A directional well dynamic liquid level measuring method and system, electronic equipment and storage medium

Abstract

The application discloses a directional well dynamic liquid level measuring method and system, electronic equipment and a storage medium. According to the detection wave data of the wellhead wave source, the distance from the wellhead wave source to the dynamic liquid level of the directional well is determined. The directional well borehole trajectory is divided into a plurality of continuous measuring sections from the wellhead, and the well depth increment and the vertical increment of each measuring section are determined. According to the distance, the actual bottom hole flowing pressure is determined. Taking the actual bottom hole flowing pressure as the starting point, the critical well depth of the foam section at the gas volume fraction of the preset value is determined. When the critical well depth of the foam section exceeds the distance, the segmentation point sequence number of the last cumulative measuring section is determined when the well depth increment cumulative value is first not lower than the critical well depth of the foam section, the corresponding well depth increment cumulative value and the vertical increment cumulative value are determined, and the vertical depth of the dynamic liquid level is determined. The accuracy of the dynamic liquid level measurement can be effectively improved, and reliable basis is provided for formulating a reasonable work system and optimizing the production capacity of the directional well.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of oil well logging, and particularly relates to a directional well dynamic liquid level measuring method and system, an electronic device and a storage medium. BACKGROUND

[0002] The liquid level depth of the annular space between the oil casing and the tubing measured in the normal production process of an oil well is called the dynamic liquid level. The dynamic liquid level is an important indicator reflecting the formation liquid supply capacity and is an important basis for determining the reasonable submergence and formulating a reasonable work system.

[0003] The commonly used oil well dynamic liquid level testing method is the echo testing method, which calculates the annular space liquid level depth of the oil well by using the principle of sound wave reflection. However, this method has two shortcomings in the application of directional wells: first, the natural gas in the oil casing annular space will separate from the oil under the condition of being lower than the saturation pressure, and a large amount of foam will be generated to form a foam section, which causes the sound wave to only identify the foam section, affecting the accuracy of the dynamic liquid level test result, and the tested dynamic liquid level will obviously deviate from the true dynamic liquid level, especially for high gas content directional wells, the influence is more obvious; second, the well trajectory of the directional well is an irregular three-dimensional space curve, when the echo test is used to test the dynamic liquid level, the sound wave is transmitted along the well trajectory, and the detection distance cannot reflect the true dynamic liquid level depth of the directional well. SUMMARY

[0004] In order to solve the above problems, the present application is made, and through the specific embodiment, a directional well dynamic liquid level measuring method, system, electronic device and storage medium are provided.

[0005] In a first aspect, the present application embodiment provides a directional well dynamic liquid level measuring method, including the following steps:

[0006] According to the detection wave data of the wellhead wave source, the distance from the wellhead wave source to the tested dynamic liquid level of the directional well is determined;

[0007] The well trajectory of the directional well is divided into a plurality of continuous measuring sections from the wellhead, and the well depth increment and the vertical increment of each measuring section are determined;

[0008] According to the distance, the actual bottom hole flowing pressure is determined;

[0009] Taking the actual bottom hole flowing pressure as the starting point, the critical well depth of the foam section at the gas volume fraction of the preset value is determined;

[0010] When the critical well depth of the foam section exceeds the distance, the vertical depth of the dynamic liquid level is determined according to the following method: when the well depth increment cumulative value is first not less than the critical well depth of the foam section, the split point serial number of the last cumulative measuring section is recorded as parameter one; according to the well depth increment cumulative value and the vertical increment cumulative value corresponding to the parameter one split point, the vertical depth of the dynamic liquid level is determined.

[0011] In a second aspect, an embodiment of the present application provides a directional well dynamic fluid level measuring system, comprising:

[0012] A test dynamic fluid level determining module is configured to determine a distance from a wellhead wave source to a test dynamic fluid level of the directional well according to detection wave data of the wellhead wave source.

[0013] A real dynamic fluid level measuring module is configured to divide a wellbore trajectory of the directional well into a plurality of continuous measuring sections from the wellhead, determine an incremental well depth and a vertical increment of each measuring section, determine an actual bottom hole flowing pressure according to the distance, determine a foam section critical well depth at which a gas phase volume fraction is a preset value, and determine a dynamic fluid level vertical depth according to the following method when the foam section critical well depth exceeds the distance: when an incremental well depth cumulative value is first not lower than the foam section critical well depth, record a split point serial number of a last cumulative measuring section as a parameter one; and determine the dynamic fluid level vertical depth according to an incremental well depth cumulative value and a vertical increment cumulative value corresponding to the parameter one split point.

[0014] In a third aspect, an embodiment of the present application provides a directional well dynamic fluid level foam section judging method, comprising the following steps:

[0015] A distance from a wellhead wave source to a test dynamic fluid level of the directional well is determined according to detection wave data of the wellhead wave source.

[0016] A wellbore trajectory of the directional well is divided into a plurality of continuous measuring sections from the wellhead, and an incremental well depth and a vertical increment of each measuring section are determined.

[0017] An actual bottom hole flowing pressure is determined according to the distance.

[0018] A foam section critical well depth at which a gas phase volume fraction is a preset value is determined with the actual bottom hole flowing pressure as a starting point.

[0019] The foam section is judged according to the foam section critical well depth and the distance.

[0020] In a fourth aspect, an embodiment of the present application provides a directional well dynamic fluid level foam section judging system, comprising:

[0021] A test dynamic fluid level determining module is configured to determine a distance from a wellhead wave source to a test dynamic fluid level of the directional well according to detection wave data of the wellhead wave source.

[0022] A foam section judging module is configured to divide a wellbore trajectory of the directional well into a plurality of continuous measuring sections from the wellhead, determine an incremental well depth and a vertical increment of each measuring section, determine an actual bottom hole flowing pressure according to the distance, determine a foam section critical well depth at which a gas phase volume fraction is a preset value with the actual bottom hole flowing pressure as a starting point, and judge the foam section according to the foam section critical well depth and the distance.

[0023] Based on the same inventive concept, the embodiment of the present application provides an electronic device, comprising a memory, a processor and a computer program stored in the memory and running on the processor, wherein the processor implements the directional well dynamic fluid level calculation method or the directional well dynamic fluid level foam section judgment method when executing the computer program.

[0024] Based on the same inventive concept, the embodiment of the present application provides a computer storage medium, wherein the computer storage medium stores computer executable instructions, and the computer executable instructions implement the directional well dynamic fluid level calculation method or the directional well dynamic fluid level foam section judgment method when executed.

[0025] The beneficial effects of the above technical solutions provided by the embodiment of the present application at least include:

[0026] In the directional well dynamic fluid level calculation, the present application can collect dynamic fluid level detection acoustic wave data in real time, calculate the depth of the directional well dynamic fluid level with high precision, effectively reduce the interference of the annular foam section and the directional well borehole trajectory on the dynamic fluid level detection result, improve the accuracy of the dynamic fluid level calculation, and provide a reliable basis for formulating a reasonable work system and optimizing the production capacity of the directional well.

[0027] In the directional well dynamic fluid level foam section judgment, the present application can collect dynamic fluid level detection acoustic wave data in real time, judge the foam section condition of the directional well dynamic fluid level with high precision, facilitate to reduce the interference of the annular foam section and the directional well borehole trajectory on the dynamic fluid level foam section judgment result, improve the accuracy of the foam section judgment, and provide a reliable basis for formulating a reasonable work system and optimizing the production capacity of the directional well.

[0028] Other features and advantages of the present application will be described in the following description, or will be apparent from the description, or will be understood by those skilled in the art. The purposes and other advantages of the present application can be achieved and obtained by the structures specifically pointed out in the written description, claims and drawings.

[0029] The technical solutions of the present application will be further described in detail below with the help of the drawings and examples. BRIEF DESCRIPTION OF DRAWINGS

[0030] The drawings are used to provide a further understanding of the present application, and constitute a part of the specification, together with the embodiments of the present application, to explain the present application, and do not constitute a limitation on the present application. In the drawings:

[0031] Figure 1 The flowchart of the directional well dynamic fluid level calculation method for the X well in the embodiment of the present application is shown in the figure;

[0032] Figure 2 The flowchart of calculating the vertical depth of the dynamic fluid level is shown in the figure;

[0033] Figure 3This is a flow chart for calculating the dynamic liquid level height of a directional well in an embodiment of the present invention;

[0034] Figure 4 Schematic diagram of the structure of an electronic device in an embodiment of the present invention. DETAILED DESCRIPTION

[0035] Exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. Although exemplary embodiments of the present disclosure are shown in the accompanying drawings, it should be understood that the present disclosure can be implemented in various forms and should not be limited by the embodiments set forth herein. Rather, these embodiments are provided to enable a more thorough understanding of the present disclosure and to fully convey the scope of the present disclosure to those skilled in the art.

[0036] In order to solve the problems existing in the prior art, embodiments of the present invention provide a method, system, electronic device and storage medium for measuring dynamic liquid level in a directional well.

[0037] The embodiment of the present invention provides a method for calculating the dynamic liquid level of a directional well, the process of which is as follows: Figure 1 As shown, the following steps are included:

[0038] Step S1: Determine the distance from the wellhead wave source to the test dynamic fluid level in the directional well based on the sound wave data from the wellhead wave source. The test dynamic fluid level is the estimated position of the dynamic fluid level based on the determined distance from the wellhead wave source to the test dynamic fluid level in the directional well. Because it may be affected by the foam segment, there may be a deviation between the test dynamic fluid level and the actual dynamic fluid level.

[0039] In some specific embodiments, the distance from the wellhead wave source to the dynamic liquid surface of the directional well test is determined based on the detection wave data of the wellhead wave source, including the following steps: obtaining the average speed of the detection wave propagating in the well through the oil pipe coupling echo; and determining the distance from the wellhead wave source to the dynamic liquid surface of the directional well test based on the average speed and the time taken for the detection wave to reach the liquid surface.

[0040] Specifically, the average speed of infrasound propagation is obtained by identifying the clearer echo of the tubing collar:

[0041]

[0042] Combined with the liquid surface echo time t, calculate the test dynamic liquid surface depth L d :

[0043]

[0044] Where, is the average sound velocity, m / s; N is the number of coupling waves selected from the tubing coupling echo, dimensionless; h is the tubing length, generally 9.6m; t1 is the time it takes for the infrasound wave to reach the selected point, s; L dm is the depth of the dynamic liquid level; t is the time taken by the infrasound wave to reach the liquid level, s .

[0045] Step S2: Dividing the directional well borehole trajectory into continuous multiple sections from the wellhead, determining the well depth increment and vertical increment of each section.

[0046] In some specific embodiments, determining the vertical increment of each section comprises the following steps: dividing the well depth increment of each section by the variation of the hole inclination angle at the division point of the corresponding section to obtain the curvature radius of each section; when the hole inclination angle at the division point of the section has no variation, multiplying the well depth increment of the corresponding section by the cosine of the hole inclination angle at the division point to determine the vertical increment of the corresponding section; when the hole inclination angle at the division point of the section has variation, multiplying the difference between the sine of the hole inclination angle at the division point of the section and the sine of the hole inclination angle at the division point of the previous section by the curvature radius of the section to obtain the vertical increment of the corresponding section.

[0047] Specifically, the three-dimensional borehole data of the directional well is imported, the borehole trajectory is divided into n sections, and the curvature radius method is used to calculate the curvature radius R of each section on the vertical profile Hi :

[0048]

[0049] The vertical increment of each section is calculated as follows:

[0050] ΔH i = R Hi (sinα i -sinα i-1 )

[0051] When Δα i = 0, ΔH i is calculated as follows:

[0052] ΔH i = ΔL i cosα i

[0053] The cumulative well depth of each section is calculated as follows:

[0054]

[0055] The cumulative vertical increment of each section is calculated as follows:

[0056]

[0057] If L i <L d , repeat the calculation process in step 2 until L i ≥ L d , and record the value i.

[0058] The vertical depth H of the test distance of the dynamic fluid level detected by the acoustic wave is calculated by linear interpolation d :

[0059]

[0060] In the formula, R Hi is the radius of curvature of the measured section on the vertical profile, m; ΔL i is the well depth increment of the measured section, m; Δα i is the well inclination angle increment of the measured section, rad; ΔH i is the vertical increment of the measured section, m; α i is the well inclination angle of the ith point, rad; L i is the cumulative well depth of each measured section to the ith point, m; H i is the cumulative vertical increment of each measured section to the ith point, m; H d is the vertical depth of the test dynamic fluid level, m.

[0061] Step S3: determining the actual well bottom flow pressure according to the distance.

[0062] In some specific embodiments, determining the actual well bottom flow pressure according to the distance comprises the following steps: recording the sequence number of the split point of the last accumulated measured section as parameter two when the well depth increment cumulative value is first not lower than the distance; determining the vertical depth of the test dynamic fluid level according to the well depth increment cumulative value and the vertical increment cumulative value corresponding to the parameter two split point; determining the well bottom flow pressure estimation value according to the sum of the pressure at the test dynamic fluid level and the casing pressure; taking the well bottom flow pressure estimation value as the initial pressure, determining the fluid level depth when the pressure is the pressure at the test dynamic fluid level, adjusting the well bottom flow pressure estimation value when the fluid level depth is different from the test distance, determining a new fluid level depth, and determining the well bottom flow pressure estimation value at this time as the actual well bottom flow pressure until the new fluid level depth is equal to the test distance.

[0063] In some specific embodiments, determining the vertical depth of the test dynamic fluid level according to the well depth increment cumulative value and the vertical increment cumulative value corresponding to the parameter two split point comprises the following steps: determining the vertical depth of the test dynamic fluid level by determining the vertical depth of the test dynamic fluid level, wherein H d is the vertical depth of the test dynamic fluid level, H i is the vertical increment cumulative value of the measured section corresponding to the sequence number i split point from the first measured section, and the sequence number i is the parameter two at this time, H i-1 is the vertical increment cumulative value of the measured section corresponding to the sequence number i-1 split point from the first measured section, L i is the well depth increment cumulative value of the measured section corresponding to the sequence number i split point from the first measured section, L i-1L is the well depth increment accumulated from the first section to the section corresponding to the i-1 split point d L is the distance from the wellhead wave source to the dynamic testing fluid level of the directional well.

[0064] In some specific embodiments, the bottom-hole flowing pressure estimate is determined according to the sum of the pressure at the vertical depth of the dynamic testing fluid level and the casing pressure, including the following steps: the bottom-hole flowing pressure estimate is determined by P wf ’ = P c + ρgH d , wherein P wf ’ represents the bottom-hole flowing pressure estimate, P c is the casing pressure, ρ is the density of the bottom-hole fluid, g represents the acceleration of gravity, and H d is the vertical depth of the dynamic testing fluid level.

[0065] In some specific embodiments, the pressure at the dynamic testing fluid level is determined, including the following steps:

[0066] The annular gas column pressure P g is determined by P

[0067] wherein,

[0068] The pressure at the dynamic testing fluid level is determined by P d = P g + P c , wherein P c is the casing pressure, e is the base of the natural logarithm, f is the annular module coefficient, q g is the gas flow rate, Y cp is the average temperature of the gas column, Z cp is the average deviation coefficient of the gas column, d1 is the inner diameter of the casing, d2 is the outer diameter of the tubing, γ g is the relative density of natural gas, and H z is the middle well depth of the oil well.

[0069] In some specific embodiments, the oil-casing annulus pressure gradient is calculated with the bottom-hole flowing pressure estimate as the starting pressure, to obtain the oil-casing annulus pressure distribution;

[0070] wherein the oil-casing annulus pressure gradient is calculated by , represents the oil-casing annulus pressure, ρ l is the liquid density, H l is the liquid holdup, ρ g is the gas density, g is the acceleration of gravity, θ is the inclination angle of the corresponding section, λ is the resistance coefficient, G m is the total mass flow rate of gas and liquid, v m is the apparent velocity of the gas-liquid mixture, and D is the hydraulic diameter of the annular space.​p is the annulus area, v sg is the superficial velocity of gas, is the average pressure of the calculation section.

[0071] Specifically, given the estimated bottom hole flowing pressure P wf , the Begges-Brill method for calculating multiphase pipe flow is used to calculate the annulus pressure gradient, and the annulus pressure distribution is obtained, and the liquid level L d at which the pressure is P d is calculated. If L d ≠ L d , change the estimated bottom hole flowing pressure, recalculate until L d = L d , and the actual bottom hole flowing pressure P wf is obtained.

[0072] where, since the annulus pressure distribution is calculated, the above formula needs to be modified. Specifically, D is modified to the hydraulic diameter of the annular space, and A p is modified to the annulus area.

[0073] D = d1-d2

[0074]

[0075] d1 is the inside diameter of the casing, d2 is the outside diameter of the tubing, and the pressure increment iteration method is used to calculate the annulus pressure distribution with the estimated bottom hole flowing pressure P wf as the starting pressure, and the liquid level L d at which the pressure is P d is calculated. If L d ≠ L d , change the estimated bottom hole flowing pressure P wf , recalculate until L d = L d , and the actual bottom hole flowing pressure P wf is obtained.

[0076] Step S4: Taking the actual bottom hole flowing pressure as the starting point, determine the critical well depth of the foam section at which the gas volume fraction is the preset value.

[0077] Natural gas in the annular space of the casing will separate from the oil under a saturation pressure, producing a nearly foam-like slug flow section with extremely small density, i.e. the foam section. Since the fluid flow regime in the wellbore is gradually transitional, there is no obvious boundary, and therefore the definition of foam in chemical concepts is used as the basis for judging the foam section, i.e. the dispersion system of gas in liquid, which is specifically embodied in the volume fraction of gas phase.

[0078] In some specific embodiments, the method of determining the critical well depth of the foam section at a preset gas phase volume fraction based on the actual bottom hole flowing pressure includes the following steps:

[0079] Taking the actual bottom hole flowing pressure as the starting point, calculate the gas volume fraction at different depths in the casing annular space, and find the critical well depth L of the foam section where the gas volume fraction is the preset value. cr ;

[0080] Among them, through Calculate the gas phase volume fraction, β is the gas phase volume fraction, q g is the gas volume flow rate, q l is the liquid volume flow rate,

[0081] pass Determine the gas volume flow rate q g , p o is the starting pressure of the corresponding measuring section, is the average temperature of the corresponding measuring section, Z' is the natural gas compression factor, R p is the production gas-oil ratio, R s is the dissolved gas-oil ratio, q o is the oil well production, is the average pressure of the corresponding measuring section, T o is the starting temperature of the corresponding measurement section,

[0082] pass Determine the liquid volume flow rate q l ,q o is the oil well production, B o is the volume coefficient of crude oil.

[0083] For example, the gas phase volume fraction is preset to 90%. Starting from the actual bottomhole flowing pressure, the Begges-Brill method for calculating multiphase pipe flow is used to calculate the fluid properties and flow parameters at different depths in the casing annulus, and the critical well depth of the foam section where the gas phase volume fraction reaches 90% is found.

[0084] Step S5: When the critical well depth of the foam section exceeds the distance, the vertical depth of the dynamic liquid level is determined according to the following method: When the cumulative depth increment value is not less than the critical well depth of the foam section for the first time, the segmentation point number of the last cumulative measurement segment is recorded as parameter one; the vertical depth of the dynamic liquid level is determined based on the cumulative depth increment value and the vertical increment value corresponding to the segmentation point of parameter one. The vertical depth of the dynamic liquid level in a directional well is also called the dynamic liquid level height in a directional well.

[0085] In some specific embodiments, the vertical depth of the dynamic liquid level is determined according to the well depth incremental cumulative value and the vertical incremental cumulative value corresponding to the parameter-division point, including the following steps: Determination of the test dynamic liquid level vertical depth, wherein H is the dynamic liquid level vertical depth, H i is the vertical increment cumulative value of the corresponding measuring section from the first measuring section to the partition point with serial number i, wherein the serial number i is the first parameter, H i-1 is the vertical increment cumulative value of the corresponding measuring section from the first measuring section to the partition point with serial number i-1, L i is the well depth increment cumulative value of the corresponding measuring section from the first measuring section to the partition point with serial number i, L i-1 is the well depth increment cumulative value of the corresponding measuring section from the first measuring section to the partition point with serial number i-1, L cr is the critical well depth of the foam section at the gas phase volume fraction of the preset value.

[0086] In one specific embodiment, taking X well as an example, the X well basic data: the oil layer middle well depth is 2355 m, the tubing outer diameter is 0.073 m, the casing inner diameter is 0.124 m, the gas production is 0.93 m 3 / s, the natural gas relative density is 0.6, the original formation temperature is 115℃, the ground temperature gradient is 0.022℃ / m, the ground crude oil density is 860 kg / m 3 , the reservoir saturation pressure is 10.2 MPa, the water content is 0.85, and the production gas oil ratio is 60 m 3 / m 3 . As shown in the figure, the method for measuring and calculating the dynamic liquid level of the directional well in the embodiment of the application comprises the following steps: Figure 1

[0087] Step 1: Real-time acquisition of probe sound wave data, calculation of the test distance of the sound wave probe to the dynamic liquid level.

[0088] The average sound velocity of the subsonic wave propagation is obtained by identifying the clearer tubing coupling echo:

[0089]

[0090] Combined with the liquid level echo time t, the test dynamic liquid level depth L d is calculated:

[0091]

[0092] In the formula, is the average sound velocity, m / s; N is the number of selected coupling waves in the tubing coupling echo, dimensionless; h is the tubing length, generally 9.6 m; t1 is the time used by the subsonic wave to reach the selected point, s; L d is the test dynamic liquid level depth, m; t is the time used by the subsonic wave to reach the liquid level, s.

[0093] Step 2: Calculation of the vertical depth of the test dynamic liquid level according to the three-dimensional wellbore data.

[0094] As​Figure 2 The three-dimensional wellbore data of the directional well is imported, the wellbore trajectory is divided into n sections, the curvature radius method is used to calculate the curvature radius R of each section on the vertical profile Hi :

[0095]

[0096] The vertical increment of each section is calculated:

[0097] ΔH i = R Hi (sinα i -sinα i-1 )

[0098] When Δα i = 0, ΔH i is calculated according to the following formula:

[0099] ΔH i = ΔL i cosα i

[0100] The cumulative well depth of each section is calculated:

[0101]

[0102] The cumulative vertical increment of each section is calculated:

[0103]

[0104] If L i <L d , repeat the calculation process in step 2 until L i ≥ L d , and record the value i.

[0105] The vertical depth H of the test distance of the acoustic wave detected to the liquid level is calculated by linear interpolation: d :

[0106]

[0107] In the formula, R Hi is the curvature radius of the section on the vertical profile, m; ΔL i is the well depth increment of the section, m; Δα i is the well inclination angle increment of the section, rad; ΔH i is the vertical increment of the section, m; α i is the well inclination angle of the i-th point, rad; L i is the cumulative well depth of each section to the i-th point, m; H i is the cumulative vertical increment of each section to the i-th point, m; H dis the vertical depth of the test dynamic liquid surface, m.

[0108] Step 3: Calculate the annular air column pressure to obtain the pressure at the test dynamic liquid surface.

[0109] The casing pressure data P collected in real time c is 1.2 MPa, calculate the average temperature T of the gas column cp =t o +2355×0.022 / 2+273.15=315.26K, the friction coefficient f is 0.014, and the comparison temperature is calculated. Comparison of temperature Among them, t o Local average temperature, ℃; T cr is the critical temperature of gas 199.5K, P cr The critical pressure of gas is 4.6MPa. According to T r and P r , check the Standing-Katz chart, gas deviation coefficient Z cp is 0.96, calculate the annular air column pressure P g =1.4MPa.

[0110] Calculate the pressure P at the test dynamic liquid surface d =1.4+1.2=2.6MPa.

[0111] Where, P g is the annular air column pressure, MPa; P c is the casing pressure, MPa; e is the base of the natural logarithm, which is 2.718; f is the annular module coefficient, dimensionless; q g is the natural gas production, m 3 / d;T cp is the average temperature of the air column, K; Z cp is the average deviation coefficient of the gas column, dimensionless; d1 is the inner diameter of the casing, m; d2 is the outer diameter of the tubing, m; γ g is the relative density of natural gas, dimensionless; H z is the depth of the middle part of the oil well, m; P d To test the pressure at the dynamic liquid surface, MPa.

[0112] Step 4: If Figure 3 As shown, given the estimated bottom hole pressure P wf ', using the Begges-Brill method for calculating multiphase pipe flow, calculate the casing annulus pressure gradient and obtain the casing annulus pressure distribution. The calculated pressure is P d The liquid depth L d ', if L d '≠L d, change the bottom hole flowing pressure estimate, recalculate until L d ‘ = L d , get the actual bottom hole flowing pressure P wf .

[0113] Given the bottom hole flowing pressure estimate P wf ’ = P c + pgH d = 1.2 + 890 * 9.8 * 965.2 * 10 -6 = 9.6 MPa, wherein p is the bottom hole liquid density, kg / m 3 .

[0114] The formula for calculating the pressure gradient is:

[0115]

[0116] Where, since the oil casing annulus pressure distribution is calculated, the above formula needs to be modified. Specifically, D is modified to the hydraulic diameter of the annular space, A p is modified to the oil casing annulus area.

[0117] D = d1 - d2 = 0.051 m

[0118]

[0119] Using the pressure increment iteration method, the annulus pressure distribution is calculated with the bottom hole flowing pressure estimate P wf ’ as the starting pressure, and the liquid surface depth L d ’ at which the pressure is P d is calculated. If L d ’ ≠ L d , change the bottom hole flowing pressure estimate P wf ’, recalculate until L d ’ = L d , get the actual bottom hole flowing pressure P wf = 9.3 MPa.

[0120] In the formula, P wf ’ is the bottom hole flowing pressure estimate, MPa; L d ’ is the liquid surface depth calculated at which the pressure is P d , m; P wf is the actual bottom hole flowing pressure, MPa; dp is the pressure interval, MPa; dZ is the depth interval, m; p l is the liquid density, kg / m 3 ; p g is the gas density, kg / m 3 ; g is the acceleration of gravity, m / s 2 ; D is the hydraulic diameter of the annular space, m; A pis the annular area of casing, m2 2 ; H l is the holdup, dimensionless; θ is the inclination angle of the calculation section, °; λ is the resistance coefficient, dimensionless; G m is the total mass flow rate of gas and liquid, kg / s; v sg is the superficial velocity of gas, m / s; v m is the superficial velocity of gas-liquid mixture, m / s; is the average pressure of the calculation section, MPa.

[0121] Step 5: Calculate the critical well depth L cr of the foam section.

[0122] Taking the actual bottom hole flowing pressure as the starting point, the Begges-Brill method of multiphase pipe flow is used to calculate the fluid property parameters and flow parameters at different depths in the casing annular space, and the critical well depth L cr of the foam section where the volume fraction of gas phase is 90% is found.

[0123] When q g = 0.74 m 3 / s, q l = 0.08 m 3 / s, α = 90%, the corresponding well depth is found to be the critical well depth L cr of the foam section, which is 1153.3 m.

[0124] Step 6: As shown in Figure 3 , the test dynamic liquid level depth L d is 1005.8 m, and the critical well depth L cr of the foam section is 1153.3 m, i.e. L d <L cr , indicating that there is a foam section in the dynamic liquid level, and the length of the foam section L p = 1153.3-1005.8 = 147.5 m.

[0125] Step 7: Calculate the vertical depth of the dynamic liquid level of the directional well. The vertical depth of the dynamic liquid level of the directional well is also known as the height of the dynamic liquid level of the directional well.

[0126] Calculate the cumulative well depth L i of each section and the cumulative vertical increment H i of each section. If L i <L cr , continue to accumulate until L i ≥ L cr .

[0127] The vertical depth of the dynamic liquid level of the directional well H is calculated by linear interpolation:

[0128]

[0129] The dynamic fluid level measurement of the directional well can collect dynamic fluid level detection acoustic wave data in real time, measure the dynamic fluid level depth of the directional well with high precision, effectively reduce the interference of the annular foam section and the wellbore trajectory of the directional well on the dynamic fluid level detection result, improve the accuracy of the dynamic fluid level measurement, and provide a reliable basis for formulating a reasonable work system and optimizing the production capacity of the directional well.

[0130] Those skilled in the art can transform the above sequence without departing from the protection scope of the present disclosure.

[0131] Another embodiment of the present application provides a directional well dynamic fluid level measurement system, comprising:

[0132] The test dynamic fluid level determination module is configured to determine the distance from the wellhead wave source to the test dynamic fluid level of the directional well according to the detection wave data of the wellhead wave source.

[0133] The real dynamic fluid level measurement module is configured to divide the wellbore trajectory of the directional well into a plurality of continuous measurement sections from the wellhead, determine the well depth increment and the vertical increment of each measurement section, determine the actual bottom hole flowing pressure according to the distance, and determine the foam section critical well depth at which the gas volume fraction is a preset value, starting from the actual bottom hole flowing pressure.

[0134] As to the system in the above embodiments, the specific manner in which each module performs operations has been described in detail in the embodiments related to the method, and will not be described in detail here.

[0135] The dynamic fluid level measurement of the directional well can collect dynamic fluid level detection acoustic wave data in real time, measure the dynamic fluid level depth of the directional well with high precision, effectively reduce the interference of the annular foam section and the wellbore trajectory of the directional well on the dynamic fluid level detection result, improve the accuracy of the dynamic fluid level measurement, and provide a reliable basis for formulating a reasonable work system and optimizing the production capacity of the directional well.

[0136] Another embodiment of the present application provides a directional well dynamic fluid level foam section judgment method, comprising the following steps:

[0137] The distance from the wellhead wave source to the test dynamic fluid level of the directional well is determined according to the detection wave data of the wellhead wave source.

[0138] The wellbore trajectory of the directional well is divided into a plurality of continuous measurement sections from the wellhead, and the well depth increment and the vertical increment of each measurement section are determined.

[0139] determine an actual bottom hole flowing pressure according to the distance;

[0140] determine a foam section critical well depth at which the gas phase volume fraction is the preset value, taking the actual bottom hole flowing pressure as a starting point;

[0141] judge the foam section according to the foam section critical well depth and the distance.

[0142] Specifically, judging the foam section according to the foam section critical well depth and the distance includes the following steps:

[0143] when the foam section critical well depth exceeds the distance, it is judged that there is a foam section in the dynamic liquid level;

[0144] or when the foam section critical well depth does not exceed the distance, it is judged that there is no foam section in the dynamic liquid level.

[0145] Specifically, the directional well dynamic liquid level foam section judgment method further includes the following steps:

[0146] determine the difference between the foam section critical well depth and the distance as the foam section length. For details, see step 6 in the X well example.

[0147] In the directional well dynamic liquid level foam section judgment of the embodiment, the dynamic liquid level detection sound wave data can be collected in real time, the foam section condition of the directional well dynamic liquid level can be judged with high precision, the interference of the annular foam section and the directional well borehole trajectory on the foam section condition judgment result of the dynamic liquid level is reduced, the accuracy of the foam section judgment is improved, and reliable basis is provided for formulating a reasonable work system and optimizing the production capacity of the directional well.

[0148] Another embodiment of the application provides a directional well dynamic liquid level foam section judgment system, which includes:

[0149] a test dynamic liquid level determination module configured to determine the distance from the wellhead wave source to the test dynamic liquid level of the directional well according to the detection wave data of the wellhead wave source;

[0150] a foam section judgment module configured to divide the directional well borehole trajectory from the wellhead into a plurality of continuous measurement sections, determine the well depth increment and the vertical increment of each measurement section, determine an actual bottom hole flowing pressure according to the distance, and determine a foam section critical well depth at which the gas phase volume fraction is a preset value, taking the actual bottom hole flowing pressure as a starting point.

[0151] In the foam section of the dynamic fluid level of the directional well in the embodiment, the sound wave data of the dynamic fluid level detection can be collected in real time, the foam section of the dynamic fluid level of the directional well can be determined with high precision, the interference of the annular foam section and the well trajectory of the directional well on the determination result of the foam section of the dynamic fluid level can be reduced, the accuracy of the foam section determination can be improved, and reliable basis can be provided for formulating a reasonable work system and optimizing the production capacity of the directional well.

[0152] Based on the same inventive concept, the embodiment of the present application provides an electronic device, the structure of which is shown in Figure 4 The processor executes the computer program to realize the foregoing directional well dynamic fluid level calculation method or the foam section of the directional well dynamic fluid level determination method.

[0153] Based on the same inventive concept, the embodiment of the present application provides a computer storage medium, the computer storage medium storing computer executable instructions, the computer executable instructions being executed to realize the foregoing directional well dynamic fluid level calculation method or the foam section of the directional well dynamic fluid level determination method.

[0154] Any modification, supplement and equivalent replacement within the principle range of the present application shall still belong to the patent coverage range of the present application.

Claims

1. A method for calculating the dynamic liquid level in a directional well, characterized in that: The following steps are involved: According to the detection wave data of the wellhead wave source, the distance from the wellhead wave source to the dynamic liquid surface of the directional well test is determined; Divide the directional wellbore trajectory into multiple continuous measurement sections starting from the wellhead, and determine the well depth increment and vertical increment of each measurement section; Determining the actual bottom hole flow pressure based on the distance includes the following steps: When the well depth increment accumulated value is not less than the distance for the first time, the split point number of the last accumulated measurement section is recorded as parameter 2; Determine the vertical depth of the test dynamic liquid level according to the well depth increment cumulative value and the vertical increment cumulative value corresponding to the parameter two-division point; including the following steps: , determine the vertical depth of the test dynamic liquid surface, where, To test the vertical depth of the dynamic liquid surface, It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. At this time, sequence number i is parameter 2. It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i-1. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segment number i-1. The distance from the wellhead wave source to the dynamic liquid level of the directional well test; Determine the estimated bottom hole flow pressure based on the sum of the pressure at the vertical depth of the test dynamic liquid level and the casing pressure; Taking the estimated bottom hole flow pressure as the starting pressure, determining the liquid surface depth when the pressure is equal to the pressure at the test dynamic liquid surface; when the liquid surface depth is different from the distance, adjusting the estimated bottom hole flow pressure and determining a new liquid surface depth until the new liquid surface depth is equal to the distance; and determining the estimated bottom hole flow pressure at this time as the actual bottom hole flow pressure; Taking the actual bottom hole flowing pressure as the starting point, determine the critical well depth of the foam section where the gas phase volume fraction reaches a preset value; When the critical well depth of the foam section exceeds the distance, the vertical depth of the dynamic liquid level is determined according to the following method: when the well depth increment cumulative value is not lower than the critical well depth of the foam section for the first time, the segmentation point number of the last cumulative measurement section is recorded as parameter one; the vertical depth of the dynamic liquid level is determined according to the well depth increment cumulative value and the vertical increment cumulative value corresponding to the segmentation point of parameter one; the following steps are included: , determine the vertical depth of the test dynamic liquid surface, where H is the vertical depth of the dynamic liquid surface, It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. At this time, sequence number i is parameter one. It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i-1. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segment number i-1. is the critical well depth of the foam section when the gas phase volume fraction is a preset value.

2. The method according to claim 1, wherein Determining the distance from the wellhead wave source to the dynamic fluid level of the directional well test based on the detection wave data of the wellhead wave source includes the following steps: The average speed of the detection wave propagating in the well is obtained through the echo of the tubing collar; The distance from the wellhead wave source to the dynamic liquid surface of the directional well test is determined based on the average speed and the time taken for the detection wave to reach the liquid surface.

3. The method according to claim 1, wherein Determine the vertical increment for each segment, including the following steps: The depth increment of each measuring section is divided by the change in the well inclination angle at the dividing point of the corresponding measuring section to obtain the curvature radius of each measuring section; When the well inclination angle at the dividing point of the measuring section does not change, the vertical increment of the corresponding measuring section is determined by multiplying the well depth increment of the corresponding measuring section by the cosine of the well inclination angle at the dividing point; When the inclination angle of the segment division point changes, the difference between the sine of the inclination angle of the segment division point and the sine of the inclination angle of the previous segment division point is multiplied by the curvature radius of the segment to obtain the vertical increment of the corresponding segment.

4. The method according to claim 1, wherein The estimated bottom hole flow pressure is determined based on the sum of the pressure at the vertical depth of the test dynamic liquid level and the casing pressure, including the following steps: pass , determine the estimated bottom hole pressure, where represents the estimated bottom hole flowing pressure, is the casing pressure, is the density of the bottom hole liquid, represents the acceleration due to gravity, To test the vertical depth of the dynamic liquid surface.

5. The method according to claim 1, wherein Determining the pressure at the test dynamic liquid level includes the following steps: pass , determine the annular air column pressure , in, , pass , determine the pressure at the test dynamic liquid surface, is the casing pressure, e is the base of the natural logarithm, is the annulus module coefficient, is the gas flow rate, is the average temperature of the air column, is the average deviation coefficient of the air column, is the inner diameter of the casing, is the outer diameter of the oil pipe, is the relative density of natural gas, The depth is in the middle of the oil well.

6. The method according to claim 1, wherein The method for calculating the dynamic liquid level in a directional well further comprises the following steps: Taking the estimated bottom hole flowing pressure as the starting pressure, the casing annulus pressure gradient is calculated to obtain the casing annulus pressure distribution; Among them, through , calculate the casing annulus pressure gradient, Indicates the casing annulus pressure, is the liquid density, is the liquid holdup, is the gas density, is the acceleration due to gravity, is the well inclination angle of the corresponding measuring section, is the drag coefficient, is the total gas-liquid mass flow rate, is the superficial velocity of gas-liquid mixing, D is the hydraulic diameter of the annular space, is the casing annulus area, is the gas superficial velocity, is the average pressure of the calculation section.

7. The method according to claim 1, wherein Taking the actual bottom hole flowing pressure as the starting point, determining the critical well depth of the foam section where the gas phase volume fraction is a preset value includes the following steps: Taking the actual bottom hole flowing pressure as the starting point, calculate the gas volume fraction at different depths in the casing annular space, and find the critical well depth of the foam section where the gas volume fraction is the preset value. ; Among them, through , calculate the gas phase volume fraction, is the gas phase volume fraction, is the gas volume flow rate, is the liquid volume flow rate, pass , determine the gas volume flow rate , is the starting pressure of the corresponding measuring section, is the average temperature of the corresponding measuring section, Z' is the natural gas compression factor, is the production gas-oil ratio, is the dissolved gas-oil ratio, is the oil well production, is the average pressure of the corresponding measuring section, is the starting temperature of the corresponding measurement section, pass , determine the liquid volume flow rate , is the oil well production, is the volume coefficient of crude oil.

8. A directional well dynamic liquid level measurement system, characterized in that: include: The test dynamic liquid level determination module is used to determine the distance from the wellhead wave source to the directional well test dynamic liquid level based on the detection wave data of the wellhead wave source; The real dynamic liquid level measurement module is used to divide the directional wellbore trajectory into a plurality of continuous measurement sections starting from the wellhead, determine the well depth increment and vertical increment of each measurement section; determine the actual bottom hole flow pressure according to the distance; determine the critical well depth of the foam section at a preset gas phase volume fraction with the actual bottom hole flow pressure as the starting point; when the critical well depth of the foam section exceeds the distance, determine the vertical depth of the dynamic liquid level according to the following method: when the cumulative value of the well depth increment is not lower than the critical well depth of the foam section for the first time, record the segmentation point number of the last cumulative measurement section as parameter one; determine the vertical depth of the dynamic liquid level according to the cumulative value of the well depth increment and the cumulative value of the vertical increment corresponding to the segmentation point of parameter one; wherein, determining the actual bottom hole flow pressure according to the distance includes the following steps: when the cumulative value of the well depth increment is not lower than the distance for the first time, record the segmentation point number of the last cumulative measurement section as parameter two; determine the vertical depth of the test dynamic liquid level according to the cumulative value of the well depth increment and the cumulative value of the vertical increment corresponding to the segmentation point of parameter two; including the following steps: through , determine the vertical depth of the test dynamic liquid surface, where, To test the vertical depth of the dynamic liquid surface, It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. At this time, sequence number i is parameter 2. It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i-1. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segment number i-1. is the distance from the wellhead wave source to the dynamic liquid surface of the directional well test; the estimated value of the bottom hole flow pressure is determined according to the sum of the pressure at the vertical depth of the test dynamic liquid surface and the casing pressure; the estimated value of the bottom hole flow pressure is used as the starting pressure, and the liquid surface depth when the pressure is the pressure at the test dynamic liquid surface is determined; when the liquid surface depth is different from the distance, the estimated value of the bottom hole flow pressure is modulated to determine a new liquid surface depth until the new liquid surface depth is equal to the distance, and the estimated value of the bottom hole flow pressure at this time is determined as the actual bottom hole flow pressure; the vertical depth of the dynamic liquid surface is determined according to the well depth incremental cumulative value and the vertical incremental cumulative value corresponding to the parameter-division point, including the following steps: through , determine the vertical depth of the test dynamic liquid surface, where H is the vertical depth of the dynamic liquid surface, It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. At this time, sequence number i is parameter one. It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i-1. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segment number i-1. is the critical well depth of the foam section when the gas phase volume fraction is a preset value.

9. A method for determining the dynamic liquid level foam section in a directional well, characterized in that: The following steps are involved: According to the detection wave data of the wellhead wave source, the distance from the wellhead wave source to the dynamic liquid surface of the directional well test is determined; Divide the directional wellbore trajectory into multiple continuous measurement sections starting from the wellhead, and determine the well depth increment and vertical increment of each measurement section; Determining the actual bottom hole flow pressure based on the distance includes the following steps: When the well depth increment accumulated value is not less than the distance for the first time, the split point number of the last accumulated measurement section is recorded as parameter 2; Determine the vertical depth of the test dynamic liquid level according to the well depth increment cumulative value and the vertical increment cumulative value corresponding to the parameter two-division point; including the following steps: , determine the vertical depth of the test dynamic liquid surface, where, To test the vertical depth of the dynamic liquid surface, It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. At this time, sequence number i is parameter 2. It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i-1. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segment number i-1. The distance from the wellhead wave source to the dynamic liquid level of the directional well test; Determine the estimated bottom hole flow pressure based on the sum of the pressure at the vertical depth of the test dynamic liquid level and the casing pressure; Taking the estimated bottom hole flow pressure as the starting pressure, determining the liquid surface depth when the pressure is equal to the pressure at the test dynamic liquid surface; when the liquid surface depth is different from the distance, adjusting the estimated bottom hole flow pressure and determining a new liquid surface depth until the new liquid surface depth is equal to the distance; and determining the estimated bottom hole flow pressure at this time as the actual bottom hole flow pressure; Taking the actual bottom hole flowing pressure as the starting point, determine the critical well depth of the foam section where the gas phase volume fraction reaches a preset value; The foam section is judged according to the critical well depth of the foam section and the distance.

10. The method according to claim 9, wherein Judging the foam section according to the critical well depth of the foam section and the distance includes the following steps: When the critical well depth of the foam section exceeds the distance, it is determined that a foam section exists in the dynamic liquid surface; Or when the critical well depth of the foam section does not exceed the distance, it is determined that no foam section exists in the dynamic liquid surface.

11. The method according to claim 9, wherein The method for determining the dynamic liquid level foam section of a directional well further comprises the following steps: The difference between the critical well depth of the foam section and the distance is determined as the foam section length.

12. A directional well dynamic liquid level foam section judgment system, characterized in that: include: The test dynamic liquid level determination module is used to determine the distance from the wellhead wave source to the directional well test dynamic liquid level based on the detection wave data of the wellhead wave source; The foam section judgment module is used to divide the directional wellbore trajectory into a plurality of continuous measurement sections starting from the wellhead, determine the well depth increment and vertical increment of each measurement section; determine the actual bottom hole flow pressure according to the distance; determine the critical well depth of the foam section where the gas phase volume fraction is a preset value with the actual bottom hole flow pressure as the starting point; judge the foam section according to the critical well depth of the foam section and the distance; wherein, determining the actual bottom hole flow pressure according to the distance includes the following steps: when the accumulated value of the well depth increment is not less than the distance for the first time, recording the segmentation point number of the last accumulated measurement section as parameter two; determining the vertical depth of the test dynamic liquid surface according to the accumulated value of the well depth increment and the accumulated value of the vertical increment corresponding to the segmentation point of parameter two; including the following steps: through , determine the vertical depth of the test dynamic liquid surface, where, To test the vertical depth of the dynamic liquid surface, It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. At this time, sequence number i is parameter 2. It is the vertical incremental cumulative value from the first measuring section to the measuring section corresponding to the dividing point of sequence number i-1. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the dividing point of sequence number i. It is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segment number i-1. is the distance from the wellhead wave source to the dynamic liquid level of the directional well test; the estimated bottom hole flow pressure is determined according to the sum of the pressure at the vertical depth of the test dynamic liquid level and the casing pressure; the estimated bottom hole flow pressure is used as the starting pressure, and the liquid level depth when the pressure is the pressure at the test dynamic liquid level is determined; when the liquid level depth is different from the distance, the estimated bottom hole flow pressure is modulated to determine a new liquid level depth until the new liquid level depth is equal to the distance, and the estimated bottom hole flow pressure at this time is determined as the actual bottom hole flow pressure.

13. An electronic device, characterized in that: include: A memory, a processor, and a computer program stored in the memory and running on the processor, wherein when the processor executes the computer program, the method for measuring the dynamic liquid level in a directional well according to any one of claims 1 to 7 or the method for determining the foam section of the dynamic liquid level in a directional well according to any one of claims 9 to 11 is implemented.

14. A computer storage medium, characterized in that The computer storage medium stores computer executable instructions, which, when executed, implement the directional well dynamic liquid level measurement method described in any one of claims 1 to 7, or the directional well dynamic liquid level foam section judgment method described in any one of claims 9 to 11.

Images