stable state, the pressure value P[N5] corresponding to the start of the second suction, the preset suction volume V, and the pressure drop flow factor C... pf The fluidity MOB can then be calculated.

[0093]

[0094] The method for determining whether the pressure in the fluid pipeline has returned to stability is as follows: if the pressure fluctuation in the fluid pipeline is less than 1 psi / min within a certain time period, then the pressure in the fluid pipeline is determined to have returned to stability, and at this time the pressure in the fluid pipeline is equal to the formation pressure.

[0095] In one alternative approach, after the calculation unit calculates the fluid flow rate based on the time and real-time pressure at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, the method further includes: transmitting the calculated fluid flow rate to a ground receiving unit via a pulser, so that the ground receiving unit can calculate the fluid permeability based on the received fluid flow rate.

[0096] In this embodiment, the data transmitted to the ground is the calculated fluid mobility data. The permeability can be calculated based on the fluid mobility data. Compared with the prior art, this embodiment greatly shortens the data transmission time and has the advantage of better timeliness.

[0097] This invention provides a non-volatile computer storage medium storing at least one executable instruction that can execute the method for calculating fluid flow rate under drilling conditions in any of the above method embodiments.

[0098] Figure 7 The diagram shows a structural schematic of an embodiment of a computing device according to the present invention. The specific embodiments of the present invention do not limit the specific implementation of the computing device.

[0099] like Figure 7 As shown, the computing device may include: a processor 402, a communications interface 404, a memory 406, and a communications bus 408.

[0100] The processor 402, communication interface 404, and memory 406 communicate with each other via communication bus 408. Communication interface 404 is used to communicate with other network elements, such as clients or other servers. Processor 402 executes program 410, specifically performing the relevant steps in the above-described method embodiment for calculating fluid flow rate under drilling conditions.

[0101] Specifically, program 410 may include program code that includes computer operation instructions.

[0102] Processor 402 may be a central processing unit (CPU), an application-specific integrated circuit (ASIC), or one or more integrated circuits configured to implement embodiments of the present invention. The apparatus for calculating fluid flow rate during drilling operations includes one or more processors, which may be processors of the same type, such as one or more CPUs; or processors of different types, such as one or more CPUs and one or more ASICs.

[0103] Memory 406 is used to store program 410. Memory 406 may include high-speed RAM memory, and may also include non-volatile memory, such as at least one disk storage device.

[0104] Specifically, program 410 can be used to cause processor 402 to execute the method for calculating fluid mobility under drilling conditions in any of the above method embodiments.

[0105] The algorithms or displays provided herein are not inherently related to any particular computer, virtual system, or other device. Various general-purpose systems can also be used in conjunction with the teachings herein. The required structure for constructing such systems is apparent from the above description. Furthermore, the embodiments of the present invention are not directed to any particular programming language. It should be understood that the content of the invention described herein can be implemented using various programming languages, and the above description of specific languages ​​is for the purpose of disclosing the best mode of implementation of the invention.

[0106] Numerous specific details are set forth in the specification provided herein. However, it will be understood that embodiments of the invention may be practiced without these specific details. In some instances, well-known methods, structures, and techniques have not been shown in detail so as not to obscure the understanding of this specification.

[0107] Similarly, it should be understood that, in order to simplify the invention and aid in understanding one or more of the various inventive aspects, features of the embodiments of the invention are sometimes grouped together in a single embodiment, figure, or description thereof in the above description of exemplary embodiments of the invention. However, this disclosure should not be construed as reflecting an intention that the claimed invention requires more features than are expressly recited in each claim. Rather, as reflected in the following claims, inventive aspects lie in fewer than all features of a single foregoing disclosed embodiment. Therefore, the claims following the detailed description are hereby expressly incorporated into this detailed description, wherein each claim itself is a separate embodiment of the invention.

[0108] Those skilled in the art will understand that modules in the device of the embodiments can be adaptively changed and placed in one or more devices different from that embodiment. Modules, units, or components in the embodiments can be combined into a single module, unit, or component, and further, they can be divided into multiple sub-modules, sub-units, or sub-components. Except where at least some of such features and / or processes or units are mutually exclusive, any combination can be used to combine all features disclosed in this specification (including the accompanying claims, abstract, and drawings) and all processes or units of any method or device so disclosed. Unless expressly stated otherwise, each feature disclosed in this specification (including the accompanying claims, abstract, and drawings) may be replaced by an alternative feature that serves the same, equivalent, or similar purpose.

[0109] Furthermore, those skilled in the art will understand that although some embodiments herein include certain features included in other embodiments but not others, combinations of features from different embodiments are intended to be within the scope of the invention and form different embodiments. For example, in the following claims, any of the claimed embodiments can be used in any combination.

[0110] The various component embodiments of the present invention can be implemented in hardware, or as software modules running on one or more processors, or a combination thereof. Those skilled in the art will understand that microprocessors or digital signal processors (DSPs) can be used in practice to implement some or all of the functions of some or all of the components according to the embodiments of the present invention. The present invention can also be implemented as a device or apparatus program (e.g., a computer program and computer program product) for performing part or all of the methods described herein. Such programs implementing the present invention can be stored on a computer-readable medium, or can be in the form of one or more signals. Such signals can be downloaded from an Internet website, provided on a carrier signal, or provided in any other form.

[0111] It should be noted that the above embodiments are illustrative of the invention and not restrictive, and that those skilled in the art can devise alternative embodiments without departing from the scope of the appended claims. In the claims, any reference signs placed between parentheses should not be construed as limiting the claims. The word "comprising" does not exclude the presence of elements or steps not listed in the claims. The word "a" or "an" preceding an element does not exclude the presence of a plurality of such elements. The invention can be implemented by means of hardware comprising several different elements and by means of a suitably programmed computer. In the unit claims enumerating several means, several of these means may be embodied by the same item of hardware. The use of the words first, second, and third, etc., does not indicate any order. These words can be interpreted as names. The steps in the above embodiments, unless otherwise specified, should not be construed as limiting the order of execution.

Claims

1. A method for calculating fluid mobility under drilling conditions, characterized in that, include: The drilling instrument is controlled to perform the first fluid extraction according to the preset extraction volume; After determining that the pressure in the fluid pipeline has stabilized, the time when the pressure stabilizes is taken as the start time of the second fluid extraction, and the drilling instrument is controlled to perform the second fluid extraction according to the preset extraction volume. After determining that the pressure in the fluid pipeline has stabilized again, the flow rate of the fluid is calculated based on the time at each moment during the process from the start of the second suction to the stabilization of the pressure in the fluid pipeline and the real-time pressure at each moment. Before calculating the fluid flow rate based on the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, and the real-time pressure at each moment, the method further includes: converting the time at each moment into a time series in the digital field corresponding to the time at each moment; The calculation of the fluid flow rate based on the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, as well as the real-time pressure at each moment, specifically involves: calculating the fluid flow rate based on the digital field time series corresponding to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, as well as the real-time pressure at each moment. The calculation of the fluid flowability based on the digital domain time series corresponding to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, and the real-time pressure at each moment, further includes: When the second suction begins, the accumulated pressure value is set to zero. The accumulated pressure value for each time series after the start of the second suction is calculated, and the accumulation stops when the pressure in the fluid pipeline stabilizes. The accumulated pressure value at this point is obtained. The accumulated pressure value for each time series after the start of the second suction is equal to the sum of the pressure value for the current time series and the accumulated pressure value for the previous time series. The fluidity is calculated based on the accumulated pressure value when the pressure in the fluid pipeline stabilizes, the sampling period, the time series and pressure value corresponding to the start time of the second suction, the time series and pressure value corresponding to the time when the pressure in the fluid pipeline stabilizes, the preset suction volume, and the pressure drop flow factor. The calculation of the fluid flowability based on the accumulated pressure value when the pressure in the fluid pipeline stabilizes, the sampling period, the time series and pressure value corresponding to the start time of the second suction, the time series and pressure value corresponding to the time when the pressure in the fluid pipeline stabilizes, the preset suction volume, and the pressure drop flow factor is specifically as follows: The accumulated pressure value when the pressure in the fluid pipeline stabilizes is set to sum[N5], the sampling period is T, the preset suction volume is V, and the pressure drop flow factor is C. pf The time series corresponding to the start time of the second suction is N3, the pressure value corresponding to the start of the second suction is P[N3], the time series corresponding to the time when the pressure in the fluid pipeline recovers to a stable state is N5, the pressure value corresponding to the time when the pressure in the fluid pipeline recovers to a stable state is P[N5], and the flow rate of the fluid is set to MOB, then: 。 2. The method according to claim 1, characterized in that, The specific steps for converting the time at each moment into a time series in the corresponding digital field are as follows: The time series of the digital field corresponding to each time point is equal to the time at each time point divided by the sampling period of the drilling instrument.

3. The method according to claim 1, characterized in that, The method for determining whether the pressure in the fluid pipeline has returned to stability is as follows: If the pressure fluctuation in the fluid pipeline is less than 1 psi / min within a certain period of time, it is determined that the pressure in the fluid pipeline has returned to stability, and at this time the pressure in the fluid pipeline is equal to the formation pressure.

4. The method according to claim 1, characterized in that, After calculating the fluid flow rate based on the time intervals and real-time pressures at each moment during the process from the start of the second suction to the pressure stabilization in the fluid pipeline, the method further includes: The calculated fluid flow rate is transmitted to the ground receiving unit via a pulser, so that the ground receiving unit can calculate the fluid permeability based on the received fluid flow rate.

5. A device for calculating fluid mobility under drilling conditions, characterized in that, include: Control unit: Used to control the drilling instrument to perform the first fluid extraction according to the preset extraction volume; And to determine the time when the pressure in the fluid pipeline has recovered to a stable state, and to use the time of recovery to a stable state as the start time for the second fluid extraction, and to control the drilling instrument to perform the second fluid extraction according to the preset extraction volume. The calculation unit is used to calculate the flow rate of the fluid based on the time at each moment during the process from the start of the second suction to the time when the pressure in the fluid pipeline stabilizes, and the real-time pressure at each moment, after determining that the pressure in the fluid pipeline has stabilized again. Before the calculation unit calculates the fluid flow rate based on the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, as well as the real-time pressure at each moment, the device further includes a conversion unit, which is used to convert the time at each moment into a time series in the digital field corresponding to the time at each moment. The calculation unit calculates the fluid flow rate based on the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, as well as the real-time pressure at each moment. Specifically, the fluid flow rate is calculated based on the digital field time series corresponding to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, as well as the real-time pressure at each moment. The calculation of the fluid flowability based on the digital domain time series corresponding to the time at each moment during the process from the start of the second suction to the pressure recovery and stabilization in the fluid pipeline, and the real-time pressure at each moment, further includes: When the second suction begins, the accumulated pressure value is set to zero. The accumulated pressure value for each time series after the start of the second suction is calculated, and the accumulation stops when the pressure in the fluid pipeline stabilizes. The accumulated pressure value at this point is obtained. The accumulated pressure value for each time series after the start of the second suction is equal to the sum of the pressure value for the current time series and the accumulated pressure value for the previous time series. The fluidity is calculated based on the accumulated pressure value when the pressure in the fluid pipeline stabilizes, the sampling period, the time series and pressure value corresponding to the start time of the second suction, the time series and pressure value corresponding to the time when the pressure in the fluid pipeline stabilizes, the preset suction volume, and the pressure drop flow factor. The calculation of the fluid flowability based on the accumulated pressure value when the pressure in the fluid pipeline stabilizes, the sampling period, the time series and pressure value corresponding to the start time of the second suction, the time series and pressure value corresponding to the time when the pressure in the fluid pipeline stabilizes, the preset suction volume, and the pressure drop flow factor is specifically as follows: The accumulated pressure value when the pressure in the fluid pipeline stabilizes is set to sum[N5], the sampling period is T, the preset suction volume is V, and the pressure drop flow factor is C. pf The time series corresponding to the start time of the second suction is N3, the pressure value corresponding to the start of the second suction is P[N3], the time series corresponding to the time when the pressure in the fluid pipeline recovers to a stable state is N5, the pressure value corresponding to the time when the pressure in the fluid pipeline recovers to a stable state is P[N5], and the flow rate of the fluid is set to MOB, then: 。 6. A computing device, comprising: The processor, memory, communication interface, and communication bus are provided, wherein the processor, memory, and communication interface communicate with each other via the communication bus. The memory is used to store at least one executable instruction that causes the processor to perform an operation corresponding to the method for calculating fluid mobility under drilling conditions as described in any one of claims 1-4.

7. A computer storage medium storing at least one executable instruction that causes a processor to perform an operation corresponding to the method for calculating fluid mobility under drilling conditions as described in any one of claims 1-4.

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