A device and method for testing mineral components and content in uranium-containing reservoirs

Abstract

The present invention relates to the field of wireline logging technology, specifically disclosing a device and method for testing the mineral composition and content of uranium-bearing reservoirs. The device comprises a wireline logging system, a logging depth calibration system, and a time synchronization system. The logging tool assembly comprises a spectral logging tool, a natural gamma ray spectroscopy logging tool, an epithermal neutron logging tool, and a neutron capture gamma ray spectroscopy logging tool. The method comprises: combining the logging tool assembly with the wireline logging system, configuring a logging depth calibration system, configuring a time synchronization system, performing PTP time synchronization on the wireline logging system and the logging depth calibration system, collecting raw logging time and raw logging data, performing time resampling and depth correction on the raw logging data, and demarcating the formation structure based on the logging depth and time resampled logging data. The present invention enables the acquisition and data fusion of the mineral composition, radioactive element content, and porosity characteristics of the formation surrounding the wellbore, thereby improving exploration precision, efficiency, and evaluation accuracy.

Description

Technical Field

[0001] The present application relates to the technical field of cable logging, and in particular to a device and method for testing the mineral composition and content of uranium-containing reservoirs. Background Art

[0002] In uranium resource exploration and development, well logging technology is a crucial means of obtaining information on the mineral composition of uranium-bearing reservoirs. The resulting data can be directly applied to resource exploration, program design, actual production, and environmental assessments. Using well logging technology to obtain and comprehensively consider geophysical properties such as elemental and mineral composition, radionuclides, and pore structure in formations is crucial for uranium reserve prediction and mineability assessment.

[0003] Currently, mainstream logging technologies are primarily focused on elemental logging, including natural gamma ray spectrum logging, neutron capture gamma logging, and thermal / epitothermal neutron logging. Publication number CN112523742B describes a method for determining the content of natural gamma-ray radioactive elements based on characteristic spectral bands of energy spectrum logging. This method quantitatively analyzes the content of radionuclides such as uranium, thorium, and potassium in formations by detecting the total amount of gamma rays or the energy spectrum count rate. Publication number US08311744B2 describes a method for obtaining elemental chemistry downhole using chemically and geologically consistent constraints. This method obtains formation element concentrations and estimates lithology by comprehensively acquiring and analyzing natural gamma ray and neutron gamma ray spectra.

[0004] However, this type of elemental logging technology relies on the elements' own radioactivity and their slowing and capturing properties of neutrons, and cannot fully reflect geophysical properties such as reservoir mineral composition and porosity, resulting in inefficient and inaccurate reservoir and uranium resource evaluation. Spectroscopy, gamma spectroscopy, and neutron logging offer unique advantages in identifying formation minerals, radionuclides, and porosity. Therefore, it is necessary to develop a device and method for testing the mineral composition and content of uranium-bearing reservoirs, which can comprehensively obtain information on reservoir elemental chemistry and pore structure, thereby improving the accuracy of logging data acquisition and stratigraphic delineation capabilities. Summary of the Invention

[0005] In order to comprehensively obtain reservoir element chemistry and pore structure information and improve the accuracy of logging data acquisition and stratigraphic division capabilities, the present application provides a mineral composition and content testing device and method suitable for uranium-containing reservoirs.

[0006] The present application provides a method for testing the mineral composition and content of uranium-containing reservoirs using the following technical solutions:

[0007] A method for testing the mineral composition and content of uranium-containing reservoirs, comprising the following steps:

[0008] A combined logging tool assembly and a wireline logging system, wherein the logging tool assembly includes a spectral logging tool, a natural gamma ray spectrum logging tool, an epithermal neutron logging tool, and a neutron capture gamma ray spectrum logging tool, each logging tool having a different sampling frequency, and the logging tool assembly is connected to a surface processing system via a logging cable;

[0009] Configure a logging depth calibration system, including marking depth markers at equal intervals on the logging cable, and configure a depth recorder and velocity sensor;

[0010] Configure the time synchronization system, including configuring a master clock, intermediate logging tool clocks, and sensor intermediate clocks that support the Precision Time Protocol, and configuring slave clocks for each logging tool, depth logger, and velocity sensor;

[0011] Perform PTP time synchronization on the cable logging system and the logging depth calibration system, calculate the primary and secondary time delays, and perform time correction on the local clock;

[0012] Collect original logging time and original logging data, and synchronously record marked depth and vertical velocity;

[0013] Perform time resampling and depth correction on the original logging data to generate time resampled logging data and logging depth;

[0014] The stratigraphic structure is divided according to the logging depth and time of resampling logging data.

[0015] Furthermore, the configuration of the well logging depth calibration system includes:

[0016] Mark equidistant depth markers based on the zero depth position corresponding to the logging cable joint;

[0017] The marked depth MD is recorded by a depth recorder, and the vertical velocity v of the logging tool assembly is measured by a velocity sensor.

[0018] Furthermore, the method for calculating the first-level time delay includes: sending a first-level hardware timestamp to the logging tool intermediate clock and the sensor intermediate clock through the master clock, and calculating the first-level time delay T1D1 of the logging tool intermediate clock and the first-level time delay T1D2 of the sensor intermediate clock respectively.

[0019] Furthermore, the calculation method of the secondary time delay includes:

[0020] Send secondary hardware timestamps to slave clocks of spectral logging tools, natural gamma ray spectroscopy logging tools, epithermal neutron logging tools, and neutron capture gamma ray spectroscopy logging tools through the logging tool intermediate clock, and calculate the corresponding secondary time delays T2D1, T2D2, T2D3, and T2D4 respectively;

[0021] The secondary hardware timestamp is sent to the slave clocks of the depth recorder and the speed sensor via the sensor intermediate clock, and the corresponding secondary time delays T2D5 and T2D6 are calculated respectively.

[0022] Furthermore, the method for correcting the time of the local clock includes:

[0023] Perform time correction on the local clock of each logging tool based on the secondary hardware timestamp, the primary time delay T1D1 of the logging tool's intermediate clock, and the secondary time delays T2D1, T2D2, T2D3, and T2D4 of each logging tool;

[0024] The local clocks of the depth recorder and speed sensor are time-corrected based on the secondary hardware timestamp, the primary time delay T1D2 of the sensor intermediate clock, and the secondary time delays T2D5 and T2D6 of the depth recorder and speed sensor.

[0025] Furthermore, the steps of collecting original logging time and original logging data include:

[0026] Mark the starting depth marker and ending depth marker on the logging cable according to the logging depth range and depth marker;

[0027] Align the logging tool assembly with the center of the borehole and adjust the height until the starting depth marker is flush with the ground surface. Record the marked depth MD = 0, vertical velocity v = 0, and reference depth BD = 0 corresponding to the initial time T = 0.

[0028] Starting from time T=0, the logging tool assembly is lowered at a nearly uniform speed. The spectral logging tool, natural gamma ray spectroscopy logging tool, epithermal neutron logging tool, and neutron capture gamma ray spectroscopy logging tool are controlled by the local clock to automatically collect the original logging times T1, T2, T3, and T4 and the corresponding logging data, and transmit them to the surface processing system via the logging cable.

[0029] At the standard time T=t n Recording mark depth MD n and vertical velocity v n , where: t n Generated by accumulating the standard time interval Δt, where Δt is the maximum sampling frequency f in each logging tool max The reciprocal of T1, T2, T3, and T4 are generated by the independent sampling frequencies f1, f2, f3, and f4 of each logging tool respectively;

[0030] When the end depth marker is flush with the ground surface, stop logging and organize the test data.

[0031] Furthermore, the method for time resampling and depth correction of the original logging data includes:

[0032] According to the vertical velocity v recorded by the velocity sensor n and time interval Δt, and calculate the standard time T=t by accumulating n Corresponding reference depth BD n ;

[0033] The original logging time T1, T2, T3, T4 of each logging tool is interpolated with the standard time t n Alignment, generating time-resampled logging data;

[0034] Reference depth BD n Perform depth correction to generate the logging depth D of each logging tool 1n 、D 2n 、D 3n 、D 4n .

[0035] Furthermore, the method of dividing the stratigraphic structure by resampling the logging data according to the logging depth and time includes:

[0036] According to the logging depth D 1n 、D 2n 、D 3n 、D 4n and time-resampled logging data to draw mineral component distribution maps, radionuclide distribution maps, and porosity characteristic distribution maps;

[0037] The stratigraphic structure is divided according to the mineral component distribution map, radionuclide distribution map, and porosity characteristic distribution map.

[0038] The present application also provides a device for testing the mineral composition and content of uranium-containing reservoirs, which is used to implement a method for testing the mineral composition and content of uranium-containing reservoirs. The device includes:

[0039] A wireline logging system, comprising a logging tool assembly, a logging cable, and a surface processing system. The logging tool assembly comprises a spectral logging tool, a natural gamma ray spectrum logging tool, an epithermal neutron logging tool, a neutron generator, and a neutron capture gamma ray spectrum logging tool.

[0040] Well logging depth calibration system, including depth markers on logging cables, depth recorders and velocity sensors;

[0041] A time synchronization system includes a PTP domain. The PTP domain configures a master clock to connect to a slave clock via an intermediate clock. The slave clock is associated with a local clock. The master clock and the local clock are ordinary clocks, and the intermediate clock and the slave clock are boundary clocks.

[0042] Furthermore, the sampling frequencies of the spectrum logging tool, the natural gamma ray spectrum logging tool, the epithermal neutron logging tool, and the neutron capture gamma ray spectrum logging tool are different.

[0043] In summary, this application has the following beneficial technical effects: It integrates spectral, natural gamma, epithermal neutron, and neutron capture gamma spectroscopy logging technologies to detect comprehensive information such as uranium abundance, non-radioactive mineral content, and formation porosity in uranium strata. Through multi-dimensional data complementation, it improves the accuracy of uranium reservoir identification. The use of time synchronization and depth correction technologies significantly reduces the time delay and depth measurement errors caused by deep logging cables. In particular, a two-level, dual-path time synchronization system improves network load distribution and error transmission between low-frequency logging tools and high-frequency sensors.

[0044] By time resampling and depth-correcting raw data from different acquisition frequencies, combined with two-level hardware time delay correction, data fusion accuracy is significantly improved and time errors are reduced. Combining depth markers, velocity sensors, and probe correction distances, a real-time mapping model between reference depth and logging depth is proposed, overcoming depth deviations caused by cable expansion and tool string length differences. While traditional methods rely on static correction, this application achieves dynamic depth calibration through dynamic interpolation and velocity integration, thereby improving the positioning accuracy of the reservoir interface. BRIEF DESCRIPTION OF THE DRAWINGS

[0045] Figure 1 Schematic diagram of the structure of the cable logging system in the embodiment of the present application;

[0046] Figure 2 is a schematic structural diagram of a well logging tool assembly in an embodiment of the present application;

[0047] Figure 3 is a schematic diagram of a time synchronization system in an embodiment of the present application;

[0048] Figure 4 This is a flow chart of a method for testing the mineral composition and content of uranium-containing reservoirs according to an embodiment of the present application.

[0049] Figure 1: 1. Logging tool assembly; 2. Logging cable connector; 3. Ground support; 4. Logging cable; 5. Cable winch; 6. Ground processing system; 7. Spectral logging tool; 701. Light source; 702. Spectral probe; 703. Spectrometer; 704. Photodetector; 8. Natural gamma ray spectrum logging tool; 801. Natural gamma ray spectrum probe; 802. Natural gamma ray scintillation crystal; 803. Natural gamma photomultiplier tube; 804. Natural gamma ray signal processing module; 9. epithermal neutron logging tool; 901. epithermal neutron probe; 902. epithermal neutron detector; 10. neutron generator; 11. neutron capture gamma spectroscopy logging tool; 1101. neutron capture gamma spectroscopy probe; 1102. neutron capture gamma scintillator crystal; 113. neutron capture gamma photomultiplier tube; 1104. neutron capture gamma signal processing module; 12. depth recorder; 13. velocity sensor; 14. zero depth position. DETAILED DESCRIPTION

[0050] The following is combined with Figure 1-4 This application is described in further detail.

[0051] The present invention discloses a device for testing the mineral composition and content of uranium-containing reservoirs. The device comprises a wireline logging system, a logging depth calibration system, and a time synchronization system.

[0052] Reference Figure 1 The cable logging system includes a logging tool assembly 1, a logging cable connector 2, a logging cable 4, a ground support 3, a cable winch 5, and a ground processing system 6. The logging cable connector 2 is used to fixedly connect the logging tool assembly 1 and the logging cable 4. The logging cable 4 is connected to the logging tool assembly 1 and the ground processing system 6, respectively, and is used to carry the logging tool assembly 1 and transmit the control signals and logging data of the logging tool assembly 1. The ground support 3 is used to adjust the direction and posture of the logging tool assembly 1. The cable winch 5 is used to retract and extend the logging cable 4 and control the lowering and lifting of the logging tool assembly 1. The ground processing system 6 is used to control the data acquisition and data processing of the logging tool assembly 1.

[0053] Reference Figure 2 The logging tool assembly 1 includes, arranged from bottom to top, a spectroscopic logging tool 7, a natural gamma ray spectroscopy logging tool 8, an epithermal neutron logging tool 9, a neutron generator 10, and a neutron capture gamma ray spectroscopy logging tool 11. Furthermore, the sampling frequencies of the spectroscopic logging tool 7, the natural gamma ray spectroscopy logging tool 8, the epithermal neutron logging tool 9, and the neutron capture gamma ray spectroscopy logging tool 11 are different: f1, f2, f3, and f4, respectively.

[0054] Reference Figure 2The spectral logging tool 7 includes a light source 701, a spectral probe 702, a spectrometer 703, and a photodetector 704. The light source 701 is capable of emitting visible and invisible broadband electromagnetic radiation into the formation surrounding the wellbore. The electromagnetic radiation range is greater than or equal to the detection range of the photodetector 704. The spectral probe 702 is connected to the spectrometer 703 and is configured to receive the broadband electromagnetic radiation emitted by the light source 701 and reflected by the formation surrounding the wellbore, and transmit the broadband electromagnetic radiation to the spectrometer 703. The spectrometer 703 is connected to the photodetector 704 and is configured to split the broadband electromagnetic radiation into a plurality of narrowband electromagnetic radiations, which are then transmitted to the photodetector 704. The photodetector 704 is connected to the surface processing system 6 via the logging cable 4 and is configured to receive the narrowband electromagnetic radiation and process the optical signal into an electrical signal.

[0055] Reference Figure 2 The natural gamma ray spectrum logging tool 8 includes a natural gamma ray spectrum probe 801, a natural gamma scintillation crystal 802, a natural gamma photomultiplier tube 803, and a natural gamma ray signal processing module 804. The natural gamma ray spectrum probe 801 is connected to the natural gamma scintillation crystal 802 and is configured to receive natural gamma rays emitted by the formation surrounding the wellbore and transmit the natural gamma rays to the natural gamma scintillation crystal 802. The natural gamma scintillation crystal 802 is connected to the natural gamma photomultiplier tube 803 and is configured to convert the natural gamma rays into optical pulse signals and transmit the optical pulse signals to the natural gamma ray spectrum logging tool 803. The natural gamma ray spectrum logging tool 803 is connected to the natural gamma ray signal processing module 804 and is configured to convert the optical pulse signals into amplified negative voltage pulse signals and transmit the amplified negative voltage pulse signals to the natural gamma ray spectrum logging tool 804. The natural gamma ray spectrum logging tool 804 is connected to the surface processing system 6 via the logging cable 4 and is configured to perform amplitude discrimination, frequency division, shaping, power amplification, and other processing on the amplified negative voltage signal pulses.

[0056] Reference Figure 2 The neutron generator 10 is used to generate and emit fast neutrons into the formation around the well. The fast neutrons are slowed down and captured by the formation elements to produce epithermal neutrons and captured gamma rays respectively.

[0057] Reference Figure 2 Epithermal neutron logging tool 9 includes an epithermal neutron probe 901 and an epithermal neutron detector 902. Epithermal neutron probe 901 is connected to epithermal neutron detector 902 to acquire epithermal neutrons in the formation and transmit them to epithermal neutron detector 902. Epithermal neutron detector 902 is connected to a surface processing system 6 via a logging cable 4 to detect the epithermal neutron content in the formation surrounding the wellbore.

[0058] Reference Figure 2The neutron capture gamma spectroscopy logging tool 11 includes a neutron capture gamma spectroscopy probe 1101, a neutron capture gamma scintillation crystal 1102, a neutron capture gamma photomultiplier tube 113, and a neutron capture gamma signal processing module 1104. The neutron capture gamma spectroscopy probe 1101 is connected to the neutron capture gamma scintillation crystal 1102 and is configured to acquire neutron capture gamma rays from the formation surrounding the wellbore and transmit the neutron capture gamma rays to the neutron capture gamma scintillation crystal 1102. The neutron capture gamma scintillation crystal 1102 is connected to the neutron capture gamma photomultiplier tube 113 and is configured to convert the neutron capture gamma rays into optical pulse signals and transmit the optical pulse signals to the neutron capture gamma photomultiplier tube 113. The neutron capture gamma photomultiplier tube 113 is connected to the neutron capture gamma signal processing module 1104 and is configured to convert the optical pulse signal into an amplified negative voltage pulse signal and transmit the amplified negative voltage pulse signal to the neutron capture gamma signal processing module 1104. The neutron capture gamma signal processing module 1104 is connected to the surface processing system 6 via the logging cable 4 and is configured to perform amplitude identification, frequency division, shaping, power amplification, and other processing on the amplified negative voltage signal pulse.

[0059] Reference Figure 2 The logging depth calibration system includes a depth marker, a depth recorder 12, and a velocity sensor 13. The depth marker is positioned at the zero depth position 14 at the logging cable connector 2, and the corresponding depth marker is 0.00 m. Starting from the zero depth position 14, depth markers are marked on the logging cable 4 at equal intervals. The depth recorder 12 is mounted on the cable winch 5 and is used to read the most recent depth marker that passed through the depth recorder 12 during the process of retracting and extending the logging cable 4, and to record the corresponding marked depth. The velocity sensor 13 is mounted on the logging tool assembly 1 and is used to measure the vertical velocity of the logging tool assembly 1.

[0060] Reference Figure 3 The time synchronization system includes a PTP domain. A PTP domain (Precision Time Protocol domain) refers to a group of devices that share the same time source in a network that uses the PTP protocol. The PTP domain includes the master clock, the logging tool intermediate clock, the sensor intermediate clock, slave clock 1, slave clock 2, slave clock 3, slave clock 4, slave clock 5, slave clock 6, local clock 1, local clock 2, local clock 3, local clock 4, local clock 5, and local clock 6.

[0061] Furthermore, the master clock is connected to slave clocks 1, 2, 3, and 4 through the logging tool intermediate clock, and to slave clocks 5 and 6 through the sensor intermediate clock. Slave clocks 1, 2, 3, 4, 5, and 6 are connected to local clocks 1, 2, 3, 4, 5, and 6, respectively.

[0062] The clock type of the master clock and local clock is ordinary clock, and the clock type of the logging tool intermediate clock, sensor intermediate clock and slave clock is boundary clock.

[0063] The above-mentioned mineral composition and content testing device applicable to uranium-containing reservoirs is used to implement a mineral composition and content testing method applicable to uranium-containing reservoirs, referring to Figure 4 , the method comprises the following steps:

[0064] Step S1: Assembling the logging tool assembly and the wireline logging system, specifically including:

[0065] Step S101: assembling logging tool assemblies in the order of logging, wherein the logging tool assemblies are, from bottom to top, a spectrum logging tool, a natural gamma ray spectrum logging tool, an epithermal neutron logging tool, and a neutron capture gamma ray spectrum logging tool;

[0066] Step S102: Assembling the logging tool assembly, the logging cable connector, the logging cable, the ground support, the cable winch, and the ground processing system, and performing system debugging;

[0067] Step S103: Determine the vertical distances between the logging cable connector and the spectrum probe, natural gamma ray spectrum probe, epithermal neutron probe, and neutron capture gamma ray spectrum probe, which are recorded as spectrum correction distance L1, natural gamma ray spectrum correction distance L2, epithermal neutron correction distance L3, and neutron capture gamma ray spectrum correction distance L4, respectively.

[0068] Step S2: Configure the logging depth calibration system, including marking depth markers at equal intervals on the logging cable, and configuring a depth recorder and velocity sensor. Specifically:

[0069] Step S201: Mark the zero depth position corresponding to the logging cable joint with a depth marker of 0.00 m, and mark depth markers on the logging cable at equal intervals along the length of the logging cable starting from the zero depth position;

[0070] Step S202: a depth recorder is configured on the cable winch, and during the process of retracting and extending the logging cable, the depth marker of the most recent depth recorder is read and the corresponding marked depth MD is recorded;

[0071] Step S203: A velocity sensor is configured on the logging tool assembly to measure the vertical velocity v of the logging tool assembly.

[0072] Step S3: Configure the time synchronization system, including configuring the master clock and the logging tool intermediate clock and sensor intermediate clock that support the precision time protocol, and configuring slave clocks for each logging tool, depth recorder, and velocity sensor. Specifically:

[0073] Step S301: Select an optimal clock source for the PTP domain from among high-precision clock sources such as atomic clocks, GPS clocks, and crystal oscillators, either manually or automatically using the Best Master Clock (BMC) algorithm. This optimal clock source is used as the master clock for the time synchronization network.

[0074] Step S302: Configure the logging tool intermediate clock and sensor intermediate clock that support PTP in the surface processing system. The logging tool intermediate clock and sensor intermediate clock receive the time reference sent by the master clock via wired or wireless transmission.

[0075] Step S303: Configure slave clocks 1, 2, 3, 4, 5, and 6 that support PTP in the spectral logging tool, natural gamma ray spectroscopy logging tool, epithermal neutron logging tool, neutron capture gamma ray spectroscopy logging tool, depth recorder, and velocity sensor, respectively. Also configure local clocks 1, 2, 3, 4, 5, and 6. Slave clocks 1, 2, 3, and 4 receive time references from the logging tool intermediate clock via wired or wireless transmission. Slave clocks 5 and 6 receive time references from the sensor intermediate clock via wired or wireless transmission.

[0076] Step S4: Perform PTP time synchronization on the wireline logging system and the logging depth calibration system, calculate the primary time delay and the secondary time delay, and perform time correction on the local clock. The specific method includes:

[0077] Step S401: Start the wireline logging system, the logging depth calibration system, and the time synchronization system, and enter a stable working state;

[0078] Step S402: Using a single-step synchronization or two-step synchronization mode, the master clock is controlled to send a first-level hardware timestamp to the logging tool intermediate clock and the sensor intermediate clock, and a first-level time delay is calculated; the first-level time delays corresponding to the logging tool intermediate clock and the sensor intermediate clock are T1D1 and T1D2 respectively;

[0079] Step S403: Using a single-step synchronization or two-step synchronization mode, the logging tool intermediate clock is controlled to send a secondary hardware timestamp to slave clocks 1, 2, 3, and 4, and a secondary time delay is calculated. The secondary time delays corresponding to slave clocks 1, 2, 3, and 4 are T2D1, T2D2, T2D3, and T2D4, respectively.

[0080] Step S404: Using single-step or two-step synchronization mode, control the sensor intermediate clock to send secondary hardware timestamps to slave clocks 5 and 6, and calculate the secondary time delay. The secondary time delays corresponding to slave clocks 5 and 6 are T2D5 and T2D6 respectively.

[0081] Step S405: Based on the secondary hardware timestamp and the calculated primary time delay and secondary time delay, the local clock is corrected. Specifically:

[0082] The local clocks of spectral logging tools, natural gamma ray spectroscopy logging tools, epithermal neutron logging tools, and neutron capture gamma ray spectroscopy logging tools are corrected to:

[0083] Local clock 1 = slave clock 1 - T1D1 - T2D1

[0084] Local clock 2 = slave clock 2 - T1D1 - T2D2

[0085] Local clock 3 = slave clock 3 - T1D1 - T2D3

[0086] Local clock 4 = slave clock 4 - T1D1 - T2D4

[0087] The local clocks of the depth logger and speed sensor are corrected to:

[0088] Local clock 5 = slave clock 5 - T1D2 - T2D5

[0089] Local clock 6 = slave clock 6 - T1D2 - T2D6

[0090] Step S5: Collecting the original logging time and original logging data, and synchronously recording the marked depth and vertical velocity, specifically including:

[0091] Step S501: Use a dedicated tool to check the quality of the borehole wall to ensure that the logging tool assembly can be safely and smoothly lowered to the maximum testing depth;

[0092] Step S502: marking a start depth marker and an end depth marker on the logging cable according to the logging depth range and the depth marker, wherein the position of the start depth marker is the zero depth position;

[0093] Step S503: starting the wireline logging system, the logging depth calibration system, and the time synchronization system, and entering a stable working state;

[0094] Step S504: Using the ground support and cable winch, the logging tool assembly is erected and aligned with the center of the borehole. The height of the logging tool assembly is adjusted until the starting depth marker is flush with the surface height. This time is recorded as time T=0, and the corresponding marked depth MD=0, vertical velocity v=0, and reference depth BD=0 are recorded.

[0095] Step S505: Starting from time T=0, the logging tool assembly is lowered vertically and nearly uniformly into the borehole. The logging tool assembly is controlled by the local clock to automatically collect the original logging time and original logging data, and the original logging time and original logging data are transmitted to the surface processing system via the logging cable. At the same time, at the standard time T=t n (n=1, 2, 3...) record the corresponding mark depth MD n , vertical speed v n , the calculation formula is as follows:

[0096] t n =n·Δt (n=1, 2, 3...)

[0097] Δt=1 / f max

[0098] f max =max{f1, f2, f3, f4}

[0099] For spectral logging tools, natural gamma ray spectroscopy logging tools, epithermal neutron logging tools, and neutron capture gamma ray spectroscopy logging tools, the corresponding original logging times are T1, T2, T3, and T4, respectively. The calculation formula is as follows:

[0100] T1 = n·Δt1 (n=1, 2, 3...)

[0101] Δt1= 1 / f1

[0102] T2 = n·Δt2 (n=1, 2, 3...)

[0103] Δt2= 1 / f2

[0104] T3 = n·Δt3 (n=1, 2, 3...)

[0105] Δt3= 1 / f3

[0106] T4= n·Δt4 (n=1, 2, 3...)

[0107] Δt4= 1 / f4

[0108] Step S506: When the end depth marker is flush with the surface height, the well logging is completed and the test data is recorded and organized.

[0109] Step S6: Time resampling and depth correction are performed on the original logging data to generate time resampled logging data and logging depth, specifically including:

[0110] Step S601: Estimate the standard time T = t according to the vertical speed and time interval Δt recorded by the speed sensor n (n=1, 2, 3...) corresponding reference depth BD n The calculation formula is as follows:

[0111] (n=1, 2, 3...)

[0112] Step S602: resample the original logging time and the original logging data by using an interpolation algorithm (such as linear interpolation, spline interpolation, etc.), and compare the original logging time T1, T2, T3, T4 with the standard time T=t n (n=1, 2, 3...) aligned to generate the standard time T=t n (n=1, 2, 3...) corresponding time-resampled logging data;

[0113] Step S603: Determine the reference depth BD n Perform depth correction to generate logging depth D n For spectrum logging tools, natural gamma ray spectrum logging tools, epithermal neutron logging tools, and neutron capture gamma ray spectrum logging tools, the corresponding logging depths are D 1n 、D 2n 、D 3n 、D 4n The calculation formula is as follows:

[0114] D 1n = BD n +L1

[0115] D 2n = BD n +L2

[0116] D 3n = BD n +L3

[0117] D 4n = BD n +L4

[0118] Step S7: Dividing the stratigraphic structure of the resampled logging data according to the logging depth and time, specifically including:

[0119] According to the logging depth D 1n 、D 2n 、D 3n 、D 4n and time-resampled logging data to draw mineral component distribution maps, radionuclide distribution maps, and porosity characteristic distribution maps;

[0120] The stratigraphic structure is divided according to the mineral component distribution map, radionuclide distribution map, and porosity characteristic distribution map.

[0121] The above are all preferred embodiments of the present application, and are not intended to limit the scope of protection of the present application. Therefore, any equivalent changes made based on the structure, shape, and principle of the present application should be included in the scope of protection of the present application.

Claims

1. A method for testing the mineral composition and content of uranium-containing reservoirs, characterized by: The following steps are involved: A combined logging tool assembly and a wireline logging system, wherein the logging tool assembly includes a spectral logging tool, a natural gamma ray spectrum logging tool, an epithermal neutron logging tool, and a neutron capture gamma ray spectrum logging tool, each logging tool having a different sampling frequency, and the logging tool assembly is connected to a surface processing system via a logging cable; Configure a logging depth calibration system, including marking depth markers at equal intervals on the logging cable, and configure a depth recorder and velocity sensor; Configure the time synchronization system, including configuring a master clock, intermediate logging tool clocks, and sensor intermediate clocks that support the Precision Time Protocol, and configuring slave clocks for each logging tool, depth logger, and velocity sensor; Perform PTP time synchronization on the cable logging system and the logging depth calibration system, calculate the primary and secondary time delays, and perform time correction on the local clock; Collect original logging time and original logging data, and synchronously record marked depth and vertical velocity; Perform time resampling and depth correction on the original logging data to generate time resampled logging data and logging depth; The stratigraphic structure is divided according to the logging depth and time of resampling logging data.

2. The method for testing the mineral composition and content of uranium-containing reservoirs according to claim 1, characterized in that: The configuration of the well logging depth calibration system includes: Mark equidistant depth markers based on the zero depth position corresponding to the logging cable joint; The marked depth MD is recorded by a depth recorder, and the vertical velocity v of the logging tool assembly is measured by a velocity sensor.

3. The method for testing the mineral composition and content of uranium-containing reservoirs according to claim 2, characterized in that: The method for calculating the first-level time delay includes: sending a first-level hardware timestamp to the logging tool intermediate clock and the sensor intermediate clock through the master clock, and calculating the first-level time delay T1D1 of the logging tool intermediate clock and the first-level time delay T1D2 of the sensor intermediate clock respectively.

4. The method for testing the mineral composition and content of uranium-containing reservoirs according to claim 3, characterized in that: The calculation method of the secondary time delay includes: Send secondary hardware timestamps to slave clocks of spectral logging tools, natural gamma ray spectroscopy logging tools, epithermal neutron logging tools, and neutron capture gamma ray spectroscopy logging tools through the logging tool intermediate clock, and calculate the corresponding secondary time delays T2D1, T2D2, T2D3, and T2D4 respectively; The secondary hardware timestamp is sent to the slave clocks of the depth recorder and the speed sensor via the sensor intermediate clock, and the corresponding secondary time delays T2D5 and T2D6 are calculated respectively.

5. The method for testing the mineral composition and content of uranium-containing reservoirs according to claim 4, characterized in that: Methods for correcting the local clock time include: Perform time correction on the local clock of each logging tool based on the secondary hardware timestamp, the primary time delay T1D1 of the logging tool's intermediate clock, and the secondary time delays T2D1, T2D2, T2D3, and T2D4 of each logging tool; The local clocks of the depth recorder and speed sensor are time-corrected based on the secondary hardware timestamp, the primary time delay T1D2 of the sensor intermediate clock, and the secondary time delays T2D5 and T2D6 of the depth recorder and speed sensor.

6. The method for testing the mineral composition and content of uranium-containing reservoirs according to claim 5, characterized in that: The steps for collecting original logging time and original logging data include: Mark the starting depth marker and ending depth marker on the logging cable according to the logging depth range and depth marker; Align the logging tool assembly with the center of the borehole and adjust the height until the starting depth marker is flush with the ground surface. Record the marked depth MD = 0, vertical velocity v = 0, and reference depth BD = 0 corresponding to the initial time T = 0. Starting from time T=0, the logging tool assembly is lowered at a nearly uniform speed. The spectral logging tool, natural gamma ray spectroscopy logging tool, epithermal neutron logging tool, and neutron capture gamma ray spectroscopy logging tool are controlled by the local clock to automatically collect the original logging times T1, T2, T3, and T4 and the corresponding logging data, and transmit them to the surface processing system via the logging cable. At the standard time T=t n Recording mark depth MD n and vertical velocity v n , where: t n Generated by accumulating the standard time interval Δt, where Δt is the maximum sampling frequency f in each logging tool max The reciprocal of T1, T2, T3, and T4 are generated by the independent sampling frequencies f1, f2, f3, and f4 of each logging tool respectively; When the end depth marker is flush with the ground surface, stop logging and organize the test data.

7. A method for testing mineral components and contents in uranium-containing reservoirs according to claim 6, characterized in that: Methods for time resampling and depth correction of raw logging data include: According to the vertical velocity v recorded by the velocity sensor n and time interval Δt, and calculate the standard time T=t by accumulating n Corresponding reference depth BD n ; The original logging time T1, T2, T3, T4 of each logging tool is interpolated with the standard time t n Alignment, generating time-resampled logging data; Reference depth BD n Perform depth correction to generate the logging depth D of each logging tool 1n 、D 2n 、D 3n 、D 4n .

8. The method for testing the mineral composition and content of uranium-containing reservoirs according to claim 7, characterized in that: Methods for dividing stratigraphic structures based on resampling logging data by logging depth and time include: According to the logging depth D 1n 、D 2n 、D 3n 、D 4n and time-resampled logging data to draw mineral component distribution maps, radionuclide distribution maps, and porosity characteristic distribution maps; The stratigraphic structure is divided according to the mineral component distribution map, radionuclide distribution map, and porosity characteristic distribution map.

9. A device for testing the mineral composition and content of uranium-containing reservoirs, used for implementing the method for testing the mineral composition and content of uranium-containing reservoirs according to any one of claims 1 to 8, characterized in that: include: A wireline logging system, comprising a logging tool assembly, a logging cable, and a surface processing system. The logging tool assembly comprises a spectral logging tool, a natural gamma ray spectrum logging tool, an epithermal neutron logging tool, a neutron generator, and a neutron capture gamma ray spectrum logging tool. Well logging depth calibration system, including depth markers on logging cables, depth recorders and velocity sensors; A time synchronization system includes a PTP domain. The PTP domain configures a master clock to connect to a slave clock via an intermediate clock. The slave clock is associated with a local clock. The master clock and the local clock are ordinary clocks, and the intermediate clock and the slave clock are boundary clocks.

10. The device for testing mineral components and contents in uranium-containing reservoirs according to claim 9, characterized in that: The sampling frequencies of the spectrum logging tool, the natural gamma ray spectrum logging tool, the epithermal neutron logging tool, and the neutron capture gamma ray spectrum logging tool are different.

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