Horizontal shale oil and gas well flow parameter measuring method based on thermal and radiation fusion

Abstract

The invention belongs to the technical field of petroleum engineering, and particularly relates to a horizontal shale oil and gas well flow parameter measuring method based on thermal and radiation fusion. The method comprises the following steps: 1, judging whether the horizontal shale oil-water two-phase flow is stable by using a pair of temperature sensor arrays and measuring an initial temperature; 2, selecting a proper heat source generator material, and controlling a heat source generator to instantly heat the horizontal shale oil-water two-phase flow so as to measure the horizontal shale oil-water two-phase flow; 3, temperature signals of horizontal shale oil-water two-phase flow are collected, and the water content is calculated; 4, calculating the flow velocity of the oil phase and the water phase through the particles injected into the horizontal shale oil-water two-phase flow; and 5, establishing a conversion equation model of the water content and the water holding rate, and calculating the water holding rate of the horizontal shale oil-water two-phase flow. The problem that the flow and the holdup of the horizontal shale oil-water two-phase flow are not accurately measured under the high-temperature condition of 200-350 DEG C is solved, and the flow parameters of the horizontal shale oil-water two-phase flow are more accurately measured.

Description

TECHNICAL FIELD

[0001] The present application belongs to the technical field of petroleum engineering, and particularly relates to a horizontal shale oil and gas well flow parameter measurement method based on thermal and radiation fusion. BACKGROUND

[0002] The flow rate and holdup of oil-water two-phase flow are important parameters in the process of oilfield development, and accurate measurement of the parameters helps to master the production information of each layer of the underground reservoir and oil well, which is of great significance for scientifically formulating oilfield development injection-production schemes, ensuring optimized production and stable production. Currently, the commonly used horizontal oil-water two-phase flow production well flow parameter measurement devices include turbine flow meters, ultrasonic flow meters, conductivity sensors and microwave sensors. Due to the limitations of the devices themselves, the measurement error is large when the oil-water two-phase flow fluid has high viscosity, high sand content, low conductivity and small dielectric constant, which seriously affects the oilfield production efficiency.

[0003] The flow parameter measurement device for measuring the flow parameters of horizontal shale oil and gas production wells based on thermal and radiation fusion has no movable parts and is not affected by the high viscosity and high sand content of the oil-water two-phase flow fluid, and has been widely applied in oilfields. However, since in-situ hot injection for shale oil and gas needs to be carried out at a temperature of 200-350 DEG C, the original device cannot meet the production needs in terms of precision and cannot be applied to the measurement of the flow parameters of horizontal shale oil-water two-phase flow. SUMMARY

[0004] In order to solve the problem of inaccurate measurement of the flow rate and holdup of horizontal shale oil-water two-phase flow under high temperature conditions, the present application provides a horizontal shale oil and gas well flow parameter measurement method based on thermal and radiation fusion. The method mainly indirectly calculates the flow rate of horizontal shale oil-water two-phase flow through thermal tracing, and obtains the holdup of horizontal shale oil-water two-phase flow by using the horizontal shale oil-water two-phase flow fluid after pulse heating of the heat source generator passing through the temperature sensor array, and then obtains the holdup of horizontal shale oil-water two-phase flow through the particle tracing device, thereby improving the measurement precision of the flow rate and holdup of horizontal shale oil and gas production well oil-water two-phase flow and meeting the needs of the flow parameter measurement of horizontal shale oil and gas production well oil-water two-phase flow under actual conditions.

[0005] The technical scheme adopted by the present application is as follows: a horizontal shale oil and gas well flow parameter measurement method based on thermal and radiation fusion, wherein the measurement device for measuring the parameters of horizontal shale oil-water two-phase flow comprises a heat source generator, a pair of temperature sensor arrays, a particle injector and a pair of gamma detector arrays; one heat source generator and one particle injector are installed upstream of the horizontal shale oil-water two-phase flow parameter measurement device, and a pair of temperature sensor arrays and a pair of gamma detector arrays are placed downstream of the horizontal shale oil-water two-phase flow parameter measurement device; the pair of temperature sensor arrays are respectively named temperature sensor array 1 and temperature sensor array 2, the heat source generator is 2 meters away from the temperature sensor array 2, the particle injector is 2 meters away from the temperature sensor array 1, the temperature sensor array 1 is 2 meters away from the temperature sensor array 2, the temperature sensor array 1 is 2 meters away from the particle injector, the temperature sensor array 2 is 2 meters away from the heat source generator, the particle injector is 2 meters away from the heat source generator, the temperature sensor array 1 is 2 meters away from the gamma detector array 1, the temperature sensor array 2 is 2 meters away from the gamma detector array 2, the gamma detector array 1 is 2 meters away from the temperature sensor array 1, and the gamma detector array 2 is 2 meters away from the temperature sensor array 2. The temperature sensor array 1 is placed between the temperature sensor array 2 and the heat source generator, and the distance to both is .

[0006] Further, a measurement method for measuring the flow rate and holdup of horizontal shale oil-water two-phase flow using the horizontal shale oil-water two-phase flow parameter measurement device, the measurement method comprising the following steps:

[0007] Step one: determining whether the horizontal shale oil-water two-phase flow fluid in the horizontal shale oil-water two-phase flow parameter measurement device reaches a steady state, and measuring the initial temperature after reaching the steady state ;

[0008] The temperature signals collected by the temperature sensor array 1 and the temperature sensor array 2 in the pipeline of the horizontal shale oil-water two-phase flow parameter measurement device are , represents the temperature sensor array, represents the temperature sensor with the pipeline center as the center and clockwise from top to bottom, the positions of the temperature sensors in the two temperature sensor arrays are the same, and the included angle between two adjacent temperature sensors is , The value range of n is 1, 2; The value range of m is 1, 2, 3, 4, 5, and 72°.

[0009] The temperature sensor array 1 and the temperature sensor array 2 can measure the temperature curve of the horizontal shale oil-water two-phase flow fluid, and whether the horizontal shale oil-water two-phase flow fluid in the horizontal shale oil-water two-phase flow parameter measurement device reaches a steady state is determined by calculating the similarity of the two groups of temperature curves.

[0010] The continuous temperature curve A measured by the temperature sensor array 1 is sampled, and the discrete time sequence obtained by sampling is: .

[0011] The discrete time sequence data points obtained by sampling the continuous temperature curve A are:

[0012]

[0013] Among them, is the discrete time sequence sampling data point of the continuous temperature curve A, is the starting sampling time, and in the present application, the time when the temperature sensor array 1 detects the horizontal shale oil-water two-phase flow fluid is taken; is the fixed sampling time interval, which is taken as 1 s in the present invention; n is the total number of the sampled data points of the continuous temperature curve A, which is taken as 40 in the present invention.

[0014] The continuous temperature curve B measured by the temperature sensor array 2 is sampled, and the discrete time series obtained by sampling is: .

[0015] The discrete time series data points obtained by sampling the continuous temperature curve B are:

[0016]

[0017] wherein, is the sampled data point of the discrete time series of the continuous temperature curve B, is the time of starting sampling, which is taken as the time when the temperature sensor array 2 detects the horizontal oil-water two-phase flow fluid in the present invention, and m is the total number of the sampled data points of the continuous temperature curve B, which is taken as 40 in the present invention.

[0018] The discrete time series of the continuous temperature curve is normalized as:

[0019]

[0020] wherein, is the normalized value of the data point in the sequence, is the mean value of the discrete time series , and is the standard deviation of the discrete time series . The discrete time series of the continuous temperature curve

[0021] is normalized as:

[0022]

[0023] wherein, is the normalized value of the data point in the sequence, is the mean value of the discrete time series , and is the standard deviation of the discrete time series .

[0024] The expressions of the static consistency , correlation and shape similarity of the temperature curve A and the temperature curve B are as follows:​​​​

[0025]

[0026] in, , Temperature curves and temperature curve In the Temperature at any moment This represents a temperature curve. average temperature This represents a temperature curve. average temperature It is the cumulative distance. , They are time series , The index position, It is the sum of all local distances on the optimal time warp path.

[0027] Similarity Cumulative distance in function formula The formula is as follows:

[0028]

[0029] in, It is a local distance, expressed as:

[0030]

[0031] The stability of the horizontal shale oil-water two-phase flow within the parameter measurement device is determined by the similarity between temperature curves A and B, and the similarity between temperature curves A and B is related to static consistency. Correlation and shape similarity Based on the correlation of three parameters, the stability determination model for the horizontal shale oil-water two-phase flow within the flow parameter measurement device is established as follows:

[0032]

[0033] When temperature curves A and B meet the above conditions, the horizontal shale oil-water two-phase flow fluid in the horizontal shale oil-water two-phase flow parameter measuring device reaches a stable state.

[0034] in, The static consistency determination threshold is set to 0.3 in this invention; The correlation threshold is set to 0.9 in this invention. The similarity threshold is set to 1 in this invention.

[0035] After the horizontal shale oil-water two-phase flow fluid reaches stability, the initial temperature of the horizontal shale oil-water two-phase flow fluid is measured by the temperature sensor array 1 and the temperature sensor array 2 ;

[0036] Step two: selecting a suitable heat source generator material, controlling the heat source generator in the horizontal shale oil-water two-phase flow parameter measurement device to generate a short time and high amplitude heat pulse, and instantaneously heating the horizontal shale oil-water two-phase flow fluid to measure the flow rate of the horizontal shale oil-water two-phase flow;

[0037] To investigate the maximum temperature rise of different heat source generator materials under high temperature conditions, the thermal conductivity of metal materials is calculated using the heat conduction formula. Since the flow parameters of the horizontal shale oil-water two-phase flow fluid need to be measured at a temperature of 200-350°C, common metals cannot meet the measurement requirements under this condition. Therefore, the thermal conductivities of two metal materials, iron-chromium alloy used for preparing fireproof materials and chromium-zirconium-copper alloy used for motor commutator equipment, are compared and analyzed.

[0038] The thermal conductivity of the iron-chromium alloy is expressed as follows:

[0039]

[0040] wherein, is the thermal conductivity of the iron-chromium alloy, is the electronic thermal conductivity of the iron-chromium alloy, is the lattice thermal conductivity of the iron-chromium alloy, is the Lorentz constant of the iron-chromium alloy, is the absolute temperature, is the resistivity of the iron-chromium alloy, is the resistivity coefficient caused by solute atom scattering of the iron-chromium alloy, is the atomic fraction of the iron-chromium alloy , is the resistivity temperature coefficient caused by lattice thermal vibration scattering of the iron-chromium alloy.

[0041] The thermal conductivity of the chromium-zirconium-copper alloy is expressed as follows:

[0042]

[0043] wherein, is the thermal conductivity of the chromium-zirconium-copper alloy, is the electronic thermal conductivity of the chromium-zirconium-copper alloy, is the lattice thermal conductivity of the chromium-zirconium-copper alloy, is the Lorentz constant of the chromium-zirconium-copper alloy, is the resistivity of the chromium-zirconium-copper alloy, is the resistivity of the chromium-zirconium-copper alloy at 300K, The relative temperature coefficient of resistance for chromium-zirconium-copper alloy. These are the lattice vibration characteristic parameters of chromium-zirconium-copper alloys. The volume fraction of the precipitated phase in the chromium-zirconium-copper alloy.

[0044] Calculate at 200℃, 275℃, and 350℃ respectively, taking... The thermal conductivity of iron-chromium alloy at a value of 0.15 is:

[0045] At 200℃, the thermal conductivity of iron-chromium alloy is approximately .

[0046] At 275℃, the thermal conductivity of iron-chromium alloy is approximately .

[0047] At 350℃, the thermal conductivity of iron-chromium alloy is approximately .

[0048] Calculate at 200℃, 275℃, and 350℃ respectively, taking... 3 , It is 30. The thermal conductivity of chromium-zirconium-copper alloy is as follows, given a value of 0.015:

[0049] At 200℃, the thermal conductivity of chromium-zirconium-copper alloy is approximately .

[0050] At 275℃, the thermal conductivity of chromium-zirconium-copper alloy is approximately .

[0051] At 350℃, the thermal conductivity of chromium-zirconium-copper alloy is approximately .

[0052] Calculations and comparisons show that, under temperature conditions of 200-350℃, the thermal conductivity of chromium-zirconium-copper alloy is better than that of iron-chromium alloy. Therefore, chromium-zirconium-copper alloy was chosen as the material for the heat source generator.

[0053] To measure the flow rate of a horizontal shale oil-water two-phase flow using a thermal method, the flow velocity of the horizontal shale oil-water two-phase flow is first calculated. Temperature curves A and B correspond to the respective temperature curve functions. and temperature curve function , and cross-correlation function The expression is as follows:

[0054]

[0055] in, the whole time period from the start of recording the temperature sensor array 1 and temperature sensor array 2 signals to the stop of recording, temperature function time offset of the temperature function .

[0056] cross-correlation function reaches a maximum value, the time at which the maximum value is reached is the transit time required for the fluid to pass through the temperature sensor array 1 and temperature sensor array 2, so that the flow rate of the horizontal shale oil-water two-phase flow fluid can be calculated , which is expressed as:

[0057]

[0058] wherein, is the distance between the temperature sensor array 1 and temperature sensor array 2.

[0059] Therefore, the total flow rate of the horizontal shale oil-water two-phase flow is:

[0060]

[0061] wherein, is the total flow rate of the horizontal shale oil-water two-phase flow, is the pipe cross-sectional area of the horizontal shale oil-water two-phase flow parameter measuring device.

[0062] Step three: after the horizontal shale oil-water two-phase flow fluid heated by the heat source generator passes through the two temperature sensor arrays, the temperature signals of the horizontal shale oil-water two-phase flow in the horizontal shale oil-water two-phase flow parameter measuring device are collected, and the water cut of the horizontal shale oil-water two-phase flow is calculated;

[0063] The principle of measuring the oil content by the thermal method is as follows: the specific heat capacity of the horizontal shale oil-water two-phase flow medium is different, under the same heating condition, the oil content is different, and the temperature change of the horizontal shale oil-water two-phase flow fluid is also different. According to the law of conservation of energy, the relationship between the horizontal shale oil-water two-phase flow parameter and the heat transfer is established as follows:

[0064]

[0065] wherein, P is the released power of the heat source generator, C P is the mass specific heat capacity at constant pressure of the fluid, is the density of the horizontal shale oil-water two-phase flow fluid, is the temperature difference between the initial temperature of the temperature sensor array 1 and the horizontal shale oil-water two-phase flow fluid after stabilization .

[0066] Once the oil and water are fully mixed, according to the heat transfer principle, the upstream heat source generator releases power. The temperature sensor array 1 and the initial temperature of the horizontal shale oil-water two-phase flow after stabilization temperature difference The relation is:

[0067]

[0068] in, The specific heat capacity at constant pressure of the oil. The density of the oil, For oil content, The specific heat capacity at constant pressure of water, This is the density of water.

[0069] The total flow rate of horizontal shale oil-water two-phase flow is known. and the power of the heat source generator When the temperature sensor array 1 remains constant, the initial temperature of the horizontal shale oil-water two-phase flow after stabilization is... temperature difference With oil content The temperature changes accordingly, so as long as the initial temperature of the horizontal shale oil-water two-phase flow stabilizes, it is only necessary to obtain the temperature sensor array 1 and the initial temperature of the horizontal shale oil-water two-phase flow. temperature difference You can then obtain the oil content. expression:

[0070]

[0071] Thus, the moisture content is obtained. :

[0072] .

[0073] Step 4: The particle injector located upstream of the horizontal shale oil-water two-phase flow parameter measuring device injects a large number of hydrophilic and hydrophobic particles with different radioactive elements into the pipeline of the horizontal shale oil-water two-phase flow parameter measuring device in a short period of time. After the hydrophobic and hydrophilic particles with different radioactivity flow through the two downstream gamma ray detectors, the flow velocities of the oil phase and the water phase can be calculated.

[0074] The principle of measuring the flow velocities of the water and oil phases in horizontal shale oil-water two-phase flow is that hydrophobic and hydrophilic particles with different radioactivity are injected into the pipeline of the horizontal shale oil-water two-phase flow parameter measuring device and adsorbed onto oil droplets and water droplets respectively. Oil droplets adsorbed with radioactive hydrophobic particles form a radioactive oil phase, and water droplets adsorbed with radioactive hydrophilic particles form a radioactive water phase.

[0075] The radioactive oil phase flows through the gamma detector 1 and the gamma detector 2, and the two gamma detectors generate radioactive intensity functions in real time and the cross-correlation function of the radioactive intensity functions , and The expression of the cross-correlation function of the radioactive intensity functions is as follows:

[0076]

[0077] wherein, is the whole time from the beginning of recording the signals of the gamma detector 1 and the gamma detector 2 to the end of recording, is the time offset of the radioactive intensity function relative to the radioactive intensity function .

[0078] The radioactive water phase flows through the gamma detector 1 and the gamma detector 2, and the two gamma detectors generate radioactive intensity functions in real time and the cross-correlation function of the radioactive intensity functions , and The expression of the cross-correlation function of the radioactive intensity functions is as follows:

[0079]

[0080] wherein, is the time offset of the radioactive intensity function relative to the radioactive intensity function .

[0081] The cross-correlation function reaches the maximum value, and the obtained at this time is the transit time of the oil droplets flowing through the gamma detector 1 and the gamma detector 2, so that the oil phase flow rate can be calculated, and the expression is as follows:

[0082]

[0083] wherein, is the flow rate of the oil phase, and D is the distance between the gamma detector 1 and the gamma detector 2.

[0084] The cross-correlation function reaches the maximum value, and the obtained at this time is the transit time of the water droplets flowing through the gamma detector 1 and the gamma detector 2, so that the water phase flow rate can be calculated, and the expression is as follows:

[0085]

[0086] wherein,​​ The flow rate of the water phase.

[0087] Step five: a conversion equation model of water cut and water holdup is established, and then the water holdup of the shale oil-water two-phase flow is calculated;

[0088] Water cut The expression is as follows:

[0089]

[0090] Wherein, The water phase volumetric flow rate, The water holdup.

[0091] Slip ratio The expression is as follows:

[0092]

[0093] The slip ratio formula is substituted into the water cut expression to obtain a further water cut Expression:

[0094]

[0095] Therefore, the water holdup The expression is as follows:

[0096]

[0097] Further, the oil holdup Expression:

[0098]

[0099] The present application has the beneficial effects: a horizontal shale oil and gas well flow parameter measurement method based on thermal and radiation fusion is proposed, the method is to measure the flow rate and flow rate of horizontal shale oil-water two-phase flow through the temperature sensor array after thermal pulse heating; the temperature difference The temperature difference between the temperature sensor array 1 and the initial temperature of the horizontal shale oil-water two-phase flow after stabilization The water cut of the horizontal shale oil-water two-phase flow can be calculated; after the flow rate of the water phase and the oil phase is obtained through the particle injector and the gamma detector array, the holdup is finally derived through the conversion equation model of water cut and water holdup. The measurement accuracy of the flow parameter of the horizontal shale oil and gas production well oil-water two-phase flow is improved, and the flow parameter measurement needs of the horizontal shale oil and gas production well oil-water two-phase flow under actual conditions are met. The main advantages are as follows:

[0100] (1) The two temperature sensor arrays are used to judge the stability of the horizontal shale oil and water two-phase flow fluid, without adding other components to judge the stability of the horizontal shale oil and water two-phase flow fluid, thereby ensuring the robustness of the horizontal shale oil and water two-phase flow parameter measuring device.

[0101] (2) The heat source generator uses chromium-zirconium-copper alloy, so that the horizontal shale oil and water two-phase flow parameter measuring device can still accurately measure the horizontal shale oil and water two-phase flow parameters under the temperature condition of 200-350°C.

[0102] (3) The horizontal shale oil and water two-phase flow parameter measuring device increases the particle injector and the gamma detector, so that the flow rates of the water phase and the oil phase can be measured separately, and finally a mathematical model is established to fuse the content rate, the water phase flow rate and the oil phase flow rate, and the water cut of the horizontal shale oil and water two-phase flow is finally calculated. Through the joint calculation of multiple sensors, the accuracy and consistency of the output parameters are greatly improved. BRIEF DESCRIPTION OF DRAWINGS

[0103] Figure 1 is a schematic diagram of the horizontal shale oil and gas well flow parameter measurement method combining heat and radiation in Example 2;

[0104] Figure 2 is a comparison diagram of the water cut calculated by the method and the existing method in Example 2;

[0105] Figure 3 is a comparison diagram of the water cut accuracy after the horizontal shale oil and water two-phase flow fluid is judged to be stable by the method and the water cut accuracy measured without judging the stability of the horizontal shale oil and water two-phase flow fluid in Example 2;

[0106] Figure 4 is a comparison diagram of the measurement results of the method and the electrical and optical methods in Example 2. DETAILED DESCRIPTION

[0107] Example 1

[0108] Reference Figure 1 The horizontal shale oil and gas well flow parameter measurement method based on the combination of heat and radiation, the horizontal shale oil and water two-phase flow parameter measuring device comprises: a heat source generator, a pair of temperature sensor arrays, a particle injector, and a pair of gamma detector arrays; one heat source generator and one particle injector are installed upstream of the horizontal shale oil and water two-phase flow parameter measuring device, and a pair of temperature sensor arrays and a pair of gamma detector arrays are placed downstream of the horizontal shale oil and water two-phase flow parameter measuring device; the pair of temperature sensor arrays are respectively named temperature sensor array 1 and temperature sensor array 2, and the distance between the heat source generator and temperature sensor array 2 is The temperature sensor array 1 is placed between the temperature sensor array 2 and the heat source generator, and the distance from both is .

[0109] Example 2

[0110] Reference Figures 2-4 A method for measuring flow parameters in horizontal shale oil and gas wells based on the fusion of thermal and radiometric methods, the method comprising the following steps:

[0111] Step 1: Use temperature sensor array 1 and temperature sensor array 2 to measure whether the horizontal shale oil-water two-phase flow has reached a steady state within the horizontal shale oil-water two-phase flow parameter measurement device, and measure the initial temperature after stabilization. ;

[0112] The temperature signals collected by temperature sensor array 1 and temperature sensor array 2 inside the pipeline of the horizontal shale oil-water two-phase flow parameter measurement device are as follows: , It indicates the first An array of temperature sensors, This indicates the number of circles centered on the center of the pipe, moving clockwise from top to bottom. There are two temperature sensors, and the temperature sensors in the two temperature sensor arrays are placed in the same position. The angle between any two adjacent temperature sensors is [missing information]. , The value range is 1 and 2; The value range is 1, 2, 3, 4, 5. Take 72°.

[0113] Temperature sensor array 1 and temperature sensor array 2 can measure the temperature curve of the horizontal shale oil-water two-phase flow. By calculating the similarity between the two sets of temperature curves, it can be determined whether the horizontal shale oil-water two-phase flow in the parameter measuring device has reached a stable state.

[0114] The continuous temperature curve A measured by temperature sensor array 1 is sampled, and the resulting discrete time series is as follows: .

[0115] The discrete-time series data points obtained by sampling the continuous temperature curve A are:

[0116]

[0117] in, For a continuous temperature curve A, the discrete-time series sampling data points are used. The sampling start time is the time when the temperature sensor array 1 detects the horizontal shale oil-water two-phase flow in this invention. The sampling time interval is fixed, which is 1 second in this invention; n is the total number of sampling data points for the continuous temperature curve A, which is 40 in this invention.

[0118] The continuous temperature curve B measured by the temperature sensor array 2 is sampled, and the discrete time sequence obtained by sampling is: .

[0119] The discrete time sequence data points obtained by sampling the continuous temperature curve B are:

[0120]

[0121] wherein, is the discrete time sequence sampling data point of the continuous temperature curve B, is the time of starting sampling, in the present application, the time when the temperature sensor array 2 detects the horizontal shale oil-water two-phase flow fluid, and m is the total number of sampling data points of the continuous temperature curve B, in the present application, m is 40.

[0122] The discrete time sequence of the continuous temperature curve is normalized as:

[0123]

[0124] wherein, is the normalized value of the data point in the sequence, is the mean of the discrete time sequence, is the standard deviation of the discrete time sequence. The discrete time sequence of the continuous temperature curve is normalized as:

[0125]

[0126]

[0127] wherein, is the normalized value of the data point in the sequence, is the mean of the discrete time sequence, is the standard deviation of the discrete time sequence. The expressions of the static consistency, correlation and shape similarity of the temperature curve A and the temperature curve B are as follows:

[0128]

[0129] ​​​​​​​​​​​​​

[0130] wherein, , respectively are temperature curves and temperature curve at the first moment, denotes the average temperature of the temperature curve , denotes the average temperature of the temperature curve , is the cumulative distance, , are respectively the index positions of the time series , , is the sum of all local distances on the optimal time warping path.

[0131] The similarity function formula cumulative distance is as follows:

[0132]

[0133] wherein, is the local distance, the expression is:

[0134]

[0135] The stability of the horizontal shale oil-water two-phase flow fluid in the horizontal shale oil-water two-phase flow parameter measuring device is determined by the similarity of the temperature curve A and the temperature curve B, and the similarity of the temperature curve A and the temperature curve B is related to the static consistency , the correlation and the shape similarity three parameters, the stability determination model of the horizontal shale oil-water two-phase flow fluid in the horizontal shale oil-water two-phase flow parameter measuring device is established as follows:

[0136]

[0137] When the temperature curve A and the temperature curve B meet the above conditions, the horizontal shale oil-water two-phase flow fluid in the horizontal shale oil-water two-phase flow parameter measuring device reaches a stable state.

[0138] wherein, is the static consistency determination threshold, which is 0.3 in the present application; is the correlation threshold, which is 0.9 in the present application; is the similarity threshold, which is 1 in the present application.

[0139] The initial temperature of the horizontal shale oil-water two-phase flow fluid is measured by the temperature sensor array 1 and the temperature sensor array 2 after the horizontal shale oil-water two-phase flow fluid reaches stability ;

[0140] Step two: selecting a suitable heat source generator material, controlling the heat source generator in the horizontal shale oil-water two-phase flow parameter measurement device to generate a short-time and high-amplitude heat pulse, and instantaneously heating the horizontal shale oil-water two-phase flow fluid to measure the flow rate of the horizontal shale oil-water two-phase flow;

[0141] To investigate the maximum temperature rise of different heat source generator materials under high temperature conditions, the thermal conductivity of metal materials is calculated using the heat conduction formula. Since the flow parameters of the horizontal shale oil-water two-phase flow fluid need to be measured at a temperature of 200-350°C, common metals cannot meet the measurement requirements under this condition. Therefore, the thermal conductivities of two metal materials, iron-chromium alloy used for fireproof material and chromium-zirconium-copper alloy used for motor commutator equipment, are selected for comparative analysis.

[0142] The thermal conductivity of the iron-chromium alloy is expressed as follows:

[0143]

[0144] wherein, is the thermal conductivity of the iron-chromium alloy, is the electronic thermal conductivity of the iron-chromium alloy, is the lattice thermal conductivity of the iron-chromium alloy, is the Lorentz constant of the iron-chromium alloy, is the absolute temperature, is the resistivity of the iron-chromium alloy, is the resistivity coefficient caused by solute atom scattering of the iron-chromium alloy, is the atomic fraction of the iron-chromium alloy , is the resistivity temperature coefficient caused by lattice thermal vibration scattering of the iron-chromium alloy.

[0145] The thermal conductivity of the chromium-zirconium-copper alloy is expressed as follows:

[0146]

[0147] wherein, is the thermal conductivity of the chromium-zirconium-copper alloy, is the electronic thermal conductivity of the chromium-zirconium-copper alloy, is the lattice thermal conductivity of the chromium-zirconium-copper alloy, is the Lorentz constant of the chromium-zirconium-copper alloy, is the resistivity of the chromium-zirconium-copper alloy, is the resistivity of the chromium-zirconium-copper alloy at 300K, is the relative resistivity temperature coefficient of the chromium-zirconium-copper alloy, is a chromium-zirconium-copper alloy lattice vibration characteristic parameter, is a chromium-zirconium-copper alloy precipitated phase volume fraction.

[0148] The thermal conductivity of the iron-chromium alloy is calculated under the conditions that the temperature is 200℃, 275℃, 350℃, the value of is 0.15, respectively. The thermal conductivity of the iron-chromium alloy is calculated under the conditions that the temperature is 200℃, 275℃, 350℃, the value of is 0.15, respectively.

[0149] The thermal conductivity of the iron-chromium alloy is calculated under the conditions that the temperature is 200℃, 275℃, 350℃, the value of is 0.15, respectively. .

[0150] The thermal conductivity of the iron-chromium alloy is calculated under the conditions that the temperature is 200℃, 275℃, 350℃, the value of is 0.15, respectively. .

[0151] The thermal conductivity of the iron-chromium alloy is calculated under the conditions that the temperature is 200℃, 275℃, 350℃, the value of is 0.15, respectively. .

[0152] The thermal conductivity of the iron-chromium alloy is calculated under the conditions that the temperature is 200℃, 275℃, 350℃, the value of is 0.15, respectively. , , is 30, is 0.015, respectively.

[0153] The thermal conductivity of the iron-chromium alloy is calculated under the conditions that the temperature is 200℃, 275℃, 350℃, the value of is 0.15, respectively. .

[0154] The thermal conductivity of the iron-chromium alloy is calculated under the conditions that the temperature is 200℃, 275℃, 350℃, the value of is 0.15, respectively. .

[0155] The thermal conductivity of the iron-chromium alloy is calculated under the conditions that the temperature is 200℃, 275℃, 350℃, the value of is 0.15, respectively. .

[0156] The thermal conductivity of the iron-chromium alloy is calculated under the conditions that the temperature is 200℃, 275℃, 350℃, the value of is 0.15, respectively.

[0157] The horizontal shale oil-water two-phase flow rate is calculated first, and then the horizontal shale oil-water two-phase flow rate is measured by using the thermal method. Temperature curve A and temperature curve B correspond to temperature curve functions and , and , respectively. The expression of the cross-correlation function of the temperature sensor array from the start of recording the temperature sensor array 1 and the temperature sensor array 2 signal to the stop of recording the whole period is as follows:

[0158]

[0159] Among them, is the whole period from the start of recording the temperature sensor array 1 and the temperature sensor array 2 signal to the stop of recording. temperature function time offset relative to the temperature function .

[0160] cross-correlation function reaches a maximum value, the time taken to reach the maximum value is the transit time taken by the fluid to flow through the temperature sensor array 1 and the temperature sensor array 2, so that the flow rate of the horizontal shale oil-water two-phase flow fluid can be calculated , which is expressed as:

[0161]

[0162] wherein, is the distance between the temperature sensor array 1 and the temperature sensor array 2.

[0163] Therefore, the total flow rate of the horizontal shale oil-water two-phase flow is:

[0164]

[0165] wherein, is the total flow rate of the horizontal shale oil-water two-phase flow, is the pipe cross-sectional area of the horizontal shale oil-water two-phase flow parameter measuring device.

[0166] Step three: after the horizontal shale oil-water two-phase flow fluid heated by the heat source generator flows through the two temperature sensor arrays, the temperature signal of the horizontal shale oil-water two-phase flow in the horizontal shale oil-water two-phase flow parameter measuring device is collected, and the water cut of the horizontal shale oil-water two-phase flow is calculated;

[0167] The principle of measuring oil content by the thermal method is as follows: the specific heat capacity of the horizontal shale oil-water two-phase flow medium is different, under the same heating condition, the oil content is different, and the temperature change of the horizontal shale oil-water two-phase flow fluid is also different. According to the law of conservation of energy, the relationship between the horizontal shale oil-water two-phase flow parameter and the heat transfer is established as follows:

[0168]

[0169] wherein, P is the released power of the heat source generator, C P is the mass specific heat capacity at constant pressure of the fluid, is the density of the horizontal shale oil-water two-phase flow fluid, is the temperature difference between the initial temperature of the temperature sensor array 1 and the horizontal shale oil-water two-phase flow fluid after stabilization .

[0170] When the oil and water are fully mixed, according to the heat transfer law, the released power of the upstream heat source generator The temperature difference between the initial temperature of the temperature sensor array 1 and the stable temperature of the horizontal oil-water two-phase flow fluid The relationship between the temperature difference between the initial temperature of the temperature sensor array 1 and the stable temperature of the horizontal oil-water two-phase flow fluid The relationship is:

[0171]

[0172] Wherein, Cp, oil, is the specific heat capacity of oil at constant pressure, is the density of oil, is the oil content, Cp, water, is the specific heat capacity of water at constant pressure, is the density of water.

[0173] The total flow rate of the horizontal oil-water two-phase flow is known The power of the heat source generator is constant The temperature difference between the initial temperature of the temperature sensor array 1 and the stable temperature of the horizontal oil-water two-phase flow fluid Changes with the oil content Therefore, as long as the temperature difference between the initial temperature of the temperature sensor array 1 and the stable temperature of the horizontal oil-water two-phase flow fluid Changes with the oil content The oil content The expression is:

[0174]

[0175] Further, the water content :

[0176] .

[0177] Step four: The particle injector located upstream of the horizontal oil-water two-phase flow parameter measurement device injects a large number of hydrophilic particles and hydrophobic particles with different radioactive elements into the pipeline of the horizontal oil-water two-phase flow parameter measurement device in a short time. The flow of hydrophobic particles and hydrophilic particles with different radioactivity through the downstream two gamma ray detectors can calculate the flow rate of the oil phase and the water phase;

[0178] The principle of measuring the flow rate of the water phase and the oil phase in the horizontal oil-water two-phase flow is that the hydrophobic particles and hydrophilic particles with different radioactivity injected into the pipeline of the horizontal oil-water two-phase flow parameter measurement device are respectively adsorbed on oil droplets and water droplets in the horizontal oil-water two-phase flow. The oil droplets adsorbed with radioactive hydrophobic particles form a radioactive oil phase, and the water droplets adsorbed with radioactive hydrophilic particles form a radioactive water phase.

[0179] The radioactive oil phase flows through the gamma detector 1 and the gamma detector 2, and the two gamma detectors generate a radioactive intensity function in real time​ and radioactive intensity function , and cross-correlation function The expression of the cross-correlation function

[0180]

[0181] wherein, is the whole time from the beginning of recording the gamma detector 1 signal and the gamma detector 2 signal to the end of recording, is the time offset of the radioactive intensity function relative to the radioactive intensity function .

[0182] The radioactive water phase flows through the gamma detector 1 and the gamma detector 2, and the two gamma detectors generate the radioactive intensity function and the radioactive intensity function , and cross-correlation function The expression of the cross-correlation function

[0183]

[0184] wherein, is the time offset of the radioactive intensity function relative to the radioactive intensity function .

[0185] The cross-correlation function reaches the maximum value, and the obtained at this time is the transit time required for the oil droplets to flow through the gamma detector 1 and the gamma detector 2, so that the oil phase flow rate can be calculated, and the expression is:

[0186]

[0187] wherein, is the flow rate of the oil phase, and D is the distance between the gamma detector 1 and the gamma detector 2.

[0188] The cross-correlation function reaches the maximum value, and the obtained at this time is the transit time required for the water droplets to flow through the gamma detector 1 and the gamma detector 2, so that the water phase flow rate can be calculated, and the expression is:

[0189]

[0190] wherein, is the flow rate of the water phase.

[0191] Step five: a conversion equation model of water content and water holdup is established, and then the water holdup of the shale oil-water two-phase flow is calculated;

[0192] Water content The expression is as follows:

[0193]

[0194] Wherein, The water phase volume flow rate, The water holdup.

[0195] Slip ratio The expression is as follows:

[0196]

[0197] The slip ratio formula is substituted into the water content expression to obtain a further water content Expression:

[0198]

[0199] Therefore, the water holdup The expression is as follows:

[0200]

[0201] Further, the oil holdup Expression:

[0202]

[0203] The present application establishes a mathematical model, combines the content, water phase flow rate and oil phase flow rate, and finally calculates the water holdup of the horizontal shale oil-water two-phase flow. Figure 2 It can be known from Figure 2 that the water holdup measurement method of the present application is higher than the existing method under different water holdups, and the maximum error of the present method is 3.3%, while the maximum error of the existing method is 4.2%.

[0204] Under the same water holdup, the present application uses two temperature sensor arrays to judge the stability of the horizontal shale oil-water two-phase flow fluid, and the experimental results are shown in Figure 3 It can be known from Figure 3 that in 10 experiments, the method of using two temperature sensor arrays to judge the stability of the horizontal shale oil-water two-phase flow fluid is stable and reliable, and the measurement results of the existing method without judging the fluid stability are reliable for 2 times and unreliable for 8 times.

[0205] The present method, electrical method and optical method are used to measure the water holdup of 5-50%, and the measurement results are as followsFigure 4 .Depend on Figure 4 It can be seen that the error of this method at each measurement point is smaller than that of the electrical method and the optical method. The maximum deviation of this method is 2.45%, the maximum deviation of the electrical method is 3.56%, and the maximum deviation of the optical method is 3.45%.

Claims

1. A method for measuring flow parameters in horizontal shale oil and gas wells based on the fusion of thermal and radiometric methods, characterized in that: The measurement method includes the following steps: Step 1: Determine whether the horizontal shale oil-water two-phase flow within the horizontal shale oil-water two-phase flow parameter measuring device has reached a steady state, and measure the initial temperature after stabilization. ; Step 2: Select a suitable heat source generator material, control the heat source generator in the horizontal shale oil-water two-phase flow parameter measuring device to generate short-duration, high-amplitude heat pulses, instantaneously heat the horizontal shale oil-water two-phase flow fluid, and then measure the flow rate of the horizontal shale oil-water two-phase flow. Step 3: After the horizontal shale oil-water two-phase flow heated by the heat source generator flows through two temperature sensor arrays, the temperature signal of the horizontal shale oil-water two-phase flow in the parameter measurement device is collected, and the water cut of the horizontal shale oil-water two-phase flow is calculated. Step 4: The particle injector located upstream of the horizontal shale oil-water two-phase flow parameter measuring device injects a large number of hydrophilic and hydrophobic particles with different radioactive elements into the pipeline of the horizontal shale oil-water two-phase flow parameter measuring device in a short period of time. After the hydrophobic and hydrophilic particles with different radioactivity flow through the two downstream gamma ray detectors, the flow velocities of the oil phase and the water phase are calculated. Step 5: Establish a conversion equation model between water cut and water holdup, and then calculate the holdup of shale oil-water two-phase flow.

2. The method for measuring flow parameters of horizontal shale oil and gas wells based on thermal and radiometric fusion as described in claim 1, characterized in that: The method for determining whether the horizontal shale oil-water two-phase flow has reached a steady state within the horizontal shale oil-water two-phase flow parameter measurement device is as follows: The temperature signals collected by temperature sensor array 1 and temperature sensor array 2 inside the pipeline of the horizontal shale oil-water two-phase flow parameter measurement device are as follows: , It indicates the first An array of temperature sensors, This indicates the number of circles centered on the center of the pipe, moving clockwise from top to bottom. There are two temperature sensors, and the temperature sensors in the two temperature sensor arrays are placed in the same position. The angle between any two adjacent temperature sensors is [missing information]. , The value range is 1 and 2; The value range is 1, 2, 3, 4, 5; The continuous temperature curve A measured by temperature sensor array 1 is sampled, and the resulting discrete time series is as follows: ; The discrete-time series data points obtained by sampling the continuous temperature curve A are: ； in, For a continuous temperature curve A, sample data points are taken from discrete time series. The sampling start time is the time when the temperature sensor array 1 detects the horizontal shale oil-water two-phase flow in this invention. is a fixed sampling time interval; n is the total number of sampling data points for the continuous temperature curve A; The continuous temperature curve B measured by temperature sensor array 2 is sampled, and the resulting discrete time series is as follows: ; The discrete-time series data points obtained by sampling the continuous temperature curve B are: ； in, For the continuous temperature curve B, the discrete-time series sampling data points are used. The sampling start time is the time when the temperature sensor array 2 detects the horizontal shale oil-water two-phase flow in this invention, and m is the total number of sampling data points of the continuous temperature curve B. For continuous temperature curves Discrete time series Standardize: ； in, for Data points in the sequence Standardized value Discrete time series The mean, Discrete time series Standard deviation; For continuous temperature curves Discrete time series Standardize: ； in, for Data points in the sequence Standardized value Discrete time series The mean, Discrete time series Standard deviation; Static consistency between temperature curve A and temperature curve B Correlation and shape similarity The expression is as follows: ； in, , Temperature curves and temperature curve In the Temperature at any moment This represents a temperature curve. average temperature This represents a temperature curve. average temperature It is the cumulative distance. , They are time series , The index position, This is the sum of all local distances on the optimal time warp path; Similarity Cumulative distance in function formula The formula is as follows: ； in, It is a local distance, expressed as: ； The stability determination model for the horizontal shale oil-water two-phase flow within the flow parameter measurement device is as follows: ； When temperature curves A and B meet the above conditions, the horizontal shale oil-water two-phase flow fluid in the horizontal shale oil-water two-phase flow parameter measuring device reaches a stable state. in, This is the threshold for determining static consistency. This is the correlation threshold. This is the similarity threshold.

3. The method for measuring flow parameters of horizontal shale oil and gas wells based on thermal and radiometric fusion as described in claim 2, characterized in that: The selection of heat source generator materials and the calculation method for the flow rate of horizontal shale oil-water two-phase flow are as follows: The thermal conductivity of iron-chromium alloys is expressed as follows: ； in, For the thermal conductivity of iron-chromium alloy, For the electronic thermal conductivity of iron-chromium alloy, The lattice thermal conductivity of iron-chromium alloys, The Lorentz constant for iron-chromium alloys is... Absolute temperature The resistivity of iron-chromium alloy, The resistivity coefficient is caused by the scattering of solute atoms in the iron-chromium alloy. Iron-chromium alloy Atomic fraction, The resistivity temperature coefficient is caused by thermal vibration scattering of the iron-chromium alloy lattice. The thermal conductivity of chromium-zirconium-copper alloy is expressed as follows: ； in, For the thermal conductivity of chromium-zirconium-copper alloy, For the electronic thermal conductivity of chromium-zirconium-copper alloy, The lattice thermal conductivity of chromium-zirconium-copper alloy is... The Lorentz constant for chromium-zirconium-copper alloys is... The resistivity of chromium-zirconium-copper alloy is... The resistivity of chromium-zirconium-copper alloy at 300K. The relative temperature coefficient of resistance for chromium-zirconium-copper alloy. These are the lattice vibration characteristic parameters of chromium-zirconium-copper alloys. The volume fraction of precipitated phases in chromium-zirconium-copper alloy; At temperatures of 200-350℃, chromium-zirconium-copper alloy has better thermal conductivity than iron-chromium alloy, so chromium-zirconium-copper alloy is chosen as the material for the heat source generator. The transit time required for the volume flow to pass through temperature sensor array 1 and temperature sensor array 2 is obtained by cross-correlation method. The flow velocity of horizontal shale oil-water two-phase flow The expression is: ； in, The distance between temperature sensor array 1 and temperature sensor array 2; Therefore, the total flow rate of the horizontal shale oil-water two-phase flow is: ； in, This represents the total flow rate of the horizontal shale oil-water two-phase flow. The cross-sectional area of ​​the pipe for measuring the parameters of a horizontal shale oil-water two-phase flow device.

4. The method for measuring flow parameters of horizontal shale oil and gas wells based on thermal and radiometric fusion as described in claim 3, characterized in that: The method for calculating the water cut of horizontal shale oil-water two-phase flow is as follows: Based on the law of conservation of energy, the relationship between the flow parameters and heat transfer in horizontal shale oil-water two-phase flow is established as follows: ； Where P is the power released by the heat source generator, and C P The specific heat capacity at constant pressure for fluid mass. The fluid density of a horizontal shale oil-water two-phase flow. The initial temperature of the horizontal shale oil-water two-phase flow after the temperature sensor array 1 stabilizes. Temperature difference; Once the oil and water are fully mixed, according to the heat transfer principle, the upstream heat source generator releases power. The temperature sensor array 1 and the initial temperature of the horizontal shale oil-water two-phase flow after stabilization temperature difference The relation is: ； in, The specific heat capacity at constant pressure of the oil. The density of the oil, For oil content, The specific heat capacity at constant pressure of water, The density of water; The total flow rate of horizontal shale oil-water two-phase flow is known. and the power of the heat source generator When the temperature sensor array 1 remains constant, the initial temperature of the horizontal shale oil-water two-phase flow after stabilization is... temperature difference With oil content The temperature changes accordingly, so as long as the initial temperature of the horizontal shale oil-water two-phase flow stabilizes, it is only necessary to obtain the temperature sensor array 1 and the initial temperature of the horizontal shale oil-water two-phase flow. temperature difference You can then obtain the oil content. expression: ； Thus, the moisture content is obtained. : 。 5. The method for measuring flow parameters of horizontal shale oil and gas wells based on thermal and radiometric fusion as described in claim 4, characterized in that: The calculation method for the flow velocities of the oil and water phases in horizontal shale oil-water two-phase flow is as follows: Radioactivity intensity function obtained by cross-correlation method Relative to the function of radioactivity intensity time offset and radioactivity intensity function Relative to the function of radioactivity intensity time offset Oil phase flow rate and water phase velocity The expression is as follows: ； Where D is the distance between gamma detector 1 and gamma detector 2.

6. The method for measuring flow parameters of horizontal shale oil and gas wells based on thermal and radiometric fusion as described in claim 5, characterized in that: The method for calculating the holdup of horizontal shale oil-water two-phase flow is as follows: Moisture content expression: ； in, The volumetric flow rate of the aqueous phase. For water holding capacity, It is the slip ratio; Water holding capacity The expression is as follows: ； Oil retention rate The expression is as follows: 。

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