Light hydrocarbon logging field automatic sampling data acquisition control system

Abstract

The present application belongs to the technical field of automatic control and data acquisition of mud logging site, and discloses a light hydrocarbon mud logging site automatic sampling data acquisition control system. The system generates a formation release synchronous sampling window according to drilling state data, circulating carrying state data and wellbore return lag data, forms a pose compensation sampling path or a compensation sampling control path by combining disturbance and feedback in a corresponding surface sampling period, and screens out invalid drilling fluid samples through sample state lockout. The system generates light hydrocarbon chromatogram signals and corresponding background interference detection data for the released drilling fluid samples, aligns the data through a reserved window to obtain an interference section mask, and performs background subtraction, peak shape correction and interference risk marking on the reserved time section indicated by the interference section mask, outputs corrected target light hydrocarbon concentration data, and reduces sampling depth dislocation and background peak interference.

Description

Technical Field

[0001] This invention relates to the field of automatic control and data acquisition technology for well logging, specifically to an automatic sampling and data acquisition control system for light hydrocarbon well logging. Background Technology

[0002] Light hydrocarbon logging requires obtaining information on the hydrocarbon components carried by the drilling fluid during drilling. After the drill bit breaks up the formation, methane, ethane, propane, butane, pentane, and other light hydrocarbons with higher carbon numbers in the formation pores enter the wellbore annulus along with the cuttings and drilling fluid, and are carried back to the surface by the circulating drilling fluid. The drilling fluid sample taken at the surface sampling port does not directly correspond to the current drill bit depth, but rather to the releases from a previous drilled depth. When the drilling rate, drilling pump displacement, wellbore size, casing structure, drill string assembly, wellbore enlargement status, sampling port installation location, and drilling fluid rheological state change, the time it takes for the underground release event to reach the surface sampling port also changes.

[0003] Existing automated logging equipment for light hydrocarbons mainly revolves around degassers, automatic sampling mechanisms, online chromatographs, sample vial delivery mechanisms, and data acquisition software. Degasser level tracking ensures a relatively stable immersion depth of the degasser in the drilling fluid; automatic sampling mechanisms reduce manual injection errors; chromatographic systems with shorter analysis cycles shorten the time from when the drilling fluid sample enters the detection channel to when the light hydrocarbon chromatographic signal is output; and spectral library comparison or concentration correction algorithms can post-process some abnormal peaks. While these technologies can improve the stability of individual components, under conditions such as rapid drilling through thin interbedded layers, frequent pump rate adjustments, changes in wellbore volume, disturbances in the bottomhole return path, and significant outlet fluid slugging, fixed-time sampling may still deviate from the time period when the target formation releases material return to the surface.

[0004] In fixed-period sampling methods, the sampling system typically starts the sampling pump, opens the sampling valve assembly, or prompts manual sampling at preset time intervals. Sampling batches are only linked to surface sampling times, failing to guarantee that the surface sampling period covers the return front, peak center, and peak rear edge of the released material at the target depth. When the drilling pump displacement increases, the time for formation released material to return to the surface shortens; when the drilling pump displacement decreases or is restarted after a shutdown, the return time lengthens, and the return peak shape may be widened. If the sampling system does not use drilling status data, circulation carryover status data, and wellbore return lag data together for sampling triggering, light hydrocarbon concentration data can easily be incorrectly labeled to adjacent depth segments. Even if the detection instrument has a short analysis cycle, if the input drilling fluid sample comes from an incorrect return period, the output concentration still cannot accurately reflect the release status of the target formation.

[0005] The on-site sampling process is also affected by drilling platform vibration, fluid level fluctuations at the sampling port, gas-liquid slugging, solid particle impact, pressure fluctuations in the sampling channel, and pipeline residues. If the three-dimensional linear motion mechanism operates only according to the static coordinates after installation and calibration, it may draw in too much gas when the fluid level at the sampling port drops, and may cause drilling fluid sample overflow or contamination at the execution end when the fluid level at the sampling port rises. If the fixed sampling probe operates only according to a fixed pump speed and fixed valve position, it may experience partial blockage at the suction port, insufficient sample volume, or abnormal pressure response when there is high sand content or rock cuttings impacting the sampling port. After abnormal drilling fluid samples enter the detection channel, the light hydrocarbon release process and the drilling fluid sample delivery process will be affected, and the peak shape of the light hydrocarbon chromatographic signal will be distorted, resulting in a lack of reliable drilling fluid sample basis for subsequent correction of the target light hydrocarbon concentration data.

[0006] Lubricants, anti-collapse agents, filtration reducers, fluorescent agents, oil-based components, synthetic components, circulating contaminants, and pipeline residues in the drilling fluid system may also form background peaks near the target light hydrocarbon retention window. A single light hydrocarbon chromatographic signal typically only reflects the overall response of the detection channel, making it difficult to determine which portion of the peak area originates from the target formation light hydrocarbons and which from the current drilling fluid matrix background. If relying solely on a fixed spectral library or manual experience, changes in drilling fluid additives, mud system switching, downhole high-temperature circulation, and pipeline residues can cause shifts in the position, width, and intensity of background peaks, resulting in the corrected target light hydrocarbon concentration data still deviating from the actual formation release state. Summary of the Invention

[0007] The purpose of this invention is to provide an automatic sampling data acquisition and control system for light hydrocarbon logging sites. The technical problem this invention aims to solve is that in light hydrocarbon logging sites, fixed-period sampling or single-instrument-triggered sampling cannot dynamically generate surface sampling periods based on drilling status, circulation carrying status, and wellbore return lag, resulting in misalignment between surface sampling batches and underground formation release depth segments. At the same time, when drilling fluid sample conditions are abnormal and drilling fluid matrix background peaks enter the light hydrocarbon chromatographic signal, it is difficult to complete traceable correction of single-channel detection results within the same sampling batch.

[0008] To solve the above-mentioned technical problems, the technical solution adopted by the present invention is as follows: A light hydrocarbon logging field automatic sampling data acquisition and control system includes a main control processing module and a drilling operation synchronization module, a posture compensation sampling execution module, a sample status interlocking module and a dual-channel chromatography reconstruction module, which are respectively connected to the main control processing module. The drilling status synchronization module receives drilling status data, circulating carry status data, and wellbore return lag data. It converts the drilling status data, circulating carry status data, and wellbore return lag data into a formation release synchronization sampling window and sends the formation release synchronization sampling window to the main control processing module. The formation release synchronization sampling window includes the formation release synchronization sampling window start time, formation release synchronization sampling window end time, target depth label, and formation release synchronization sampling window reliability. The main control processing module generates a sampling trigger queue containing the surface sampling period according to the formation release synchronous sampling window, and sends the sampling trigger queue to the pose compensation sampling execution module. The pose compensation sampling execution module receives sampling execution disturbance data, receives execution end position feedback data when a three-dimensional linear motion mechanism is used, and receives sampling end status feedback data when a fixed sampling probe is used. During the surface sampling period, it generates a pose compensation sampling path or a compensation sampling control path and collects drilling fluid samples according to the pose compensation sampling path or the compensation sampling control path. The pose compensation sampling execution module sends the drilling fluid sample into the detection flow path of the sample state locking module, and sends the sample state data corresponding to the drilling fluid sample to the sample state locking module through the main control processing module. The sample status interlocking module outputs a sample release result or a sample interception result based on the sample status data, and returns the sample release result or the sample interception result to the main control processing module; The main control processing module sends the sample release result to the dual-channel chromatographic reconstruction module and controls the injection valve to send the drilling fluid sample corresponding to the sample release result into the dual-channel chromatographic reconstruction module; After receiving the sample release result, the dual-channel chromatographic reconstruction module generates a light hydrocarbon chromatographic signal for the drilling fluid sample of the same sampling batch and acquires the background interference detection data corresponding to the same sampling batch. The light hydrocarbon chromatographic signal and the background interference detection data are aligned with the retention window to obtain the interference segment mask. The interference segment mask is then used to perform background subtraction, peak shape correction and interference risk marking on the retention time segment of the light hydrocarbon chromatographic signal indicated by the interference segment mask, and outputs the corrected target light hydrocarbon concentration data.

[0009] As a preferred embodiment of the present invention, the drilling condition synchronization module includes a depth-time analysis unit, a footage pulse analysis unit, and a cycle status analysis unit; the depth-time analysis unit extracts drilling depth-time data from the logging data bus, the drilling depth interface, or the field depth database; the footage pulse analysis unit extracts footage change data from the winch encoder, the top drive position sensor, or the drilling depth interface; and the cycle status analysis unit extracts the cycle-carrying status data from the drilling pump displacement meter, the pump pulse counter, the riser pressure interface, the outlet flow interface, or the pump displacement setting interface.

[0010] As a preferred embodiment of the present invention, the main control processing module includes a hysteresis correction sampling scheduling unit; the hysteresis correction sampling scheduling unit generates wellbore return hysteresis data based on wellbore geometric data, the circulating carry-over state data, sampling port location data, and hysteresis correction source data, and maps the formation release time period corresponding to the drilled formation depth interval to the surface sampling time period, wherein the hysteresis correction source data includes at least one of tracer pulse arrival data, historical gas logging peak offset data, and logging engineer correction input data.

[0011] As a preferred embodiment of the present invention, the hysteresis correction sampling scheduling unit performs upper limit constraint on the maximum allowable interval between adjacent valid sampling batches, lower limit constraint on the minimum execution interval between adjacent sampling actions, and merges adjacent formation release synchronous sampling windows; when the drilling status data, the cyclic carry-over status data, or the hysteresis correction source data are missing, the hysteresis correction sampling scheduling unit generates a conservative sampling trigger queue based on the most recent valid wellbore return hysteresis data, and writes a missing data marker and a formation release synchronous sampling window reliability reduction marker in the system control log.

[0012] As a preferred embodiment of the present invention, the pose-compensated sampling execution module includes a disturbance acquisition unit, a path compensation unit, and a sampling execution unit. The disturbance acquisition unit receives at least one of the following: drilling platform vibration acceleration data, actuator encoder residual data, sampling port fluid level position data, servo current fluctuation data, and sampling channel pressure fluctuation data. When the sampling execution unit employs a three-dimensional linear motion mechanism, the path compensation unit corrects the basic sampling coordinates based on the sampling execution disturbance data and the actuator position feedback data, generating the pose-compensated sampling path including an approach path, a stable waiting section, a sampling suction section, and a withdrawal path. When the sampling execution unit employs a fixed sampling probe or a valve-controlled sampling pump, the path compensation unit corrects the basic sampling control sequence based on the sampling execution disturbance data and the sampling end status feedback data, generating the compensated sampling control path including the sampling valve group status, sampling pump flow status, bypass sample rejection status, and backflushing status. The sampling execution unit completes the drilling fluid sample collection according to the pose-compensated sampling path or the compensated sampling control path.

[0013] As a preferred embodiment of the present invention, the sampling execution unit includes a metering pump, a level detector, a sampling valve assembly, and a bypass waste sampling pipeline; the main control processing module generates a drive pulse for the metering pump based on the target sampling volume, the level detection result, and the pressure change result of the sampling channel; the sampling valve assembly connects the sample collection channel during the surface sampling period and connects the bypass waste sampling pipeline outside the surface sampling period; when the sampling execution unit uses a fixed sampling probe to collect the drilling fluid sample, the main control processing module controls the connection status of the sampling valve assembly, the metering pump, and the bypass waste sampling pipeline according to the compensated sampling control path.

[0014] As a preferred embodiment of the present invention, the sample status interlocking module receives at least liquid level data and sampling channel pressure data, and receives at least one of sampling channel temperature data, sample turbidity data, gas-liquid ratio data, and pump pulse response data; when the sample status data meets the preset release conditions, the sample status interlocking module outputs the sample release result; when the sample status data does not meet the preset release conditions, the sample status interlocking module outputs the sample interception result.

[0015] As a preferred technical solution of the present invention, after receiving the sample interception result, the main control processing module controls the pose compensation sampling execution module to perform bypass sample abandonment, pipeline cleaning and blank liquid verification. After completing the blank liquid verification, the module decides to resample or generate a sampling failure mark based on the remaining duration of the formation release synchronous sampling window, the reliability of the formation release synchronous sampling window and the sampling execution status.

[0016] As a preferred embodiment of the present invention, the dual-channel chromatographic reconstruction module includes a sample splitting unit, a light hydrocarbon release detection unit, and a background interference detection unit; When using the same batch background detection method, the sample splitting unit splits the drilling fluid sample from the same sampling batch into light hydrocarbon release detection subsample and matrix background detection subsample. When using the blank drilling fluid background detection method, the sample splitting unit obtains light hydrocarbon release detection sub-samples from the drilling fluid samples of the same sampling batch, and the main control processing module binds the blank drilling fluid samples of the same circulation section to the same sampling batch. The light hydrocarbon release detection unit degasses and separates the light hydrocarbon release detection sample and generates the light hydrocarbon chromatographic signal. The background interference detection unit performs background detection on the matrix background detection sample or the blank drilling fluid sample of the same circulation section bound to the same sampling batch and generates the background interference detection data. The background detection includes at least one of residual matrix chromatographic detection, three-dimensional fluorescence detection and blank drilling fluid background detection.

[0017] As a preferred technical solution of the present invention, the dual-channel chromatographic reconstruction module includes a window alignment unit and an interference mask generation unit; The retention window alignment unit converts the light hydrocarbon chromatographic signal and the background interference detection data to the same time reference or the same retention window reference, extracts the peak start point, peak apex and peak end point from the light hydrocarbon chromatographic signal, and extracts the background segment start point, background segment center point and background segment end point from the converted background interference detection data; The interference mask generation unit generates the interference segment mask based on the peak width overlap relationship, peak position offset relationship, background segment intensity relationship, and channel baseline stability.

[0018] As a preferred embodiment of the present invention, the dual-channel chromatographic reconstruction module includes a concentration reconstruction unit; The concentration reconstruction unit performs background subtraction, baseline correction, peak area verification, and interference risk labeling on the light hydrocarbon chromatographic signal within the retention time range indicated by the interference segment mask. Within the retention time range not indicated by the interference segment mask, it retains the effective peak shape of the light hydrocarbon chromatographic signal and outputs the corrected target light hydrocarbon concentration data with depth label, sampling time label, formation release synchronous sampling window confidence label, sample status label, and channel status label.

[0019] As a preferred embodiment of the present invention, the main control processing module further includes a control status monitoring unit, a feedback scheduling unit, and a traceability packet unit; The control status monitoring unit monitors the communication status, execution status, and abnormal status of the drilling condition synchronization module, the pose compensation sampling execution module, the sample status locking module, and the dual-channel chromatographic reconstruction module. When the target light hydrocarbon concentration data increases for three consecutive sampling batches and the interference segment mask corresponds to a weak interference intensity, the feedback scheduling unit increases the sampling priority of the subsequent sampling trigger queue; when the interference segment mask corresponds to a medium interference intensity, the feedback scheduling unit increases the background interference detection frequency. The feedback scheduling unit increases the frequency of pipeline cleaning when the interference section mask corresponds to a strong interference intensity. The traceability packet unit writes the sampling trigger queue, the pose compensation sampling path or the compensation sampling control path, the sample release result, the sample interception result, the interference segment mask, and the corrected target light hydrocarbon concentration data into a timestamped data packet.

[0020] In addition, this invention also discloses a method for automatic sampling data acquisition and control in light hydrocarbon logging, applied to the aforementioned automatic sampling data acquisition and control system for light hydrocarbon logging. The method includes: The main control processing module acquires drilling status data, cyclically carried status data, and wellbore return lag data, and generates a formation release synchronous sampling window. The formation release synchronous sampling window includes the formation release synchronous sampling window start time, formation release synchronous sampling window end time, target depth label, and formation release synchronous sampling window reliability. The main control processing module generates a sampling trigger queue containing surface sampling time periods based on the formation release synchronous sampling window. During the surface sampling period, the pose compensation sampling execution module generates a pose compensation sampling path or a compensation sampling control path based on the sampling execution disturbance data and the execution end position feedback data or the sampling end status feedback data, and collects drilling fluid samples according to the pose compensation sampling path or the compensation sampling control path, while simultaneously collecting the sample status data corresponding to the drilling fluid samples. The sample status interlocking module outputs the sample release result or the sample interception result based on the sample status data; after receiving the sample release result, the main control processing module sends the sample release result to the dual-channel chromatographic reconstruction module and controls the released drilling fluid sample to enter the dual-channel chromatographic reconstruction module. The dual-channel chromatographic reconstruction module generates light hydrocarbon chromatographic signals for the drilling fluid samples from the same sampling batch and acquires background interference detection data corresponding to the same sampling batch. The light hydrocarbon chromatographic signals and the background interference detection data are aligned with the retention window to obtain an interference segment mask. The interference segment mask is then used to perform background subtraction, peak shape correction, and interference risk marking on the retention time segments of the light hydrocarbon chromatographic signals indicated by the interference segment mask, and the corrected target light hydrocarbon concentration data is output.

[0021] Meanwhile, the present invention also discloses a computer-readable storage medium storing a computer program, which, when executed by a processor, implements the above-described method for automatic sampling data acquisition and control in light hydrocarbon logging.

[0022] Compared with the prior art, the present invention has the following beneficial effects: This invention uses drilling status data, cyclic carryover status data, and wellbore return lag data to generate a formation release synchronous sampling window. This eliminates the dependence of sampling triggering on fixed time intervals, instead forming a sampling trigger queue based on the mapping relationship between underground release time and surface return time. Therefore, when drilling rate and pump displacement change, sampling batches can carry target depth labels and the reliability of the formation release synchronous sampling window, reducing the risk of thin-layer releases being incorrectly classified into adjacent depth segments.

[0023] This invention utilizes sampling execution disturbance data, execution end position feedback data, or sampling end status feedback data to generate pose-compensated sampling paths or compensated sampling control paths. This enables the sampling execution unit to adapt to drilling platform vibration, fluid level fluctuations, execution end positioning deviations, sampling valve group status changes, and sampling channel pressure fluctuations during surface sampling periods. Consequently, the sampling action no longer operates solely based on static coordinates or fixed pump durations, reducing the risk of inhaling drilling fluid samples with abnormal gas-liquid ratios, or continuing sampling after drilling fluid sample spillage or pipeline blockage. The sample status interlocking module assesses liquid level, pressure, temperature, turbidity, gas-liquid ratio, or pump pulse response before the drilling fluid sample enters the dual-channel chromatographic reconstruction module. For drilling fluid samples that do not meet preset release conditions, it performs interception, bypass discarding, pipeline cleaning, and blank fluid calibration. Therefore, failed drilling fluid samples will not directly enter the detection channel, reducing the impact of abnormal drilling fluid samples on light hydrocarbon chromatographic signals, background interference detection data, and subsequent batch pipeline status.

[0024] This invention's dual-channel chromatographic reconstruction module generates light hydrocarbon chromatographic signals based on the same sampling batch and acquires background interference detection data corresponding to the same sampling batch. It then forms an interference segment mask through window alignment processing and performs background subtraction, peak shape correction, and interference risk marking within the retention time range defined by the interference segment mask. Thus, the background interference detection data becomes the actual constraint for concentration reconstruction, rather than merely a manual reference spectrum, reducing the impact of drilling fluid additives, circulating contaminants, and pipeline residual background peaks on the target light hydrocarbon peak area. The traceability packet unit binds the sampling trigger queue, pose-compensated sampling path or compensated sampling control path, sample state locking result, interference segment mask, and corrected target light hydrocarbon concentration data into a timestamped data packet. This allows each corrected target light hydrocarbon concentration data to be traced back to the sampling window, drilling fluid sample state, and detection channel state, facilitating on-site interpretation, data verification, and quality traceability. Attached Figure Description

[0025] To more clearly illustrate the technical solutions of the embodiments of the present invention, the accompanying drawings used in the embodiments will be briefly introduced below. It should be understood that the following drawings only show some embodiments of the present invention and should not be regarded as a limitation of the scope. For those skilled in the art, other related drawings can be obtained from these drawings without creative effort.

[0026] Figure 1 This is a flowchart of the method of the present invention.

[0027] Figure 2 This is a flowchart of the sub-process for generating the formation release synchronous sampling window in this invention.

[0028] Figure 3 This is a flowchart of the pose compensation sampling execution sub-process of the three-dimensional linear motion mechanism of the present invention.

[0029] Figure 4 This is a flowchart of the fixed sampling probe compensation sampling control sub-process of the present invention.

[0030] Figure 5 This is a flowchart of the sample state locking and anomaly handling sub-process of the present invention.

[0031] Figure 6 This is a flowchart of the dual-channel detection sub-process for samples in the same batch according to the present invention.

[0032] Figure 7 This is a flowchart of the interference segment mask generation sub-process of the present invention.

[0033] Figure 8 This is a flowchart of the chromatographic signal reconstruction and traceability process for sealing buns according to the present invention. Detailed Implementation

[0034] In the following description, only certain exemplary embodiments are briefly described. As those skilled in the art will recognize, the described embodiments can be modified in various ways without departing from the spirit or scope of the embodiments of the invention. Therefore, the drawings and description are considered to be exemplary in nature and not restrictive.

[0035] The following is in conjunction with the appendix Figures 1-8 The embodiments of the present invention will be described in detail below.

[0036] Example 1: This example provides an automatic sampling data acquisition and control system for light hydrocarbon logging. The system is located in the logging instrument room, beside the drilling fluid outlet pipeline, in a protected sampling area near the vibrating screen, on the side of the buffer tank, or in a sampling and analysis area that has undergone explosion-proof isolation at the drilling site. The system does not necessarily rely on a specific model of logging instrument, chromatograph, robotic arm, or degasser; instead, it uses a main control processing module to synchronously control the drilling conditions, sampling execution, drilling fluid sample status, and dual-channel detection data.

[0037] The automatic sampling data acquisition and control system for light hydrocarbon logging includes a main control processing module, a drilling operation synchronization module, a posture compensation sampling execution module, a sample status interlocking module, and a dual-channel chromatographic reconstruction module. The main control processing module can be composed of an industrial computer, a programmable logic controller (PLC), an edge computing controller, an embedded controller, or a processor with real-time acquisition and control output capabilities. The main control processing module connects to the logging data bus, drilling pump displacement acquisition interface, winch encoder interface, top drive position interface, sampling execution mechanism drive interface, sensor acquisition interface, valve group control interface, chromatographic signal acquisition interface, and human-machine interface. Internally, the main control processing module runs drilling synchronization programs, sampling scheduling programs, posture compensation control programs, compensated sampling control programs, sample interlocking programs, dual-channel chromatographic reconstruction programs, anomaly monitoring programs, and traceability packaging programs.

[0038] The pose-compensated sampling execution module includes a sampling actuator, a sampling pump, a sampling valve assembly, a sampling pipeline, and sampling pipeline sensors. After collecting drilling fluid samples, the pose-compensated sampling execution module sends the drilling fluid samples to the detection flow path of the sample status interlocking module. The detection flow path of the sample status interlocking module includes at least two of the following: a liquid level detection section, a pressure detection section, a temperature detection section, a turbidity detection section, and a gas-liquid ratio detection section. The detection flow path of either the pose-compensated sampling execution module or the sample status interlocking module collects the sample status data corresponding to the drilling fluid sample and sends the sample status data to the main control processing module. The main control processing module sends the sample status data to the sample status interlocking module. After the sample status interlocking module outputs the sample release result, the main control processing module sends the sample release result to the dual-channel chromatographic reconstruction module and controls the injection valve to send the drilling fluid sample into the dual-channel chromatographic reconstruction module. After the sample status interlocking module outputs the sample interception result, the main control processing module controls the sampling valve assembly to connect to the bypass discard pipeline.

[0039] The drilling status synchronization module receives drilling status data, circulation status data, and wellbore return lag data. Drilling status data includes one or more of the following: drilling depth-time data, footage change data, current bit depth data, drilling time data, drilling speed data, drilling pressure status data, and drilling start / stop status data. Drilling depth-time data can come from the integrated logging system's field data bus, well site information transmission interface, drilling measurement-while-drilling interface, winch encoder, top drive position sensor, driller's cabin data interface, or field depth database. Footage change data can be obtained from winch encoder pulses, top drive displacement changes, drill string connection records, bit depth curve differentials, or manually confirmed depth events. Circulation status data includes one or more of the following: drilling pump displacement data, pump flushing data, pump start / stop status data, riser pressure change data, outlet flow rate data, drilling fluid density data, drilling fluid viscosity data, circulation tank level change data, and choke manifold status data.

[0040] Furthermore, wellbore return hysteresis data is used to characterize the time it takes for subsurface formation releases to travel from the drilled depth to the surface sampling port. Wellbore return hysteresis data can be calculated from wellbore geometry data, circulation carryover data, and sampling port location data, or from tracer pulse arrival data, historical gas peak shift data, or data corrected by logging engineers. Wellbore geometry data includes well depth, casing inner diameter, drill pipe outer diameter, drill collar outer diameter, wellbore dimensions, wellbore enlargement information, distance from the sampling port to the vibrating screen or outlet pipeline, pipeline volume from the sampling port to the chromatographic inlet, and annular volume correction data. Tracer pulse arrival data can be derived from field-permissible conductivity perturbations, temperature perturbations, pump displacement abrupt changes, known circulation state changes, or background responses detectable at the surface. Historical gas peak shift data can be derived from the verification results between the gas peak center and the corresponding cuttings depth in the drilled section. The data that logging engineers can correct can include manually confirmed late arrival times, circulation tank status change times, drilling fluid system change times, and known return anomaly event times.

[0041] The basic return lag result is the uncorrected initial calculated value of the wellbore return lag data. Lag correction source data is used to correct the basic return lag result obtained from wellbore geometry data and circulation carryover state data. When calculating the wellbore return lag data, the main control processing module first uses wellbore geometry data and circulation carryover state data to form the basic return lag result, and then uses tracer pulse arrival data, historical gas logging peak offset data, or logging engineer correction input data to correct the basic return lag result. If multiple lag correction source data exist simultaneously, the main control processing module selects the data to be corrected based on data source time, data integrity, and field calibration priority, and writes the selection result to the system control log. The system control log records the control decisions, abnormal events, parameter changes, and data source switching processes of the light hydrocarbon logging field automatic sampling data acquisition and control system.

[0042] After receiving data from different sources, the drilling status synchronization module first performs time base unification. The main control processing module adds a unified system timestamp to each frame of drilling status data, cyclically carried status data, and wellbore return lag data, while retaining the original equipment timestamp and data source identifier. Due to the different sampling frequencies of different devices, the main control processing module performs window aggregation on high-frequency data, maintains updates on low-frequency data, and performs edge-triggered recording on event-based data. If there is a short-term interruption in the logging data bus, the main control processing module retains the most recent valid data and records the data failure duration to prevent data without a source from being used as real-time data.

[0043] The depth-time analysis unit determines the drilled formation depth interval and formation release time period from the drilling depth-time data. When the depth curve continuously increases and the drilling status is effective drilling, the depth-time analysis unit identifies the time period between adjacent depth points as the release time period of the corresponding depth segment. If the drill bit is in the reaming, observation, tripping, or single-joint operation state, the depth-time analysis unit controls the generation of the release time period according to the drilling status marker. For thin interbedded sections, the depth-time analysis unit divides the continuous depth curve into multiple small depth intervals according to the preset depth sampling granularity, and records the release start time, release end time, drilling speed, and depth reliability for each depth interval. The preset depth sampling granularity is jointly determined by the logging interpretation accuracy requirements, the sampling mechanism's execution capability, and the detection channel analysis cycle.

[0044] The footage pulse analysis unit is used to verify the drilling depth-time data. It statistically analyzes the number and direction of footage pulses within the control cycle, generating footage change data. The main control processing module compares the footage change data with the drilling depth-time data for consistency. When the deviation between the footage change data and the drilling depth-time data is within a preset range, the depth reliability remains normal. When the deviation exceeds the preset range, the main control processing module selects reliable data according to data source priority and writes a depth source anomaly flag into the formation release synchronous sampling window. The preset range is determined by the winch encoder calibration results, top drive position sensor resolution, drill string status, and on-site depth calibration procedures. The depth source anomaly flag does not directly delete the formation release synchronous sampling window but affects the priority of subsequent sampling trigger queues and the reliability of the formation release synchronous sampling window.

[0045] The circulation status analysis unit converts data such as drilling pump displacement, pump flushing, pump start / stop, riser pressure, and outlet flow rate into circulation carryover status data. Circulation carryover status data reflects the transport status of drilling fluid carrying formation releases from the wellbore to the surface. A stable circulation flag indicates that the current circulation carryover status data is suitable for use in wellbore return hysteresis data calculation. An abnormal circulation flag indicates that the current circulation carryover status data shows pump stoppage, sudden changes in displacement, or abnormal outlet flow rate.

[0046] For example, if the drilling pump operates continuously and the drilling pump displacement is continuous The fluctuation range within the range does not exceed the average drilling pump displacement. The cycle state analysis unit outputs a stable cycle flag; if the drilling pump stops or the drilling pump displacement is continuously... The fluctuation range within the range exceeds the average drilling pump displacement. Export flow decreased by more than the average export flow. If the circulating tank level is abnormal, the circulating status analysis unit will output a circulating abnormality flag. When generating the wellbore return lag data, the main control processing module reads the stable circulating flag or the circulating abnormality flag and adjusts the reliability of the formation release synchronous sampling window during the surface sampling period.

[0047] The hysteresis-corrected sampling scheduling unit generates wellbore return hysteresis data based on wellbore geometry data, circulation carryover status data, sampling port location data, and hysteresis correction source data. The hysteresis-corrected sampling scheduling unit can establish a mapping relationship between underground release time and surface sampling time using methods such as annular volume integral segment accumulation, pump flush accumulation, displacement integral, tracer pulse correction, or historical gas peak regression. The hysteresis-corrected sampling scheduling unit first determines the annular transport path corresponding to the drilled formation depth range, then determines the time required for the drilling fluid volume in the annular transport path to be carried to the sampling port based on the circulation carryover status data. Subsequently, it corrects the required time using tracer pulse arrival data or historical gas peak offset data, ultimately obtaining the surface return front time, surface return peak center time, and surface return trailing edge time corresponding to the target depth range.

[0048] The formation release synchronous sampling window is jointly determined by the surface return front time, surface return peak center time, surface return trailing edge time, sampling execution preparation time, and detection channel occupancy status. The formation release synchronous sampling window includes the formation release synchronous sampling window start time, formation release synchronous sampling window end time, target depth label, and formation release synchronous sampling window reliability. The formation release synchronous sampling window start time controls the sampling execution unit to enter a preparation or stable waiting state. The formation release synchronous sampling window end time controls the closure of the sample collection channel or the determination of sampling failure. The target depth label is used for subsequent depth marking of the target light hydrocarbon concentration data. The formation release synchronous sampling window reliability reflects the reliability of depth data, circulation carryover status data, wellbore return hysteresis data, and sampling execution status.

[0049] The reliability of the formation release synchronous sampling window is synthesized from the reliability of depth data, circulation carryover status, wellbore return hysteresis, and sampling execution status. Depth data reliability characterizes the accuracy of drilling depth-time data, determined by the consistency between drilling depth-time data and footage pulse data. Circulation carryover status reliability characterizes the stability of the drilling fluid circulation carryover status, determined by drilling pump displacement data, pump flushing data, standpipe pressure change data, and outlet flow rate data. Wellbore return hysteresis reliability characterizes the reliability of wellbore return hysteresis data, determined by the deviation between the base return hysteresis result and the hysteresis correction source data. Sampling execution status reliability characterizes whether the pose-compensated sampling path or compensated sampling control path is fully executed, determined by the sampling execution status, drilling fluid sample release status, and detection channel status.

[0050] In one possible implementation, for example, the reliability of depth data, the reliability of the cycle carry-over state, the reliability of the wellbore return hysteresis, and the reliability of the sampling execution state all adopt... , and Three numerical levels. The depth deviation between drilling depth-time data and footage pulse data is less than or equal to... At that time, the reliability of depth data was Depth deviation greater than and less than or equal to At that time, the reliability of depth data was Depth deviation greater than At that time, the reliability of depth data was Drilling pump displacement data in continuous The fluctuation range within the range is less than or equal to the average drilling pump displacement. At that time, the reliability of the cyclically carried state is Drilling pump displacement data in continuous The fluctuation range within is greater than and less than or equal to At that time, the reliability of the cyclically carried state is Drilling pump displacement data in continuous The fluctuation range within is greater than In the event of a pump stoppage, the reliability of the cyclic carryover state is: The time deviation between the base return lag result and the lag correction source data is less than or equal to... At that time, the reliability of the wellbore return hysteresis was Time deviation greater than and less than or equal to At that time, the reliability of the wellbore return hysteresis was Time deviation greater than When hysteresis correction source data is lacking, the wellbore return hysteresis reliability is: When the pose-compensated sampling path or the compensatory sampling control path is fully executed and the drilling fluid sample is released, the reliability of the sampling execution status is [value missing]. When the pose-compensated sampling path or the compensatory sampling control path is fully executed but the drilling fluid sample needs to be resampled, the reliability of the sampling execution status is: When the pose compensation sampling path or compensation sampling control path is not fully executed or a sampling failure flag is generated, the sampling execution status reliability is 1. .

[0051] The confidence level of the formation release synchronous sampling window is calculated using the following formula:

[0052] in, To enhance the reliability of the simultaneous sampling window for formation release, To enhance the credibility of deep data, To ensure the reliability of the cyclically carried state, To assess the reliability of wellbore return lag, To assess the reliability of the sampled execution status.

[0053] The confidence level of the formation release synchronous sampling window is greater than or equal to When the formation release synchronous sampling window confidence level is set to high confidence, the confidence level of the formation release synchronous sampling window is greater than or equal to [a certain value]. and less than When the formation release synchronous sampling window confidence level is less than a certain value, the confidence level label is medium confidence. At that time, the confidence level of the formation release synchronous sampling window was set to low confidence.

[0054] The main control processing module generates a sampling trigger queue based on the formation release synchronous sampling window. The sampling trigger queue includes the surface sampling period, sampling start time, pre-sampling cleaning status, sampling execution mechanism preparation status, target sampling volume, sample bottle number, expected detection channel, background interference detection mode, and anomaly handling strategy. The surface sampling period is converted from the start and end times of the formation release synchronous sampling window and is used to limit the time range for the sampling execution unit to collect drilling fluid samples. The main control processing module performs upper limit constraints on the sampling interval, lower limit constraints on the sampling interval, and merges adjacent formation release synchronous sampling windows on the sampling trigger queue. The upper limit constraint on the sampling interval limits the maximum allowable interval between adjacent valid sampling batches. The lower limit constraint on the sampling interval limits the minimum execution interval between adjacent sampling actions. The merge of adjacent formation release synchronous sampling windows generates a single sampling action with a composite depth label when two formation release synchronous sampling windows highly overlap and the target depth difference is less than the preset depth distinction requirement.

[0055] The conservative sampling trigger queue is a fallback sampling queue generated in scenarios with missing data. The difference between the conservative and normal sampling trigger queues lies in the fact that the conservative sampling trigger queue corresponds to a wider surface sampling period than the normal one, and the reliability of the formation release synchronization sampling window corresponding to the conservative trigger queue is lower than that of the normal one. When the drilling pump stops, discharge data is missing, or depth data becomes temporarily invalid, the main control processing module generates a conservative sampling trigger queue based on the most recent valid wellbore return lag data and writes a missing data marker into the data packet. If the missing time exceeds the preset tolerance period, the main control processing module stops outputting corrected target light hydrocarbon concentration data that can be used for interpretation and evaluation, retaining only the original acquisition records and abnormal status labels. The preset tolerance period is determined by the logging operation procedures, the sampling agency's execution capability, and the data acquisition system communication cycle.

[0056] The pose-compensated sampling execution module is used to collect drilling fluid samples according to a sampling trigger queue. The pose-compensated sampling execution module may include a three-dimensional linear motion mechanism, a fixed sampling probe, a valve-controlled sampling pump, a metering pump, a sampling valve assembly, a bypass discard pipeline, a pipeline cleaning assembly, a sample vial delivery mechanism, and an execution-end sensor. The three-dimensional linear motion mechanism can move along a first horizontal direction, a second horizontal direction, and a vertical direction. The execution end is equipped with a sampling port, a short probe, or a metering suction structure. The fixed sampling probe can be installed in the stable fluid zone of the drilling fluid outlet pipeline, on the side of the buffer tank, or in the buffer trough before the vibrating screen, and the suction timing is controlled by the sampling valve assembly and the sampling pump. In the three-dimensional linear motion mechanism implementation, the feedback data is the execution-end position feedback data. In the fixed sampling probe implementation, the feedback data is the sampling-end status feedback data, which includes one or more of the following: sampling valve assembly positioning data, sampling pump inlet pressure data, sampling pump flow rate data, and sampling probe blockage status data.

[0057] The disturbance acquisition unit receives sampling execution disturbance data. This data may include drilling rig vibration acceleration data, actuator encoder residual data, sampling port fluid level position data, servo current fluctuation data, sampling channel pressure fluctuation data, image positioning deviation data, sampling pump inlet pressure data, and sampling flow rate fluctuation data. Drilling rig vibration acceleration data reflects the impact of well site equipment vibration on the actuator. Actuator encoder residual data reflects the deviation between the control command position and the actual execution position. Sampling port fluid level position data reflects the fluctuations in the drilling fluid return surface. Servo current fluctuation data reflects changes in actuator load. Sampling channel pressure fluctuation data reflects the gas-liquid slug, blockage, or leakage status near the sampling probe inlet.

[0058] The basic sampling coordinates are the default operating coordinates of the three-dimensional linear motion mechanism. These coordinates are predetermined by installation calibration, sampling port structural dimensions, liquid level calibration height, and safety avoidance zone. When the sampling execution unit uses a three-dimensional linear motion mechanism, the path compensation unit corrects the basic sampling coordinates based on sampling execution disturbance data and execution end position feedback data, generating a pose-compensated sampling path. The pose-compensated sampling path includes an approach path, a stabilization waiting section, a sampling suction section, and an withdrawal path. The approach path moves the execution end from a safe position to near the sampling port. The stabilization waiting section keeps the execution end in the sampleable area before the start of the surface sampling period and continuously reads the liquid level position, vibration status, and execution end position feedback. The sampling suction section starts the metering pump or opens the sample collection channel during the surface sampling period. The withdrawal path removes the execution end from the splash area after sampling and switches the sampling valve assembly to bypass discard or cleaning mode.

[0059] In the implementation of the three-dimensional linear motion mechanism, the difference between the calibrated height of the sampling port liquid level and the current position of the sampling port liquid level is greater than... At this time, the path compensation unit performs height compensation. The height compensation amount is the difference between the calibrated height of the liquid level at the sampling port and the current position of the liquid level at the sampling port. The maximum height compensation is The root mean square value of the drilling rig vibration acceleration data is less than or equal to... At that time, the stable waiting period is not extended; the root mean square value of the drilling rig vibration acceleration data is greater than 1. and less than or equal to At that time, the stable waiting period is extended. The root mean square value of the drilling rig vibration acceleration data is greater than 100%. and less than or equal to At that time, the stable waiting period is extended. The root mean square value of the drilling rig vibration acceleration data is greater than 100%. When the time is insufficient, the main control processing module determines whether the remaining time of the surface sampling period meets the requirement of waiting again. If the remaining time of the surface sampling period is insufficient, a sampling failure mark is generated.

[0060] The basic sampling control sequence is the default sampling control timing for a fixed sampling probe or valve-controlled sampling pump. The basic sampling control sequence consists of the initial state of the sampling valve group, the basic flow rate of the sampling pump, the pre-sampling flushing duration, the drilling fluid sample collection duration, the bypass discarding duration, and the backflushing trigger condition. When the sampling execution unit uses a fixed sampling probe or valve-controlled sampling pump, the path compensation unit modifies the basic sampling control sequence based on the sampling execution disturbance data and the sampling end status feedback data, generating a compensated sampling control path. The compensated sampling control path includes the sampling valve group state, the sampling pump flow rate state, the bypass discarding state, and the backflushing state. The sampling valve group state determines the connectivity between the fixed sampling probe and the sample collection channel, bypass discarding pipeline, or cleaning channel. The sampling pump flow rate state determines the sampling suction flow rate, the pre-sampling flushing flow rate, and the cleaning flow rate. The bypass discarding state discharges the pre-sampling flushing fluid, abnormal drilling fluid samples, and cleaning waste into the waste fluid collection path. The backflushing state is used to control the cleaning fluid or drilling fluid to pass through the fixed sampling probe inlet and sampling channel in the opposite direction to the direction of drilling fluid sample intake, so as to discharge the rock cuttings particles attached to the fixed sampling probe inlet or sampling channel.

[0061] Furthermore, in the fixed sampling probe implementation, the sampling pump inlet pressure fluctuation amplitude is greater than... and less than or equal to At that time, the path compensation unit extends the duration of the bypass abandonment state in the basic sampling control sequence. The sampling pump inlet pressure fluctuation amplitude is greater than When the path compensation unit triggers the backwash state, the backwash state lasts for a period of time. The sampling pump flow rate data is lower than the target sampling pump flow rate. And the sampling pump inlet pressure rises by more than At this time, the path compensation unit triggers the backwash state. When the sampling valve group's arrival data is inconsistent with the valve group's target state in the sampling trigger queue, the main control processing module prevents the drilling fluid sample from entering the detection channel and triggers the sample state interlocking module to generate a sample interception result. By compensating the sampling control path, the fixed sampling probe can still correct the sampling action based on the on-site disturbance and sampling end state feedback without spatial displacement.

[0062] The sampling execution unit includes a metering pump, a level detector, a sampling valve assembly, and a bypass discard line. The metering pump can be a plunger pump, peristaltic pump, diaphragm pump, or syringe pump. The level detector can be installed at the inlet of the sample cup, transparent detection section, buffer chamber, or sample vial. The sampling valve assembly includes a sample collection valve, a bypass discard valve, a cleaning fluid valve, a blank fluid valve, and a detection channel valve. The bypass discard line is used to discharge pre-sampling flushing fluid, abnormal drilling fluid samples, and cleaning waste to a permitted waste collection container on site. The main control processing module generates metering pump drive pulses based on the target sampling volume, level detection results, and sampling channel pressure changes. If the metering pump has already output a drive pulse corresponding to the target sampling volume, but the level detector has not reached the target level, the main control processing module determines that there is a risk of air leakage, air blockage, or insufficient sampling, and triggers the sample status interlock module to generate a sample interception result.

[0063] The preset release conditions are the judgment rules used by the sample status interlock module to determine whether a drilling fluid sample can enter the dual-channel chromatographic reconstruction module. The sample status interlock module receives sample status data corresponding to the drilling fluid sample. This data includes liquid level data, sampling channel pressure data, sampling channel temperature data, sample turbidity data, gas-liquid ratio data, pump pulse response data, and valve assembly positioning data. Liquid level data is used to confirm whether the drilling fluid sample volume has reached the minimum required for light hydrocarbon release detection and background interference detection. Sampling channel pressure data is used to determine if there is pipeline blockage, leakage, gas lock, or valve assembly misalignment. Sampling channel temperature data is used to determine if the drilling fluid sample is within the suitable temperature range for degassing and delivery. Sample turbidity data is used to determine if the solid particle content is too high. Gas-liquid ratio data can be obtained through transparent detection section images, pressure difference fluctuations, liquid level fluctuations, or photoelectric detection. Pump pulse response data is used to compare the correspondence between pump drive pulses and actual liquid level and pressure changes.

[0064] Furthermore, in one possible implementation, the preset release conditions include: the actual sampling volume corresponding to the liquid level data is greater than or equal to the target sampling volume. The fluctuation range of the sampling channel pressure data relative to the stable operating pressure of the sampling pump shall not exceed [the specified value]. The sampling channel temperature data is located between 15℃ and... The sample turbidity data should not exceed the upper limit of the on-site calibration turbidity. The upper limit of the on-site calibration turbidity can be set to... The liquid volume fraction in the gas-liquid ratio data is greater than or equal to... The deviation between the estimated sampling volume corresponding to the pump pulse response data and the actual sampling volume corresponding to the liquid level data shall not exceed [a certain value]. The valve group positioning data is consistent with the target valve group status in the sampling trigger queue. When the liquid level data and sampling channel pressure data meet the preset release conditions, and at least one of the sampling channel temperature data, sample turbidity data, gas-liquid ratio data, and pump pulse response data meets the preset release conditions, the sample status interlocking module outputs the sample release result. After receiving the sample release result, the main control processing module sends the sample release result to the dual-channel chromatographic reconstruction module and controls the injection valve to send the drilling fluid sample into the dual-channel chromatographic reconstruction module.

[0065] When the liquid level is insufficient, the pressure response is abnormal, the temperature does not meet the processing range, the turbidity is too high, the gas-liquid ratio is abnormal, the pump pulse response is missing, or the valve assembly is not in position, the sample status interlock module outputs the sample interception result. After receiving the sample interception result, the main control processing module controls the sampling valve assembly to connect the bypass discard pipeline to discharge the abnormal drilling fluid sample, and controls the pipeline cleaning assembly to perform cleaning. Pipeline cleaning may include cleaning fluid flushing, blank fluid replacement, compressed gas purging, and low flow rate maintenance. After cleaning is completed, the main control processing module performs blank fluid verification. Blank fluid verification is used to determine whether there are still residual peaks or pressure anomalies in the sampling channel and detection front end. If the blank fluid verification passes and the formation release synchronous sampling window still has remaining valid time, the main control processing module re-triggers sampling; if the formation release synchronous sampling window has expired, the main control processing module generates a sampling failure flag and writes the failure reason into the data packet.

[0066] The dual-channel chromatographic reconstruction module is used to generate light hydrocarbon chromatographic signals from drilling fluid samples of the same sampling batch and acquire background interference detection data corresponding to the same sampling batch. The same sampling batch refers to a set of drilling fluid samples triggered by the same formation release synchronous sampling window and possessing the same target depth label, the same sampling time label, or the same batch identifier. Background interference detection data corresponding to the same sampling batch refers to data from matrix background detection subsamples of the same sampling batch, or blank drilling fluid background detection data from the same circulation section, the same drilling fluid system, and bound to the same sampling batch by the main control processing module.

[0067] When using the same-batch background detection method, the sample splitting unit divides drilling fluid samples from the same sampling batch into light hydrocarbon release detection subsamples and matrix background detection subsamples. The light hydrocarbon release detection subsamples enter the light hydrocarbon release detection unit, where they undergo thermal degassing, vacuum degassing, membrane degassing, headspace degassing, or a combination of degassing to generate light hydrocarbon chromatographic signals. The matrix background detection subsamples enter the background interference detection unit to generate background interference detection data.

[0068] When using the blank drilling fluid background detection method, the sample splitting unit obtains light hydrocarbon release detection subsamples from drilling fluid samples of the same sampling batch. Outside the target formation release synchronous sampling window, the main control processing module selects a non-target formation release period, pre-sampling flushing period, or circulation stabilization period within the same circulation segment to collect blank drilling fluid samples from the same circulation segment, and binds these blank drilling fluid samples to the same sampling batch. These blank drilling fluid samples from the same circulation segment are not used as target formation light hydrocarbon release samples, but rather to generate background interference detection data. The main control processing module records the collection time, circulation status, background applicable marker, and bound batch identifier of the blank drilling fluid samples from the same circulation segment in the data packet.

[0069] The light hydrocarbon release detection unit may include a degassing chamber, a gas-liquid separation chamber, a carrier gas channel, a chromatographic column, a detector, and a chromatographic acquisition circuit. After the light hydrocarbon release sample enters the degassing chamber, the light hydrocarbon components are released from the drilling fluid into the carrier gas channel, and then enter the chromatographic column for separation. The light hydrocarbon chromatographic signal may include the retention time, peak height, peak area, and peak shape characteristics of methane, ethane, propane, isobutane, n-butane, isopentane, n-pentane, and higher carbon number light hydrocarbons. The background interference detection unit may employ residual matrix chromatography, three-dimensional fluorescence detection, or blank drilling fluid background detection. Background interference detection data does not require quantification of all background components; it only needs to indicate the location of interfering peaks, the width of interfering peaks, the intensity of background regions, and background source labels.

[0070] In residual matrix chromatography detection, the background interference detection unit performs a different pretreatment on the matrix background detection sample than that used for light hydrocarbon release detection. This process preserves the characteristic peaks of drilling fluid additives, oil-based components, or pipeline residues, resulting in the output of background interference chromatographic signals. Background interference chromatographic signals are a type of background interference detection data. Both background interference and light hydrocarbon chromatographic signals have retention time coordinates, allowing for peak start, peak apex, and peak end alignment on these coordinates. In three-dimensional fluorescence detection, the background interference detection unit dilutes or filters the matrix background detection sample used for three-dimensional fluorescence detection before introducing it into the fluorescence detection cell, outputting background fluorescence spectrum data composed of excitation wavelength, emission wavelength, and fluorescence intensity. Background fluorescence spectrum data is a type of background interference detection data. In blank drilling fluid background detection, the main control processing module collects blank drilling fluid samples from the same circulation segment outside the target formation release synchronous sampling window and binds the blank drilling fluid background detection data to the corresponding sampling batch. Blank drilling fluid background detection data is a type of background interference detection data.

[0071] The background feature mapping table is established using field calibration samples. The main control processing module selects calibration samples containing known drilling fluid additive backgrounds and performs light hydrocarbon release detection and background interference detection on the calibration samples respectively. The dual-channel chromatographic reconstruction module extracts the retention time segments from the light hydrocarbon chromatographic signals and extracts the background feature positions, background feature widths, and background segment intensities from the background interference detection data. When the background features in the same calibration sample repeatedly correspond to the light hydrocarbon chromatographic retention time segments in multiple batches, the main control processing module binds the background features to the retention time segments to form a background feature mapping table. During field operation, the retention window alignment unit converts the background interference detection data of the current batch into background indicators on the retention time segments according to the background feature mapping table. If the background feature mapping table does not cover the current background features, the main control processing module does not perform deterministic background subtraction but instead generates unknown background source labels and interference risk markers.

[0072] In the three-dimensional fluorescence detection method, a background feature mapping table records the correspondence between fluorescence features and light hydrocarbon chromatographic retention time segments. Fluorescence features include excitation wavelength, emission wavelength, fluorescence intensity peak, and fluorescence peak width. The retention window alignment unit converts the background fluorescence spectrum data into a background intensity curve along the retention time dimension based on the correspondence between fluorescence intensity peaks and light hydrocarbon chromatographic retention time segments in the background feature mapping table. The horizontal axis of the background intensity curve represents retention time, and the vertical axis represents the normalized background segment intensity. The retention window alignment unit extracts the background segment start point, background segment center point, and background segment end point from the background intensity curve. The background segment start point is the position where the background intensity curve first exceeds three times the background noise level; the background segment center point is the position where the background intensity curve reaches its maximum intensity; and the background segment end point is the position where the background intensity curve falls back below three times the background noise level.

[0073] The retention window alignment unit converts the light hydrocarbon chromatographic signal and background interference detection data to the same time base or the same retention window base. If the background interference detection data is a background interference chromatographic signal, the retention window alignment unit directly aligns the peak start point, peak apex, and peak end point in the light hydrocarbon chromatographic signal under the retention time coordinate, and extracts the background segment start point, background segment center point, and background segment end point from the background interference chromatographic signal. If the background interference detection data is background fluorescence spectrum data, the retention window alignment unit maps the background spectral features to the background indicator on the light hydrocarbon chromatographic retention window according to the on-site calibration sample, background feature mapping table, or historical batch correspondence, and then extracts the background segment start point, background segment center point, and background segment end point from the converted background interference detection data. The retention window alignment process includes time base calibration, peak start point extraction, peak apex extraction, peak end point extraction, background segment start point extraction, background segment center point extraction, background segment end point extraction, peak width matching, peak position shift correction, and channel baseline stability judgment.

[0074] The interference mask generation unit generates interference segment masks based on peak width overlap, peak position shift, background segment intensity, and channel baseline stability. The interference segment mask includes mask start time, mask end time, interference intensity level, interference source label, subtraction confidence level, and channel baseline status. The interference intensity level characterizes the degree of influence of background interference detection data on the light hydrocarbon chromatographic signal; interference intensity levels are categorized as weak, medium, and strong. The subtraction confidence level characterizes the reliability of background subtraction and peak shape correction results; subtraction confidence level is categorized as high, medium, and low.

[0075] Peak width overlap is used to determine the degree of coverage between the background region and the target light hydrocarbon peak in terms of retention time. Peak position shift is used to determine whether there is retention time drift between the light hydrocarbon release detection channel and the background interference detection channel. Background region intensity is used to determine whether the background interference has reached the level of affecting the light hydrocarbon peak area. Channel baseline stability is used to determine whether the background subtraction has a reliable basis.

[0076] The peak width overlap ratio is calculated using the following formula:

[0077] in, The peak width overlap ratio, The overlap length between the target light hydrocarbon peak and the background region on the retention time coordinate. The peak width of the target light hydrocarbon peak.

[0078] The signal-to-noise ratio of the background section is calculated using the following formula:

[0079] in, The signal-to-noise ratio of the background section. The maximum intensity of the background section. This represents the amplitude of the baseline noise in the background segment.

[0080] Channel baseline stability is calculated using the following formula:

[0081] in, For channel baseline stability, The standard deviation of the adjacent baselines in the background section. This represents the maximum intensity of the background section.

[0082] When the peak width overlap ratio Greater than or equal to Background section signal-to-noise ratio Greater than or equal to And channel baseline stability Less than or equal to At that time, the interference mask generation unit determines the corresponding retention time segment as the interference segment. The start and end times of the interference segment mask are determined according to the following formula:

[0083] in, The start time of the interference segment mask. The starting time of the target light hydrocarbon peak. The starting time of the background segment, The peak width of the target light hydrocarbon peak. This indicates the later time between the target light hydrocarbon peak start time and the background section start time. This is the expansion factor that extends the peak width of the target light hydrocarbon peak forward.

[0084]

[0085] in, The end time of the interference segment mask. The endpoint time of the target light hydrocarbon peak. The end time of the background segment. The peak width of the target light hydrocarbon peak. This indicates the earlier of the target light hydrocarbon peak endpoint time and the background section endpoint time. This is the expansion factor that extends the peak width of the target light hydrocarbon peak backward.

[0086] The start time of the interference section mask must not be earlier than the start time of the target light hydrocarbon peak, and the end time of the interference section mask must not be later than the end time of the target light hydrocarbon peak.

[0087] When the signal-to-noise ratio of the background section Greater than or equal to and less than At that time, the interference intensity level was weak interference. When the signal-to-noise ratio of the background section Greater than or equal to and less than At that time, the interference intensity level was medium interference intensity; When the signal-to-noise ratio of the background section Greater than or equal to At that time, the interference intensity level was strong interference intensity.

[0088] When the peak width overlap ratio Greater than or equal to Channel baseline stability Less than or equal to And the peak position shift does not exceed When the confidence level is high, the subtraction confidence level is used. When the peak width overlap ratio Greater than or equal to and less than Or channel baseline stability Greater than and less than or equal to When the confidence level is reduced, the confidence level is reduced to the middle confidence level. When the channel baseline is stable Greater than Or peak position shift exceeds At this point, the deduction confidence level is low. The interference segment mask corresponding to the low deduction confidence level does not trigger deterministic background deduction, but only triggers interference risk marking.

[0089] The concentration reconstruction unit reconstructs the light hydrocarbon chromatographic signal using an interference segment mask. Within the retention time range not indicated by the interference segment mask, the concentration reconstruction unit retains the effective peak shape of the light hydrocarbon chromatographic signal and performs baseline correction, peak area calculation, and concentration conversion. An effective peak shape refers to a light hydrocarbon chromatographic peak shape that is not indicated by the interference segment mask and whose peak initiation, peak apex, peak end, and channel baseline stability meet the peak area calculation requirements. Within the retention time range indicated by the interference segment mask, the concentration reconstruction unit performs background subtraction, local baseline correction, peak area verification, and interference risk labeling. If the background interference detection data has a high subtraction confidence level with the light hydrocarbon chromatographic signal, the concentration reconstruction unit performs bounded correction on the target light hydrocarbon peak area according to the relationship between the background segment intensity and peak shape; if the subtraction confidence level is low, the concentration reconstruction unit does not output a deterministic correction value, but instead outputs corrected target light hydrocarbon concentration data with an interference risk label. This processing avoids mistaking unreliable background peaks as true formation light hydrocarbon peaks and also avoids unconstrained subtraction of the entire light hydrocarbon chromatographic signal.

[0090] The sample status label, generated from sample release results, sample interception results, and sample status data, is used to mark the validity of the drilling fluid sample in correcting the target light hydrocarbon concentration data. The channel status label records the communication status, baseline status, and reserved window alignment status of the light hydrocarbon release detection unit and the background interference detection unit. The formation release synchronous sampling window reliability label, generated from the formation release synchronous sampling window reliability, indicates whether the formation release synchronous sampling window corresponding to the corrected target light hydrocarbon concentration data is reliable. The main control processing module encapsulates the corrected target light hydrocarbon concentration data along with the target depth label, sampling time label, formation release synchronous sampling window reliability label, sample status label, channel status label, interference segment mask, and sampling trigger queue.

[0091] The traceability packet unit generates a unique batch identifier for each sampling batch. This unique batch identifier is associated with drilling status data, cyclic carryover status data, wellbore return lag data, formation release synchronous sampling window, sampling trigger queue, pose-compensated sampling path or compensated sampling control path, sample status data, sample release results, sample interception results, light hydrocarbon chromatographic signals, background interference detection data, interference section mask, and corrected target light hydrocarbon concentration data. Data packets can be stored in a local database, a well logging interpretation system, a remote data center, or a write-once log storage unit. Data packets can record data transmission relationships and reconstruction constraints under different sensor and instrument conditions, facilitating the verification of sampling batches, drilling fluid sample status, and test results.

[0092] The control status monitoring unit periodically reads the communication status, execution status, and abnormal status of the drilling operation synchronization module, the pose compensation sampling execution module, the sample status lockout module, and the dual-channel chromatographic reconstruction module. If the drilling operation synchronization module communication is interrupted, the light hydrocarbon logging field automatic sampling data acquisition and control system switches to conservative sampling mode. If the pose compensation sampling execution module malfunctions, the light hydrocarbon logging field automatic sampling data acquisition and control system stops physical sampling and outputs a sampling execution abnormality tag. If the sample status lockout module malfunctions, the light hydrocarbon logging field automatic sampling data acquisition and control system prohibits drilling fluid samples from entering the detection channel. If the dual-channel chromatographic reconstruction module malfunctions, the light hydrocarbon logging field automatic sampling data acquisition and control system retains the original light hydrocarbon chromatographic signal but outputs a channel abnormality tag and a mark that cannot be used for interpretation and evaluation. The control status monitoring unit can generate corresponding abnormal tags when there are module communication abnormalities, sampling execution abnormalities, sample lockout abnormalities, and detection channel abnormalities, and prevent abnormal drilling fluid samples or abnormal data from entering the normal interpretation process.

[0093] In this embodiment, a continuous technical chain is formed between underground release events, surface sampling actions, drilling fluid sample validity assessment, and light hydrocarbon chromatographic signal reconstruction. The formation release synchronous sampling window is generated from drilling status data, circulation carryover status data, and wellbore return hysteresis data, and is actually used by the main control processing module to generate the sampling trigger queue. The sampling trigger queue drives the pose-compensated sampling execution module to perform physical sampling. The drilling fluid sample output by the pose-compensated sampling execution module enters the sample status locking module. The sample release result determines whether the dual-channel chromatographic reconstruction module performs detection and reconstruction. The corrected target light hydrocarbon concentration data output by the dual-channel chromatographic reconstruction module is then bound to depth, time, and channel status by the traceability encapsulation unit. Each intermediate result is used by subsequent processes, avoiding isolated data acquisition and judgment without a source.

[0094] Example 2: This example is basically the same as Example 1, except that the pose compensation sampling execution module does not use a three-dimensional linear motion mechanism, but instead uses a fixed sampling probe, a variable frequency sampling pump, a sampling valve assembly, and a bypass discard pipeline. The fixed sampling probe is installed in the stable fluid zone or buffer tank of the drilling fluid outlet pipeline, with the inlet of the fixed sampling probe facing the lateral area of ​​the mainstream direction to reduce the probability of large rock cuttings directly impacting the sampling port. The main control processing module controls the sampling valve assembly according to the formation release synchronous sampling window. Before the surface sampling period arrives, the sampling valve assembly remains in bypass discard state, and the variable frequency sampling pump flushes the sampling channel at a low flow rate; at the start of the surface sampling period, the sampling valve assembly switches to the sample collection channel, and the variable frequency sampling pump operates according to the target sampling volume; after the surface sampling period ends, the sampling valve assembly switches back to the bypass discard pipeline. The fixed sampling probe implementation eliminates the spatial movement of the motion mechanism, but the physical sampling action is still controlled by the formation release synchronous sampling window.

[0095] In the fixed sampling probe implementation, the sampling execution disturbance data no longer primarily consists of three-dimensional coordinate disturbances, but rather of fluctuations in the sampling pump inlet pressure, sampling flow rate, outlet fluid level, pump current, and valve assembly positioning. The main control processing module uses this disturbance data to determine whether the drilling fluid flow is suitable for drilling fluid sample collection. When the inlet pressure experiences periodic large fluctuations, the main control processing module determines that there may be a gas-liquid slug near the sampling port; when the pump current increases and the sampling flow rate decreases, the main control processing module determines that the fixed sampling probe or sampling pipeline may be blocked by cuttings; when the valve assembly is not in position, the main control processing module prohibits the drilling fluid sample from entering the detection channel. At this time, the compensated sampling control path consists of the sampling valve assembly status, sampling pump flow rate status, bypass sample rejection status, and backflushing status, which can replace the pose-compensated sampling path in the three-dimensional linear motion mechanism implementation.

[0096] In some preferred embodiments, the wellbore return hysteresis data does not entirely depend on wellbore geometry and pump displacement data. The wellbore return hysteresis data can be corrected in the field using tracer pulses. The tracer pulses can be within safe limits of conductivity changes, temperature perturbations, sudden pump displacement responses, engineering-known cyclic state changes, or background responses detectable at the surface. The main control processing module records the time the tracer pulse enters the wellbore circulation system and updates the wellbore return hysteresis data after observing the corresponding response at the surface sampling port, outlet flow interface, or detection channel. After tracer pulse correction is complete, the main control processing module recalculates the subsequent formation release synchronization sampling window and writes the change in the formation release synchronization sampling window before and after correction into the system control log. This extended implementation is suitable for extended reach wells, horizontal wells, wellbore enlargement, complex wellbore trajectories, or conditions with frequent pump displacement adjustments.

[0097] In some preferred embodiments, the wellbore return lag data is obtained by correcting for historical gas logging peak offsets. The main control processing module reads gas logging peaks, cuttings indications, or drilling response events with a clear depth source in the drilled section, compares the theoretical return time corresponding to the formation depth of the event with the center time of the surface detection peak, and obtains historical gas logging peak offset data. The main control processing module uses the historical gas logging peak offset data as the source data for lag correction to correct the formation release synchronous sampling window for subsequent target depth segments. If the historical gas logging peak offset exhibits segmented characteristics with changes in pump displacement, the main control processing module writes the offset values ​​corresponding to different displacement ranges into the lag correction table respectively. The light hydrocarbon logging field automatic sampling data acquisition and control system can improve the reliability of the formation release synchronous sampling window when there are errors in the wellbore geometry data or the wellbore enlargement is not fully measured.

[0098] In some preferred embodiments, background interference detection data is generated by a three-dimensional fluorescence background detection channel. The sample splitting unit splits drilling fluid samples from the same sampling batch into light hydrocarbon release detection subsamples and matrix background detection subsamples for three-dimensional fluorescence detection. The light hydrocarbon release detection subsamples are degassed and separated to generate light hydrocarbon chromatographic signals. The matrix background detection subsamples for three-dimensional fluorescence detection are diluted, filtered, or allowed to stand before entering the fluorescence detection cell. The background interference detection unit outputs background fluorescence spectrum data composed of excitation wavelength, emission wavelength, and fluorescence intensity. The dual-channel chromatographic reconstruction module converts the background fluorescence spectrum data into background intensity curves on retention time segments according to a background feature mapping table, and then the interference mask generation unit generates an interference segment mask. This extended implementation is suitable for situations where drilling fluid additives have fluorescence responses, and also for scenarios where background peaks are inconvenient to detect directly using the same chromatographic column.

[0099] In some preferred embodiments, background interference detection data is generated from a blank drilling fluid background channel. Outside the target formation release synchronous sampling window, the main control processing module selects adjacent non-target depth segments, circulation stabilization segments, or pre-sampling flushing segments to collect blank drilling fluid samples from the same circulation segment. These blank drilling fluid samples from the same circulation segment are not used to evaluate the release of light hydrocarbons from the target formation, but rather to generate background interference detection data. A dual-channel chromatographic reconstruction module compares the light hydrocarbon chromatographic signals of the target sampling batch with the blank drilling fluid background detection data, generating an interference segment mask within the same retention window. This extended implementation is suitable for field applications where sufficient matrix background detection subsamples cannot be separated from the same sampling batch. To avoid excessive time intervals between the blank drilling fluid background detection data and the target sampling batch, the main control processing module records the collection time, circulation status, and background applicability markers of the blank drilling fluid samples from the same circulation segment in the data packet.

[0100] In some preferred embodiments, the background interference detection unit employs residual matrix chromatography. The light hydrocarbon release detection sample is treated with degassing conditions suitable for releasing light hydrocarbon components in the methane to pentane range, while the matrix background detection sample is treated with pretreatment conditions suitable for retaining or releasing characteristic components of drilling fluid additives. The dual-channel chromatographic reconstruction module does not require the background interference detection unit to output the exact same component concentrations as the light hydrocarbon release detection unit, but rather requires the background interference detection unit to output background peak positions, peak widths, and intensity regions that can be mapped to the light hydrocarbon chromatographic retention window. Thus, the background interference detection data becomes a constraint variable for light hydrocarbon chromatographic signal reconstruction, adaptable to different chromatographic instrument models and column selections.

[0101] In some preferred embodiments, the main control processing module sets up multi-level anomaly handling logic. Level 1 anomalies are data missing anomalies, which do not directly affect the sampling hardware execution but do affect the reliability of the formation release synchronous sampling window. Level 1 anomalies include short-term loss of drilling pump displacement data, winch encoder data jumps, and logging data bus communication delays. Level 2 anomalies are sampling execution anomalies, which affect the validity of drilling fluid samples. Level 2 anomalies include sampling pump pressure non-response, sampling valve assembly not in position, excessive execution end position deviation, and suspected blockage of the fixed sampling probe. Level 3 anomalies are detection channel anomalies, which affect the validity of corrected target light hydrocarbon concentration data. Level 3 anomalies include excessive baseline drift of the light hydrocarbon release detection unit, no response from the background interference detection unit, and misalignment of the two channel retention windows. For Level 1 anomalies, the main control processing module uses the most recent valid data to generate a conservative sampling trigger queue and marks the reliability of the formation release synchronous sampling window. For Level 2 anomalies, the main control processing module stops the current sample release and performs bypass sample abandonment, pipeline cleaning, or backflushing. For Level 3 anomalies, the main control processing module outputs corrected target light hydrocarbon concentration data with an anomaly label, or marks the current batch as unusable for interpretation and evaluation.

[0102] In some preferred embodiments, the corrected target light hydrocarbon concentration data is fed back to the sampling scheduling program. If the corrected target light hydrocarbon concentration data of three consecutive sampling batches at the same target depth are all higher than the previous sampling batch, and the interference intensity level corresponding to the interference section mask is weak, the feedback scheduling unit increases the sampling priority of adjacent depth sections. If the interference intensity level corresponding to the interference section mask is medium, the feedback scheduling unit increases the frequency of background interference detection. If the interference intensity level corresponding to the interference section mask is strong, the feedback scheduling unit increases the frequency of pipeline cleaning and prompts on-site personnel to check changes in drilling fluid additives. In this way, the dual-channel chromatographic reconstruction results are not only used for display but can also influence subsequent sampling control.

[0103] In some preferred embodiments, the automatic sampling data acquisition and control system for light hydrocarbon logging includes a sample bottle delivery and sealing mechanism. After sample release, the main control module controls the sample bottle delivery mechanism to move the empty bottle to the injection position. After injection, it reads the bottle position detection data and sealing torque data. After sealing, the traceability sealing unit binds the sample bottle number to the data packet. If the sample bottle is not in place or the sealing torque is abnormal, the sample status interlocking module outputs a sample interception result or a sample sealing anomaly marker. The sample bottle delivery and sealing mechanism improves unattended sampling and subsequent verification capabilities.

[0104] In some preferred embodiments, the light hydrocarbon logging field automatic sampling data acquisition and control system includes a human-machine interface (HMI). The HMI displays the current drill bit depth, pump displacement, formation release synchronous sampling window, sampling trigger queue, execution status of the pose-compensated sampling path or compensation sampling control path, sample status lockout result, light hydrocarbon chromatographic signal, background interference detection data, interference section mask, and corrected target light hydrocarbon concentration data. The HMI displays not only the concentration curve but also the formation release synchronous sampling window reliability label, sample status label, and channel status label for each concentration point. When a concentration point experiences decreased reliability of the formation release synchronous sampling window, abnormal drilling fluid sample status, or background interference risk, the HMI uses different graphic markers to alert the logging interpreter. This display method helps prevent the misuse of low-reliability data as normal oil and gas display data.

[0105] In some preferred embodiments, the traceability packet unit uses an overwriteable log, hash check, electronic signature, or write-once log storage unit to store key control data. The data packet includes batch identifier, target depth label, sampling time label, formation release synchronous sampling window reliability, sampling trigger queue, pose-compensated sampling path or compensated sampling control path, sample status data, sample release result, sample interception result, light hydrocarbon chromatographic signal, background interference detection data, interference segment mask, corrected target light hydrocarbon concentration data, and abnormal status label. This packet method facilitates subsequent determination of whether a specific corrected target light hydrocarbon concentration has passed through the formation release synchronous sampling window control, whether sample status locking exists, and whether reconstruction using an interference segment mask has been performed.

[0106] In some preferred embodiments, the main control processing module includes access control and a manual confirmation interface. The manual confirmation interface allows logging engineers to input wellbore return hysteresis correction values, sampling port maintenance status, drilling fluid additive change events, and sensor maintenance events. The main control processing module treats the manual confirmation input as correction input data or background source labels for logging engineers, rather than directly replacing automatic judgment. If the manual confirmation input contradicts the sensor data, the main control processing module writes a manual input conflict flag into the data packet and reduces the reliability of the formation release synchronous sampling window or channel status. The light hydrocarbon logging field automatic sampling data acquisition and control system allows for the intervention of field experience while avoiding unrecorded changes to the target light hydrocarbon concentration data by manual input.

[0107] In some preferred embodiments, the automatic sampling data acquisition and control system for light hydrocarbon logging sites is equipped with explosion-proof isolation and safety interlocks. The sampling execution unit, sampling valve assembly, metering pump, and sensors can be arranged in an explosion-proof box, isolation cabinet, or safe area. The main control processing module reads the status of the explosion-proof door, grounding status, power supply status, and combustible gas alarm status. When the safety interlock is not met, the main control processing module prohibits the sampling execution unit from starting, prohibits the sampling valve assembly from connecting to the detection channel, and outputs a safety interlock abnormality flag. The safety interlock does not change the light hydrocarbon chromatographic signal reconstruction logic, but enables the automatic sampling data acquisition and control system for light hydrocarbon logging sites to adapt to the safety requirements of the logging site.

[0108] In some preferred embodiments, the automatic sampling data acquisition and control system for light hydrocarbon logging can be connected to an existing integrated logging instrument. The integrated logging instrument provides drilling status data, circulation carryover status data, raw gas logging data, and engineering parameter data. The automatic sampling data acquisition and control system for light hydrocarbon logging can be used as an external control unit for the integrated logging instrument or integrated within it. Regardless of whether an external or integrated approach is used, as long as the main control processing module can receive drilling status data, circulation carryover status data, and wellbore return hysteresis data, and generate a sampling trigger queue, a pose-compensated sampling path or a compensated sampling control path, sample status lockout results, and interference section masks according to the process of this invention, it falls under the embodiments of this invention.

[0109] Although preferred embodiments of the invention have been described, those skilled in the art, upon learning the basic inventive concept, can make other changes and modifications to these embodiments. Therefore, the appended claims are intended to be interpreted as including both the preferred embodiments and all changes and modifications falling within the scope of the invention.

[0110] The above description is merely a preferred embodiment of the present invention and is not intended to limit the present invention. It should be noted that any modifications, equivalent substitutions, and improvements made within the spirit and principles of the present invention should be included within the protection scope of the present invention.

Claims

1. A light hydrocarbon logging field automatic sampling data acquisition and control system, characterized in that, It includes a main control processing module and a drilling condition synchronization module, a pose compensation sampling execution module, a sample status locking module, and a dual-channel chromatographic reconstruction module, all of which are connected to the main control processing module. The drilling status synchronization module receives drilling status data, circulating carry status data, and wellbore return lag data. It converts the drilling status data, circulating carry status data, and wellbore return lag data into a formation release synchronization sampling window and sends the formation release synchronization sampling window to the main control processing module. The formation release synchronization sampling window includes the formation release synchronization sampling window start time, formation release synchronization sampling window end time, target depth label, and formation release synchronization sampling window reliability. The main control processing module generates a sampling trigger queue containing the surface sampling period according to the formation release synchronous sampling window, and sends the sampling trigger queue to the pose compensation sampling execution module. The pose compensation sampling execution module receives sampling execution disturbance data, receives execution end position feedback data when a three-dimensional linear motion mechanism is used, and receives sampling end status feedback data when a fixed sampling probe is used. During the surface sampling period, it generates a pose compensation sampling path or a compensation sampling control path and collects drilling fluid samples according to the pose compensation sampling path or the compensation sampling control path. The pose compensation sampling execution module sends the drilling fluid sample into the detection flow path of the sample state locking module, and sends the sample state data corresponding to the drilling fluid sample to the sample state locking module through the main control processing module. The sample status interlocking module outputs a sample release result or a sample interception result based on the sample status data, and returns the sample release result or the sample interception result to the main control processing module; The main control processing module sends the sample release result to the dual-channel chromatographic reconstruction module and controls the injection valve to send the drilling fluid sample corresponding to the sample release result into the dual-channel chromatographic reconstruction module; After receiving the sample release result, the dual-channel chromatographic reconstruction module generates a light hydrocarbon chromatographic signal for the drilling fluid sample of the same sampling batch and acquires the background interference detection data corresponding to the same sampling batch. The light hydrocarbon chromatographic signal and the background interference detection data are aligned with the retention window to obtain the interference segment mask. The interference segment mask is then used to perform background subtraction, peak shape correction and interference risk marking on the retention time segment of the light hydrocarbon chromatographic signal indicated by the interference segment mask, and outputs the corrected target light hydrocarbon concentration data.

2. The automatic sampling data acquisition and control system for light hydrocarbon logging as described in claim 1, characterized in that, The drilling condition synchronization module includes a depth-time analysis unit, a footage pulse analysis unit, and a cycle status analysis unit. The depth-time analysis unit extracts drilling depth-time data from the logging data bus, the drilling depth interface, or the field depth database. The footage pulse analysis unit extracts footage change data from the winch encoder, the top drive position sensor, or the drilling depth interface. The cycle status analysis unit extracts the cycle-carried status data from the drilling pump displacement meter, the pump pulse counter, the riser pressure interface, the outlet flow interface, or the pump displacement setting interface.

3. The automatic sampling data acquisition and control system for light hydrocarbon logging as described in claim 1, characterized in that, The main control processing module includes a hysteresis correction sampling scheduling unit; the hysteresis correction sampling scheduling unit generates wellbore return hysteresis data based on wellbore geometric data, the circulating carry-over status data, sampling port location data, and hysteresis correction source data, and maps the formation release time period corresponding to the drilled formation depth interval to the surface sampling time period. The hysteresis correction source data includes at least one of tracer pulse arrival data, historical gas logging peak offset data, and logging engineer correction input data.

4. The automatic sampling data acquisition and control system for light hydrocarbon logging as described in claim 3, characterized in that, The hysteresis correction sampling scheduling unit imposes an upper limit constraint on the maximum allowable interval between adjacent valid sampling batches, an upper limit constraint on the minimum execution interval between adjacent sampling actions, and performs merging processing on adjacent formation release synchronous sampling windows. When the drilling status data, the cyclic carry-over status data, or the hysteresis correction source data are missing, the hysteresis correction sampling scheduling unit generates a conservative sampling trigger queue based on the most recent valid wellbore return hysteresis data, and writes a missing data marker and a formation release synchronous sampling window reliability reduction marker in the system control log.

5. The automatic sampling data acquisition and control system for light hydrocarbon logging as described in claim 1, characterized in that, The pose-compensated sampling execution module includes a disturbance acquisition unit, a path compensation unit, and a sampling execution unit. The disturbance acquisition unit receives at least one of the following: drilling platform vibration acceleration data, actuator encoder residual data, sampling port fluid level position data, servo current fluctuation data, and sampling channel pressure fluctuation data. When the sampling execution unit uses a three-dimensional linear motion mechanism, the path compensation unit corrects the basic sampling coordinates based on the sampling execution disturbance data and the actuator position feedback data, generating the pose-compensated sampling path, which includes an approach path, a stable waiting section, a sampling suction section, and a withdrawal path. When the sampling execution unit uses a fixed sampling probe or a valve-controlled sampling pump, the path compensation unit corrects the basic sampling control sequence based on the sampling execution disturbance data and the sampling end status feedback data, generating the compensated sampling control path, which includes the sampling valve group status, sampling pump flow status, bypass sample rejection status, and backflushing status. The sampling execution unit completes the drilling fluid sample acquisition according to the pose-compensated sampling path or the compensated sampling control path.

6. The automatic sampling data acquisition and control system for light hydrocarbon logging as described in claim 5, characterized in that, The sampling execution unit includes a metering pump, a level detector, a sampling valve assembly, and a bypass waste pipe. The main control processing module generates a drive pulse for the metering pump based on the target sampling volume, the level detection result, and the pressure change result of the sampling channel. The sampling valve assembly connects the sample collection channel during the surface sampling period and connects the bypass waste pipe outside the surface sampling period. When the sampling execution unit collects the drilling fluid sample using a fixed sampling probe, the main control processing module controls the connection status of the sampling valve assembly, the metering pump, and the bypass waste pipe according to the compensated sampling control path.

7. The automatic sampling data acquisition and control system for light hydrocarbon logging as described in claim 1, characterized in that, The sample status interlocking module receives at least liquid level data and sampling channel pressure data, and receives at least one of sampling channel temperature data, sample turbidity data, gas-liquid ratio data, and pump pulse response data. When the sample status data meets the preset release conditions, the sample status interlocking module outputs the sample release result; when the sample status data does not meet the preset release conditions, the sample status interlocking module outputs the sample interception result.

8. The automatic sampling data acquisition and control system for light hydrocarbon logging as described in claim 7, characterized in that, After receiving the sample interception result, the main control processing module controls the pose compensation sampling execution module to perform bypass sample rejection, pipeline cleaning, and blank liquid verification. After completing the blank liquid verification, the module decides to resample or generate a sampling failure flag based on the remaining duration of the formation release synchronous sampling window, the reliability of the formation release synchronous sampling window, and the sampling execution status.

9. The automatic sampling data acquisition and control system for light hydrocarbon logging as described in claim 1, characterized in that, The dual-channel chromatographic reconstruction module includes a sample splitting unit, a light hydrocarbon release detection unit, and a background interference detection unit. When using the same batch background detection method, the sample splitting unit splits the drilling fluid sample from the same sampling batch into light hydrocarbon release detection subsample and matrix background detection subsample. When using the blank drilling fluid background detection method, the sample splitting unit obtains light hydrocarbon release detection sub-samples from the drilling fluid samples of the same sampling batch, and the main control processing module binds the blank drilling fluid samples of the same circulation section to the same sampling batch. The light hydrocarbon release detection unit degasses and separates the light hydrocarbon release detection sample and generates the light hydrocarbon chromatographic signal. The background interference detection unit performs background detection on the matrix background detection sample or the blank drilling fluid sample of the same circulation section bound to the same sampling batch and generates the background interference detection data. The background detection includes at least one of residual matrix chromatographic detection, three-dimensional fluorescence detection and blank drilling fluid background detection.

10. The automatic sampling data acquisition and control system for light hydrocarbon logging as described in claim 9, characterized in that, The dual-channel chromatographic reconstruction module includes a window alignment unit and an interference mask generation unit. The retention window alignment unit converts the light hydrocarbon chromatographic signal and the background interference detection data to the same time reference or the same retention window reference, extracts the peak start point, peak apex and peak end point from the light hydrocarbon chromatographic signal, and extracts the background segment start point, background segment center point and background segment end point from the converted background interference detection data; The interference mask generation unit generates the interference segment mask based on the peak width overlap relationship, peak position offset relationship, background segment intensity relationship, and channel baseline stability.

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