A push-to-store production logging system and method

Abstract

The application provides a direct push storage type production logging system and method, which comprises a depth-time recording device, which obtains a real-time logging depth signal by using a sensor and a winch assembly parameter of a working machine; a downhole detection module connected with a winch of an oil well working machine and a tubing, which pushes the detection module to a measurement target layer by connecting the tubing to form a pipe column with a certain length to obtain downhole logging data; a downhole storage module which stores the downhole detection data; and a collection control module which communicates with the depth-time recording device and the downhole storage module, and which is used for realizing data collection and correction and generating a logging file corresponding to data and depth. By using the above system, even under the condition of complex well conditions such as inclined wells or horizontal wells, the target layer can be reliably and stably reached, and the overall downhole production or injection condition can be obtained, and the data is corrected based on the downhole magnetic positioning data, so that repeated data processing is avoided, and the detection efficiency and reliability are significantly improved.

Description

Technical Field

[0001] This invention relates to the field of exploration and development logging technology, and in particular to a direct-push storage production logging system and method. Background Technology

[0002] Production logging is a crucial tool for evaluating the production or injection profiles of oil and gas wells in exploration and development projects. Production logging data can be used to determine the production status of oil and gas wells, providing important information for subsequent measures such as water shut-off and profile control to increase oil and gas production. Currently, production logging primarily uses a surface system connected to downhole instruments via a winch cable. The downhole instruments are lowered to the target formation using their own weight or with the assistance of a downhole crawler, along with the cable. The surface system supplies power to the downhole instruments via the cable, and then the surface winch pulls up the cable to move the instruments and measure fluid information in the well in real time. However, using this method for logging can be problematic in complex well conditions such as casing deformation, highly deviated wells, or long horizontal well sections. In such cases, the downhole instruments may struggle to reach the target formation, leading to invalid logging data and insufficient reliability.

[0003] The information disclosed in the background section of this invention is intended only to enhance the understanding of the general background of this invention, and should not be construed as an admission or in any way implying that such information constitutes prior art known to those skilled in the art. Summary of the Invention

[0004] To address the above problems, the present invention provides a direct-push storage production logging system and method. In one embodiment, the system includes:

[0005] A depth time recording device, which is associated with an oil well workover rig, is configured to acquire real-time logging depth signals based on sensors and winch component parameters of the oil well workover rig;

[0006] The downhole detection module is pushed to the target layer by continuously connecting the tubing to the well workover rig to form a tubing string of a certain length, so as to obtain downhole detection data and depth correction data.

[0007] The downhole storage module is configured to store the data acquired by the downhole detection module in real time according to a set period.

[0008] The acquisition and control module is communicatively connected to the depth time recording device and the downhole storage module, and is used to realize depth calculation and recording, as well as to perform synchronous processing of detection data and depth data;

[0009] In a preferred embodiment, the depth time recording device includes a tension acquisition and conversion module;

[0010] The tension acquisition and conversion module includes a tension sensor installed on the dead rope of the oil well workover machine winch, used to acquire the tension electrical signal data of the main rope of the workover machine;

[0011] The tension acquisition and conversion module also includes a current-to-voltage conversion circuit and an analog-to-digital conversion circuit connected in sequence. The current-to-voltage conversion circuit converts the current signal data acquired by the tension sensor into voltage signal data, and the analog-to-digital conversion circuit converts it into a digital signal of tension data.

[0012] Furthermore, in one embodiment, the depth time recording device further includes a pulse counting module;

[0013] The pulse counting module includes a depth encoder, a winch interface circuit, and a pulse counting circuit.

[0014] The depth encoder installed on the winch roller of the oil well workover machine outputs a rotation encoding signal. After being processed by the winch interface circuit to meet the level requirements of the pulse counting circuit, the signal is transmitted to the pulse counting circuit.

[0015] Specifically, the acquisition and control module determines whether the depth of the downhole detection module has changed based on the signal pulse data from the pulse counting circuit and the tension data from the tension acquisition and conversion module. It also calculates the depth of the bottom of the downhole tubing by combining the drum length of the oil well workover machine, the diameter of the winch roller, the number of layers of the main rope on the drum, the diameter of the main rope, and the number of strands of the main rope, and records the depth of the bottom of the downhole tubing in real time.

[0016] In one embodiment, the downhole detection module includes: temperature, pressure, flow rate, fluid density, and oil, gas and water holdup detectors, which are connected to form a downhole detection instrument string for collecting real-time downhole detection data at the corresponding depth;

[0017] After the downhole storage module and the surface time-depth recording device are synchronized by the acquisition and control module, the downhole detection instrument to be run into the well is connected to the bottom end of the tubing after the outer diameter size and connection thread type are changed through the transition short section.

[0018] Furthermore, in one embodiment, the downhole detection module further includes a magnetic positioning detector;

[0019] The magnetic positioning detector is used to record the changes in the positioning data of the downhole detection module in real time. Since it can capture the depth when the downhole detection module is not moving, after the downhole detection module returns to the surface, it identifies and clears duplicate depth data through magnetic positioning data, and clears the interfering detection data corresponding to the duplicate depth.

[0020] In an optional embodiment, the downhole detection module further includes a natural gamma detector, used to compare the natural gamma data it collects with the natural gamma data of the open hole well to obtain the offset of the depth data during the current logging process, so as to achieve further depth correction by combining the distance data between each detector and the bottom of its instrument string.

[0021] Specifically, in one embodiment, the depth time recording device records the tension signal of the well workover machine's main rope according to a set recording time period, and the acquisition control module synchronously calculates and records the depth position of the bottom of the tubing. The recording time period is less than the lower limit of the detection period of any detector.

[0022] The acquisition and control module reads the time data and corresponding detection data from the downhole storage module according to the set reading cycle.

[0023] Based on aspects of the system described in any one or more of the above embodiments, the present invention also provides a direct-pull storage production logging method applied to the system described in any one or more of the above embodiments, the method comprising:

[0024] Before going down into the well, measure the component parameters of the well workover machine winch, including: drum length, winch roller diameter, number of main rope layers on the drum, main rope diameter, and number of main rope strands;

[0025] The length of the instrument string and the distance between each detector and the bottom of the instrument string are measured.

[0026] Experiments were conducted based on the component parameters of the well workover machine winch roller and the properties of the tension sensor to determine the effective tension threshold of the downhole detection module.

[0027] After the well begins to run, the tension signal of the workover rig's main rope is recorded by the depth-time recording device at a set recording time period. Based on the tension signal of the workover rig's main rope and the parameters of the oil well workover rig components, the depth position of the bottom of the tubing is calculated and recorded synchronously to form a time-depth signal file. The recording time period is less than the lower limit of the detection period of any detector.

[0028] After the downhole exploration module returns to the surface, the acquisition and control module reads the time data and corresponding exploration data from the downhole storage module according to the set reading cycle, forming a time-downhole data file;

[0029] Based on the time correspondence, the depth signals in the two files are matched one-to-one with the downhole data to form a tubing depth-downhole data file;

[0030] The depth data and detection data are initially corrected based on the data from the magnetic positioning detector to filter out interference data with repeated depth positions.

[0031] The depth offset is determined by comparing the logging data of the natural gamma detector with the natural gamma data of the open hole. The depth data is then corrected by combining the distance data between each detector and the bottom of its instrument string.

[0032] The acquisition and control module performs data resampling on the corrected depth data and exploration data to generate logging data that is synchronized with the depth and exploration data.

[0033] Compared with the closest prior art, the present invention also has the following beneficial effects:

[0034] This invention provides a direct-push storage production logging system and method, which connects a downhole detection module to the downhole tubing of an oil well workover rig. By continuously connecting the tubing to form a string of a certain length, the oil well workover rig pushes the detection module to the target layer. Even in complex well conditions such as long-distance inclined or horizontal wells, it can reliably and steadily reach the target layer and effectively obtain comprehensive downhole logging data. In addition, the real-time depth of the downhole detection module can be calculated and determined on the surface using a time-depth recording device and an acquisition control module, which offers high flexibility and operability while ensuring the accuracy of depth data.

[0035] Other features and advantages of the invention will be set forth in the description which follows, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures particularly pointed out in the description, claims, and drawings. Attached Figure Description

[0036] The accompanying drawings are provided to further illustrate the invention and form part of the specification. They are used in conjunction with the embodiments of the invention to explain the invention and do not constitute a limitation thereof. In the drawings:

[0037] Figure 1 This is a schematic diagram of the structure of a direct-push storage production logging system provided in an embodiment of the present invention;

[0038] Figure 2 This is an example diagram of the downhole detection instrument string of the direct-push storage production logging system provided in this embodiment of the invention;

[0039] Figure 3 This is a flowchart illustrating the data processing principle of a direct-push storage production logging system provided in another embodiment of the present invention;

[0040] Figure 4 This is a schematic diagram of the depth-time recording device of a direct-push storage production logging system provided in an embodiment of the present invention. Detailed Implementation

[0041] The embodiments of the present invention will be described in detail below with reference to the accompanying drawings and examples. Those skilled in the art will then fully understand how the present invention uses technical means to solve technical problems and achieve technical effects, and will be able to implement the present invention specifically based on the above-described implementation process. It should be noted that, as long as there is no conflict, the various embodiments and features of the present invention can be combined with each other, and the resulting technical solutions are all within the protection scope of the present invention.

[0042] Although the flowchart describes the operations as sequential processes, many of these operations can be performed in parallel, concurrently, or simultaneously. The order of the operations can be rearranged. A process can terminate when its operation is complete, but it may also have additional steps not included in the diagram. A process can correspond to a method, function, procedure, subroutine, subroutine, etc.

[0043] Computer equipment includes user equipment and network equipment. User equipment or clients include, but are not limited to, computers, smartphones, PDAs, etc.; network equipment includes, but is not limited to, a single network server, a server group consisting of multiple network servers, or a cloud based on cloud computing consisting of a large number of computers or network servers. Computer equipment can operate independently to implement this invention, or it can connect to a network and implement this invention through interaction with other computer equipment in the network. The network in which the computer equipment is located includes, but is not limited to, the Internet, wide area network, metropolitan area network, local area network, VPN network, etc.

[0044] The terminology used herein is for the purpose of describing particular embodiments only and is not intended to limit the exemplary embodiments. Unless the context clearly indicates otherwise, the singular forms “a” and “an” as used herein are also intended to include the plural. It should also be understood that the terms “comprising” and / or “including” as used herein specify the presence of the stated features, integers, steps, operations, units, and / or components, without excluding the presence or addition of one or more other features, integers, steps, operations, units, components, and / or combinations thereof.

[0045] In development projects, production or injection profile data from oil and gas wells are crucial for assessing well production status and for implementing subsequent water shut-off and profile control measures to increase oil and gas production. Production logging is a vital method for obtaining this data. Currently, the most common production logging approach involves using a surface system connected to downhole instruments via a winch cable. The instruments are lowered to the target formation using their own weight or with the assistance of a downhole crawler, along with the cable. The surface winch then lifts the cable, allowing the instruments to measure fluid information in the well in real time. However, this method is problematic in complex well conditions, such as casing deformation or long horizontal well sections, making it difficult to lower the instruments to the target formation. This results in logging data errors, insufficient reliability, and even logging failures.

[0046] To address the aforementioned problems, this invention provides a direct-drive storage-type production logging system and method. This system uses an oil well workover rig connected to tubing to deliver downhole instruments. Measurement information is stored inside the downhole instruments. After measurement is completed and the downhole instruments are retrieved from the wellhead, the surface acquisition and control module reads the stored data and correlates it with the tubing depth on the surface to form complete logging data. This effectively solves the logging problem of instruments being difficult to reach the target formation under complex well conditions, while ensuring the accuracy and completeness of the logging data.

[0047] The following describes the detailed flow of the method according to an embodiment of the present invention with reference to the accompanying drawings, the steps of which can be executed in a computer system containing, for example, a set of computer-executable instructions. Although the logical order of the steps is shown in the flowchart, in some cases, the steps shown or described may be performed in a different order than that shown here.

[0048] Example 1

[0049] Figure 1 This diagram illustrates the structure of the direct-push storage production logging system provided in Embodiment 1 of the present invention. (Refer to...) Figure 1 It can be seen that the system includes:

[0050] A depth time recording device, which is set up in conjunction with an oil well workover rig, is configured to acquire real-time logging depth signals based on sensors and winch component parameters of the oil well workover rig;

[0051] The downhole detection module is set up in conjunction with the main rope and tubing of the well workover rig. The well workover rig continuously connects the tubing to form a tubing string of a certain length, pushing the detection module to the target layer for measurement in order to obtain downhole detection data and depth correction data.

[0052] The downhole storage module is configured to store the data acquired by the downhole detection module in real time according to a set period.

[0053] The acquisition and control module is communicatively connected to the depth time recording device and the downhole storage module, and is used to realize depth data acquisition and correction, as well as to perform synchronous processing of detection data and depth data;

[0054] The downhole power supply module uses batteries to provide power to the downhole detection module and storage module.

[0055] In one embodiment, the downhole detection module includes detectors for temperature, pressure, flow rate, fluid density, and oil, gas and water holdup. These detectors are connected to form a downhole detection instrument string for collecting real-time downhole detection data at different depths.

[0056] Furthermore, in one embodiment, the downhole detection module further includes a magnetic positioning detector;

[0057] The magnetic positioning detector is used to record the changes in the positioning data of the downhole detection module in real time. Since it can capture the depth when the downhole detection module is not moving, after the downhole instrument returns to the surface, it can identify and clear duplicate depth data through magnetic positioning data to achieve correction, and clear the interference detection data corresponding to duplicate depths.

[0058] In practical applications, the downhole power supply module can be a downhole battery sub, and the downhole storage module can be a downhole storage sub. These are connected to a magnetic positioning detector, a natural gamma detector, and detectors for temperature, pressure, flow rate, fluid density, and oil / gas / water holdup to form a complete downhole instrument string. Before running it into the well, the specific combination of the downhole instrument string can be decided or adjusted by the operator based on the actual logging needs of the oil well. In one embodiment, the instrument string consisting of the downhole battery sub, the downhole storage sub, and detectors for magnetic positioning, natural gamma, temperature, pressure, flow rate, fluid density, and oil / gas / water holdup is as follows: Figure 2 As shown.

[0059] In practical applications, in one embodiment, the total length of the downhole detection instrument string is set to l. After the downhole storage sub and the surface time-depth recording device are synchronized via the surface acquisition control module, the downhole instrument string is connected to the bottom of the tubing after the outer diameter and connecting thread type are changed through the transition sub. The workover rig pushes the downhole instrument to the target layer by continuously connecting the tubing to form a tubing string of a certain length. The downhole storage sub controls the downhole battery sub to continuously supply power to the downhole detector at predetermined time intervals to perform measurements and sample the measured values ​​of the downhole detector at a certain frequency for storage, generating a time-downhole data file. Its storage frequency is the same as or multiple times the sampling frequency of the surface time-depth recording device.

[0060] Furthermore, in one embodiment, the downhole detection module also includes a natural gamma detector, which is used to compare the natural gamma data collected by it with the natural gamma data of the open hole well to obtain the offset of the depth data during the current logging process, so as to achieve further depth correction by combining the distance data between each detector and the bottom of its instrument string.

[0061] In practical applications, natural gamma and magnetic positioning measurement are used to complete the depth correction of logging data. First, duplicate depth data are removed based on magnetic positioning data. Then, the natural gamma data is compared with the natural gamma data of open hole logging to determine the offset of the direct-pull storage production logging depth, which is used to calculate accurate logging depth data.

[0062] Specifically, after the downhole instrument returns to the surface, the surface acquisition and control module reads the time-downhole data file from the downhole storage segment and performs integrated processing with the time-depth file recorded on the surface. The data processing flow diagram is shown below. Figure 3 Based on the time correspondence, the depth signals in the two files are matched one-to-one with the downhole data to form a tubing depth-downhole data file;

[0063] Because no signal is generated when the instrument is stationary in magnetic positioning logging, the recorded magnetic positioning data shows relatively small fluctuations. In a specific embodiment, the movement of the tubing and instrument is determined based on the magnetic positioning data. When a continuous logging curve needs to be formed, the repeated depths recorded when the instrument is stationary and the corresponding detector data should be removed. Then, the natural gamma data is compared with the natural gamma data from open-hole logging to determine the offset (ΔD) of the direct-pull storage production logging depth.

[0064] Furthermore, if the depth of the bottom of the tubing is D, and the distance of a certain detector in the instrument string from the bottom of the instrument string is oft, then the formation depth corresponding to the data of that detector is D+ΔD+l-oft. After depth correction, a formation depth-downhole data file for each downhole detector is formed. The maximum formation depth in the file is selected as the same starting depth. The same depth sampling interval is used to resample the formation depth-downhole data file of each downhole detector before outputting the logging file data.

[0065] Specifically, in one embodiment, the depth time recording device includes a tension acquisition and conversion module;

[0066] The tension acquisition and conversion module includes a tension sensor installed on the dead rope of the oil well workover machine winch, used to acquire the tension electrical signal data of the main rope of the workover machine;

[0067] The tension acquisition and conversion module also includes a current-to-voltage conversion circuit and an analog-to-digital conversion circuit connected in sequence. The current-to-voltage conversion circuit converts the current signal data acquired by the tension sensor into voltage signal data, and the analog-to-digital conversion circuit converts it into a digital signal of tension data.

[0068] In one embodiment, the depth time recording device uses a pressure-side tension sensor to collect the main rope tension of the oil well workover rig, so that the acquisition control module can further control the processing and recording of depth data through the real-time main rope tension parameters.

[0069] Furthermore, the depth time recording device also includes a pulse counting module;

[0070] The pulse counting module includes a depth encoder, a winch interface circuit, and a pulse counting circuit.

[0071] The depth encoder installed on the winch drum of the oil well workover machine outputs a rotation encoding signal. After being processed by the winch interface circuit to meet the level requirements of the pulse counting circuit, the signal is transmitted to the pulse counting circuit.

[0072] The acquisition and control module determines whether the depth of the downhole detection module has changed based on the signal pulse data from the pulse counting circuit and the tension data from the tension acquisition and conversion module. It also calculates the depth of the bottom of the downhole tubing by combining the drum length of the oil well workover machine, the diameter of the winch roller, the number of layers of the main rope on the drum, the diameter of the main rope, and the number of strands of the main rope, and records the depth of the bottom of the downhole tubing in real time.

[0073] In one embodiment, the acquisition and control module calculates the bottom depth of the tubing based on the signal pulse data from the pulse counting circuit, combined with the drum length of the well workover machine, the winch roller diameter, the number of layers of the main rope on the drum, the main rope diameter, and the number of main rope strands, in order to record the formation time-tubing depth file.

[0074] In practical applications, in one embodiment, the depth time recording device is as follows: Figure 4 As shown, the system mainly consists of a pressure-side tension sensor, a depth encoder, a winch interface circuit, an I / V current-to-voltage converter, an A / D analog-to-digital converter, and a pulse counting circuit. The pressure-side tension sensor is installed on the dead rope of the oil well workover rig, and the depth encoder is installed on the winch drum shaft. The output encoded signal is preprocessed by the winch interface circuit to meet the level requirements of the counter, and then sent to the pulse counting circuit. The pulse counting circuit determines the movement direction of the instrument based on the phase difference between the A and B phase signals of the encoded signal and performs addition and subtraction counting. The current signal output by the pressure-side tension sensor is converted into a voltage signal by the I / V converter and sent to the A / D analog-to-digital converter to form a digital signal T. 张 The acquisition and control module acquires the output data CT from the pulse counter and the data T output from the A / D analog-to-digital converter circuit at a certain sampling time interval Δt. 张 .

[0075] Before logging begins, the acquisition control module can be pre-set with a large rope tension threshold value T. th By combining the results of the large rope tension signal and the threshold value, the depth data of the bottom of the downhole tubing under different conditions is calculated.

[0076] Assume that at the initial time t0, the depth of the bottom of the tubing is D1. 0 The number of layers of the large rope on the drum is C1. 0 The outermost large rope has n1 loops. t0 Pulse counter data for CT 0 Then at time t1 = t0 + Δt, if T 张 >T thBased on the number of signal pulses N output by the depth encoder per revolution, the drum length L, the winch roller diameter d1, the main rope diameter d2, and the number of main rope strands n2, the acquisition and control module will convert the pulse counter data CT. 1 Converted to the lowest point of the tubing depth D1 1 And calculate the number of large rope layers on the drum at this time as C1. 1 and the number of loops of the outermost large rope n1 t1 .

[0077] Let ΔCT = CT 1 -CT 0 .

[0078] When ΔCT≤0 and |ΔCT|<n1 t0 ×N or ΔCT > 0 and hour

[0079] Number of large rope layers on the drum C1 1 =C1 0 ;

[0080] Number of outermost large rope loops

[0081] Depth of the bottom of the tubing

[0082] When ΔCT < 0 and |ΔCT| > n1 t0 ×N times

[0083] Number of large rope layers on the drum C1 1 =C1 0 -1;

[0084] Number of outermost large rope loops

[0085] Depth of the bottom of the tubing

[0086] when hour

[0087] Number of large rope layers on the drum C1 1 =C1 0 +1;

[0088] Number of outermost large rope loops

[0089] Depth of the bottom of the tubing

[0090] If T 张 <T th Then the acquisition and control module only calculates the number of large rope layers C1 on the drum at this time. 1and the number of loops of the outermost large rope n1 t1 D1 1 It remains unchanged.

[0091] Data Acquisition and Control Module Records D1 1 And store it as a time-depth data file, and n1 t1 Assigned to n1 t0 C1 1 Assign to C1 0 D1 1 Assign to D1 0 CT scan 1 Assigned to CT 0 At the next Δt time, the acquisition control module repeats the above process until the logging is completed, and finally generates a time-tubing depth file.

[0092] In one embodiment, the depth-time recording device records the tension signal of the well workover machine's main rope according to a set recording time period, and the acquisition control module synchronously calculates the depth of the bottom of the downhole tubing. The recording time period is less than the lower limit of the detection period of any detector.

[0093] The acquisition and control module reads the time data and corresponding detection data from the downhole storage module according to the set reading cycle.

[0094] In the direct-push storage production logging system provided in this embodiment of the invention, each detector in the detector module can operate independently or in combination according to actual logging and analysis needs to achieve the corresponding technical effects.

[0095] The direct-push storage production logging system provided in the above embodiments of the present invention can reliably and steadily reach the target formation even under complex well conditions to obtain downhole production or injection status. This provides data support for oilfields to formulate oil and gas well strategies, helps improve oil and gas recovery rates, and will undoubtedly generate significant economic and social benefits. Furthermore, when the instrument encounters obstacles downhole, it can identify and correct interfering data hovering at the same depth, saving computational operations and further improving the processing efficiency of logging data.

[0096] Example 2

[0097] The systems described in detail in the above-disclosed embodiments of the present invention are based on other aspects of the systems described in any one or more of the above embodiments. The present invention also provides a direct-drive storage production logging method, which is applied to the use guidance of the direct-drive storage production logging system described in any one or more of the above embodiments. Specific embodiments are given below for detailed description.

[0098] Specifically, in one embodiment, the direct-push storage production logging method includes:

[0099] Before going down into the well, measure the component parameters of the winch roller of the oil well workover machine, including: roller length, winch roller diameter, number of main rope layers on the roller, main rope diameter, and number of main rope strands;

[0100] The length of the instrument string and the distance between each detector and the bottom of the instrument string are measured.

[0101] Experiments were conducted based on the component parameters of the well workover machine winch roller and the properties of the tension sensor to determine the effective tension threshold of the downhole detection module.

[0102] After the downhole storage module and the surface time-depth recording device are synchronized with the surface acquisition and control module, the instrument string to be run downhole is connected to the bottom of the tubing after the outer diameter size and connection thread type are changed through the transition short section.

[0103] After the descent into the well begins, the tension signal of the main rope of the work machine is recorded by the depth-time recording device according to the set recording time period;

[0104] The acquisition and control module calculates the depth of the bottom of the downhole tubing in real time based on the tension signal of the main rope of the work machine and the parameters of the winch components. The recording time period is less than the lower limit of the detection period of any detector. The downhole power supply module provides power to the downhole detection module for measurement under the control of the downhole storage module. The downhole storage module works and samples the measurement values ​​of the downhole detector at a certain frequency for storage.

[0105] After the instrument cluster returns to the surface, the acquisition and control module reads the time data and corresponding detection data from the downhole storage module according to the set reading cycle, forming a time-downhole data file.

[0106] Based on the time correspondence, the depth signals in the two files are matched one-to-one with the downhole data to form a tubing depth-downhole data file;

[0107] The depth data and detection data are initially corrected based on the data from the magnetic positioning detector to filter out interference data with repeated depth positions.

[0108] The depth offset is determined by comparing the logging data of the natural gamma detector with the natural gamma data of the open hole. The depth data is then corrected by combining the distance data between each detector and the bottom of its instrument string.

[0109] The acquisition and control module performs data resampling on the corrected depth data and exploration data to generate a logging data file that synchronizes depth and exploration data.

[0110] In one embodiment, the downhole detection module includes detectors for temperature, pressure, flow rate, fluid density, and oil, gas and water holdup. These detectors are connected to form a downhole detection instrument string for collecting downhole fluid data at different depths.

[0111] Furthermore, the downhole detection module also includes a magnetic positioning detector;

[0112] The magnetic positioning detector is used to record the changes in the positioning data of the downhole detection module in real time. Since it can capture the depth when the downhole detection module is not moving, after the downhole instrument returns to the surface, it identifies and clears duplicate depth data through magnetic positioning data, and clears the interfering detection data corresponding to the duplicate depth.

[0113] In practical applications, the downhole power supply module can be a downhole battery sub, and the downhole storage module can be a downhole storage sub. These are connected to a magnetic positioning detector, a natural gamma detector, and detectors for temperature, pressure, flow rate, fluid density, and oil / gas / water holdup to form a complete downhole instrument string. Before running it into the well, the specific combination of the downhole instrument string can be decided or adjusted by the operator based on the actual logging needs of the oil well. In one embodiment, the downhole battery sub, downhole storage sub, and detectors for magnetic positioning, natural gamma, temperature, pressure, flow rate, fluid density, and oil / gas / water holdup are connected sequentially to form the instrument string.

[0114] In practical applications, in one embodiment, after the downhole storage sub and the surface time-depth recording device are synchronized via the surface acquisition and control system, the downhole instrument string is connected to the bottom of the tubing after its outer diameter and thread type are changed through a transition sub. The workover rig pushes the downhole instrument directly to the target layer by continuously connecting tubing to form a tubing string of a certain length. The downhole storage sub controls the downhole battery sub to continuously supply power to the downhole detector at predetermined time intervals and sample the downhole detector's measurement values ​​at a certain frequency for storage, generating a time-downhole data file. The storage frequency is the same as or a multiple of the sampling frequency of the surface time-depth recording device.

[0115] Furthermore, in one embodiment, the downhole detection module also includes a natural gamma detector, which compares the natural gamma data collected by the detector with the natural gamma data of the open hole well to obtain the offset of the depth data during the current logging process, so as to achieve further depth correction by combining the distance data between each detector and the bottom of its instrument string.

[0116] In practical applications, after the instrument string returns to the surface, natural gamma and magnetic positioning data are used to complete the depth correction of the logging data. First, duplicate depth data are eliminated based on the magnetic positioning data. Then, the natural gamma data is compared with the natural gamma data of the open hole logging to determine the offset of the direct-push storage production logging depth, which is used to calculate the accurate logging depth data.

[0117] Specifically, after the downhole instrument returns to the surface, the surface acquisition and control module reads the time-downhole data file of the downhole storage segment and performs integrated processing with the time-depth file recorded on the surface. Based on the time correspondence, the depth signals in the two files are matched one-to-one with the downhole data to form the tubing depth-downhole data file.

[0118] Because no signal is generated when the instrument is stationary in magnetic positioning logging, the recorded magnetic positioning data shows relatively small fluctuations. In a specific embodiment, the movement of the tubing and instrument is determined based on the magnetic positioning data. When a continuous logging curve needs to be formed, the repeated depths recorded when the instrument is stationary and the corresponding detector data should be removed. Then, the natural gamma data is compared with the natural gamma data from open-hole logging to determine the offset (ΔD) of the direct-pull storage production logging depth.

[0119] Furthermore, if the total length of the instrument string is l, and the distance of a certain detector in the instrument string from the bottom of the instrument string is oft, then the formation depth corresponding to the data of that detector is D+ΔD+l-oft. After depth correction, a formation depth-downhole data file for each downhole detector is formed. The maximum formation depth in the file is selected as the same starting depth. The same depth sampling interval is used to resample the formation depth-downhole data file of each downhole detector before outputting the logging file data.

[0120] Specifically, the depth-time recording device includes a tension acquisition and conversion module;

[0121] The tension acquisition and conversion module includes a tension sensor installed on the dead rope of the winch of the oil well workover machine, used to acquire the tension electrical signal data of the winch main rope;

[0122] The tension acquisition and conversion module also includes a current-to-voltage conversion circuit and an analog-to-digital conversion circuit connected in sequence. The current-to-voltage conversion circuit converts the current signal data acquired by the tension sensor into voltage signal data, and the analog-to-digital conversion circuit converts it into a digital signal of tension data.

[0123] In one embodiment, the depth time recording device uses a pressure-side tension sensor to collect the tension of the main rope of the oil well workover rig, so that the acquisition control module can further control the processing and recording of depth data by judging the magnitude of the main rope tension.

[0124] Furthermore, the depth time recording device also includes a pulse counting module;

[0125] The pulse counting module includes a depth encoder, a winch interface circuit, and a pulse counting circuit.

[0126] The depth encoder installed on the winch drum of the oil well workover machine outputs a rotation encoding signal. After being processed by the winch interface circuit to meet the level requirements of the pulse counting circuit, the signal is transmitted to the pulse counting circuit.

[0127] The acquisition and control module determines whether the depth of the downhole detection module has changed based on the signal pulse data from the pulse counting circuit and the tension data from the tension acquisition and conversion module. It also calculates the depth of the bottom of the downhole tubing by combining the drum length of the oil well workover machine, the diameter of the winch roller, the number of layers of the main rope on the drum, the diameter of the main rope, and the number of strands of the main rope, and records the depth of the bottom of the downhole tubing in real time.

[0128] In a practical application, one embodiment employs a depth-time recording device consisting of a pressure-side tension sensor, a depth encoder, a winch interface circuit, an I / V current-to-voltage converter, an A / D analog-to-digital converter, and a pulse counting circuit. The pressure-side tension sensor is mounted on the dead rope of the oil well workover rig, and the depth encoder is mounted on the winch drum shaft. The output encoded signal is preprocessed by the winch interface circuit to meet the level requirements of the counter, and then sent to the pulse counting circuit. The pulse counting circuit determines the movement direction of the instrument based on the phase difference between the A and B phase signals of the encoded signal and performs addition and subtraction counting. The current signal output by the pressure-side tension sensor is converted into a voltage signal via I / V conversion and sent to the A / D analog-to-digital converter to form a digital signal T. 张 The acquisition and control module acquires the output data CT from the pulse counter and the data T output from the A / D analog-to-digital converter circuit at a certain sampling time interval Δt. 张 .

[0129] Before logging begins, the acquisition control module can be pre-set with a large rope tension threshold value T. th By combining the results of the large rope tension signal and the threshold value, the depth data of the bottom of the downhole tubing under different conditions is calculated.

[0130] Assume that at the initial time t0, the depth of the bottom of the tubing is D1. 0 The number of layers of the large rope on the drum is C1. 0 The outermost large rope has n1 loops. t0 Pulse counter data for CT 0 Then at time t1 = t0 + Δt, if T 张 >T th Based on the number of signal pulses N output by the depth encoder per revolution, the drum length L, the winch roller diameter d1, the main rope diameter d2, and the number of main rope strands n2, the acquisition and control module will convert the pulse counter data CT. 1 Converted to the lowest point of the tubing (D1) 1 ), and calculate the number of large rope layers on the drum at this time as C1. 1 and the number of loops of the outermost large rope n1 t1 .

[0131] Let ΔCT = CT 1 -CT 0 .

[0132] When ΔCT≤0 and |ΔCT|<n1 t0 ×N or ΔCT > 0 and hour

[0133] Number of large rope layers on the drum C1 1 =C1 0 ;

[0134] Number of outermost large rope loops

[0135] Depth of the bottom of the tubing

[0136] When ΔCT < 0 and |ΔCT| > n1 t0 ×N times

[0137] Number of large rope layers on the drum C1 1 =C1 0 -1;

[0138] Number of outermost large rope loops

[0139] Depth of the bottom of the tubing

[0140] when hour

[0141] Number of large rope layers on the drum C1 1 =C1 0 +1;

[0142] Number of outermost large rope loops

[0143] Depth of the bottom of the tubing

[0144] If T 张 <T th Then the acquisition and control module only calculates the number of large rope layers C1 on the drum at this time. 1 and the number of loops of the outermost large rope n1 t1 D1 1 It remains unchanged.

[0145] Data Acquisition and Control Module Records D1 1 And store time-depth data, and n1 t1 Assigned to n1 t0 C1 1 Assign to C1 0D1 1 Assign to D1 0 CT scan 1 Assigned to CT 0 At the next Δt time, the acquisition control module repeats the above process until the logging is completed, and finally generates a time-tubing depth file.

[0146] In one embodiment, the depth-time recording device records the tension signal of the well workover machine's main rope according to a set recording time period, and the acquisition control module synchronously calculates the depth position of the bottom of the tubing. The recording time period is less than the lower limit of the detection period of any detector.

[0147] The acquisition and control module reads the time data and corresponding detection data from the downhole storage module according to the set reading cycle.

[0148] For the foregoing method embodiments, in order to simplify the description, they are all described as a series of actions. However, those skilled in the art should understand that the present invention is not limited to the described order of actions, because according to the present invention, some steps can be performed in other orders or simultaneously. Furthermore, those skilled in the art should also understand that the embodiments described in the specification are preferred embodiments, and the actions and modules involved are not necessarily essential to the present invention.

[0149] It should be noted that, in other embodiments of the present invention, the method can also be combined with one or more of the above embodiments to obtain a new direct-push storage production logging method, so as to achieve reliable detection of oil, gas and water production or injection volume related parameters of various formations downhole.

[0150] It should be noted that, based on the methods in any one or more embodiments of the present invention described above, the present invention also provides a storage medium storing program code that can implement the methods described in any one or more embodiments, and when the code is executed by the operating system, it can implement the direct-push storage-type production logging method as described above.

[0151] It should be understood that the embodiments disclosed herein are not limited to the specific structures, processing steps, or materials disclosed herein, but should be extended to equivalent substitutions of these features as understood by those skilled in the art. It should also be understood that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting.

[0152] The phrase "an embodiment" in the specification means that a specific feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the invention. Therefore, the phrase "an embodiment" appearing in various places throughout the specification does not necessarily refer to the same embodiment.

[0153] While the embodiments disclosed in this invention are as described above, the content is merely for the purpose of facilitating understanding of the invention and is not intended to limit the invention. Any person skilled in the art to which this invention pertains may make any modifications and variations in form and detail of the implementation without departing from the spirit and scope disclosed herein; however, the scope of patent protection for this invention shall still be determined by the scope defined in the appended claims.

Claims

1. A direct-push storage production logging system, characterized in that, The system includes: A depth time recording device, which is associated with an oil well workover rig, is configured to acquire real-time logging depth signals based on sensors and winch component parameters of the oil well workover rig; The downhole detection module is pushed to the target layer by continuously connecting the tubing to the well workover rig to form a tubing string of a certain length, so as to obtain downhole detection data and depth correction data. The downhole storage module is configured to store the data acquired by the downhole detection module in real time according to a set period. The acquisition and control module is communicatively connected to the depth time recording device and the downhole storage module, and is used to realize depth calculation and correction, as well as to perform synchronous processing of detection data and depth data; The downhole power supply module uses batteries to provide power to the downhole detection module and storage module. The acquisition and control module uses the signal pulse data from the pulse counting circuit in the depth time recording device, combined with the tension data from the tension acquisition and conversion module, to determine whether the depth of the downhole detection module has changed. It also uses the drum length of the oil well workover machine, the diameter of the winch roller, the number of layers of the main rope on the drum, the diameter of the main rope, and the number of strands of the main rope to calculate the depth of the bottom of the tubing. The acquisition and control module is pre-set with a large rope tension threshold value T. th By combining the results of the large rope tension signal and the threshold value, the depth data of the bottom of the downhole tubing under different conditions is calculated. Assume the depth of the bottom of the tubing at the initial time t0 is D1. 0 The number of layers of the large rope on the drum is C1. 0 The outermost large rope has n1 loops. t0 Pulse counter data for CT 0 Then at time t1 = t0 + Δt, if T 张 >T th Based on the number of signal pulses N output by the depth encoder per revolution, the drum length L, the winch roller diameter d1, the main rope diameter d2, and the number of main rope strands n2, the acquisition and control module will convert the pulse counter data CT. 1 Converted to the lowest point of the tubing depth D1 1 And calculate the number of large rope layers on the drum at this time as C1. 1 and the number of loops of the outermost large rope n1 t1 ; Let ΔCT = CT 1 - CT 0 ; When ΔCT≤0 and |ΔCT| <n1 t0 ×N or ΔCT>0 and or hour, Number of large rope layers on the drum C1 1 =C1 0 The number of loops in the outermost layer of rope ; Depth of the bottom of the tubing ; When ΔCT < 0 and |ΔCT| > n1 t0 When ×N; the number of large rope layers on the drum, C1 1 =C1 0 -1; Number of outermost large rope loops ; Depth of the bottom of the tubing: when At that time; the number of layers of large rope on the drum C1 1 =C1 0 +1; Number of outermost large rope loops ; Depth of the bottom of the tubing: If T 张 <T th Then the acquisition and control module only calculates the number of large rope layers C1 on the drum at this time. 1 and the number of loops of the outermost large rope n1 t1 D1 1 Remain unchanged; The acquisition and control module records D1 1 And store it as a time-depth data file, and n1 t1 Assigned to n1 t0 C1 1 Assign to C1 0 D1 1 Assign to D1 0 CT scan 1 Assigned to CT 0 After the next Δt time, the acquisition and control module repeats the above process until the logging is completed, and finally generates a time-tubing depth file. The downhole detection module also includes a natural gamma detector, which is used to compare the natural gamma data collected by the well logging with the natural gamma data of the open hole well to obtain the offset of the depth data during the current logging process, so as to achieve further depth correction by combining the distance data between each detector and the bottom of its instrument string.

2. The system as described in claim 1, characterized in that, The depth time recording device includes a tension acquisition and conversion module; The tension acquisition and conversion module includes a tension sensor installed on the dead rope of the oil well machine winch, used to acquire the tension electrical signal data of the dead rope; The tension acquisition and conversion module also includes a current-to-voltage conversion circuit and an analog-to-digital conversion circuit connected in sequence. The current-to-voltage conversion circuit converts the current signal data acquired by the tension sensor into voltage signal data, and the analog-to-digital conversion circuit converts it into a digital signal of tension data.

3. The system as described in claim 1, characterized in that, The depth time recording device also includes a pulse counting module; The pulse counting module includes a depth encoder, a winch interface circuit, and a pulse counting circuit. The depth encoder installed on the winch drum of the oil well workover machine outputs a rotation encoding signal. After being processed by the winch interface circuit to meet the level requirements of the pulse counting circuit, the signal is transmitted to the pulse counting circuit.

4. The system as described in claim 1, characterized in that, The downhole detection module includes temperature, pressure, flow rate, fluid density, and oil, gas and water holdup detectors. Various detectors are connected to form a downhole detection instrument string, which is used to collect real-time downhole detection data at the corresponding depth. After the downhole storage module and the surface time-depth recording device are synchronized by the acquisition and control module, the downhole detection instrument to be run into the well is connected to the bottom end of the tubing after the outer diameter size and connection thread type are changed through the transition short section.

5. The system as described in claim 1, characterized in that, The downhole detection module also includes a magnetic positioning detector; The magnetic positioning detector is used to record the changes in the positioning data of the downhole detection module in real time. Since it can capture the depth when the downhole detection module is not moving, after the downhole instrument returns to the surface, it identifies and clears duplicate depth data through magnetic positioning data, and clears the interfering detection data corresponding to the duplicate depth.

6. The system as described in claim 1, characterized in that, The depth-time recording device records the tension signal of the well workover machine's main rope according to the set recording time period. The acquisition and control module synchronously calculates and records the depth position of the bottom of the tubing. The recording time period is less than the lower limit of the detection period of any detector. The acquisition and control module reads the time data and corresponding detection data from the downhole storage module according to the set reading cycle.

7. The system as described in claim 1, characterized in that, Before being lowered into the well, the downhole power supply module is configured by the acquisition and control module to supply power to the downhole detection module and storage module only during a specified time period.

8. A direct-push storage production logging method, characterized in that, The method is applied to the system according to any one of claims 1 to 7, and the method includes: Before going down into the well, measure the component parameters of the well workover machine winch, including: drum length, winch roller diameter, number of main rope layers on the drum, main rope diameter, and number of main rope strands; Measure the length of the instrument string and the distance between each detector and the bottom of the instrument string; Experiments were conducted based on the component parameters of the well workover machine winch and the properties of the tension sensor to determine the effective tension threshold of the downhole detection module. After the well begins to run, the tension signal of the work machine's main rope is recorded by the depth-time recording device at a set recording time period; the depth position of the bottom of the tubing is calculated synchronously based on the tension signal of the work machine's main rope, and the recording time period is less than the lower limit of the detection period of any detector. After logging is completed and the system returns to the surface, the acquisition and control module reads the time data and corresponding detection data from the downhole storage module according to the set reading cycle. The depth data and detection data are initially corrected based on the data from the magnetic positioning detector to filter out interference data with repeated depth positions. The depth offset is determined by comparing the logging data of the natural gamma detector with the natural gamma data of the open hole. The depth data is then corrected by combining the distance data between each detector and the bottom of its instrument string. The acquisition and control module processes the corrected depth data and probe data to generate logging data that is synchronized with the depth and probe data.

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