Method and system for measuring and calculating working fluid level of directional well, electronic equipment and storage medium

Abstract

The invention discloses a directional well working fluid level measuring and calculating method and system, electronic equipment and a storage medium. According to the detection wave data of the wellhead wave source, the distance between the wellhead wave source and the directional well testing working fluid level is determined; dividing the well track of the directional well into a plurality of continuous measurement sections from a wellhead, and determining the well depth increment and the vertical increment of each measurement section; according to the distance, the actual flowing bottomhole pressure is determined; the critical well depth of the foam section with the gas phase volume fraction as the preset value is determined with the actual flowing bottomhole pressure as the starting point; and when the critical well depth of the foam section exceeds the distance, determining a corresponding well depth increment accumulated value and a vertical increment accumulated value according to the division point serial number of the final accumulated measurement section when the well depth increment accumulated value is not lower than the critical well depth of the foam section for the first time, and determining the vertical depth of the working fluid level. The accuracy of working fluid level measurement and calculation can be effectively improved, and a reliable basis is provided for formulating a reasonable working system and optimizing the production capacity of the directional well.

Description

Technical Field

[0001] The present invention relates to the technical field of petroleum well logging, and in particular to a method, system, electronic equipment and storage medium for measuring dynamic liquid level in a directional well. Background Art

[0002] The depth of the liquid level in the annular space of the oil casing measured during the normal production of the oil well is called the dynamic liquid level. The dynamic liquid level is an important indicator reflecting the liquid supply capacity of the formation and an important basis for the oil field to determine the reasonable subsidence and formulate a reasonable work system.

[0003] At present, the commonly used method for testing the dynamic liquid level of oil wells is the echo test method, which uses the principle of sound wave reflection to calculate the annular liquid level depth of the oil well. However, this method has two disadvantages in the application of directional wells: first, the natural gas in the annular space of the casing will separate from the oil when the pressure is lower than the saturation pressure, generating a large amount of foam to form a foam segment, resulting in the sound wave only being able to identify the foam segment, affecting the accuracy of the dynamic liquid level test results. The tested dynamic liquid level will obviously deviate from the real dynamic liquid level, especially for high-gas directional wells, the impact is more obvious; second, the wellbore trajectory of the directional well is an irregular three-dimensional space curve. When using echo to test the dynamic liquid level, the sound wave is transmitted along the wellbore trajectory, and its detection distance cannot reflect the real dynamic liquid level depth of the directional well. Summary of the invention

[0004] In order to solve the above problems, the inventors have made the present invention, and through specific implementation methods, provide a directional well dynamic liquid level measurement method, system, electronic device and storage medium.

[0005] In a first aspect, an embodiment of the present invention provides a method for calculating a dynamic liquid level in a directional well, comprising the following steps:

[0006] According to the detection wave data of the wellhead wave source, determine the distance from the wellhead wave source to the dynamic liquid surface of the directional well test;

[0007] 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;

[0008] determining an actual bottom hole flowing pressure based on the distance;

[0009] 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 is a preset value;

[0010] When the critical well depth of the foam section exceeds the distance, the vertical depth of the dynamic liquid surface is determined according to the following method: when the well depth increment accumulated value is not lower than the critical well depth of the foam section for the first time, the segmentation point number of the last accumulated measurement section is recorded as parameter one; the vertical depth of the dynamic liquid surface is determined according to the well depth increment accumulated value and the vertical increment accumulated value corresponding to the segmentation point of parameter one.

[0011] In a second aspect, an embodiment of the present invention provides a directional well dynamic liquid level measurement system, comprising:

[0012] The test dynamic liquid level determination module is used 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;

[0013] The real dynamic liquid level measurement module is used to divide the wellbore trajectory of the directional well into multiple 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; take the actual bottom hole flow pressure as the starting point, determine the critical well depth of the foam section where the gas phase volume fraction is a preset value; 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 accumulated 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 accumulated measurement section as parameter one; determine the vertical depth of the dynamic liquid level 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 one.

[0014] In a third aspect, an embodiment of the present invention provides a method for determining a dynamic liquid surface foam section in a directional well, comprising the following steps:

[0015] According to the detection wave data of the wellhead wave source, determine the distance from the wellhead wave source to the dynamic liquid surface of the directional well test;

[0016] 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;

[0017] determining an actual bottom hole flowing pressure based on the distance;

[0018] 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 is a preset value;

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

[0020] In a fourth aspect, an embodiment of the present invention provides a directional well dynamic liquid surface foam segment judgment system, comprising:

[0021] The test dynamic liquid level determination module is used 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;

[0022] The foam section judgment module is used to divide the wellbore trajectory of the directional well 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 which the gas phase volume fraction is a preset value with the actual bottom hole flow pressure as the starting point; and judge the foam section according to the critical well depth of the foam section and the distance.

[0023] Based on the same inventive concept, an embodiment of the present invention provides an electronic device, including: a memory, a processor, and a computer program stored in the memory and running on the processor. When the processor executes the computer program, the aforementioned directional well dynamic liquid level measurement method or directional well dynamic liquid level foam section judgment method is implemented.

[0024] Based on the same inventive concept, an embodiment of the present invention provides a computer storage medium, in which computer executable instructions are stored. When the computer executable instructions are executed, the aforementioned directional well dynamic liquid level measurement method or directional well dynamic liquid level foam section judgment method is implemented.

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

[0026] In the dynamic liquid level measurement of directional wells, the present invention can collect dynamic liquid level detection acoustic wave data in real time, calculate the dynamic liquid level depth of the directional well with high precision, effectively reduce the interference of the annular foam section and the directional wellbore trajectory on the dynamic liquid level detection results, improve the accuracy of dynamic liquid level measurement, and provide a reliable basis for formulating reasonable work systems and optimizing production capacity for directional wells.

[0027] In the judgment of the foam section of the dynamic liquid surface in a directional well, the present invention can collect the dynamic liquid surface detection acoustic wave data in real time, and judge the foam section situation of the dynamic liquid surface in the directional well with high precision, so as to reduce the interference of the annular foam section and the directional wellbore trajectory on the judgment result of the dynamic liquid surface foam section situation, improve the accuracy of the foam section judgment, and provide a reliable basis for formulating a reasonable working system and optimizing the production capacity of the directional well.

[0028] Other features and advantages of the present invention will be described in the following description, or will be understood by practicing the present invention. The purpose and other advantages of the present invention can be realized and obtained by the structures particularly pointed out in the written description, claims, and drawings.

[0029] The technical solution of the present invention is further described in detail below through the accompanying drawings and embodiments. BRIEF DESCRIPTION OF THE DRAWINGS

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

[0031] Figure 1 This is a flow chart of a method for calculating the dynamic liquid level of a directional well X in an embodiment of the present invention;

[0032] Figure 2 A flow chart of calculating the vertical depth of the test dynamic liquid level in an embodiment of the present invention;

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

[0034] Figure 4 The figure is a schematic diagram of the structure of an electronic device in an embodiment of the present invention. DETAILED DESCRIPTION

[0035] The exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. Although the 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. On the contrary, 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, an embodiment of the present invention provides 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 liquid level of the directional well according to the detection wave data of the wellhead wave source. The test dynamic liquid level refers to the position of the dynamic liquid level estimated based on the determined distance from the wellhead wave source to the test dynamic liquid level of the directional well. Because it may be interfered by the foam segment, there may be a deviation between the test dynamic liquid level and the actual dynamic liquid 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 tubing 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] In the formula, 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 taken for the infrasound wave to reach the selected point, s; L dis the depth of the test liquid surface, m; t is the time it takes for the infrasound wave to reach the liquid surface, s .

[0045] Step S2: Divide the borehole trajectory of the directional well into a plurality of continuous measurement sections starting from the wellhead, and determine the well depth increment and vertical increment of each measurement section.

[0046] In some specific embodiments, determining the vertical increment of each measuring section includes the following steps: dividing the well depth increment of each measuring section 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, multiplying the well depth increment of the corresponding measuring section by the cosine of the well inclination angle at the dividing point to determine the vertical increment of the corresponding measuring section; when the well inclination angle at the dividing point of the measuring section changes, multiplying the difference between the sine of the well inclination angle at the dividing point of the measuring section and the sine of the well inclination angle at the dividing point of the previous measuring section by the curvature radius of the measuring section to obtain the vertical increment of the corresponding measuring section.

[0047] Specifically, the 3D borehole data of the directional well is imported, the borehole trajectory is divided into n segments, and the curvature radius R of each segment on the vertical section is calculated using the curvature radius method. Hi :

[0048]

[0049] Calculate the vertical increment for each segment:

[0050] ΔH i =R Hi (sinα i -sinα i-1 )

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

[0052] ΔH i =ΔL i cosα i

[0053] Calculate the cumulative well depth of each measuring section:

[0054]

[0055] Calculate the cumulative vertical increment of each measuring section:

[0056]

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

[0058] Calculate the vertical depth H of the test distance from the acoustic wave detection to the dynamic liquid surface by linear interpolation d :

[0059]

[0060] In the formula, R Hi is the radius of curvature of the measuring section on the vertical section, m; ΔL i is the depth increment of the measuring section, m; Δα i is the increment of the well inclination angle of the measuring section, rad; ΔH i is the vertical increment of the measuring section, m; α i is the well inclination angle at the i-th point, rad; L i H is the cumulative well depth of each measuring section up to the i-th point, m; i is the cumulative vertical increment of each measuring section to the i-th point, m; H d is the vertical depth of the test dynamic liquid surface, m.

[0061] Step S3: Determine the actual bottom hole flow pressure according to the distance.

[0062] In some specific embodiments, the actual bottom hole flow pressure is determined according to the distance, including the following steps: when the well depth increment cumulative value is not less than the distance for the first time, the segmentation point number of the last accumulated measurement section is recorded as parameter two; the vertical depth of the test dynamic liquid surface is determined according to the well depth increment cumulative value and the vertical increment cumulative value corresponding to the segmentation point of parameter two; the estimated 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; taking the estimated bottom hole flow pressure as the starting pressure, determine the liquid surface depth when the pressure is the pressure at the test dynamic liquid surface, when the liquid surface depth is different from the test distance, modulate the estimated bottom hole flow pressure, determine the new liquid surface depth, until the new liquid surface depth is equal to the test distance, and determine the estimated bottom hole flow pressure at this time as the actual bottom hole flow pressure.

[0063] In some specific embodiments, the vertical depth of the test dynamic liquid level is determined according to the well depth incremental cumulative value and the vertical incremental cumulative value corresponding to the parameter two-division point, including the following steps: Determine the vertical depth of the test dynamic liquid surface, where H d H is the vertical depth of the test liquid surface. i 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, H i-1 L is the vertical incremental cumulative value from the first measuring section to the corresponding measuring section of the sequence number i-1 split point. i L is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segmentation point number i. i-1is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segmentation point number i-1, L d It is the distance from the wellhead wave source to the dynamic liquid surface of the directional well test.

[0064] In some specific embodiments, determining the estimated bottom hole flow pressure according to the sum of the pressure at the vertical depth of the dynamic liquid level and the casing pressure includes the following steps: wf '=P c +ρgH d , determine the estimated bottom hole pressure, where P wf ' represents the estimated bottom hole pressure, P c is the casing pressure, ρ is the density of the bottom hole liquid, g represents the acceleration of gravity, H d To test the vertical depth of the dynamic liquid surface.

[0065] In some specific embodiments, determining the pressure at the test dynamic liquid level includes the following steps:

[0066] pass Determine the annular air column pressure P g ,

[0067] in,

[0068] By P d =P g +P c , determine the pressure at the test dynamic liquid surface, P c is the casing pressure, e is the base of the natural logarithm, f is the annulus module coefficient, q g is the gas flow rate, Y cp is the average temperature of the air 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, H z It is the depth in the middle of the oil well.

[0069] In some specific embodiments, the estimated bottom hole flowing pressure is used as the starting pressure, and the casing annulus pressure gradient is calculated to obtain the casing annulus pressure distribution;

[0070] Among them, through Calculate the casing annulus pressure gradient, Indicates the casing annulus pressure, ρ l is the liquid density, H l is the liquid holdup, ρ g is the gas density, g is the gravitational acceleration, θ is the well inclination angle of the corresponding measuring section, λ is the resistance coefficient, G m is the total mass flow rate of gas and liquid, v m is the superficial velocity of gas-liquid mixing, D is the hydraulic diameter of the annular space, Ap is the annular area of ​​the casing, v sg is the gas superficial velocity, is the average pressure of the calculation segment.

[0071] Specifically, given the estimated bottom hole pressure P wf ', using the Begges-Brill method for calculating multiphase pipe flow, the casing annulus pressure gradient is calculated to obtain the casing annulus pressure distribution, and the calculated pressure is P d The liquid depth L d ', if L d '≠L d , change the estimated bottom hole pressure and recalculate until L' d =L d , and the actual bottom hole pressure P is obtained wf .

[0072] Among them, because the calculation is the pressure distribution of the casing annulus, the above formula needs to be corrected. Specifically, D is corrected to the hydraulic diameter of the annular space, A p Corrected to the casing annulus area.

[0073] D=d1-d2

[0074]

[0075] d1 is the inner diameter of the casing, d2 is the outer diameter of the tubing, and the bottom hole flow pressure is used to estimate P using the pressure increment iteration method. wf ' is the starting pressure to calculate the pressure distribution in the annulus, and the calculated pressure is P d The liquid depth L d ', if L d '≠L d , change the estimated bottom hole pressure P wf ', recalculate until L d '=L d , and the actual bottom hole pressure P is obtained wf .

[0076] Step S4: 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 is a preset value.

[0077] When the natural gas in the annular space of the casing is lower than the saturation pressure, it will separate from the oil, producing a slug flow section with extremely low density and close to foam, namely the foam section. Since the flow state of the fluid in the wellbore is gradually transitioned without obvious boundaries, the definition of foam in chemical concepts is used as the basis for judging the foam section, that is, the dispersed system of gas in liquid, which is specifically reflected in the volume fraction of the gas phase.

[0078] In some specific embodiments, 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:

[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 preset value of the gas phase volume fraction is 90%. Taking the actual bottom hole flow pressure as the starting point, the Begges-Brill method for calculating 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 of the foam section where the gas phase volume fraction is 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 well depth increment cumulative 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 section is recorded as parameter 1; according to the well depth increment cumulative value and the vertical increment cumulative value corresponding to the segmentation point of parameter 1, the vertical depth of the dynamic liquid level is determined. The vertical depth of the dynamic liquid level of a directional well is also called the dynamic liquid level height of a directional well.

[0085] In some specific embodiments, determining the vertical depth of the dynamic liquid surface according to the well depth incremental cumulative value and the vertical incremental cumulative value corresponding to the parameter one segmentation point includes the following steps: Determine the vertical depth of the test dynamic liquid surface, where H is the vertical depth of the dynamic liquid surface, H i 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 1, H i-1 L is the vertical incremental cumulative value from the first measuring section to the corresponding measuring section of the sequence number i-1 split point. i L is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segmentation point number i. i-1 is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segmentation point number i-1, L cr is the critical well depth of the foam section when the gas phase volume fraction is a preset value.

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

[0087] Step 1: Collect detection sound wave data in real time and calculate the test distance from the sound wave detection to the dynamic liquid surface.

[0088] By identifying the clearer echo of the tubing collar, the average speed of infrasound propagation is obtained:

[0089]

[0090] Combined with the liquid surface echo time t, calculate the test dynamic liquid surface depth L d :

[0091]

[0092] In the formula, 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 taken for the infrasound wave to reach the selected point, s; L d is the test dynamic liquid surface depth, m; t is the time taken for the infrasound wave to reach the liquid surface, s.

[0093] Step 2: Calculate the vertical depth of the test dynamic liquid surface based on the 3D wellbore data.

[0094] like Figure 2 As shown in the figure, the 3D borehole data of the directional well is imported, the borehole trajectory is divided into n segments, and the curvature radius R of each segment on the vertical section is calculated using the curvature radius method. Hi :

[0095]

[0096] Calculate the vertical increment for each segment:

[0097] ΔH i =R Hi (sinα i -sinα i-1 )

[0098] When Δα i =0, ΔH i Calculated as follows:

[0099] ΔH i =ΔL i cosα i

[0100] Calculate the cumulative well depth of each measuring section:

[0101]

[0102] Calculate the cumulative vertical increment of each measuring section:

[0103]

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

[0105] Calculate the vertical depth H of the test distance from the acoustic wave detection to the dynamic liquid surface by linear interpolation d :

[0106]

[0107] In the formula, R Hi is the radius of curvature of the measuring section on the vertical section, m; ΔL i is the depth increment of the measuring section, m; Δα i is the increment of the well inclination angle of the measuring section, rad; ΔH i is the vertical increment of the measuring section, m; α i is the well inclination angle at the i-th point, rad; L i H is the cumulative well depth of each measuring section up to the i-th point, m; i is the cumulative vertical increment of each measuring 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 1.2MPa, 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, calculate the contrast temperature Compare 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: Figure 3 As shown, given the estimated bottom hole pressure P wf ', using the Begges-Brill method for calculating multiphase pipe flow, the casing annulus pressure gradient is calculated to obtain the casing annulus pressure distribution, and the calculated pressure is P d The liquid depth L d ', if L d '≠L d, change the estimated bottom hole pressure and recalculate until L d '=L d , and the actual bottom hole pressure P is obtained wf .

[0113] Given the estimated bottom hole pressure P wf '=P c +ρgH d =1.2+890×9.8×965.2×10 -6 =9.6MPa, where ρ is the bottom hole liquid density, kg / m 3 .

[0114] The pressure gradient is calculated as:

[0115]

[0116] Among them, because the calculation is the pressure distribution of the casing annulus, the above formula needs to be corrected. Specifically, D is corrected to the hydraulic diameter of the annular space, A p Corrected to the casing annulus area.

[0117] D=d1-d2=0.051m

[0118]

[0119] Using the pressure increment iteration method, the bottom hole flowing pressure is used to estimate P wf ' is the starting pressure to calculate the pressure distribution in the annulus, and the calculated pressure is P d The liquid depth L d ', if L d '≠L d , change the estimated bottom hole pressure P wf ', recalculate until L d '=L d , and the actual bottom hole pressure P is obtained wf =9.3MPa.

[0120] Where P wf ' is the estimated bottom hole pressure, MPa; L d ' is the pressure P d The liquid depth calculated at the time, m; P wf is the actual bottom hole flowing pressure, MPa; dp is the pressure interval, MPa; dZ is the depth interval, m; ρ l is the liquid density, kg / m 3 ρ g is the gas density, kg / m 3 ; g is the acceleration due to gravity, m / s 2 ; D is the hydraulic diameter of the annular space, m; A pis the casing annulus area, m 2 ;H l is the liquid holdup, dimensionless; θ is the inclination angle of the calculation section, unit: °; λ is the resistance coefficient, dimensionless; G m is the total mass flow rate of gas and liquid, kg / s; v sg is the gas superficial velocity, m / s; v m is the gas-liquid mixing superficial velocity, m / s; is the average pressure of the calculation section, MPa.

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

[0122] Taking the actual bottom hole pressure as the starting point, the Begges-Brill method for calculating 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 of the foam section where the volume fraction of the gas phase is 90% is found. cr .

[0123] Calculate when q g =0.74m 3 / s,q l =0.08m 3 / s, α=90%, and the corresponding well depth is the critical well depth L of the foam section. cr =1153.3m.

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

[0125] Step 7: Calculate the vertical depth of the dynamic fluid level in the directional well. The vertical depth of the dynamic fluid level in the directional well is also called the dynamic fluid level height in the directional well.

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

[0127] Calculate the vertical depth H of the dynamic liquid level in the directional well by interpolation using the straight line method:

[0128]

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

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

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

[0132] The test dynamic liquid level determination module is used 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;

[0133] The real dynamic liquid level measurement module is used to divide the wellbore trajectory of the directional well into multiple 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; take the actual bottom hole flow pressure as the starting point, determine the critical well depth of the foam section where the gas phase volume fraction is a preset value; 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 accumulated 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 accumulated measurement section as parameter one; determine the vertical depth of the dynamic liquid level 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 one.

[0134] Regarding the system in the above embodiment, the specific manner in which each module performs operations has been described in detail in the embodiment of the method, and will not be elaborated here.

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

[0136] Another embodiment of the present invention provides a method for determining a dynamic liquid surface foam section in a directional well, comprising the following steps:

[0137] According to the detection wave data of the wellhead wave source, determine the distance from the wellhead wave source to the dynamic liquid surface of the directional well test;

[0138] 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;

[0139] determining an actual bottom hole flowing pressure based on the distance;

[0140] 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 is a preset value;

[0141] The foam section is judged according to the critical well depth of the foam section and the distance.

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

[0143] 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;

[0144] 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.

[0145] Specifically, the method for determining the dynamic liquid surface foam section of a directional well further comprises the following steps:

[0146] The difference between the critical well depth of the foam section and the distance is determined as the foam section length. See step 6 in the previous X-well embodiment for details.

[0147] In the judgment of the dynamic liquid surface foam section of the directional well in this embodiment, the dynamic liquid surface detection acoustic wave data can be collected in real time, and the foam section situation of the dynamic liquid surface of the directional well can be judged with high precision, which is convenient for reducing the interference of the annular foam section and the directional wellbore trajectory on the judgment result of the dynamic liquid surface foam section situation, improving the accuracy of the foam section judgment, and providing a reliable basis for formulating a reasonable work system and optimizing production capacity for directional wells.

[0148] Another embodiment of the present invention provides a directional well dynamic liquid surface foam segment judgment system, comprising:

[0149] The test dynamic liquid level determination module is used 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] The foam section judgment module is used to divide the wellbore trajectory of the directional well 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 which the gas phase volume fraction is a preset value with the actual bottom hole flow pressure as the starting point; and judge the foam section according to the critical well depth of the foam section and the distance.

[0151] In the judgment of the dynamic liquid surface foam section of the directional well in this embodiment, the dynamic liquid surface detection acoustic wave data can be collected in real time, and the foam section situation of the dynamic liquid surface of the directional well can be judged with high precision, which is convenient for reducing the interference of the annular foam section and the directional wellbore trajectory on the judgment result of the dynamic liquid surface foam section situation, improving the accuracy of the foam section judgment, and providing a reliable basis for formulating a reasonable work system and optimizing production capacity for directional wells.

[0152] Based on the same inventive concept, an embodiment of the present invention provides an electronic device, whose structure is as follows Figure 4 As shown, it includes: a memory, a processor, and a computer program stored in the memory and running on the processor. When the processor executes the computer program, the above-mentioned directional well dynamic liquid level measurement method or directional well dynamic liquid level foam section judgment method is implemented.

[0153] Based on the same inventive concept, an embodiment of the present invention provides a computer storage medium, in which computer executable instructions are stored. When the computer executable instructions are executed, the aforementioned directional well dynamic liquid level measurement method or directional well dynamic liquid level foam section judgment method is implemented.

[0154] Any modifications, supplements and equivalent substitutions made within the scope of the principles of the present invention shall still fall within the patent scope of the present invention.

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, determine the distance from the wellhead wave source to the dynamic liquid surface of the directional well test; 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 an actual bottom hole flowing pressure based on the distance; 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 is a preset value; When the critical well depth of the foam section exceeds the distance, the vertical depth of the dynamic liquid surface is determined according to the following method: when the well depth increment accumulated value is not lower than the critical well depth of the foam section for the first time, the segmentation point number of the last accumulated measurement section is recorded as parameter one; the vertical depth of the dynamic liquid surface is determined according to the well depth increment accumulated value and the vertical increment accumulated value corresponding to the segmentation point of parameter one.

2. The method according to claim 1, characterized in that 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, including the following steps: The average speed of the detection wave propagating in the well is obtained through the tubing collar echo; The distance from the wellhead wave source to the dynamic liquid surface of the directional well test is determined according to the average speed and the time taken for the detection wave to reach the liquid surface.

3. The method according to claim 1, characterized in that 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 well depth increment of the corresponding measuring section is multiplied by the cosine of the well inclination angle at the dividing point to determine the vertical increment of the corresponding measuring section; When the well inclination angle of the segmentation point of the measuring section changes, the difference between the well inclination angle sine of the segmentation point of the measuring section and the well inclination angle sine of the previous segmentation point of the measuring section is multiplied by the curvature radius of the measuring section to obtain the vertical increment of the corresponding measuring section.

4. The method according to claim 1, characterized in that According to the distance, determining the actual bottom hole flow pressure comprises the following steps: When the well depth increment accumulated value is not less than the distance for the first time, the segmentation point number of the last accumulated measurement section is recorded as parameter 2; Determine the vertical depth of the test dynamic liquid surface according to the well depth incremental cumulative value and the vertical incremental cumulative value corresponding to the parameter two-division point; Determine the estimated value of bottom hole flow pressure based on the sum of the pressure at the vertical depth of the dynamic liquid surface and the casing pressure; The estimated bottom hole flow pressure is used as the starting pressure, and the liquid surface depth is determined when the pressure is the pressure at the test dynamic liquid surface. When the liquid surface depth is different from the test distance, the estimated bottom hole flow pressure is modulated to determine a new liquid surface depth until the new liquid surface depth is equal to the test distance. The estimated bottom hole flow pressure at this time is determined as the actual bottom hole flow pressure.

5. The method according to claim 4, characterized in that According to the well depth increment accumulated value and the vertical increment accumulated value corresponding to the parameter two-division point, the vertical depth of the test dynamic liquid surface is determined, including the following steps: pass Determine the vertical depth of the test dynamic liquid surface, where H d H is the vertical depth of the test liquid surface. i 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, H i-1 L is the vertical incremental cumulative value from the first measuring section to the corresponding measuring section of the sequence number i-1 split point. i L is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segmentation point with sequence number i. i-1 is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segmentation point number i-1, L d It is the distance from the wellhead wave source to the dynamic liquid surface of the directional well test.

6. The method according to claim 4, characterized in that Determine the estimated value of the bottom hole flow pressure according to the sum of the pressure at the vertical depth of the test dynamic liquid level and the casing pressure, including the following steps: By P wf '=P c +ρgH d , determine the estimated bottom hole pressure, where P wf ' represents the estimated bottom hole pressure, P c is the casing pressure, ρ is the density of the bottom hole liquid, g represents the acceleration of gravity, H d To test the vertical depth of the dynamic liquid surface.

7. The method according to claim 4, characterized in that Determining the pressure at the test dynamic liquid level includes the following steps: pass Determine the annular air column pressure P g , in, By p d =P g +P c , determine the pressure at the test dynamic liquid surface, P c is the casing pressure, e is the base of the natural logarithm, f is the annulus module coefficient, q g is the gas flow rate, T cp is the average temperature of the air 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, H z It is the depth in the middle of the oil well.

8. The method according to claim 1, characterized in that The method for calculating the dynamic liquid level of 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, ρ l is the liquid density, H l is the liquid holdup, ρ g is the gas density, g is the gravitational acceleration, θ is the well inclination angle of the corresponding measuring section, λ is the resistance coefficient, G m is the total mass flow rate of gas and liquid, v m is the superficial velocity of gas-liquid mixing, D is the hydraulic diameter of the annular space, A p is the annular area of ​​the casing, v sg is the gas superficial velocity, is the average pressure of the calculated segment.

9. The method according to claim 1, characterized in that 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 L of the foam section where the gas volume fraction is the preset value. cr ; 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, 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, 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.

10. The method according to claim 1, characterized in that Determining the vertical depth of the dynamic liquid surface according to the well depth incremental cumulative value and the vertical incremental cumulative value corresponding to the parameter one segmentation point includes the following steps: pass Determine the vertical depth of the test dynamic liquid surface, where H is the vertical depth of the dynamic liquid surface, H i 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 1, H i-1 L is the vertical incremental cumulative value from the first measuring section to the corresponding measuring section of the sequence number i-1 split point. i L is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segmentation point number i. i-1 L is the cumulative value of the well depth increment from the first measuring section to the measuring section corresponding to the segmentation point number i-1. cr is the critical well depth of the foam section when the gas phase volume fraction is a preset value.

11. 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 test dynamic liquid level of the directional well according to the detection wave data of the wellhead wave source; The real dynamic liquid level measurement module is used to divide the wellbore trajectory of the directional well into multiple 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; take the actual bottom hole flow pressure as the starting point, determine the critical well depth of the foam section where the gas phase volume fraction is a preset value; 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 accumulated 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 accumulated measurement section as parameter one; determine the vertical depth of the dynamic liquid level 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 one.

12. A method for determining the dynamic liquid surface 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, determine the distance from the wellhead wave source to the dynamic liquid surface of the directional well test; 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 an actual bottom hole flowing pressure based on the distance; 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 is a preset value; The foam section is judged according to the critical well depth of the foam section and the distance.

13. The method according to claim 12, characterized in that 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 there is no foam section in the dynamic liquid surface.

14. The method according to claim 12, characterized in that 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.

15. A directional well dynamic liquid surface foam segment 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 test dynamic liquid level of the directional well according to the detection wave data of the wellhead wave source; The foam section judgment module is used to divide the wellbore trajectory of the directional well 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 which the gas phase volume fraction is a preset value with the actual bottom hole flow pressure as the starting point; and judge the foam section according to the critical well depth of the foam section and the distance.

16. 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 calculating the dynamic liquid level in a directional well as described in any one of claims 1 to 10, or the method for determining the foam section of the dynamic liquid level in a directional well as described in any one of claims 12 to 14 is implemented.

17. 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 10, or the directional well dynamic liquid level foam section judgment method described in any one of claims 12 to 14.

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