Method, device, equipment and medium for calculating oil well producing depth of fault-soluble body reservoir

Abstract

The application discloses a kind of faulted dissolution body reservoir oil well producing depth acquisition method, device, equipment and medium.Faulted dissolution body reservoir oil well producing depth acquisition method includes: obtaining the temperature well testing monitoring data of target faulted dissolution body reservoir oil well;Temperature well testing monitoring data is handled, and actual temperature well testing interpretation curve is obtained;Temperature well testing model of target faulted dissolution body reservoir oil well is constructed, and the theoretical temperature well testing interpretation curve corresponding to multiple heat transfer distances is obtained based on temperature well testing model;Comparative analysis actual temperature well testing interpretation curve and theoretical temperature well testing interpretation curve, the heat transfer distance corresponding to the theoretical temperature well testing interpretation curve most matched with actual temperature well testing interpretation curve is determined as the producing depth of target faulted dissolution body reservoir oil well.Using the present application can reduce the uncertainty of faulted dissolution body reservoir producing depth calculation, improve the accuracy of producing depth calculation.

Description

Technical Field

[0001] This invention relates to the field of oil and gas field development technology, and in particular to a method, apparatus, equipment and medium for determining the working depth of oil wells in fractured solution reservoirs. Background Technology

[0002] Fault-solved reservoirs are a new type of carbonate reservoir discovered in recent years. Their main reservoir space types are cavities or fractures formed by faulting. For conventional sandstone reservoirs, particularly clastic reservoirs, the effective evaluation parameter for the extent of reservoir exploitation is the exploit radius, which primarily considers the planar exploitation range. However, fault-solved reservoirs typically exhibit a "thick plate-like" structure. Considering this characteristic, simply considering the planar exploitation range no longer aligns with geological understanding. Furthermore, production dynamics show temperature differences between flow and static temperatures during the development of fault-solved reservoirs, indicating that fluid flow is primarily vertical. Based on this understanding, the concept of "exploitation depth" for fault-solved wells is proposed, referring to the vertical distance from the point below the wellbore where fluid flow begins during well production.

[0003] The "explosive depth" of oil wells in fractured solution reservoirs has a similar significance to parameters such as the (effective, limit) excavation radius, which characterizes the planar excavation range of oil wells in low-permeability, tight, and heavy oil reservoirs, and the production layer, which characterizes the vertical excavation location of oil wells in conventional sandstone reservoirs with multi-layer synergistic production. It mainly reflects the excavation range of oil well reserves.

[0004] As a novel reservoir type, research on the well activation depth in fault-subsidence reservoirs is currently limited. At present, the calculation of well activation depth in fault-subsidence reservoirs mainly relies on numerical simulation to fit pressure and temperature data, thereby determining the activation location. However, this method is significantly affected by factors such as operating conditions, production rate, and geological understanding, resulting in considerable uncertainty in determining the activation depth. Summary of the Invention

[0005] The technical problem to be solved by the present invention is that there is a large uncertainty in the determination of the utilization depth in the prior art.

[0006] To solve the above-mentioned technical problems, the present invention provides a method, apparatus, equipment and medium for determining the working depth of oil wells in fractured solution reservoirs.

[0007] A method for determining the operational depth of an oil well in a fractured solution reservoir includes:

[0008] Acquire temperature well test monitoring data of oil wells in the target fractured solution reservoir;

[0009] The temperature well test monitoring data is processed to obtain the actual temperature well test interpretation curve;

[0010] A temperature well test model for the target fractured solution reservoir well is constructed, and theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances are obtained based on the temperature well test model.

[0011] By comparing and analyzing the actual temperature well test interpretation curve and the theoretical temperature well test interpretation curve, the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve is determined as the activation depth of the target fractured solution reservoir well.

[0012] Optionally, the temperature well test monitoring data includes the formation temperature corresponding to each acquisition time; the processing of the temperature well test monitoring data to obtain the actual temperature well test interpretation curve includes:

[0013] The temperature derivative is obtained using the formation temperature at each time point.

[0014] Based on the formation temperature and the temperature derivative, a double logarithmic curve is plotted to obtain the actual temperature well test interpretation curve.

[0015] Optionally, the step of using the formation temperature at each time point to calculate the temperature derivative includes:

[0016]

[0017] Wherein, △T′ is the temperature derivative, △T is the temperature change of the formation temperature, △t is the time change at the time of acquisition, n is the total number of temperature data points calculated in segments, and i is the number of data points calculated in segments.

[0018] Optionally, the temperature well test model includes the heat transfer equation for porous media, the heat transfer equation for fractured media, and the wellbore heat transfer model; the construction of the temperature well test model for the target fractured-dissolved reservoir well, and the acquisition of theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances based on the temperature well test model, includes:

[0019] Establish the heat transfer equations for the pore medium, the heat transfer equations for the fracture medium, and the heat transfer model for the wellbore in the target fractured solution reservoir, and set the boundary conditions;

[0020] The wellbore heat transfer model was subjected to Laplace transform based on the boundary conditions, and temperature solutions were obtained for multiple heat transfer distances.

[0021] The temperature solution in Laplace space was converted into the temperature solution in real space by using the numerical inversion method, and the temperature inside the wellbore corresponding to multiple heat transfer distances was obtained.

[0022] Based on the wellbore temperature corresponding to each heat transfer distance, a double logarithmic curve of temperature and temperature derivative is plotted to obtain the theoretical temperature well test interpretation curve corresponding to the heat transfer distance.

[0023] Optionally, the heat transfer equation of the porous medium includes:

[0024]

[0025] The heat transfer equation of the fracture medium includes:

[0026]

[0027] The wellbore heat transfer model includes:

[0028]

[0029] The boundary conditions include:

[0030]

[0031] T w (z,t=0)=T i (z);

[0032]

[0033]

[0034] T1(z=0,t=T0;

[0035] Among them, T V Z represents the surface temperature within the porous medium, in Kelvin (K); Z represents the heat transfer distance, in meters (m); ρ V Density of rock within porous media, in kg / m³ 3 ;λ v C represents the thermal conductivity of the stratum in a porous medium, expressed in W / (m·K); v T represents the specific heat of a porous medium within a stratum, expressed in J / (kg·K); F ρ represents the formation temperature within the fractured medium, in Kelvin (K). F The average surface crude oil density is expressed in kg / m³. 3 ;λ F λ is the thermal conductivity of the fractured formation, expressed in W / (m·K); V h represents the thermal conductivity of porous media formations, expressed in W / (m·K). F T represents the thickness of the fractured formation, in meters (m). w The temperature inside the wellbore is expressed in Kelvin (K); ρ f This refers to the fluid density inside the wellbore, expressed in kg / m³. 3 C f λ is the specific heat of the fluid inside the wellbore, expressed in J / (kg·K); tRt is the thermal conductivity of the fluid inside the wellbore, in W / (m·K); Q is the flow rate of the fluid inside the wellbore, in ms / s; rt w 1 is the wellbore radius in meters; 2 is the operating radius in meters; 3 is the overall thermal conductivity coefficient; 4 is the formation temperature in Kelvin; 5 is the temperature at operating depth of 0 in Kelvin; 6 is the initial formation temperature in Kelvin.

[0036] Optionally, the comparative analysis of the actual temperature well test interpretation curve and the theoretical temperature well test interpretation curve, determining the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve as the activation depth of the target fractured solution reservoir well, includes:

[0037] The actual temperature well test interpretation curve is fitted with the theoretical temperature well test interpretation curve at multiple heat transfer distances;

[0038] The theoretical temperature well test interpretation curve with the highest fitting degree to the actual temperature well test interpretation curve is determined, and the heat transfer distance corresponding to the determined theoretical temperature well test interpretation curve is taken as the activation depth of the oil well in the target fractured solution reservoir.

[0039] An apparatus for determining the working depth of an oil well in a fractured solution reservoir includes:

[0040] The data acquisition module is used to acquire temperature well test monitoring data of the target fractured solution reservoir well;

[0041] The actual curve generation module is used to process the temperature well test monitoring data to obtain the actual temperature well test interpretation curve;

[0042] The theoretical curve generation module is used to construct a temperature well test model for the target fractured solution reservoir well, and obtain theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances based on the temperature well test model.

[0043] The activation depth calculation module is used to compare and analyze the actual temperature well test interpretation curve and the theoretical temperature well test interpretation curve, and determine the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve as the activation depth of the target fractured solution reservoir well.

[0044] Optionally, the temperature well test monitoring data includes the formation temperature corresponding to each acquisition time; the actual curve generation module uses the formation temperature corresponding to each time to calculate the temperature derivative; and a double logarithmic curve is plotted based on the formation temperature and the temperature derivative to obtain the actual temperature well test interpretation curve.

[0045] A computer device includes a memory and a processor, the memory storing a computer program, and the processor executing the computer program performing the following steps:

[0046] Acquire temperature well test monitoring data of oil wells in the target fractured solution reservoir;

[0047] The temperature well test monitoring data is processed to obtain the actual temperature well test interpretation curve;

[0048] A temperature well test model for the target fractured solution reservoir well is constructed, and theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances are obtained based on the temperature well test model.

[0049] By comparing and analyzing the actual temperature well test interpretation curve and the theoretical temperature well test interpretation curve, the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve is determined as the activation depth of the target fractured solution reservoir well.

[0050] A computer-readable storage medium having a computer program stored thereon, the computer program performing the following steps when executed by a processor:

[0051] Acquire temperature well test monitoring data of oil wells in the target fractured solution reservoir;

[0052] The temperature well test monitoring data is processed to obtain the actual temperature well test interpretation curve;

[0053] A temperature well test model for the target fractured solution reservoir well is constructed, and theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances are obtained based on the temperature well test model.

[0054] By comparing and analyzing the actual temperature well test interpretation curve and the theoretical temperature well test interpretation curve, the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve is determined as the activation depth of the target fractured solution reservoir well.

[0055] Compared with the prior art, one or more embodiments of the above solutions may have the following advantages or beneficial effects:

[0056] By utilizing temperature well test monitoring data, two methods are employed: firstly, processing the data to obtain actual temperature well test interpretation curves; and secondly, deriving theoretical temperature well test interpretation curves based on temperature well test models. Comparative analysis of these two interpretation curves yields the activation depth, thereby clarifying the well's reservoir activation status. This method effectively eliminates the influence of factors such as operating regime, production rate, and geological understanding on the determination of activation depth in numerical simulation methods, reducing the uncertainty in calculating activation depth in fractured-solution reservoirs and improving the accuracy of activation depth calculations. Furthermore, it provides a clear material basis for the formulation of reservoir operating regimes and recovery rate methods, which is of great significance for the efficient development of fractured-solution reservoirs. Attached Figure Description

[0057] The scope of this disclosure can be better understood by reading the following detailed description of exemplary embodiments in conjunction with the accompanying drawings. The accompanying drawings are:

[0058] Figure 1(a) shows a comparison of the flow temperature and static temperature test results of a typical oil well with a fractured solution.

[0059] Figure 1(b) is a magnified view of a portion of Figure 1(a);

[0060] Figure 2 A schematic diagram of the operating depth of oil wells in ultra-deep fractured-collapse reservoirs;

[0061] Figure 3 This is a typical seismic profile of a fault-collapsed reservoir.

[0062] Figure 4 This is a flowchart illustrating a method for determining the activation depth of an oil well in a fractured solution reservoir, as shown in one embodiment.

[0063] Figure 5 A graph illustrating the actual temperature well test results in one embodiment;

[0064] Figure 6 A physical model of a dual-medium reservoir where large-scale karst caves are directly connected to wellbores;

[0065] Figure 7 This is a theoretical temperature well test interpretation curve calculated using a temperature well test model in one embodiment;

[0066] Figure 8 A double logarithmic curve of temperature and temperature derivative corresponding to different heat transfer distances;

[0067] Figure 9 This is a structural block diagram of a device for determining the working depth of an oil well in a fractured solution reservoir, as shown in one embodiment.

[0068] Figure 10 shows the temperature test interpretation and fitting curves of different wells in a typical fractured solution in the SHB reservoir; among them, (a) is the curve fitting diagram of well SH5 (time 1), (b) is the curve fitting diagram of well SH5 (time 2), (c) is the curve fitting diagram of well SH5-2, and (d) is the curve fitting diagram of well SH5-12H. Detailed Implementation

[0069] To make the objectives, technical solutions, and advantages of the present invention clearer, the implementation method of the present invention will be described in detail below with reference to the accompanying drawings and embodiments, so that the process of how the present invention uses technical means to solve technical problems and achieve technical effects can be fully understood and implemented accordingly.

[0070] Fault-solved reservoirs are a novel type of fault-solved reservoir. Current technologies for calculating the working depth of fault-solved reservoirs propose the concept of "oil source depth" and use numerical simulation to fit temperature changes to estimate the oil source depth. However, this method is highly dependent on the accuracy of the model, the fitting process is complex, and there are many uncertainties. Regarding temperature testing, Ramey established an approximate solution model for wellbore temperature curves of production and injection wells. This model is a milestone in the development of wellbore temperature interpretation models. After proposing this approximate solution model, many scholars have developed different wellbore temperature calculation models based on it. Considering the complexity of heat transfer in porous media, most models treat the heat transfer from the wellbore to the formation as a steady-state process and use numerical methods to study the heat transfer problem between the wellbore and the formation. Satter et al. established a wellbore temperature prediction model for steam injection wells based on the Remy model, using phase changes during production as model calculation constants, clarifying the heat loss during fluid flow and its impact on the well temperature profile. Saga et al. added the momentum conservation equation and Joule-Thomson coefficient calculation to the Ramey model to study the wellbore temperature distribution under multiphase flow conditions. Hansan and Kabi established a wellbore temperature model for analyzing two-phase flow in the wellbore based on the heat conduction and convection equations, assuming that the annulus has a significant impact on the wellbore temperature. Farshad et al., based on existing temperature prediction models, developed a new wellbore temperature prediction method using a neural network model based on the laws of conservation of mass, momentum, and energy in thermodynamic equations. Jacques Hagoor solved the error of the Ramey model under transient conditions using linear calculation methods. Yoshioka et al. studied the influence of fluid inflow temperature on wellbore temperature by establishing a horizontal well temperature inversion model. Steady-state temperature models treat the heat transfer from the wellbore to the formation as a steady-state process, which differs greatly from reality. Currently, there is relatively little research on transient heat transfer in the wellbore; most studies analyze the transient heat transfer process by establishing a wellbore-reservoir coupling model.

[0071] Analysis shows that current methods for calculating the activation depth of fractured solution reservoirs mainly rely on numerical simulation to fit pressure and temperature data, thereby determining the activation location. However, these methods are significantly affected by factors such as working conditions, production rate, and geological understanding, resulting in considerable uncertainty in determining the activation depth. Furthermore, the geological model construction and numerical simulation research cycles are too long, failing to meet the fast-paced requirements of mining operations and making field implementation difficult.

[0072] Analysis of the monitoring data for flow temperature and static temperature revealed that at shallow depths, the flow temperature and static temperature exhibited consistent trends with small differences in curve slope. As depth increased, the overall difference between flow temperature and static temperature decreased. However, at depths exceeding 6500m, the slope of the static temperature curve did not change significantly, while the flow temperature increased slowly with depth, exhibiting a convex shape. The static temperature gradually approached the flow temperature, but they were not equal, as shown in Figures 1(a) and 1(b). Figure 1 shows that when the depth is less than 6500m, both flow temperature and static temperature monitoring results indicate a linear relationship between temperature and depth. However, when the depth exceeds 6500m, the slope of the static temperature curve did not change significantly, while the flow temperature increased slowly with depth, exhibiting a convex shape. The analysis suggests that the difference between flow temperature and static temperature is due to the vertical movement of the fluid: the pressure at the bottom of the well is low, and the higher-temperature fluid in the reservoir below flows towards the bottom under the pressure difference. Figure 2 As shown, Figure 2 This reflects the flow of warmer fluids in the reservoir below the wellbore towards the wellbore under pressure differential; fluid flow in fault-collapsed reservoirs is primarily vertical. Fault-collapsed reservoirs exhibit a beaded network of interconnected caverns along their vertical direction, such as... Figure 3 The reservoirs are vertically developed in three types of fractured-solution reservoirs, with good vertical connectivity. During production, deep fluids flow upward along beaded karst channels to supply fluid to the wellbore. How to invert the depth of the supplied fluid and obtain the exploitable depth of the reservoir is a difficult problem that urgently needs to be solved.

[0073] Based on this, this application provides a method for determining the activation depth of an oil well in a fractured solution reservoir. The method is based on the observation of a significant increase in flow temperature during the oil well production process. The temperature changes with pressure and production. The method uses temperature monitoring data to interpret well test data and obtain the vertical position where the fluid begins to move, i.e., the activation depth.

[0074] Example 1

[0075] A method for determining the operational depth of oil wells in fractured solution reservoirs is provided, such as... Figure 4 As shown, the method includes:

[0076] S110: Obtain temperature well test monitoring data of the target fractured solution reservoir well.

[0077] The target well in the fractured solution reservoir is the well in the fractured solution reservoir where the operating depth needs to be determined. Among them, the temperature well test monitoring data is obtained through temperature well testing.

[0078] S130: Process the temperature test monitoring data to obtain the actual temperature test interpretation curve.

[0079] S150: Construct a temperature well test model for the target fractured solution reservoir well, and obtain theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances based on the temperature well test model.

[0080] S170: By comparing and analyzing the actual temperature well test interpretation curves and the theoretical temperature well test interpretation curves, the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve is determined as the activation depth of the target fractured solution reservoir well.

[0081] The aforementioned method for determining the well activation depth in fault-collapsed reservoirs utilizes temperature well test monitoring data. On one hand, it processes the temperature well test monitoring data to obtain the actual temperature well test interpretation curve; on the other hand, it derives the theoretical temperature well test interpretation curve based on a temperature well test model. By comparing and analyzing the actual and theoretical temperature well test interpretation curves, the activation depth is determined, thus clarifying the well's reserve activation status. This method effectively eliminates the influence of factors such as operating regime, production rate, and geological understanding on the determination of activation depth in numerical simulation methods, reducing the uncertainty in calculating the activation depth of fault-collapsed reservoirs and improving the accuracy of activation depth calculations. Furthermore, it provides a clear material basis for the formulation of reservoir operating regimes and recovery rate methods, which is of great significance for the efficient development of fault-collapsed reservoirs.

[0082] Preferably, the temperature well test monitoring data includes the formation temperature corresponding to each acquisition time. Step S130 includes: using the formation temperature corresponding to each time, calculating the temperature derivative; and plotting a double logarithmic curve based on the formation temperature and the temperature derivative to obtain the actual temperature well test interpretation curve.

[0083] Temperature well test monitoring data can be used to obtain the change of formation temperature (T) over time (t), and the temperature derivative ΔT′ can be calculated. Based on the calculated temperature derivative ΔT′ and the formation temperature T obtained from the well test monitoring, logarithmic curves showing the relationship between t and T and t and ΔT′ are plotted. The resulting curves are the interpretation curves of the actual temperature well test. For example, Figure 5 The actual temperature well test interpretation curve is shown for a typical oil well in a fractured solution reservoir.

[0084] Preferably, the temperature derivative can be obtained using the following formula 1:

[0085]

[0086] Where △T′ is the temperature derivative, △T is the temperature change of the formation, △t is the time change at the time of acquisition, n is the total number of temperature data points calculated in segments, and i is the number of data points calculated in segments.

[0087] Preferably, the temperature well test model may include the heat transfer equation for porous media, the heat transfer equation for fractured media, and the heat transfer model for the wellbore. Step S150 includes steps (a1) to (a4).

[0088] Step (a1): Establish the heat transfer equations for the pore medium, the heat transfer equations for the fracture medium, and the heat transfer model for the wellbore in the target fractured solution reservoir, and set the boundary conditions.

[0089] Among them, the heat transfer equations of porous media and fractured media belong to the formation heat transfer model; that is, the formation heat transfer model includes the heat transfer equations of porous media and fractured media.

[0090] Step (a2): Perform a Laplace transform on the wellbore heat transfer model in conjunction with the boundary conditions and solve for the temperature at multiple heat transfer distances.

[0091] Step (a3): Use numerical inversion to convert the temperature solution in Laplace space into the temperature solution in real space, and obtain the wellbore temperature corresponding to multiple heat transfer distances.

[0092] Step (a4): Based on the temperature inside the wellbore corresponding to each heat transfer distance, plot the double logarithmic curves of temperature and temperature derivative to obtain the well test interpretation curve of the theoretical temperature corresponding to the heat transfer distance.

[0093] Specifically, by utilizing the heat loss caused by the upward flow of fluid to the surrounding wellbore, a wellbore heat transfer model is established. This model is then coupled with a formation heat transfer model to analyze the fluid supply depth of the reservoir. For example... Figure 6 As shown, there is a certain distance between the reservoir fluid supply depth and the test point. The fluid flows upward along the beaded cavern channel to supply fluid to the wellbore. During the upward flow, heat is continuously dissipated to the surrounding area of ​​the wellbore, resulting in heat loss. A wellbore heat transfer model is established and coupled with a formation heat transfer model to analyze the fluid supply depth of the reservoir so as to obtain the utilization depth based on the test point location.

[0094] Specifically, the basic assumptions for establishing the temperature well test model are: the fluid is single-phase and slightly compressible; the reservoir rock is homogeneous and isotropic; gravity and capillary effects can be ignored; the flowing fluid and reservoir rock are in thermal equilibrium; and the fluid flowing from the reservoir into the wellbore is an isenthalpic process.

[0095] Optionally, a temperature well test model is established based on the principle of energy conservation, wherein the heat transfer equation of the porous medium includes:

[0096]

[0097] The heat transfer equations for fractured media include:

[0098]

[0099] Wellbore heat transfer models include:

[0100]

[0101] Boundary conditions include:

[0102]

[0103] T w (z,t=0)=T i (z);

[0104]

[0105]

[0106] T1(z=0,t=T0;

[0107] Among them, T V Z represents the surface temperature within the porous medium, in Kelvin (K); Z represents the heat transfer distance, in meters (m); ρ V Density of rock within porous media, in kg / m³ 3 ;λ v C represents the thermal conductivity of the stratum in a porous medium, expressed in W / (m·K); v T represents the specific heat of a porous medium within a stratum, expressed in J / (kg·K); F ρ represents the formation temperature within the fractured medium, in Kelvin (K). F The average surface crude oil density is expressed in kg / m³. 3 ;λ F λ is the thermal conductivity of the fractured formation, expressed in W / (m·K); V h represents the thermal conductivity of porous media formations, expressed in W / (m·K). F T represents the thickness of the fractured formation, in meters (m). w The temperature inside the wellbore is expressed in Kelvin (K); ρ f This refers to the fluid density inside the wellbore, expressed in kg / m³. 3 C f λ is the specific heat of the fluid inside the wellbore, expressed in J / (kg·K); t Rt is the thermal conductivity of the fluid inside the wellbore, in W / (m·K); Q is the flow rate of the fluid inside the wellbore, in ms / s; rt w1 is the wellbore radius in meters; 2 is the operating radius in meters; 3 is the overall thermal conductivity coefficient; 4 is the formation temperature in Kelvin; 5 is the temperature at operating depth of 0 in Kelvin; 6 is the initial formation temperature in Kelvin.

[0108] Optionally, step S170 includes: fitting the actual temperature well test interpretation curve with the theoretical temperature well test interpretation curve under multiple heat transfer distances; determining the theoretical temperature well test interpretation curve with the highest fitting degree to the actual temperature well test interpretation curve, and using the heat transfer distance corresponding to the determined theoretical temperature well test interpretation curve as the activation depth of the target fractured solution reservoir well.

[0109] For example, Figure 7 As shown, the double logarithmic curves of temperature and temperature derivatives calculated using the temperature well test model include stages such as the thermal reservoir influence stage, the first thermal radial flow stage, the crossflow stage, and the second thermal radial flow stage. Among them:

[0110] ① Thermal storage capacity influence stage: This stage represents the influence of the fluid's thermal storage capacity. The temperature and temperature derivative curves will show a straight line with a slope of 1.

[0111] ② The first thermal radial flow stage indicates that the thermal flow in the fracture medium has reached the radial flow stage;

[0112] ③ The thermal runaway stage refers to the thermal runaway stage in the dissolution cavity to the fracture. A "dip" appears on the temperature derivative curve. The depth and position of the "dip" are related to the fracture storage ratio and the thermal runaway coefficient.

[0113] ④ The second thermal radial flow stage indicates that the thermal flow in the crack and pore media simultaneously reaches the radial flow stage.

[0114] This paper analyzes the impact of heat transfer distance (i.e., operational depth, m) on the interpretation curve of the theoretical temperature well test, focusing on the main factors of interest. Figure 8 It is known that the greater the heat transfer distance, the greater the fluid temperature change, the faster the temperature change rate, and the higher the temperature derivative curve. Therefore, by fitting the actual temperature well test interpretation curve with the theoretical temperature well test interpretation curve at different heat transfer distances, the curve shape that is closest to the actual temperature well test interpretation curve is the theoretical temperature well test interpretation curve with the highest fitting degree. The heat transfer distance corresponding to the theoretical temperature well test interpretation curve with the highest fitting degree is taken as the activation depth of the oil well in the target fractured solution reservoir.

[0115] Example 2

[0116] A device for determining the working depth of oil wells in fractured solution reservoirs is provided, such as... Figure 9 As shown, the device includes:

[0117] The data acquisition module 910 is used to acquire temperature well test monitoring data of the target fractured-dissolve reservoir well; the actual curve generation module 930 is used to process the temperature well test monitoring data to obtain the actual temperature well test interpretation curve; the theoretical curve generation module 950 is used to construct the temperature well test model of the target fractured-dissolve reservoir well, and obtain the theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances based on the temperature well test model; the operating depth determination module 970 is used to compare and analyze the actual temperature well test interpretation curve and the theoretical temperature well test interpretation curve, and determine the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve as the operating depth of the target fractured-dissolve reservoir well.

[0118] The aforementioned well activation depth determination device for fractured-solution reservoirs utilizes temperature well test monitoring data. On one hand, it processes the temperature well test monitoring data to obtain actual temperature well test interpretation curves; on the other hand, it generates theoretical temperature well test interpretation curves based on a temperature well test model. By comparing and analyzing the actual and theoretical temperature well test interpretation curves, the activation depth is determined, thus clarifying the well's reservoir activation status. This effectively eliminates the influence of factors such as operating conditions, production rate, and geological understanding on the determination of activation depth in numerical simulation methods, reducing the uncertainty in calculating the activation depth of fractured-solution reservoirs and improving the accuracy of activation depth calculations. Furthermore, it provides a clear material basis for the formulation of reservoir operating conditions and recovery rate methods, which is of great significance for the efficient development of fractured-solution reservoirs.

[0119] Preferably, the temperature well test monitoring data includes the formation temperature corresponding to each acquisition time; the actual curve generation module 930 uses the formation temperature corresponding to each time to calculate the temperature derivative; and a double logarithmic curve is plotted based on the formation temperature and the temperature derivative to obtain the actual temperature well test interpretation curve.

[0120] Temperature well test monitoring data can be used to obtain the change of formation temperature (T) over time (t), and the temperature derivative ΔT′ can be calculated. Based on the calculated temperature derivative ΔT′ and the formation temperature T obtained from well test monitoring, a double logarithmic relationship curve of t with T and t with ΔT′ can be plotted. The resulting curve is the actual temperature well test interpretation curve.

[0121] Preferably, the temperature derivative can be obtained using the following formula 1:

[0122]

[0123] Where △T′ is the temperature derivative, △T is the temperature change of the formation, △t is the time change at the time of acquisition, n is the total number of temperature data points calculated in segments, and i is the number of data points calculated in segments.

[0124] Preferably, the temperature well test model may include the heat transfer equation for the porous medium, the heat transfer equation for the fractured medium, and the wellbore heat transfer model. The theoretical curve generation module 950 is used to: establish the heat transfer equations for the porous medium, the heat transfer equations for the fractured medium, and the wellbore heat transfer model for the target fractured solution reservoir well, and set boundary conditions; perform a Laplace transform on the wellbore heat transfer model based on the boundary conditions and solve for temperature solutions at multiple heat transfer distances; convert the temperature solutions in Laplace space to temperature solutions in real space using a numerical inversion method to obtain the wellbore temperatures corresponding to multiple heat transfer distances; and plot double logarithmic curves of temperature and temperature derivatives based on the wellbore temperatures corresponding to each heat transfer distance to obtain the theoretical temperature well test interpretation curves corresponding to the heat transfer distances.

[0125] Among them, the heat transfer equations for porous media and fractured media belong to the formation heat transfer model. Specifically, during the upward flow of fluid, heat is continuously dissipated to the surrounding wellbore, resulting in heat loss, to establish a wellbore heat transfer model. This model is then coupled with the formation heat transfer model to analyze the fluid supply depth of the reservoir.

[0126] Specifically, the basic assumptions for establishing the temperature well test model are: the fluid is single-phase and slightly compressible; the reservoir rock is homogeneous and isotropic; gravity and capillary effects can be ignored; the flowing fluid and reservoir rock are in thermal equilibrium; and the fluid flowing from the reservoir into the wellbore is an isenthalpic process.

[0127] Optionally, a temperature well test model is established based on the principle of energy conservation, wherein the heat transfer equation of the porous medium includes:

[0128]

[0129] The heat transfer equations for fractured media include:

[0130]

[0131] Wellbore heat transfer models include:

[0132]

[0133] Boundary conditions include:

[0134]

[0135] T w (z,t=0)=T i (z);

[0136]

[0137]

[0138] T1(z=0,t=T0;

[0139] Among them, T V Z represents the surface temperature within the porous medium, in Kelvin (K); Z represents the heat transfer distance, in meters (m); ρ V Density of rock within porous media, in kg / m³ 3 ;λ v C represents the thermal conductivity of the stratum in a porous medium, expressed in W / (m·K); v T represents the specific heat of a porous medium within a stratum, expressed in J / (kg·K); F ρ represents the formation temperature within the fractured medium, in Kelvin (K). F The average surface crude oil density is expressed in kg / m³. 3 ;λ F λ is the thermal conductivity of the fractured formation, expressed in W / (m·K); V h represents the thermal conductivity of porous media formations, expressed in W / (m·K). F T represents the thickness of the fractured formation, in meters (m). w The temperature inside the wellbore is expressed in Kelvin (K); ρ f This refers to the fluid density inside the wellbore, expressed in kg / m³. 3 C f λ is the specific heat of the fluid inside the wellbore, expressed in J / (kg·K); t Rt is the thermal conductivity of the fluid inside the wellbore, in W / (m·K); Q is the flow rate of the fluid inside the wellbore, in ms / s; rt w 1 is the wellbore radius in meters; 2 is the operational radius in meters; 3 is the overall thermal conductivity coefficient; 4 is the formation temperature in Kelvin; 5 is the temperature at depth 0 in Kelvin; 6 is the initial surface temperature in Kelvin.

[0140] Optionally, the activation depth determination module is used to: fit the actual temperature well test interpretation curve with the theoretical temperature well test interpretation curve under multiple heat transfer distances; determine the theoretical temperature well test interpretation curve with the highest fitting degree to the actual temperature well test interpretation curve, and use the heat transfer distance corresponding to the determined theoretical temperature well test interpretation curve as the activation depth of the target fractured solution reservoir well.

[0141] The actual temperature well test interpretation curve is fitted with the theoretical temperature well test interpretation curve at different heat transfer distances. The curve with the closest shape to the actual temperature well test interpretation curve is the theoretical temperature well test interpretation curve with the highest fitting degree. The heat transfer distance corresponding to the theoretical temperature well test interpretation curve with the highest fitting degree is used as the activation depth of the oil well in the target fractured solution reservoir.

[0142] Specific limitations regarding the device for determining the well operating depth in fault-collapsed reservoirs can be found in the above-described limitations on the method for determining the well operating depth in fault-collapsed reservoirs, and will not be repeated here. Each module in the aforementioned device for determining the well operating depth in fault-collapsed reservoirs can be implemented entirely or partially through software, hardware, or a combination thereof. These modules can be embedded in or independent of the processor in a computer device, or stored in the memory of a computer device as software, so that the processor can call and execute the operations corresponding to each module. It should be noted that the module division in this embodiment is illustrative and only represents a logical functional division; other division methods may be used in actual implementation.

[0143] Example 3

[0144] In one embodiment, a computer device is provided, including a memory and a processor, wherein the memory stores a computer program, and the processor executes the computer program to perform the following steps:

[0145] Step (10): Obtain temperature well test monitoring data of the target fractured solution reservoir well.

[0146] Step (30): Process the temperature test monitoring data to obtain the actual temperature test interpretation curve.

[0147] Step (50): Construct a temperature well test model for the target fractured solution reservoir well, and obtain theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances based on the temperature well test model.

[0148] Step (70): Compare and analyze the actual temperature well test interpretation curve and the theoretical temperature well test interpretation curve, and determine the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve as the activation depth of the target fractured solution reservoir well.

[0149] The aforementioned computer equipment, whose processor executes a computer program, utilizes temperature well test monitoring data. On one hand, it processes the data to obtain actual temperature well test interpretation curves; on the other hand, it generates theoretical temperature well test interpretation curves based on a temperature well test model. By comparing and analyzing the actual and theoretical interpretation curves, the activation depth is determined, thus clarifying the oil well's reserve activation status. This effectively eliminates the influence of factors such as operating conditions, production rate, and geological understanding on the determination of activation depth in numerical simulation methods, reducing the uncertainty in calculating activation depth in fractured-dissolved reservoirs and improving the accuracy of activation depth calculations. Furthermore, it provides a clear material basis for the formulation of reservoir operating conditions and recovery rate methods, which is of great significance for the efficient development of fractured-dissolved reservoirs.

[0150] Preferably, the temperature well test monitoring data includes the formation temperature corresponding to each acquisition time. When the processor executes the computer program, step (30) includes: using the formation temperature corresponding to each time to obtain the temperature derivative; and plotting a double logarithmic curve based on the formation temperature and the temperature derivative to obtain the actual temperature well test interpretation curve.

[0151] Temperature well test monitoring data can be used to obtain the change of formation temperature (T) over time (t), and the temperature derivative ΔT′ can be calculated. Based on the calculated temperature derivative ΔT′ and the formation temperature T obtained from well test monitoring, a double logarithmic relationship curve of t with T and t with ΔT′ can be plotted. The resulting curve is the actual temperature well test interpretation curve.

[0152] Preferably, the temperature derivative can be obtained using the following formula 1:

[0153]

[0154] Where △T′ is the temperature derivative, △T is the temperature change of the formation, △t is the time change at the time of acquisition, n is the total number of temperature data points calculated in segments, and i is the number of data points calculated in segments.

[0155] Preferably, the temperature well test model may include the heat transfer equation of the porous medium, the heat transfer equation of the fractured medium, and the wellbore heat transfer model. When the processor executes the computer program, step (50) includes: establishing the heat transfer equation of the porous medium, the heat transfer equation of the fractured medium, and the wellbore heat transfer model of the target fractured solution reservoir well, and setting boundary conditions; performing a Laplace transform on the wellbore heat transfer model in combination with the boundary conditions and solving for temperature solutions at multiple heat transfer distances; using the numerical inversion method to convert the temperature solutions in Laplace space into temperature solutions in real space, and obtaining the wellbore temperatures corresponding to multiple heat transfer distances; plotting double logarithmic curves of temperature and temperature derivatives according to the wellbore temperatures corresponding to each heat transfer distance, and obtaining the theoretical temperature well test interpretation curves corresponding to the heat transfer distances.

[0156] Among them, the heat transfer equations for porous media and fractured media belong to the formation heat transfer model. Specifically, during the upward flow of fluid, heat is continuously dissipated to the surrounding wellbore, resulting in heat loss, to establish a wellbore heat transfer model. This model is then coupled with the formation heat transfer model to analyze the fluid supply depth of the reservoir.

[0157] Specifically, the basic assumptions for establishing the temperature well test model are: the fluid is single-phase and slightly compressible; the reservoir rock is homogeneous and isotropic; gravity and capillary effects can be ignored; the flowing fluid and reservoir rock are in thermal equilibrium; and the fluid flowing from the reservoir into the wellbore is an isenthalpic process.

[0158] Optionally, a temperature well test model is established based on the principle of energy conservation, wherein the heat transfer equation of the porous medium includes:

[0159]

[0160] The heat transfer equations for fractured media include:

[0161]

[0162] Wellbore heat transfer models include:

[0163]

[0164] Boundary conditions include:

[0165]

[0166] T w (z,t=0)=T i (z);

[0167]

[0168]

[0169] T1(z=0,t=T0;

[0170] Among them, T V Z represents the surface temperature within the porous medium, in Kelvin (K); Z represents the heat transfer distance, in meters (m); ρ V Density of rock within porous media, in kg / m³ 3 ;λ v C represents the thermal conductivity of the stratum in a porous medium, expressed in W / (m·K); v T represents the specific heat of a porous medium within a stratum, expressed in J / (kg·K); F ρ represents the formation temperature within the fractured medium, in Kelvin (K). F The average surface crude oil density is expressed in kg / m³. 3 ;λ F λ is the thermal conductivity of the fractured formation, expressed in W / (m·K); V h represents the thermal conductivity of porous media formations, expressed in W / (m·K). F T represents the thickness of the fractured formation, in meters (m). w The temperature inside the wellbore is expressed in Kelvin (K); ρ f This refers to the fluid density inside the wellbore, expressed in kg / m³. 3 C f λ is the specific heat of the fluid inside the wellbore, expressed in J / (kg·K); t Rt is the thermal conductivity of the fluid inside the wellbore, in W / (m·K); Q is the flow rate of the fluid inside the wellbore, in ms / s; rt w1 is the wellbore radius in meters; 2 is the operational radius in meters; 3 is the overall thermal conductivity coefficient; 4 is the formation temperature in Kelvin; 5 is the temperature at depth 0 in Kelvin; 6 is the initial surface temperature in Kelvin.

[0171] Optionally, when the processor executes the computer program, step (70) includes: fitting the actual temperature well test interpretation curve with the theoretical temperature well test interpretation curve under multiple heat transfer distances; determining the theoretical temperature well test interpretation curve with the highest fitting degree to the actual temperature well test interpretation curve, and using the heat transfer distance corresponding to the determined theoretical temperature well test interpretation curve as the activation depth of the target fractured solution reservoir well.

[0172] The actual temperature well test interpretation curve is fitted with the theoretical temperature well test interpretation curve at different heat transfer distances. The curve with the closest shape to the actual temperature well test interpretation curve is the theoretical temperature well test interpretation curve with the highest fitting degree. The heat transfer distance corresponding to the theoretical temperature well test interpretation curve with the highest fitting degree is used as the activation depth of the oil well in the target fractured solution reservoir.

[0173] Example 4

[0174] In one embodiment, a computer-readable storage medium is provided having a computer program stored thereon, which, when executed by a processor, performs the following steps:

[0175] Step (10): Obtain temperature well test monitoring data of the target fractured solution reservoir well.

[0176] Step (30): Process the temperature test monitoring data to obtain the actual temperature test interpretation curve.

[0177] Step (50): Construct a temperature well test model for the target fractured solution reservoir well, and obtain theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances based on the temperature well test model.

[0178] Step (70): Compare and analyze the actual temperature well test interpretation curve and the theoretical temperature well test interpretation curve, and determine the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve as the activation depth of the target fractured solution reservoir well.

[0179] The aforementioned computer-readable storage medium stores a computer program that utilizes temperature well test monitoring data. On one hand, it processes the data to obtain actual temperature well test interpretation curves; on the other hand, it generates theoretical temperature well test interpretation curves based on a temperature well test model. By comparing and analyzing the actual and theoretical interpretation curves, the activation depth is determined, thus clarifying the well's reservoir activation status. This effectively eliminates the influence of factors such as operating conditions, production rate, and geological understanding on the determination of activation depth in numerical simulation methods, reducing the uncertainty in calculating activation depth in fractured-dissolve reservoirs and improving the accuracy of activation depth calculations. Furthermore, it provides a clear material basis for the formulation of reservoir operating conditions and recovery rate methods, which is of great significance for the efficient development of fractured-dissolve reservoirs.

[0180] Preferably, the temperature well test monitoring data includes the formation temperature corresponding to each acquisition time. When the computer program is executed by the processor, step (30) includes: using the formation temperature corresponding to each time to calculate the temperature derivative; and plotting a double logarithmic curve based on the formation temperature and the temperature derivative to obtain the actual temperature well test interpretation curve.

[0181] Temperature well test monitoring data can be used to obtain the change of formation temperature (T) over time (t), and the temperature derivative ΔT′ can be calculated. Based on the calculated temperature derivative ΔT′ and the formation temperature T obtained from well test monitoring, a double logarithmic relationship curve of t with T and t with ΔT′ can be plotted. The resulting curve is the actual temperature well test interpretation curve.

[0182] Preferably, the temperature derivative can be obtained using the following formula 1:

[0183]

[0184] Where △T′ is the temperature derivative, △T is the temperature change of the formation, △t is the time change at the time of acquisition, n is the total number of temperature data points calculated in segments, and i is the number of data points calculated in segments.

[0185] Preferably, the temperature well test model may include the heat transfer equation of the porous medium, the heat transfer equation of the fractured medium, and the wellbore heat transfer model. When the computer program is executed by the processor, step (50) includes: establishing the heat transfer equation of the porous medium, the heat transfer equation of the fractured medium, and the wellbore heat transfer model of the target fractured solution reservoir well, and setting boundary conditions; performing a Laplace transform on the wellbore heat transfer model in combination with the boundary conditions and solving for temperature solutions at multiple heat transfer distances; converting the temperature solutions in Laplace space to temperature solutions in real space using the numerical inversion method to obtain the wellbore temperatures corresponding to multiple heat transfer distances; and plotting double logarithmic curves of temperature and temperature derivatives according to the wellbore temperatures corresponding to each heat transfer distance to obtain the theoretical temperature well test interpretation curves corresponding to the heat transfer distances.

[0186] Among them, the heat transfer equations for porous media and fractured media belong to the formation heat transfer model. Specifically, during the upward flow of fluid, heat is continuously dissipated to the surrounding wellbore, resulting in heat loss, to establish a wellbore heat transfer model. This model is then coupled with the formation heat transfer model to analyze the fluid supply depth of the reservoir.

[0187] Specifically, the basic assumptions for establishing the temperature well test model are: the fluid is single-phase and slightly compressible; the reservoir rock is homogeneous and isotropic; gravity and capillary effects can be ignored; the flowing fluid and reservoir rock are in thermal equilibrium; and the fluid flowing from the reservoir into the wellbore is an isenthalpic process.

[0188] Optionally, a temperature well test model is established based on the principle of energy conservation, wherein the heat transfer equation of the porous medium includes:

[0189]

[0190] The heat transfer equations for fractured media include:

[0191]

[0192] Wellbore heat transfer models include:

[0193]

[0194] Boundary conditions include:

[0195]

[0196] T w (z,t=0)=T i (z);

[0197]

[0198]

[0199] T1(z=0,t=T0;

[0200] Among them, T V Z represents the surface temperature within the porous medium, in Kelvin (K); Z represents the heat transfer distance, in meters (m); ρ V Density of rock within porous media, in kg / m³ 3 ;λ v C represents the thermal conductivity of the stratum in a porous medium, expressed in W / (m·K); v T represents the specific heat of a porous medium within a stratum, expressed in J / (kg·K); F ρ represents the formation temperature within the fractured medium, in Kelvin (K). F The average surface crude oil density is expressed in kg / m³. 3 ;λF λ is the thermal conductivity of the fractured formation, expressed in W / (m·K); V h represents the thermal conductivity of porous media formations, expressed in W / (m·K). F T represents the thickness of the fractured formation, in meters (m). w The temperature inside the wellbore is expressed in Kelvin (K); ρ f This refers to the fluid density inside the wellbore, expressed in kg / m³. 3 C f λ is the specific heat of the fluid inside the wellbore, expressed in J / (kg·K); t Rt is the thermal conductivity of the fluid inside the wellbore, in W / (m·K); Q is the flow rate of the fluid inside the wellbore, in ms / s; rt w 1 is the wellbore radius in meters; 2 is the operational radius in meters; 3 is the overall thermal conductivity coefficient; 4 is the formation temperature in Kelvin; 5 is the temperature at depth 0 in Kelvin; 6 is the initial surface temperature in Kelvin.

[0201] Optionally, when the computer program is executed by the processor, step (70) includes: fitting the actual temperature well test interpretation curve with the theoretical temperature well test interpretation curve under multiple heat transfer distances; determining the theoretical temperature well test interpretation curve with the highest fitting degree to the actual temperature well test interpretation curve, and using the heat transfer distance corresponding to the determined theoretical temperature well test interpretation curve as the activation depth of the target fractured solution reservoir well.

[0202] The actual temperature well test interpretation curve is fitted with the theoretical temperature well test interpretation curve at different heat transfer distances. The curve with the closest shape to the actual temperature well test interpretation curve is the theoretical temperature well test interpretation curve with the highest fitting degree. The heat transfer distance corresponding to the theoretical temperature well test interpretation curve with the highest fitting degree is used as the activation depth of the oil well in the target fractured solution reservoir.

[0203] Example 5

[0204] In the production development plan for the SHB oilfield, existing well test interpretation methods can retrieve parameters such as reservoir permeability, formation pressure, fracture half-length, and reservoir contamination, but cannot determine the fluid production location and activation depth. The following steps are performed to determine the activation depth of wells in fractured-dissolved reservoirs:

[0205] 1. Obtain temperature well test monitoring data for the target fractured solution reservoir well:

[0206] 2. Process the temperature test monitoring data to obtain the actual temperature test interpretation curve;

[0207] 3. Construct a temperature well test model for the target fractured solution reservoir well, and obtain theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances based on the temperature well test model.

[0208] 4. By comparing and analyzing the interpretation curves of actual temperature well tests with those of theoretical temperature well tests, the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve is determined as the activation depth of the oil well in the target fractured solution reservoir.

[0209] By interpreting temperature data from 9 SHB oilfield wells, the fitting results are as follows: Figures 10(a) to 10(d) The explanation is as follows:

[0210] Table 1

[0211]

[0212] The temperature data interpretation results show that the reservoir within 200m of the temperature measurement point in zone 5 exhibits vertical fluid supply, reflecting good vertical connectivity. Based on this understanding, four infill wells were deployed and improved, achieving an average daily production of 150t / d per well after commissioning. Pressure monitoring data shows no inter-well interference between the newly commissioned wells and existing wells, proving the high accuracy of the calculated depth.

[0213] Those skilled in the art will understand that all or part of the processes in the methods of the above embodiments can be implemented by a computer program instructing related hardware. The computer program can be stored in a non-volatile computer-readable storage medium, and when executed, it can include the processes of the embodiments of the methods described above. Any references to memory, storage, databases, or other media used in the embodiments provided in this application can include at least one of non-volatile and volatile memory. Non-volatile memory can include read-only memory (ROM), magnetic tape, floppy disk, flash memory, or optical storage, etc. Volatile memory can include random access memory (RAM) or external cache memory. By way of illustration and not limitation, RAM can be in various forms, such as static random access memory (SRAM) or dynamic random access memory (DRAM), etc.

[0214] The technical features of the above embodiments can be combined in any way. For the sake of brevity, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this specification.

[0215] While the embodiments disclosed in this invention are as described above, the content is merely for the purpose of facilitating understanding of the invention and is not intended to limit the invention. Any person skilled in the art to which this invention pertains may make any modifications and changes in form and detail of the implementation without departing from the spirit and scope disclosed herein; however, the scope of protection of this invention shall still be determined by the scope defined in the appended claims.

Claims

1. A method for determining the working depth of an oil well in a fractured solution reservoir, characterized in that, include: Acquire temperature well test monitoring data of oil wells in the target fractured solution reservoir; The temperature well test monitoring data is processed to obtain the actual temperature well test interpretation curve; A temperature well test model for the target fractured solution reservoir well is constructed, and theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances are obtained based on the temperature well test model. By comparing and analyzing the actual temperature well test interpretation curve and the theoretical temperature well test interpretation curve, the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve is determined as the activation depth of the target fractured solution reservoir well. The temperature well test model includes the heat transfer equations for porous media, fractured media, and wellbore heat transfer model. The construction of the temperature well test model for the target fractured-dissolved reservoir well, and the acquisition of theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances based on the temperature well test model, includes: establishing the heat transfer equations for porous media, fractured media, and wellbore heat transfer model for the target fractured-dissolved reservoir well, and setting boundary conditions; performing a Laplace transform on the wellbore heat transfer model based on the boundary conditions and solving for temperature solutions at multiple heat transfer distances; converting the temperature solutions in Laplace space to temperature solutions in real space using numerical inversion to obtain the wellbore temperatures corresponding to multiple heat transfer distances; and plotting double logarithmic curves of temperature and temperature derivatives based on the wellbore temperatures corresponding to each heat transfer distance to obtain the theoretical temperature well test interpretation curves corresponding to the heat transfer distances.

2. The method according to claim 1, characterized in that, The temperature well test monitoring data includes the formation temperature corresponding to each acquisition time; the processing of the temperature well test monitoring data to obtain the actual temperature well test interpretation curve includes: The temperature derivative is obtained using the formation temperature at each time point. Based on the formation temperature and the temperature derivative, a double logarithmic curve is plotted to obtain the actual temperature well test interpretation curve.

3. The method according to claim 2, characterized in that, The step of using the formation temperature at each time point to calculate the temperature derivative includes: ； Wherein, △T′ is the temperature derivative, △T is the temperature change of the formation temperature, △t is the time change at the time of data acquisition, and n is the total number of temperature data points calculated in segments. i This represents the number of data points calculated in segments.

4. The method according to claim 1, characterized in that, The heat transfer equation for the porous medium includes: ； The heat transfer equation of the fracture medium includes: ； The wellbore heat transfer model includes: The boundary conditions include: ； ； ； ； ； in, Temperature of the stratum within a porous medium, expressed in Kelvin (K). Z This refers to the heat transfer distance, measured in meters (m). The density of the rock within the porous medium is expressed in kg / m³. is the thermal conductivity of the stratum in a porous medium, expressed in W / (m•K); Specific heat of the strata in porous media, expressed in J / (kg·K); The temperature of the formation within the fractured medium is expressed in Kelvin (K). The average surface crude oil density is expressed in kg / m³. The thermal conductivity of the fractured formation is expressed in W / (m·K). The thermal conductivity of porous media formations is expressed in W / (m·K). The thickness of the fractured strata is expressed in meters (m). Temperature inside the wellbore, in Kelvin (K). This represents the density of the fluid inside the wellbore, expressed in kg / m³. Specific heat of the fluid inside the wellbore, expressed in J / (kg·K); The thermal conductivity of the fluid inside the wellbore is expressed in W / (m·K). This represents the fluid flow rate inside the wellbore, expressed in m³ / s. The radius of the wellbore is in meters (m). r The radius used is in meters (m). U The overall thermal conductivity coefficient; T Formation temperature, in Kelvin (K). T1 Temperature at depth 0, in Kelvin (K). T0 This represents the initial formation temperature, expressed in Kelvin (K).

5. The method according to claim 1, characterized in that, The comparative analysis of the actual temperature well test interpretation curve and the theoretical temperature well test interpretation curve, and the determination of the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve as the activation depth of the target fractured solution reservoir well, includes: The actual temperature well test interpretation curve is fitted with the theoretical temperature well test interpretation curve at multiple heat transfer distances; The theoretical temperature well test interpretation curve with the highest fitting degree to the actual temperature well test interpretation curve is determined, and the heat transfer distance corresponding to the determined theoretical temperature well test interpretation curve is taken as the activation depth of the oil well in the target fractured solution reservoir.

6. A device for determining the working depth of an oil well in a fractured solution reservoir, characterized in that, include: The data acquisition module is used to acquire temperature well test monitoring data of the target fractured solution reservoir well; The actual curve generation module is used to process the temperature well test monitoring data to obtain the actual temperature well test interpretation curve; The theoretical curve generation module is used to construct a temperature well test model for the target fractured solution reservoir well, and obtain theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances based on the temperature well test model. The activation depth calculation module is used to compare and analyze the actual temperature well test interpretation curve and the theoretical temperature well test interpretation curve, and determine the heat transfer distance corresponding to the theoretical temperature well test interpretation curve that best matches the actual temperature well test interpretation curve as the activation depth of the target fractured solution reservoir well. The temperature well test model includes the heat transfer equations for porous media, fractured media, and wellbore heat transfer model. The construction of the temperature well test model for the target fractured-dissolved reservoir well, and the acquisition of theoretical temperature well test interpretation curves corresponding to multiple heat transfer distances based on the temperature well test model, includes: establishing the heat transfer equations for porous media, fractured media, and wellbore heat transfer model for the target fractured-dissolved reservoir well, and setting boundary conditions; performing a Laplace transform on the wellbore heat transfer model based on the boundary conditions and solving for temperature solutions at multiple heat transfer distances; converting the temperature solutions in Laplace space to temperature solutions in real space using numerical inversion to obtain the wellbore temperatures corresponding to multiple heat transfer distances; and plotting double logarithmic curves of temperature and temperature derivatives based on the wellbore temperatures corresponding to each heat transfer distance to obtain the theoretical temperature well test interpretation curves corresponding to the heat transfer distances.

7. The apparatus according to claim 6, characterized in that, The temperature well test monitoring data includes the formation temperature corresponding to each acquisition time; the actual curve generation module uses the formation temperature corresponding to each time to calculate the temperature derivative; based on the formation temperature and the temperature derivative, a double logarithmic curve is plotted to obtain the actual temperature well test interpretation curve.

8. A computer device comprising a memory and a processor, wherein the memory stores a computer program, characterized in that, When the processor executes the computer program, it implements the steps of the method according to any one of claims 1 to 5.

9. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by a processor, it implements the steps of the method according to any one of claims 1 to 5.

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