Method and device for determining leakage risk point, equipment and medium

Abstract

According to the scheme, the method comprises the steps that a first candidate leakage risk horizon is determined according to a well logging curve of a drilled well within a preset range around a to-be-detected target well; determining a crack plane distribution diagram of the target well under different depths, and determining a second candidate leakage risk horizon according to the crack plane distribution diagram; determining a leakage risk horizon through the first candidate leakage risk horizon and the second candidate leakage risk horizon; and determining the leakage speed of each leakage risk horizon, and determining a leakage risk point according to the leakage speed. According to the scheme, stratum lithology changes and possible fractured stratum conditions are analyzed through adjacent well logging data, seismic data inversion is combined, leakage channel characteristics such as stratum fractures of the target well are further analyzed, leakage velocity calculation is carried out through the seepage theory, and the leakage risk point position of the target well is determined.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas exploration, and in particular to a method, device, equipment and medium for determining leakage risk points. Background Art

[0002] Well leakage is a common problem in the drilling process of oil and gas fields at home and abroad. It will extend the drilling cycle, waste a lot of drilling fluid and leak-proof plugging materials, and may cause complex accidents such as pipe sticking, well kick and even blowout. In severe cases, it may cause the wellbore to be scrapped. At the same time, after the leakage occurs, the drilling fluid leaks into the formation, causing pollution to the formation, affecting the accuracy of the logging data, and also having a great impact on the subsequent drilling operations. Therefore, predicting and warning the risk points of well leakage in advance can minimize the risk of well leakage.

[0003] The calculation of leakage layer and leakage velocity can be done by statistical analysis of field data, fitting the relationship between leakage velocity and pressure difference for calculation. This method requires a large amount of actual data and high data accuracy. The prediction of leakage velocity can also refer to the calculation of oil field water injection development, but this method requires detailed drilling records and has different accuracy for different characteristic formations.

[0004] Based on the defects of the existing technical solutions, a method for determining the leakage layer using conventional logging data and seismic data is needed. Summary of the invention

[0005] The present invention provides a method, device, equipment and medium for determining a leakage risk point, so as to determine a well logging leakage layer by using conventional well logging data and seismic data.

[0006] According to one aspect of the present invention, a method for determining a missing risk point is provided, comprising:

[0007] Determine a first candidate leakage risk layer according to the well logging curves of the wells drilled within a preset range around the target well to be detected;

[0008] Determine a fracture plane distribution map of the target well at different depths and determine a second candidate leakage risk layer according to the fracture plane distribution map;

[0009] Determine a leakage risk horizon through the first candidate leakage risk horizon and the second candidate leakage risk horizon;

[0010] The leakage velocity of each leakage risk layer is determined, and the leakage risk point is determined according to the leakage velocity.

[0011] Optionally, determining the first candidate leakage risk layer according to the well logging curves of the wells within a preset range around the target well to be detected includes:

[0012] Determine a mutation point and / or an abnormal point in at least one logging data in the logging curve;

[0013] The first candidate leakage risk layer is determined according to the layer where the mutation point and / or the abnormal point are located.

[0014] Optionally, determining a fracture plane distribution map of the target well at different depths and determining a second candidate leakage risk layer according to the fracture plane distribution map includes:

[0015] Acquiring the three-dimensional seismic data volume covering the target well;

[0016] Performing ant body fracture inversion on the three-dimensional seismic data volume by using an ant body tracking algorithm to obtain a fracture plane distribution map of the target well at different depths, wherein the fracture plane distribution map includes fracture distribution and fracture density;

[0017] Based on the fracture distribution, the layer where the high point of the fracture density is located is determined as the second candidate leakage risk layer.

[0018] Optionally, determining the leakage velocity of the leakage risk layer includes:

[0019] For each of the leakage risk zones, perform:

[0020] Determine the wellbore pressure difference of the current leakage risk layer, wherein the wellbore pressure difference represents the difference between the drilling fluid column pressure of the target well and the formation pressure;

[0021] Determine the formation permeability of the current leakage risk layer;

[0022] The leakage rate of the current leakage risk layer is determined according to the pressure difference in the wellbore and the formation permeability.

[0023] Optionally, determining the formation permeability of the current leakage risk layer includes:

[0024] The formation permeability of the current leakage risk layer is calculated by the following formula:

[0025] K = 8.33 × 10 6 φb 2 ;

[0026] Wherein, K is the formation permeability, φ is the formation porosity of the current leakage risk layer, and b is the leakage channel parameter of the current leakage risk layer.

[0027] Optionally, determining the leakage rate of the current leakage risk layer according to the pressure difference in the wellbore and the formation permeability includes:

[0028] The leakage velocity of the current leakage risk layer is determined by the following parameters:

[0029] The leakage rate of the current leakage risk layer; the leakage correction coefficient, which is determined by the formation and block of the current leakage risk layer; the formation permeability; the pressure difference in the wellbore; the plastic viscosity of the drilling fluid, which is determined by the drilling fluid used in the target well; the leakage influence radius; the wellbore radius of the target well; and the skin coefficient.

[0030] Optionally, determining the leakage risk point according to the leakage rate includes:

[0031] Generate a leakage velocity profile diagram according to the leakage velocity, in combination with the well logging curve and the fracture plane distribution diagram;

[0032] The leakage risk point is determined according to the leakage velocity profile.

[0033] According to another aspect of the present invention, there is provided a device for determining a leakage risk point, comprising:

[0034] A first candidate leakage risk layer determination unit, used to determine a first candidate leakage risk layer according to a well logging curve of a well within a preset range around a target well to be detected;

[0035] A second candidate leakage risk layer determination unit, used to determine a fracture plane distribution map of the target well at different depths and determine a second candidate leakage risk layer according to the fracture plane distribution map;

[0036] a leakage risk horizon determining unit, configured to determine a leakage risk horizon through the first candidate leakage risk horizon and the second candidate leakage risk horizon;

[0037] The leakage velocity determination unit is used to determine the leakage velocity of each leakage risk layer and determine the leakage risk point according to the leakage velocity.

[0038] According to another aspect of the present invention, an electronic device is provided, the electronic device comprising:

[0039] At least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores a computer program executable by the at least one processor, and the computer program is executed by the at least one processor so that the at least one processor can execute the method for determining a loss risk point as described in any embodiment of the present invention.

[0040] According to another aspect of the present invention, a computer-readable storage medium is provided, wherein the computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a processor to implement the method for determining a leakage risk point described in any embodiment of the present invention when executed.

[0041] The technical solution of the embodiment of the present invention determines the first candidate leakage risk layer according to the logging curve of the wells drilled within a preset range around the target well to be detected; determines the plane distribution map of the fractures of the target well at different depths and determines the second candidate leakage risk layer according to the plane distribution map of the fractures; determines the leakage risk layer through the first candidate leakage risk layer and the second candidate leakage risk layer; determines the leakage velocity of each leakage risk layer, and determines the leakage risk point according to the leakage velocity. The solution of the embodiment of the present invention analyzes the formation lithology changes and possible fracture formation conditions through the logging data of adjacent wells, combines with the inversion of seismic data, further analyzes the leakage channel characteristics such as the formation fractures of the target well, and calculates the leakage velocity through the seepage theory to determine the location of the leakage risk point of the target well.

[0042] It should be understood that the contents described in this section are not intended to identify the key or important features of the embodiments of the present invention, nor are they intended to limit the scope of the present invention. Other features of the present invention will become easily understood through the following description. BRIEF DESCRIPTION OF THE DRAWINGS

[0043] In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the following briefly introduces the drawings required for use in the description of the embodiments. Obviously, the drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0044] Figure 1 This is a flow chart of a method for determining a missing risk point provided in the first embodiment of the present invention;

[0045] Figure 2 is a schematic diagram of well logging data applicable to the first embodiment of the present invention;

[0046] Figure 3 is a schematic diagram of a fracture inversion applicable to the first embodiment of the present invention;

[0047] Figure 4 is a leakage velocity profile diagram applicable to the first embodiment of the present invention;

[0048] Figure 5 It is a structural schematic diagram of a device for determining a leakage risk point provided in Embodiment 2 of the present invention;

[0049] Figure 6It is a structural schematic diagram of an electronic device for implementing the method for determining a leakage risk point according to an embodiment of the present invention. DETAILED DESCRIPTION

[0050] In order to enable those skilled in the art to better understand the scheme of the present invention, the technical scheme in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present invention.

[0051] It should be noted that the terms "first", "second", etc. in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchanged where appropriate, so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units that are clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0052] Embodiment 1

[0053] Figure 1 This is a flow chart of a method for determining a leakage risk point provided by the first embodiment of the present invention. This embodiment is applicable to the case of determining a leakage risk point of drilling. The method can be executed by a leakage risk point determination device. The leakage risk point determination device can be implemented in the form of hardware and / or software. The leakage risk point determination device can be configured in an electronic device. Figure 1 As shown, the method includes:

[0054] S110, determining a first candidate leakage risk layer according to the logging curves of the wells drilled within a preset range around the target well to be detected.

[0055] The preset range can be determined based on the distance between other wells and the target well, or based on the wells in the same logging operation area. The logging curves in the logging data of the target well's neighboring wells can be used to analyze the formation lithology changes and possible fracture formation conditions in the area, thereby determining the possible first candidate loss risk layer.

[0056] In the embodiment of the present invention, step S110 specifically includes:

[0057] Determine a mutation point and / or an abnormal point in at least one logging data in the logging curve;

[0058] The first candidate leakage risk layer is determined according to the layer where the mutation point and / or the abnormal point are located.

[0059] Among them, the drilling and logging data of the neighboring wells of the target well are summarized, and the logging curve characteristics of the neighboring wells are analyzed. The logging data include but are not limited to sonic time difference, natural gamma, formation density, resistivity, etc. According to the obvious anomalies or mutations in the logging data, the lithology changes and the possible locations of fractured formations are analyzed, that is, the first candidate leakage risk layer.

[0060] Specifically, the logging curve suddenly changes, that is, the formation lithology suddenly changes, resulting in a well section with obvious abnormalities in natural gamma logging; and when there are cracks, pores, and caves, the acoustic time difference shows a high value, the formation density shows a low value, and the resistivity shows a low value. When the drilling fluid is lost, the wellbore will expand, the natural gamma value of the mudstone section will decrease slightly, and the value of the sandstone section will increase or change insignificantly; the measured formation acoustic time difference value increases, and the application effect of acoustic logging in carbonate formations is better. The well leakage characteristics of the fracture development zone are obvious: the acoustic logging value increases sharply, "cycle jump" occurs, and the Stoneley wave amplitude decreases; the measured formation density value decreases; the radial extension of the pressure fracture is generally not large, the shallow lateral resistivity decreases, and the deep lateral resistivity decreases little, and the difference amplitude is generally large; the "double track" phenomenon is particularly obvious, the parallelism decreases, and the difference amplitude also decreases.

[0061] S120, determining a fracture plane distribution map of the target well at different depths and determining a second candidate leakage risk layer according to the fracture plane distribution map.

[0062] Among them, the fracture plane distribution map can be determined and drawn by means of seismic data inversion and other methods to determine the lithology changes, formation fracture distribution and fracture parameters at different depths of the target well. The fracture characteristics reflected in the fracture plane distribution map can determine the second candidate leakage risk layer.

[0063] In the embodiment of the present invention, step S120 specifically includes:

[0064] Acquiring the three-dimensional seismic data volume covering the target well;

[0065] Performing ant body fracture inversion on the three-dimensional seismic data volume by using an ant body tracking algorithm to obtain a fracture plane distribution map of the target well at different depths, wherein the fracture plane distribution map includes fracture distribution and fracture density;

[0066] Based on the fracture distribution, the layer where the high point of the fracture density is located is determined as the second candidate leakage risk layer.

[0067] The ant body tracking algorithm is a highly efficient bionic optimization algorithm. A large number of electronic ants are spread in the three-dimensional seismic data volume and fracture conditions are set. These electronic ants then track and interpret the fracture traces that meet the preset fracture conditions, while those fracture traces that do not meet the fracture conditions will not be identified. Finally, an ant body with low noise and clear fracture traces is obtained.

[0068] Based on the ant body tracking algorithm, the seismic data of the target well is inverted to obtain the ant body attribute volume, and the fracture plane distribution map is determined according to the ant body attribute volume. The fracture plane distribution map reflects the fracture distribution and fracture density at different depths of the target well.

[0069] S130. Determine a leakage risk layer by using the first candidate leakage risk layer and the second candidate leakage risk layer.

[0070] When there are obvious changes in the logging curves such as sonic time difference, natural gamma, formation density, resistivity, etc., it means that there may be a sudden change in lithology or the existence of cracks, which is a potential risk of leakage. Combined with the inversion of fracture distribution based on the seismic data of the target well, the layers with high fracture density and obvious lithology changes are the layers with higher risk of leakage.

[0071] Exemplarily, the leakage risk horizon can be determined according to the combination of the well section of the first candidate leakage risk horizon and the second candidate leakage risk horizon. For example, if the first candidate leakage risk horizon is 4100m and 7400m, and the second candidate leakage risk horizon is 5100m and 6000m, then the leakage risk horizon can be the well section of 4100m, 5100m, 6000m and 7400m. When the values ​​of the first candidate leakage risk horizon and the second candidate leakage risk horizon are not much different, the numerical range of the two can also be used as the leakage risk horizon. For example, if the first leakage risk horizon is 4100m and the second leakage risk horizon is 4400m, then the leakage risk horizon can be the well section of 4100m-4400m.

[0072] S140, determining the leakage velocity of each leakage risk layer, and determining the leakage risk point according to the leakage velocity.

[0073] In an embodiment of the present invention, determining the leakage velocity of each leakage risk layer includes:

[0074] For each of the leakage risk zones, perform:

[0075] Determine the wellbore pressure difference of the current leakage risk layer, wherein the wellbore pressure difference represents the difference between the drilling fluid column pressure of the target well and the formation pressure;

[0076] Determine the formation permeability of the current leakage risk layer;

[0077] The leakage rate of the current leakage risk layer is determined according to the pressure difference in the wellbore and the formation permeability.

[0078] Among them, it is necessary to first calculate the pressure difference in the wellbore. The pressure difference in the wellbore is the difference between the drilling fluid column pressure and the formation pressure. The pressure difference ΔP calculation formula is:

[0079]

[0080] P P is the formation pressure, in MPa; n is the fluidity index, and Measured by flow rate rotation viscometer.

[0081] In an embodiment of the present invention, determining the formation permeability of the current leakage risk layer includes:

[0082] The formation permeability of the current leakage risk layer is calculated by the following formula:

[0083] K = 8.33 × 10 6 φb 2 ;

[0084] Wherein, K is the formation permeability, φ is the formation porosity of the current leakage risk layer, and b is the leakage channel parameter of the current leakage risk layer.

[0085] Specifically, the formation porosity φ is calculated as follows:

[0086] For formations without fractures:

[0087] For fractured formations: φ=ρ C b;

[0088] ρ b is the formation density, in g / cm 3 , ρ ma is the rock skeleton density, in g / cm 3 , ρ f is the density of pore fluid, fresh water fluid is 1g / cm 3 , saline fluid is 1.1 g / cm 3 , unit is g / cm 3 , ρ C is the crack density, in m -1 .

[0089] In an embodiment of the present invention, determining the leakage rate of the current leakage risk layer according to the wellbore pressure difference and the formation permeability includes:

[0090] The leakage velocity of the current leakage risk layer is determined by the following parameters:

[0091] The leakage rate of the current leakage risk layer; the leakage correction coefficient, which is determined by the formation and block of the current leakage risk layer; the formation permeability; the pressure difference in the wellbore; the plastic viscosity of the drilling fluid, which is determined by the drilling fluid used in the target well; the leakage influence radius; the wellbore radius of the target well; and the skin coefficient.

[0092] Specifically, the leakage rate can be calculated using the seepage theory, in which specific coefficients are taken for correction for different formations and blocks, while considering the effect of the drilling fluid fluidity index on the seepage.

[0093] In an embodiment of the present invention, determining the leakage risk point according to the leakage rate includes:

[0094] Generate a leakage velocity profile diagram according to the leakage velocity, in combination with the well logging curve and the fracture plane distribution diagram;

[0095] The leakage risk point is determined according to the leakage velocity profile.

[0096] Among them, after obtaining the leakage velocity by combining the logging data and seismic fracture inversion data, the leakage velocity profile at different depths of the target well is obtained, the layer section with higher leakage velocity is determined, and the leakage risk point of the target well is clarified.

[0097] The solution of the embodiment of the present invention is further explained below by a specific embodiment:

[0098] Take the drilling of a certain oil field as an example. The well had leakage at a depth of 4242m. According to the daily drilling report and well history, the drilling fluid density was 1.27g / cm 3 , the plastic viscosity of the drilling fluid is 23s, the fluidity index n = 0.7457; the formation pressure at this depth is 1.07g / cm 3 , formation density 2.56g / cm 3 , wellbore radius r w =311.2mm.

[0099] Analyze the drilling data, logging curve characteristics and formation lithology characteristics. The logging data such as acoustic time difference, natural gamma, formation density, resistivity, etc. show obvious anomalies or mutations. The logging curve mutation means that the formation lithology has a mutation, which leads to obvious segmentation of natural gamma logging; and when there is a leakage channel, the acoustic time difference shows a high value, the formation density shows a low value, and the resistivity shows a low value. Figure 2 is a schematic diagram of a well logging data applicable to the first embodiment of the present invention, such as Figure 2As shown in the figure, the acoustic time difference and natural gamma logging curves suddenly change near 4128m, which is inferred to be the lithology interface layer, which is the main risk point for leakage. At the same time, the natural gamma and acoustic time difference suddenly decrease near 7422m, indicating that the lithology of this layer has changed, which is a layer prone to leakage.

[0100] Using 3D seismic interpretation to perform ant body fracture inversion, the fracture distribution and fracture density are obtained. Figure 3 is a schematic diagram of a fracture inversion applicable to the first embodiment of the present invention, such as Figure 3 As shown in the figure, the leakage channels are well developed in the well sections near the peak points of fracture density at 5100m and 6000m, and there is a risk of leakage.

[0101] Taking into account the characteristics of logging curves and seismic fracture density inversion, four sections with high leakage risks were identified, namely the 4160-4400m section, the section near 5100m, the section near 6000m and the 7300-7600m section.

[0102] Taking the leakage rate at 4242m of the target well as an example, first calculate the well difference in the wellbore Among them, the fluidity index From this, we can get, ΔP = (1.27*4242*0.00981-1.0727*4242*0.00981) 0.75 =4.81MPa.

[0103] Calculate the formation permeability, K = 8.33 × 10 6 φb 2 , K = 8.33 × 10 6 ×0.17×0.002 2 =5.61μm 2 .

[0104] When α is 1, calculate the drilling loss velocity, assuming it is 5.42m 3 / h.

[0105] According to the above steps: drilling fluid density 1.27g / cm3, drilling fluid plastic viscosity 23s, fluidity index n = 0.7457, wellbore pressure difference 4.81MPa. Wellbore radius rw = 311.2mm. The formation permeability is calculated to be 5.56. In this example, take 1, and calculate the loss rate of the loss layer at a well depth of 4242m to be 5.42m3 / h. The actual loss rate at this location is 5.88m3 / h, with an absolute error of 0.46m3 / h and a relative error of 8%.

[0106] Figure 4This is a leakage velocity profile diagram applicable to the first embodiment of the present invention. The leakage velocity profile diagram can be obtained by repeating the above calculation steps to obtain the leakage velocity at different well depths of the target well.

[0107] According to the logging data of the well, the acoustic time difference, natural gamma, formation density, resistivity and other logging data of the formations near the depths of 4128m and 7422m were analyzed, and there were large changes, indicating that the lithology of this layer section has changed, and it is a layer prone to leakage. The formation fracture inversion based on seismic data shows that the fracture density is high in the section near the depth of 5100m and 6000m in the target well, and the leakage channel is well developed, and there is a risk of leakage in the corresponding section. Further combining the logging data, seismic fracture inversion data, and the performance parameters of the drilling fluid to be used in the target well, the leakage velocity profile at different depths of the target well is calculated (such as Figure 4 ), indicating that there is a high loss rate near the 4160-4400m, 5100m, 6000m and 7300-7600m sections. Therefore, it can be predicted that the target well is in the 4160-4400m, 5100m, 6000m and 7300-7600m sections with a high loss risk. According to the drilling log records, during the actual drilling process of the target well, lost circulation occurred at the depths of 4195.43m, 4242m, 5160m, 6037m and 7561.5m, which is consistent with the loss risk points determined by this method.

[0108] In summary, the embodiment of the present invention provides a method for determining leakage risk points based on seismic and well logging data, which analyzes formation lithology changes and possible cracks through well logging data of adjacent wells, obtains formation crack distribution and crack parameters through inversion of seismic data, clarifies the well section with leakage risk of the target well, calculates rock physics and mechanics and formation crack parameters based on logging and seismic data, calculates the leakage rate of the target well at different depths based on seepage theory, and comprehensively judges the well section with high leakage risk by combining logging data changes and seismic crack inversion, thereby clarifying the leakage risk point of the target well. This method is highly operational and has reliable prediction accuracy. After the leakage risk point of the target well is determined by this method, before drilling into the formation, the drilling engineering will specifically strengthen the plugging property of the drilling fluid, and prepare relevant plugging measures and technical measures in advance, which is conducive to reducing complex situations such as drilling fluid leakage, thereby saving drilling cycles and drilling costs.

[0109] Embodiment 2

[0110] Figure 5 Schematic diagram of the structure of a device for determining a leakage risk point provided by Embodiment 2 of the present invention. Figure 5 As shown, the device comprises:

[0111] A first candidate leakage risk layer determination unit 510 is used to determine a first candidate leakage risk layer according to the well logging curves of the wells within a preset range around the target well to be detected;

[0112] A second candidate leakage risk layer determination unit 520, configured to determine a fracture plane distribution map of the target well at different depths and determine a second candidate leakage risk layer according to the fracture plane distribution map;

[0113] A leakage risk layer determining unit 530, configured to determine a leakage risk layer by using the first candidate leakage risk layer and the second candidate leakage risk layer;

[0114] The leakage velocity determination unit 540 is used to determine the leakage velocity of each leakage risk layer, and determine the leakage risk point according to the leakage velocity.

[0115] Optionally, the first candidate leakage risk layer determination unit 510 is specifically configured to execute:

[0116] Determine a mutation point and / or an abnormal point in at least one logging data in the logging curve;

[0117] The first candidate leakage risk layer is determined according to the layer where the mutation point and / or the abnormal point are located.

[0118] Optionally, the second candidate leakage risk layer determination unit 520 is specifically configured to execute:

[0119] Acquiring the three-dimensional seismic data volume covering the target well;

[0120] Performing ant body fracture inversion on the three-dimensional seismic data volume by using an ant body tracking algorithm to obtain a fracture plane distribution map of the target well at different depths, wherein the fracture plane distribution map includes fracture distribution and fracture density;

[0121] Based on the fracture distribution, the layer where the high point of the fracture density is located is determined as the second candidate leakage risk layer.

[0122] Optionally, when determining the leakage velocity of the leakage risk layer, the leakage velocity determining unit 540 performs, for each leakage risk layer:

[0123] Determine the wellbore pressure difference of the current leakage risk layer, wherein the wellbore pressure difference represents the difference between the drilling fluid column pressure of the target well and the formation pressure;

[0124] Determine the formation permeability of the current leakage risk layer;

[0125] The leakage rate of the current leakage risk layer is determined according to the pressure difference in the wellbore and the formation permeability.

[0126] Optionally, the leakage velocity determination unit 540, when determining the formation permeability of the current leakage risk layer, specifically performs:

[0127] The formation permeability of the current leakage risk layer is calculated by the following formula:

[0128] K = 8.33 × 10 6 φb 2 ;

[0129] Wherein, K is the formation permeability, φ is the formation porosity of the current leakage risk layer, and b is the leakage channel parameter of the current leakage risk layer.

[0130] Optionally, the leakage velocity determining unit 540, when determining the leakage velocity of the current leakage risk layer according to the wellbore pressure difference and the formation permeability, specifically performs:

[0131] The leakage velocity of the current leakage risk layer is determined by the following parameters:

[0132] The leakage rate of the current leakage risk layer; the leakage correction coefficient, which is determined by the formation and block of the current leakage risk layer; the formation permeability; the pressure difference in the wellbore; the plastic viscosity of the drilling fluid, which is determined by the drilling fluid used in the target well; the leakage influence radius; the wellbore radius of the target well; and the skin coefficient.

[0133] Optionally, the leakage velocity determining unit 540, when determining the leakage risk point according to the leakage velocity, specifically performs:

[0134] Generate a leakage velocity profile diagram according to the leakage velocity, in combination with the well logging curve and the fracture plane distribution diagram;

[0135] The leakage risk point is determined according to the leakage velocity profile.

[0136] The leakage risk point determination device provided in the embodiment of the present invention can execute the leakage risk point determination method provided in any embodiment of the present invention, and has the corresponding functional modules and beneficial effects of the execution method.

[0137] Embodiment 3

[0138] Figure 6A schematic diagram of the structure of an electronic device 10 that can be used to implement an embodiment of the present invention is shown. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processing, cellular phones, smart phones, wearable devices (such as helmets, glasses, watches, etc.) and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely examples and are not intended to limit the implementation of the present invention described and / or required herein.

[0139] like Figure 6 As shown, the electronic device 10 includes at least one processor 11, and a memory connected to the at least one processor 11, such as a read-only memory (ROM) 12, a random access memory (RAM) 13, etc., wherein the memory stores a computer program that can be executed by at least one processor, and the processor 11 can perform various appropriate actions and processes according to the computer program stored in the read-only memory (ROM) 12 or the computer program loaded from the storage unit 18 to the random access memory (RAM) 13. In the RAM 13, various programs and data required for the operation of the electronic device 10 can also be stored. The processor 11, the ROM 12, and the RAM 13 are connected to each other through a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0140] A number of components in the electronic device 10 are connected to the I / O interface 15, including: an input unit 16, such as a keyboard, a mouse, etc.; an output unit 17, such as various types of displays, speakers, etc.; a storage unit 18, such as a disk, an optical disk, etc.; and a communication unit 19, such as a network card, a modem, a wireless communication transceiver, etc. The communication unit 19 allows the electronic device 10 to exchange information / data with other devices through a computer network such as the Internet and / or various telecommunication networks.

[0141] The processor 11 may be a variety of general and / or special processing components with processing and computing capabilities. Some examples of the processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any appropriate processor, controller, microcontroller, etc. The processor 11 executes the various methods and processes described above, such as the method for determining the risk point of leakage.

[0142] In some embodiments, the method for determining the risk of leakage points may be implemented as a computer program, which is tangibly contained in a computer-readable storage medium, such as a storage unit 18. In some embodiments, part or all of the computer program may be loaded and / or installed on the electronic device 10 via the ROM 12 and / or the communication unit 19. When the computer program is loaded into the RAM 13 and executed by the processor 11, one or more steps of the method for determining the risk of leakage points described above may be performed. Alternatively, in other embodiments, the processor 11 may be configured to perform the method for determining the risk of leakage points in any other appropriate manner (e.g., by means of firmware).

[0143] Various implementations of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field programmable gate arrays (FPGAs), application specific integrated circuits (ASICs), application specific standard products (ASSPs), systems on chips (SOCs), load programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various implementations can include: being implemented in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which can be a special purpose or general purpose programmable processor that can receive data and instructions from a storage system, at least one input device, and at least one output device, and transmit data and instructions to the storage system, the at least one input device, and the at least one output device.

[0144] Computer programs for implementing the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, so that when the computer program is executed by the processor, the functions / operations specified in the flow chart and / or block diagram are implemented. The computer program may be executed entirely on the machine, partially on the machine, partially on the machine and partially on a remote machine as a stand-alone software package, or entirely on a remote machine or server.

[0145] In the context of the present invention, a computer-readable storage medium may be a tangible medium that may contain or store a computer program for use by or in combination with an instruction execution system, device or equipment. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, devices or equipment, or any suitable combination of the foregoing. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. A more specific example of a machine-readable storage medium may include an electrical connection based on one or more lines, a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing.

[0146] To provide interaction with a user, the systems and techniques described herein may be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and a pointing device (e.g., a mouse or trackball) through which the user can provide input to the electronic device. Other types of devices may also be used to provide interaction with the user; for example, the feedback provided to the user may be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user may be received in any form (including acoustic input, voice input, or tactile input).

[0147] The systems and techniques described herein may be implemented in a computing system that includes backend components (e.g., as a data server), or a computing system that includes middleware components (e.g., an application server), or a computing system that includes frontend components (e.g., a user computer with a graphical user interface or a web browser through which a user can interact with implementations of the systems and techniques described herein), or a computing system that includes any combination of such backend components, middleware components, or frontend components. The components of the system may be interconnected by any form or medium of digital data communication (e.g., a communication network). Examples of communication networks include: a local area network (LAN), a wide area network (WAN), a blockchain network, and the Internet.

[0148] A computing system may include a client and a server. The client and the server are generally remote from each other and usually interact through a communication network. The client and server relationship is generated by computer programs running on the corresponding computers and having a client-server relationship with each other. The server may be a cloud server, also known as a cloud computing server or cloud host, which is a host product in the cloud computing service system to solve the defects of difficult management and weak business scalability in traditional physical hosts and VPS services.

[0149] It should be understood that the various forms of processes shown above can be used to reorder, add or delete steps. For example, the steps described in the present invention can be executed in parallel, sequentially or in different orders, as long as the desired results of the technical solution of the present invention can be achieved, and this document does not limit this.

[0150] The above specific implementations do not constitute a limitation on the protection scope of the present invention. It should be understood by those skilled in the art that various modifications, combinations, sub-combinations and substitutions can be made according to design requirements and other factors. Any modification, equivalent substitution and improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.

Claims

1. A method for determining a missing risk point, characterized in that: include: Determine a first candidate leakage risk layer according to the well logging curves of the wells drilled within a preset range around the target well to be detected; Determine a fracture plane distribution map of the target well at different depths and determine a second candidate leakage risk layer according to the fracture plane distribution map; Determine a leakage risk horizon through the first candidate leakage risk horizon and the second candidate leakage risk horizon; The leakage velocity of each leakage risk layer is determined, and the leakage risk point is determined according to the leakage velocity.

2. The method according to claim 1, characterized in that The method of determining the first candidate leakage risk layer according to the well logging curves of the wells within a preset range around the target well to be detected includes: Determine a mutation point and / or an abnormal point in at least one logging data in the logging curve; The first candidate leakage risk layer is determined according to the layer where the mutation point and / or the abnormal point are located.

3. The method according to claim 1, characterized in that: Determining the fracture plane distribution map of the target well at different depths and determining the second candidate leakage risk layer according to the fracture plane distribution map, including: Acquiring the three-dimensional seismic data volume covering the target well; Performing ant body fracture inversion on the three-dimensional seismic data volume by using an ant body tracking algorithm to obtain a fracture plane distribution map of the target well at different depths, wherein the fracture plane distribution map includes fracture distribution and fracture density; Based on the fracture distribution, the layer where the high point of the fracture density is located is determined as the second candidate leakage risk layer.

4. The method according to claim 1, characterized in that: Determining the leakage rate of the leakage risk layer includes: For each of the leakage risk zones, perform: Determine the wellbore pressure difference of the current leakage risk layer, wherein the wellbore pressure difference represents the difference between the drilling fluid column pressure of the target well and the formation pressure; Determine the formation permeability of the current leakage risk layer; The leakage rate of the current leakage risk layer is determined according to the pressure difference in the wellbore and the formation permeability.

5. The method according to claim 4, characterized in that Determining the formation permeability of the current leakage risk layer includes: The formation permeability of the current leakage risk layer is calculated by the following formula: K=8.33×10 6 φb 2 ; Wherein, K is the formation permeability, φ is the formation porosity of the current leakage risk layer, and b is the leakage channel parameter of the current leakage risk layer.

6. The method according to claim 4, characterized in that The step of determining the leakage rate of the current leakage risk layer according to the pressure difference in the wellbore and the formation permeability includes: The leakage velocity of the current leakage risk layer is determined by the following parameters: The leakage rate of the current leakage risk layer; the leakage correction coefficient, which is determined by the formation and block of the current leakage risk layer; the formation permeability; the pressure difference in the wellbore; the plastic viscosity of the drilling fluid, which is determined by the drilling fluid used in the target well; the leakage influence radius; the wellbore radius of the target well; and the skin coefficient.

7. The method according to claim 1, characterized in that The determining of the leakage risk point according to the leakage velocity includes: Generate a leakage velocity profile diagram according to the leakage velocity, in combination with the well logging curve and the fracture plane distribution diagram; The leakage risk point is determined according to the leakage velocity profile.

8. A device for determining a leakage risk point, characterized in that: include: A first candidate leakage risk layer determination unit, used to determine a first candidate leakage risk layer according to a well logging curve of a well within a preset range around a target well to be detected; A second candidate leakage risk layer determination unit, used to determine a fracture plane distribution map of the target well at different depths and determine a second candidate leakage risk layer according to the fracture plane distribution map; a leakage risk horizon determining unit, configured to determine a leakage risk horizon through the first candidate leakage risk horizon and the second candidate leakage risk horizon; The leakage velocity determination unit is used to determine the leakage velocity of each leakage risk layer and determine the leakage risk point according to the leakage velocity.

9. An electronic device, characterized in that The electronic device comprises: At least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores a computer program executable by the at least one processor, and the computer program is executed by the at least one processor so that the at least one processor can execute the method for determining a leakage risk point according to any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that The computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a processor to implement the method for determining a leakage risk point according to any one of claims 1 to 7 when executed.

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