A method and system for phase detection of reservoir fluids

Abstract

The present invention relates to the technical field of fluid detection, and specifically to a method and system for phase state detection of reservoir fluids, comprising the following steps: Based on the multi-point temperature and pressure sampling data of reservoir fluids, pressure, temperature and volume parameters are extracted, a gas-liquid ratio sensor is called to record the change of the gas-liquid ratio, the pressure and volume data are matched point by point, and the change trend of the gas-liquid ratio is calculated through time series to generate a dynamic dataset of the gas-liquid ratio. In the present invention, various data are extracted through temperature and pressure sampling, the gas-liquid ratio is recorded in combination with the gas-liquid ratio sensor, the multi-dimensional monitoring ability of the fluid state is improved, the analysis depth of the change law of the gas-liquid ratio is enhanced by comparing the change rate of the gas-liquid ratio with the pressure and volume parameters, the identification of the multi-phase region boundary under complex environments is optimized by combining the pressure gradient and volume characteristics, and the states of the gas-liquid two-phase and multi-phase regions are characterized through the correlation analysis of the pressure gradient and gas-liquid ratio data, providing comprehensive support for the dynamic monitoring of reservoir fluids and the analysis of phase state distribution.

Description

Technical Field

[0001] The present invention relates to the technical field of fluid detection, and particularly to a method and system for detecting the phase state of reservoir fluids. Background Art

[0002] The technical field of fluid detection involves the detection and analysis of the physical properties and chemical compositions of various fluids. The core content of this technical field includes measuring parameters such as pressure, temperature, density, viscosity, and component ratios of fluids through instrument equipment and detection methods to accurately obtain the basic properties and state information of fluids. Fluid detection technology is widely applied in scenarios such as industrial production, oil and gas extraction, and chemical processes, mainly involving specific links such as collecting fluid samples, testing fluid states, and analyzing fluid components, and usually completing the comprehensive detection and evaluation of fluids through means such as instrumental analysis, sample processing, and physical property testing.

[0003] Among them, the method for detecting the phase state of reservoir fluids refers to the technical means for analyzing the phase state of reservoir fluid samples. This patent theme targets multiphase fluids in reservoirs and determines their specific phase state characteristics by measuring fluid pressure, temperature, and their component ratios. Specifically, after collecting samples using oil and gas sample collection equipment, pressure and temperature are adjusted through experimental devices and measurement methods to construct different phase state environments, and each component in the oil and gas mixture is separated and quantitatively analyzed to determine its phase state distribution characteristics under specific conditions.

[0004] The prior art mainly constructs a phase state environment through single-point sampling and single pressure and temperature adjustment, making it difficult to cope with the multi-point and multi-dimensional dynamic characteristics in complex reservoirs, resulting in an incomplete description of the overall state of the fluid; in the study of gas-liquid ratio changes, usually only relying on static parameter measurements, ignoring the dynamic change characteristics of the gas-liquid ratio under changes in pressure and volume conditions, making it difficult to reflect the true distribution characteristics of the fluid in a complex environment; for the identification of gas-liquid two-phase conversion points and phase state segmentation points, the prior art mostly relies on experimental analysis under fixed conditions, lacking the analysis of distribution regions under multi-dimensional gradient conditions and unable to accurately locate the boundaries of multiphase regions; in the analysis of multiphase regions, the prior art relies on separation experiments and component analysis for single-point determination, lacking the induction of dynamic cooperation characteristics under multi-point conditions and making it difficult to effectively reveal the overall distribution law of multiphase states. These deficiencies make it difficult for the prior art to provide comprehensive fluid state detection and phase state distribution characteristic analysis in complex reservoir environments, restricting its actual application effect. Summary of the Invention

[0005] The object of the present invention is to solve the deficiencies existing in the prior art and propose a method and system for detecting the phase state of reservoir fluids.

[0006] To achieve the above object, the present invention adopts the following technical solution: A method for detecting the phase state of oil and gas reservoir fluids, comprising the following steps:

[0007] S1: Based on the multi-point temperature and pressure sampling data of the oil and gas reservoir fluids, extract the pressure, temperature and volume parameters, call the gas-liquid ratio sensor to record the change of the gas-liquid ratio, match the pressure and volume data point by point, calculate the change trend of the gas-liquid ratio through time series, and generate a dynamic gas-liquid ratio data set;

[0008] S2: Based on the dynamic gas-liquid ratio data set, compare the change rate of the gas-liquid ratio with the pressure and volume parameters item by item, calculate the pressure and volume differences, screen the change characteristic points and extract the gas-liquid ratio intervals, mark the change ranges and the initial phase state evolution regions point by point, and generate the change characteristic range of the gas-liquid ratio;

[0009] S3: Based on the change characteristic range of the gas-liquid ratio, extract the fluid distribution paths under different pressure gradients, combine the pressure and volume parameters to calculate the change rate of the gas-liquid ratio, screen the distribution regions and locate the gas-liquid two-phase conversion points, and extract the phase state segmentation points through the change amplitude to generate the fluid phase state conversion critical point data;

[0010] S4: Based on the fluid phase state conversion critical point data, call the pressure and volume characteristic ranges, calculate the influence of the pressure gradient on the change of the gas-liquid ratio point by point, screen the pressure distribution range and volume values in the transition region, combine the multi-point data to generate the multi-phase characteristic distribution trend of the fluid, and obtain the characteristic data of the phase state conversion region;

[0011] S5: Based on the characteristic data of the phase state conversion region, classify and mark the pressure and gas-liquid ratio distribution ranges, extract the distribution boundaries and change trends segment by segment, summarize the correlation characteristics of the pressure and volume in the multi-phase regions, and combine the boundary ranges to generate the distribution states of the gas-liquid two-phase and multi-phase regions, and generate the fluid phase state distribution results.

[0012] As a further solution of the present invention, the dynamic gas-liquid ratio data set includes pressure parameters, temperature parameters, volume parameters, gas-liquid ratio change values, and time series trend data. The change characteristic range of the gas-liquid ratio includes the gas-liquid ratio change rate range, pressure change interval, volume change interval, gas-liquid ratio characteristic points, and phase state evolution boundaries. The fluid phase state conversion critical point data includes the positions of the gas-liquid two-phase conversion points, phase state segmentation point parameters, pressure gradient intervals, and volume characteristic intervals. The characteristic data of the phase state conversion region includes the pressure characteristics in the transition region, gas-liquid ratio characteristic intervals, multi-phase distribution trends, and associated volume characteristics. The fluid phase state distribution results include the gas-liquid two-phase distribution range, multi-phase distribution range, pressure distribution characteristics, volume distribution characteristics, and boundary correlation characteristics.

[0013] As a further solution of the present invention, based on the multi-point temperature and pressure sampling data of the reservoir fluid, pressure, temperature and volume parameters are extracted, the gas-liquid ratio sensor is called to record the gas-liquid ratio change, the pressure and volume data are matched point by point, and the gas-liquid ratio change trend is calculated through time series. The specific steps for generating the gas-liquid ratio dynamic data set are as follows:

[0014] S101: Based on the multi-point temperature and pressure sampling data of the reservoir fluid, pressure, temperature and volume parameters are extracted, the sampling data is sorted according to the time series, the pressure and volume parameters are extracted and matched point by point, and joint processing is performed according to time to generate a pressure-volume matching data set;

[0015] S102: Based on the pressure-volume matching data set, the gas-liquid ratio sensor is called to record the gas-liquid ratio change, the gas-liquid ratio data is calibrated to the corresponding pressure-volume points according to the time series, and synchronous correlation processing is performed on the gas-liquid ratio data and the matching data set to form a gas-liquid ratio change mapping data set;

[0016] S103: Based on the gas-liquid ratio change mapping data set, the gas-liquid ratio change trend data is extracted according to the time series, and correlation analysis is performed using the trend change value and the time parameter to generate a gas-liquid ratio dynamic data set.

[0017] As a further solution of the present invention, based on the gas-liquid ratio dynamic data set, the gas-liquid ratio change rate is compared item by item with the pressure and volume parameters, the pressure and volume differences are calculated, the change characteristic points are screened and the gas-liquid ratio intervals are extracted, and the change range and the initial region of phase evolution are marked point by point to generate the specific steps of the gas-liquid ratio change characteristic range are as follows:

[0018] S201: Based on the gas-liquid ratio dynamic data set, the gas-liquid ratio change rate and the pressure and volume parameters are extracted point by point, the pressure difference and volume difference between adjacent points are calculated, the gas-liquid ratio change rate is compared with the pressure and volume differences respectively, and the results are correlated and marked according to the time series to generate a gas-liquid ratio change comparison result set;

[0019] S202: Based on the gas-liquid ratio change comparison result set, the gas-liquid ratio change rate and the pressure and volume differences are extracted, the characteristic points of the correlation are analyzed, the gas-liquid ratio intervals and the pressure and volume parameters of the characteristic points are extracted point by point, and the characteristic range values are marked according to the extraction order to generate a gas-liquid ratio change characteristic point set;

[0020] S203: Based on the gas-liquid ratio change characteristic point set, the change ranges of the gas-liquid ratio intervals corresponding to the characteristic points are extracted in turn, the gas-liquid ratio change range is combined with the characteristic point pressure-volume parameters, the initial region is delimited and the position is marked to generate the gas-liquid ratio change characteristic range.

[0021] As a further solution of the present invention, based on the above-mentioned gas-liquid ratio change characteristic range, the fluid distribution paths under different pressure gradients are extracted, the pressure and volume parameters are combined to calculate the gas-liquid ratio change rate, the distribution regions are screened and the gas-liquid two-phase conversion points are located, and the specific steps of generating the fluid phase conversion critical point data by extracting the phase state segmentation points through the change amplitude are as follows:

[0022] S301: Based on the above-mentioned gas-liquid ratio change characteristic range, extract the fluid distribution paths corresponding to different pressure gradients, associate the pressure gradient values with the fluid positions, extract the fluid distribution positions according to the pressure gradient regions, and perform path classification. Sort the path classification results by region and complete the mapping to generate a fluid distribution path data set;

[0023] S302: Based on the above-mentioned fluid distribution path data set, extract and process the pressure and volume parameters point by point, calculate the gas-liquid ratio change rate, classify the change rate by path, and associate and match it with the pressure and volume parameters. Screen the path regions with large differences in the gas-liquid ratio change rate and calibrate the distribution positions to generate the positioning result of the gas-liquid two-phase conversion point;

[0024] S303: Based on the above-mentioned positioning result of the gas-liquid two-phase conversion point, extract the numerical ranges of the regions with significant differences in the change rate item by item, combine the pressure and volume parameters, calculate the change amplitude within the region, calibrate the amplitude change points as the phase state segmentation points of the gas-liquid two-phase and mark the positions to generate the fluid phase conversion critical point data.

[0025] As a further solution of the present invention, the specific formula for calculating the gas-liquid ratio change rate is as follows:

[0026] ;

[0027] Wherein, represents the gas-liquid ratio change rate, represents the pressure difference between adjacent time points, represents the volume difference between adjacent time points, represents the time interval between adjacent time points, and respectively represent the reference pressure and the reference volume.

[0028] As a further solution of the present invention, based on the above-mentioned fluid phase conversion critical point data, call the pressure and volume characteristic ranges, calculate the influence of the pressure gradient on the gas-liquid ratio change point by point, screen the pressure distribution range and volume values in the transition region, and combine multi-point data to generate the fluid multi-phase characteristic distribution trend and obtain the specific steps of the phase conversion region characteristic data are as follows:

[0029] S401: Based on the fluid phase transition critical point data, extract the pressure and volume characteristic ranges, classify the gas-liquid ratio data point by point according to the pressure gradient, extract the corresponding values of the volume parameter and the pressure change, correlate the pressure and volume data according to the time series, and generate a pressure-volume characteristic matching data set;

[0030] S402: Based on the pressure-volume characteristic matching data set, calculate the influence degree value of the pressure gradient on the change of the gas-liquid ratio, correlate the pressure gradient change with the gas-liquid ratio rate, screen the transition regions with large differences between the pressure gradient change and the gas-liquid ratio, locate the pressure distribution range and map the volume values, and generate the pressure-volume distribution result of the transition region;

[0031] S403: Based on the pressure-volume distribution result of the transition region, extract the multi-point trend data of the gas-liquid ratio change, calculate the multi-phase characteristic distribution trend in combination with the distribution laws of the pressure and volume, integrate the gas-liquid ratio change trend and the position characteristic data by region, and obtain the characteristic data of the phase transition region.

[0032] As a further solution of the present invention, the specific calculation formula for the influence degree value of the pressure gradient on the change of the gas-liquid ratio is:

[0033] ;

[0034] Wherein, represents the influence degree value of the pressure gradient on the change of the gas-liquid ratio, represents the pressure change value between adjacent time points, represents the volume value at the corresponding time point, represents the time interval between adjacent time points, represents the gas-liquid ratio value at the corresponding time point.

[0035] As a further solution of the present invention, based on the characteristic data of the phase transition region, classify and mark the pressure and gas-liquid ratio distribution ranges, extract the distribution boundaries and change trends segment by segment, summarize the correlation characteristics of the pressure and volume in the multi-phase region, and generate the distribution states of the gas-liquid two-phase and multi-phase regions in combination with the boundary ranges. The specific steps for generating the fluid phase distribution result are:

[0036] S501: Based on the characteristic data of the phase transition region, classify and mark the pressure and gas-liquid ratio distribution ranges, segment the pressure data and the gas-liquid ratio values by region, extract the upper and lower limits of the distribution range item by item and perform region marking, integrate the extraction results and complete the classification mapping, and generate the pressure-gas-liquid ratio distribution classification data;

[0037] S502: Based on the classified data of the pressure gas-liquid ratio distribution, extract the distribution boundaries and change trends of each region, associate the boundary positions with the pressure range and the change trend of the gas-liquid ratio, sort and organize the pressure and volume parameters of the multiphase region, extract the associated parameters and calibrate the characteristics of the boundary region, and generate the multiphase region boundary and associated characteristic data;

[0038] S503: Based on the multiphase region boundary and associated characteristic data, extract the pressure and volume distribution laws of the multiphase region, summarize the distribution characteristics of the gas-liquid two-phase and multiphase regions section by section in combination with the boundary position data, integrate the summarized results and output the region state data, and obtain the fluid phase distribution result.

[0039] A phase detection system for oil and gas reservoir fluids, comprising:

[0040] The data acquisition module extracts pressure, temperature and volume parameters based on the multi-point temperature and pressure sampling data of the oil and gas reservoir fluids, calls the gas-liquid ratio sensor to record the change of the gas-liquid ratio, calculates the change trend of the gas-liquid ratio through time series, and generates a gas-liquid ratio dynamic data set;

[0041] The feature analysis module compares the change rate of the gas-liquid ratio with the pressure and volume parameters item by item based on the gas-liquid ratio dynamic data set, calculates the pressure and volume differences, marks the change range and the initial region of phase state evolution point by point, and generates the gas-liquid ratio change feature range;

[0042] The path recognition module extracts the fluid distribution paths under different pressure gradients based on the gas-liquid ratio change feature range, combines the pressure and volume parameters to calculate the change rate of the gas-liquid ratio, extracts the phase state segmentation points through the change amplitude, and generates the fluid phase conversion critical point data;

[0043] The dynamic trend module calls the pressure and volume characteristic ranges based on the fluid phase conversion critical point data, calculates the influence of the pressure gradient on the change of the gas-liquid ratio point by point, combines the multi-point data to generate the fluid multiphase characteristic distribution trend, and obtains the phase state conversion region characteristic data;

[0044] The result marking module classifies and marks the pressure and gas-liquid ratio distribution ranges based on the phase state conversion region characteristic data, extracts the distribution boundaries and change trends section by section, combines the boundary ranges to generate the gas-liquid two-phase and multiphase region distribution states, and generates the fluid phase distribution result.

[0045] Compared with the prior art, the advantages and positive effects of the present invention are as follows:

[0046] In the present invention, various data are extracted through temperature and pressure sampling, and the gas-liquid ratio is recorded by combining with a gas-liquid ratio sensor, enhancing the multi-dimensional monitoring ability of the fluid state. By comparing the change rate of the gas-liquid ratio with pressure and volume parameters, the analysis depth of the change law of the gas-liquid ratio is enhanced. Combining the pressure gradient with volume characteristics, the identification of the multi-phase region boundary under complex environments is optimized. Through the correlation analysis of the pressure gradient and gas-liquid ratio data, the states of the gas-liquid two-phase and multi-phase regions are characterized, providing comprehensive support for the dynamic monitoring of oil and gas reservoir fluids and the analysis of phase state distribution. BRIEF DESCRIPTION OF THE DRAWINGS

[0047] To more clearly illustrate the technical solutions in the embodiments of the present invention, the following will briefly introduce the drawings required for the description of the embodiments. Obviously, the following drawings are only some embodiments of the present invention. For those of ordinary skill in the art, without creative efforts, other drawings can also be obtained based on these drawings.

[0048] Figure 1 It is a schematic flow chart of the steps of the present invention;

[0049] Figure 2 It is a flow chart of step S1 of the present invention;

[0050] Figure 3 It is a flow chart of step S2 of the present invention;

[0051] Figure 4 It is a flow chart of step S3 of the present invention;

[0052] Figure 5 It is a flow chart of step S4 of the present invention;

[0053] Figure 6 It is a flow chart of step S5 of the present invention;

[0054] Figure 7 It is a system module diagram of the present invention. DETAILED DESCRIPTION OF THE EMBODIMENTS

[0055] The following will describe the technical solutions in the present invention in conjunction with the drawings.

[0056] In the embodiments of the present invention, words such as "exemplarily" and "for example" are used to represent examples, illustrations or explanations. Any embodiment or design solution described as "example" in the present invention should not be construed as more preferred or more advantageous than other embodiments or design solutions. Exactly, the use of the word "example" is intended to present concepts in a specific manner. In addition, in the embodiments of the present invention, the meaning expressed by "and / or" can be both, or either one of the two.

[0057] In the embodiments of the present invention, "image" and "picture" can sometimes be used interchangeably. It should be noted that when not emphasizing their differences, they have the same meaning. "Of", "corresponding", and "corresponding" can sometimes be used interchangeably. It should be noted that when not emphasizing their differences, they have the same meaning.

[0058] In the embodiments of the present invention, sometimes subscripts such as W1 may be written in a non-subscript form such as W1. When not emphasizing their differences, they have the same meaning.

[0059] To make the technical problems, technical solutions, and advantages to be solved by the present invention clearer, the following will be described in detail with reference to the accompanying drawings and specific embodiments.

[0060] Please refer to Figure 1 , a method for detecting the phase state of reservoir fluids, comprising the following steps:

[0061] S1: Based on the multi-point temperature and pressure sampling data of reservoir fluids, extract pressure, temperature, and volume parameters, call a gas-liquid ratio sensor to record the change in gas-liquid ratio, match the pressure and volume data point by point, calculate the change trend of the gas-liquid ratio through time series, and generate a dynamic gas-liquid ratio dataset;

[0062] S2: Based on the dynamic gas-liquid ratio dataset, compare the change rate of the gas-liquid ratio with the pressure and volume parameters item by item, calculate the pressure and volume differences, screen the change characteristic points and extract the gas-liquid ratio intervals, mark the change range and the initial region of phase state evolution point by point, and generate the change characteristic range of the gas-liquid ratio;

[0063] S3: Based on the change characteristic range of the gas-liquid ratio, extract the fluid distribution paths under different pressure gradients, combine the pressure and volume parameters to calculate the change rate of the gas-liquid ratio, screen the distribution regions and locate the gas-liquid two-phase conversion points, extract the phase state segmentation points through the change amplitude, and generate the critical point data of fluid phase state conversion;

[0064] S4: Based on the critical point data of fluid phase state conversion, call the pressure and volume characteristic ranges, calculate the influence of the pressure gradient on the change of the gas-liquid ratio point by point, screen the pressure distribution range and volume values in the transition region, combine the multi-point data to generate the multi-phase characteristic distribution trend of the fluid, and obtain the characteristic data of the phase state conversion region;

[0065] S5: Based on the characteristic data of the phase state conversion region, classify and mark the pressure and gas-liquid ratio distribution ranges, extract the distribution boundaries and change trends segment by segment, summarize the correlation characteristics of pressure and volume in the multi-phase region, and combine the boundary ranges to generate the distribution states of the gas-liquid two-phase and multi-phase regions, and generate the fluid phase state distribution results.

[0066] The gas-liquid ratio dynamic data set includes pressure parameters, temperature parameters, volume parameters, gas-liquid ratio change values, and time series trend data. The gas-liquid ratio change characteristic range includes the gas-liquid ratio change rate range, pressure change interval, volume change interval, gas-liquid ratio characteristic points, and phase state evolution boundary. The fluid phase state conversion critical point data includes the gas-liquid two-phase conversion point position, phase state segmentation point parameters, pressure gradient interval, and volume characteristic interval. The phase state conversion region characteristic data includes the transition region pressure characteristics, gas-liquid ratio characteristic interval, multiphase distribution trend, and associated volume characteristics. The fluid phase state distribution result includes the gas-liquid two-phase distribution range, multiphase distribution range, pressure distribution characteristics, volume distribution characteristics, and boundary association characteristics.

[0067] Please refer to Figure 2 , and the specific steps of S1 are as follows:

[0068] S101: Based on the multi-point temperature and pressure sampling data of the oil and gas reservoir fluid, extract the pressure, temperature, and volume parameters, sort the sampling data according to the time series, perform point-by-point extraction and matching on the pressure and volume parameters, and perform joint processing according to time to generate a pressure-volume matching data set;

[0069] Obtain the temperature, pressure, and volume parameters through a dedicated temperature and pressure sampling device. Sort the data according to the time axis for different sampling points, perform point-by-point extraction on the pressure and volume parameters and establish a time series, perform joint processing on the temperature and pressure data output by the temperature and pressure sensors and the volume data output by the volumetric flowmeter, and match the pressure and volume parameters at different time points through an interpolation algorithm to generate a matching pressure-volume data set.

[0070] S102: Based on the pressure-volume matching data set, call the gas-liquid ratio sensor to record the gas-liquid ratio change, calibrate the gas-liquid ratio data to the corresponding pressure-volume points according to the time series, and perform synchronous association processing on the gas-liquid ratio data and the matching data set to form a gas-liquid ratio change mapping data set;

[0071] Calibrate the gas-liquid ratio data to the corresponding pressure-volume points according to the time series, and according to the formula

[0072] ;

[0073] Calculate the gas-liquid ratio;

[0074] In the formula, represents the gas-liquid ratio, represents the pressure, represents the volume, is the gas deviation factor, is the gas constant, is the temperature.

[0075] The gas-liquid ratio formula is derived from the gas state equation. The gas-liquid ratio is calculated by combining the pressure-volume matching data set in actual operation and the real-time temperature recorded by the temperature sensor. The pressure value P is collected in real time by the pressure sensor, with the unit of Pascal; the volume V is measured by the flowmeter, with the unit of cubic meter; the gas deviation factor Z is obtained through experimental calibration and acquired by the interpolation method of the calibration table; the temperature T has the unit of Kelvin, and the gas constant takes the value of 8.314 J / (mol·K).

[0076] Example calculation:

[0077] Suppose the pressure P collected at a certain moment is 1.5×10 6 Pa, the volume V is 0.02 m 3 , Z is 0.95, and T is 298 K. Calculate the gas-liquid ratio:

[0078] ;

[0079] Calculate:

[0080] ;

[0081] This result indicates that the gas-liquid ratio at the corresponding pressure-volume matching point is 12.72, which means the ratio of the number of moles of gas to the number of moles of liquid is 12.72, and it is further used to form the gas-liquid ratio change mapping data set.

[0082] S103: Based on the gas-liquid ratio change mapping data set, extract the gas-liquid ratio change trend data according to the time series, and perform correlation analysis using the trend change value and the time parameter to generate the gas-liquid ratio dynamic data set;

[0083] By extracting the gas-liquid ratio values at different time points in the time series, calculating the gas-liquid ratio change rate using the numerical derivative method, taking the change rate as the basis of the gas-liquid ratio trend data, analyzing through the data associated with the time points, extracting the dynamic characteristics of the gas-liquid ratio changing with time, and fitting the trend change value through the differential equations, finally generating the gas-liquid ratio dynamic data set.

[0084] Please refer to Figure 3 , and the specific steps of S2 are as follows:

[0085] S201: Based on the gas-liquid ratio dynamic data set, extract the gas-liquid ratio change rate and the pressure and volume parameters point by point, calculate the pressure difference and volume difference between adjacent points, compare the gas-liquid ratio change rate with the pressure and volume differences respectively, correlate and label the results according to the time series, and generate the gas-liquid ratio change comparison result set;

[0086] The change rate of the gas-liquid ratio is calculated by the numerical derivative method. The pressure difference between adjacent points is obtained by differentiating the collected pressure data, and the volume difference is obtained by differentiating the volume data. The pressure difference and the volume difference are respectively compared in combination with the change rate of the gas-liquid ratio. The change rate data of pressure, volume and gas-liquid ratio are associated through time series. The associated data points are marked according to the set annotation rules, and finally a result set of the comparison of the gas-liquid ratio changes is generated.

[0087] S202: Based on the result set of the comparison of the gas-liquid ratio changes, extract the change rate of the gas-liquid ratio and the pressure and volume differences, analyze the characteristic points of the correlation, extract the gas-liquid ratio interval and the pressure and volume parameters of the characteristic points point by point, mark the characteristic range values in the extraction order, and generate a set of characteristic points of the gas-liquid ratio changes;

[0088] Perform characteristic point analysis on the change rate of the gas-liquid ratio and the pressure and volume differences. According to the formula

[0089] ;

[0090] Calculate the correlation characteristic value;

[0091] In the formula, represents the characteristic value, represents the pressure difference, represents the volume difference.

[0092] The characteristic value calculation formula combines the sum of the squares of the pressure difference and the volume difference, and measures the influence of the pressure and volume changes on the gas-liquid ratio change. The pressure difference is obtained by differentiating the time series data recorded by the pressure sensor, with the unit of Pascal. The volume difference is obtained by differentiating the volume data recorded by the flow meter, with the unit of cubic meter; then an equivalent coefficient k is introduced to make the dimensions of the two terms k⋅ΔV and ΔP consistent, but the equivalent coefficient k does not change the value of ΔV, and the unit of F is also Pascal.

[0093] Example calculation:

[0094] If the pressures of two adjacent points are respectively and , and the volumes are respectively and , then:

[0095] ;

[0096] ;

[0097] Substitute into the formula:

[0098] ;

[0099] ;

[0100] ;

[0101] The result shows that the comprehensive feature of the pressure and volume difference corresponding to this feature point is , which is used to extract the gas-liquid ratio interval and pressure and volume parameters of the feature point subsequently.

[0102] S203: Based on the gas-liquid ratio change feature point set, sequentially extract the change range of the gas-liquid ratio interval corresponding to the feature points, combine the gas-liquid ratio change range with the pressure-volume parameters of the feature points, delimit the initial area and mark the position to generate the gas-liquid ratio change feature range;

[0103] Analyze the change range of the gas-liquid ratio interval of the extracted feature points. Obtain the change range by calculating the difference between the maximum and minimum values of the gas-liquid ratio interval in the time series. Delimit the spatial position of the change range in combination with the pressure-volume feature point parameters, and label the delimited area in a time- and space-related manner to finally generate the gas-liquid ratio change feature range.

[0104] Please refer to Figure 4 , the specific steps of S3 are as follows:

[0105] S301: Based on the gas-liquid ratio change feature range, extract the fluid distribution path corresponding to the differential pressure gradient, associate the pressure gradient value with the fluid position, extract the fluid distribution position according to the pressure gradient area, and perform path classification. Sort the path classification results by area and complete the mapping to generate the fluid distribution path data set;

[0106] By extracting the differential pressure gradient data, point-by-point associate the change value of the pressure gradient with the position data of the fluid in the time series. Use the differential calculation method to obtain the distribution range and direction of the pressure gradient, divide the pressure gradient value into regions and label specific ranges, classify the fluid position distribution within each region, sort according to the characteristic values of the fluid paths, and complete the path mapping through the association matrix between paths to finally generate the fluid distribution path data set.

[0107] S302: Based on the fluid distribution path data set, extract the pressure and volume parameters for point-by-point combination processing, calculate the gas-liquid ratio change rate, classify the change rate by path, and associate and match it with the pressure and volume parameters. Screen the path regions with large differences in the gas-liquid ratio change rate and calibrate the distribution position to generate the positioning result of the gas-liquid two-phase conversion point;

[0108] The specific formula for calculating the gas-liquid ratio change rate is:

[0109] ;

[0110] Among them, represents the change rate of gas-liquid ratio, represents the pressure difference between adjacent time points, represents the volume difference between adjacent time points, represents the time interval between adjacent time points, and respectively represent the reference pressure and reference volume.

[0111] Given: initial pressure , termination pressure , pressure change , volume change , time interval ;

[0112] Calculate the normalized change rate: Let the reference pressure be , and let the reference volume be ;

[0113] Calculate the normalized pressure change rate:

[0114] ;

[0115] Calculate the normalized volume change rate:

[0116] ;

[0117] Calculate the final rate:

[0118] ;

[0119] ;

[0120] The result shows that the change rate of gas-liquid ratio is 0.0353, which is used as a parameter to evaluate the change range of gas-liquid ratio in the path classification. The numerical result is closely related to the path classification and the matching of pressure and volume parameters in the steps, providing a quantitative basis for screening out the path regions with significant differences in the change rate of gas-liquid ratio, and at the same time calibrating the specific distribution positions.

[0121] S303: Based on the gas-liquid two-phase conversion point positioning result, extract the numerical range of the regions with significant differences in the change rate item by item, combine the pressure and volume parameters, calculate the change range within the region, calibrate the amplitude change point as the phase state segmentation point of the gas-liquid two-phase and mark the position, and generate the fluid phase state conversion critical point data;

[0122] Joint processing is carried out using pressure and volume parameters to calculate the amplitude of the gas-liquid ratio change within the region point by point. The amplitude change value of each point is obtained through the difference calculation method, the spatial coordinates of the change points are calibrated, and the points with significant change amplitudes are calibrated as the phase separation points of the gas-liquid two-phase. By constructing a spatial position mapping method, the critical points of fluid phase conversion are marked, and finally, the critical point data of fluid phase conversion are generated.

[0123] Please refer to Figure 5 , and the specific steps of S4 are as follows:

[0124] S401: Based on the critical point data of fluid phase conversion, extract the pressure and volume characteristic ranges, classify the gas-liquid ratio data point by point according to the pressure gradient, extract the corresponding values of volume parameters and pressure changes, correlate the pressure and volume data according to the time series, and generate a pressure-volume characteristic matching data set;

[0125] According to the classification rule of dividing the gas-liquid ratio data by the pressure gradient, calculate the difference values respectively using the time series pressure data and volume data collected by the pressure sensor to obtain the change rule, correlate the pressure and volume parameters point by point according to the time series, and perform item-by-item matching processing on the classified gas-liquid ratio data and the time series pressure-volume data, and finally generate a pressure-volume characteristic matching data set.

[0126] S402: Based on the pressure-volume characteristic matching data set, calculate the influence degree value of the pressure gradient on the gas-liquid ratio change, correlate the pressure gradient change with the gas-liquid ratio rate, screen the transition regions with large differences between the pressure gradient change and the gas-liquid ratio, locate the pressure distribution range and map the volume values, and generate the pressure-volume distribution result of the transition region;

[0127] The specific calculation formula for the influence degree value of the pressure gradient on the gas-liquid ratio change is:

[0128] ;

[0129] Among them, represents the influence degree value of the pressure gradient on the gas-liquid ratio change, represents the pressure change value between adjacent time points, represents the volume value at the corresponding time point, represents the time interval between adjacent time points, represents the gas-liquid ratio value at the corresponding time point.

[0130] Calculation process:

[0131] Set a group of sampling data: the pressure value decreases from Pascals to Pascals, the volume is 0.04 cubic meters, the gas-liquid ratio is 12, and the time interval is 5 seconds.

[0132] Calculate the pressure change value:

[0133] ;

[0134] Determine the volume parameter:

[0135] ;

[0136] Determine the gas-liquid ratio:

[0137] ;

[0138] Determine the time interval:

[0139] ;

[0140] Substitute into the formula for calculation:

[0141] ;

[0142] Calculate the numerator:

[0143] ;

[0144] Calculate the denominator:

[0145] ;

[0146] Calculate the influence degree value:

[0147] ;

[0148] The result shows that the influence degree value is 200 Pa·m³ / s, indicating the comprehensive change intensity under the current pressure gradient change and gas-liquid ratio rate conditions. This value is used to further screen the regions with large differences in pressure gradient change and gas-liquid ratio in the transition region and provide basic data support for locating the pressure distribution range.

[0149] S403: Based on the pressure-volume distribution results in the transition region, extract the multi-point trend data of the gas-liquid ratio change, calculate the multi-phase characteristic distribution trend by combining the distribution laws of pressure and volume, and integrate the gas-liquid ratio change trend and position characteristic data by region to obtain the characteristic data of the phase transition region;

[0150] By extracting the gas-liquid ratio change trend data point by point, using the multi-point interpolation method to calculate the distribution laws of pressure and volume in the time series, conducting a correlation analysis on the change amplitudes of pressure and volume parameters in different regions, integrating the gas-liquid ratio change trend and position characteristic parameters in the region, constructing a multi-phase distribution model, and finally obtaining the characteristic data of the phase transition region and calibrating the region range.

[0151] Please refer to Figure 6 , the specific steps of S5 are as follows:

[0152] S501: Classify and label the pressure and gas-liquid ratio distribution ranges based on the characteristic data of the phase transition region, segment the pressure data and gas-liquid ratio values by region, extract the upper and lower limits of the distribution range item by item and mark the regions, integrate the extraction results and complete the classification mapping to generate pressure-gas-liquid ratio distribution classification data;

[0153] Perform segmented processing on the pressure sensor and gas-liquid ratio data by region, determine the range interval by calculating the upper and lower limits of each distribution range, perform segmented association on the pressure data and gas-liquid ratio values in different regions, uniformly mark and integrate the upper and lower limit data of each region, and finally generate pressure-gas-liquid ratio distribution classification data by constructing a segmented mapping relationship.

[0154] S502: Based on the pressure-gas-liquid ratio distribution classification data, extract the distribution boundaries and change trends of each region, associate the boundary positions with the pressure range and gas-liquid ratio change trend, sort out the pressure and volume parameters of the multiphase region, extract the associated parameters and calibrate the boundary region characteristics to generate multiphase region boundary and associated characteristic data;

[0155] Extract the distribution boundaries and change trends of each region, according to the formula

[0156] ;

[0157] Calculate the associated characteristics of the boundary region;

[0158] In the formula, represents the boundary association characteristic value, and are the upper and lower pressure limits of the boundary respectively, is the rate of change of the gas-liquid ratio with pressure, is the volume.

[0159] Formula:

[0160] ;

[0161] Among them: (the rate of change of the gas-liquid ratio with pressure): The unit should be (volume): The unit is (pressure change): The unit is

[0162] Therefore, the unit after integral calculation is:

[0163] ;

[0164] That is, the unit of E should be , representing the volumetric rate of change of the gas-liquid ratio.

[0165] Recalculate E:

[0166] Pressure range:

[0167] Lower limit ;

[0168] Upper limit ;

[0169] Gas-liquid ratio change rate :

[0170] Let At be ;

[0171] Let At be ;

[0172] Adopt a linear change model:

[0173] ;

[0174] Solve for a and b through known points:

[0175] ;

[0176] ;

[0177] Volume ;

[0178] Calculate the change equation of the gas-liquid ratio change rate:

[0179] Solve the system of equations:

[0180] ;

[0181] ;

[0182] ;

[0183] Find b:

[0184] ;

[0185] ;

[0186] ;

[0187] So:

[0188] ;

[0189] Calculate the integral:

[0190] ;

[0191] ;

[0192] Calculate the first part:

[0193] ;

[0194] ;

[0195] ;

[0196] ;

[0197] ;

[0198] Multiply by :

[0199] ;

[0200] Calculate the second part:

[0201] ;

[0202] ;

[0203] Multiply by :

[0204] ;

[0205] Sum:

[0206] ;

[0207] Multiply by the volume :

[0208] ;

[0209] ;

[0210] Calculation result:

[0211] The corrected boundary relation characteristic value .

[0212] This unit represents the volumetric rate of change of the gas-liquid ratio, that is, how the change in the gas-liquid ratio affects the volumetric flow within this region.

[0213] Summary of calculation steps

[0214] Set pressure range 、 Given The changing trend, solve for a and b using a linear equation, establish an integral equation, considering The change, rather than substituting with constants, calculate the integral, calculate item by item And To solve for the final boundary relation eigenvalue And check the units.

[0215] After correction, the boundary eigenvalue Is used to calibrate the characteristics of the region and generate the boundary and associated characteristic data of the multiphase region.

[0216] S503: Based on the boundary and associated characteristic data of the multiphase region, extract the pressure and volume distribution laws of the multiphase region, combine the boundary position data to inductively summarize the distribution characteristics of the gas-liquid two-phase and multiphase regions section by section, integrate the inductive results and output the regional state data to obtain the fluid phase distribution result;

[0217] Adopt the gradient change analysis method to inductively summarize the distribution characteristics of the gas-liquid two-phase and multiphase regions. By calculating the associated data of pressure, volume and gas-liquid ratio for each region section by section, integrate the distribution characteristics within each region to form a multiphase region distribution law model, and combine the boundary position data for unified output to finally obtain the fluid phase distribution result.

[0218] Please refer to Figure 7 For a phase detection system of reservoir fluids, including:

[0219] The data acquisition module extracts pressure, temperature and volume parameters based on the multi-point temperature and pressure sampling data of reservoir fluids, calls the gas-liquid ratio sensor to record the change of gas-liquid ratio, calculates the change trend of gas-liquid ratio through time series, and generates a dynamic gas-liquid ratio dataset;

[0220] The feature analysis module compares the change rate of gas-liquid ratio with pressure and volume parameters item by item based on the dynamic gas-liquid ratio dataset, calculates the pressure and volume differences, marks the change range and the initial region of phase evolution point by point, and generates the change feature range of gas-liquid ratio;

[0221] The path recognition module extracts the fluid distribution paths under different differential pressure gradients based on the change feature range of gas-liquid ratio, combines the pressure and volume parameters to calculate the change rate of gas-liquid ratio, extracts the phase segmentation points through the change amplitude, and generates the fluid phase conversion critical point data;

[0222] The dynamic trend module, based on the critical point data of fluid phase state conversion, calls the pressure and volume characteristic ranges, calculates the influence of the pressure gradient on the gas-liquid ratio change point by point, generates the fluid multi-phase characteristic distribution trend by combining multi-point data, and obtains the characteristic data of the phase state conversion region;

[0223] The result marking module, based on the characteristic data of the phase state conversion region, classifies and marks the pressure and gas-liquid ratio distribution ranges, extracts the distribution boundaries and change trends segment by segment, generates the gas-liquid two-phase and multi-phase region distribution states by combining the boundary ranges, and generates the fluid phase state distribution result.

[0224] As mentioned above, it is only the specific implementation manner of the present invention, but the protection scope of the present invention is not limited thereto. Any person skilled in the art within the technical scope disclosed by the present invention can easily think of changes or substitutions, which should be covered within the protection scope of the present invention. Therefore, the protection scope of the present invention should be subject to the protection scope of the claimed rights.

Claims

1. A method for detecting the phase state of hydrocarbon reservoir fluids, characterized in that, It includes the following steps: S1: Based on the multi-point temperature and pressure sampling data of the reservoir fluid, extract the pressure, temperature and volume parameters, call the gas-liquid ratio sensor to record the change of the gas-liquid ratio, match the pressure and volume data point by point, calculate the change trend of the gas-liquid ratio through time series, and generate a dynamic gas-liquid ratio dataset; S2: Based on the dynamic gas-liquid ratio dataset, compare the change rate of the gas-liquid ratio with the pressure and volume parameters item by item, calculate the pressure and volume differences, screen the change characteristic points and extract the gas-liquid ratio intervals, mark the change ranges and the initial regions of phase state evolution point by point, and generate the change characteristic range of the gas-liquid ratio; S3: Based on the change characteristic range of the gas-liquid ratio, extract the fluid distribution paths under different pressure gradients, combine the pressure and volume parameters to calculate the change rate of the gas-liquid ratio, screen the distribution regions and locate the gas-liquid two-phase conversion points, and extract the phase state segmentation points through the change amplitude to generate the critical point data of fluid phase state conversion; S4: Based on the critical point data of fluid phase state conversion, call the pressure and volume characteristic ranges, calculate the influence of the pressure gradient on the change of the gas-liquid ratio point by point, screen the pressure distribution range and volume values in the transition region, combine the multi-point data to generate the multi-phase characteristic distribution trend of the fluid, and obtain the characteristic data of the phase state conversion region; S5: Based on the characteristic data of the phase state conversion region, classify and mark the pressure and gas-liquid ratio distribution ranges, extract the distribution boundaries and change trends segment by segment, summarize the correlation characteristics of pressure and volume in the multi-phase region, and combine the boundary ranges to generate the distribution states of the gas-liquid two-phase and multi-phase regions, and generate the fluid phase state distribution result; Among them, the dynamic gas-liquid ratio dataset includes pressure parameters, temperature parameters, volume parameters, gas-liquid ratio change values, and time series trend data. The change characteristic range of the gas-liquid ratio includes the gas-liquid ratio change rate range, pressure change interval, volume change interval, gas-liquid ratio characteristic points, and phase state evolution boundaries. The critical point data of fluid phase state conversion includes the positions of gas-liquid two-phase conversion points, phase state segmentation point parameters, pressure gradient intervals, and volume characteristic intervals. The characteristic data of the phase state conversion region includes the pressure characteristics in the transition region, gas-liquid ratio characteristic intervals, multi-phase distribution trends, and associated volume characteristics. The fluid phase state distribution result includes the gas-liquid two-phase distribution range, multi-phase distribution range, pressure distribution characteristics, volume distribution characteristics, and boundary correlation characteristics.

2. The phase state detection method of the reservoir fluid according to claim 1, wherein The specific steps for generating a dynamic gas-liquid ratio dataset based on the multi-point temperature and pressure sampling data of the reservoir fluid, extracting the pressure, temperature and volume parameters, calling the gas-liquid ratio sensor to record the change of the gas-liquid ratio, matching the pressure and volume data point by point, and calculating the change trend of the gas-liquid ratio through time series are as follows: S101: Based on the multi-point temperature and pressure sampling data of the reservoir fluid, extract the pressure, temperature and volume parameters, sort the sampling data according to the time series, extract and match the pressure and volume parameters point by point, and perform joint processing according to the time to generate a pressure-volume matching dataset; S102: Based on the pressure-volume matching dataset, call the gas-liquid ratio sensor to record the change of the gas-liquid ratio, calibrate the gas-liquid ratio data to the corresponding pressure-volume points according to the time series, and perform synchronous correlation processing on the gas-liquid ratio data and the matching dataset to form a gas-liquid ratio change mapping dataset; S103: Based on the gas-liquid ratio change mapping data set, extract the gas-liquid ratio change trend data according to the time series, perform correlation analysis using the trend change value and time parameter, and generate the gas-liquid ratio dynamic data set.

3. The phase state detection method of the reservoir fluid according to claim 1, characterized in that, Based on the gas-liquid ratio dynamic data set, compare the gas-liquid ratio change rate with the pressure and volume parameters item by item, calculate the pressure and volume differences, screen the change characteristic points and extract the gas-liquid ratio intervals, and mark the change range and the initial region of phase state evolution point by point. The specific steps for generating the gas-liquid ratio change characteristic range are as follows: S201: Based on the gas-liquid ratio dynamic data set, extract the gas-liquid ratio change rate and the pressure and volume parameters point by point, calculate the pressure difference and volume difference between adjacent points, compare the gas-liquid ratio change rate with the pressure and volume differences respectively, correlate and label the results according to the time series, and generate the gas-liquid ratio change comparison result set; S202: Based on the gas-liquid ratio change comparison result set, extract the gas-liquid ratio change rate and the pressure and volume differences, analyze the characteristic points of the correlation, extract the gas-liquid ratio interval and the pressure and volume parameters of the characteristic points point by point, and mark the characteristic range values in the extraction order to generate the gas-liquid ratio change characteristic point set; S203: Based on the gas-liquid ratio change characteristic point set, sequentially extract the change ranges of the gas-liquid ratio intervals corresponding to the characteristic points, combine the gas-liquid ratio change ranges with the pressure and volume parameters of the characteristic points, delimit the initial region and mark the position to generate the gas-liquid ratio change characteristic range.

4. The phase state detection method for reservoir fluid according to claim 1, characterized in that, Based on the gas-liquid ratio change characteristic range, extract the fluid distribution path under different pressure gradients, calculate the gas-liquid ratio change rate by combining the pressure and volume parameters, screen the distribution region and locate the gas-liquid two-phase conversion point, and extract the phase state segmentation point through the change amplitude. The specific steps for generating the fluid phase state conversion critical point data are as follows: S301: Based on the gas-liquid ratio change characteristic range, extract the fluid distribution path corresponding to different pressure gradients, correlate the pressure gradient value with the fluid position, extract the fluid distribution positions according to the pressure gradient region, and perform path classification. Sort the path classification results by region and complete the mapping to generate the fluid distribution path data set; S302: Based on the fluid distribution path data set, extract the pressure and volume parameters for point-by-point combination processing, calculate the gas-liquid ratio change rate, classify the change rate by path, and correlate and match it with the pressure and volume parameters. Screen the path regions with large differences in gas-liquid ratio change rate and mark the distribution positions to generate the gas-liquid two-phase conversion point positioning result; S303: Based on the gas-liquid two-phase conversion point positioning result, extract the numerical range of the region with significant difference in change rate item by item, combine the pressure and volume parameters, calculate the change amplitude within the region, mark the amplitude change point as the phase state segmentation point of the gas-liquid two-phase and mark the position to generate the fluid phase state conversion critical point data.

5. The phase state detection method for reservoir fluid according to claim 4, wherein The specific formula for calculating the gas-liquid ratio change rate is as follows: ； Among them, represents the change rate of the gas-liquid ratio, represents the pressure difference between adjacent time points, represents the volume difference between adjacent time points, represents the time interval between adjacent time points, and respectively represent the reference pressure and the reference volume.

6. The phase state detection method of the reservoir fluid according to claim 1, characterized in that, Based on the fluid phase state conversion critical point data, call the pressure and volume characteristic ranges, calculate the influence of the pressure gradient on the gas-liquid ratio change point by point, screen the pressure distribution range and volume value of the transition region, combine the multi-point data to generate the fluid multi-phase characteristic distribution trend, and obtain the specific steps for the characteristic data of the phase state conversion region are as follows: S401: Based on the fluid phase transition critical point data, extract the pressure and volume characteristic ranges, classify the gas-liquid ratio data point by point according to the pressure gradient, extract the corresponding values of the volume parameter and the pressure change, correlate the pressure and volume data according to the time series, and generate a pressure-volume characteristic matching data set; S402: Based on the pressure-volume characteristic matching data set, calculate the influence degree value of the pressure gradient on the gas-liquid ratio change, correlate the pressure gradient change with the gas-liquid ratio rate, screen the transition regions with large differences between the pressure gradient change and the gas-liquid ratio, locate the pressure distribution range and map the volume values, and generate the pressure-volume distribution result of the transition region; S403: Based on the pressure-volume distribution result of the transition region, extract the multi-point trend data of the gas-liquid ratio change, calculate the multi-phase characteristic distribution trend by combining the distribution laws of pressure and volume, integrate the gas-liquid ratio change trend and the position characteristic data by region, and obtain the characteristic data of the phase transition region.

7. The phase state detection method for reservoir fluid according to claim 6, characterized in that, The specific calculation formula for the influence degree value of the pressure gradient on the gas-liquid ratio change is: ； Among them, represents the influence degree value of the pressure gradient on the change of gas-liquid ratio, represents the pressure change value at adjacent time points, represents the volume value at the corresponding time point, represents the time interval between adjacent time points, represents the gas-liquid ratio value at the corresponding time point.

8. The phase state detection method for hydrocarbon reservoir fluids according to claim 1, characterized in that, Based on the characteristic data of the phase transition region, classify and label the distribution ranges of pressure and gas-liquid ratio, extract the distribution boundaries and change trends segment by segment, summarize the correlation characteristics of pressure and volume in the multi-phase region, and generate the distribution states of the gas-liquid two-phase and multi-phase regions in combination with the boundary ranges. The specific steps for generating the fluid phase distribution result are: S501: Based on the characteristic data of the phase transition region, classify and label the distribution ranges of pressure and gas-liquid ratio, perform segmented processing on the pressure data and the gas-liquid ratio values by region, extract the upper and lower limits of the distribution range item by item and perform region marking, integrate the extraction results and complete the classification mapping, and generate the pressure-gas-liquid ratio distribution classification data; S502: Based on the pressure-gas-liquid ratio distribution classification data, extract the distribution boundaries and change trends of each region, correlate the boundary positions according to the pressure range and the gas-liquid ratio change trend, perform zoning arrangement on the pressure and volume parameters in the multi-phase region, extract the correlation parameters and calibrate the boundary region characteristics, and generate the multi-phase region boundary and correlation characteristic data; S503: Based on the multi-phase region boundary and correlation characteristic data, extract the pressure and volume distribution laws in the multi-phase region, summarize the distribution characteristics of the gas-liquid two-phase and multi-phase regions segment by segment in combination with the boundary position data, integrate the summary results and output the region state data, and obtain the fluid phase distribution result.

9. A phase detection system for reservoir fluids, characterized in that, A phase detection method for oil and gas reservoir fluids according to any one of claims 1-8, the system comprising: The data acquisition module extracts pressure, temperature and volume parameters based on the multi-point temperature and pressure sampling data of the oil and gas reservoir fluid, calls the gas-liquid ratio sensor to record the gas-liquid ratio change, calculates the gas-liquid ratio change trend through the time series, and generates a gas-liquid ratio dynamic data set; The feature analysis module compares the gas-liquid ratio change rate with the pressure and volume parameters item by item based on the gas-liquid ratio dynamic data set, calculates the pressure and volume differences, marks the change range and the initial region of phase state evolution point by point, and generates the gas-liquid ratio change feature range; Based on the range of the gas-liquid ratio change characteristics, the path recognition module extracts the fluid distribution paths under different pressure gradients, combines the pressure and volume parameters to calculate the gas-liquid ratio change rate, extracts the phase segmentation points through the change amplitude, and generates the fluid phase transition critical point data; Based on the fluid phase transition critical point data, the dynamic trend module calls the pressure and volume characteristic ranges, calculates the influence of the pressure gradient on the gas-liquid ratio change point by point, generates the multi-phase characteristic distribution trend of the fluid by combining multi-point data, and obtains the phase transition region characteristic data; Based on the phase transition region characteristic data, the result marking module classifies and marks the pressure and gas-liquid ratio distribution ranges, extracts the distribution boundaries and change trends section by section, generates the gas-liquid two-phase and multi-phase region distribution states by combining the boundary ranges, and generates the fluid phase distribution result.

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