CN114991747A - Shale oil yield interpretation method based on annular array probe measurement - Google Patents
Shale oil yield interpretation method based on annular array probe measurement Download PDFInfo
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/002—Survey of boreholes or wells by visual inspection
- E21B47/0025—Survey of boreholes or wells by visual inspection generating an image of the borehole wall using down-hole measurements, e.g. acoustic or electric
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
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Abstract
The invention discloses a shale oil yield interpretation method based on annular array probe measurement, which comprises the following steps: establishing a multi-speed logging database; correcting the position of the annular array probe; processing data and imaging the holdup of the annular array holdup instrument; processing data and imaging speed of the annular turbine flowmeter; calculating PVT physical property parameters; constructing a drift model; calculating the accumulated yield and net yield of each layer of the downhole multiple production layers; and converting the accumulated yield and each layer of net yield into ground flow data. The method utilizes an annular array holdup instrument to identify the measurement of an oil-water interface, a local holdup and an average holdup from low water content to high water content, and combines an interpolation imaging algorithm to obtain two-dimensional holdup imaging of oil and water when the oil and water flows in a shaft; the method comprises the steps of measuring local speeds and average speeds at different positions in a shaft by using an annular turbine flowmeter, obtaining a speed distribution rule of oil and water flowing in the shaft by combining a speed fitting algorithm, and calculating the flow of a shale oil single-layer oil phase and a shale oil phase based on a drift model.
Description
Technical Field
The invention relates to the technical field of dynamic monitoring in oil development, in particular to a shale oil yield interpretation method based on annular array probe measurement.
Background
The reserves of domestic shale oil resources are rich, and the shale oil resources are one of important unconventional oil and gas reservoir resources and have higher exploitation value, but the current interpretation method research on the yield of a single shale oil production layer is few. When a shale oil reservoir is exploited, horizontal well drilling, segmented hydraulic fracturing and multi-stage perforation are mainly adopted, and the problems that the existing single retention rate probe and the single turbine flow logging are few in acquisition parameters, large in error, incapable of accurately identifying the actual condition of oil-water flow in a shaft, poor in interpretation effect of shale oil single-layer yield, low in precision and the like due to the fact that the output layers are multiple, single-layer yield is low, oil-water is simultaneously output, the change range of water content is wide, and the oil-water flow state in the shaft is complex exist.
Disclosure of Invention
In order to solve the technical problems, the invention discloses a shale oil yield interpretation method based on annular array probe measurement, which utilizes an annular array holdup instrument and the improved output profile test data of an annular array turbine in a shale oil well to comprehensively interpret the holdup and flow rate under multi-pass speed measurement.
In order to achieve the purpose, the invention adopts the following technical scheme:
a shale oil production interpretation method based on annular array probe measurement comprises the following steps:
s1: establishing a multi-speed logging database;
s2: correcting the position of the annular array probe;
s3: processing data and imaging the persistence rate by using an annular array persistence rate instrument;
s4: processing data and imaging speed of the annular turbine flowmeter;
s5: calculating PVT physical property parameters;
s6: constructing a drift model;
s7: calculating the accumulated yield and net yield of each layer of the downhole multiple production layers;
s8: and converting the accumulated yield and each layer of net yield into ground flow data.
Optionally, in step S1, the step of establishing a multi-velocity logging database includes:
s11 collecting on-site logging data including response data of each probe, rotation angle, well deviation data, well diameter data, temperature and pressure data in a shaft, ground single-day production data and shaft perforation data;
s12, selecting intervals as explanation layers according to the characteristics of the fracturing section, the perforation cluster, the measurement data of each probe and the temperature and pressure curve data in the shaft, and carrying out curve value taking on the intervals.
Optionally, in step S2, in the step of performing position correction on the circular array probe, the circular array probe includes a circular array capacitance probe CAT and a circular array resistance probe RAT, where the position correction on the circular array capacitance probe CAT includes:
defining X, Y axial direction, defining the starting direction of No. 1 probe in the positive direction of Y axis, each probe is distributed at equal intervals around the annular instrument, and the position of the annular array capacitance probe CAT in the section of the shaft is corrected as follows:
in the formula, CAL is the diameter of a shaft and the unit is mm; CATROT is the rotation angle of the annular array capacitance probe CAT, and the unit is rad; ROT i Is the starting angle of the ith probe in rad.
Optionally, in step S3, the step of data processing and rate-of-rotation imaging of the circular array rate-of-rotation instrument includes:
s31, calculating the local water holding rate value around each probe according to the calibration value of each probe of the annular array water holding rate instrument, wherein the local water holding rate calculation formula of the annular array capacitance probe CAT is as follows:
in the formula, Y wi The local water holding rate of the I probe of the annular array capacitor CAT; CPS i The original response value of the I & ltth & gt probe of the annular array capacitor CAT is cps; CPSW i For annular array capacitor CATThe response value of the ith probe in pure water is cps; CPSO i The response value of the ring array capacitor CAT ith probe in the pure oil is cps;
the calculation formula of the local water holding rate of the annular array resistance probe RAT is as follows:
in the formula, Y wi Local water holding capacity of the ith probe of the annular array resistor RAT; CPS i Is the original response value of the ith probe of the annular array resistor RAT, and the unit is cps; CPSW i Is the response value of the ith probe of the annular array resistor RAT in pure water, and the unit is cps; sigma i 2 The standard deviation of the original response value of the ith probe of the annular array resistance probe RAT is obtained;
s32, interpolating the local water holdup of the annular array capacitance probe CAT and the annular array resistance probe RAT, regarding the cross section of the shaft as a circle with the actual diameter of the shaft, and performing grid division on the circle; interpolating other grids through the local water holding rate, and calculating to obtain the average water holding rate of the cross section of the shaft under the current speed measurement; finally, weighted accumulation is carried out on the shaft section water holdup calculated by the plurality of speed measurement data, and the average water holdup of the shaft section under the plurality of speed measurements is obtained;
s33, drawing a retention rate two-dimensional imaging graph, visually expressing the oil-water distribution of each explanation layer, and visualizing the oil-water two-phase distribution condition of the current explanation layer.
Optionally, in step S4, the step of annular turbine flowmeter data processing and speed imaging includes:
s41, intersecting the response value of each turbine of the array turbine flowmeter with the corresponding cable speed;
the response intercept of the turbine cable response relation on the x axis is the apparent fluid velocity V a According to the slope K, Va of the turbine intersection and the calibrated response value of each probe of the turbine flowmeter under pure oil and pure water, the starting speed V of the turbine Ti And calculating to obtain the local average flow speed of the turbine, wherein the formula is as follows:
in the formula, V fi The fluid flow rate of the coverage area of the ith turbine is m/s; RPS i Is the ith turbine response value in rps; k is i Is the response slope of the ith turbine; v Ti The response intercept of the ith turbine response relation on the x axis, namely the starting speed, is in m/s; v LSPD The speed is measured by pulling, namely the speed of the cable, and is generally marked as negative in the upper measurement and positive in the lower measurement, wherein the unit is m/min;
s42, assuming that the flow velocity of the fluid at the same height in the shaft is the same, projecting all turbines onto the perpendicular bisector of the shaft section, fitting the local flow velocity of the turbine at different height points by using a polynomial to obtain a fitting curve, and then integrating the fitting curve in the vertical direction, wherein the average flow velocity calculation formula of the multiphase flow at the shaft section is as follows:
in the formula (I), the compound is shown in the specification,
is the average wellbore flow rate; r is the inner diameter of a shaft and is in mm; wherein f (h) is a polynomial obtained by fitting the local flow velocity of each turbine probe to the height of the turbine projected onto the perpendicular bisector; h is the height in the section of the shaft and is in mm, the polynomial takes the height (h) of each turbine as an independent variable, and the flow speed (v) represented by the rotating speed of the turbine is a dependent variable;
s43 visualizes the average flow velocity of the cross section of the shaft, visually observes the flow velocity change of the fluid in the cross section, adopts a grid interpolation method for the velocity imaging of the cross section of the shaft, endows the grid where the array turbine flowmeter is located with the local flow velocity calculated in the formula (5), and interpolates other grids through the assigned grids.
Optionally, in step 5, the fluid PVT physical parameters are mainly used to determine the retention rate and slip speed of the interpretation layer in the production logging interpretation, which affects the result of the production logging interpretation. Through calculation of PVT physical property parameters, the phase state of multiphase flow in the logging can be determined, and conversion of downhole production to surface production is completed.
Optionally, in step S6, the step of constructing the drift model includes:
s61 calculating the speed limit U of single bubble in infinite continuous phase through the density of water, the density of oil, the gravity acceleration and the surface tension of oil-water two-phase ∞ ；
S62 passing the data point
Respectively determining bubble diameter indexes n corresponding to the annular array capacitance probe CAT and the annular array resistance probe RAT under the distribution condition when the bubble diameter indexes n take different values;
the S63 drift model is as follows:
U d ＝C 0 U m +U dj (7)
U dj ＝C 0 U m +U ∞ (1-Y d ) n (8)
in the formula of U d Refers to the phase velocity of the dispersed phase; c 0 Is the phase distribution coefficient, passing C 0 And Y w Fitting to obtain C 0 As the coefficient of variation of the drift model; u shape m The flow rate of the oil phase and the water phase is the mixing flow rate; u shape ∞ Is the velocity limit of a single bubble in an infinite continuous phase; u shape dj Is the drift velocity of the dispersed phase.
Optionally, in step 7, a drift model is established according to the average holding rate data, the average flow rate data and the PVT physical property parameter calculation results and according to the formula (7) and the formula (8), and the downhole accumulated yield is calculated.
Alternatively, in step S8, the yield calculated by each interpretation layer is the accumulated yield, and the net yield of a single interpretation layer is the difference between the accumulated yield of the interpretation layer and the accumulated yields of the interpretation layers adjacent to the interpretation layer and having larger depth values.
The beneficial effect of the invention is that,
1. aiming at the characteristics of more shale oil production layers and low single-layer yield, the annular array probe instrument combined by the annular array holdup instrument and the annular array turbine flowmeter is adopted to acquire data, the acquired data is comprehensively interpreted, holdup imaging and speed imaging for dynamically displaying the oil-water two-phase flow state in a shaft can be realized, main production layers are accurately found, the oil phase flow and the water phase flow of each main production layer are accurately calculated, and technical support is provided for efficient development of shale oil.
2. According to the invention, the oil-water interface identification, the measurement of local holding rate and average holding rate from low water content to high water content can be effectively identified by using the annular array capacitance probe and the annular array resistance probe, and the holding rate two-dimensional imaging of oil-water flowing in a shaft is obtained by combining an interpolation imaging algorithm; the annular turbine flowmeter with the diameter of the turbine blade increased can be used for measuring local speeds and average speeds at different positions in a shaft, a speed fitting algorithm is combined to obtain a speed distribution rule of oil and water flowing in the shaft, and a drift model is established based on different instrument combinations and flow patterns and is effectively used for accurately calculating the flow of a shale oil single-layer oil phase and a water phase.
Drawings
FIG. 1 is a flow chart of a shale oil production interpretation method based on annular array probe measurement according to the present invention;
FIG. 2 is a block diagram of a circular array probe of the present invention, wherein (a) is a schematic structural diagram of a circular array capacitive probe or a circular array resistive probe, and (b) is a schematic structural diagram of a circular array turbine flowmeter;
FIG. 3 is a schematic diagram of a CAT position calibration set-up coordinate system of the circular array capacitance probe of the present invention;
FIG. 4 is a diagram of the position calibration of the circular array probe of the present invention, wherein a1 and a2 are diagrams of CAT position calibration of the circular array capacitive probe, a1 is before the position calibration, a2 is after the position calibration, and CAT1 is number 1 probe of CAT instrument; b1 and b2 are position correction graphs of the improved ring array turbine MSAT, b1 is before position correction, b2 is after position correction, and SAT1 is the number 1 turbine of MSAT;
FIG. 5 is a schematic representation of wellbore cross-sectional meshing of the present invention;
FIG. 6 is a graph of two-dimensional rate of retention imaging for the present invention, wherein (a) is two-dimensional rate of retention imaging for the capacitive ring array CAT and (b) is two-dimensional rate of retention imaging for the resistive ring array RAT;
FIG. 7 is a graph of turbine speed versus cable speed for the present invention;
FIG. 8 is a velocity two-dimensional imaging plot of the present invention;
FIG. 9 is a flow chart of PVT physical property parameter calculation according to the present invention;
FIG. 10 is a W-well shale oil-water two-phase interpretation result diagram of the invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
A shale oil production interpretation method based on annular array probe measurement, as shown in fig. 1, comprising the following steps:
s1: establishing a multi-speed logging database;
s2: correcting the position of the annular array probe;
s3: processing data and imaging the holdup of the annular array holdup instrument;
s4: processing data and imaging speed of the annular turbine flowmeter;
s5: calculating PVT physical property parameters;
s6: constructing a drift model;
s7: calculating the accumulated yield and net yield of each layer of the downhole multiple production layers;
s8: and converting the accumulated yield and each layer of net yield into ground flow data.
Optionally, in step S1, the step of establishing a multi-velocity logging database includes:
s11 collecting on-site logging data including response data of each probe, rotation angle, well deviation data, well diameter data, temperature and pressure data in a shaft, ground single-day production data and shaft perforation data; the structure of the annular array probe is shown in fig. 2 and comprises an annular array capacitance probe, an annular array resistance probe and an annular array turbine, wherein the annular array capacitance probe is formed by distributing 12 micro capacitance sensors on the radial section of a shaft at equal intervals; the annular array resistance probe is similar to the annular array capacitance probe, and 12 miniature resistance sensors are distributed on the radial section of the shaft at equal intervals; the annular array turbines are 6 turbines which are distributed on the radial section of the shaft at equal intervals;
s12, selecting the interval as the explaining layer according to the characteristics of the fracturing segment, the perforation cluster, the measurement data of each probe and the temperature and pressure curve data in the shaft, and carrying out curve value taking on the layered segment.
Optionally, in step S2, in the step of performing position correction on the circular array probe, the circular array probe includes a circular array capacitance probe CAT and a circular array resistance probe RAT, and the circular array capacitance probe CAT, the circular array resistance probe RAT, and the modified circular array turbine MSAT which the diameter of the turbine blade is increased rotate with the influence of the flow velocity during measurement, and the position correction needs to be performed according to the measured rotation angle. The RAT calibration concept of the circular array resistance probe is consistent with that of the circular array capacitance probe CAT. Wherein, annular array capacitance probe CAT position correction includes:
defining X, Y axial direction, as shown in fig. 3, and defining the starting direction of probe No. 1 in the positive direction of Y axis, 12 probes are distributed at equal intervals around the ring instrument, and after the position correction of the ring array capacitance probe CAT in the cross section of the shaft:
in the formula, CAL is the diameter of a shaft and the unit is mm; CATROT is the rotation angle of the annular array capacitance probe CAT, and the unit is rad; ROT i Is the starting angle of the ith probe in rad.
The annular array holdup meter positions and annular array turbine meter positions before and after calibration are shown in fig. 4.
Optionally, in step S3, the step of data processing and rate-of-rotation imaging of the circular array rate-of-rotation instrument includes:
s31 retention data reflects the proportion of oil phase and water phase of the current interpretation layer, and local water retention values around the probes are calculated according to the calibration values of the probes of the annular array retention instrument, wherein the local water retention calculation formula of the annular array capacitance probe CAT is as follows:
in the formula, Y wi The local water holding rate of the I probe of the annular array capacitor CAT; CPS i The original response value of the I & ltth & gt probe of the annular array capacitor CAT is cps; CPSW i Is the response value of the ring array capacitor CAT ith probe in pure water, and the unit is cps; CPSO i The response value of the ring array capacitor CAT ith probe in the pure oil is cps;
the calculation formula of the local water holding rate of the annular array resistance probe RAT is as follows:
in the formula, Y wi Local water holding capacity of the ith probe of the annular array resistor RAT; CPS i Is the original response value of the ith probe of the annular array resistor RAT, and the unit is cps; CPSW i Is the response value of the ith probe of the annular array resistor RAT in pure water, and the unit is cps; sigma i 2 For the original response of the ith probe of the annular array resistance probe RATStandard deviation of response values;
s32, interpolating the local water holdup of the annular array capacitance probe CAT and the annular array resistance probe RAT, regarding the cross section of the shaft as a circle with the actual diameter of the shaft, and meshing the circle, as shown in FIG. 5; interpolating other grids through the local water holding rate, and calculating to obtain the average water holding rate of the cross section of the shaft under the current speed measurement; finally, weighted accumulation is carried out on the shaft section water holdup calculated by a plurality of speed measurement data to obtain the average water holdup of the shaft section under a plurality of times of speed measurement, and the influence of the problem data condition in the measurement process of a single speed measuring instrument is reduced;
s33, drawing a retention rate two-dimensional imaging graph, visually expressing the oil-water distribution of each interpretation layer, and visualizing the oil-water two-phase distribution condition of the current interpretation layer;
the image of the retention rate of an explanation layer is shown in fig. 6, wherein the black color of the upper layer is oil, the gray black color of the lower layer is water, and the white color of the middle layer is oil-water two-phase mixture. And judging whether the retention value of each grid represents an oil phase or a water phase according to the calculated retention data of the grids, and then imaging the retention according to the retention value.
Optionally, in step S4, the step of annular turbine flowmeter data processing and speed imaging includes:
s41 intersecting the response values of each turbine of the array turbine flow meter with the corresponding cable speed, the intersection graph is shown in fig. 7;
the response intercept of the turbine cable response relation on the x axis is the apparent fluid velocity V a According to the slope K, Va of the turbine intersection and the calibrated response value of each probe of the turbine flowmeter under pure oil and pure water, the starting speed V of the turbine Ti And calculating to obtain the local average flow speed of the turbine, wherein the formula is as follows:
in the formula, V fi The fluid flow rate of the coverage area of the ith turbine is m/s; RPS i Is the ith turbine response value in rps; k i Of the ith turbineA response slope; v Ti The response intercept of the ith turbine response relation on the x axis, namely the starting speed, is in the unit of m/s; v LSPD The speed is measured by pulling, namely the speed of the cable, and is generally marked as negative in the upper measurement and positive in the lower measurement, wherein the unit is m/min;
s42, assuming that the flow velocity of the fluid at the same height in the shaft is the same, projecting all turbines onto the perpendicular bisector of the shaft section, fitting the local flow velocity of the turbine at different height points by using a polynomial to obtain a fitting curve, and then integrating the fitting curve in the vertical direction, wherein the average flow velocity calculation formula of the multiphase flow at the shaft section is as follows:
in the formula (I), the compound is shown in the specification,
is the average wellbore flow rate; r is the inner diameter of a shaft and is in mm; wherein f (h) is a polynomial obtained by fitting the local flow velocities of 6 turbine probes to the height of the turbine projected onto the perpendicular bisector, i.e. the six points (v1, h1), (v2, h2), (v3, h3), (v4, h4), (v5, h5), (v6, h6) are obtained in a computer using a fourth order polynomial fit, with the fitting code final polymonomial currvetfitter. final double [ 2 ]]coeff ═ fitter. fit (obs. tolist ()), where obs. tolist () is six points (v1, h1), (v2, h2), (v3, h3), (v4, h4), (v5, h5), (v6, h6), coeff array is the coefficient of the nth power of h, n is 0, 1, 2, 3, 4; h is the height in the section of the shaft and is in mm, the polynomial takes the height (h) of each turbine as an independent variable, and the flow speed (v) represented by the rotating speed of the turbine is a dependent variable;
s43, visualizing the average flow velocity of the cross section of the shaft, visually observing the flow velocity change of the fluid in the cross section, applying a grid interpolation method to the velocity imaging of the cross section of the shaft, giving the local flow velocity calculated in the formula (5) to the grid where the array turbine flowmeter is located, and interpolating other grids through the assigned grids; velocity two-dimensional imaging as shown in fig. 8, darker colors indicate greater fluid flow velocity.
Optionally, in step 5, the fluid PVT physical parameters are mainly used to determine the retention rate and slip speed of the interpretation layer in the production logging interpretation, which affects the result of the production logging interpretation. The phase state of multiphase flow in the logging can be determined and the conversion of downhole production to surface production can be completed through the calculation of the PVT physical property parameters, and in the example well data, the parameters required to be input and the calculation method required to be selected for the calculation of the PVT physical property parameters are shown in FIG. 9.
Optionally, in step S6, the drift model not only considers the velocity difference between phases, but also considers the influence of the mixture concentration distribution and velocity distribution in the wellbore, and in this embodiment, the drift model is used to calculate the flow rate; the method comprises the following steps of:
s61 calculating the speed limit U of single bubble in infinite continuous phase through the density of water, the density of oil, the gravity acceleration and the surface tension of oil and water phases ∞ ；
S62 passing the data point
Respectively determining bubble diameter indexes n corresponding to the ring array capacitance probe CAT and the ring array resistance probe RAT according to the distribution condition when the bubble diameter indexes n take different values;
the S63 drift model is:
U d ＝C 0 U m +U dj (7)
U dj ＝C 0 U m +U ∞ (1-Y d ) n (8)
in the formula of U d Refers to the phase velocity of the dispersed phase; c 0 Is the phase distribution coefficient, passing C 0 And Y w Fitting to give C 0 As the coefficient of variation of the drift model; u shape m The flow rate of the oil phase and the water phase is the mixing flow rate; u shape ∞ Is the velocity limit of a single bubble in an infinite continuous phase; u shape dj Is the drift velocity of the dispersed phase.
Optionally, in step 7, a drift model is established according to the average holding rate data, the average flow rate data and the PVT physical property parameter calculation results and according to the formula (7) and the formula (8), and the downhole accumulated yield is calculated.
Alternatively, in step S8, the calculation result of the PVT physical property parameter and the calculated downhole flow data are calculated in a comprehensive manner, and the downhole flow data is converted into surface flow data. The calculated yield for each interpretation layer is the accumulated yield, and the net yield for a single interpretation layer is the difference between the accumulated yield for that interpretation layer and the accumulated yield for the interpretation layer that is adjacent to it and has a larger depth value.
In the example well, the volume coefficients of oil and water in the PVT physical property parameter calculation result are respectively multiplied by the underground oil phase and water flow to obtain the surface oil production and water production.
Although the shale oil is layered and has a large yield, the main production layer in the well can be accurately found in the interpretation process of the well in the example, the calculated single-layer yield is also more accurate with the interpretation result of the total yield, the interpretation result is shown in figure 10, the selected interpretation layer is analyzed by the response data of a capacitor, a resistance probe and a turbine flowmeter, and the yield calculated by combining the method of the invention is approximately consistent with the yield in the well distributed optical fiber DFA logging interpretation report of the embodiment. In the figure, for convenience of viewing, only one probe of the array capacitance probe, the array resistance probe and the array turbine is selected to be placed in the figure, UP1 represents data of each probe when the cable speed is-15 m/min, UP2 represents data of each probe when the cable speed is-20 m/min, UP3 represents data of each probe when the cable speed is-25 m/min, DN1 represents data of each probe when the cable speed is 10m/min, DN2 represents data of each probe when the cable speed is 15m/min, and DN3 represents data of each probe when the cable speed is 20 m/min.
It is to be understood that the above description is not intended to limit the present invention, and the present invention is not limited to the above examples, and those skilled in the art may make modifications, alterations, additions or substitutions within the spirit and scope of the present invention.
Claims (7)
1. A shale oil production interpretation method based on annular array probe measurement is characterized by comprising the following steps:
s1: establishing a multi-speed logging database;
s2: correcting the position of the annular array probe;
s3: processing data and imaging the holdup of the annular array holdup instrument;
s4: processing data and imaging speed of the annular turbine flowmeter;
s5: calculating PVT physical property parameters;
s6: constructing a drift model;
s7: calculating the accumulated yield of a plurality of underground output layers and the net yield of each layer;
s8: and converting the accumulated yield and each layer of net yield into ground flow data.
2. The shale oil production interpretation method based on annular array probe measurement of claim 1,
in step S1, the step of establishing a multi-velocity logging database includes:
s11 collecting on-site logging data including response data of each probe, rotation angle, well deviation data, well diameter data, temperature and pressure data in a shaft, ground single-day production data and shaft perforation data;
s12, selecting intervals as explanation layers according to the characteristics of the fracturing section, the perforation cluster, the measurement data of each probe and the temperature and pressure curve data in the shaft, and carrying out curve value taking on the intervals.
3. The shale oil production interpretation method based on annular array probe measurement of claim 1,
in step S2, in the step of correcting the position of the circular array probe, the circular array probe includes a circular array capacitance probe CAT and a circular array resistance probe RAT, where the correcting the position of the circular array capacitance probe CAT includes:
defining X, Y axle direction to the initial direction of definition No. 1 probe is in Y axle positive direction, and each probe is equidistant to be distributed everywhere in the ring instrument, and annular array capacitance probe CAT is after the position correction of pit shaft cross-section:
in the formula, CAL is the diameter of a shaft and the unit is mm; CATROT is the rotation angle of the annular array capacitance probe CAT, and the unit is rad; ROT i Is the starting angle of the ith probe in rad.
4. The shale oil production interpretation method based on annular array probe measurement of claim 1,
in step S3, the steps of data processing and rate-of-exposure imaging for the circular array rate-of-exposure instrument include:
s31, calculating the local water holding rate value around each probe according to the calibration value of each probe of the annular array water holding rate instrument, wherein the local water holding rate calculation formula of the annular array capacitance probe CAT is as follows:
in the formula, Y wi The local water holding rate of the I probe of the annular array capacitor CAT; CPS i The original response value of the I & ltth & gt probe of the annular array capacitor CAT is cps; CPSW i Is the response value of the ring array capacitor CAT ith probe in pure water, and the unit is cps; CPSO i The response value of the ring array capacitor CAT ith probe in the pure oil is cps;
the calculation formula of the local water holding rate of the annular array resistance probe RAT is as follows:
in the formula, Y wi Local water holding capacity of the ith probe of the annular array resistor RAT; CPS i Is the original response value of the ith probe of the annular array resistor RAT, and the unit is cps; CPSW i Is the response value of the ith probe of the annular array resistor RAT in pure water, and the unit is cps; sigma i 2 The standard deviation of the original response value of the ith probe of the annular array resistance probe RAT is obtained;
s32, interpolating the local water holdup of the annular array capacitance probe CAT and the annular array resistance probe RAT, regarding the cross section of the shaft as a circle with the actual diameter of the shaft, and performing grid division on the circle; interpolating other grids through the local water holding rate, and calculating to obtain the average water holding rate of the cross section of the shaft under the current speed measurement; finally, weighted accumulation is carried out on the water holding rates of the sections of the mineshaft calculated by the plurality of speed measurement data to obtain the average water holding rate of the sections of the mineshaft under the condition of multiple times of speed measurement;
s33, drawing a retention rate two-dimensional imaging graph, visually expressing the oil-water distribution of each explanation layer, and visualizing the oil-water two-phase distribution condition of the current explanation layer.
5. The method for interpreting shale oil production based on annular array probe measurement of claim 1, wherein in step S4, the annular turbine flowmeter data processing and speed imaging steps comprise:
s41, intersecting the response value of each turbine of the array turbine flowmeter with the corresponding cable speed;
the response intercept of the turbine cable response relation on the x axis is the apparent fluid velocity V a According to the slope K, Va of the turbine intersection and the calibrated response value of each probe of the turbine flowmeter under pure oil and pure water, the starting speed V of the turbine Ti And calculating to obtain the local average flow speed of the turbine, wherein the formula is as follows:
in the formula, V fi The fluid flow rate of the coverage area of the ith turbine is m/s; RPS i Is the ith turbine response value in rps; k i Is the response slope of the ith turbine; v Ti The response intercept of the ith turbine response relation on the x axis, namely the starting speed, is in the unit of m/s; v LSPD The speed is measured by pulling, namely the speed of the cable, and is generally marked as negative in the upper measurement and positive in the lower measurement, wherein the unit is m/min;
s42, assuming that the flow velocity of the fluid at the same height in the shaft is the same, projecting all turbines onto the perpendicular bisector of the shaft section, fitting the local flow velocity of the turbine at different height points by using a polynomial to obtain a fitting curve, and then integrating the fitting curve in the vertical direction, wherein the average flow velocity calculation formula of the multiphase flow at the shaft section is as follows:
in the formula (I), the compound is shown in the specification,
is the average wellbore flow rate; r is the inner diameter of a shaft and is in mm; wherein f (h) is a polynomial obtained by fitting the local flow velocity of each turbine probe to the height of the turbine projected onto the perpendicular bisector; h is the height in the section of the shaft and is in mm, the polynomial takes the height (h) of each turbine as an independent variable, and the flow speed (v) represented by the rotating speed of the turbine is a dependent variable;
s43 visualizes the average flow velocity of the cross section of the shaft, visually observes the flow velocity change of the fluid in the cross section, adopts a grid interpolation method for the velocity imaging of the cross section of the shaft, endows the grid where the array turbine flowmeter is located with the local flow velocity calculated in the formula (5), and interpolates other grids through the assigned grids.
6. The method for interpreting shale oil production based on ring array probe measurement as claimed in claim 1, wherein in step S6, the step of constructing a drift model comprises:
s61 calculating the speed limit U of single bubble in infinite continuous phase through the density of water, the density of oil, the gravity acceleration and the surface tension of oil and water phases ∞ ；
S62 passing the data point
Respectively determining bubble diameter indexes n corresponding to the annular array capacitance probe CAT and the annular array resistance probe RAT under the distribution condition when the bubble diameter indexes n take different values;
the S63 drift model is:
U d ＝C 0 U m +U dj (7)
U dj ＝C 0 U m +U ∞ (1-Y d ) n (8)
in the formula of U d Refers to the phase velocity of the dispersed phase; c 0 Is the phase distribution coefficient by C 0 And Y w Fitting to obtain C 0 As the coefficient of variation of the drift model; u shape m The flow rate of the oil phase and the water phase is the mixing flow rate; u shape ∞ Is the velocity limit of a single bubble in an infinite continuous phase; u shape dj Is the drift velocity of the dispersed phase.
7. The method of claim 1, wherein in step S8, the calculated yield of each interpretation layer is an accumulated yield, and the net yield of a single interpretation layer is the difference between the accumulated yield of the interpretation layer and the accumulated yields of the interpretation layers adjacent to the interpretation layer and having larger depth values.
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