Method, device, equipment and storage medium for determining wellbore trajectory in oil reservoir
By analyzing the distribution characteristics of hard formations in soft formations, determining the reservoir type and designing suitable wellbore trajectories, the problems of prone to collapse of soft formation drilling and low oil and gas output are solved, and cost reduction and recovery rate improvement are achieved.
Patent Information
- Application Number
- CN202110088538.2
- Authority / Receiving Office
- CN · China
- Patent Type
- Patents(China)
- Current Assignee / Owner
- Filing Date
- 2021-01-22
- Publication Date
- 2025-02-25
- Estimated Expiration
- 2041-01-22
AI Technical Summary
Collapse is prone to occur during drilling in soft formations, resulting in high drilling costs and low oil and gas output when using large slope wells.
By analyzing the distribution characteristics of the hard formation in the reservoir, determining the reservoir type, and determining the applicable wellbore trajectory based on the type, so as to reasonably deploy the well position and avoid collapse.
It reduces the cost during reservoir exploration, improves the exploration success rate, and improves the oil and gas recovery rate.
Smart Images
Figure CN114810047B_ABST
Abstract
Description
Technical Field
[0001] The present application relates to the field of oil reservoir exploration, and in particular to a method, device, equipment and storage medium for determining a wellbore trajectory in an oil reservoir. Background Art
[0002] With the development of drilling technology, especially the application of "horizontal well + volume fracturing" technology to drilling, the drilling of unconventional oil and gas such as shale oil and gas has entered a stage of vigorous development.
[0003] Shale oil and gas reservoirs are mainly contained in soft formations, which refer to loose and soft formations such as soil and sand layers. Due to the characteristics of soft formations, collapse is prone to occur during the drilling process of soft formations.
[0004] In the related technologies, horizontal wells and high-angle wells are mostly used for drilling in soft formations such as shale oil and gas. Among them, horizontal wells are applied to the drilling process of soft formations. Since horizontal wells are mostly drilled along high-quality reservoirs, oil and gas production can be effectively increased. However, due to the characteristics of soft formations, collapse is very likely to occur during the drilling of horizontal wells, resulting in high drilling costs. If high-angle wells are used to drill soft formations, the oil and gas production will be low. Summary of the invention
[0005] The embodiment of the present application provides a method, device, equipment and storage medium for determining a wellbore trajectory in an oil reservoir, which can reduce the cost in the oil reservoir exploration process. The technical solution is as follows:
[0006] In one aspect, a method for determining a wellbore trajectory in an oil reservoir is provided, the method comprising:
[0007] Acquire formation characteristic parameters corresponding to the target reservoir, wherein the formation characteristic parameters at least include the thickness of the hard formation contained in the target reservoir;
[0008] Determining a target reservoir type corresponding to the target reservoir according to the formation characteristic parameters, wherein the reservoir type indicates a distribution characteristic of the hard formation in the target reservoir;
[0009] According to the target reservoir type, a target wellbore trajectory corresponding to the target reservoir is determined, and the target wellbore trajectory is used to indicate the deployment position of the wellbore in the target reservoir, wherein the distribution characteristics of different hard formations correspond to different target wellbore trajectories.
[0010] In another aspect, a device for determining a wellbore trajectory in an oil reservoir is provided, the device comprising:
[0011] An acquisition module, used for acquiring formation characteristic parameters corresponding to a target reservoir, wherein the formation characteristic parameters at least include the thickness of a hard formation contained in the target reservoir;
[0012] A first determination module is used to determine a target reservoir type corresponding to the target reservoir according to the formation characteristic parameters, wherein the reservoir type indicates a distribution characteristic of the hard formation in the target reservoir;
[0013] The second determination module is used to determine the target wellbore trajectory corresponding to the target reservoir according to the target reservoir type, and the target wellbore trajectory is used to indicate the deployment position of the wellbore in the target reservoir, wherein the distribution characteristics of different hard formations correspond to different target wellbore trajectories.
[0014] On the other hand, a computer device is provided, which includes a processor and a memory, wherein the memory stores at least one instruction, and the instruction is loaded and executed by the processor to implement the method for determining a wellbore trajectory in an oil reservoir as described in the above aspects.
[0015] On the other hand, a computer-readable storage medium is provided, in which at least one instruction is stored, and the at least one instruction is loaded and executed by a processor to implement the method for determining a wellbore trajectory in an oil reservoir as described in the above aspects.
[0016] On the other hand, according to one aspect of the present application, a computer program product or computer program is provided, the computer program product or computer program includes computer instructions, the computer instructions are stored in a computer-readable storage medium. A processor of a computer device reads the computer instructions from the computer-readable storage medium, and the processor executes the computer instructions, so that the computer device executes the method for determining a wellbore trajectory in an oil reservoir provided in various optional implementations of the above aspects.
[0017] The beneficial effects brought by the technical solution provided by the embodiment of the present application include at least:
[0018] By analyzing the distribution characteristics of hard formations in the reservoir, the reservoir type corresponding to the reservoir is determined, so that in the actual exploration process, the wellbore trajectory suitable for the reservoir can be determined according to the reservoir type, so that suitable well locations can be deployed for reservoirs with different hard formation distribution characteristics to avoid collapse during the exploration process, thereby reducing the cost of reservoir exploration and improving the success rate of reservoir exploration. BRIEF DESCRIPTION OF THE DRAWINGS
[0019] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.
[0020] Figure 1A flow chart showing a method for determining a wellbore trajectory in an oil reservoir provided by an exemplary embodiment of the present application is shown;
[0021] Figure 2 A flow chart showing a method for determining a wellbore trajectory in an oil reservoir provided by another exemplary embodiment of the present application;
[0022] Figure 3 A schematic diagram of a reservoir corresponding to a type without interlayers shown in an exemplary embodiment of the present application is shown;
[0023] Figure 4 A schematic diagram of a reservoir corresponding to a thin barrier type shown in an exemplary embodiment of the present application is shown;
[0024] Figure 5 A schematic diagram of a reservoir corresponding to a thick barrier type shown in an exemplary embodiment of the present application is shown;
[0025] Figure 6 A schematic diagram of a water tank model shown in an exemplary embodiment of the present application is shown;
[0026] Figure 7 A schematic diagram of a horizontal model shown in an exemplary embodiment of the present application is shown;
[0027] Figure 8 A schematic diagram of a wave model shown in an exemplary embodiment of the present application is shown;
[0028] Fig. 9 A structural block diagram of a device for determining a wellbore trajectory in an oil reservoir provided by an exemplary embodiment of the present application is shown;
[0029] Fig.10 A schematic diagram of the structure of a computer device provided by an exemplary embodiment of the present application is shown. DETAILED DESCRIPTION
[0030] Exemplary embodiments will be described in detail herein, examples of which are shown in the accompanying drawings. When the following description refers to the drawings, the same numbers in different drawings represent the same or similar elements unless otherwise indicated. The implementations described in the following exemplary embodiments do not represent all implementations consistent with the present application. Instead, they are merely examples of devices and methods consistent with some aspects of the present application as detailed in the appended claims.
[0031] It should be noted that the method for determining the wellbore trajectory in the oil reservoir provided in each embodiment of the present application is applied to a reservoir whose formation characteristics are soft formations, and the soft formations may be mixed with hard formations. By analyzing the distribution characteristics of the hard formations in the soft formations, for example, the thickness of the hard formations contained in the soft formations, the wellbore trajectory applicable to the reservoir is determined.
[0032] Please refer to Figure 1 , which shows a flow chart of a method for determining a wellbore trajectory in an oil reservoir provided by an exemplary embodiment of the present application. The present application embodiment is described by taking the method applied to a computer device as an example, and the method includes:
[0033] Step 101, obtaining formation characteristic parameters corresponding to a target reservoir, where the formation characteristic parameters at least include the thickness of a hard formation contained in the target reservoir.
[0034] The embodiment of the present application provides a method for determining a borehole trajectory for the exploration of oil and gas reservoirs such as shale oil and gas contained in soft formations. Correspondingly, the target reservoir in the embodiment of the present application is a soft formation. Optionally, due to the complexity of the geological conditions, some hard formations may be mixed in the soft formations. Among them, the soft formations are composed of rocks with lower hardness, which are easy to collapse during drilling, mainly including shale and mudstone, etc.; the hard formations are composed of rocks with higher hardness, which are not easy to collapse during drilling, mainly including sandstone and carbonate rock, etc.
[0035] The formation characteristic parameters may include whether the target reservoir contains a hard formation and the thickness of the hard formation. Optionally, the formation characteristic parameters may also include the thickness of the target reservoir. Optionally, the formation characteristic parameters may also include the formation pressure corresponding to the target reservoir, etc. The embodiments of the present application do not limit the specific formation characteristic parameters.
[0036] In one possible implementation, when drilling for a target reservoir, it is first necessary to measure and obtain the formation characteristic parameters corresponding to the target reservoir. In the embodiment of the present application, the thickness of each hard formation distributed in the target reservoir is mainly measured to determine the reservoir type to which the target reservoir belongs.
[0037] Step 102: determining a target reservoir type corresponding to the target reservoir according to the formation characteristic parameters, where the reservoir type indicates the distribution characteristics of the hard formation in the target reservoir.
[0038] Among them, the reservoir type refers to the distribution characteristics of the hard strata in the target reservoir, for example, the target reservoir is entirely soft strata with no intermixed hard strata; or only a small number of hard strata are intermixed; or there are hard strata of a certain thickness evenly distributed in the target reservoir; or there are relatively thick hard strata distributed in the target reservoir.
[0039] In a possible implementation, the target reservoir type corresponding to the target reservoir is determined by analyzing the thickness and distribution position of the hard formation in the reservoir.
[0040] Among them, the target reservoir type can be no interlayer (does not contain hard formations, or contains hard formations but the thickness of the hard formations is extremely thin), thick interlayer (contains hard formations and the thickness of the hard formations is relatively thick), thin interlayer (contains hard formations and the thickness of the hard formations is relatively thin), and the target reservoir type can also be divided more finely according to the thickness of the hard formation. The embodiments of the present application do not constitute a limitation on the target reservoir type.
[0041] Step 103, determining a target wellbore trajectory corresponding to the target reservoir according to the target reservoir type, where the target wellbore trajectory is used to indicate the deployment position of the wellbore in the target reservoir.
[0042] In the related art, horizontal wells are usually used for the exploration process of soft formations. However, due to the characteristics of soft formations, if horizontal wells are used, collapse is likely to occur during the drilling process of the soft formation. In order to avoid collapse and to successfully drill the reservoir, it is usually necessary to significantly increase the drilling cost. In the embodiment of the present application, in order to reduce the drilling cost of soft formations and to solve the problem of collapse during the drilling process of soft formations, the distribution characteristics of hard formations in the target reservoir are analyzed, and the target wellbore trajectory corresponding to the target reservoir is determined based on the distribution characteristics, so that the wellbore trajectory can conform to the reservoir type of the target reservoir.
[0043] The distribution characteristics of different hard formations correspond to different target wellbore trajectories. That is, in the embodiment of the present application, the target wellbore trajectory applicable to the target reservoir is determined by the distribution characteristics of the hard formations in the soft formations.
[0044] In an illustrative example, if the target reservoir is of a non-interlayer type, that is, the target reservoir does not contain hard formations, or contains fewer intercalated hard formations, a wellbore trajectory with a water trough-shaped cross-section can be used. The wellbore trajectory has a downward section, a horizontal section, and an upward section, wherein the downward section and the upward section have a certain slope to prevent collapse, and the horizontal section is located in a hard formation adjacent to the target reservoir, which can further prevent collapse.
[0045] To sum up, in the embodiments of the present application, the reservoir type corresponding to the reservoir is determined by analyzing the distribution characteristics of the hard formations in the reservoir, so that in the actual exploration process, the wellbore trajectory suitable for the reservoir can be determined according to the reservoir type, so that suitable well locations can be deployed for reservoirs with different hard formation distribution characteristics to avoid collapse during the exploration process, thereby reducing the cost of the reservoir exploration process and improving the success rate of the reservoir exploration process.
[0046] The embodiments of the present application classify soft formations into three types according to the distribution characteristics of hard formations in soft formations, namely, a non-interlayer type, a thick interlayer type, and a thin interlayer type. Correspondingly, suitable wellbore trajectory models are designed for these three types, respectively, wherein the non-interlayer type is suitable for a water tank model, the thick interlayer type is suitable for a horizontal model, and the thin interlayer type is suitable for a wave model. The following embodiments focus on describing several soft formation types and their applicable wellbore trajectory models.
[0047] In an illustrative example, Figure 2 As shown, it shows a flow chart of a method for determining a wellbore trajectory in an oil reservoir provided by another exemplary embodiment of the present application. The present application embodiment takes the method applied to a computer device as an example to illustrate, and the method includes:
[0048] Step 201, obtaining formation characteristic parameters corresponding to the target reservoir, where the formation characteristic parameters at least include the thickness of the hard formation contained in the target reservoir.
[0049] The implementation of step 201 may refer to the above embodiment, and this embodiment will not be described in detail here.
[0050] Step 202: If the thickness of the hard formation included in the target reservoir is less than a first thickness threshold, the non-interlayer type is determined as the target reservoir type corresponding to the target reservoir.
[0051] In one possible implementation, the type of the target reservoir is divided according to the thickness of the hard strata contained in the target reservoir, wherein the first thickness threshold is determined by engineers according to the actual situation of the target reservoir. For example, the first thickness threshold is 0.2 m. When the thickness of the hard strata mixed in the target reservoir is less than 0.2 m, it means that the target reservoir is composed of soft strata, or a small number of hard strata are mixed in the soft strata, and the thickness of the hard strata is thin and can be ignored. Correspondingly, the reservoir type corresponding to the target reservoir is a non-interlayer type.
[0052] like Figure 3 As shown, it shows a schematic diagram of a reservoir corresponding to a non-interlayer type shown in an exemplary embodiment of the present application. Among them, the target reservoirs are all soft formations, and there is no hard formation.
[0053] In an illustrative example, if it is measured that the target reservoir does not contain any hard strata, it is determined that the target reservoir is of a non-interlayer type; if the first thickness threshold is 0.2m, and it is measured that the target reservoir contains a hard stratum, and the thickness of the hard stratum is 0.1m, correspondingly, it is determined that the target reservoir is of a non-interlayer type.
[0054] Step 203: If the thickness of the hard formation included in the target reservoir is greater than the first thickness threshold and less than the second thickness threshold, the thin interlayer type is determined as the target reservoir type corresponding to the target reservoir.
[0055] In a possible implementation, if the target reservoir is interspersed with hard strata, and the thickness of the hard strata is between the first thickness threshold and the second thickness threshold, that is, the soft strata are interspersed with thinner hard strata, correspondingly, this type of target reservoir is determined as a thin barrier type.
[0056] The second thickness threshold may be set by engineers themselves, for example, the second thickness threshold is 1 m.
[0057] like Figure 4 As shown, it shows a schematic diagram of a reservoir corresponding to a thin barrier type shown in an exemplary embodiment of the present application. A relatively thin hard layer is interspersed in the soft layer (target reservoir).
[0058] In an illustrative example, if the first thickness threshold is 0.2m, the second thickness threshold is 1m, there are 3 hard strata distributed in the target reservoir, the thickness of the first hard strata is 0.3m, the thickness of the second hard strata is 0.4m, and the thickness of the third hard strata is 0.7m. It can be seen that the thickness of each hard stratum in the target reservoir is between the first thickness threshold and the second thickness threshold. Correspondingly, it is determined that the reservoir type corresponding to the target reservoir is a thin interlayer type.
[0059] Step 204: If the thickness of the hard formation included in the target reservoir is greater than the second thickness threshold, the thick barrier layer type is determined as the target reservoir type corresponding to the target reservoir.
[0060] In a possible implementation, if there is at least one hard formation in the target reservoir with a relatively large thickness and greater than a second thickness threshold, it is correspondingly determined that the target reservoir belongs to the thick barrier type.
[0061] In an illustrative example, if the second thickness threshold is 1m, the target reservoir contains 3 hard strata, the thickness of the first hard stratum is 0.5m, the thickness of the second hard stratum is 2m, and the thickness of the third hard stratum is 0.2m. It can be seen that the thickness of the second hard stratum is greater than the second thickness threshold, and it is determined that there is a hard stratum in the target reservoir with a thickness greater than the second thickness threshold, and correspondingly, it is determined that the target reservoir belongs to the thick barrier type.
[0062] like Figure 5 As shown, it shows a schematic diagram of a reservoir corresponding to a thick barrier type shown in an exemplary embodiment of the present application, wherein a hard layer with a thickness of H is interspersed in the soft layer (target reservoir), wherein H is greater than a second thickness threshold.
[0063] Step 205, determining a target wellbore trajectory model corresponding to the target reservoir according to the target reservoir type, wherein different reservoir types correspond to different wellbore trajectory models, and the target wellbore trajectory model is a trajectory shape corresponding to the target wellbore trajectory in the target reservoir.
[0064] In the embodiment of the present application, different wellbore trajectory models are designed for different reservoir types, and the wellbore trajectory model is used to indicate the trajectory shape corresponding to the wellbore trajectory in the reservoir.
[0065] Among them, the wellbore trajectory model includes three types: the flume model, the horizontal model and the wave model. The flume model indicates that the shape of the wellbore trajectory in the reservoir is like the cross section of a flume; the horizontal model indicates that the shape of the wellbore trajectory in the reservoir is approximately horizontal; and the wave model indicates that the shape of the wellbore trajectory in the reservoir is similar to a wave.
[0066] The process of determining the target wellbore trajectory model according to the target reservoir type may include the following steps:
[0067] First, if the target reservoir type is a non-interlayer type, the water tank model is determined as the target wellbore trajectory model corresponding to the target reservoir.
[0068] The flume model includes a first downlink section, a first horizontal section and a first uplink section, wherein the first downlink section is connected to the first horizontal section, and the first horizontal section is connected to the first uplink section. The uplink section and the downlink section have a certain slope, which can prevent collapse during drilling, and can also contact the oil and gas stored in the soft formation over a large area, which is beneficial to oil and gas production, thereby improving the oil and gas recovery rate; the bottom horizontal section passes through the hard formation (the hard formation is the bottom layer adjacent to the target reservoir) to further prevent collapse, and after perforating the bottom horizontal section, the hard formation can be shot through to fracture the oil and gas stored in the soft formation, which is beneficial to oil and gas production and improves the oil and gas recovery rate.
[0069] For the target reservoir of the non-interlayer type, since most of the reservoir is soft formation, collapse is very likely to occur if horizontal wells are used during drilling. Therefore, in order to prevent collapse, based on the characteristics of the above-mentioned flume model, the downward and upward sections in the flume model have a certain slope, and the horizontal section is also located in the hard formation, both of which can prevent collapse. For the target reservoir of the non-interlayer type, the flume model is determined as the target wellbore trajectory model applicable to it.
[0070] like Figure 6As shown, it shows a schematic diagram of a flume model shown in an exemplary embodiment of the present application. Among them, the thickness of the target reservoir is H, and it is a non-interlayer type, that is, there is no hard formation within the thickness of H, and the target reservoir is adjacent to the hard formation. The flume model 601 includes a downlink section 602, a horizontal section 603 and an uplink section 604. The downlink section 602 and the uplink section 604 are located in the soft formation, and the horizontal section 603 is located in the hard formation; and the angle between the downlink section 602 and the plumb line is the well inclination angle θ1 of the downlink section 602, and the angle between the uplink section 604 and the plumb line is the well inclination angle θ2 of the uplink section 604; the length of the horizontal section 603 is L2, and the length of the flume model 601 in the horizontal direction is L1.
[0071] Optionally, closing and pressurizing the upward segment of the wellbore trajectory in the water tank model can increase the formation pressure corresponding to the target reservoir, thereby promoting the migration of oil and gas contained in the low-pressure layer of the soft formation to the downward segment and horizontal segment, which is beneficial to oil and gas production and improves the oil and gas recovery rate. Therefore, the water tank model can also be applied to reservoirs in the low-pressure layer.
[0072] Optionally, since the flume model has a downward section and an upward section, the downward section of the flume model can be closed and pressurized accordingly, and the formation pressure corresponding to the target reservoir can be increased, thereby promoting the migration of oil and gas contained in the low-pressure layer of the soft formation to the upward section and horizontal section, which can also achieve the purpose of improving the oil and gas recovery rate.
[0073] Second, if the target reservoir type is a thick barrier type, the horizontal model is determined as the target wellbore trajectory model corresponding to the target reservoir.
[0074] Among them, the horizontal model includes a second downward section and a second horizontal section, the second downward section and the second horizontal section are connected, the second downward section is located in a soft formation, and the second horizontal section is located in a hard formation. Since the second downward section has a certain slope, collapse can be prevented; and since the second horizontal section is located in a thicker hard formation, collapse can be further prevented, and it is suitable for geological guidance and drilling.
[0075] For reservoirs with thick interlayer type, since there are thicker hard strata in the reservoirs and the hard strata can divide the reservoirs into unconnected soft strata, in order to prevent collapse from occurring during the drilling process of the soft strata and to fully improve the recovery rate of oil and gas in the soft strata, in a possible implementation mode, the horizontal model is determined as the target wellbore trajectory model applicable to the thick interlayer type reservoirs.
[0076] like Figure 7As shown, it shows a schematic diagram of a horizontal model shown in an exemplary embodiment of the present application. Among them, the thickness of the target reservoir is H, and the target reservoir is interspersed with thicker hard formations. The hard formation divides the target reservoir into two discontinuous soft formations. The target reservoir is suitable for the horizontal model. The horizontal model 701 includes a downlink section 702 and a horizontal section 703. The downlink section 702 is located in the soft formation, and the horizontal section 703 is located in the hard formation. The angle between the downlink section 702 and the plumb line is the well inclination angle θ corresponding to the downlink section 702. The length of the horizontal section of the horizontal model 701 on the ground is L.
[0077] Depend on Figure 7 It can be seen that since the hard formation is located in the middle of the soft formation, after perforating in the horizontal section indicated by the horizontal model, the hard formation can be penetrated, thereby contacting the oil and gas contained in the soft formations above and below the hard formation over a large area, which is beneficial to oil and gas exploitation and improves the oil and gas recovery rate.
[0078] 3. If the target reservoir type is a thin-layer type, the wave model is determined as the target wellbore trajectory model corresponding to the target reservoir.
[0079] The wave-shaped model includes at least one third downward segment and at least one second upward segment, and the third downward segment is connected to the second upward segment; and the downward segment and the upward segment have a certain slope to prevent collapse.
[0080] For reservoirs with a thin interlayer type, since there are multiple thin hard strata distributed in the reservoir, and the hard strata divide the reservoir into multiple unconnected soft strata, in order to avoid the collapse phenomenon that is easy to occur when drilling in the soft strata, and at the same time connect the oil and gas contained in the separated soft strata, in a possible implementation method, the wave model is determined as the target wellbore trajectory model corresponding to the thin interlayer type.
[0081] like Figure 8 As shown, it shows a schematic diagram of a wave model shown in an exemplary embodiment of the present application. Among them, the target reservoir with a thickness of H includes multiple hard strata, and the hard strata divide the oil and gas contained in the soft strata into multiple sets of oil and gas flow units that are not connected to each other. The target reservoir is suitable for the wave model 801, and the wave model 801 includes multiple groups of downlink segments 802 and uplink segments 803. The downlink segments 802 and the uplink segments 803 can pass through the hard strata and the soft strata, and the angle between the downlink segment 802 and the plumb line is θ1, and the angle between the uplink segment 803 and the plumb line is θ2.
[0082] Depend on Figure 8It can be seen that the wave model is mainly composed of multiple groups of descending sections and ascending sections. Due to the existence of multiple hard formations in the reservoir, the oil and gas stored in the soft formations are divided into multiple sets of unconnected oil and gas flow units. By using the wave model, on the one hand, the inclination of the wellbore trajectory of the descending section and the ascending section can prevent collapse during drilling, and can drill through the interlayer (i.e., hard formation) to connect the oil and gas stored in the divided soft formations. It can also contact the oil and gas stored in the soft formations over a large area, which is beneficial to oil and gas exploitation and further improves the oil and gas recovery rate.
[0083] In summary, in this embodiment, suitable wellbore trajectory models are designed for different types of reservoirs, wherein the type without interlayer is suitable for the flume model, the type with thin interlayer is suitable for the wave model, and the type with thick interlayer is suitable for the horizontal model.
[0084] Optionally, based on the advantages of different wellbore trajectory models, the above-mentioned wellbore trajectory model can also be applied to other types of reservoirs. For example, during the application of the water tank model, the formation pressure can be increased by closing and pressurizing the downlink section, and the oil and gas stored in the low-pressure layer of the soft formation can be pushed to migrate to the downlink section and the horizontal section, which is beneficial to oil and gas production. Correspondingly, the low-pressure layer can also be applied to the water tank model. Engineers can select a suitable wellbore trajectory model according to the reservoir characteristics and the purpose to be achieved, and are not limited to the applicable relationship shown in the above embodiment.
[0085] In another possible implementation, when it is determined that the formation pressure of the soft formation is lower than a preset pressure threshold, and there is no hard formation exceeding the first thickness threshold in the soft formation, the water tank model is also applicable to such low-pressure layers, wherein the preset pressure threshold may be 0.9 Mpa / 100 m.
[0086] Step 206, determining a target wellbore trajectory corresponding to the target reservoir according to the target wellbore trajectory model and formation characteristic parameters.
[0087] In one possible implementation, after determining the target wellbore trajectory model applicable to the target reservoir, if the target wellbore trajectory model needs to be applied to the target reservoir, the actual parameters of each part of the target wellbore trajectory model need to be calculated based on the actual formation characteristic parameters corresponding to the target reservoir, so as to obtain the target wellbore trajectory corresponding to the target reservoir.
[0088] In an exemplary example, according to the target wellbore trajectory model and formation characteristic parameters, a method for determining the target wellbore trajectory may include the following steps:
[0089] 1. If the target wellbore trajectory model is a flume model, the length of the first horizontal segment of the target wellbore trajectory corresponding to the target reservoir is calculated according to the thickness of the target reservoir and the first control radius. The length of the first horizontal segment is the actual length of the first horizontal segment in the flume model.
[0090] For the scenario where the target reservoir is of the non-interlayer type and the target wellbore trajectory model is a water tank model, in actual application, it is necessary to predetermine the length of the horizontal section, the well inclination angle of the downlink section, and the well inclination angle of the uplink section in the water tank model in the actual application scenario, so as to determine the actual wellbore trajectory corresponding to the target reservoir based on these parameters.
[0091] Since the downlink section and the uplink section in the flume model are located in soft formations, in order to avoid collapse during drilling, the well inclination angles corresponding to the downlink section and the uplink section need to meet the condition of not being prone to collapse. For example, the well inclination angle of the downlink section can be 45 degrees, and the well inclination angle of the uplink section can be 135 degrees. The embodiments of the present application do not limit the specific values of the well inclination angles corresponding to the downlink section and the uplink section, respectively, and can be adaptively adjusted according to the actual reservoir.
[0092] Depend on Figure 6 It can be seen that two horizontal lengths need to be determined in the flume model, one is the actual length L1 of the horizontal section set in the hard formation, and the other is the upper length L2 of the flume model in the soft formation. In actual application, the lengths of L1 and L2 are both related to the thickness of the target reservoir and the control radius. Therefore, in a possible implementation, the thickness of the target reservoir and the first control radius applicable to the target reservoir are measured to calculate the first horizontal section length of the target wellbore trajectory corresponding to the target reservoir.
[0093] The control radius is related to the permeability of the target reservoir. The higher the permeability of the target reservoir, the larger the corresponding control radius. Conversely, the lower the permeability of the target reservoir, the smaller the corresponding control radius. The value of the control radius can be 500m.
[0094] In an exemplary example, taking the well inclination angle of the downlink segment as 45 degrees and the well inclination angle of the uplink segment as 135 degrees, the actual parameter relationship of the flume model can be as follows:
[0095] L1=2×R1+H
[0096] L2=2×R1-H
[0097] θ1=45°
[0098] θ2=135°
[0099] Wherein, L1 represents the upper length of the flume model in the reservoir (i.e., the length of all wellbore trajectories in the reservoir in the horizontal direction), L2 represents the lower length of the flume model in the reservoir (i.e., the actual length of the horizontal section in the flume model), R1 represents the average radius of oil and gas flowing from the soft formation to the wellbore in the horizontal direction (i.e., the first control radius), H represents the thickness of the soft formation (i.e., the thickness of the target reservoir), θ1 represents the angle between the wellbore trajectory and the vertical line when entering the lower part of the soft formation from the upper part of the soft formation (i.e., the well inclination angle corresponding to the downward section in the flume model); θ2 represents the angle between the wellbore trajectory and the vertical line when entering the upper part of the soft formation from the lower part of the soft formation (i.e., the well inclination angle corresponding to the upward section in the flume model).
[0100] Optionally, if the target wellbore trajectory model is a water tank model, the corresponding formation characteristic parameters that need to be measured include: the thickness of the target reservoir and the first control radius corresponding to the target reservoir.
[0101] 2. If the target wellbore trajectory model is a horizontal model, the second horizontal segment length of the target wellbore trajectory corresponding to the target reservoir is calculated according to the second control radius, and the second horizontal segment length is the actual length of the second horizontal segment in the horizontal model.
[0102] For the scenario where the target reservoir is a thick interlayer type and the target wellbore trajectory model is a horizontal model, in the actual application scenario, it is necessary to predetermine the length of the horizontal section and the well inclination angle of the downlink section in the horizontal model in the actual application, so as to determine the actual wellbore trajectory corresponding to the target reservoir based on these parameters.
[0103] Since the downlink section in the horizontal model is located in a soft formation, in order to avoid collapse during drilling, the downlink section's well inclination angle needs to meet the condition of not being prone to collapse. The downlink section's well inclination angle should be an acute angle, for example, the downlink section's well inclination angle is 45 degrees. Engineers can adaptively adjust the downlink section's well inclination angle based on the actual reservoir.
[0104] Depend on Figure 7 It can be seen that the horizontal model includes a second horizontal segment located in the hard formation, and it is necessary to determine the length of the second horizontal segment in actual application, that is, the length of the second horizontal segment corresponding to the target wellbore trajectory. In actual application, the actual length of L is related to the control radius corresponding to the target reservoir. Therefore, in one possible implementation, the length of the second horizontal segment of the target wellbore trajectory corresponding to the target reservoir is calculated by obtaining the second control radius applicable to the target reservoir.
[0105] The second control radius is determined by the permeability corresponding to the target reservoir. The higher the permeability corresponding to the target reservoir, the larger the corresponding second control radius. Conversely, the smaller the second control radius.
[0106] In an illustrative example, the relationship between the parameters in the level model can be expressed as:
[0107] L3=4×R2
[0108] 45°≤θ3<90°
[0109] Among them, L3 represents the horizontal section length of the wellbore trajectory in the reservoir (i.e., the horizontal section length in the hard formation in the flume model), R2 represents the average radius of oil and gas flowing from the soft formation to the wellbore in the horizontal direction (i.e., the second control radius), and θ3 represents the angle between the wellbore trajectory in the soft formation and the vertical line of the lead (i.e., the well inclination angle corresponding to the downward section).
[0110] 3. If the target wellbore trajectory model is a wave model, the third horizontal length of the target wellbore trajectory corresponding to the target reservoir is calculated according to the third control radius, and the well inclination angle of the target wellbore trajectory corresponding to the target reservoir is calculated according to the third control radius and the thickness of the target reservoir, and the well inclination angle includes the well inclination angle of the third downward segment and the well inclination angle of the second upward segment in the wave model.
[0111] For the scenario where the target reservoir is a thin-layer type and the target wellbore trajectory model is a wave model, in actual application, it is necessary to predetermine the horizontal length of the wave model and the well inclination angles of each group of downlink and uplink segments, so as to determine the actual wellbore trajectory corresponding to the target reservoir based on these parameters.
[0112] Since the downlink and uplink sections in the wave model pass through soft formations, in order to avoid collapse during drilling, the well inclination angles corresponding to the downlink and uplink sections need to meet the condition of no collapse. For example, the well inclination angle of the downlink section can be 50 degrees, and the well inclination angle of the uplink section can be 130 degrees. This embodiment does not limit the specific value of the well inclination angle, and engineers can adaptively adjust the well inclination angle according to actual needs.
[0113] In a possible implementation, by acquiring a third control radius applicable to the target reservoir, a third horizontal length of the wellbore trajectory in the target reservoir in the horizontal direction is determined according to the third control radius, that is, Figure 8 L in the target wellbore trajectory, and according to the thickness of the target reservoir and the third control radius, the well inclination angles in the downlink and uplink segments of the target wellbore trajectory (i.e. Figure 8 θ1 and θ2 in θ).
[0114] In an illustrative example, the relationship between the various parameters in the wave model can be expressed as:
[0115] L4=4×R3
[0116] θ4=arctan(R3 / H)
[0117] θ5=180°-arctan(R3 / H)
[0118] Wherein, L4 represents the third horizontal length of the reservoir in the horizontal direction, R3 represents the average radius of oil and gas flowing from the soft formation to the wellbore in the horizontal direction (i.e., the third control radius), H represents the thickness of the target reservoir, θ4 represents the angle between the wellbore trajectory and the vertical line when entering the lower part of the target reservoir from the upper part of the target reservoir (i.e., the well inclination angle corresponding to the downward segment in the wave model), θ5 represents the angle between the wellbore trajectory and the vertical line when entering the upper part of the target reservoir from the lower part of the target reservoir (i.e., the well inclination angle corresponding to the upward segment in the wave model); arctan(x) represents the inverse tangent function.
[0119] In summary, in one possible implementation, after the target wellbore trajectory model corresponding to the target reservoir is determined, the various parameters of each target wellbore trajectory model in the actual application process can be calculated according to the above-mentioned formulas for calculating the wellbore trajectory, such as the well inclination angle and the horizontal section length, etc., and the actual wellbore trajectory in the target reservoir can be determined based on the calculated parameters.
[0120] In this embodiment, suitable wellbore trajectory models are specially set for different types of reservoirs, so that the various parameters of the wellbore trajectory in actual application can be determined according to the wellbore trajectory model, thereby providing a basis for well site deployment, improving the success rate of the later exploration process, and further improving the oil and gas recovery rate.
[0121] In an illustrative example, through geological evaluation, the stratigraphic characteristics of the target reservoir are obtained as follows: the high-quality shale oil layers are mainly distributed in the a layer and b layer of the third sub-member of the first section, with a depth of 2383m and 2414m, and the lithology is mainly black shale, which is a soft formation and easy to collapse. Among them, there is an interlayer at a depth of 2400m to 2402m, with a thickness of 2m, and the lithology is mud limestone, which is a hard formation with stable distribution and long extension. Therefore, the reservoir type of the target reservoir is a thick interlayer type; according to the relationship between the reservoir type and the applicable wellbore trajectory model, the target reservoir is determined. The target reservoir is suitable for the horizontal model; the control radius of a single shale oil well corresponding to the target reservoir is generally 300m. The horizontal section length L corresponding to the wellbore trajectory is calculated to be 1200m, and the well inclination angle θ is 40 degrees. Since the horizontal section corresponding to the wellbore trajectory is located in the hard formation, the horizontal section of the wellbore trajectory is drilled along the middle of the marl interlayer at a depth of 2401m, with a drilling length of 1200m. After the drilling is completed, the horizontal section is perforated and sand is added in stages for fracturing. The upward fracturing height is controlled within 18m, and the downward fracturing height is controlled within 13m.
[0122] Since the wellbore trajectory is drilled through a 2m thick marl hard formation, the wellbore can be kept stable and not prone to collapse. It can be geologically guided, which is conducive to the formation of fractures in the soft formations above and below the marl interlayer after sand fracturing, which is conducive to the oil and gas stored in the soft formations flowing into the wellbore through the fractures, thereby improving the oil and gas recovery rate.
[0123] Please refer to Fig. 9 , which shows a structural block diagram of a device for determining a wellbore trajectory in an oil reservoir provided by an exemplary embodiment of the present application, the device comprising:
[0124] An acquisition module 901 is used to acquire formation characteristic parameters corresponding to a target reservoir, wherein the formation characteristic parameters at least include the thickness of a hard formation contained in the target reservoir;
[0125] A first determination module 902 is used to determine a target reservoir type corresponding to the target reservoir according to the formation characteristic parameters, wherein the reservoir type indicates a distribution characteristic of the hard formation in the target reservoir;
[0126] The second determination module 903 is used to determine the target wellbore trajectory corresponding to the target reservoir according to the target reservoir type, and the target wellbore trajectory is used to indicate the deployment position of the wellbore in the target reservoir, wherein the distribution characteristics of different hard formations correspond to different target wellbore trajectories.
[0127] Optionally, the second determining module 903 includes:
[0128] A first determination unit is used to determine a target wellbore trajectory model corresponding to the target reservoir according to the target reservoir type, wherein different reservoir types correspond to different wellbore trajectory models, and the target wellbore trajectory model is a trajectory shape corresponding to the target wellbore trajectory in the target reservoir;
[0129] The second determination unit is used to determine the target wellbore trajectory corresponding to the target reservoir according to the target wellbore trajectory model and the formation characteristic parameters.
[0130] Optionally, the reservoir type includes at least one of a non-barrier type, a thick barrier type, and a thin barrier type;
[0131] The first determining module 902 includes:
[0132] A third determining unit is configured to determine the non-interlayer type as the target reservoir type corresponding to the target reservoir if the thickness of the hard formation included in the target reservoir is less than a first thickness threshold;
[0133] a fourth determining unit, configured to determine the thin interlayer type as the target reservoir type corresponding to the target reservoir if the thickness of the hard formation included in the target reservoir is greater than the first thickness threshold and less than a second thickness threshold;
[0134] A fifth determining unit is configured to determine the thick barrier layer type as the target reservoir type corresponding to the target reservoir if the thickness of the hard formation included in the target reservoir is greater than the second thickness threshold.
[0135] Optionally, the wellbore trajectory model includes at least one of a flume model, a horizontal model and a wave model;
[0136] The first determining unit is further configured to:
[0137] If the target reservoir type is the non-interlayer type, the water tank model is determined as the target wellbore trajectory model corresponding to the target reservoir, the water tank model includes a first downlink segment, a first horizontal segment and a first uplink segment, the first downlink segment is connected to the first horizontal segment, and the first horizontal segment is connected to the first uplink segment;
[0138] If the target reservoir type is the thick barrier type, the horizontal model is determined as the target wellbore trajectory model corresponding to the target reservoir, the horizontal model includes a second descending segment and a second horizontal segment, and the second descending segment is connected to the second horizontal segment;
[0139] If the target reservoir type is the thin interlayer type shown, the wave model is determined as the target wellbore trajectory model corresponding to the target reservoir, and the wave model includes at least one third downward segment and at least one second upward segment, and the third downward segment is connected to the second upward segment.
[0140] Optionally, the target wellbore trajectory model is the water tank model, and the formation characteristic parameters further include the thickness of the target reservoir and a first control radius corresponding to the target reservoir;
[0141] The second determining unit is further configured to:
[0142] According to the thickness of the target reservoir and the first control radius, the first horizontal segment length of the target wellbore trajectory corresponding to the target reservoir is calculated, and the first horizontal segment length is the actual length of the first horizontal segment in the flume model.
[0143] Optionally, the target wellbore trajectory model is the horizontal model, and the formation characteristic parameter further includes a second control radius corresponding to the target reservoir;
[0144] The second determining unit is further configured to:
[0145] The second horizontal segment length of the target wellbore trajectory corresponding to the target reservoir is calculated according to the second control radius, and the second horizontal segment length is the actual length of the second horizontal segment in the horizontal model.
[0146] Optionally, the target wellbore trajectory model is the wave model, and the formation characteristic parameters further include the thickness of the target reservoir and a third control radius corresponding to the target reservoir;
[0147] The second determining unit is further configured to:
[0148] Calculating a third horizontal length of the target wellbore trajectory corresponding to the target reservoir according to the third control radius;
[0149] The well inclination angle of the target wellbore trajectory corresponding to the target reservoir is calculated according to the third control radius and the thickness of the target reservoir, and the well inclination angle includes the well inclination angle of the third downlink segment and the well inclination angle of the second uplink segment in the wave model.
[0150] In summary, by analyzing the distribution characteristics of hard formations in the reservoir, the reservoir type corresponding to the reservoir is determined, so that in the actual exploration process, the wellbore trajectory suitable for the reservoir can be determined according to the reservoir type, so that suitable well locations can be deployed for reservoirs with different hard formation distribution characteristics to avoid collapse during the exploration process, thereby reducing the cost of reservoir exploration and improving the success rate of reservoir exploration.
[0151] It should be noted that the device for determining the wellbore trajectory in the oil reservoir provided in the above embodiment is only illustrated by the division of the above functional modules. In actual applications, the above functions can be assigned to different functional modules as needed, that is, the internal structure of the equipment can be divided into different functional modules to complete all or part of the above description.
[0152] The present application also provides a computer device, which includes a processor and a memory, wherein the memory stores at least one instruction, and the at least one instruction is loaded and executed by the processor to implement the method for determining the wellbore trajectory in the oil reservoir provided by the above-mentioned various method embodiments. It should be noted that the computer device can be as follows Fig.10 Computer equipment provided.
[0153] Please refer to Fig.10, which shows a schematic diagram of the structure of a computer device provided by an exemplary embodiment of the present application. Specifically, the computer device 1000 includes a central processing unit (CPU) 1001, a system memory 1004 including a random access memory (RAM) 1002 and a read-only memory (ROM) 1003, and a system bus 1005 connecting the system memory 1004 and the central processing unit 1001. The computer device 1000 also includes a basic input / output (I / O) system 1006 that helps transmit information between various devices in the computer, and a large-capacity storage device 1007 for storing an operating system 1013, an application program 1014 and other program modules 1015.
[0154] The basic input / output system 1006 includes a display 1008 for displaying information and an input device 1009 such as a mouse and a keyboard for user inputting information. The display 1008 and the input device 1009 are connected to the central processing unit 1001 through an input / output controller 1010 connected to the system bus 1005. The basic input / output system 1006 may also include an input / output controller 1010 for receiving and processing inputs from a plurality of other devices such as a keyboard, a mouse, or an electronic stylus. Similarly, the input / output controller 1010 also provides output to a display screen, a printer, or other types of output devices.
[0155] The mass storage device 1007 is connected to the central processing unit 1001 through a mass storage controller (not shown) connected to the system bus 1005. The mass storage device 1007 and its associated computer readable media provide non-volatile storage for the computer device 1000. That is, the mass storage device 1007 may include a computer readable medium (not shown) such as a hard disk or a CD-ROM drive.
[0156] Without loss of generality, computer readable media may include computer storage media and communication media. Computer storage media include volatile and non-volatile, removable and non-removable media implemented by any method or technology for storing information such as computer readable instructions, data structures, program modules or other data. Computer storage media include RAM, ROM, Erasable Programmable Read Only Memory (EPROM), Electrically Erasable Programmable Read-Only Memory (EEPROM), flash memory or other solid-state storage technology, CD-ROM, Digital Video Disc (DVD) or other optical storage, cassettes, tapes, disk storage or other magnetic storage devices. Of course, those skilled in the art will appreciate that computer storage media are not limited to the above. The above-mentioned system memory 1004 and mass storage device 1007 can be collectively referred to as memory.
[0157] The memory stores one or more programs, and the one or more programs are configured to be executed by one or more central processing units 1001. The one or more programs contain instructions for implementing the above-mentioned shale oil production area division method. The central processing unit 1001 executes the one or more programs to implement the method for determining the wellbore trajectory in the oil reservoir provided by the above-mentioned various method embodiments.
[0158] According to various embodiments of the present application, the computer device 1000 can also be connected to a remote computer on the network through a network such as the Internet. That is, the computer device 1000 can be connected to the network 1012 through the network interface unit 1011 connected to the system bus 1005, or the network interface unit 1011 can be used to connect to other types of networks or remote computer systems (not shown).
[0159] The memory also includes one or more programs, one or more programs are stored in the memory, and one or more programs include steps executed by a computer device (server) in the method for determining the wellbore trajectory in the oil reservoir provided in the embodiment of the present application.
[0160] A person skilled in the art can understand that all or part of the steps in the various methods of the above embodiments can be completed by instructing the relevant hardware through a program, and the program can be stored in a computer-readable storage medium, which can be a computer-readable storage medium contained in the memory in the above embodiments; or a computer-readable storage medium that exists independently and is not assembled into a computer device. The computer-readable storage medium stores at least one instruction, at least one program, code set or instruction set, and the at least one instruction, at least one program, code set or instruction set is loaded and executed by a processor to implement the above method for determining the wellbore trajectory in the oil reservoir.
[0161] Optionally, the computer readable storage medium may include: ROM, RAM, solid state drives (SSD) or optical disks, etc. Among them, the random access memory may include resistance random access memory (ReRAM) and dynamic random access memory (DRAM).
[0162] According to one aspect of the present application, a computer program product or computer program is provided, the computer program product or computer program comprising computer instructions, the computer instructions being stored in a computer-readable storage medium. A processor of a computer device reads the computer instructions from the computer-readable storage medium, and the processor executes the computer instructions, so that the computer device executes the method for determining a wellbore trajectory in an oil reservoir provided in various optional implementations of the above aspects.
[0163] It should be understood that the "multiple" mentioned in this article refers to two or more. "And / or" describes the association relationship of associated objects, indicating that three relationships may exist. For example, A and / or B can represent: A exists alone, A and B exist at the same time, and B exists alone. The character " / " generally indicates that the objects associated before and after are in an "or" relationship. In addition, the step numbers described in this article only illustrate a possible execution sequence between the steps. In some other embodiments, the above steps may not be executed in the order of the numbers, such as two steps with different numbers are executed at the same time, or two steps with different numbers are executed in the opposite order to the diagram. The embodiments of the present application are not limited to this.
[0164] The above description is only an optional embodiment of the present application and is not intended to limit the present application. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present application shall be included in the protection scope of the present application.
Claims
1. A method for determining a wellbore trajectory in an oil reservoir, characterized in that: The method comprises: Acquire formation characteristic parameters corresponding to the target reservoir, wherein the formation characteristic parameters at least include the thickness of the hard formation contained in the target reservoir, and the target reservoir is a soft formation; Determining a target reservoir type corresponding to the target reservoir according to the formation characteristic parameters, wherein the reservoir type indicates a distribution characteristic of the hard formation in the target reservoir; According to the target reservoir type, a target wellbore trajectory model corresponding to the target reservoir is determined, wherein the wellbore trajectory model includes at least one of a flume model, a horizontal model and a wave model; different reservoir types correspond to different wellbore trajectory models, and the target wellbore trajectory model is a trajectory shape corresponding to the target wellbore trajectory in the target reservoir; Determine a target wellbore trajectory corresponding to the target reservoir according to the target wellbore trajectory model and the formation characteristic parameters, wherein the target wellbore trajectory is used to indicate the deployment position of the wellbore in the target reservoir, wherein the distribution characteristics of different hard formations correspond to different target wellbore trajectories; Determining a target wellbore trajectory model corresponding to the target reservoir according to the target reservoir type includes: If the target reservoir type is a non-interlayer type, the water tank model is determined as the target wellbore trajectory model corresponding to the target reservoir, the water tank model includes a first descending segment, a first horizontal segment and a first ascending segment, the first descending segment is connected to the first horizontal segment, the first horizontal segment is connected to the first ascending segment, the first ascending segment and the first descending segment both have a certain slope, and the first ascending segment and the first descending segment are located in the soft formation, and the first horizontal segment is located in the hard formation; If the target reservoir type is a thin barrier type, the wave model is determined as the target wellbore trajectory model corresponding to the target reservoir, and the wave model includes at least one third downlink segment and at least one second uplink segment, the third downlink segment is connected to the second uplink segment, and the third downlink segment and the second uplink segment pass through hard formations and soft formations.
2. The method according to claim 1, characterized in that The reservoir type includes at least one of a non-interlayer type, a thick-interlayer type, and a thin-interlayer type; Determining the target reservoir type corresponding to the target reservoir according to the formation characteristic parameters includes: If the thickness of the hard formation contained in the target reservoir is less than a first thickness threshold, determining the non-interlayer type as the target reservoir type corresponding to the target reservoir; If the thickness of the hard formation contained in the target reservoir is greater than the first thickness threshold and less than the second thickness threshold, the thin interlayer type is determined as the target reservoir type corresponding to the target reservoir; If the thickness of the hard formation contained in the target reservoir is greater than the second thickness threshold, the thick barrier layer type is determined as the target reservoir type corresponding to the target reservoir.
3. The method according to claim 2, characterized in that Determining a target wellbore trajectory model corresponding to the target reservoir according to the target reservoir type further includes: If the target reservoir type is the thick barrier type, the horizontal model is determined as the target wellbore trajectory model corresponding to the target reservoir, and the horizontal model includes a second downward segment and a second horizontal segment, and the second downward segment is connected to the second horizontal segment.
4. The method according to claim 3, characterized in that The target wellbore trajectory model is the water tank model, and the formation characteristic parameters further include the thickness of the target reservoir and the first control radius corresponding to the target reservoir; Determining the target wellbore trajectory corresponding to the target reservoir according to the target wellbore trajectory model and the formation characteristic parameters includes: According to the thickness of the target reservoir and the first control radius, the first horizontal segment length of the target wellbore trajectory corresponding to the target reservoir is calculated, and the first horizontal segment length is the actual length of the first horizontal segment in the flume model.
5. The method according to claim 3, characterized in that: The target wellbore trajectory model is the horizontal model, and the formation characteristic parameters further include a second control radius corresponding to the target reservoir; Determining the target wellbore trajectory corresponding to the target reservoir according to the target wellbore trajectory model and the formation characteristic parameters includes: The second horizontal segment length of the target wellbore trajectory corresponding to the target reservoir is calculated according to the second control radius, and the second horizontal segment length is the actual length of the second horizontal segment in the horizontal model.
6. The method according to claim 3, characterized in that: The target wellbore trajectory model is the wave model, and the formation characteristic parameters further include the thickness of the target reservoir and a third control radius corresponding to the target reservoir; Determining the target wellbore trajectory corresponding to the target reservoir according to the target wellbore trajectory model and the formation characteristic parameters includes: Calculating a third horizontal length of the target wellbore trajectory corresponding to the target reservoir according to the third control radius; The well inclination angle of the target wellbore trajectory corresponding to the target reservoir is calculated according to the third control radius and the thickness of the target reservoir, and the well inclination angle includes the well inclination angle of the third downlink segment and the well inclination angle of the second uplink segment in the wave model.
7. A device for determining a wellbore trajectory in an oil reservoir, characterized in that: The device comprises: An acquisition module, used for acquiring formation characteristic parameters corresponding to a target reservoir, wherein the formation characteristic parameters at least include the thickness of a hard formation contained in the target reservoir, and the target reservoir is a soft formation; A first determination module is used to determine a target reservoir type corresponding to the target reservoir according to the formation characteristic parameters, wherein the reservoir type indicates a distribution characteristic of the hard formation in the target reservoir; A first determination unit is used to determine a target wellbore trajectory model corresponding to the target reservoir according to the target reservoir type, wherein the wellbore trajectory model includes at least one of a flume model, a horizontal model and a wave model; different reservoir types correspond to different wellbore trajectory models, and the target wellbore trajectory model is a trajectory shape corresponding to the target wellbore trajectory in the target reservoir; A second determination unit is used to determine a target wellbore trajectory corresponding to the target reservoir according to the target wellbore trajectory model and the formation characteristic parameters, wherein the target wellbore trajectory is used to indicate the deployment position of the wellbore in the target reservoir, wherein the distribution characteristics of different hard formations correspond to different target wellbore trajectories; The first determination unit is further used for, if the target reservoir type is a non-interlayer type, determining the water tank model as the target wellbore trajectory model corresponding to the target reservoir, the water tank model comprising a first downlink segment, a first horizontal segment and a first uplink segment, the first downlink segment is connected to the first horizontal segment, the first horizontal segment is connected to the first uplink segment, the first uplink segment and the first downlink segment both have a certain slope, and the first uplink segment and the first downlink segment are located in the soft formation, and the first horizontal segment is located in the hard formation; if the target reservoir type is a thin interlayer type, determining the wave model as the target wellbore trajectory model corresponding to the target reservoir, the wave model comprising at least one third downlink segment and at least one second uplink segment, the third downlink segment is connected to the second uplink segment, and the third downlink segment and the second uplink segment pass through the hard formation and the soft formation.
8. A computer device, characterized in that: The computer device includes a processor and a memory, wherein the memory stores at least one instruction, and the instruction is loaded and executed by the processor to implement the method for determining a wellbore trajectory in an oil reservoir as described in any one of claims 1 to 6.
9. A computer-readable storage medium, characterized in that: The readable storage medium stores at least one instruction, and the at least one instruction is loaded and executed by the processor to implement the method for determining a wellbore trajectory in an oil reservoir as described in any one of claims 1 to 6.